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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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' 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: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 7-. I. s'2 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: , vLogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Dat Date: //41/6--- /s/ ae Project Proofing BY: 405 Date: 5/4. /s/ u • Scanning Preparation (Q x 30 = 1 0 + a 0 = TOTAL PAGES a OO (Count does not include cover sheet) BY: OP Date: 5/ IfAs—� /s/ Production Scanning Stage 1 Page Count from Scanned File: c 0I (Count does include cover sheet) Pa•e Count Matches Number in Scanning Preparation: VYES NO BY: dp Date: 6141 IE. /s/ (114 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES: 12-' Digital version appended by: Meredith Michal Date: 5/q((s- /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 333 Scanning is complete at this point unless rescanning is required. 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O aaR 7 CL = 0 w IX z CO w J W J U ca, o Z a r, N 7 J as o. ° co ICI- o o O ' o- E Uj� 3 U o a' co a, a z u Z a r co G o a 0 C = N c z M m 16 CO m o 0 a o • m a c n Z E 0 U m 2 a • co Co N > v d o d N 1 > d E co re 0 N H1 0 O C C U c6 C7 Q a 2 0 ci RECEIVED -, STATE OF ALASKA ALASKA viL AND GAS CONSERVATION COMMISSION J A N 0 9 : ii ill REPORT OF SUNDRY WELL OPERATIONS Alaska Oil&t La:.Co .rrCommissi 1.Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U AM ftenpletion Performed: Alter Casing ❑ Pull Tubing Perforate New Pool 0 Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Perforate 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: \§.Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc. Development 0 ExploratoryBC 207-182 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service API Number: Anchorage,AK 99501 50-703-20561-00 7.Property Designation(Lease,Number): 8.Well Name and Num er: ADL 355036 ODSN-36 9.Field/Pool(s): \ Oooguruk-Nuiqsut Oil Pool 10.Present Well Condition Summary: Total Depth measured\ 17,525 feet Plugs(measured) N/A feet true vertical 6380 feet Junk(measured) N/A feet Effective Depth measured 17,449 feet Packer(measured) see info below feet true vertical 6370 feet (true vertical) feet Casing Length Size MD ND Burst Collapse Structural Conductor 114' 16" 158' 158' N/A N/A Surface 3625' 9-5/8" 3665' 3014' 5750 3090 Intermediate 10,580' 7" 10,618' 6396' 7240 5410 Production Liner 6997' 4-1/2" 10,453'- 17,450' 6353'-6370' N/A N/A Perforation depth: Measured depth: See Attachment,pg.2 True Vertical depth: See Attachment,pg.2 Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80, IBT-M 8866'MD 5909'TVD 2-7/8"ScSSSV WFT 7"x 2-7/8" / WFT Liner Top Pkr WFT Swell Pkrs 11,297 MD/6454 m Dm& Packers and SSSV (type,measured and true vertical depth): 755'MD/754TVD 4859'MD/37951-VD 10,469'MD/6358TVD 1 ,2g7�MD/645TVD 11.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 77 bbls diesel freeze protect;3500 psi 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 568 392 0 1185 312 Subsequent to operation: 823 167 0 244 275 13.Attachments: I.Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ❑ Daily Report of Well Operations X Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WAG 0 GINJ❑ WINJ❑ SPLUG 0 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: 309-348 Contact Tim Crumrine,343-2184 Prepared By:Kathy Campoamor,343-2183 Printed Name Ver oh Title Sr.Staff Drilling Engineer Signature .-�� /764) Phone 343-2111 Date 1/6/2010 MOMS JAN 112Qp Ai// ,0 '' ' G Form 10-404 Revised 7/2009 Submit Original Only Pioneer Natural Resources Alaska Inc. ODSN-36 Page 2 AOGCC Form 10-404, Report of Sundry Well Operations Box #10, Attachment - Perforation Depth 10. Perforation Depth (MD and TVD) 4-1/2", 12.6#, L-80 Liner - perforated pup jts with 6-1/2" holes @ depths listed: MD TVD 10,794' - 10,798' 6432' - 6433' 11,503' - 11,507' 6446' - 6446' 11,692' - 11,696' 6435' - 6435' 11,881' - 11,885' 6419' - 6419' 12,072' - 12,076' 6404' - 6404' 12,262' - 12,266' 6388' - 6387' 12,452' - 12,456' 6374' - 6374' 12,642' - 12,646' 6364' - 6364' 12,832' - 12,836' 6358' - 6358' 13,021' - 13,025' 6355' - 6355' 13,209' - 13,213' 6350' - 6350' 13,416' - 13,420' 6344' - 6344' 13,618' - 13,622' 6340' - 6340' 13,827' - 13,831' 6347' - 6347' 14,037' - 14,041' 6359' - 6360' 14,247' - 14,251' 6374' - 6374' 14,447' - 14,451' 6385' - 6385' 14,644' - 14,648' 6391' - 6391' 14,842' - 14,846' 6387' - 6387' 15,039' - 15,043' 6382' - 6382' 15,239' - 15,243' 6382' - 6383' 15,440' - 15,444' 6383' - 6383' 15,641' - 15,645' 6382' - 6381' 15,843' - 15,847' 6375' - 6375' 16,043' - 16,047' 6361' - 6360' 16,243' - 16,247' 6346' - 6346' 16,445' - 16,449' 6334' - 6334' 16,646' - 16,650' 6324' - 6324' 16,849' - 16,853' 6316' - 6316' 17,050' - 17,054' 6323' - 6323' 17,250' - 17,254' 6345' - 6345' PIONEER 1perations Summary Report NATURAL RESOURCES Well Name: ODSN-36 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT COMPLETION Start Date: 12/1/2009 End Date: 12/4/2009 Depth Start Foot/Meters Last Mud Start Date End Date (ftKB) (ft) Dens(lb/gal) Summary 12/1/2009 12/2/2009 17,525.0 8.50 RU slickline unit& lubricator. RIH to 6,872'wlm, latch on to roller stem ball and rod, POOH with same. RIH to 6,880'wlm,latch on to RHC-M plug, POOH with same. RD slickline unit. RD Nabors 19AC.Skid rig from ODSN-37 to ODSN-36. RU same. RU kill line to reverse circulate on IA. Reverse circ 155 bbls down the IA taking returns to the flowback tanks. Bull head 133 bbls seawater down the IA.Bleed gas cap of tubing down to 0. Install BPV in tubing hanger. Install test dart on BPV. NU BOPE and all MPD equipment. RU test equipment.Test Annular to 250 psi low/2500 psi hgh.Test Upper 2-7/8"x 5" VBR's, Lower 4.5"Single Bore Rams with 4.5"tubing, Blind Rams,Choke and Kill Line HCR's,Choke and Kill Line manual valves, Floor I Safety Valve, Dart valve, Upper and Lower IBOP, 14 Choke manifold valves to 250 psi low/ 3500 psi high.All low and high tests held 5 min ea.All tests charted.Accumulator test,System Pressure 2900 psi,After Closure 2000 psi, Initial 200 psi recovery 19 sec's, Full recovery 1 min 33 sec's.AOGCC representative John Crisp waived witness of test on 12/01/09 at 13:15 hrs. RD test equipment. Rig accepted 12/01/09 @ 00:00 hrs 12/2/2009 112/3/2009 17,525.0 8.50'Removed BOPE Test Plug and BPV. Pull Hanger to rig floor.Circulated well with seawater. Monitored well,Well taking fluid at 30 bph.POOH with 4-1/2' Hydril Frac strin0. Installed BOPE Test Plug.Change lower rams f/4-1/2"-U 2-7/8".Test Annular to 250 psi low/2500 psi high. Test Upper VBR's(2-7/8"x 5")and Lower 2-7/8"Rams(single bore)to 250 psi low/3500 psi high.All test held 5 min each.All tested charted.RU 2-7/8"Tubing Tongs and handling equipment. PU and MU BHI Centrilifts Pump Assy and Discharge Head Assy. 12/3/2009 12/4/2009 17,525.0 8.50 MU Centrilifts Pump Assy,Discharge Head Assy, Discharge Gauge Assy and Automatic Divert Valve. Make Motor Lead Extension connection and Discharge Gauge SS Control line. Perform ESP cable splice to Centirlifts Pump Assy. RIH w/2-7/8"ESP Completion Tubing as per Tally f/75' t/5,021'. 12/4/2009 12/5/2009 17,525.0 8.50 RIH w/2-7/8" ESP Completion Tubing and land at 8,866'.Test Upper and Lower Hanger seals to 5000 psi. Remove Landing Jt and install TWC.Change Lower rams to 4-1/2".ND BOPE's. NU Tubing Adaptor and Production Tree.Test to 250 psi low/5000 psi,high. RU circulating manifold to wellhead.Rig released 12/04/09 @ 24:00 hrs. Page 1/1 Report Printed: 1/4/2010 ;a ` , ODSt. 6 As Run ESP Compilion Casing Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 9-5/8"40#L-80 BTC,8.835"ID 3,665 3,014 C 7"26#L-80 BTC-M,6.276"ID 10,618 6,399 D 4-1/2" 12.6#Hydril 521 1958"ID 17,450 6,370 E '2-7/8"6.5#L-80 IBT-M,2.441"ID 8,866 5,909 ipilWell Head: 9-5/8",5K,VetcoGray -.� , 1. 'r. Tree: 4-1/2",5K,Horizontal 1 VetcoGray Tubing Hanger 34 34 2 2-7/8"Wellstar Tubing Retreiveble ScSSSV 755 754 3 GLM#1 -2-7/8"x 1-1/2"(min.3 jts above top X nipple) 4,664 3,675 0 I 2-7/8"X Nipple 2.313"I.D.(min.2 jts above Gas Vent III 4 Valve Pa 5 TVD cker) 4,777 3,744 WFT 7"x 2-7/8"Gas Vent Valve Packer(max. 3800') 4,859 3,795 AA A ` 6 GLM#2-2-7/8"x 1-1/2"(min.2 jts above X nipple) 8,013 5,628 2-7/8"X Nipple,2.313" ID(max. incl.66 deg)w/RHC-M AV 7 Plug Body 8,094 5,662 0 8 Automatic Divert Valve(ADV) 8,795 5,889 9 ESP(Pump, Motor,and Jewelry) 8,805 5,892 End of Assembly 8,866 5,909 1. E ' 10 WFT PBR Tie Back Sleeve 15ft 10,453 6,353 0 I11 WFT"NTH"Liner Top Pkr 10,469 6,358 _ 12 WFT"PHR"Rotating Hyd Set Liner Hanger 10,472 6,359 13 4-1/2"12.60L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes). 10,794 6,432 WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base s 14 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 10,867 6,445 B 15 Blank Pipe III ON WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base 16 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 11,297 6,454 5� 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,503 6,446 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,692 6,436 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,881 6,419 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,072 6,404 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,262 6,388 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,452 6,374 O J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,642 6,364 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,832 6,358 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,021 6,355 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,209 6,350 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,416 6,344 ■ ■ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,618 6,339 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,827 6,347 _ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,037 6,359 8) 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,247 6,374 0 O 0 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 14,447 6,385 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,644 6,391 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,842 6,387 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,039 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,239 6,383 g 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,440 6,384 �� 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,641 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,843 6,376 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,043 6,361 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,243 6,346 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,445 6,334 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,646 6,324 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,849 6,315 10 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,050 6,323 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 17,250 6,345 WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 pri /�117\ 17 Box 17,449 6,370 TD 17,450 6,370 0 13 ' 17 00 • ,16 00 00 00 00 00 00 14 15 00 00 00 00 00 \ / 00 00 00 00 00 00 Date: Revision By: Comments PlO N E E 10/07/2009 TWC Proposed ESP Completion Design ODSN-36 Producer 11/20/2009 TWC Removed XN Nipple Well Schematic NEW RESOURCES AIAS10 12/09/2009 TWC Final Completion ESP Completion -, E Gji r in\ t L SEAN PARNELL,GOVERNOR F � I ALASKA OIL AND GAS / 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 1` FAX (907)276-7542 Mr. James Frank Sr. Staff Drilling Engineer Pioneer Natural Resources 700 G Street, Suite 600 �.. Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk-Nuiqut Oil Pool, ODSN-36 Sundry Number: 309-348 Dear Mr. Frank: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4# Daniel T. Seamount, Jr. Chair DATED this g day of October, 2009 Encl. ap, A RECEIVED STATE OF ALASKA 0 C T 0 7 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALska Oil&Gas Cons.Commission 20 AAC 25.280 An rete 1.Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver Other❑.r Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ ESP Completion - Change approved program❑ Pull Tubing Q - 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 2 . Exploratory ❑ 207-182 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 700 G Street, Suite 600 Anchorage,AK 99501 50-703-20561-00 - 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes ❑ No O . ODSN-36 9.Property Designation: 10.KB Elevation(ft): 11.Field/Pool(s): ADL 355036 • 56.2' Ooogurk-Nuiqsut Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17,525' • 6380' • 17,448' 6370' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 158' 158' N/A N/A Surface 3625' 9-5/8" 3665' 3014' 5750 psi 3090 psi Intermediate 10580' 7" 10,618' 6396' 7240 psi 5410 psi Production 6997' - 4-1/2" 17,450' 6370' N/A N/A Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment&Schematic See Attachment&Schematic 4-1/2", 12.6# L-80, Hydril 521 10,430' Packers and SSSV Type: ScSSSV;W FT"NTH" Liner Top Packer; Packers and SSSV MD(ft): W FT Swell Packer;WFT Swell Packer 755'; 10,469'; 10,867'; 11,297' 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Development Q • Service ❑ 15. Estimated Date for 16.Well Status after proposed work: Commencing Operations: 10/19/2009 Oil 0 , Gas ❑ Plugged ❑ Abandoned ❑ 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name James Franks Title Sr. Staff Drilling Engineer Signature hone 343-2179 Date 10/7/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /� 3/ is 34 Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ v I Other: 3 500 ps 066 f l c�S 4 Z Sao Pry �n n ...Ar i";:,)"/'"C Subsequent Form Required: !d— go `/ APPROVED BY Approved by ,r / - - . COMMISSIQNE�, t C TH MISSION Date: /6 i qi / Form 10-403 Revis :. ,r. 4'n13 �� �.0 SubmitteD D • Pioneer Natural Resources Alaska Inc. ODSN-36 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Box #12, Perforation Attachment - Present Well Condition Summary 23. Open to production or injection i 4_ " -, 12.6#, L-80 Linerperforated pup jts with 6-1/2" holes @ depths listed: MD TVD 10,794' - 10,798' 6432' - 6433' 11,503' - 11,507' 6446' - 6446' 11,692' - 11,696' 6435' - 6435' 11,881' - 11,885' 6419' - 6419' 12,072' - 12,076' 6404' - 6404' 12,262' - 12,266' 6388' - 6387' 12,452' - 12,456' 6374' - 6374' 12,642' - 12,646' 6364' - 6364' 12,832' - 12,836' 6358' - 6358' 13,021' - 13,025' 6355' - 6355' 13,209' - 13,213' 6350' - 6350' 13,416' - 13,420' 6344' - 6344' 13,618' - 13,622' 6340' - 6340' 13,827' - 13,831' 6347' - 6347' 14,037' - 14,041' 6359' - 6360' 14,247' - 14,251' 6374' - 6374' 14,447' - 14,451' 6385' - 6385' 14,644' - 14,648' 6391' - 6391' 14,842' - 14,846' 6387' - 6387' 15,039' - 15,043' 6382' - 6382' 15,239' - 15,243' 6382' - 6383' 15,440' - 15,444' 6383' - 6383' 15,641' - 15,645' 6382' - 6381' 15,843' - 15,847' 6375' - 6375' 16,043' - 16,047' 6361' - 6360' 16,243' - 16,247' 6346' - 6346' 16,445' - 16,449' 6334' - 6334' 16,646' - 16,650' 6324' - 6324' 16,849' - 16,853' 6316' - 6316' 17,050' - 17,054' 6323' - 6323' 17,250' - 17,254' 6345' - 6345' ODSN-36 Oac String Completion - As Run Casing Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 9-5/8"40#L-80 BTC,8.835"ID 3,665 3014 C 7"26#L-80 BTC-M,6.276"ID 10,618 6399 Well Head: 9-5/8",5K,VetcoGray D 4-1/2"12.6#Hydril 521 3.958"ID 17,450 Tree: 4-1/2",5K, Horizontal 'Estimated TOC @ 4025'MD O 1 VetcoGray Tubing Hanger 34 34 4-1/2"XXO Safety Val'.e Landing Nipple w/Wireline ' ` 2 Retreivable ScSSSV 755 754 3 GLM#1 Brou-1A GLM 4-1/2"x 1" 2,697 2,396 ' 4 GLM#2 Brou-1A GLM 4-1/2"x 1" 5,018 3,892 5 GLM#3 Brou-1A GLM 4-1/2"x 1" 6,292 4,696 O6 GLM#4 Brou-1A GLM 4-1/2"x 1" 7,336 5,305 7 4 1/2"XN Nipple,3.725" ID Nogo 8,047 5,643 End of Assembly 10,465 6,357 O 8 WFT PBR Te Back Sleeee 158 10,453 6,353 9 WFT"NTH"Liner Top Pkr 10,469 6,358 3 J 10 WFT"PHR"Rotating Hyd Set Liner Hanger 10,472 6,359 11 4-1/2" 12.60E-80 Hydril Pupjt Oft(Ported w/6 1/2 holes). 10,794 6,432 WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base ® 12 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 10,867 6,445 13 Blank Pipe WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base 14 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 11,297 6,454 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,503 6,446 q 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,692 6,436 J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,881 6,419 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,072 6,404 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,262 6,388 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,452 6,374 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,642 6,364 ._J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,832 6,358 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,021 6,355 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,209 6,350 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,416 6,344 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,618 6,339 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,827 6,347 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,037 6,359 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,247 6,374 U6 J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,447 6,385 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 14,644 6,391 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,842 6,387 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,039 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,239 6,383 4-1/2 12.60 L-80 Hydril Pupjt 48(Ported w/6 1/2 holes) 15,440 6,384 O. 44--11//22 -1/2 12.60 L-80 Hydril Pupjt 48(Ported w/6 1/2 holes) 15,641 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,843 6,376 112 .„ 4-1/2 12.60 L-80 Hydril Pupil 48(Ported w/6 1/2 holes) 16,043 6,361 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,243 6,346 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,445 6,334 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,646 6,324 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,849 6,315 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,050 6,323 9 ` 8 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,250 6,345 WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 15 Box 17,449 6,370 10) TD 17,450 6,370 14 O 11 ,2 ..00 00 00 00 (---1-300 "00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 I I . 17525'MDrkb/6,380'TVDrkb Date: Revision By: Comments PlO N E E R8/7/2009 TWC Pre-TD Update 09/14/2009 TWC As-Run ODSN-36 Producer Well Schematic NA1URALRES00RCESALAS(A Frac String Completion • . , . , ODSNI 3 Proposed ESP Com, -ation Casing Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 9-5/8"40#L-80 BTC,8.835"ID 3,665 3014 C 7"26#L-80 BTC-M,6.276"ID 10,618 6399 D 4-1/2"12.6#Hydril 521 3.958"ID 17,450 Well Head: 9-5/8",5K,VetcoGray 'Estimated TOC @ 4025'MD Tree: 4-1/2",5K,Horizontal 1 VetcoGray Tubing Hanger 34 34 0 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 750 750 3 GLM#1-2-7/8"x 1-1/2"(min.3 jts above top X nipple) 4,670 3,678 2-7/8"X Nipple 2.313"I.D.(min.2 jts above Gas Vent ® ' ` 4 Valve Packer) 4,770 3,740 5 WFT 7"x 2-7/8"Gas Vent Valve Packer(max.TVD 3800') 4,850 3,789 -1♦ 1 2-7/8"X Nipple 2.313"I.D.(min.2 jts below Gas Vent 6 Valve Packer) 4,930 3,838 7 GLM#2-2-7/8"x 1-1/2"(min.2 jts above)0'1 nipple) 8,020 5,63-1- 8 2-7/8"XN Nipple,2.205"ID Nogo(min.2 jts above ESP) 8,100 5,665 9 Automatic Divert Valve(ADV) 8,800 5,890 10 ESP(Pump,Motor,and Jewelry) 8,807 5,892 D End of Assembly 8,867 5,909 11 WFT PBR Tie Back Sleeve 15ft 10,453 6,353 I 12 WFT"NTH"Liner Top Pkr 10,469 6,358 n 13 WFT"PHR"Rotating Hyd Set Liner Hanger 10,472 6,359 6,432 O ���J 14 4-1/2"12.60L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes). 10,794 WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base • Oq 15 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 10,867 6,445 16 Blank Pipe 2 O 2K WFT Genesis 5.750 OD x 41/2 12.60 x 15 Ft Oil Base 17 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 11,297 6,454 IN M 6 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,503 6,446 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,692 6,436 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,881 6,419 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,072 6,404 O J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,262 6,388 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,452 6,374 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,642 6,364 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,832 6,358 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,021 6,355 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,209 6,350 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,416 6,344 II O8 . 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,618 6,339 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,827 6,347 Og _ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,037 6,359 O O O _ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,247 6,374 _ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,447 6,385 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,644 6,391 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,842 6,387 _ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,039 6,382 10 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 15,239 6,383 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 15,440 6,384 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,641 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,843 6,376 I4-1/2 12_.60 L-80 Hydril Pupjt 48(Ported w/6 1/2 holes) 16,043 6,361 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,243 6,346 4-1/2 12.60 L 80Hydr l Pupjt Oft(Ported w/6 1/2 holes) 16,445 6,334 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,646 6,324 41/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 16,849 6,315 11 41/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,050 6,323 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,250 6,345 ® 14 WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 18 Box 15 17,449 6,370 TD 17,450 6,370 O 16 17 18 . 00 00 00 •• 00 00 00 00 00 00 00 00 00 00 00 00 00 0 0 im 00 00 00 Date: Revision By: Comments P 10 N E E R - 10/07/2009 TWO Proposed ESP Completion Design ODSN-36 Producer NATURAL RESOURCES ALAS0 well Schematic ESP Completion P to N E Ek RECEIVED OCT 0 7 2009 NATURAL R E S O U R C E SAIaska ori&Gas cons.Commission Anchorage October 7, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry, Recomplete with an ESP Permit to Drill # 207-182 Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM X = 469881.69, Y = 6031065.83, ASP4 Pioneer Natural Resources, Alaska (PNRA) is submitting an ESP recompletion proposal for AOGCC's review and approval for the ODSN-36 well. The proposed plan is as follows: Pre-Rig Work: 1. Provide 48 hours notice for the testing of the BOPE. 2. Post Permit to Drill #207-182 Re-Complete ODSN-36 with ESP 1. Kill well, Circ kill weight brine 2. MIRU ODSN-36. 3. ND Tree, NU BOPE 4. Test BOPE as per AOGCC to 250/3500 psi 5. Pull 4 1/2"fracture completion string. 6. MU completion with ESP and RIH. 7. Land the tubing and RILDS. 8. Circulate corrosion inhibited brine and diesel to freeze protect the well to —2000' TVD. 9. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi—chart and hold for 30 Alaska Oil & Gas Conservation Commission October 7, 2009 Page 2 of 3 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi—chart and hold for 30 minutes. Bleed off pressure. 10. Install TWC 11. ND BOPE, NU tree, test to 5,000 psi. 12. Remove TWC 13. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 14. RD Slickline. RDMO to next well. Alaska Oil & Gas Conservation Commission October 7, 2009 Page 3 of 3 Please find attached information for your review: 1) Form 10-403 Application for Sundry. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report James Franks, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2179 iames.frankspxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggett a(�pxd.com Sincerely, James Franks Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-36 Well File Page 1 of 1 Maunder, Thomas E (DOA) From: Vaughan, Alex [AIex.Vaughan@pxd.com] Sent: Wednesday, September 30, 2009 2:21 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vern Subject: RE: ODSN-36 (207-182) Tom, Please find ODSN-36 fracture Stimulation Operations Summary Below: R/U SLB frac equipment on ODSN-36 and hold PJSM. Pressure test system to 8500 psi-good test. Pump frac job as per SLB design. Pumped 6,950 bbls of YF125ST and 610,800 lbs of 20/40 C-Lite. Pumped approximately 20 bio-balls per stage as diverting agent to complete 10 fractures along the horizontal zone from 11300 ft to 17500 ft. Average Pressure 4150 psi, Average Rate 40.0 BPM, Total Clean Fluid Pumped 7650 bbls, Total Slurry Fluid Pumped 8,211 bbls, Total 20/40 C-Lite Proppant Pumped 610,800 lbs. Further information can be provided as required. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Tuesday, September 29, 2009 1:19 PM To: Vaughan, Alex Cc: Johnson, Vern Subject: ODSN-36 (207-182) Alex and Vern, I am reviewing the completion report(10-407)for this well. Could you provide more detail regarding the frac operation? On the work reported for August 12 — 13, the only information provided is"...perform frac job as per frac design with RA tracers"which does not provide sufficient operational details. Thanks in advance. Tom Maunder, PE AOGCC 9/30/2009 ' ' Ai STATE OF ALASKA ;' ALAShm OIL AND GAS CONSERVATION COMMISiuN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil .'Gas❑ Plugged❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25105 20AAC 25110 Development Q Exploratory GINJ❑ WINJ❑ WDSPL❑ WAG❑ Others No.of Completions: 1 Service ❑ Stratigraphic Test❑ 2.Operator Name 5.Date Comp.,Susp.,or /12.Permit to Drill Number: Z 0c.‘_rta Pioneer Natural Resources Alaska Inc Aband.: 8/13/2009 207-182 SOct-‘5S 3.Address: 6.Date Spudded: 13.API Number: 700 G Street, Suite 600,Anchorage,AK 99501 1/30/2008 ✓ 50-703-20561-00 / 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number. Surface: 2951' FSL, 1117' FEL, Sec. 11,T13N, R7E, UM 8/6/2009 L./ ODSN-36 ./ Top of Productive Horizon: 8.KB(ft above MSL): 56.2''15.Field/Pool(s): 732' FSL, 3909' FEL, Sec. 11,T13N, R7E, UM Ground(ft MSL): 13.50/ Total Depth 9. Plug Back Depth(MD+TVD): Oooguruk- Nuiqsut Oil Pool 322' FSL, 3388'FEL, Sec. 3,T13N, R7E, UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27)• 10.Total Depth(MD+TVD): 16.Property Designation. Surface: x- 469881.69 y- 6031065 83 Zone-AsP4 17,525'/MD/6380'1VD ADL 355036 / TPI. x- 467082.51 y- 6028859.56 Zone-AsP4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 462339.62/ y- 6033752.14 i Zone-ASP4 755'MD/754'TVD 417497 18.Directional Survey: Yes Q 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) 862' 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD, DIR, MWD, GR, EWR, GABI, DGR, PWD, CTN, RES, DEN, DDS-R 22. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 1094 H-40 Surface 158' Surface 158' 24" Driven 9-5/8" 40# L-8o BTC Surface 3665' Surface 3014' 12-1/4' 438 sx PF'L',201 sx Class'G' 7" 26# L-80 Surface 10.618' Surface 6396' 8-3/4" 161 sx 12.5ppg Class'G' BTC-M 109 sx 15.800a Class'G' 4-1/2" 12.6# L-80 10,453' 17,450' 6353' 6370' 6-1/8" Uncemented Liner 23 Open to production or injection? Yes2 No If Yes,list each 24. TUBING RECORD 0-'11 s....to interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) )r-VA�SS 4-1/2", 12.6#, L-80 ya4'36 r 10,469';10,867'; 11,297' �oti1c►5 1='\sc- -o v uosr See Attachment (page 3) ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See perf detail, pg.3 617,800#20/40 Carbolite 26. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.): 8/15/2009 Gas Lift Date of Test Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 8/15/2009 12 Test Period ..► 1820 217.8 214.9 3" 120 Flow Tubing Casing Press: Calculated Oil-Bbl. Gas-MCF: Water-Bbl: Oil Gravity-API(corr). Press. 449 1161.0 24-Hour Rate ...00 3640 435.6 429.8 18 27. CORE DATA Conventional Core(s)Acquired? Yes❑ No Q Sidewall Cores Acquired? Yes ❑ No E 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,it needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. COMPLETION VIE None 'E3 D RBOMS BFL EP: 2009 ;_ 4`cRIFiZ ` Form 10-407 Revised 2/2007 CONTINUED ON REVERSE Arc%ck 6 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes C No 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 844' 842' Base Permafrost 1780' 1704' Top West Sak 2710' 2404' Top Torok 6920' 5078' Top HRZ 8429' 5781' Top Kuparuk C 9461' 6074' Top Nuiqsut 10,568' 6384' None 30. List of Attachments:Summary of Daily Drilling Operations,Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan,343-2186 Printed Name: Vern son Title: Sr. Staff Drilling Engineer Signature: ✓ Phone: 343-2111 Date: 9/14/2009 Well No.ODSN-36 Permit No.207-182 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 Pioneer Natural Resources Alaska Inc. ODSN-36 Page 3 AOGCC Form 10-407, Well Completion or Recompletion Report and Log Box #23, Attachment 23. Open to production or injection 4-1", 12.6#, L-80 Liner - perforated pup jts with 6-1/2" holes @ depths listed: MD TVD 10,794' - 10,798' 6432' - 6433' 11,503' - 11,507' 6446' - 6446' 11,692' - 11,696' 6435' - 6435' 11,881' - 11,885' 6419' - 6419' 12,072' - 12,076' 6404' - 6404' 12,262' - 12,266' 6388' - 6387' 12,452' - 12,456' 6374' - 6374' 12,642' - 12,646' 6364' - 6364' 12,832' - 12,836' 6358' - 6358' 13,021' - 13,025' 6355' - 6355' 13,209' - 13,213' 6350' - 6350' 13,416' - 13,420' 6344' - 6344' 13,618' - 13,622' 6340' - 6340' 13,827' - 13,831' 6347' - 6347' 14,037' - 14,041' 6359' - 6360' 14,247' - 14,251' 6374' - 6374' 14,447' - 14,451' 6385' - 6385' 14,644' - 14,648' 6391' - 6391' 14,842' - 14,846' 6387' - 6387' 15,039' - 15,043' 6382' - 6382' 15,239' - 15,243' 6382' - 6383' 15,440' - 15,444' 6383' - 6383' 15,641' - 15,645' 6382' - 6381' 15,843' - 15,847' 6375' - 6375' 16,043' - 16,047' 6361' - 6360' 16,243' - 16,247' 6346' - 6346' 16,445' - 16,449' 6334' - 6334' 16,646' - 16,650' 6324' - 6324' 16,849' - 16,853' 6316' - 6316' 17,050' - 17,054' 6323' - 6323' 17,250' - 17,254' 6345' - 6345' ODSN-36 'ac String Completior ' As Run Casing Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 9-5/8"40#L-80 BTC,8.835"ID 3,665 3014 C 7"26#L-80 BTC-M,6.276"ID 10,618 6399 Well Head: 9-5/8",5K,VetcoGray D 4-1/2"12.6#Hydril 521 3.958"ID 17,450 Tree: 4-1/2",5K,Horizontal *Estimated TOC @ 4025'MD 0 1 VetcoGray Tubing Hanger 34 34 L. 4-1/2")0(O Safety Valve Landing Nipple w/Wireline O ' 2 Retrei able ScSSSV 755 754 3 GLM#1 Brou-1A GLM 4-1/2"x 1" 2,697 2,396 --1. 27114 GLM#2 Brou-1A GLM 4-1/2"x 1" 5,018 3,892 5 GLM#3 Brou-1A GLM 4-1/2"x 1" 6,292 4,696 2 6 GLM#4 Brou-1A GLM 4-1/2"x 1" 7,336 5,305 �/ 7 4 1/2"XN Nipple,3.725"ID Nogo 8,047 5,643 End of Assembly 10,465 6,357 Oitertt = , 8 WFT PBR Te Back Sleeve 15ft 10,453 6,353 9 WFT"NTH"Liner Top Pkr 10,469 6,358 J 10 WFT"PHR"Rotating Hyd Set Liner Hanger 10,472 6,359 11 4-1/2" 12.60E-80 Hydril Pupjt Oft(Ported w/6 1/2 holes). 10,794 6,432 C WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base 0 1 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 10,867 6,445 13 Blank Pipe WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base 14 Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 11,297 6,454 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,503 6,446 i„'\ 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,692 6,436 J_J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 11,881 6,419 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,072 6,404 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,262 6,388 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,452 6,374 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,642 6,364 (51 J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,832 6,358 �J 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,021 6,355 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,209 6,350 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,416 6,344 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,618 6,339 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,827 6,347 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,037 6,359 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,247 6,374 6 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,447 6,385 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,644 6,391 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,842 6,387 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,039 6,382 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,239 6,383 . 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,440 6,384 1�/� 4-1/2 12.60 L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 15,641 6,382 0 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,843 6,376 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,043 6,361 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,243 6,346 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,445 6,334 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,646 6,324 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,849 6,315 I 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,050 6,323 0 4-1/2 12.60 L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 17,250 6,345 WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 4) 15 Box 17,449 6,370 TD 17,450 6,370 O 11 C-1). 14 1)15 00 00 00 00 13 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 . 17525'MDrkb/6,380'TVDrkb Date: Revision By: Comments PIONEER8/7/2009 • TWC Pre-TD Update 09/14/2009 TWO As-Run ODSN-36 Producer U�.IRESOURCESAI.SI� Well Schematic NAT Frac String Completion ! PIONEER Operations Summary Report NATURAL RESOURCES IWell Name: ODSN-36 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Spud Date: 1/30/2008 Rig Release Date: Depth Start Foot/Ma � ;Last Mud Start Date End Date (1tKB)': (ft) peens(Ib/gat) Summary 1/28/2008 1/29/2008 153.0 0.00 RDMO ODSDW1-44 to ODSK-36i. RU lines,outside stairs,equipment,&organize pad. Rig accepted @ 18:00hrs 01/28/08.NU 21-1/4"diverter system. 1/29/2008 1/30/2008 153.0 0.00 1 9.00 NU Diverter System.Transfer 500bbls spud mud to rig pits from RSC. Perform Diverter function test, (ok).State waived witness of same. Fill&check Diverter&mud lines, (ok).PU/MU 12-1/4' 1 BHA#1 tools&prepare to spud well. Loading pipe shed w/9-5/8"40 ppf L-80 casing. 1/30/2008 1/31/2008 153.0 1,230.00 9.30 PU/MU 12-1/4" BHA#1 & RIH.Circulate Riser&lines,(Check for leaks-ok). RU Wire line unit &hang sheaves. Drill 12-1/4"Surface hole, (2 stds HWDP). POOH 2 Stds& PU/MU rest of 12-1/4" BHA#1. RIH&Gyro survey.Drill ahead 12-1/4"hole V 1383'. 1/31/2008 '2/1/2008 1,383.0 1,931.00 9.50 Drill/Slide/Survery 12-1/4"Surface Hole f/1,383'V3,314'.Total of 50 joints of 2-7/8"6.4#L-80 Tubing staged for Kill string. 2/1/2008 2/2/2008 3,314.0 369.00 9.50'Drill/Slide/Survey 12-1/4"Surface hole(/3314't/3683'.C&C for wiper trip. Pump 65 bbl high vis . sweep,CBU 2x.POOH/Log f/3683'V3605.W&RM f/1924'1/3602'.Survey @ 2682',2779', 2875'. /2 •• ' ;;', 2/3/2008 3,683.Q 0,:00 9.60'W&RMV btm @ 3683'.POOH f/3683'V BHA#1.LD BHA#1. RU 9-5/8"casing equip,make dummy run w/hanger and landing jt. PU&RIH w/9-5/8'40 ppf L-80 casing.Check float equip ittng (ok)& RIH V1282'. 2/3/2008 2/4/2008 3,683.0 0.001 9.50 RIH w/9-5/8"40 ppf L-80 Casing f/1882;V3619'. PU/MU hanger/Landing Jt and land shoe @ 3665'.MU Cement head. Held PJSM for cementing of 9-5/8".PT lines V 3500 psi(ok). Pump 5 bbls fresh water,40 bble spacer,324 bbls(438 sks) 10.7 ppq lead cement,42 bbls(201 sks) 15.9 ppg tail cmt, 10 bbls water. BP w/500 psi.70 bbls 10.7 ppg cement to surface.CIP @ 13:40 hrs. / 00 2/5/�"Q0 3,889 • ,•t,‘•,'. • •0 8.50 ND Diverter system.Spot&install wellhead equipment in well bay.Test mutibowl V 5000 psi for 10 min(ok). RIH/Land 2-7/8"6.5 ppfptubing @ 1903', RILDS.Test hanger V 5000 psi{ok), PJSM.NU tree&test V 5000 psi ok Test 9-5/8"casin. to 3500 •si`for 30 min ok.Freeze )• •rotect well w/155 bbls diesel 0 psi fo owing II-tu•e. '1 V•. 'tg 'e ease• :•• r. ,2/5/2008 2/25/2009 3,683.0' 0.00 8.50 Inactive 2/25/200972/26/2009 3,683.0 0.00 8.70 Move rig f/ODSN-341 V ODSN-36.Circulate out 155 bbls of freeze protect diesel.ND Tree.NU', BOPE&MPD head.POOH, lay down 1900'of 2-7/8"tubing. RIH,with ",drtllyipe t/2850° POOH with 5"drill pipe ins ectin hardbandin NOTE:AOGCC re r'eSen we John Cris" 11 1 ,<.4 pP p 9 9• �, k ,�: Vlir „ waived the witness of the initial BOPE test @ 06.00hrs on 02/25/09 r 2/26/2009 2/27/2009 3.683.0 0.00 9.30 POOH laying down bad pipe.Test BOPE's as Der AOGCC permit V 250 psi low-3,500 psi high. Tested 2 ea.5" DP rams,blind rams,manual choke&kill,HCR choke&kill, 14 choke manifold valves,floor safety valve,floor Dart valve,upper&lower TD IBOP valves.Anular tested V ,250-2500psi.Accumulator test,3100 initial psi, 1min 42 sec recovery time,3100 psi final pressure. PT RCD 250 psi low/3500 psi high.AOGCC rep.John Crisp waived witnessing test. MU& RIH with 8-3/4" BHA. RIH and Wash V3529'. 2/27/2009 2/28/2009 3,683.00 9.30 Drill out cement and float equipment @ 3579' V3665'.Change over mud system to 9.2 ppg ' LSN.Drill 20'new 8-3/4"open hole to 3703'. Perform LOT at 3,015'TVD with 790 psi surface pressure=14.25 ppq EMW.MWD/LWD/Geo-pilot failure.Trip for BHA.Reset parameters in i MWD/LWD tools.Trip BHA to bottom @ 3703'. .. I •: 3,703.01 1 9.25Drill& survey8-3/4" Holeper WP#12, 3 703'md-5 614'm whilemaintaining 11.2EMW w/ 2/28/2009 3/1/20 91 .00d ( 9 ppg , ) MPD. Page 1/8 Report Printed: 9/14/2009 • PIONEER Dperations Summary Report ! NATURAL RESOURCES Depth Start Foot/Meters I Last Mud Start Date End Date (flKB)::.. (ft) I Dens(lb/gal): Summary 13/1/2009 3/2/2009 5.614.0' 1,708.00 9.20 Drill&survey 8-3/4"Open Hole Section per WP 4412, (5,614'md-7,322'md)while maintaining 11.2 ppg EMW w/MPD. 3/2/2009 3/3/2009 7,322.0 664.00 10.50 Drill&survey 8-3/4' Open Hole Section per WP#12,1/7417'.CBU 4x&RIH to btm. Flow check, (Static)&POOH on elevators to 3,620'md.CBU 1.5x&Slip/cut drilling line.Service Rig&TDS, Crown. PJSM&C/O RCD element per MPD Rep. RIH t/7,41Tmd&stage up circulation. Perform 400 BBL dilution&raise MW to 10.5ppg. Perform Dynamic FIT to 12.5ppg EMW& continue to drill 8-3/4' Hole section f/7,417'md 117,986'md maintaining 12.5ppg EMW w/MPD. 3/3/2009 3/4/2009 7.986.01 1,705.00 10.70 Drill&survey 8-3/4"Open Hole Section per WP 4412,f/7986'119691'. Lost 40% returns while drilling. Unable to drill ahead with current loss rate. RSC building mud volume. Loss rate at 003 bh.Contact ODS Senior Drilling Engineer and discuss options. Decision made to short trip drill string and build mud volume in attempt to regain full circulation.Work pipe&build mud volume. :Prepare to trip drill string to 8600'. 1 3/4/2009 3/5/2009 9,691.0 114.00' 10.70 POOH 1/9691'118555'.Build mud volume @ Ri. Pits&RSC.while losin. °• :', • • - maintaining 12.2-12.5ppq 'TV w V•S.Build 40#/BBL Hi-Vis sweep l3araCarb/BaraFibre/Steel Seal pill&RIH 1/9407'.W&RM f/9407'-1/9636'&spot 50 Bbls LCM pill.Allow to soak while applying back pressure w/MPD(11.69ppg ECD).Clean out 119691'& drill 1/9754', losses @ 150 BPH.Mix&spot 50 Bbls Hi-vis/40+#/BBL LCM pill& POOH 1/8555'. 'Decision made'for DOB2C pill if unable to maintain drilling w/12.5ppg ECD. RIH I/9754'w/o i 'issues&drill 1/9754 119805',w/managable losses 1/9795',hit microfracture,losses=200 BPH.. II POOH 118550'. Decision made to build DOB2C pill. f 3/5/2009 3/6/2009 9,805.0 0.00 10.701 Continue to build volume @ RSC& Rig pits, in prepartion for spotting DOB2C LCM slurry. RIH w/assembly t/9240'. Line up on HT Cement pump&flush lines w/LVT&pressure test to 2500psi, (ok). Pump 15 Bbls LVT/22.5 Bbls DOB2C Slurry(incl.66 sxs Eremium Cmt&50 Sea IMud Gel=62 sxs)/20 Bbls LVT. Displace w/106.6 Bbls Fresh mud.Close MPD RCD&go 'through Kill Line w/Mud pumps,after ensuring line clear.Spot DOB2C Slurry.Slurry in place @ 12:06 hrs. Let pill cure and performed FIT w/12.5 ppq EMW w/MPD.No losses recorded. RIH 119120'. 3/6/20e. rasez„Zi37 9.805.0 0.00 10.701 POOH (packed off)1/9122'I/8936'.W&RM f/8936'119320'.POOH 1/9320'1/8543.C/O',AO• Element per HES.Test same, (ok). RIH 1/8543'1/9320.W&RM 1/9320'1/9661'. iff 4 3/7/2009 3/8/2009 9.805.0 5.00 10.70 W&RM 1/9775't/9805'. POOH 1/8540'. Prepare for spotting DOB2C LCM slurry. RIH f/8,540' 119,465'w/138 BPH loss rate.Line up on HT Cement pump&flush lines w/LVT&pressure test Ito 3000psi, (ok). Pump 15 Bbls LVT/25 Bbls DOB2C Slurry(incl 66 sxs Premium Cmt&50#/sx 'Sea Mud Gel=62 sxs)/20 Bbls LVT. Displace w/103 Bbls Fresh mud.Close MPD RCD&go :through Kill Line w/Mud pumps,after ensuring line clear.Spot DOB2C Slurry.Slurry in place @ I17:07hrs, POOH 1/8540'where able to apply 12.5ppq EMW on MPD.Consult Town ODE after lest. no losses w/12.5ppg EMW.POOH(/8540'1/5709'. Fresh mud.Close MPD RCD&go through Kill Line w/Mud pumps,after ensuring line clear.Spot DOB2C Slurry.Slurry in place @ 17:07hrs. POOH 1/8540'where able to apply 12.5ppg EMW on MPD.Consult Town ODE after est.no losses w/12.5ppg EMW.POOH f/8540'115709'. ' II 111 3/8/2009 3/9/2009 9,810.0 0.00 10.70'POOH w/8-3/4"BHA 443 f/5709'112450'.Spot 22 BBL Hi-Vis Fresh H2O pill f/2450'V2050 - 1 POOH 1/2050'&spot 130 Bbls of 17.0ppq Kill wt mud f/2050'1/340'.Flow check,(Well Static) PJSM&retrieve RCD Elementper MPD Rep.Continue POOH 11559'.LD BHA#3.Slip/Cut p drilling line&service rig. PU/MU 8-3/4' BHA#4 w/re-run 8-3/4'bit from BHAf3t,RIH t!o +1-2,000', install RCD element/bearing assembly. it 11 I Page 2/8 Report Printed: 9/14/2009 PIONEER )perations Summary Report I NATURAL RESOURCES h F /M t Dept Start ooi eters 1 Las Mud Start Date End Date (ftKB); (f) Dens Qb/gar), Summary 13/9/2009 3/10/2009 9.810.0 0.00 10.751 Circulate out&capture 100 BBIs of 17.0ppq Kill fluid(had pumped 130 BBLs)holding 12.5ppg EMW w/MPD). RIH f/2.050't/3,665'. Circulate out test of contaminated 17.0ppg Kill mud (cut to 12.0-12.3ppg) &20 BBLs Hi-Vis Fresh H2O pill. RIH w/BHA#14 f/3,665'115,766'. Control running speed.as losses occurr if to fast. Pull 5 std's to confirm not balled up bit(still had 14 BPH losses). ontinue to IH f/5957't/7203'. CBU @ 7203'while getting surveys. RIH f/7203' It/9280'. Pull back t/8925'.W&RM f/8925't/9170'. it it 13/10/2009 3/11/2009 9,810.0 0.00 10.70 W&RM f/9160't/9367'.Packing off so attempt to clean up hole and freepipe f/9350'1/9367'). Work pipe f/9367'up 119,320'.Wash and ream f/9,320'(/9,483'with no pack off problems. Pack Doff and attempt to regain circulation f/9483'(/9390'.Work tight hole f/9390'(/9401'.W&RM f/9401'(/9655'Pump 30 bbl hi-vis pill at 9,435'.Tagged DOB2C pill at 9,504'.DOB2C pill taking rsitt%i. up to 30K WOB could not pull up from 9,655'. PU 119635'.Ream down(/9,635'(/9,702'. 3 .._, 3/11/2009 3/12/2009 9,810.01 709.00 10.70 W&RM 1/9682'(/9810'. Rotary drilling f/9,810't/9.856'while maintaining 12.5 EMW w/MPD.CO IRCD Element.test same, (OK). Resume Rotary drilling in 8-3/4"Hole section(/9856'(/10287' Imaintaining 12.5 EMW using MPD equipment. Pack off 10287', Picked up string to 10.255'to 'regain circulation and ream back to bottom @ 10.287'.Continue Rotary drilling and surveying 8-3/4" hole section f/10,287'1110,519'while maintaining 12.5 ppg EMW with MPD equipment. 3/12/2009 3/13/2009 10,519.01 116.001 10.80 Drill 8-3/4"Hole section to"TD" @ 10,635'.CBU 3x while reciprocating DP.Begin Back Reaming oufot the-note 171U63b U9/Ub'. Encounter tight spot and attempt to work pipe free. 3/13/2009 3/14/20.9 10,635.0 0.00 10.80 Packed off @ 9,706'& unable to regain circulation. Unable to get movement up or down or rotation. Attempt circulation while holding the 12.5 ppg EMW w/the MPD and prepare for Back-Off services. I , 3/14/2009 3/15/2009 10,635.0 ' 0.00; 10.80 Rig up e-line lubricator.Troubleshoot E-line unit,wait on parts for unit and change out same. Rig e-line unit and tools. RIH with freepoint/CCL to 5500'.Attempt freepoint calibration failed. • �- 'POOH(/5500'.Troubleshoot freepoint tools.Work stuck pipe. 3/15/2009 3/16/2009 ' 10.635.0 0.00 10.80 RIH w/string shot t/9394'wlm.Apply left hand torque and fire same-unsuccessful in back off attempt. POOH and rerun stringshot-tagged up at 8.320'unable to get down, POOH and rig down e-line equipment. Establish circulation and attempt to back off pipe with left hand torque- unsuccessful. I I 3/16/2009 3/1:1 019 10,635.0 0.001 10.801CBU @ 9394'. Hole packed off. RIH with CCI/String Shot.Fired shot @ 9394'WLM.Worked 5 pile and back-off string. String free with 390k Up Wt.and 65k Dn Wt.POOH with Wireline 3/17/2009 3/18/2009 10,635.0 0.00 10.80 POOH w/wireline. POOH w/drill string. RU test equipment and test 2ea 5"pipe rams, blind rams,choke& kill HCR's, manual kill&choke, 14 choke manifold valves, IBOP, floor safety valve&daret valve to 250 psi Low&3500 psi High.annular to 250 psi Low&2500 psi High. Start time 2200 hrs 3/17/09,finish time 0200 hrs 3/18/09.Test witnessed by AOGCC representative Bob Noble. !3/18/2009 3/19/2009 10,635.0 0.001 10.80 Test BOPE as per drilling •permit.AOGCC rep,Bob Noble,witnessed`BOPE test.PU&MU clean oput BHA. RIH hole to 3,666'.Circulate out 17.0 ppg mud.RIH to 6,500. 1 j 3/19/2009 3/20/2009 10.635.0 0.00 10.801 Wash and team f/6500'1/8306'. Pump rate @ 550 gpm 2450 psi. 13/20/2009 3/21/2009 10,635.0 0.001 10.85 Wash and ream thru open hole f/8306'1/8680'. � I 3/21/2009 '3/22/2009 10.635.0 0.00 10.80 Wash and ream thru open hole(/8680'(/9.438'. 13/22/2009 3/23/2009 10,635.01 0.00' 10.80'Wash down to TOF @ 9442'.CBU to clean hole. Page 3/8 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES Depth StartFoot/Meters Last Mud Start Date End Date (ttKB) I (ft) Dens(Ib/gal) oummary 3/23/2009 3/24/2009 10.635.0: 0.00 10.80 POOH on elevators from 9438'V surface. LD clean out BHA.MU fishing assembly. RIH. 3/24/2009 3/25/2009 10,635.01 0.00' 10.80'RIH with fishing BHA V9,442'.Attempt to recover fish with out success.POOH. 113/25/2009 3/26/2009 10.635.0 0.00 10.801 LD Fishing BHA.C/O lower rams f/4" V 5".Tested V 250-3500 psi. RIH and set 55.8 bbls of 115.8 ppg Class "G"cement abondonment plug f/9,420'118,920'. 3/26/2009 '3/27/2009 10,635.0' 0.00 10.80 Spot 55.8 bbls(265 sx) 15.8 ppg Class"G"cement abandonment plug f/9,420'118,920'. POOH ,117,150'.Spot 55.8 bbls(310 sx) 17 ppg Class"G"cement sidetrack plug f/7,150'V6,650'. POOH.Test BOPE's.Annular tested V 250-2500psi,2 ea.5"pipe rams,choke&kill NCR's, choke&kill manuals, 14 ea choke manifold valves,floor safety valve,Dart valve,TD IBOP � 1 tested V 250-3500psi.Witness of test waived by AOGCC rep John Crisp. Perform drill pipe maintenance. 3/27/2009 3/28/2009 6.654.0 0.00 10.80,Perform drill pipe maintenance. MU 8-3/4" BHA#8. RIH V5,479'. 113/28/2009 13/29/2009 6,654.01 633.00 10.801 RIH to 6645'. Sidetrack well @ 6645'. Drill 8-3/4"hole f/6645'V7287'maintaining 12.5 ppg EMW 1 w/MPD. r` I 3,29/2009 3/30/2009 7.287.0 783.00 10.80 Drill 8-3/4"hole f/7.287'V8.070'maintaining 12.5 ppg EMW w/MPD. 3/30/2009 3/31/2009 8,070.0 1,114.00! 10.80',Drill 8-3/4"hole f/8,070'119,184'maintaining 12.5 ppg EMW w/MPD.Circulate and condition 1 ihole.Make wiper trip, POOH f/9184'V8738' 3/31/2009 4/1/2009 9.184.0 102.00 10.80 BROH f/8738't/8426'. POOH(/8426'117952'. RIH w/assembly f/7952'119080'.Wash/Ream f/9080'119184'.Drill(/9184'1/9286'where experienced 400-600psi total pressure loss. Check !pumps, (ok)&determine down hole losses. POOH/BROH(/9286'V9173'. POOH after pumping 130 BBL's of 17.0ppg MW in DP(wash above floats). POOH V3136'. 1 14/1/2009 4/2/2009 9,286.0 0.00 10.80Pump 104 bbls of 17.0 ppg mud.Well static. Pull RCD element,set trip nipple. POOH continue looking for wash out in drill string.Locate wash out in box end on joint of HWDP below iars, LD washed drlg jar&HWDP&questionable looking HWDP. RIH w/BHA#9 f/497'112212'.CBU& !capture 120 BBL's kill wt. Mud. RIH to casing shoe&CBU lx. RIH to+/-5000'&CBU lx. RIH to 17011'. C/O RCD bearing. 4/2/2009 4/3/2009 9.286.0 0.00 10.801C/O RCD bearing assembly(closed Annular Fieventer-non well control event). RIH f/7046' 118564'. Encounter bridge @ 8564'. POOH to 8516'& Est.circulation.CBU lx. Ream f/8516' 119226'where had pack off&tight hole. Re-establish circulation&continue to Ream w/hole troubles f/9226'1/9265'. I ' 4/3/2009 4/4/2009 9,286.0 223.00, 10.801 ji Wash/Ream(/9,265't/9,286'. rill 8-3/4"hole section f/9.286't/9 348'where experienced hiy losses(up to 100%w/12.5ppg EMW maintain on MPD).Mix&spot a Hi-Vis 60 BBL LCM pill of 180#/BBL of Steel Seal,Barafiber,BaraCarb 50. Pull Back to 9.226'&perform weekly ROPF function test per AOGCC requirement.Stage up to 12.1 ppg ECD w/86 BPH loss rate& 12.3ppg 1 I ECD=150 BPH losses. RIH V9,348'&drill 8-3/4"hole section f/9348'V9509'. POOH V9300'& I 'prepare for DOB2C LCM pill#3. POOH to+/-8300'.PJSM&RIH 119298'.Line up on HT cement pump&flush lines w/LVT&pressure test to 3000psi, (ok). Pump 15 BBL's LVT/22.5 BBL's DOB2C Slurry(incl 66 sxs Premium Cmt&50 Sea Mud Gel=62 sxs)/20 BBL's LVT.Spot DOB2C Slurry.DOB2C LCM Slurry In Place @ 14:42hrs.Wait on Pill,RIH V9,026'but unable to I !circ.POOH t/8,847'&ream V8,910'. Page 4/8 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES Depth Start Foot Meters Last Mud I - -- Start Date I; End Date (ftKB) (tt) Dens(Ib/gal)1 Summary 71/4/2009 4/5/2009 9,509.0 0.00 10.80J Wash/Ream(/8,910't/9,509'. Losses at 20-200 boh with 11.7-12.5 EMW w/MPD.BROH f19,509't19.226'. Losses @ 90 bph. POOH 1/9,226't/8,085'.TIH f/8,085't/9,300'. Spot DOB2C pill#4 per program, Line up on HT Cement pump&flush lines w/LVT&pressure test to I3000psi, (ok). Pump 15 Bbls LVT/25 Bbls DOB2C Slurry,/20 Bbls LVT.Spot DOB2C Slurry. I I POOH f/9,300't/8,085'.CBU and reciprocate pipe.Wait on DOB2C pill maintaining 12.5 ppg 1 EMW with no losses. 4/5/2009 4/6/2009 9,509.01 0.00 ` 10.80 Ream f/8,942't/9,230'w/numerous pack off events.Attempt to back ream f/9,230'118,974'(no good-packed off). POOH 118,974'est.circulation and continue to ream 1/8,974'119,096',where t I Lost 400 psi at 9.096'. Inspect all surface equipment, but found communication between annulus and drill pipe-apparent DP or BHA washout.Transter 60 bbls of 15.bppg mud from I RSC to rig,weight up same to 17.0 ppg,spot 30 bbls in the drill pipe to overcome the 525 psi being held on the annulus by MPD equipment. .� 4/6/2009 4/7/2009 9.509.0 0.00 11.10 POOH(/9096't/6975'-found wash out. Circulate out 17.0 ppg pill surface to surface.TIH 776,970.V8.590'-tagged tight spot.wash and ream(/8,564'118,658'.Observed 500 psi loss on DP pressure at 8,658'.Spot 37 bbls of 17.0 ppg mud in drill pipe.POOH f/8,658'115,964'-found wash out in drill pipe.LD washed out joint,but still had communication with annulus-indicating !another wash out. POOH 1/5,964'114,923'-found wash out in drill pipe#3.LD washed out joint, i !raise annulus pressure to 450 psi with no communication to drill pipe.Circulate out 17.0 ppg Pill I I&bottoms up at 4,923'.POOH f/4,923'112,200'. Pump 31 bbl Hi-Vis gel pill at 2,200'and 1 !displace same with 28 bbls 17.0 ppg weighted pill. POOH to the top of the gel pill at 1,800'and continue pumping 77 bbls of 17.0 ppg weighted pill to maintain 12.5 ppg EMW on bottom. 14/7/2009 4/8/20099,509.0 0.00 11.10'PJSM, Remove RCD bearing and install trip nipple. POOH f/1,800'to the BHA. LD BHA and 'download MWD data.Switch rig to generator power to perform step down of ODS transformer #£li �(unsuccessful),switch back after recieve OK from Op's.TIH and LD all 5"drill pipe in 20 stand intervals. ,� -,6 :'tee 14/8/2009 !4/9/2009 9,509.0 0.00 10.90 Finish LD 5"DP from Derrick.Set test plug&Test ROPE per AOGCC requirements,w/250 psi Low/2500psi High on Annular Preventer&3500 psi High on all other Rams,valves,choke ;manifold,floor valves,(chart same 5 min each test). Function test Koomey system 1 min&45 'sec(ok).Test&record gas alarms in NAD log book.BD choke mainfold&line valve for drilling. I 1 I Pull test plug&shut Blind rams,Slip&Cut drilling line&perform maintainance on TDS,grease !blocks&crown.Open Blind Rams&insure Kill line BD. PU&RIH 75 jts 5"DP&hack back in !Derrick.PU&MU BHA#10,8-3/4"Bit w/Geo Pilot assembly.Test MWD,OK&continue to RIH iw/same,PU 11 Jts 5"fresh HWDP& Fresh 5"DP.Continue to single in fresh 5"DP 1/1,344'. ! I I 4/9/2009 4/10/2009 ' 9,509.0' 0.00 10.90 RIH w/5"drill pipe from pipe shed f/1,344'112,200'.CBU @ 2200'to circulate out 17.0 ppg weighted pill while increasing backside pressure with MPD equipment to maintain 12.5 ppg EMW on bottom. RIH w/5"drill pipe from pipe shed f/2,200'1/3,638'.CBU @ 3,638'.Continue 1 l TIH&PU 5"drill pipe from pipe shed from 3,638'to 5,272'.TIH picking up 5"drill pipe from pipe shed f/5,272'116,774'.Stacked out with 60k at 6,745'.Wash/Ream 1/6,745'116,808'.Survey @ '6,774'and realized in wrong wellbore.POOH f/6,808't/6,716'.Ream f/6,716'1/6,808'but unable to chase into correct wellbore. POOH f/6,808'116,338'. 14/10/2009 14/11/2009 6.740.0 741.00 10.80 TIH V6,719'. Make LWD mad pass f/6,719'V6,808'.Drilling side track#21/6,808'116,973'.Make I wiper trip through sidetrack#2.Drilling f/6,973'V7,481'. I I 4//112009 4/12/21 s 7,481.0 995.00, 10.80 Drill 8-3/4"hole 1/7,481't/8,476'maintaining 12.5 ppg EMW w/MPD. 14/12/2009 4/13/2009 8,476.0 944.00 10.75 Directional drill 1/8.476'119,420'.Circulate hole clean with sweeps. Back ream out the hole I if/9,321'V9,090'. 1 4/13/2009 4/14/2009 9,420.01 202.00 10.80 Backream t/8,381'. CBU. RIH 119,420'.Drill V9,622',started losing fluid @ 9,500'.Spot 25 bbl DOB2C LCM pill @ 9,490'. POOH V8,665.CBU t( 8665'. I 5t. ;tt ' ✓u Wit ,,,,, _ .,.,r r✓u . ..:..,ta :' .... Page 5/8 Report Printed: 9/14/2009 1 PIONEER )perations Summary Report I NATURAL RESOURCE:- Depth ESOURCEDepth Start Foot/Meters I Last Mud Start Date End Date { (ttKB) --.._.(ft) J Dens(Ibigal) 1 Summary 4/14/2009 14/15/2009 9.622.0 0.00; 10.80 Wash& 1/8.665'1/8.938 maintaining 12.5 ppg EMW w/MPD.CBU lx @ 8.938'.Wash 1 i&Ream f18.938'119,530'maintaining 12.2 EMW w/MPD. Losses 120-180 bbl/hr. 1 4/15/2009 4/16/2009 9,622.0 336.001: 10.80Back ream 1/9,137'. Circulate& ream 1/9,608. Spot 30 bbl DOB2C pill to control fluid losses. Ream to bottom at 9,622'. Drill 8-3/4"to 9,958' 12.5EMW w/MPD. Imaintaining ppg 1 14/16/2009 4/17/2009 9.958.0. 432.00 10.80 Drill 8-3/4'open hole 1/9.958 1/10.390'maintaining 12.5 ppg EMW w/MPD. 1 :4/17/2009 4/18/2009 10,390.0235.00, 10.801 Drill 8-3/4"hole t/10,625'maintaining 12.5 ppg EMW w/MPD. POOH,back reaming 1/10,625' 1110,170'. 4/18/2009 4/19/2009 10.625.0 0.00 10.80 C/O RCD element. POOH while back reaming 1/10,170'119,682'. 4/19/2009 4/20/2009 10,625.0 0.00' 11.10'Back reaming 1/8,959'. POOH on elevators 1/8,759'_Wash and ream down 1/9,231'. 3 i 4/20/2009 4/21/2009 10.625.0 0.00 11.10 RIH, wash and ream to bottom at 10.625'. Circulate and weight up mud system to 12.8 ppg. 14/21/2009 4/22/2009 10,625.01 0.00 12.80,POOH&LD BHA.Test BOPE's,7"upper rams,5"lower rams,choke& kill HCR valves, manual choke& kill valves, 14 choke manifold valves,floor safety,dart&top drive IBOP valves to 250 psi Low/3500 psi High.Annular to 250 psi Low/2500 psi High.All test held 10 min and charted.Witness of test waived by AOGCC representative Jeff Jones. 4/22/2009 4/23/2009 10.625.0 0.00 12.40 Complete BOPE test. RIH w/7"26#L-80 casing 1/8.398'. 4/23/2009 4/24/2009 10,625.0 0.00 11.80IRun 7"264#L-80 casino 1/10,618'.Land same.Circulate mud system to 12.6 ppg.Cement 7" casing with 68.8 bbls(161 sx)lead slurry cement at 12.5 ppg followed'by 22.9 bbls(109sx)tail ' slurry at 15.8 ppg.BP w/3500 psi,CIP @ 14:30 hrs. Install and test 7"packoff. Run 7744 jts 1 2-7/8"6.4#`L-80 kill string. Freeze protect 7" x 9-5/8"annulus with 110 bbls of diesel.0 psi 1 following U-tube. ND MPD and BOPE. Released Rig from operations on well ODSN-36 at 24:00 1 hrs. C.C4 � 5�3 MMGI� 4/24/2009 7/18/2009 10,625.011 0.00 11.801 Inactive 7/18/2009 7/19/2009 10,625.0 0.001 8.80 Tie-In and land 4-1/2" Hydril 521 frac string.Tested to 4500 psi(ok).ND BOPE's. NU Frac Tree and test to 5000 psi(ok). RDMO ODSN-31. MIRU ODSN-36. PU 36 jts 4"DP. RU to displace !freeze protect from ODSN-36.NOTE;AOGCC given 48 hr notice for initial BOPE test. ,7/19/2009 7/20/2009 10,625.0 0.00 8.751 RU and displace freeze protect from Tbg and IA. Set TWC and ND Tree. NU BOPE's, MPD ACD Head and Trip Nipple. Pull l WC. MU Landing Jt and Pull Tbg Hanger to rig floor. POOH Iw/2-7/8"work string. C/O lower pipe rams f/4-1/2"-1/4".Test BOPE's as per AOGCC permit requirements. I ested 14 Choke Manifold valves while POOH w/2-7/8"l bg.Tested Annular to 250 psi Low/2500 psi High. Upper and lower 4" pipe rams, Kill&Choke HCR s, Manual Kill& choke valves. Floor Safety valve,Dart valve, Upper and Lower TD IBOP to 250 psi Low/3500 psi High.Tested Blind rams 1/250 psi Low/4500 psi High.All low/high tests held 5 min each. :All tests charted.Witness of test waived by AOGCC rep.Chuck Scheve. 7/20/2009 7/21/2009 10,625.0 0.001 8.75 Test MPD.Test 7"csg 1/4500 psi. PU BHA#11. RIH 1/4,803'. Discovered wrong program installed in MWD. POOH w/BHA#11. Installed proper program in MWD and test same. RIH w/ 'BHA#12 t/3,342'. • 1 Page 6/8 Report Printed: 9/14/2009 ' PIONEER )perations Summary Report INATURAL RESOURCES III Depth Start Foot/Meters . Last Mud Start Date 1 End Date (OKB) (ft) Dens(Ib/gal) Summary 7/21/2009 17/22/2009 10.625.0 200.00, 8.70 RIH w/6-1/8"BHA#12.t/10.475',tagged cement stringer(filling DP every 2.500'). Installed MPD RCD. Displaced seawater with 8.75 ppg Ouikdril-M WBM.Clean out cement stringers It/10.526'. Drill cement.float equipment,clean out shoe track,7"shoe and 7'of 8-3/4"old hole 11 It/10.625'. RM shoe& collar 3x. Drill f/10.625'(110.645'. Perform FIT w/13.0 ppg EMW. Pumped 1 11.66 bbls. bled back.66 bbls. brill f/10,645'(110.825'maintaining 9.8 ppg EMW w/MPD. I i 7/22/2009 7/23/2009 10,825.0 444.001 8.75!Drill 6-1/8"f/10,825'V10.833'maintaining 9.8 ppg EMW w/MPD.C/O RCD bearing. Drill If/10,833'(/11.037'. Ream f/11,020'(/11,037',(dog leg). Drill f/11,037'V11,269'.CBU x 2. POOH (/11,075'. 17/23/2009 17/24/2009 11,269.0 723.00 8.70 Short trip to 7"shoe at 10.618'.Service Top Drive. RIH(/11,269',no issues, no fill. Drill 6-1/8" hole 1/11.269' (111.954'maintaining 9.7 ppg EMW w/MPD @ shoe.Time Drill(/11.954' V11,972'. Drill f/11,972'V11.992'. I 17/24/2009 7/25/2009 1 11,992.0 1,185.001 8.701 Drill f/11,992'V12,006'.Time Drill f/12,006'(/12,008'. Drill(/12,008'(112,523'.Service Rig.Drill 6-1/8"hole f/12,523'V13,177'maintaining 9.8 ppg EMW w/MPD @ 7' shoe. 7/25/2009 7/26/2009 13,177.01 1.085.00 8.65 Drill f/13,177' (/13.297'. Service Top Drive. Drill(/13.297'V13.875'.Service Top Drive. Drill 'f/13.875' (114.262'maintaining 9.8 ppg EMW w/MPD @ 7"casing shoe. 7/26/2009 7/27/2009 14,262.0 509.001 8.75 6-1/8"hole f/14,252' (/14,323'_Time Drill f/14,312'V14,323'. Drill(/14,323'V14,358'. 'Service Top Drive. Functioned BOPE's as per AOGCC regulations. Drill f/14,358'V14,770'. Time Drill(/14,770'V14,771 maintaining 9.8 ppg EMW w/MPD @ 7' shoe. 7/27/2009 7/28'2009 14,771.0 256.00 8.70 Time Drill 6-1/8"hole(/14,771'(114.797'. Drill(/14.797'1/14.841'.Service Top Drive. Drill 1/14,841'V 15.025'.Time Drill f/15.025'(/15.027'maintaining 9.8 ppg EMW w/MPD @ 7"shoe. 7/28/2009 7/29/2009 15,027.0 844.001 8.80ITime Drill 6-1/8"hole f/15,027'V15,038'.Drill f/15,038'(/15,130.Service Top Drive. Drill ,; f/15,130'V15,613'.Service Top Drive.Drill f/15,613'V15,868'.Time Drill f/15,868'(/15,871' 1 maintaining 9.8 ppg EMW w/MPD @ 7"shoe. 17/29/2009 7/30/2009 15.871.0 8.00 8.60 Drill 6-1/8"hole 1/15,789'. Circ Well clean(/15.879'. LD drill pipe 1/15.806'.CBU f/15.806'. POOH' f/15.806'V12.419'. BROH f/12,419'V12,260'. POOH f/12.260'(/11,806'. 7/30/2009 7/31/2009 15,879.0 0.001 10.10 POOH f/11,807'V11,045'.Spot 30 bbl hi vis spacer at 11,045'. POOH(/10,425'.Displace well to 110.1 brine f/10,425'w/340 bbls. Remove RCD head and install trip nipple. POOH(/10,425'to 'BHA.LD BHA#12. 17/31/2009 8/1/2009 15.879.0 0.00 10.10 Rig service,Test BOPs to 250 psi Low/3500 psi High upper and lower Rams, inner and outer choke and kill valves,choke manifold.'lest annular to 250 psi Low/2500 psi High.Witness wavied by AOGCC Rep.John Crisp. PU 6-1/8 BHA#13 RIH with drill pipe. 18/1/2009 8/2/2009 I 15,879.0 0.001 10.10 RIH V1059'.Slip and cut drilling line, Install RCD head,RIH V11,060', Pump 30 bbl spacer and 150 bbl spacer displace well(/11,060'with 8.6 mud from 10.1 brine, RIH(111,425'.Geo Pilot failed, POOH V11,040'. Pump 25 bbl spacer, POOH V10,540'displace well to 10.1 brine from 1 , 8.6 mud. Remove RCD install trip nipple, POOH with 4"drill pipe to BHA, LD BHA#13. 8/2/2009 8/3/2009 15.879.0 0.00 8.70 Rig service. PU 6-1/8" BHA& RIH V10.500'. Install RCD head. RIH 1111.092', Pump 30 bbl spacer and 50 bbl spacer displace the well f/11.092'from 10.1 ppq brine to 8.6 ppq mud. RIH (111,750'.Wash and ream f/11,750'1115,186'. 8/3/2009 ` 8/4/2009 15,879.01 235.00 8.701Wash and Ream f/12,345'1/15.872'_Drill 6-1/8"hole(/15,916. Drill 6-1/8"hole V16,114' 11 maintaining 9.8 ppg EMW w/MPD @ 7"casing shoe. Page 7/8 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES Depth Start Foot/Meters 1 °.Last Mud Stan Date End Date (11KB); (ft) Dens(Ib/gat) summary 8/4/2009 18/5/2009 16.114.0 661.00 8.70 Drill 6-1/8"hole f/16.114'1116,775'maintaining 9.8 ppg EMW w/MPD @ 7"shoe. '8/5/2009 '8/6/2009 16,775.0 321.00' 8.70'.Drill 6-1/8"hole f/16,775'1117,096'maintaining 9.8 ppg EMW w/MPD @ 7"shoe. 18/6/2009 8/7/2009 17.096.0 429.00 8.70 Drill 6-1/8"hole 1117.363' maintaining 9.8 ppg EMW @ 7"shoe.Service Rig; Drill 6-1/8" hole 1117,525'"TD". Circ well clean f/17,525'1/17,460', (lx CBU), POOH 1117,460'&continue to CBU 2x Circulations, (Surf-Surf). 8/7/2009 8/8/2009 17,525.01 0.00 8.70�Circ well clean f/17.525'. Back ream lateral section f/17,525'1/10,600'.Service rig,TDS,grease crown&Circ Hi vis Sweep, (30 BBLs f/10,611't/surface). 1 8/8/2009 18/9/2009 1 17.525.0 0.00 8.601,Function test BOP's with no problems. Service rig& RIH w/BHA#14 f/10,600'1112.245',where had to start to ream/wash f/12.245'1/17.473'due to drag down, (15rpm&50 gpm).Circ well clean(22K strokes w/360 BBL's calculated wash out). Displace open hole to 8.6ppg mud,w/ 5.5%fresh NSX lubes(/17.460'w/600 BBLs. Reduced drag from 385K to 325K, rotary dropped 5K from 20K.to 15K. POOH f/17,460'1117,325'on elevators&no issues. 118/9/2009 8/10/200917,525.01 0.00 10.20 POOH f/17,170'1111,090'. Est.circ&spot 30 BBLs Hi-vis Brine 10.2ppg spacer at 11,045'. I I POOH to+/-10,600'&displace well w/10.2ppg non vis Brine, Install trip nipple.Slip and cut drilling line. POOH w/BHA414.LD BHA#14 MWD/Geo Pilot tools.Clear/Clean floor of tools& equipment, Pull wear bushing, install test plug&C/O lower rams to standard 4-1/2" ram blocks. 8/10/2009 8/11/2009 17,525.0 0.00 10.20 Test BOPE Der AOGCC requirements,w/Annular Preventer tasted to 250psi Low/3500psi High for 5 min each.Test all other rams,manifold valves, IBOP,all floor safety valves,choke/kill valves& lines.Tested Upper VBR w/both 4-1/2"&4"test jts(OK)w/250psi Low/4500psi High lest for 5 min.each-charted same(ok). Koomey test performed w/200psi recovery in 21 sec& full pressure recharge in 1min& 32 sec(OK).5x N2 Bottles=1,750psi average(ok).All gas detectors checked& passsed, (logged in Nabors book). Mr.Jeff Jones waived witness for AOGCC. Pull& LD Test plug& install wear ring/RILDS. RU& run 189 jts of 4-1/2" 12.6#L-80 Liner/Jewelry per program, MU running tools. Scraper/Magnet.SLM DP from derrick& RIH w/ Liner 1111,090'where have to rotate past wash area.Continue to RIH w/o issues 1114,340'. where negative wt. reached&necessary to rotate liner in hole 1114,345'. it 8/11/2009: 8/12/2(09/' 17,525.0 0.00 10.20 Rotate in with liner 1117,450',set liner hanger and packer @ 17450'.Attempt to test,but damaged Seals while attempting to set dogs on Hanger. Unsting from Tie-back sleeve&Circ 30 bbl Dirt Magnet sweep, in Hi-vis pill from top of liner @ 10,400'&2x more CBU. POOH with. :... scraper assy& LD same at surface. Pull wear bushing& install junk bushing and flush stack! pull junk bushing, RU 4-1/2"casing tools, PJSM, PU&RIH with 4 1/2" 12.6#L-80 frac string per Frac running program. I I 8/12/2009 8/13/2009 17.525.0 0.00 10.201 RIH w/4-1/2" 12.6# L-80 Hydril Frac Tbg string. Stab into"PBR"and test seals to 3500 psi. 1 S ace Out and land Tbq Hanger.Test Hanger seals to 5000 psi.Test Seal Assy to 4500 psi. IND MPD and BOPEs. NU Tree and test to 5000 psi.Support Frac Operations. 8/13/2009 '8/14/2009 17,525.0 0.00 10.20 Support Frac and Slick line Operations.NOTE:AOGCC given 48hr notice on initial BOPE test Ion ODSN-31 Workover on 8/13/09.AOGCC representative Bob Noble waived witness of test at 0500 hrs on 8/14/09. Page 8/8 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES Well Name: ODSN-36 Contractor: NABORS DRILLING Rig Number: 19AC Job Category: POST DRILL Spud Date: 1/30/2008 Rig Release Date: Depth Start Foot/Meters last Mud Start Date End Date tri(B) ' {ft)�, Dens(lb/gal) ', Summary 8/1/2009 8/2/2009 17,525.0 EXPRO on STBY to relocate with MIRU option once crane is released from Wireline operations on ODSN-31 conversion. Plan is to relocate on NE corner well roll. 8/2/2009 8/3/2009 17,525. ' '1j: Built secondary containment for relocate. Performed on 5 empty ' Gots communicationed from throughoutrmoe to NE side of well roll. lifts. Loadedlequip Goodsafety meeting program. 8/3/2009 8/4/2009 17,525.0 Finished all heavy loads yesterday with Nanuq assist. This took all day to move equipment up to midnight. Heaviest load=separator-78,000#. All EXPRO equipment now on North East corner of well rows. EXPRO to continue rig up to ODSN-36 as far as possible. Crew will be release tonight for Tues flight to Anchorage. Schlumberger mechanics to arrive today for maintenance on frac equipment. 8/4/2009 8/5/20• f STBY for rig to complete well. Prepare for tank preheat in anticii-tion of 8/5/2009 8/6/2009 17,525.0 STBY for rig to complete well. Prepare for tank preheat in anticipation of frac. 8/6/2009 8/7/2009 * Order up crews for frac prep. Pollard to arrive today begin tank heating in PM. Continue to 1STBY 1 � � it 4.11t" 8/7/2009 8/8/2009 17,525.0 Continue to heat frac tanks in prep for frac program. Schlumberger employees on location to begin loading chemicals. Will return for gel prep in AM. 8/8/2009 8/9/2009 17,525.0' 'SWS back on location to mix gel with diesel. Pollard continue to heat tanks. All systems go for i frac. STBY for rig. 0,5 • 8/9/2009 8/10/2009 17,525.0 Pollard hot oil services continue to maintain temp in frac tanks. Stinger rep on location,staged for frac. HES employees staged for frac. STBY for Rig complete. 8/10/2009 8/11/2009 17,525.0 Pollard continue to monitor tank heat. SWS on location to mix prep..STBY for rig. • 8/11/2009 8/12/2009 17,525.0 Pollard to maintain heat in frac tanks. SWS on location to complete mixing gel. Expro at OTP staged for flow back. Protechnics on location with materials. Pollard safety rep on location for frac.CH2MHILL to arrive in AM boat along with complete frac crew. Stinger rep on loc.STBYU. 8/12/2009 8/13/2009 17,525.0 Make final preparations for frac job. Rig up Stinger well head isolation tool,rig up SLB pumping, services to Stinger tool,and had pre frac safety meeting with all personnel on the island. 'ressure test lines to 8500 .si and .erform frac'ob as ger frac design with RA racers.Shut well in and rig down SLB and Stinger tool. 8/13/2009 8/14/2009 17,525.0 1Rig up slick line unit and lubricator,pressure test same to 500 psi-good test. Run in the hole to 716'wlm and pull out the hole with SSSV isolation sleeve.Change out tools and pick up 4.5" BLB and 3.80"GR,rig up kill line from rig pumps to brush and flush. Run in the hole to 7,500' wlm at 1 bpm with sea water down tubing at 1,100 psi-total fluid pumped away=80 bbls.Pull out the hole and pick up XN catcher and run in the hole set same at 8,015'wlm. Pull out the hole and change out tools to KOT to pull valves, run in the hole and pull out 2 dummy valves and 2 memory gauges from 7,303',6,263',4,989'2,666'-one missed run on first station.RIH and install live GLV at each station. RIH and retrieve catcher from 8,015'. RIH and install SSSV insert at 716'. Rig down lubricator and slickline unit. Page 1/3 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date End Date (ttKB) (ft) Dens(Ib'gal) Summary 8/14/2009 8/15/2009 I 17,525.0 Finish rig up of Expro equipment after moving HES slickline unit out of the way. Fill all lines and equipment and pressure test same to 2,765 psi using injection water line. Bring on well with 500 MSCF of lift gas and adjust choke accordingly to bring on the well.Well had to be shut in at approximately 17:00 hrs due to other activities on the rig. Bring well back on at approximately 118:00 hrs and increased choke incrementally to 128/64'ths. Increased GL rate to 1.0 MMSCF at '22:00 hrs, 1.5 MMSCF at 02:00 hrs and 2.0 MMSCF at 05:00 hrs. 8/15/2009 8/16/2009 17 525.0 Continue flowing back ODSN-36 through Expro equipment.Swapped returns over to production via the test header at 09:00 hrs. Flowed back 1,426 bbls of water approxiamtely 18%of the water pumped during frac job. I 1 8/16/2009 8/17/2009 17.525.0 Continue flowing back ODSN-36 through Expro equipment. Flowed back 1.526 bbls of water approxiamtelv 19.5%of the 7,883 bbls pumped during frac job. • • • 8/17/2009 8/18/2009 17.525.01 (Continue flowing back ODSN-36 through Expro equipment. Flowed back 1568 bbls of water • approxiamtely 20%of the 7,883 bbls pumped during frac job.ASRC welders continue to work a 4-1,�'t7�',on ULSD line and began working on tie in for ODSN-36. 4,'•5',..T$411‘. 8/18/2009 8/19/2009 17.525.0 Continue flowing back ODSN-36 through Expro equipment. Flowed back 1,598 bbls of water approxiamtely 20%of the 7,883 bbls pumped during frac job.ASRC welders continue to work atZ),1)loon ULSD line and the tie in lines for ODSN-36. • 8/19/2009 8/20/2009 I 17,525.0 1Continue flowing back ODSN-36 through Expro equipment.At approximately 9:45 hrs the SSSV, was accidentally closed when the pad ops were hooking up the tubing to the control line. {Brought well back on at 3 MMSCF but rates were considerably lower than before shut in, r� consulted with town engineer and slowed lift gas rate to.5 MMSCF.and increased by,.5 MMSCF ever 2 hours upto 3 MMSCF and rates returned to pre shut in rates.Mowed back 1,609 bbls y aoL4of water approxiately 20%of the 7,883 bbls pumped during frac jog.ASRC welders continue ' Ao work on ULSD line and the tie in lines for ODSN-36. 8/20/2009 8/21/2009 17,525.0 Continue flowing back ODSN-36 through Expro equipment.At approximately 14:45 hrs well was shut in to re-route as in'ection line. Brought well back on at 17:00 hours after repairing a leak in the Expro gas meter with a lift gas rate of.5 MMSCF and increased by.5 MMSCF every 2 hours up to 3 MMSCF. Flowed back 1,621 bbls of water approximately 20%of the 7,883 bbls pumped 0\30' during frac job.ASRC welders continue to work on ULSD line and the tie in lines for ODSN-36. 8/21/2009 8/22/2009 17,525.0 j I Continue flowing back ODSN-36 through Expro equipment.At approximately 10:00 hrs well was• shut in due to a process shutdown at OTP.Brought well back on at 10:45 hours with a lift gas rate of.5 MMSCF and increased by.5 MMSCF every 2 hours up to 2s MMSCF. Flowed back •1,626 bbls of water approximately 20%of the 7,883 bbls pumped during frac job.ASRC welders cont~ inue to work on tie in lines for ODSN-36. i 8/22/2009 8/23/2009 17,525.0 Continue flowing back ODSN-36 through Expro equipment.After conversation with town • resevoir engineer at 11:30 we started dropping injection rate by.1 MMSCF every hour and monitor rates. Dropped lift gas rate from 2.0 MMSCF down to 1.3 MMSCF without seeing any 'reduction in liquid rate. At approximately 19:00 well was shut in due to a process shutdown at �I O,,TP.-Brought well back on at 23:00 hours with a lift gas rate of.5 MMSCF and increased by.1 TMMSCF every 2 hours. Had issues with the SSSV opening and remaining open_causino the welt to be shut in lonaer than normal.Flowed back 1.627 hhls of water approximately 20%of the 7.883 bbls pumped during frac job.ASRC welders continue to work on tie in lines for ODSN-36. • 1 8/ ;2.16'4 8/24/2009 17,528°r I Continue flowing back ODSN-36 through Expro equipment. . Flowed back 1,631 bbls of water !approximately 20%of the 7,883 bbls pumped during frac job.ASRC welders continue to work on tie in lines for ODSN-36. Page 2/3 Report Printed: 9/14/2009 PIONEER )perations Summary Report NATURAL RESOURCES I Depth Start FooOMeters Last Mud Start Date ' End Date i (ftKB) (ft) Dens(Ib/gal) Summary 8/24/2009 8/25/2009 17,525.0 Continue to flow back ODSN-36 through Expro equipment and into production. Shut well in at ;14:45 hrs and rig down Expro equipment.ASRC welders continue to work on tie in piping for ODSN-36. • Page 3/3 Report Printed: 9/14/2009 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Project Oooguruk Developement Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-36-Slot ODS-36 Well Position +N/-S 0.0 ft Northing: 6,031,065.83 ft Latitude: 70°29'45.399 N +E/-W 0.0 ft Easting: 469,881.69 ft Longitude: 150°14'46.595 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-36 Magnetics Model Name Sample Date Declination Dip Angle Field Strengthi/ (0) (0) (nT) ','' IGRF200510 2/25/2009 22.36 80.81 57,724 Design ODSN-36 PN10 Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,740.0 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) =-_ 42.7 0.0 0.0 293.08 Survey Program Date 8/21/2009 From To ' (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.0 263.0 ODSN-36 PN10 PB1 Gyro(ODSN-36 PE CB-GYRO-SS Camera based gyro single shot 3/13/2009 t 305.5 6.627.0 ODSN-36 PN10 PB1 MWD(ODSN-36 P MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 3/13/2009 1: 6,654.5 6.740.0 ODSN-36 PN10 MWD PB2(ODSN-36 P MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 4/9/2009 12: 6,782.0 17.423.2 ODSN-36 Surveys_MWD(ODSN-36) MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 3/20/2009 1: Survey i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1000) (ft) Survey Tool Name I 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 43.8 0.2 -0.1 6,031.066.0 469,881.6 0.7 0.15 CB-GYRO-SS(1) 173.0 0.34 6.40 173.0 116.8 0.6 -0.2 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS(1) 263.0 0.12 82.32 263.0 206.8 0.9 -0.1 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS(1) 305.5 0.34 85.09 305.5 249.3 0.9 0.1 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS(2 395.7 1.67 137.26 395.7 339.5 -0.1 1.3 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS(2 489.5 4.21 129.08 489.3 433.1 -3.2 4.9 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS(2 580.2 5.08 122.30 579.7 523.5 -7.5 10.8 6,031,058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS(2 671.1 6.36 126.84 670.2 614.0 -12.6 18.3 6,031.053.1 469,899.9 1.5 -21.77 MWD+SAG+CA+IIFR+MS(2 764.1 6.03 126.15 762.6 706.4 -18.6 26.3 6,031,047.1 469,907.9 0.4 -31.53 MWD+SAG+CA+IIFR+MS(2 859.5 6.88 128.79 857.4 801.2 -25.2 34.8 6,031,040.5 469,916.4 0.9 -41.91 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:16:16PM Page 2 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Survey 1 Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 948.9 7.50 128.01 946.1 889.9 -32.1 43.6 6,031,033.6 469,925.2 0.7 -52.70 MWD+SAG+CA+11FR4AS(2 1,043.5 9.23 133.51 1,039.7 983.5 -41.1 54.0 6,031,024.5 469,935.5 2.0 -65.78 MWD+SAG+CA+IIFR+MS(2 1,139.9 11.67 130.99 1,134.5 1,078.3 -52.8 66.9 6,031,012.7 469,948.4 2.6 -82.30 MWD+SAG+CA+IIFR+MS(2 1,236.3 15.41 132.58 1,228.2 1,172.0 -67.9 83.7 6,030,997.6 469,965.2 3.9 -103.67 MWD+SAG+CA+IIFR+MS(2 1,286.8 18.40 133.42 1,276.6 1,220.4 -77.9 94.5 6,030,987.5 469,975.9 5.9 -117.48 MWD+SAG+CA+IIFR+MS(2 1,332.9 20.25 132.03 1,320.0 1,263.8 -88.3 105.7 6,030,977.1 469,987.0 4.1 -131.83 MWD+SAG+CA+IIFR+MS(2 1,429.6 23.87 135.45 1,409.7 1,353.5 -113.4 131.9 6,030,951.9 470,013.1 4.0 -165.77 MWD+SAG+CA+IIFR+MS(2 1,477.4 27.27 133.74 1,452.8 1,396.6 -127.9 146.6 6,030,937.3 470,027.7 7.3 -184.97 MWD+SAG+CA+I1FR+MS(2 1,526.1 29.56 132.65 1,495.6 1,439.4 -143.7 163.4 6,030,921.4 470,044.5 4.8 -206.71 MWD+SAG+CA+1IFR+MS(2 1,623.1 33.50 131.69 1,578.2 1,522.0 -177.8 201.0 6,030,887.3 470,082.0 4.1 -254.64 MWD+SAG+CA+IIFR+MS(2 1,719.4 38.04 132.23 1,656.4 1,600.2 -215.4 242.9 6,030,849.4 470,123.7 4.7 -307.90 MWD+SAG+CA+IIFR+MS(2 1,816.4 39.04 132.22 1,732.2 1,676.0 -256.0 287.6 6,030,808.7 470,168.3 1.0 -364.99 MWD+SAG+CA+IIFR+MS(2 1,913.6 38.51 133.70 1,808.0 1,751.8 -297.5 332.2 6,030,767.0 470,212.6 1.1 -422.23 MWD+SAG+CA+IIFR+MS(2 2,008.2 36.95 136.81 1,882.8 1,826.6 -338.6 372.9 6,030,725.8 470,253.2 2.6 -475.82 MWD+SAG+CA+IIFR+MS(2' 2,104.6 38.08 140.89 1,959.3 1,903.1 -382.8 411.6 6,030,681.4 470,291.7 2.8 -528.68 MWD+SAG+CA+IIFR+MS(2 2,201.8 39.39 147.75 2,035.2 1,979.0 -432.2 446.9 6,030,631.9 470,326.8 4.6 -580.57 MWD+SAG+CA+IIFR+MS(2 2,298.1 41.01 151.13 2,108.7 2,052.5 -485.7 478.5 6,030,578.3 470,358.2 2.8 -630.59 MWD+SAG+CA+IIFR+MS(2 2,396.0 40.88 152.82 2,182.7 2,126.5 -542.3 508.6 6,030,521.5 470,388.1 1.1 -680.52 MWD+SAG+CA+IIFR+MS(2 2,491.7 42.54 154.78 2,254.1 2,197.9 -599.4 536.7 6,030,464.3 470,415.9 2.2 -728.76 MWD+SAG+CA+IIFR+MS(2 2,587.9 44.85 156.23 2,323.7 2,267.5 -659.9 564.3 6,030,403.7 470,443.2 2.6 -777.80 MWD+SAG+CA+I1FR+MS(2 2,634.7 47.29 157.78 2,356.1 2,299.9 -690.9 577.4 6,030,372.6 470,456.2 5.7 -802.06 MWD+SAG+CA+I1FR+MS(2 2,684.5 51.29 157.87 2,388.6 2,332.4 -725.9 591.7 6,030,337.6 470,470.3 8.0 -828.87 MWD+SAG+CA+IIFR+MS(2 2,732.3 53.75 159.28 2,417.7 2,361.5 -761.2 605.5 6,030,302.2 470,484.1 5.7 -855.47 MWD+SAG+CA+IIFR+MS(2 2,781.0 55.96 162.61 2,445.7 2,389.5 -798.8 618.5 6,030,264.6 470,496.9 7.2 -882.13 MWD+SAG+CA+IIFR+MS(2 2,828.3 56.38 162.38 2,472.1 2,415.9 -836.3 630.3 6,030,227.0 470,508.6 1.0 -907.73 MWD+SAG+CA+IIFR+MS(2 2,877.9 57.18 163.23 2,499.3 2,443.1 -876.0 642.6 6,030,187.4 470,520.7 2.2 -934.54 MWD+SAG+CA+IIFR+MS(2 2,974.2 57.45 166.81 2,551.3 2,495.1 -954.2 663.5 6,030,109.0 470,541.3 3.1 -984.49 MWD+SAG+CA+IIFR+MS(2 3,070.5 53.94 166.00 2,605.5 2,549.3 -1,031.5 682.2 6,030,031.7 470,559.6 3.7 -1,031.96 MWD+SAG+CA+IIFR+MS(2 3,166.8 49.33 165.38 2,665.3 2,609.1 -1,104.7 700.8 6,029,958.5 470,578.0 4.8 -1,077.79 MWD+SAG+CA+IIFR+MS(2 3,263.5 47.48 164.96 2,729.5 2,673.3 -1,174.6 719.4 6,029,888.4 470,596.2 1.9 -1,122.24 MWD+SAG+CA+IIFR+MS(2 3,360.9 46.77 162.67 2,795.8 2,739.6 -1,243.1 739.2 6,029,819.8 470,615.8 1.9 -1,167.39 MWD+SAG+CA+IIFR+MS(2 3,457.7 45.27 162.67 2,863.0 2,806.8 -1,309.7 760.0 6,029,753.2 470,636.3 1.5 -1,212.57 MWD+SAG+CA+IIFR+MS(2 3,554.2 42.57 163.25 2,932.5 2,876.3 -1,373.7 779.6 6,029,689.2 470,655.7 2.8 -1,255.71 MWD+SAG+CA+IIFR+MS(2 3,634.0 42.77 162.93 2,991.2 2,935.0 -1,425.4 795.3 6,029,637.4 470,671.2 0.4 -1,290.46 MWD+SAG+CA+IIFR+MS(2 3,686.7 43.44 161.54 3,029.6 2,973.4 -1,459.6 806.3 6,029,603.1 470,682.0 2.2 -1,313.99 MWD+SAG+CA+IIFR+MS(2 3,740.0 44.21 162.62 3,068.1 3,011.9 -1,494.8 817.7 6,029,567.9 470,693.2 2.0 -1,338.23 MWD+SAG+CA+IIFR+MS(2 3,783.5 44.72 161.58 3,099.1 3,042.9 -1,523.8 827.1 6,029,538.9 470,702.5 2.0 -1,358.20 MWD+SAG+CA+11FR+MS(2 3,878.2 44.25 161.84 3,166.7 3,110.5 -1,586.8 847.9 6,029,475.8 470,723.1 0.5 -1,402.07 MWD+SAG+CA+1IFR+MS(2 3,972.8 44.56 162.68 3,234.3 3,178.1 -1,649.8 868.0 6,029,412.7 470,743.0 0.7 -1,445.32 MWD+SAG+CA+IIFR+MS(2 4,068.1 46.87 164.02 3,300.8 3,244.6 -1,715.2 887.6 6,029,347.3 470,762.2 2.6 -1,488.90 MWD+SAG+CA+1IFR+MS(2 8/24/2009 2:16:16PM Page 3 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.T+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Survey i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (C/100) (ft) Survey Tool Name i 4,164.0 49.70 166.27 3,364.6 3,308.4 -1,784.3 905.9 6,029,278.0 470,780.2 3.4 -1,532.87 MWD+SAG+CA+1IFR+MS(2 4,257.7 50.65 168.64 3,424.7 3,368.5 -1,854.6 921.5 6,029,207.7 470,795.6 2.2 -1,574.81 MWD+SAG+CA+IIFR+MS(2 4,351.7 50.91 170.49 '3,484.1 3,427.9 -1,926.2 934.7 6,029,136.0 470,808.5 1.5 -1,615.00 MWD+SAG+CA+IIFR+MS(2 4,446.8 52.02 172.32 3,543.4 3,487.2 -1,999.8 945.8 6,029,062.4 470,819.3 1.9 -1,654.06 MWD+SAG+CA+IIFR+MS(2 4,541.3 52.94 173.13 3,600.9 3,544.7 -2,074.1 955.3 6,028,988.1 470,828.5 1.2 -1,691.91 MWD+SAG+CA+IIFR+MS(2 4,635.8 53.17 172.12 3,657.7 3,601.5 -2,149.1 965.0 6,028,913.1 470,837.9 0.9 -1,730.22 MWD+SAG+CA+IIFR+MS(2 4,730.9 51.72 172.49 3,715.6 3,659.4 -2,223.7 975.1 6,028,838.4 470,847.7 1.6 -1,768.77 MWD+SAG+CA+IIFR+MS(2 4,826.3 52.12 173.04 3,774.5 3,718.3 -2,298.2 984.5 6,028,763.9 470,856.8 0.6 -1,806.66 MWD+SAG+CA+IIFR+MS(2 4,919.9 52.67 176.70 3,831.6 3,775.4 -2,372.1 991.2 6,028,690.0 470,863.1 3.2 -1,841.72 MWD+SAG+CA+IIFR+MS(2 5,013.4 51.64 177.77 3,889.0 3,832.8 -2,445.8 994.7 6,028,616.3 470,866.4 1.4 -1,873.90 MWD+SAG+CA+IIFR+MS(2 5,108.7 50.87 180.12 3,948.6 3,892.4 -2,520.1 996.1 6,028,542.0 470,867.5 2.1 -1,904.29 MWD+SAG+CA+IIFR+MS(2 5,204.8 52.37 179.20 4,008.3 3,952.1 -2,595.5 996.6 6,028,466.6 470,867.6 1.7 -1,934.25 MWD+SAG+CA+IIFR+MS(2 5,299.1 51.17 181.09 4,066.7 4,010.5 -2,669.5 996.4 6,028,392.5 470,867.1 2.0 -1,963.13 MWD+SAG+CA+1IFR+MS(2 5,395.2 50.26 184.27 4,127.5 4,071.3 -2,743.8 992.9 6,028,318.3 470,863.4 2.7 -1,989.06 MWD+SAG+CA+11FR+MS(2 5,491.6 49.33 189.57 4,189.8 4,133.6 -2,816.9 984.1 6,028,245.3 470,854.2 4.3 -2,009.56 MWD+SAG+CA+11FR+MS(2 5,586.7 50.07 194.04 4,251.3 4,195.1 -2,887.8 969.2 6,028,174.4 470,839.1 3.7 -2,023.72 MWD+SAG+CA+1IFR+MS(2 5,679.3 50.76 199.12 4,310.3 4,254.1 -2,956.1 948.9 6,028,106.2 470,818.5 4.3 -2,031.78 MWD+SAG+CA+IIFR+MS(2 5,773.9 50.69 203.95 4,370.3 4,314.1 -3,024.3 922.0 6,028,038.2 470,791.3 4.0 -2,033.75 MWD+SAG+CA+11FR+MS(2 5,868.4 51.20 209.30 4,429.8 4,373.6 -3,089.8 889.1 6,027,972.7 470,758.2 4.4 -2,029.21 MWD+SAG+CA+11FR+MS(2 5,962.8 52.70 212.82 4,488.0 4,431.8 -3,153.4 850.8 6,027,909.3 470,719.6 3.3 -2,018.87 MWD+SAG+CA+IIFR+MS(2 6,058.1 50.71 217.72 4,547.1 4,490.9 -3,214.5 807.6 6,027,848.4 470,676.2 4.5 -2,003.12 MWD+SAG+CA+IIFR+MS(2 6,151.9 50.37 223.81 4,606.7 4,550.5 -3,269.3 760.4 6,027,793.8 470,628.7 5.0 -1,981.15 MWD+SAG+CA+IIFR+MS(2 6,246.5 50.36 228.36 4,667.0 4,610.8 -3,319.8 708.0 6,027,743.5 470,576.1 3.7 -1,952.72 MWD+SAG+CA+IIFR+MS(2 6,341.8 49.80 232.42 4,728.2 4,672.0 -3,366.4 651.7 6,027,697.2 470,519.7 3.3 -1,919.20 MWD+SAG+CA+IIFR+MS(2 6,437.5 51.82 235.29 4,788.7 4,732.5 -3,410.1 591.8 6,027,653.7 470,459.6 3.1 -1,881.23 MWD+SAG+CA+IIFR+MS(2 6,532.2 50.20 239.91 4,848.3 4,792.1 -3,449.5 529.7 6,027,614.5 470,397.4 4.2 -1,839.58 MWD+SAG+CA+IIFR+MS(2 6,627.0 50.55 243.97 4,908.8 4,852.6 -3,483.9 465.3 6,027,580.4 470,332.8 3.3 -1,793.76 MWD+SAG+CA+11FR+MS(2 6,654.5 50.49 244.25 4,926.3 4,870.1 -3,493.2 446.2 6,027,571.2 470,313.6 0.8 -1,779.82 MWD+SAG+CA+IIFR+MS(3 6,686.3 52.76 246.15 4,946.0 4,889.8 -3,503.6 423.5 6,027,560.9 470,291.0 8.5 -1,763.08 MWD+SAG+CA+11FR+MS(3 6,740.0 54.34 248.91 4,977.9 4,921.7 -3,520.1 383.6 6,027,544.6 470,251.0 5.1 -1,732.86 MWD+SAG+CA+IIFR+MS(3 6,782.0 56.23 247.91 5,001.8 4,945.6 -3,532.8 351.5 6,027,532.0 470,218.9 4.9 -1,708.31 MWD+SAG+CA+IIFR+MS(4 6,845.5 56.70 249.78 5,037.0 4,980.8 -3,551.9 302.1 6,027,513.1 470,169.4 2.6 -1,670.36 MWD+SAG+CA+IIFR+MS(4 6,940.8 56.32 253.84 5,089.5 5,033.3 -3,576.7 226.7 6,027,488.6 470,093.9 3.6 -1,610.70 MWD+SAG+CA+1IFR+MS(4 7,035.0 56.91 256.56 5,141.4 5,085.2 -3,596.8 150.6 6,027,468.8 470,017.7 2.5 -1,548.59 MWD+SAG+CA+IIFR+MS(4 7,128.1 56.74 259.29 5,192.3 5,136.1 -3,613.1 74.4 6,027,452.8 469,941.5 2.5 -1,484.88 MWD+SAG+CA+IIFR+MS(4 7,221.9 57.22 264.10 5,243.4 5,187.2 -3,624.4 -3.3 6,027,441.8 469,863.7 4.3 -1,417.80 MWD+SAG+CA+IIFR+MS(4 7,317.4 57.73 268.15 5,294.8 5,238.6 -3,629.9 -83.6 6,027,436.7 469,783.4 3.6 -1,346.03 MWD+SAG+CA+IIFR+MS(4 7,411.0 58.81 271.86 5,344.0 5,287.8 -3,629.9 -163.2 6,027,437.0 469,703.8 3.6 -1,272.83 MWD+SAG+CA+IIFR+MS(4 I 7,502.9 60.16 274.23 5,390.7 5,334.5 -3,625.6 -242.3 6,027,441.6 469,624.8 2.7 -1,198.44 MWD+SAG+CA+IIFR+MS(4 i 7,597.8 61.52 277.72 5,437.0 5,380.8 -3,617.0 -324.7 6,027,450.5 469,542.4 3.5 -1,119.19 MWD+SAG+CA+IIFR+MS(4 6,'24/2009 2:16:16PM Page 4 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (`/100') (ft) Survey Tool Name 7,692.3 61.80 280.85 5,481.8 5,425.6 -3.603.6 -406.7 6,027,464.3 469,460.4 2.9 -1,038.49 MWD+SAG+CA+11FR+MS(4 7,786.1 62.15 282.77 5,525.9 5,469.7 -3,586.6 -487.8 6,027,481.6 469,379.4 1.8 -957.26 MWD+SAG+CA+IIFR+MS(4 7,881.1 62.69 285.84 5,569.9 5,513.7 -3,565.8 -569.4 6,027,502.7 469,297.9 2.9 -874.03 MWD+SAG+CA+IIFR+MS(4 7,977.6 64.10 288.51 5,613.1 5,556.9 -3,540.3 -651.7 6,027,528.5 469,215.7 2.9 -788.29 MWD+SAG+CA+IIFR+MS(4 8,071.4 65.72 291.71 5,652.9 5,596.7 -3,511.1 -731.5 6,027,558.1 469,136.0 3.5 -703.44 MWD+SAG+CA+IIFR+MS(4 8,163.5 67.27 293.75 5,689.6 5,633.4 -3,478.5 -809.4 6,027,591.0 469,058.3 2.6 -619.02 MWD+SAG+CA+1IFR+MS(4 8,256.7 69.52 296.07 5,724.0 5,667.8 -3,442.0 -888.0 6,027,627.8 468,979.9 3.3 -532.40 MWD+SAG+CA+11FR+MS(4 8,352.5 70.71 299.04 5,756.6 5,700.4 -3,400.3 -967.9 6,027,669.8 468,900.2 3.2 -442.57 MWD+SAG+CA+IIFR+MS(4 8,447.8 71.55 301.48 5,787.4 5,731.2 -3,354.9 -1,045.7 6,027,715.6 468,822.5 2.6 -353.15 MWD+SAG+CA+1IFR+MS(4 8,540.1 73.44 302.05 5,815.2 5,759.0 -3,308.5 -1,120.6 6,027,762.2 468,747.8 2.1 -266.08 MWD+SAG+CA+IIFR+MS(4 8,636.8 73.05 301.77 5,843.0 5,786.8 -3,259.6 -1,199.2 6,027,811.5 468,669.5 0.5 -174.64 MWD+SAG+CA+IIFR+MS(4 8,729.7 73.19 301.76 5,870.0 5,813.8 -3,212.7 -1,274.8 6,027,858.6 468,594.0 0.2 -86.70 MWD+SAG+CA+IIFR+MS(4 8,825.4 73.44 302.92 5,897.5 5,841.3 -3,163.7 -1,352.2 6,027,907.9 468,516.8 1.2 3.72 MWD+SAG+CA+I1FR+MS(4 8,919.5 74.42 303.74 5,923.5 5,867.3 -3,114.0 -1,427.7 6,027,957.9 468,441.5 1.3 92.71 MWD+SAG+CA+IIFR+MS(4 9,012.2 74.72 303.61 5,948.2 5,892.0 -3,064.5 -1,502.1 6,028,007.7 468,367.3 0.4 180.53 MWD+SAG+CA+11FR+MS(4 9,108.4 74.86 304.36 5,973.4 5,917.2 -3,012.6 -1,579.1 6,028,059.9 468,290.6 0.8 271.70 MWD+SAG+CA+11FR+MS(4 9,203.1 74.01 304.47 5,998.8 5,942.6 -2,961.1 -1,654.3 6,028,111.8 468,215.6 0.9 361.12 MWD+SAG+CA+IIFR+MS(4 9,296.8 73.05 304.59 6,025.4 5,969.2 -2,910.1 -1,728.4 6,028,163.0 468,141.7 1.0 449.22 MWD+SAG+CA+IIFR+MS(4 9,390.6 72.72 304.23 6,053.0 5,996.8 -2,859.4 -1,802.3 6,028,214.0 468,068.0 0.5 537.13 MWD+SAG+CA+IIFR+MS(4 9,486.2 73.18 302.97 6,081.0 6,024.8 -2,808.9 -1,878.4 6,028,264.9 467,992.1 1.3 626.96 MWD+SAG+CA+IIFR+MS(4 9,580.2 72.79 302.59 6,108.5 6,052.3 -2,760.2 -1,954.0 6,028,313.8 467,916.7 0.6 715.54 MWD+SAG+CA+IIFR+MS(4 9,674.7 73.31 302.39 6,136.1 6,079.9 -2,711.7 -2,030.2 6,028,362.7 467,840.7 0.6 804.71 MWD+SAG+CA+IIFR+MS(4 9,769.9 73.04 302.55 6,163.6 6,107.4 -2,662.8 -2,107.1 6,028,411.9 467,764.0 0.3 894.63 MWD+SAG+CA+11FR+MS(4 9,863.3 73.17 303.41 6,190.8 6,134.6 -2,614.1 -2,182.1 6,028,460.8 467,689.2 0.9 982.66 MWD+SAG+CA+11FR+MS(4 9,956.6 73.18 302.97 6,217.8 6,161.6 -2,565.2 -2,256.8 6,028,510.0 467,614.7 0.5 1,070.56 MWD+SAG+CA+IIFR+MS(4 � 10,050.6 73.42 303.26 6,244.8 6,188.6 -2,516.0 -2,332.3 6,028,559.5 467,539.5 0.4 1,159.26 MWD+SAG+CA+IIFR+MS(4 10,146.8 74.15 303.62 6,271.7 6,215.5 -2,465.1 -2,409.3 6,028,610.7 467,462.6 0.8 1,250.12 MWD+SAG+CA+IIFR+MS(4 10,241.0 74.72 303.65 6,296.9 6,240.7 -2,414.9 -2,484.9 6,028,661.3 467,387.3 0.6 1,339.33 MWD+SAG+CA+I1FR+MS(4 10,335.1 74.91 302.89 6,321.6 6,265.4 -2,365.0 -2,560.9 6,028,711.5 467,311.5 0.8 1,428.77 MWD+SAG+CA+I1FR+MS(4 10,429.5 74.02 302.49 6,346.9 6,290.7 -2,315.9 -2,637.3 6,028,760.8 467,235.2 1.0 1,518.37 MWD+SAG+CA+IIFR+MS(4 10,524.6 74.47 302.84 6,372.7 6,316.5 -2,266.5 -2,714.4 6,028,810.6 467,158.4 0.6 1,608.65 MWD+SAG+CA+IIFR+MS(4 10,588.3 75.49 303.05 6,389.2 6,333.0 -2,233.0 -2,766.1 6,028,844.2 467,106.9 1.6 1,669.28 MWD+SAG+CA+IIFR+MS(4 10,651.9 76.53 302.31 6,404.6 6,348.4 -2,199.7 -2,818.0 6,028,877.7 467,055.1 2.0 1,730.09 MWD+SAG+CA+IIFR+MS(4 10,748.8 79.97 302.52 6,424.3 6,368.1 -2,148.9 -2,898.0 6,028,928.9 466,975.2 3.6 1,823.68 MWD+SAG+CA+11FR+MS(4 10,846.9 80.08 303.63 6,441.3 6,385.1 -2.096.2 -2,979.0 6,028,982.0 466,894.5 1.1 1,918.84 MWD+SAG+CA+IIFR+MS(4 10,897.8 81.60 304.79 6,449.4 6,393.2 -2,067.9 -3,020.6 6,029,010.4 466,853.0 3.7 1,968.17 MWD+SAG+CA+11FR+MS(4 10,942.9 83.16 306.52 6,455.4 6,399.2 -2,041.8 -3,056.9 6,029,036.6 466,816.8 5.1 2,011.83 MWD+SAG+CA+1IFR+MS(4 10,991.6 85.26 309.64 6,460.3 6,404.1 -2,011.9 -3,095.1 6,029,066.6 466,778.8 7.7 2,058.62 MWD+SAG+CA+IIFR+MS(4 11,038.4 87.19 309.80 6,463.4 6,407.2 -1,982.1 -3,131.0 6,029,096.6 466,743.0 4.1 2,103.33 MWD+SAG+CA+11FR+MS14 11,134.5 92.50 312.35 6,463.7 6,407.5 -1,919.0 -3,203.3 6,029,160.0 466,670.9 6.1 2,194.63 MWD+SAG+CA+IIFR+MS(4 8/24/2009 2:16:16PM Page 5 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,233.0 94.29 314.99 6,457.8 6,401.6 -1.851.1 -3,274.5 6,029,228.2 466.600.0 3.2 2,286.74 MWD+SAG+CA+11FR+MS(4 11,328.9 92.92 313.35 6,451.8 6,395.6 -1,784.4 -3,343.1 6,029,295.1 466,531.7 2.2 2,376.02 MWD+SAG+CA+11FR+MS(4 11,426.3 91.56 309.58 6,448.0 6,391.8 -1,720.0 -3,416.0 6,029,359.8 466,459.0 4.1 2,468.35 MWD+SAG+CA+IIFR+MS(4 11,522.4 91.50 303.69 6,445.4 6,389.2 -1,662.7 -3,493.1 6,029,417.5 466,382.2 6.1 2,561.72 MWD+SAG+CA+IIFR+MS(4 11,618.9 93.48 300.05 6,441.2 6,385.0 -1,611.8 -3,574.9 6,029,468.7 466,300.6 4.3 2,656.92 MWD+SAG+CA+IIFR+MS(4 11,716.0 95.89 297.12 6,433.3 6,377.1 -1,565.5 -3,660.0 6,029,515.3 466,215.8 3.9 2,753.30 MWD+SAG+CA+IIFR+MS(4 11,812.4 94.58 295.71 6,424.5 6,368.3 -1,522.8 -3,745.9 6,029,558.3 466,130.1 2.0 2,849.07 MWD+SAG+CA+IIFR+MS(4 11,908.2 93.78 295.45 6,417.5 6,361.3 -1,481.6 -3,832.1 6,029,599.9 466,044.0 0.9 2,944.53 MWD+SAG+CA+IIFR+MS(4 12,005.2 95.08 295.81 6,410.0 6,353.8 -1,439.7 -3,919.2 6,029,642.1 465,957.1 1.4 3,041.12 MWD+SAG+CA+IIFR+MS(4 12,102.1 94.96 298.58 6,401.5 6,345.3 -1,395.6 -4,005.1 6,029,686.6 465,871.4 2.8 3,137.41 MWD+SAG+CA+11FR+MS(4 12,198.7 95.15 300.73 6,393.0 6,336.8 -1,348.0 -4,088.7 6,029,734.5 465,787.9 2.2 3,233.02 MWD+SAG+CA+IIFR+MS(4 , 12,294.8 94.34 304.83 6,385.1 6,328.9 -1,296.2 -4,169.2 6,029,786.7 465,707.7 4.3 3,327.40 MWD+SAG+CA+IIFR+MS(4 12,391.4 93.97 309.02 6,378.1 6,321.9 -1,238.3 -4,246.2 6,029,844.8 465,630.9 4.3 3,420.88 MWD+SAG+CA+IIFR+MS(4 12,487.8 93.16 309.15 6,372.1 6,315.9 -1,177.7 -4,320.9 6,029,905.8 465,556.5 0.9 3,513.36 MWD+SAG+CA+11FR+MS(4 li 12,585.8 92.98 309.41 6,366.8 6,310.6 -1,115.7 -4,396.6 6,029,968.1 465.481.0 0.3 3,607.34 MWD+SAG+CA+I1FR+MS(4 12,682.1 92.61 309.94 6,362.1 6,305.9 -1,054.3 -4,470.7 6,030,029.8 465,407.2 0.7 3,699.56 MWD+SAG+CA+IIFR+MS(4 12,778.8 90.94 308.97 6,359.1 6,302.9 -992.9 -4,545.3 6,030,091.5 465,332.9 2.0 3,792.24 MWD+SAG+CA+IIFR+MS(4 12,875.1 90.51 312.57 6,357.9 6,301.7 -930.0 -4,618.2 6,030,154.6 465,260.2 3.8 3,883.97 MWD+SAG+CA+IIFR+MS(4 12,971.7 91.44 317.11 6,356.3 6,300.1 -861.9 -4,686.7 6,030,223.0 465,192.0 4.8 3,973.66 MWD+SAG+CA+I1FR+MS(4 1 13,066.8 91.31 318.53 6,354.0 6,297.8 -791.5 -4,750.5 6,030,293.7 465,128.5 1.5 4,060.00 MWD+SAG+CA+IIFR+MS(4 13,164.8 91.93 316.95 6,351.2 6,295.0 -719.0 -4,816.4 6,030,366.4 465,062.9 1.7 4,149.01 MWD+SAG+CA+IIFR+MS(4 13,261.0 91.44 316.92 6,348.4 6,292.2 -648.7 -4,882.1 6,030,437.0 464,997.5 0.5 4,237.00 MWD+SAG+CA+IIFR+MS(4 13,357.6 91.69 316.90 6,345.7 6,289.5 -578.2 -4,948.1 6,030,507.8 464,931.8 0.3 4,325.36 MWD+SAG+CA+IIFR+MS(4 13,453.2 91.81 317.16 6,342.8 6,286.6 -508.3 -5,013.1 6,030,577.9 464,867.0 0.3 4,412.63 MWD+SAG+CA+11FR+MS(4 13,549.8 91.31 316.96 6,340.2 6,284.0 -437.6 -5,078.9 6,030,648.9 464,801.5 0.6 4,500.87 MWD+SAG+CA+IIFR+MS(4 13,647.6 89.58 318.20 6,339.4 6,283.2 -365.4 -5,144.9 6,030,721.3 464,735.9 2.2 4,589.84 MWD+SAG+CA+IIFR+MS(4 13,744.0 87.11 318.76 6,342.2 6,286.0 -293.2 -5,208.8 6,030,793.7 464,672.3 2.6 4,676.90 MWD+SAG+CA+IIFR+MS(4 13,839.6 86.49 319.72 6,347.6 6,291.4 -220.9 -5,271.1 6,030,866.3 464,610.2 1.2 4,762.60 MWD+SAG+CA+IIFR+MS(4 13,935.6 86.50 321.17 6,353.4 6,297.2 -147.1 -5,332.1 6,030,940.4 464,549.5 1.5 4,847.68 MWD+SAG+CA+IIFR+MS(4 14,033.1 86.81 322.49 6,359.1 6,302.9 -70.6 -5,392.2 6,031,017.1 464,489.7 1.4 4,932.96 MWD+SAG+CA+IIFR+MS(4 14,129.2 85.25 322.67 6,365.8 6,309.6 5.6 -5,450.5 6,031,093.5 464,431.8 1.6 5,016.46 MWD+SAG+CA+IIFR+MS(4 14,226.2 86.75 321.78 6,372.5 6,316.3 82.1 -5,509.8 6,031,170.2 464,372.8 1.8 5,100.97 MWD+SAG+CA+IIFR+MS(4 14,312.2 86.12 320.17 6,377.9 6,321.7 148.8 -5,563.8 6,031,237.1 464,319.0 2.0 5,176.82 MWD+SAG+CA+1IFR+MS(4 14,330.1 84.88 319.77 6,379.3 6,323.1 162.4 -5,575.3 6,031,250.8 464,307.6 7.3 5,192.71 MWD+SAG+CA+I1FR+MS(4 14,417.9 88.79 320.05 6,384.1 6,327.9 229.5 -5,631.8 6,031,318.1 464,251.5 4.5 5,270.93 MWD+SAG+CA+IIFR+MS(4 14,515.7 87.66 322.28 6,387.2 6,331.0 305.6 -5,693.0 6,031,394.4 464,190.5 2.6 5,357.13 MWD+SAG+CA+I1FR+MS(4 14,613.0 88.47 324.60 6,390.5 6,334.3 383.7 -5,751.0 6,031,472.8 464,132.9 2.5 5,441.11 MWD+SAG+CA+IIFR+MS(4 14,709.0 91.07 325.24 6,390.8 6,334.6 462.2 -5,806.1 6,031,551.5 464,078.1 2.8 5,522.58 MWD+SAG+CA+IIFR+MS(4 14,770.7 90.32 323.20 6,390.1 6,333.9 512.3 -5,842.2 6,031,601.7 464,042.2 3.5 5,575.41 MWD+SAG+CA+UFR+MS(4 14,796.6 93.07 323.00 6,389.3 6,333.1 533.0 -5,857.7 6,031,622.5 464,026.7 10.6 5,597.82 MWD+SAG+CA+IIFR+MS(4 8/24/2009 2:16:16PM Page 6 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 Surveys Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,805.4 93.36 322.81 6,388.8 6,332.6 540.0 -5,863.1 6,031,629.6 464,021.5 3.9 5,605.46 MWD+SAG+CA+IIFR+MS(4 14,899.8 91.49 323.23 6,384.8 6,328.6 615.4 -5,919.8 6,031,705.1 463,965.0 2.0 5,687.17 MWD+SAG+CA+IIFR+MS(4 14,998.6 91.38 322.70 6,382.4 6,326.2 694.2 -5,979.3 6,031,784.2 463,905.9 0.5 5,772.80 MWD+SAG+CA+IIFR+MS(4 15,024.7 89.82 321.49 6,382.1 6,325.9 714.8 -5,995.3 6,031,804.8 463,889.9 7.6 5,795.63 MWD+SAG+CA+IIFR+MS(4 15,042.6 90.02 320.94 6,382.1 6,325.9 728.8 -6,006.5 6,031,818.9 463,878.7 3.3 5,811.46 MWD+SAG+CA+11FR+MS(4 15,094.6 89.96 317.17 6,382.1 6,325.9 768.0 -6,040.6 6,031,858.3 463,844.9 7.3 5,858.18 MWD+SAG+CA+1IFR+MS(4 15,190.2 89.71 316.01 6,382.4 6,326.2 837.4 -6,106.3 6,031,927.9 463,779.5 1.2 5,945.79 MWD+SAG+CA+11FR+MS(4 15,288.7 90.02 321.02 6,382.6 6,326.4 911.2 -6,171.5 6,032,002.0 463,714.5 5.1 6,034.73 MWD+SAG+CA+IIFR+MS(4 15,385.2 . 89.27 326.84 6,383.2 6,327.0 989.2 -6,228.3 6,032,080.1 463,658.1 6.1 6,117.53 MWD+SAG+CA+IIFR+MS(4 15,481.1 90.33 329.04 6,383.6 6,327.4 1,070.5 -6,279.2 6,032,161.6 463,607.5 2.5 6,196.25 MWD+SAG+CA+IIFR+MS(4 15,577.9 91.01 330.66 6,382.4 6,326.2 1,154.2 -6,327.8 6,032,245.5 463,559.2 1.8 6,273.76 MWD+SAG+CA+IIFR+MS(4 15,673.6 90.57 328.19 6,381.1 6,324.9 1,236.6 -6,376.5 6,032,328.1 463,510.9 2.6 6,350.87 MWD+SAG+CA+IIFR+MS(4 15,770.9 91.38 324.04 6,379.5 6,323.3 1,317.3 -6,430.7 6,032,409.1 463,457.0 4.3 6,432.40 MWD+SAG+CA+IIFR+MS(4 15,880.4 95.04 321.82 6,373.3 6,317.1 1,404.5 -6,496.6 6,032,496.5 463,391.5 3.9 6,527.18 MWD+SAG+CA+I1FR+MS(4 15,974.9 93.79 322.44 6,366.1 6,309.9 1,478.9 -6,554.4 6,032,571.1 463,334.0 1.5 6,609.55 MWD+SAG+CA+I1FR+MS(4 16,073.5 95.17 323.55 6,358.4 6,302.2 1,557.4 -6,613.6 6,032,649.8 463,275.1 1.8 6,694.71 MWD+SAG+CA+1IFR+MS(4 16,170.1 93.86 325.21 6,350.7 6,294.5 1,635.7 -6,669.7 6,032,728.4 463,219.3 2.2 6,777.07 MWD+SAG+CA+IIFR+MS(4 ' 16,266.4 93.30 321.81 6,344.7 6,288.5 1,713.0 -6,726.8 6,032,805.9 463,162.5 3.6 6,859.92 MWD+SAG+CA+11FR+MS(4 16,362.5 94.11 321.48 6,338.5 6,282.3 1,788.2 -6,786.4 6,032,881.3 463,103.3 0.9 6,944.15 MWD+SAG+CA+IIFR+MS(4 16,458.0 92.18 319.73 6,333.3 6,277.1 1,861.8 -6,846.9 6,032,955.2 463,043.1 2.7 7,028.71 MWD+SAG+CA+IIFR+MS(4 16,554.3 93.62 318.87 6,328.4 6,272.2 1,934.8 -6,909.6 6,033,028.4 462.980.7 1.7 7,114.98 MWD+SAG+CA+IIFR+MS(4 16,651.3 91.44 316.37 6,324.1 6,267.9 2,006.3 -6,974.8 6,033,100.1 462,915.7 3.4 7,203.05 MWD+SAG+CA+IIFR+MS(4 16,749.0 92.76 317.34 6,320.5 6,264.3 2,077.5 -7,041.6 6,033,171.7 462,849.2 1.7 7,292.43 MWD+SAG+CA+IIFR+MS(4 16,810.4 93.62 317.65 6,317.1 6,260.9 2,122.7 -7,083.1 6,033,217.0 462,808.0 1.5 7,348.26 MWD+SAG+CA+IIFR+MS(4 16,844.8 91.67 317.75 6,315.5 6,259.3 2,148.1 -7,106.1 6,033,242.5 462,785.0 5.7 7,379.45 MWD+SAG+CA+IIFR+MS(4 16,941.1 87.60 317.88 6,316.2 6,260.0 2,219.4 -7,170.8 6,033,314.1 462,720.7 4.2 7,466.89 MWD+SAG+CA+IIFR+MS(4 16,988.0 86.94 317.16 6,318.4 6,262.2 2,254.0 -7,202.5 6,033,348.8 462,689.1 2.1 7,509.57 MWD+SAG+CA+IIFR+MS(4 17,035.7 85.19 316.66 6,321.7 6,265.5 2,288.8 -7,234.9 6,033,383.6 462,656.8 3.8 7,553.08 MWD+SAG+CA+IIFR+MS(4 17,074.6 85.90 317.18 6,324.7 6,268.5 2,317.1 -7,261.5 6,033,412.1 462,630.4 2.3 7,588.60 MWD+SAG+CA+IIFR+MS(4 17,133.9 83.57 318.43 6,330.1 6,273.9 2,360.9 -7,301.1 6,033,456.0 462,590.9 4.5 7,642.24 MWD+SAG+CA+I1FR+MS(4 17,230.6 81.90 319.50 6,342.4 6,286.2 2,433.2 -7,364.1 6,033,528.6 462,528.2 2.0 7,728.53 MWD+SAG+CA+IIFR+MS(4 17,289.0 83.18 318.54 6,349.9 6,293.7 2,476.9 -7,402.1 6,033,572.5 462,490.4 2.7 7,780.61 MWD+SAG+CA+IIFR+MS(4 17,326.0 83.10 319.62 6,354.4 6,298.2 2,504.7 -7,426.1 6,033,600.3 462,466.5 2.9 7,813.62 MWD+SAG+CA+IIFR+MS(4 17,423.2 82.48 320.22 6,366.6 6,310.4 2,578.4 -7,488.2 6,033,674.3 462.404.7 0.9 7,899.64 MWD+SAG+CA+IIFR+MS(4 17,525.0 82.48 320.22 6,379.9 6,323.7 2,656.0 -7,552.8 6,033,752.1 462,340.5 0.0 7,989.42 PROJECTED to TD 8/24/2009 2:16:16PM Page 7 COMPASS 2003.16 Build 71 I , Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooauruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB1 Database: EDM 2003.16 Single User Db Project Oooguruk Developement Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-36-Slot ODS-36 Well Position +N/-S 0.0 ft Northing: 6,031,065.83 ft Latitude: 70°29'45.399 N +E/-W 0.0 ft Easting: 469,881.69 ft Longitude: 150° 14'46.595 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-36 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF200510 3/23/2009 22.33 80.81 57,727 Design ODSN-36 PN10 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.7 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction , (ft) (ft) (ft) (°) 42.7 0.0 0.0 293.08 Survey Program Date 8/21/2009 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey',Date 100.0 263.0 ODSN-36 PN10 PB1 Gyro(ODSN-36 PE CB-GYRO-SS Camera based gyro single shot 3/13/2009 1: 305.5 10,581.7 ODSN-36 PN10 PB1 MWD(ODSN-36 P MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 3/13/2009 t Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031.065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 43.8 0.2 -0.1 6,031,066.0 469,881.6 0.7 0.15 CB-GYR0-SS(1) 173.0 0.34 6.40 173.0 116.8 0.6 -0.2 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS(1) 263.0 0.12 82.32 263.0 206.8 0.9 -0.1 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS(1) 305.5 0.34 85.09 305.5 249.3 0.9 0.1 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS(2 395.7 1.67 137.26 395.7 339.5 -0.1 1.3 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS(2 489.5 4.21 129.08 489.3 433.1 -3.2 4.9 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS(2 580.2 5.08 122.30 579.7 523.5 -7.5 10.8 6,031.058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS(2 671.1 6.36 126.84 670.2 614.0 -12.6 18.3 6,031,053.1 469,899.9 1.5 -21.77 MWD+SAG+CA+IIFR+MS(2 764.1 6.03 126.15 762.6 706.4 -18.6 26.3 6,031,047.1 469,907.9 0.4 -31.53 MWD+SAG+CA+IIFR+MS(2 859.5 6.88 128.79 857.4 801.2 -25.2 34.8 6,031,040.5 469,916.4 0.9 -41.91 MWD+SAG+CA+IIFR+MS(2 948.9 7.50 128.01 946.1 889.9 -32.1 43.6 6,031,033.6 469,925.2 0.7 -52.70 MWD+SAG+CA+IIFR+MS(2 1,043.5 9.23 133.51 1,039.7 983.5 -41.1 54.0 6,031,024.5 469,935.5 2.0 -65.78 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:17:23PM Page 2 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVD SS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,139.9 11.67 130.99 1,134.5 1,078.3 -52.8 66.9 6,031,012.7 469,948.4 2.6 -82.30 MWD+SAG+CA+11FR+MS(2 1,236.3 15.41 132.58 1,228.2 1,172.0 -67.9 83.7 6,030,997.6 469,965.2 3.9 -103.67 MWD+SAG+CA+IIFR+MS(2 1,286.8 18.40 133.42 1,276.6 1,220.4 -77.9 94.5 6,030,987.5 469,975.9 5.9 -117.48 MWD+SAG+CA+IIFR+MS(2 1,332.9 20.25 132.03 1,320.0 1,263.8 -88.3 105.7 6,030,977.1 469,987.0 4.1 -131.83 MWD+SAG+CA+IIFR+MS(2 1,429.6 23.87 135.45 1,409.7 1,353.5 -113.4 131.9 6,030,951.9 470,013.1 4.0 -165.77 MWD+SAG+CA+IIFR+MS(2 1,477.4 27.27 133.74 1,452.8 1,396.6 -127.9 146.6 6,030,937.3 470,027.7 7.3 -184.97 MWD+SAG+CA+IIFR+MS(2 1,526.1 29.56 132.65 1,495.6 1,439.4 -143.7 163.4 6,030,921.4 470,044.5 4.8 -206.71 MWD+SAG+CA+IIFR+MS(2 1 1,623.1 33.50 131.69 1,578.2 1,522.0 -177.8 201.0 6,030,887.3 470,082.0 4.1 -254.64 MWD+SAG+CA+IIFR+MS(2 1,719.4 38.04 132.23 1,656.4 1,600.2 -215.4 242.9 6,030,849.4 470,123.7 4.7 -307.90 MWD+SAG+CA+IIFR+MS(2 1,816.4 39.04 132.22 1,732.2 1,676.0 -256.0 287.6 6,030,808.7 470,168.3 1.0 -364.99 MWD+SAG+CA+1IFR+MS(2 1,913.6 38.51 133.70 1,808.0 1,751.8 -297.5 332.2 6,030,767.0 470,212.6 1.1 -422.23 MWD+SAG+CA+11FR+MS(2 2,008.2 36.95 136.81 1,882.8 1,826.6 -338.6 372.9 6,030,725.8 470,253.2 2.6 -475.82 MWD+SAG+CA+IIFR+MS(2 2,104.6 38.08 140.89 1,959.3 1,903.1 -382.8 411.6 6,030,681.4 470,291.7 2.8 -528.68 MWD+SAG+CA+IIFR+MS(2 2,201.8 39.39 147.75 2,035.2 1,979.0 -432.2 446.9 6,030,631.9 470,326.8 4.6 -580.57 MWD+SAG+CA+IIFR+MS(2 I 2,298.1 41.01 151.13 2,108.7 2,052.5 -485.7 478.5 6,030,578.3 470,358.2 2.8 -630.59 MWD+SAG+CA+IIFR+MS(2 2,396.0 40.85 152.82 2,182.7 2,126.5 -542.3 508.6 6,030,521.5 470,388.1 1.1 -680.52 MWD+SAG+CA+IIFR+MS(2 2,491.7 42.54 154.78 2,254.1 2,197.9 -599.4 536.7 6,030,464.3 470,415.9 2.2 -728.76 MWD+SAG+CA+IIFR+MS(2 2,587.9 44.85 156.23 2,323.7 2,267.5 -659.9 564.3 6,030,403.7 470,443.2 2.6 -777.80 MWD+SAG+CA+IIFR+MS(2 2,634.7 47.29 157.78 2,356.1 2,299.9 -690.9 577.4 6,030,372.6 470,456.2 5.7 -802.06 MWD+SAG+CA+IIFR+MS(2 2,684.5 51.29 157.87 2,388.6 2,332.4 -725.9 591.7 6,030,337.6 470,470.3 8.0 -828.87 MWD+SAG+CA+I1FR+MS(2 2,732.3 53.75 159.28 2,417.7 2,361.5 -761.2 605.5 6,030,302.2 470,484.1 5.7 -855.47 MWD+SAG+CA+I1FR+MS(2 , 2,781.0 55.96 162.61 2,445.7 2,389.5 -798.8 618.5 6,030,264.6 470,496.9 7.2 -882.13 MWD+SAG+CA+IIFR+MS(2 2,828.3 56.38 162.38 2,472.1 2,415.9 -836.3 630.3 6,030,227.0 470,508.6 1.0 -907.73 MWD+SAG+CA+IIFR+MS(2 2,877.9 57.18 163.23 2,499.3 2,443.1 -876.0 642.6 6,030,187.4 470,520.7 2.2 -934.54 MWD+SAG+CA+IIFR+MS(2 2,974.2 57.45 166.81 2,551.3 2,495.1 -954.2 663.5 6,030,109.0 470,541.3 3.1 -984.49 MWD+SAG+CA+IIFR+MS(2 3,070.5 53.94 166.00 2,605.5 2,549.3 -1,031.5 682.2 6,030,031.7 470,559.6 3.7 -1,031.96 MWD+SAG+CA+IIFR+MS(2 3,166.8 49.33 165.38 2,665.3 2,609.1 -1,104.7 700.8 6,029,958.5 470,578.0 4.8 -1,077.79 MWD+SAG+CA+1IFR+MS(2 3,263.5 47.48 164.96 2,729.5 2,673.3 -1,174.6 719.4 6,029,888.4 470,596.2 1.9 -1,122.24 MWD+SAG+CA+IIFR+MS(2 + + + + 4 739.26,029,819.847 1 1.9 -1,167.39 MWD SAG CA IIFR MS 2 3,360.9 46.77 162.67 2,795.8 2,739.6 -1,2 3.1 0,6 5 8 3,457.7 45.27 162.67 2,863.0 2,806.8 -1,309.7 760.0 6,029,753.2 470,636.3 1.5 -1,212.57 MWD+SAG+CA+IIFR+MS(2 I 3,554.2 42.57 163.25 2,932.5 2,876.3 -1,373.7 779.6 6,029,689.2 470,655.7 2.8 -1,255.71 MWD+SAG+CA+IIFR+MS(2 3,634.0 42.77 162.93 2,991.2 2,935.0 -1,425.4 795.3 6,029,637.4 470,671.2 0.4 -1,290.46 MWD+SAG+CA+1IFR+MS(2 3,686.7 43.44 161.54 3,029.6 2,973.4 -1,459.6 806.3 6,029,603.1 470,682.0 2.2 -1,313.99 MWD+SAG+CA+IIFR+MS(2 3,740.0 44.21 162.62 3,068.1 3,011.9 -1,494.8 817.7 6,029,567.9 470,693.2 2.0 -1,338.23 MWD+SAG+CA+IIFR+MS(2 3,783.5 44.72 161.58 3,099.1 3,042.9 -1,523.8 827.1 6,029,538.9 470,702.5 2.0 -1.358.20 MWD+SAG+CA+1IFR+MS(2 3,878.2 44.25 161.84 3,166.7 3,110.5 -1,586.8 847.9 6,029,475.8 470,723.1 0.5 -1,402.07 MWD+SAG+CA+11FR+MS(2 3,972.8 44.56 162.68 3,234.3 3,178.1 -1,649.8 868.0 6,029,412.7 470,743.0 0.7 -1,445.32 MWD+SAG+CA+IIFR+MS(2 4,068.1 46.87 164.02 3,300.8 3,244.6 -1,715.2 887.6 6,029,347.3 470,762.2 2.6 -1,488.90 MWD+SAG+CA+11FR+MS(2 4,164.0 49.70 166.27 3,364.6 3,308.4 -1,784.3 905.9 6,029,278.0 470,780.2 3.4 -1,532.87 MWD+SAG+CA+IIFR+MS(2 4,257.7 50.65 168.64 3,424.7 3,368.5 -1,854.6 921.5 6,029,207.7 470,795.6 2.2 -1,574.81 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:17:23PM Page 3 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-OoopuruF. Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (`/100') (ft) Survey Tool Name 4,351.7 50.91 170.49 3,484.1 3,427.9 -1,926.2 934.7 6,029,136.0 470,808.5 1.5 -1,615.00 MWD+SAG+CA+IIFR+MS(2 4,446.8 52.02 172.32 3,543.4 3,487.2 -1,999.8 945.8 6,029,062.4 470,819.3 1.9 -1,654.06 MWD+SAG+CA+IIFR+MS(2 4,541.3 52.94 173.13 3,600.9 3,544.7 -2,074.1 955.3 6,028,988.1 470,828.5 1.2 -1,691.91 MWD+SAG+CA+IIFR+MS(2 4,635.8 53.17 172.12 3,657.7 3,601.5 -2,149.1 965.0 6,028,913.1 470,837.9 0.9 -1,730.22 MWD+SAG+CA+I1FR+MS(2 4,730.9 51.72 172.49 3,715.6 3,659.4 -2,223.7 975.1 6,028,838.4 470,847.7 1.6 -1,768.77 MWD+SAG+CA+IIFR+MS(2 4,826.3 52.12 173.04 3,774.5 3,718.3 -2,298.2 984.5 6,028,763.9 470,856.8 0.6 -1,806.66 MWD+SAG+CA+IIFR+MS(2 4,919.9 52.67 176.70 3,831.6 3,775.4 -2,372.1 991.2 6,028,690.0 470,863.1 3.2 -1,841.72 MWD+SAG+CA+IIFR+MS(2 I 5,013.4 51.64 177.77 3,889.0 3,832.8 -2,445.8 994.7 6,028,616.3 470,866.4 1.4 -1,873.90 MWD+SAG+CA+IIFR+MS(2 5,108.7 50.87 180.12 3,948.6 3,892.4 -2,520.1 996.1 6,028,542.0 470,867.5 2.1 -1,904.29 MWD+SAG+CA+IIFR+MS(2 5,204.8 52.37 179.20 4,008.3 3,952.1 -2,595.5 996.6 6,028,466.6 470,867.6 1.7 -1,934.25 MWD+SAG+CA+IIFR+MS(2 5,299.1 51.17 181.09 4,066.7 4,010.5 -2,669.5 996.4 6,028,392.5 470,867.1 2.0 -1,963.13 MWD+SAG+CA+IIFR+MS(2 5,395.2 50.26 184.27 4,127.5 4,071.3 -2,743.8 992.9 6,028,318.3 470,863.4 2.7 -1,989.06 MWD+SAG+CA+IIFR+MS(2 5,491.6 49.33 189.57 4,189.8 4,133.6 -2,816.9 984.1 6,028,245.3 470,854.2 4.3 -2,009.56 MWD+SAG+CA+1IFR+MS(2 I 5,586.7 50.07 194.04 4,251.3 4,195.1 -2,887.8 969.2 6,028,174.4 470,839.1 3.7 -2,023.72 MWD+SAG+CA+IIFR+MS(2 5,679.3 50.76 199.12 4,310.3 4,254.1 -2,956.1 948.9 6,028,106.2 470,818.5 4.3 -2,031.78 MWD+SAG+CA+I1FR+MS(2 5,773.9 50.69 203.95 4,370.3 4,314.1 -3,024.3 922.0 6,028,038.2 470,791.3 4.0 -2,033.75 MWD+SAG+CA+IIFR+MS(2 5,868.4 51.20 209.30 4,429.8 4,373.6 -3,089.8 889.1 6,027,972.7 470,758.2 4.4 -2,029.21 MWD+SAG+CA+IIFR+MS(2 5,962.8 52.70 212.82 4,488.0 4,431.8 -3,153.4 850.8 6,027,909.3 470,719.6 3.3 -2,018.87 MWD+SAG+CA+IIFR+MS(2 6,058.1 50.71 217.72 4,547.1 4,490.9 -3,214.5 807.6 6,027,848.4 470,676.2 4.5 -2,003.12 MWD+SAG+CA+IIFR+MS(2 6,151.9 50.37 223.81 4,606.7 4,550.5 -3,269.3 760.4 6,027,793.8 470,628.7 5.0 -1,981.15 MWD+SAG+CA+IIFR+MS(2 6,246.5 50.36 228.36 4,667.0 4,610.8 -3,319.8 708.0 6,027,743.5 470,576.1 3.7 -1,952.72 MWD+SAG+CA+I1FR+MS(2 6,341.8 49.80 232.42 4,728.2 4,672.0 -3,366.4 651.7 6,027,697.2 470,519.7 3.3 -1,919.20 MWD+SAG+CA+IIFR+MS(2 6,437.5 51.82 235.29 4,788.7 4,732,5 -3,410.1 591.8 6,027,653.7 470,459.6 3.1 -1,881.23 MWD+SAG+CA+1IFR+MS(2 6,532.2 50.20 239.91 4,848.3 4,792.1 -3,449.5 529.7 6,027,614.5 470,397.4 4.2 -1,839.58 MWD+SAG+CA+IIFR+MS(2 6,627.0 50.55 243.97 4,908.8 4,852.6 -3,483.9 465.3 6,027,580.4 470,332.8 3.3 -1,793.76 MWD+SAG+CA+IIFR+MS(2 ' 6,722.4 50.73 248.72 4,969.3 4,913.1 -3,513.5 397.7 6,027,551.1 470,265.1 3.9 -1,743.21 MWD+SAG+CA+I1FR+MS(2 6,817.1 51.37 252.54 5,028.9 4,972.7 -3,537.9 328.2 6,027,527.0 470,195.6 3.2 -1,688.88 MWD+SAG+CA+IIFR+MS(2 6,912.4 53.72 257.22 5,086.8 5,030.6 -3,557.6 255.3 6,027,507.6 470,122.5 4.6 -1,629.44 MWD+SAG+CA+IIFR+MS(2 7,007.5 53.75 261.25 5,143.1 5,086.9 -3,571.9 179.9 6,027,493.6 470,047.1 3.4 -1,565.77 MWD+SAG+CA+IIFR+MS(2 7,102.4 56.05 264.91 5,197.7 5,141.5 -3,581.2 102.9 6,027,484.6 469,970.1 4.0 -1,498.56 MWD+SAG+CA+1IFR+MS(2 7,197.7 58.25 268.37 5,249.4 5,193.2 -3,585.8 23.0 6,027,480.3 469,890.2 3.8 -1,426.88 MWD+SAG+CA+IIFR+MS(2 7,293.4 60.42 272.29 5,298.2 5,242.0 -3,585.3 -59.3 6,027,481.1 469,807.9 4.2 -1,350.96 MWD+SAG+CA+1IFR+MS(2 7,387.6 62.80 274.69 5,343.0 5,286.8 -3,580.3 -142.0 6,027,486.5 469,725.2 3.4 -1,272.93 MWD+SAG+CA+I1FR+MS(2 7,482.7 64.46 278.99 5,385.3 5,329.1 -3,570.1 -226.6 6,027,497.0 469,640.7 4.4 -1,191.10 MWD+SAG+CA+IIFR+MS(2 7,577.5 66.65 282.14 5,424.5 5,368.3 -3,554.3 -311.4 6,027,513.2 469,555.9 3.8 -1,106.87 MWD+SAG+CA+11FR+MS(2 7,672.6 68.89 285.02 5,460.5 5,404.3 -3,533.6 -396.9 6,027,534.2 469,470.5 3.7 -1,020.07 MWD+SAG+CA+IIFR+MS(2 7,767.1 70.92 286.56 5,492.9 5,436.7 -3,509.4 -482.3 6,027,558.7 469,385.3 2.6 -932.10 MWD+SAG+CA+IIFR+MS(2 7,863.1 71.19 286.17 5,524.1 5,467.9 -3,483.8 -569.4 6,027,584.7 469,298.2 0.5 -841.87 MWD+SAG+CA+IIFR+MS(2 7,957.2 71.79 283.99 5,554.0 5,497.8 -3.460.6 -655.6 6,027,608.2 469,212.2 2.3 -753.53 MWD+SAG+CA+IIFR+MS(2 8,051.8 71.24 283.34 5,584.0 5,527.8 -3,439.5 -742.7 6,027,629.7 469,125.1 0.9 -665.06 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:17:23PM Page 4 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,146.7 70.20 283.81 5,615.3 5,559.1 -3.418.4 -829.8 6,027,651.1 469,038.1 1.2 -576.70 MWD4SAG+CA+IIFR+MS(2 8,241.7 69.73 283.24 5,647.9 5,591.7 -3,397.5 -916.6 6,027,672.4 468,951.4 0.7 -488.65 MWD+SAG+CA+IIFR+MS(2 8,335.9 70.20 283.66 5,680.1 5,623.9 -3,377.0 -1,002.7 6,027,693.3 468,865.5 0.7 -401.42 MWD+SAG+CA+IIFR+MS(2 8,431.1 70.68 283.56 5,712.0 5,655.8 -3,355.9 -1,089.9 6,027,714.8 468,778.3 0.5 -312.91 MWD+SAG+CA+IIFR+MS(2 8,525.8 70.31 283.16 5,743.6 5,687.4 -3,335.2 -1,176.7 6,027,735.7 468,691.6 0.6 -224.93 MWD+SAG+CA+IIFR+MS(2 8,620.8 70.45 283.07 5,775.5 5,719.3 -3,314.9 -1,263.8 6,027,756.4 468,604.6 0.2 -136.83 MWD+SAG+CA+11FR+MS(2 8,715.7 71.72 285.77 5,806.3 5,750.1 -3,292.6 -1,350.8 6,027,779.1 468,517.7 3.0 -48.05 MWD+SAG+CA+11FR+MS(2 8,811.1 69.83 284.97 5,837.7 5,781.5 -3,268.7 -1,437.6 6,027,803.3 468,431.0 2.1 41.19 MWD+SAG+CA+11FR+MS(2 8,905.6 71.26 281.99 5,869.2 5,813.0 -3,247.9 -1,524.3 6,027,824.4 468,344.4 3.3 129.02 MWD+SAG+CA+IIFR+MS(2 8,998.8 71.25 283.69 5,899.1 5,842.9 -3,228.3 -1,610.3 6,027,844.4 468,258.4 1.7 215.89 MWD+SAG+CA+11FR+MS(2 9,093.5 70.79 284.37 5,929.9 5,873.7 -3,206.6 -1,697.2 6,027,866.4 468,171.7 0.8 304.34 MWD+SAG+CA+1IFR+MS(2 9,188.3 71.31 285.20 5,960.7 5,904.5 -3,183.7 -1,783.9 6,027,889.7 468,085.1 1.0 393.03 MWD+SAG+CA+I1FR+MS(2 9,282.1 70.96 289.08 5,991.0 5,934.8 -3,157.6 -1,868.7 6,027,916.1 468,000.4 3.9 481.26 MWD+SAG+CA+IIFR+MS(2 9,377.6 69.82 293.06 6,023.1 5,966.9 -3,125.3 -1,952.6 6,027,948.8 467,916.6 4.1 571.17 MWD+SAG+CA+IIFR+MS(2 9,471.7 69.61 297.16 6,055.8 5,999.6 -3,087.8 -2,032.5 6,027,986.6 467,836.9 4.1 659.38 MWD+SAG+CA+IIFR+MS(2 9,566.9 70.27 297.91 6,088.4 6,032.2 -3,046.5 -2,111.8 6,028,028.2 467,757.8 1.0 748.49 MWD+SAG+CA+11FR+MS(2 !i 9,662.0 71.32 297.99 6,119.7 6,063.5 -3,004.4 -2,191.2 6,028,070.7 467,678.6 1.1 838.02 MWD+SAG+CA+IIFR+MS(2 9,756.2 70.77 298.58 6,150.3 6,094.1 -2,962.1 -2,269.6 6,028,113.2 467,600.3 0.8 926.76 MWD+SAG+CA+IIFR+MS(2 9,813.7 71.17 299.23 6,169.1 6,112.9 -2,935.9 -2,317.2 6,028,139.7 467,552.8 1.3 980.83 MWD+SAG+CA+IIFR+MS(2 9,917.2 71.04 301.92 6,202.6 6,146.4 -2,886.1 -2,401.5 6,028,189.8 467,468.8 2.5 1,077.90 MWD+SAG+CA+11FR+MS(2 10,011.7 71.30 305.21 6,233.1 6,176.9 -2,836.6 -2,476.0 6,028,239.6 467,394.4 3.3 1,165.86 MWD+SAG+CA+IIFR+MS(2 10,107.1 72.54 309.37 6,262.7 6,206.5 -2,781.7 -2,548.2 6,028,294.8 467,322.5 4.3 1,253.75 MWD+SAG+CA+11FR+MS(2 MWD+ A + A+IIFR+M (2 10,201.5 75.05 311.55 6,289.0 6,232.8 -2,722.9 -2,617.1 6,028,353.8 467 253.8 3.5 1,340.20 S G C S 10,297.8 76.13 312.47 6,313.0 6,256.8 -2,660.5 -2,686.4 6,028,416.5 467,184.8 1.5 1,428.42 MWD+SAG+CA+IIFR+MS(2 10,392.3 76.38 313.43 6,335.5 6,279.3 -2,597.9 -2,753.6 6,028,479.3 467,117.9 1.0 1,514.73 MWD+SAG+CA+IIFR+MS(2 10,488.1 76.13 313.59 6,358.2 6,302.0 -2,533.8 -2,821.1 6,028,543.7 467,050.6 0.3 1,601.98 MWD+SAG+CA+IIFR+MS(2 10,581.7 76.32 313.91 6,380.5 6,324.3 -2,471.0 -2,886.7 6,028,606.8 466,985.3 0.4 1,687.01 MWD+SAG+CA+IIFR+MS(2 10,635.0 76.32 313.91 6,393.1 6,336.9 -2,435.1 -2,924.0 6,028,642.9 466,948.1 0.0 1,735.39 PROJECTED to TD 8/24/2009 2:17:23PM Page 5 COMPASS 2003.16 Build 71 x Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB2 Database: EDM 2003.16 Single User Db • Project Oooguruk Developement Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-36-Slot ODS-36 Well Position +N/-S 0.0 ft Northing: 6,031,065.83 ft Latitude: 70°29'45.399 N +E/-W 0.0 ft Easting: 469,881.69 ft Longitude: 150° 14'46.595 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-36 PB2 Magnetics Model Name Sample Date Declination '' Dip Angle ld Strength •fl (0) -1,0'„'-'4'7',i'•'„ (0) S IGRF200510 4/9/2009 22.31 80.81 57,729 Design ODSN-36 PN10 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,627.0 Vertical Section: Depth From(TVD) +N/-S +E/-W ,Direction (ft) (ft) (ft) C1 42.7 0.0 0.0 293.00 Survey Program Date 8/21/2009 ''',''': '' , ',1 From To .I (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.0 263.0 ODSN-36 PN10 PB1 Gyro(ODSN-36 PE CB-GYRO-SS Camera based gyro single shot 3/13/2009 1: 305.5 6,627.0 ODSN-36 PN10 PB1 MWD(ODSN-36 P MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 3/13/2009 1: 6,654.5 9,381.3 ODSN-36 PN10 MWD PB2(ODSN-36 P MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 4/9/2009 12: I Survey,. Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 43.8 0.2 -0.1 6,031,066.0 469,881.6 0.7 0.15 CB-GYRO-SS(1) 173.0 0.34 6.40 173.0 116.8 0.6 -0.2 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS(1) 263.0 0.12 82.32 263.0 206.8 0.9 -0.1 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS(1) 305.5 0.34 85.09 305.5 249.3 0.9 0.1 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS(2 395.7 1.67 137.26 395.7 339.5 -0.1 1.3 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS(2 489.5 4.21 129.08 489.3 433.1 -3.2 4.9 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS(2 580.2 5.08 122.30 579.7 523.5 -7.5 10.8 6,031,058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS(2 671.1 6.36 126.84 670.2 614.0 -12.6 18.3 6,031,053.1 469,899.9 1.5 -21.76 MWD+SAG+CA+IIFR+MS(2 764.1 6.03 126.15 762.6 706.4 -18.6 26.3 6,031,047.1 469,907.9 0.4 -31.52 MWD+SAG+CA+IIFR+MS(2 859.5 6.88 128.79 857.4 801.2 -25.2 34.8 6,031,040.5 469,916.4 0.9 -41.89 MWD+SAG+CA+IIFR+MS(2 948.9 7.50 128.01 946.1 889.9 -32.1 43.6 6,031,033.6 469,925.2 0.7 -52.68 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:18:21PM Page 2 COMPASS 2003.16 Build 71 li Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB2 Database: EDM 2003.16 Single User Db Survey I Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,043.5 9.23 133.51 1,039.7 983.5 -41.1 54.0 6,031,024.5 469,935.5 2.0 -65.75 MWD+SAG+CA+11FR+MS(2 1,139.9 11.67 130.99 1,134.5 1,078.3 -52.8 66.9 6,031,012.7 469,948.4 2.6 -82.27 MWD+SAG+CA+IIFR+MS(2 1,236.3 15.41 132.58 1,228.2 1,172.0 -67.9 83.7 6,030,997.6 469,965.2 3.9 -103.63 MWD+SAG+CA+IIFR+MS(2 1,286.8 18.40 133.42 1,276.6 1,220.4 -77.9 94.5 6,030,987.5 469,975.9 5.9 -117.43 MWD4SAG+CA+IIFR+MS(2 1,332.9 20.25 132.03 1,320.0 1,263.8 -88.3 105.7 6,030,977.1 469,987.0 4.1 -131.78 MWD+SAG+CA+IIFR+MS(2 1,429.6 23.87 135.45 1,409.7 1,353.5 -113.4 131.9 6,030,951.9 470,013.1 4.0 -165.69 MWD+SAG+CA+IIFR+MS(2 1,477.4 27.27 133.74 1,452.8 1,396.6 -127.9 146.6 6,030,937.3 470,027.7 7.3 -184.89 MWD+SAG+CA+IIFR+MS(2 1,526.1 29.56 132.65 1,495.6 1,439.4 -143.7 163.4 6,030,921.4 470,044.5 4.8 -206.61 MWD+SAG+CA+IIFR+MS(2 1,623.1 33.50 131.69 1,578.2 1,522.0 -177.8 201.0 6,030,887.3 470,082.0 4.1 -254.52 MWD+SAG+CA+11FR+MS(2 1,719.4 38.04 132.23 1,656.4 1,600.2 -215.4 242.9 6,030,849.4 470,123.7 4.7 -307.75 MWD+SAG+CA+11FR+MS(2 1,816.4 39.04 132.22 1,732.2 1,676.0 -256.0 287.6 6,030,808.7 470,168.3 1.0 -364.82 MWD+SAG+CA+11FR+MS(2 1,913.6 38.51 133.70 1,808.0 1,751.8 -297.5 332.2 6,030,767.0 470,212.6 1.1 -422.03 MWD+SAG+CA+11FR+MS(2 2,008.2 36.95 136.81 1,882.8 1,826.6 -338.6 372.9 6,030,725.8 470,253.2 2.6 -475.59 MWD+SAG+CA+11FR+MS(2 2,104.6 38.08 140.89 1,959.3 1,903.1 -382.8 411.6 6,030,681.4 470,291.7 2.8 -528.42 MWD+SAG+CA+11FR+MS(2 2,201.8 39.39 147.75 2,035.2 1,979.0 -432.2 446.9 6,030,631.9 470,326.8 4.6 -580.26 MWD+SAG+CA+IIFR+MS(2 2,298.1 41.01 151.13 2,108.7 2,052.5 -485.7 478.5 6,030,578.3 470,358.2 2.8 -630.23 MWD+SAG+CA+IIFR+MS(2 2,396.0 40.88 152.82 2,182.7 2,126.5 -542.3 508.6 6,030,521.5 470,388.1 1.1 -680.10 MWD+SAG+CA+I1FR+MS(2 2,491.7 42.54 154.78 2,254.1 2,197.9 -599.4 536.7 6,030,464.3 470,415.9 2.2 -728.28 MWD+SAG+CA+11FR+MS(2 2,587.9 44.85 156.23 2,323.7 2,267.5 -659.9 564.3 6,030,403.7 470,443.2 2.6 -777.26 MWD+SAG+CA+IIFR+MS(2 2,634.7 47.29 157.78 2,356.1 2,299.9 -690.9 577.4 6,030,372.6 470,456.2 5.7 -801.49 MWD+SAG+CA+IIFR+MS(2 2,684.5 51.29 157.87 2,388.6 2,332.4 -725.9 591.7 6,030,337.6 470,470.3 8.0 -828.26 MWD+SAG+CA+IIFR+MS(2 2,732.3 53.75 159.28 2,417.7 2,361.5 -761.2 605.5 6,030,302.2 470,484.1 5.7 -854.82 MWD+SAG+CA+I1FR+MS(2 2,781.0 55.96 162.61 2,445.7 2,389.5 -798.8 618.5 6,030,264.6 470,496.9 7.2 -881.45 MWD+SAG+CA+IIFR+MS(2 2,828.3 56.38 162.38 2,472.1 2,415.9 -836.3 630.3 6,030,227.0 470,508.6 1.0 -907.00 MWD+SAG+CA+IIFR+MS(2 2,877.9 57.18 163.23 2,499.3 2,443.1 -876.0 642.6 6,030,187.4 470,520.7 2.2 -933.76 MWD+SAG+CA+11FR+MS(2 2,974.2 57.45 166.81 2,551.3 2,495.1 -954.2 663.5 6,030,109.0 470,541.3 3.1 -983.62 MWD+SAG+CA+IIFR+MS(2 3,070.5 53.94 166.00 2,605.5 2,549.3 -1,031.5 682.2 6,030,031.7 470,559.6 3.7 -1,031.01 MWD+SAG+CA+IIFR+MS(2 3,166.8 49.33 165.38 2,665.3 2,609.1 -1,104.7 700.8 6,029,958.5 470,578.0 4.8 -1,076.75 MWD+SAG+CA+IIFR+MS(2 3,263.5 47.48 164.96 2,729.5 2,673.3 -1,174.6 719.4 6,029,888.4 470,596.2 1.9 -1,121.13 MWD+SAG+CA+1IFR+MS(2 3,360.9 46.77 162.67 2,795.8 2,739.6 -1,243.1 739.2 6,029,819.8 470,615.8 1.9 -1,166.20 MWD+SAG+CA+IIFR+MS(2 3,457.7 45.27 162.67 2,863.0 2,806.8 -1,309.7 760.0 6,029,753.2 470,636.3 1.5 -1,211.31 MWD+SAG+CA+IIFR+MS(2 3,554.2 42.57 163.25 2,932.5 2,876.3 -1,373.7 779.6 6,029,689.2 470,655.7 2.8 -1,254.37 MWD+SAG+CA+IIFR+MS(2 3,634.0 42.77 162.93 2,991.2 2,935.0 -1,425.4 795.3 6,029,637.4 470,671.2 0.4 -1,289.07 MWD+SAG+CA+IIFR+MS(2 3,686.7 43.44 161.54 3,029.6 2,973.4 -1,459.6 806.3 6,029,603.1 470,682.0 2.2 -1,312.56 MWD+SAG+CA+IIFR+MS(2 3,740.0 44.21 162.62 3,068.1 3,011.9 -1,494.8 817.7 6,029,567.9 470,693.2 2.0 -1,336.76 MWD+SAG+CA+IIFR+MS(2 3,783.5 44.72 161.58 3,099.1 3,042.9 -1,523.8 827.1 6,029,538.9 470,702.5 2.0 -1,356.70 MWD+SAG+CA+IIFR+MS(2 3,878.2 44.25 161.84 3,166.7 3,110.5 -1,586.8 847.9 6,029,475.8 470,723.1 0.5 -1,400.49 MWD+SAG+CA+IIFR+MS(2 3,972.8 44.56 162.68 3,234.3 3,178.1 -1,649.8 868.0 6,029,412.7 470,743.0 0.7 -1,443.67 MWD+SAG+CA+I1FR+MS(2 4,068.1 46.87 164.02 3,300.8 3,244.6 -1,715.2 887.6 6.029,347.3 470,762.2 2.6 -1,487.18 MWD+SAG+CA+1IFR+MS(2 4,164.0 49.70 166.27 3,364.6 3,308.4 -1,784.3 905.9 6,029,278.0 470,780.2 3.4 -1,531.07 MWD+SAG+CA+IIFR+MS(2 8/24/2009 2:18:21 PM Page 3 COMPASS 2003.16 Build 71 , Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS 4N1-S +Ei-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,257.7 50.65 168.64 3.424.7 3,368.5 -1,854.6 921.5 6,029,207.7 470,795.6 2.2 -1,572.93 MWD+SAG+CA+11FR+MS(2 4,351.7 50.91 170.49 3,484.1 3,427.9 -1,926.2 934.7 6,029,136.0 470,808.5 1.5 -1,613.04 MWD+SAG+CA+IIFR+MS(2 j 4,446.8 52.02 172.32 3,543.4 3,487.2 -1,999.8 945.8 6,029,062.4 470,819.3 1.9 -1,652.01 MWD+SAG+CA+IIFR+MS(2 4,541.3 52.94 173.13 3,600.9 3,544.7 -2,074.1 955.3 6,028,988.1 470,828.5 1.2 -1,689.77 MWD+SAG+CA+IIFR+MS(2 4,635.8 53.17 172.12 3,657.7 3,601.5 -2,149.1 965.0 6,028,913.1 470,837.9 0.9 -1,727.98 MWD+SAG+CA+IIFR+MS(2 4,730.9 51.72 172.49 3,715.6 3,659.4 -2,223.7 975.1 6,028,838.4 470,847.7 1.6 -1,766.45 MWD+SAG+CA+IIFR+MS(2 4,826.3 52.12 173.04 3,774.5 3,718.3 -2,298.2 984.5 6,028,763.9 470,856.8 0.6 -1,804.25 MWD+SAG+CA+IIFR+MS(2 4,919.9 52.67 176.70 3,831.6 3,775.4 -2,372.1 991.2 6,028,690.0 470,863.1 3.2 -1,839.21 MWD+SAG+CA+IIFR+MS(2 5,013.4 51.64 177.77 3.889.0 3,832.8 -2,445.8 994.7 6,028,616.3 470,866.4 1.4 -1,871.31 MWD+SAG+CA+IIFR+MS(2 5,108.7 50.87 180.12 3,948.6 3,892.4 -2,520.1 996.1 6,028,542.0 470,867.5 2.1 -1,901.59 MWD+SAG+CA+IIFR+MS(2 5,204.8 52.37 179.20 4,008.3 3,952.1 -2,595.5 996.6 6,028,466.6 470,867.6 1.7 -1,931.46 MWD+SAG+CA+IIFR+MS(2 5,299.1 51.17 181.09 4,066.7 4,010.5 -2,669.5 996.4 6,028,392.5 470,867.1 2.0 -1,960.25 MWD+SAG+CA+IIFR+MS(2 5,395.2 50.26 184.27 4,127.5 4,071.3 -2,743.8 992.9 6,028,318.3 470,863.4 2.7 -1,986.08 MWD+SAG+CA+IIFR+MS(2 5,491.6 49.33 189.57 4,189.8 4,133.6 -2,816.9 984.1 6,028,245.3 470,854.2 4.3 -2,006.48 MWD+SAG+CA+IIFR+MS(2 5,586.7 50.07 194.04 4,251.3 4,195.1 -2,887.8 969.2 6,028,174.4 470,839.1 3.7 -2,020.54 MWD+SAG+CA+IIFR+MS(2 5,679.3 50.76 199.12 4,310.3 4,254.1 -2,956.1 948.9 6,028,106.2 470,818.5 4.3 -2,028.50 MWD+SAG+CA+IIFR+MS(2 5,773.9 50.69 203.95 4,370.3 4,314.1 -3,024.3 922.0 6,028,038.2 470,791.3 4.0 -2,030.37 MWD+SAG+CA+IIFR+MS(2 5,868.4 51.20 209.30 4,429.8 4,373.6 -3,089.8 889.1 6,027,972.7 470,758.2 4.4 -2,025.72 MWD+SAG+CA+IIFR+MS(2 5,962.8 52.70 212.82 4,488.0 4,431.8 -3,153.4 850.8 6,027,909.3 470,719.6 3.3 -2,015.29 MWD+SAG+CA+IIFR+MS(2 6,058.1 50.71 217.72 4,547.1 4,490.9 -3,214.5 807.6 6,027,848.4 470,676.2 4.5 -1,999.43 MWD+SAG+CA+IIFR+MS(2 6,151.9 50.37 223.81 4,606.7 4,550.5 -3,269.3 760.4 6,027,793.8 470,628.7 5.0 -1,977.36 MWD+SAG+CA+IIFR+MS(2 6,246.5 50.36 228.36 4,667.0 4,610.8 -3,319.8 708.0 6,027,743.5 470,576.1 3.7 -1,948.84 MWD+SAG+CA+IIFR+MS(2 6,341.8 49.80 232.42 4,728.2 4,672.0 -3,366.4 651.7 6,027,697.2 470,519.7 3.3 -1,915.23 MWD+SAG+CA+IIFR+MS(2 6,437.5 51.82 235.29 4,788.7 4,732.5 -3,410.1 591.8 6,027,653.7 470,459.6 3.1 -1,877.17 MWD+SAG+CA+IIFR+MS(2 6,532.2 50.20 239.91 4,848.3 4,792.1 -3,449.5 529.7 6,027,614.5 470,397.4 4.2 -1,835.43 MWD+SAG+CA+IIFR+MS(2 6,627.0 50.55 243.97 4,908.8 4,852.6 -3,483.9 465.3 6,027,580.4 470,332.8 3.3 -1,789.53 MWD+SAG+CA+11FR+MS(2 6,654.5 50.49 244.25 4,926.3 4,870.1 -3,493.2 446.2 6,027,571.2 470,313.6 0.8 -1,775.58 MWD+SAG+CA+IIFR+MS(3 6,686.3 52.76 246.15 4,946.0 4,889.8 -3,503.6 423.5 6,027,560.9 470,291.0 8.5 -1,758.81 MWD+SAG+CA+IIFR+MS(3 6,782.2 55.63 251.00 5,002.1 4,945.9 -3,531.9 351.2 6,027,532.8 470,218.5 5.1 -1,703.29 MWD+SAG+CA+IIFR+MS(3 6,876.6 54.28 253.85 5,056.4 5,000.2 -3,555.3 277.5 6,027,509.8 470,144.8 2.9 -1,644.61 MWD+SAG+CA+1IFR+MS(3 6,971.2 51.61 257.61 5,113.4 5,057.2 -3,573.9 204.4 6,027,491.5 470,071.6 4.2 -1,584.58 MWD+SAG+CA+11FR+MS(3 7,067.0 49.92 260.74 5,174.0 5,117.8 -3,587.9 131.5 6,027,477.8 469,998.7 3.1 -1,522.97 MWD+SAG+CA+11FR+MS(3 7,162.4 51.25 265.73 5,234.6 5,178.4 -3,596.5 58.4 6,027,469.4 469,925.5 4.3 -1,459.01 MWD+SAG+CA+11FR+MS(3 7,256.9 51.60 270.98 5,293.5 5,237.3 -3,598.6 -15.4 6,027,467.6 469,851.7 4.4 -1,391.90 MWD+SAG+CA+1IFR+MS(3 7,351.9 52.02 274.61 5,352.3 5,296.1 -3,595.0 -90.0 6,027,471.6 469,777.1 3.0 -1,321.85 MWD+SAG+CA+IIFR+MS(3 7,446.3 52.16 277.90 5,410.3 5,354.1 -3,586.9 -164.0 6,027,480.0 469,703.2 2.8 -1,250.54 MWD+SAG+CA+IIFR+MS(3 7,540.7 53.71 281.06 5,467.2 5,411.0 -3,574.5 -238.3 6,027,492.7 469,629.0 3.1 -1,177.32 MWD+SAG+CA+IIFR+MS(3 7,636.1 55.23 283.24 5.522.6 5,466.4 -3,558.1 -314.2 6,027,509.4 469,553.1 2.4 -1,101.07 MWD+SAG+CA+IIFR+MS(3 7,732.2 57.41 287.13 5,575.9 5,519.7 -3,537.1 -391.3 6,027,530.7 469,476.1 4.1 -1,021.87 MWD+SAG+CA+IIFR+MS(3 7,827.4 58.66 290.28 5,626.3 5,570.1 -3,511.2 -467.8 6,027,556.9 469,399.7 3.1 -941.35 MWD+SAG+CA+IIFR+MS(3 8/24/2009 2:18:21 PM Page 4 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Project: Oooguruk Developement TVD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-36 North Reference: True Wellbore: ODSN-36 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-36 PN10 PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (`/100') (ft) Survey Tool Name 7,922.1 61.18 292.40 5,673.8 5,617.6 -3,481.4 -544.1 6,027,587.0 469,323.6 3.3 -859.45 MWD+SAG+CA+IIFR+MS(3 8,017.1 63.37 294.18 5,718.0 5,661.8 -3,448.1 -621.3 6,027,620.6 469,246.5 2.8 -775.37 MWD+SAG+CA+IIFR+MS(3 8,112.6 66.23 295.66 5,758.6 5,702.4 -3,411.7 -699.7 6,027,657.3 469,168.3 3.3 -689.02 MWD+SAG+CA+IIFR+MS(3 8,206.7 68.61 297.90 5,794.8 5,738.6 -3,372.6 -777.2 6,027,696.8 469,090.9 3.4 -602.34 MWD+SAG+CA+IIFR+MS(3 8,301.6 71.18 300.93 5,827.4 5,771.2 -3,328.8 -854.8 6,027,740.9 469,013.5 4.0 -513.80 MWD+SAG+CA+11FR+MS(3 8,395.5 73.48 302.46 5,855.9 5,799.7 -3,281.8 -930.9 6,027,788.2 468,937.6 2.9 -425.37 MWD+SAG+CA+IIFR+MS(3 8,491.2 75.57 304.79 5,881.4 5,825.2 -3,230.7 -1,007.7 6,027,839.6 468,861.0 3.2 -334.73 MWD+SAG+CA+11FR+MS(3 8,586.2 76.26 308.29 5,904.6 5,848.4 -3,175.9 -1,081.7 6,027,894.7 468,787.2 3.6 -245.17 MWD+SAG+CA+IIFR+MS(3 8,682.1 76.92 310.09 5,926.8 5,870.6 -3,116.9 -1,154.0 6,027,953.9 468,715.2 2.0 -155.59 MWD+SAG+CA+IIFR+MS(3 8,775.5 76.90 312.06 5,948.0 5,891.8 -3,057.1 -1,222.6 6,028,014.0 468,646.8 2.1 -69.11 MWD+SAG+CA+IIFR+MS(3 8,871.6 76.28 315.95 5,970.3 5,914.1 -2,992.2 -1,289.8 6,028,079.2 468,579.9 4.0 18.14 MWD+SAG+CA+IIFR+MS(3 8,965.7 76.26 317.19 5,992.6 5,936.4 -2,925.8 -1,352.7 6,028,145.8 468,517.3 1.3 101.92 MWD+SAG+CA+IIFR+MS(3 9,060.8 76.03 319.07 6,015.4 5,959.2 -2,857.1 -1,414.3 6,028,214.8 468,456.0 1.9 185.51 MWD+SAG+CA+IIFR+MS(3 9,155.1 75.76 320.26 6,038.4 5,982.2 -2,787.4 -1,473.5 6,028,284.7 468,397.1 1.3 267.24 MWD+SAG+CA+IIFR+MS(3 9,250.0 76.85 322.70 6,060.8 6,004.6 -2,715.2 -1,530.9 6,028,357.1 468,340.0 2.7 348.28 MWD+SAG+CA+IIFR+MS(3 9,291.4 76.74 322.11 6,070.3 6,014.1 -2,683.3 -1,555.5 6,028,389.1 468,315.5 1.4 383.39 MWD+SAG+CA+IIFR+MS(3 9,381.3 77.95 319.13 6,090.0 6,033.8 -2,615.5 -1,611.1 6,028,457.1 468,260.1 3.5 461.10 MWD+SAG+CA+IIFR+MS(3 9,509.0 77.95 319.13 6,116.6 6,060.4 -2,521.1 -1,692.9 6,028,551.9 468,178.8 0.0 573.22 PROJECTED to TD 8/24/2009 2:18:21PM Page 5 COMPASS 2003.16 Build 71 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: September 30, 2009 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Steve Davies 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter E Maps ❑ Report X Other—3 CDs Please replace these ❑ Agreement CDs bvlth the crIgInal CDs Included In the prevlous package-this CD set Includes log data rnIssing•rcrn the orIgInal disks.) DETAIL QTY DESCRIPTION 3 CDs ODSN-36 (API: 50-703-20561-00) ODSN-36 PB1 (API: 50-703-20561-70) ODSN-36 PB2 (API: 50-703-20561-71) 3 CDs containing digital graphic logs (EMF, CGM, PDF, TIFF)AND DIGITAL DATA (LAS, DLIS) We request that all to be treated as confidential information. Thank you. Received by: Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 D.--( `6Q 907-343-2190 fax PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: September 21, 2009 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Steve Davies 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other—10 Well Logs ❑ Agreement DETAIL QTY DESCRIPTION 8 Well Logs ODSN-36 (API: 50-703-20561-00) Combination Mud Log, 5" Combination Mud Log, Engineering Log, Gas Ratio Log ODSN-36 PB1 (API: 50-703-20561-70) Combination Mud Log, 5" Combination Mud Log, Engineering Log) ODSN-36 PB2 (API: 50-703-20561-71) Combination Mud Log, 5" Combination Mud Log, Engineering Log) We request that all data a treated as confidential information.Thank you. (1)i _— Received by: � = Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: September 15, 2009 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Steve Davies 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps E Report X Other—3 CDs, 12 Well Logs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-36 (API: 50-703-20561-00) ODSN-36 PB1 (API: 50-703-20561-70) ODSN-36 PB2 (API: 50-703-20561-71) 3 CDs 3 CDs containing digital graphic logs (EMF, CGM, PDF, TIFF)AND DIGITAL DATA (LAS, DLIS) 12 Well Logs 12 Well logs DGR, EWR-Phase 4, CTN, ALD, Horizontal Presentation (1:600, 1:240)TVD log, MD log We request that all data be treated as confidential information. Thank you. r\ Received by:‘, Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax 6 1/ 76-613 Page 1 of 1 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, July 14, 2009 10:59 AM To: Maunder, Thomas E(DOA) Cc: Fleckenstein, Robert J (DOA) Subject: RE: Oooguruk ODSN-36 Thak you for revewing records, Bob and I added an action in RBDMS that shows the BOPE test cycle was changed from 7 to 14day on 8/21/2008 (approval done by email) Jim Regg AOGCC 333 W 7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Maunder,Thomas E (DOA) Sent: Sunday, July 05, 2009 2:32 PM To: Regg,James B(DOA) Cc: Fleckenstein, Robert J (DOA) Subject: FW: Oooguruk ODSN-36 Jim and Bob, I was clearing out some old documents/emails and found this one. I have examined the file and determined the following: Original permit issued 1/11/08 for ODSK-36. 1-28—2-04-08 surface hole drilled and surface casing set. Revised permit issued 2/11/09 for ODSN-36. There is nothing specifically noted on the revised 401 regarding a 7-day BOP test schedule. The 7-day schedule was specifically noted on the original permit. It appears as you surmised that the 7-day interval was carried over in RBDMS. Lets talk about entering the note in RBDMS. Tom From: Regg,James B (DOA) Sent: Wednesday, March 18, 2009 3:13 PM To: Maunder,Thomas E (DOA) Cc: Fleckenstein, Robert 3 (DOA) Subject: Oooguruk ODSN-36 Just received BOPE test for this indicating bi-weekly test; RBDMS has a Master Well File Comment requiring BOPE test frequency every 7days; it is possible this is an unitended carry over from original application (1/11/2008; PTD 207-182) that is superceded by approval dated 2/11/2009(same PTD; BHL changed>500 ft). If intent was for BOPE test to be every 14days on OSDN-36,we need a note in RBDMS to that effect. Please advise. Jim Regg AOGCC 333 W 7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 CO P c�- 9/2/2009 STATE OF ALASKA 11/28/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 19AC DATE: 3/17/2009 Rig Rep.: James L.West Jr. Rig Phone: 670-6630 Rig Fax: 670-6612 Operator: PNRA Op. Phone: 670-6606 Op. Fax: 670-6673 Rep.: Rod Klepzig Field/Unit&Well No.: Oooguruk/ODSN-36 PTD# 207-182 Operation: Drig: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly X Test Pressure: Rams: 250/3500 Annular: 250/2,500 Valves: 250/3500 TEST DATA MISC.INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P DrI. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P _ BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 11" P Quantity Test Result Pipe Rams 1 5" P No.Valves 14 P Lower Pipe Rams 1 5" P Manual Chokes 1 P Blind Rams 1 P Hydraulic Chokes 1 P Choke Ln.Valves 1 3-1/8" P HCR Valves 2 3-1/8" P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8" P Time/Pressure Test Result Check Valve 0 NA System Pressure 3050 P Pressure After Closure 1950 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 14sec P Trip Tank P P Full Pressure Attained 1:42 P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles(avg): 5©1975 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours Components tested 28 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607,follow with written confirmation to Superviser at: Remarks: 24 HOUR NOTICE GIVEN YES x NO Waived By Date 0.3/17/0.9 Time Witness Bob Noble Test start 22:00 Finish 1:30 BOP Test(for rigs) BFL 11/28/07 BOP Naborsl9AC ODSN-36 3-17-09.xls , , �, , LT- ALASKA SARAH PAL/N,GOVERNOR ti ALASKA OIL AJVI) GAS ,'" 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ANCHOEFtAGE (907)2794339501-3539 PHONFAX (907)276-7542 James Franks Pioneer Natural Resources Alaska Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk, Nuiqsut Oil Pool, ODSN-36 Sundry Number: 309-199 Dear Mr. Franks: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Asrovided in AS 31.05.080, within 20 days after written notice of this P Y decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, -" / Daniel T. Seamount, Jr. Chair DATED this/ day of June, 2009 End. 001,1ba STATE OF ALASKA c Gft -0 (ems 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 4 G APPLICATION FOR SUNDRY APPROVALS t� 1 20 AAC 25.280 1.Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver❑ Other❑ Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate 0 • Time Extension ❑ Change approved program Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development O Exploratory ❑ 207-182 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 700 G Street,Suite 600 Anchorage,AK 99501 50-703-20561-00 . 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No EODSN-36 9. Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 355036 • 57.5'MSL . Ooogurk- Nuiqsut Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 3683' 3027' 3664' 3013' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 153' N/A N/A Surface 3625' 9-5/8" 3666' 3015' 5750 3090 Intermediate 10580' 7" 10618' 6341' 7240' 5410' Expandable Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): . Packers and SSSV Type: Packers and SSSV MD(ft): 13.Attachments: Description Summary of Proposal 0 14.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development Q • Service ❑ 15. Estimated Date for 16.Well Status after proposed work: 7/4/2009 Commencing Operations: Oil Q . Gas ❑ Plugged ❑ Abandoned ❑ 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name James Franks Title Senior Drilling Engineer Signature Phone Date 343-2179 6/11/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: )o—1 - t O` O\ Plug Integrity ❑ BOP Test gl. Mechanical Integrity Test ❑ Location Clearance ❑ Other:3Soo , mN.,v4 ` asomas;4,,\I ‘t,&‘) tx,,a, RECEIVED Q JuN i 2 7_009 Alaska Oil &Gas Cons. Commission Subsequent Form Required: LYt'1 �`.J Anchorage APPROVED BY / Approved by: "d% / COMMISSIONER THE COMMISVSION ate: `E� / C / C2( Form 10-403 Revised 06/2006 0 t \ I G I N A L o liffillekit in Duplk dt '(;g)17'`9 PIONEek NATURAL RESOURCES June 15, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry, Addition of flowback following production lateral and fracture stimulation program Permit to Drill #207-182 Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM X = 469881.69, Y = 6031065.83, ASP4 Pioneer Natural Resources, Alaska (PNRA) is submitting a fracture stimulation and flowback proposal for AOGCC's review and approval for the ODSN-36 well. Pioneer originally permitted the Nuiqsut production well to drill the 6 1/8" lateral, set a 4 '/2" 12.6# L-80 liner, and run an ESP completion. Pioneer has opted,to add a fracture stimulation and flow back period to the approved Permit to Drill (# 207-182). ODSN-36 will be produced for some period of time using gas lift prior to re-completing with ESP. Currently ODSN-36 is operationally shut down with intermediate casing run and cemented at 10,618' MD / 6341' TVD. The proposed plan is as follows: Pre-Rig Work: 1. The Oooguruk Drill Site Class 1 /Class 2 Disposal Well, ODSDW1-44, has been drilled, commissioned and operational for disposal. 2. Provide 48 hours notice for the testing of the BOPE. 3. Post Permit to Drill #207-182 Rig Activity: Drill and Complete Remaining Well 1. MIRU to ODSN-36. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. Alaska Oil & Gas Conservation Commission June 15, 2009 Page 2 of 4 2. Install TWC, ND Tree and NU BOPE, Remove TWC, Test BOPE to 250/3500 psi. 3. Pull circulation tubing string from the well. 4. MU 6-1/8" directional drilling, MWD/LWD assembly. RIH and cleanout to landing collar. A cement evaluation log will not be run. 5. Pressure test the 7"casing to 3,500 psi for 30 min. 6. Displace the well over to production hole drilling fluid. Managed Pressure Drilling will be used. 7. 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. 8. Drill the 6-1/8" production hole to TD at-18,646' MD/6,422' TVDrkb. POH. 9. Circulate and condition the hole to run liner. POH. 10. Run 4-1/2" liner on 4" DP 11. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine. POH. 12. Run 4 '/2"fracture completion string 13. Fracture stimulate well 620,000 lbs of 20/40 Carboceramics Carbolite proppant pumped in 300,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target zones 1 and 5 of the Nuiqsut reservoir in a 10 stage treatment using dynamic diversion (Bioballs). The expected surface treating pressure at a planned pump rate of 40 barrels per minute is 6800 psi. Maximum proppant concentration is 5 ppa per gallon. The Schlumberger YF125ST is a water based guar gel system with borate crosslinker. The chemical make-up of the YF125ST includes: Seawater base-983.75 gpt Clay Stabilizer-2 gpt Polymer-6.25 gpt Surfactant-2 gpt Crosslinker-6 gpt Oxidative Breaker-0.05 ppt 14. Remove SSSV sleeve and install wireline retrievable SSSV 15. Install live gaslift valves 16. Flowback well with gaslift. 17. RDMO ODSN-36 Re-Complete ODSN-36 with ESP _ 'T ~�s 4:)c) 1/4.)[\'t-�� 1. MIRU ODSN-36. SQ? G Q� v�\ 2. Pull 4 '/2"fracture completion string. f, � 3. MU completion with ESP and RIH. 971/7 4. 4. Land the tubing and RILDS. Install TWC. ic-k Alaska Oil & Gas Conservation Commission June 15, 2009 Page 3 of 4 5. ND BOPE, NU tree and test to 5,000 psi. 6. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to —2000'TVD and allow to u-tube. 7. 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. 8. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 9. RD Slickline. RDMO to next well. ' Alaska Oil & Gas Conservation Commission June 15, 2009 Page 4 of 4 Please find attached information for your review: 1) Form 10-403 Application for Sundry. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report James Franks, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2179 iames.franksapxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggettapxd.com Sincerely, 4 James Franks Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-36 Well File ' r H A LL I B U R TO N PIONEER NATURAL RESOURCES ODSN-36 Pioneer ODSN-36 Intermediate 1.0 EXECUTIVE SUMMARY Alex Vaughan Pioneer Natural Resources Alaska Anchorage,AK Dear Mr.Vaughan, Halliburton appreciates the opportunity to perform the cement job.A pre job safety meeting was held where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined 10,618'of 7"26#/ft casing was successfully cemented inside an 8-3/4"hole from TD to 1,014'above the Kup C in a planned single stage job. The well was conditioned and circulated after casing was run. 11.8 ppg mud was circulated at 4-6 bpm with circulating pressures noted at 600—1,350 psi with 40/60 bph losses. A total of 10 bbls of water were pumped and lines were tested to 3,500 psi. 50 bbls of 12.5 ppg Dual Spacer, 68.8 bbls (161 sacks) of Premium cement with 15 #/sk Microlite, 0.2% CFR-3, 0.75% Halad 344, 0.15% EZ-FLO & 0.25% SCR-100 mixed at12.5ypg, and 22.9 bbls (109 sacks) of Premium cement with 0.2%CFR-3, 0.5% Halad 344, 0.25% Super CBL and 0.5% SCR-100 mixed at 15.8 ppg were pumped prior to dropping the top cementing plug. The rig pumped the displacement. A total of 403 bbls of seawater and mud were pumped prior to landing the plug at 2,000 psi.The pressure was held for several minutes.Pressure was released and the floats were checked.The floats held. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Respectfully, Phillip Clingman 3 Created:June 12,2009 at 9:37 AM OptiCem v6.4.1 (OC v6.4.1) HALLIBURTON PIONEER NATURAL RESOURCES ODSN-36 • Pioneer ODSN-36 Intermediate 2.0 DESIGN 2.1 Customer Information Customer PIONEER NATURAL RESOURCES Sales Order 6598046 Job Configuration Conventional Cement Well Name ODSN-36 (formerly ODSK-36i) Well Number ODSN-36 Start Time Thursday, April 23, 2009 County State Alaska UWI/API 50-703-20561-00 Country United States of America H2S Present Unknown CO2 Present Unknown Customer Representative Rodney Klepzig/ Nick Scales Service Representative Ed Jans Job Name ODSN-36 7 inch Intermediate Recalcl Inaction Path Tubing/Casing 2.2 Parameters Intermediate Casing Size&Wt. 7"26#/ft Casing Depth 10,618' Surface Casing Size&Wt. 9-5/8"40#/ft Surface Casing Depth 3,665' Hole Size 8-3/4" Mud 11.8 ppg WBM Planned Volume Excess 60%Lead/30%Tail 2.3 Fluids Summary Preflush 10 bbls Water Spacer 50 bbls Dual Spacer 12.5 ppg Lead Slurry 68.8 bbls(161 sacks)Premium cement with 15#/sk Microlite,0.2% CFR-3,0.75%Halad 344, 0.15%EZ-FLO&0.25%SCR-100 mixed a 12.5 ppg yielding 2.43 cuft/sk Tail Slurry 22.9 bbls(109 sacks)Premium cement with 0.2%CFR-3,0.5%Halad 344,0.25% Super CBL and 0.5% SCR-100 mixed at 15.8 ppg yielding 1.18 cuftlsk Displacement 403 bbls seawater 2.4 Volume Calculations Lead Slurry—60%Excess 8,447'TOC- 1,607'Fill Tail Slurry—30%Excess 10,054' TOC-564' Fill +85' Shoe track 4 Created:June 12,2009 at 9:37 AM OptiCem v6.4.1 (OC v6.4.1) Page 1 of 2 Maunder, Thomas E (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Monday, April 13, 2009 12:10 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Campoamor, Kathy Subject: RE: ODSN 36 Sidetrack, Oooguruk Nabors 19AC Tom, Thanks for the response. The Kuparuk depths are as follows: Top Kuparuk 9,303' and 6073' tvd Base Kuparuk 9499' and 6115' tvd Vern Johnson From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 10, 2009 4:43 PM To: Johnson, Vern Cc: Hazzard, Vance Subject: RE: ODSN 36 Sidetrack, Oooguruk Nabors 19AC Vern and Vance, Unfortunate happening. Can you provide some information as to the specifics of the Kuparuk interval (md and tvd top and bottom)? Collapsing shales has been an issue with the earlier penetrations. The lost section should have PB2 appended to the name with the API number having a-71-. It is not necessary to file a sundry. Tom Maunder, PE AOGCC From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Fri 4/10/2009 2:52 PM To: Maunder,Thomas E (DOA) Cc: Hazzard, Vance Subject: ODSN 36 Sidetrack, Oooguruk Nabors 19AC Tom, As discussed earlier today, we have inadvertently sidetracked the well ODSN 36. After drilling through the Kuparuk sands to 9509' last week, we stopped to pump a mineral oil/bentonite/cement squeeze treatment to heal losses in the fractured Kuparuk sand. Two treatments were pumped and losses were healed after the second treatment, however we did not resume drilling until yesterday due to successive washouts in the drillstring. While reaming to bottom with a new BHA and new drillpipe, we took weight at 6745' MD. Attempts were made to wash through and ream tight hole down to 6808'MD, where surveys indicated we had sidetracked the well. Attempts were made to re-enter the old hole were unsuccessful. A revised directional plan has been generated to continue the sidetrack and drill to new targets in the Nuiqsut sand. The new target is -270'from the originally permitted location in the Nuiqsut sand. Our expectation is that the shale sections in the Kalubik and HRZ will collapse an provide some isolation above the Kuparuk sand. 9/29/2009 '-C. (-0 Page 2 of 2 Per our discussion, we don't currently plan to submit at 10-403, please let me know if this is has changed now that you have more information. Vern Johnson Sr Staff Drilling Engineer Pioneer Natural Resources 907-343-2111 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. 9/29/2009 in - ,01 �� 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 James Franks Senior Drilling Engineer Pioneer Drilling Resources Alaska Inc. 700 G Street, Ste 600 Anchorage AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-36 Sundry Number: 309-112 Dear Mr. Franks: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel, P. Seamount, Jr. S f Chair' DATED this day of April, 2009 `Ib End. ric ( -, STATE OF ALASKA RECEIVED .Q ALASKA OIL AND GAS CONSERVATION COMMISSION t v' APPLICATION FOR SUNDRY APPROVALAR 2 7 2009 X31 , 20 AAC 25.280 Alas Oil& Gas Cons. mmissio3 ( 1.Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate Lin(�mhhWeerraaiiv[�leppr Other Q Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Timetablifs tr❑ P1/4...,S c_kc,, Change approved program Q Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development ❑ Exploratory ❑ 207-182 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 700 G Street,Suite 600 Anchorage,AK 99501 50-703-20561-00 • 7. It perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E ODSN-36 9.Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 355036 • 42.67 Ooogurk - Nuiqsut Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10635 6393 9442 6045 N/A 9706' Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 158' 158' N/A N/A Surface 3622' 9-5/8" 3665' 3015' 5750 3090 Intermediate Expandable Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft): 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 15. Estimated Date for 16.Well Status after proposed work: Commencing Operations: Oil Q Gas ❑ Plugged ❑ Abandoned ❑ 17.Verbal Approval: Date:CS 2 WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: L,GOfsv l TCk-A J I 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name James Franks Title Senior Staff Drilling Engineer Signature Phone Date 343-2179 3/25/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V0 //c Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: rU'\(r OA \c�%c, V%••••••.C_ `1^AV�Q. e...::) "v...1C`\ op APPROVED BY /C Approved by: COMMISSIONER THE COMMISSION Date: 3 / 7 mac`` A APR 0 2 2009 Submit is 3.z7 ,� Form 10-403 Revised t6�2 ( (7 ' n' I A 1 BFLe, PIONEER NATURAL RESOURCES March 26, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry, Proposed Plug Back for Side Track of ODSN-36 Due to Lost in Hole BHA Permit to Drill #207-182 Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM X = 469881.69, Y = 6031065.83, ASP4 Pioneer Natural Resources, Alaska (PNRA) is submitting a plug back to side track proposal for AOGCC's review and approval for the ODSN-36 well. Verbal approval was received on Wednesday, March 25, 2009. This is the follow up Form 10-403 Sundry Application as requested. Furthermore, PNRA will submit a Permit to Drill Application due to change of bottom hole location greater than 500 feet (20 ACC 25.015 al). Pioneer originally permitted to suspend ODSN-36 upon installation of the 7" intermediate casing into the top of the Oooguruk-Nuiqsut formation at approximately 10,629' MD / 6,390' TVDrkb. PNRA permitted to re-enter ODSN-36 to drill the horizontal production interval through the Oooguruk-Nuiqsut interval tol 8,731' MD / 6,388' TVDrkb, the final TD of the well in the second quarter of this year, 2009. Unfortunately, the 8 3/4" directional BHA was lost in hole due to a pack off event. It currently is stuck off bottom at 9,706 MD'. The top of fish is at 9,442' MD. PNRA has determined after 11 days of fishing that there is no further value in attempting to retrieve the BHA and has opted to abandon the lower section of the well, plug back, and sidetrack. A nuclear source was not used in the MWD/LWD BHA. As indicated below, the drilling program will entail kicking off a cement plug at 6750' MD and drilling an 8-3/4" directional wellbore set into the Oooguruk-Nuiqsut interval at approximately 10,554' MD / 6,385' TVDrkb. ODSN-36 will be suspended and re-entered in the second quarter of this year 2009 to drill the horizontal production interval through the Oooguruk-Nuiqsut interval to18,629' MD / 6,422' TVDrkb, the final TD of the well. Alaska Oil & Gas Conservation Commission March 26, 2009 Page 2 of 4 Due to the fish stuck being off bottom, it is not possible to execute the placement of a cement plug to address the P&A requirements for the Nuiqsut hydrocarbon reservoir as per 20AAC25.112(a)(1 or 2). However, Pioneer proposes that the highly stressed and unstable Miluveach shales in the openhole section below the fish from 9,657' and to 10,407' and above the top of the Nuiqsut formation at 10,567' and will collapse and effectively seal above the Nuiqsut—qualifying as 20AAC25.112(a)(3). This specific request is focused on abandonment of the 8-3/4" hole interval below the 6,750' kick off point. The forward plan is to RIH, Set cement Kuparuk isolation cement plug, Set kick off plug, Kick off and sidetrack ODSN-36. The proposed plan is as follows: 1. RIH with 5" DP and 1061' of 4" DP stinger to 9440' MD. 2. Circulate and Condition mud. 3. Set Kuparuk isolation plug with 500' of 15.8ppg cement w/ 50% excess. o Pump 17bbl 1st sea water spacer o Pump 55.8bbl of 15.8ppg cement as per HAL, Sacks: 265 Sks, Yield: 1.18 cuft/sk, Water: 5.12 gal/sk o Pump 2.7bbl 2nd sea water spacer o Pump 145.1 bbl of displacement mud o POOH at 30 ft/min to 8431' 4. Circ to clean pipe. 5. POOH to 7650' to pump gel support spacer o Pump 500' gel support spacer 6. POOH to 7150' to pump kick off plug with 500' of 17ppg cement w/ 50% excess. NOTE: Kick off point is © 6750' with TOC © 6650'. o Pump 17bbl 1st sea water spacer 1/47 Ghti)\" o Pump 55 brof 15.8ppg cement as per HAL, Sacks: 310 Sks, Yield: 1.01 cuft/sk, Water: 3.81 gal/sk o Pump 2.7bbl 2nd sea water spacer o Pump 105.5bbl of displacement mud. o POOH at 30 ft/min to 6141'. 7. Circ to clean pipe. 8. POOH to surface 9. Test BOPE 10. RIH with 8-3/4 directional BHA, tag, and dress off kick off plug to 6,750' MD 11. Kick off, and drill 8-3/4" intermediate hole to casing point at —10,554' MD/ 6,385' TVDrkb. 12. Change one set of pipe rams to 7" and test BOPE. 13. Circulate and condition the drilling fluid to run casing. Alaska Oil & Gas Conservation Commission March 26, 2009 Page 3 of 4 14. Run and cement the 7" 26# L-80 BTC-M intermediate casing. 15. Bump plug to 3500psi and hold for 3 min., check floats. 16. RIH with 2000' 2-7/8" 6# L-80 IBT-M freeze protection string. 17. Land tubing and RILDS. 18. Install TWC, N/D BOPE, NU Tree and test, Pull TWC. 19. Circulate diesel freeze protection fluid to freeze protect the well to —2000' TVDrkb 20. Suspend the well. Alaska Oil & Gas Conservation Commission March 26, 2009 Page 4 of 4 Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) Documentation on the current well conditions and justification for suspension. 3) A revised operational shutdown wellbore schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report James Franks, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2179 iames.franks anpxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) (907) 343-2133 douq.waters(a�pxd.com Sincerely, VPPFPw James Franks Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-36 Well File ODSN -36 Draft Kick Off Plan 16"Conductor ' 153'MDrkb/153'TVDrkb 3665'MDrkb/3014'TVDrkb Estimated Top of Cement @ 500'MD w/50%excess 6650'MD allowing 100'dress 17ppg Kick off plug off length to prior to kicking off at 6750'MD 4 500'Hi-Vis Gel Support Pill The highly stressed and unstable Miluveach shales in the openhole section below the fish from 9,657' and to 10,407' and above the top of the Nuiqsut formation at 10,567' and will collapse and effectively seal above the Nuiqsut 500'w/50%excess —qualifying as 15.8ppg Kuparuk isolation 20AAC25.112(a)(3). plug above fish Top of fish @ 9,442'MD Top of Kuparuk @ 9522'MD Bit @ 9706'MD Open Hole TD©10635'MD Page 1 of 3 Maunder, Thomas E (DOA) From: Johnson, Vern [Vern.Johnson©pxd.com] Sent: Monday, March 16, 2009 1:56 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor; Polya, Joe Subject: RE: ODSN-36 Stuck Pipe Event-- Forward Plan Options Tom, As discussed, we continue to try to free our stuck pipe, and will test BOPE soon after either freeing the BHA, or backing off above the BHA, as noted by Joe. As to your question regarding the last time the BHA was last on the bank; we started picking up drilling BHA#4 at 16:30, March 8, in preparation to drill the remaining 825' of intermediate hole from 9810' MD to 10635' MD. It is BHA#4 that is currently stuck in the hole. Let me know if you have any questions. Vern Johnson Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer Direct (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 575-9430 From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Saturday, March 14, 2009 10:12 AM To: Polya, Joe Cc: Johnson, Vern; Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor Subject: RE: ODSN-36 Stuck Pipe Event -- Forward Plan Options Joe, et al, I acknowledge our conversation yesterday and confirm that Commissioner Foerster gave her oral approval of your plan forward. I will look forward to speaking with you on Monday. I do have one question regarding the prior rig operations. You indicated the plan was to hang off to accomplish the BOP test. When was the bit last on the bank? Thanks in advance. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya©pxd.com] Sent: Fri 3/13/2009 6:01 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vern; Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor Subject: ODSN-36 Stuck Pipe Event -- Forward Plan Options Mr. Maunder, Thank you for your return call regarding your conversation with the Commissioner and AOGCC's verbal approval to proceed as discussed. Pioneer will update you Monday regarding the outcome of our fishing and progress regarding salvaging this well bore versus requirements for a sidetrack. I am available at the numbers provided 3/31/2009 Page 1 of 2' Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 31, 2009 10:01 AM To: Maunder, Thomas E (DOA); 'Franks, James' Cc: 'Johnson, Vern'; 'Vaughan, Alex'; 'Campoamor, Kathy' Subject: RE: PTD (207-182)-API #for plugback leg James, et al, I wanted to confirm; The only change in the API #for the plugback portion of this well (ODSN-36PB1) is -00-00 to -07-00. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, March 30, 2009 4:23 PM To: Franks, James Cc: Johnson, Vern; Vaughan, Alex; Campoamor, Kathy Subject: RE: PTD (207-182) -API # for plugback leg James, et al, Yes there is a suffix change. I think it is -70-, but I will have to check at the office tomorrow. Your directional drilling people should know. Tom From: Franks, James [mailto:James.Franks@pxd.com] Sent: Mon 3/30/2009 4:00 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vern; Vaughan, Alex; Campoamor, Kathy Subject: PTD (207-182) - API # for plugback leg Tom, With regards to the plugback leg of the ODSN-36 well we had to abandon due to a fish, do we need to assign a suffix to the API number to identify that penetration? For example, if a well were a multilateral I know we would have-60 for a suffix...I was just wondering if there was something similar here. I don't remember doing anything like this in the past, but thought it would be a good idea to check. Thoughts? Thanks for your time, fames James Franks Pioneer Natural Resources Alaska 907.343.2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission 3/31/2009 Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 31, 2009 9:42 AM To: 'Vaughan, Alex' Cc: Johnson, Vern; Hazzard, Vance Subject: RE: ODSN-36 Distances from PB1 '] _ t D Alex, et al, p' D It would appear that you are correct. The change distance maximum is 500' for an objective formation. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan@pxd.com] Sent: Friday, March 27, 2009 1:00 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vern; Hazzard, Vance Subject: ODSN-36 Distances from PB1 Tom, After further examination of the original wellbore path of ODSN-36 and the new sidetrack wellbore path it would appear that we do not need to Re-Permit ODSN-36. The original hole(bold blue southern line)and new sidetrack(light blue northern line)are 460.23' apart at the Massive sand of the Nuiqsut. PNRA sets the intermediate shoe 3' TVD into this sand. Please see attached excel 3D distance calculation. This point is the greatest difference between the two well paths in the Oooguruk-Nuiqsut production interval. Based, on the preceding and attached information what would you recommend is the path forward in regards to a Re-Permit to Drill Application for ODSN-36? 3/31/2009 H .r M N co y O E O I- w r N N N CNi Cf) > CO CO CO CO CO IN- O } C) co co CO N N 0 0 CO CO •ch N r--: X N rn Cfl Cfl 7). 0 Z CL CD 0 M Z To .c O r2) O co ?� Z Cn m a CLO south(-)/North(+)(500 Win) r{, 00 AA W 0AN 0O 0 N 00 C O O . p 8 O O 8 8 00 O ppO O O O S Z4!) : iiiil m iIiiiiIiiiiIiiiiIi iiI iiiIiiii11iii1i � � � 1iii1 ii I . 11111111 mei M �,. j b / - / Q a o -r " - /�` 8 - z Q - / / \ z b v / s0hn- vCD/ N / o O Ao— / 8 - 7 A,\// // \ �xJ a g b ci"Q�a x•x• 2 C / ri d \ Zb a 1 yy o / _ _`- / a 'off. _\ S c �' gi A Iq 00 T 1 \6 O Qo - - \ Q g8 O 1 d\ ly N _ I \ a. q _ w \ t, f1 - c \ : Q oz $— Z $ \N y e A. d 5 ¢ Q 'E dh7 oG�G \I cr,2c4 o. c °\ IP, 4^ P Q v N A g 54 g,^`4' �! Opp O A— \ j $4 N—OO G.,iC',S. O. ry Na. e - \ w o v 0 W 63 0 X,CMr H MI tg o v ANO co �q11 �<y gCI 0 \ 0 4 Aw Z rd J Q y v N N �pO ,? d tri ONN C — U N o _ o CG $N 2 �7" z - 00 zfr"' o o A _ A m 8 d 8 r. P N_ - S'SS0 8 0 4 - c _ F' .0— _ O '' O - o A 0 p V $ $ oi�83 03 C 0 m L z off` gm a S 2aan o- 2 a , 000 w '=_ z !Pal000g o �za " $ Zooms g A nn n n _ N N V J JA 8— - 7:F2 3 a 8 i++0 O — Po d b < j C in N Z i.j prnrnN _8 O NND O - 6 O $ 6�1 (n Z Z 8 8.in DD 0 P AA (pp2 $ — p 3c nnm yy o0 2 C i Page 1 of I Maunder, Thomas E (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Wednesday, March 25, 2009 9:15 AM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Vaughan, Alex; Franks, James; OoogurukDrillingSupervisor; Polya, Joe Subject: ODSN-36 Stuck Pipe Event-- Forward Plan Options Tom, As follow up to our discussion this morning, we were unsuccessful in engaging the fish, and we don't think there is any value in making further attempts. The plan forward is to abandon the lower section of the well and sidetrack to a new BHL. We will provide a 10-403 for the abandonment, please let me know if our discussion is considered verbal approval. We will also provide a new permit to drill application for the new well below the kickoff point. With respect to naming; our plan is to call the abandoned wellbore ODSN-36 PB1, and call the 'new' wellbore that we plan to drill ODSN-36, with a new permit. The new well will land more than 500' from the previous landing point in the Nuiqsut sand, the final well targets at TD are within 500' ft of the original permit. See the plan forward below. 1. POOH with fishing BHA 2. Change rams and test 3. RIH with 5" DP w/ 1000" of 4" DP stinger to 9440' (maximum) 4. Set Kuparuk isolation plug o 500' of 15.8ppg cement w/ 50% excess o Balance sea water isolation spacer o Nerf ball in front of cement o POOH @ 30 ft/min o 500'Above top of cement circ to clean pipe, pump Nerf ball 5. POOH to approximately 7450' to pump gel support spacer o 500' gel support spacer 6. POOH to 6950' to pump kick off plug o Kick off point is @ 6750' with TOC @ 6450' o 500' of 17ppg cement w/50% excess, o Balance sea water isolation spacer o Nerf ball in front of cement o POOH @ 30 ft/min o 500'Above top of cement circ to clean pipe, pump Nerf ball 7. POOH to surface 8. TEST BOPE Please call or email if you have any questions. Vern Johnson Sr. Staff Drilling Engineer 343-2111 off 575-9430 cell 3/31/2009 Page 1 of 3 Maunder, Thomas E (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Monday, March 16, 2009 1:56 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor; Polya, Joe Subject: RE: ODSN-36 Stuck Pipe Event-- Forward Plan Options Tom, As discussed, we continue to try to free our stuck pipe, and will test BOPE soon after either freeing the BHA, or backing off above the BHA, as noted by Joe. As to your question regarding the last time the BHA was last on the bank; we started picking up drilling BHA#4 at 16:30, March 8, in preparation to drill the remaining 825' of intermediate hole from 9810' MD to 10635' MD. It is BHA#4 that is currently stuck in the hole. Let me know if you have any questions. Vern Johnson Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer Direct (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 575-9430 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 14, 2009 10:12 AM To: Polya, Joe Cc: Johnson, Vern; Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor Subject: RE: ODSN-36 Stuck Pipe Event -- Forward Plan Options Joe, et al, I acknowledge our conversation yesterday and confirm that Commissioner Foerster gave her oral approval of your plan forward. I will look forward to speaking with you on Monday. I do have one question regarding the prior rig operations. You indicated the plan was to hang off to accomplish the BOP test. When was the bit last on the bank? Thanks in advance. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Fri 3/13/2009 6:01 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vern; Hazzard, Vance; Vaughan, Alex; Franks, James; Cody, Rick; OoogurukDrillingSupervisor Subject: ODSN-36 Stuck Pipe Event -- Forward Plan Options Mr. Maunder, Thank you for your return call regarding your conversation with the Commissioner and AOGCC's verbal approval to proceed as discussed. Pioneer will update you Monday regarding the outcome of our fishing and progress regarding salvaging this well bore versus requirements for a sidetrack. I am available at the numbers provided 3/31/2009 Page 2 of 3 should you require additional information prior to Monday. Follow up to our discussion this afternoon, • Pioneer is currently in the drilling phase for the intermediate hole section for the ODSN-36 well. The rig reached TD for the intermediate hole @ 02:30 hours on 3/12/09 at 10635' and (Nuiqsut Formation Top @ 10,567' md)with a 10.7 MW while exerting a 12.5 ppg EMW with the Managed Pressure Drilling equipment. The rig circulated the hole clean and initiated a wiper trip to the 9-5/8"casing shoe @3665' md. The plan was to hang the drill string off on an RTTS and then Test BOP prior to midnite to meet our 14 day test date requirement of 3/12/2009. AOGCC representative Lou Grimaldi was on location to witness test— Mr. Grimaldi has since left location. • Unfortunately, the rig experienced tight hole and pack offs while back reaming to the last bit trip at 9800' md. The drill pipe packed off @ 9706' and and has not been able to move the pipe or establish circulation since this event occurred. The jars are able to fire up; unfortunately, we cannot fire the jars down which is the preferred pipe movement after sticking pipe while POOH. • Pioneer is currently working the pipe while the fishing equipment and personnel arrive on location—the slope is recovering from a Phase 3 Snow Blow condition. Forward plan if unable to work the pipe free is to perform a free point and back off and POOH for a fishing BHA. While out of hole to pick up the fishing BHA, the rig will perform the BOPE test. Assuming the Fishing is successful, Pioneer will clean up the hole and run 7"casing to TD. In the event Pioneer is not successful freeing the BHA, then the forward plan is as we discussed: • Spot a 500' cement plug top of the fish above the fish. o 70° inclination wellbore will collapse and provide isolation between Kuparuk and Miluveach formations. o Cement Abandonment Plug will Isolate the Kuparuk Sands from the Torok Sands. • POOH to -6725 feet and and spot a balanced cement sidetrack plug. o Original wellbore experienced 100-200 bbls losses while drilling the Kuparuk formation. o Planned sidetrack will intersect the Kuparuk 700'from original wellbore in an attempt to minimize losses. • The new well bore will intersect a fault in the shale instead of the sand. This will not guarantee no losses but should reduce the risk and minimize the loss rate. • The proposed sidetrack well will intersect the Nuiqsut formation greater than 500'from the original Nuiqsut intercept and will require a re-permit application. o In the event the sidetrack is necessary, Alex Vaughan will submit the Re-Permit early next week. ODSN-36 Well Information for Potential Abandonment and Sidetrack Depth (ft- Lithology md) Wellbore Information 3665 9-5/8" Casing Shoe Hue Shale (Colville) 3550 Top 17.0 ppg Cement Sidetrack 6000 Plug (Dressed) 3/31/2009 Page 3 of 3 6725 Base Cement Sidetrack Plug Torok Sand Top 6901 Torok Shale Top 7334 HRZ Top 8659 Kalubik Shale Top 9060 Top of 500 feet 15.8 ppg Cement 9008 Abandonment Plug 9508 Est Top of Fish if backoff @ circ sub Kuparak C Sand 9522 Miluveach Shale Top 9658 9706 Bit Nuiqsut Top 10567 TD 10635 Thank you for you time and consideration in this matter. Please contact me should you require any additional information from Pioneer. 744V/44, Pce Pam Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya pxd.com Main Office: (907) 277-2700 Direct: (907) 343-2173 New Number Fax: (907) 343-2192 Mobile: (907) 244-0668 If unable to contact me, Call Vern Johnson Pioneer Sr. Staff Drilling Engineer 907-575-9430 Mobile 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. 3/31/2009 L. AL- r rs• L1 . Y \ J SARAH PAL1N, GOVERNOR ALASKALI U E OIL AND GAS 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, ODSN-36 Pioneer Natural Resources Alaska Inc. Permit No: 207-182 (re-issue) Surface Location: 2951' FSL, 1117' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 1202' FSL, 4134' FEL, SEC. 3, T13N, R7E, UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced development well. This approval supersedes the original approval dated January 11, 2008. This permit is re-issued to account for several changes in the plans for this well. These include changing the objective formation from the Kuparuk to the Nuiqsut and significantly lengthening the well. The well name has also been changed to ODSN-36 to conform to the naming convention at Oooguruk. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Daniel T. Seamount, Jr. Chairman DATED this / / day of February, 2009 cc: Department of Fish & Game, Habitat Section w/o end. Department of Environmental Conservation w/o encl. _ RECEIVED STATE OF ALASKA ALAS ,OIL AND GAS CONSERVATION COMM., ,ION FEB 0 6 2009 PERMIT TO DRILL ha( to Alaska Oil&Gas Cons. Commission 20 AAC 25.005 la.Type of Work: 1b.Current Well Class: Exploratory ❑ Development Oil Q 1c.Specify if well is proposed for: Anchorage Drill Q Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re-entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 - ODSN-36 • 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 700 G Street,Suite 600 Anchorage,AK 99501 MD: 18,731' • TVD: 6,388'. 4a. Location of Well(Governmental Section): 7. Property Designation: Oooguruk Nuiqsut Oil Pool • Surface: 2951'FSL, 1117'FEL,Sec. 11,T13N, R7E, UM ' ADL 355036 . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 518'FSL,4049'FEL,Sec. 11,T13N, R7E,UM 417497 2/22/2009 Total Depth: 9.Acres in Property: 14.Distance to Nearest 1202'FSL,4134'FEL,Sec.3,T13N,R7E,UM • 5760 Property: 1145' 4b.Location of Well(State Base Plane Coordinates): 10. KB Elevation 15.Distance to Nearest Well Surface: x-469881.69 • y-6031065.83 ' Zone-ASP 4 (Height above GL): 44.0' feet Within Pool:ODSN-40 is 2946'away 10999' 16.Deviated wells:N/A Kickoff depth: 300 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98.96 degrees Downhole: 3197 psig • Surface: 2507 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) 8-3/4" 7" 26# L-80 BTC-M 10585' Surface Surface 10629'- 6390' . sx 12.5ppg Class'G'Lead sx 15.8ppg Class'G'Tail 6-1/8" 4-1/2" 12.6# L-80 Hydril 521 8252' 10479' 6351' 18731' . 6388' Uncemented slotted liner - 10(ac.x VitoZ Ic14 SrtA 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) a11,13 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 114' 16" Welded 158' 158' Surface 3622' 9-5/8" 438 sx Permafrost'L;201 sx Class'G' 3666' 3015' Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Filing Fee ❑ BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑✓ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements ❑ 1 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughn,343-2186 Prepared By:Kathy Campoamor,343-2183 Printed Name Joe Polya Title Sr.Drilling Engineer Signature '5\4 '.--S)'''-1C-4- l '''-t(r Phone 343-2111 Date 2/3/2009 Commission Use Only Permit to Drill O API Number: / Permit Approval ��1 See cover letter for Number: ,„,.„,7 7 /CS Z 50- 70 3-2.nSC,(^ Date: a.....44-4361-1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:[ Other: ?500 vs\ \-�s\-- Samples req'd: Yes❑ Noll Mud log req'd: Yes NoR' a QQ p QS`k .\ c-�G�t..A3�r\-ES HZS measures: Yes No0' Directional svy req'd: Yes[' No❑ S•3 )' '-\Z \ ig--.QT. i¢A-3o AAc as.o'l a t.ticoc-oS ) . X03 :,/l" nca Elcc-01-ro‘‘tt no It- C\ct,,\-:c:z.r\ vJhQr`c'cr.Svv--k-c,\----‘1=)t\dC- cIR,Q N:cts-S-Nc, VGhhQD dII/ -� APPROVED BY THE COMMISSION / // DAT . �,, ,_ _ ,COMMISSIONER !!! / .gi Form 10-401 Revised 12/2005 Submit irdEplikt.7.44 PIONEER NATURAL RESOURCES ALASKA F-4-i9 Aregka U/7 I) 1009 017 Anch01 Ccliror n February 6, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-36 Previous Permit#207-182 Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM X = 469881.69, Y = 6031065.83, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill, form 10-401, 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-Nuiqsut formation. PNRA requests the Permit to Drill based on approved Pool Rules. ODSK-36i was originally granted approval on January 11th, 2008, Permit No: 207-182. Pioneer Natural Resources is applying to Re-Permit hereby named ODSN-36 due to change of bottom hole location greater than 500 feet (20 ACC 25.015 a1 1. This well was originally permitted as a Kuparuk injector (ODSK-36i) and has been reclassified as a Nuiqsut producer (ODSN-36). Slot 36 (ODSK-36i) original target, Kuparuk D Section was moved to slot 38 (ODSK-38i) to reduce the directional wellbore profile collision risk with surrounding wells. As indicated in the attachments, the drilling program will entail drilling through the previously set surface casing at 3,666' MD / 3,015' TVDrkb an 8 3/4" directional wellbore set into the Oooguruk-Nuiqsut formation at approximately 10,629' MD / 6,390' TVDrkb. ODSN-36 will be suspended upon completion of the intermediate section. The horizontal interval will be drilled in the third quarter of this year 2009. The lateral drilling program will entail drilling a 6-1/8" production hole through the preset intermediate casing at approximately 10,629' MD /6,390' TVDrkb. The horizontal production interval will be drilled through the Oooguruk- Nuiqsut interval to18,731' MD / 6,388' TVDrkb, the final TD of the well 700 G STREET,SUITE 600 - ANCHORAGE,ALASKA 99501 - MAIN 907-277-2700 - FAX 907-343-2190 Alaska Oil & Gas Conservation Commission February 3, 2008 Page 2 of 4 The proposed casing program will utilize 9-Va" surface casing, 7" intermediate casing and 4-W slotted liner production casing. The completion will utilize 2-7/8" tubing with an ESP. PNRA plans to implement Managed Pressure Drilling technology (MPD) while drilling the intermediate and production hole of ODSN-36. At present, PNRA intends to drill with an equivalent mud weight equal to or greater than the pore pressure of the exposed formations. PNRA plans to use this technique while drilling the intermediate interval as outlined below. • From the Surface Shoe to below the Base of the Torok Sands o Use -9.2 to 10 ppg fluid while using MPD to control pressure from the surface to - 11.5-12.5 ppg EMW at the bottom of the hole. ■ Open formations: • Torok Sands, -8.7ppg Pore Pressure • From the base of the Torok Sands to Intermediate Hole TD o Use -10.2 to 11.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure PNRA plans to use this technique while drilling the production interval as outlined below. • From the Intermediate Shoe to TD o Use -7.0 to 8.7 ppg fluid while using MPD to control pressure from the surface to -9.8 to10.2 ppg EMW at the bottom of the hole during connections and while tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. Alaska Oil & Gas Conservation Commission February 3, 2008 Page 3 of 4 Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path — including traveling cylinder and development layout plots 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19-AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. 7) MPD information as referred to above • Flowchart of the MPD system • Decision Tree for handling a well control event Alaska Oil & Gas Conservation Commission February 3, 2008 Page 4 of 4 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.polyapxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) 907/343-2133 douq.waters(a�pxd.com The anticipated spud date for this well is February 22, 2009. If you have any questions or require further information, please contact Alex Vaughan at 907-343-2186. Sincerely, C� Joe Polya Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-36 Well File Page 1 of 3 Maunder, Thomas E (DOA) From: Vaughan, Alex [Alex Vaughan@pxd corn] Sent: Tuesday, February 10, 2009 9:13 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe Subject: ODSN-36 Re-Permit BOPE pressure test Tom, The following comment on page 1 of 9 is a typo (see below). The BOPE with be tested to 3500 psi as stated in steps 2 &17 of page 6 of 9 (see below), Page 1 of 9: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1323 psi @ 2958' TVDss (Based on seawater gradient of O4472 psi/ft) • Maximum surface pressure: 997 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Intermediate Section: • Maximum anticipated BHP: 3197 psi 0 6274' TVDss • Maximum surface pressure: 2507 psi * surface (Based on BHP and a full column of gas from TD 0 011 psiift) Production Hole Section: • Maximum anticipated BHP: 3197 psi 0 6274' TVDss • Maximum surface pressure: 2507 psi 0 surface (Based on BHP and a full column of gas from TD 0 0.11 psi/ft) Planned BOP lest pressure: 4500 psi (annular to 2500 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Page 6 of 9: 2/10/2009 Page 2 of 3 2. Inskil TWC, ND Tree, NU BOPE, Remove TWC, & Test BOPE to 2501 500 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 la air 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 I into the 9-5/8" casing and perform LOT. 7. Drill 8-3/4" intermediate hole to casing point at -10,629' MD/ 6,390' TVDrkb: Circulate ant condition the drilling fluid to run casing. 8. Run and cement the 7", 26# intermediate casing. 9. Bump plug to 3500psi and hold for 3 min., check floats. 10. RIM with enough 3-1/2" or 2-7/8'tubing to allow for the circulation of diesel freeze protectik to --2000' TVDrkb. 11. Land the tubing and RlIDS. Install TWO. 12. NU Tree and test. 13. Pull TWC. Circulate diesel freeze protection fluidic freeze protect the well to -2000' TVDr 14. Suspend the well. lig Activity';- Drill and Complete Remaining Well 15. MIRtI Nab rs19AC over pre-installed 7" intermediate casing. 16. RU circulation lines and circulate out the diesel freeze protection fluid arid ensure the well dead. �. 17. Install TWO, ND Tree, NU BOPE, Remove TWC, & Test BOPElo 250/3500 psi. 18. Pull circulation tubing string from the well. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 10, 2009 8:48 AM To: Vaughan, Alex Cc: Polya, Joe Subject: RE: ODSN-36 (207-182) -- AGAIN Alex and Joe, There are conflicting statements in your application regarding the BOP ram test pressure. On page 1 of 9 the ram test pressure is stated to be 4500 psi. On page 6 of 9 (the procedural steps), 3500 psi is stated in step 2 and step 17. Would you please reconcile the ram test pressures. Thanks in advance, Tom Maunder, PE AOGCC 2/10/2009 Page 3 of 3 From: Maunder, Thomas E (DOA) Sent: Tuesday, February 10, 2009 8:25 AM To: Vaughan, Alex Cc: Polya, Joe Subject: ODSN-36 (207-182) Alex and Joe, I am reviewing the revised application to drill ODSN-36 rather than ODSK-36. Would you check the 7" tail cement calculation? In the cementing section following page 9 of 9, it is stated that the tail yield is 1.17 however I calculate 21.7 bbls of slurry using 94 sx and that yield. Thanks in advance. 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. 2/10/2009 Oooguruk Well Plan Summary: Permit to Drill ODSN-36— Nuiqsut Production Well Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X=469881.69 Y= 6031065.83 Target: 517.8' FSL, 4048.8' FEL, Sec 11, T13N, R7E, UM X=466,941.87 Y= 6,028,646.06 10,629' MD/6,390' TVDrkb Bottom Hole Location: 1202.5' FSL, 4134.1' FEL, Sec 3, T13N, R7E, UM X=461,596.18 Y= 6,034,636.02 18,731' MD/6,388' TVDrkb AFE Number: 014220 Est. Start Date: February 22, 2009 Rig: Nabors 19AC Operating days: 14 days Drill Intermediate, Suspend Production lateral completed at later date TD: 18,731 MD/6,388 TVDrkb Objective: Nuiqsut • 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: 44' Rig Elevation: RKB + MSL= 57.5' • Conductor: 158' MDrkb Well Control: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1323 psi @ 2958' TVDss (Based on seawater gradient of 0.4472 psi/ft) • Maximum surface pressure: 997 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Intermediate Section: • Maximum anticipated BHP: 3197 psi @ 6274' TVDss • Maximum surface pressure: 2507 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Production Hole Section: • Maximum anticipated BHP: 3197 psi @ 6274' TVDss • Maximum surface pressure: 2507 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Planned BOP test pressure: 4500 psi (annular to 2500 psi) a. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel r 0 Pioneer Natural Resources February 2,2009 ODSN-36 Permit to Drill Page 1 of 9 Diverter(see attached schematic): Hydril 21-1/4"2M annular BOP One 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 12.0 ppg Drilling Fluids Program: Viscosity Interval Density(ppg) (secs) YP PV MBT API FL Surface Shoe to 9.2-10.0 (-10.5 ppg 40 - 60 15 -25 15-20 < 12 6 - 8 Below 2nd Fault w/MPD) . _ From Below 2"d 10.5 (-12.5 ppg w/ 40-60 15 -25 20 - 30 < 15 3-5 Fault to MPD) (8-10 HTHP) Intermediate Shoe Lateral 7.0-8.7ppg w/MPD . 40-60 10-20 10-20 < 15 3-5 (8-10 HTHP) 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 February 2,2009 ODSN-36 Permit to Drill Page 2 of 9 n Hydraulics: Intermediate Hole: 8-3/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in2) GPM (fpm) PSI emw ("/32) Surf Shoe to TD 550 4" 15.7# 215 3500 10.5-12.5 N/A 5x16 0.982 Production Hole: 6-1/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in2) GPM (fpm) PSI emw ("/32) Int Shoe to TD 275 4" 15.7# 275 2800 9.8+ N/A 3x14 0.451 Formation Markers: MD TVD Pore Press. EMW Formation Tops (rkb) (rkb) (psi) (ppg) Comments Base of Permafrost 1608 Top West Sak 2709 2346 8.7 Base of fluvial sands Violet 1 fault 3354 2733 Tuffaceous Shales 3503 2837 Prognosed Brook 2B 5619 4217 TopTorok Sand 6903 5022 _ 8.7 Top of Disposal Zone Base Torok Sand 7353 5264 Base of Disposal Zone Top H RZ 8614 5721 Base HRZ 8986 5848 Kalubik Mkr 9229 5931 Kup C 9447 6004 3059 9.8 LCU 9583 6048 BCU 10486 6295 Nuiqsut 10629 6390 3226 9.8 Top of Production Zone TD 18731 6388 Pioneer Natural Resources February 2, 2009 ODSN-36 Permit to Drill Page 3 of 9 Logging Program: 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/ Dens (Azm)/Neut/Sonic (for CBL only) Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing Weight Grade Conn. Casing Casing Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 24" 16" 109# H-40 Welded 114 Surface 158 158 12-1/4" 9-5/8" 40# L-80 BTC 3622 Surface 3666 3015 8-3/4" 7" 26# L-80 BTC-M 10585 Surface 10629 6390 6-1/8" 4-1/2" 12.6# L-80 TBA 8252 10479 18731 6388 Tubing 3-1/2" 9.3# L-80 TSHP 10356 Surface 10400 6331 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" TBA n/a n/a 289 M 289 M Pioneer Natural Resources February 2, 2009 ODSN-36 Permit to Drill Page 4 of 9 Cement •Iculations: Casing Size. 7" Intermediate Casing -single stage** Basis: Lea.. •33' of open hole with 30% excess Lead T‘ - 8,947' (500' above Kuparuk) Tail: 750' • open hole with 30%excess, plus 85' shoe track Tail TOC: -1. 125' MD Total Cement Volume: Preflush 10 bbl water Spacer 55 bbl 12.5 ppg Dual Spacer \(.\k- c> .-ad 41 bbl -94 sx. Premium Cement+ 15 #/sk MicroLite, + 0.75% Halad-344 + .2% CFR-3, + 0.15% EZ Flow+ 0.25% SCR-100 or as required �i<�`�'�� ��� Tail 17.5 bbl- 104 sx. Premium Cement+0.5% Halad-344+ 2% CFR-3, + 0.25 LB/SK. Super CBL+ 0.5% SCR-100 or a required _ \ Displacement 403 '.Is. seawater ` ,5cs.�� ) ‘C-k5 Temp BHST 145° F/ BHCT -125° F 10 *This well is outside 1/2 mile of the disposal well a e well path intersection with the disposal zone and will not need the calculated top of the cem t to be 500' MD above the top of the disposal interval. ` ecce�- Pioneer Natural Resources February 2,2009 ODSN-36 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. 9 5/8" Surface casing has been set and cemented at 3,666' MD/3,015' TVD Rig Activity: Drilling Intermediate and Suspend Well 1. MIRU Nabors 19AC over pre-installed 9 5/8" surface casing. 1. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC, ND Tree, NU BOPE, Remove TWC, &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 10,629' MD/6,390' TVDrkb. Circulate and condition the drilling fluid to run casing. 8. Run and cement the 7", 26# intermediate casing. 9. Bump plug to 3500psi and hold for 3 min., check floats. 10. RIH with enough 3-1/2" or 2-7/8"tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. 11. Land the tubing and RILDS. Install TWC. 12. NU Tree and test. 13. Pull TWC. Circulate diesel freeze protection fluid to freeze protect the well to -2000'TVDrkb 14. Suspend the well. Riq Activity: Drill and Complete Remaining Well 15. MIRU Naborsl9AC over pre-installed 7" intermediate casing. 16. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 17. Install TWC, ND Tree, NU BOPE, Remove TWC, &Test BOPE to 250/3500 psi. 18. Pull circulation tubing string from the well. 19. MU 6-1/8" directional drilling, MWD/LWD assembly with BAT Sonic (for cement bond log). RIH • and cleanout to landing collar. 20. Test the 7" casing to 3,500 psi for 30 min. 21. 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. 22. Displace the well over to production hole drilling fluid. 23. Perform a bond log over the 7" cement interval with the BAT sonic tool prior to drilling ahead. 24. Drill the 6-1/8" production hole to TD at -18,731' MD/6,388'TVDrkb. 25. Circulate and condition the hole to run liner. POH. Pioneer Natural Resources February 2, 2009 ODSN-36 Permit to Drill Page 6 of 9 26. Run 4-1/2" liner on 4" DP. 27. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine. POH. 28. RIH with 4-1/2"tubing. 29. Perform fracture stimulation. 30. Flowback well for clean up. 31. POH with 4-1/2"tubing. 32. MU ESP completion and RIH. 33. Land the tubing and RILDS. Install TWC. 34. ND BOPE, NU tree and test to 5,000 psi. • 35. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u-tube. 36. 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. 37. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 38. RD Slickline. RDMO to next well. Pioneer Natural Resources February 2,2009 ODSN-36 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 Operations Drilling Engineer for distribution as required. Pioneer Natural Resources February 2,2009 ODSN-36 Permit to Drill Page 8 of 9 ODSN-43 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened • awareness and kick detect ion. 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.To date, no increase in pressure has been seen. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling with MOBM in the abandoned wellbore of ODSN-40. The losses continued after swapping the production hole drilling fluid over to SWBM. At this time, assume that the fault drilled in the production hole will have lost circulation issues and follow the Decision Tree as required. • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK-33 and ODSN-45. During the sidetrack of ODSK-33, this zone was not problematic. In any case, close attention while drilling this interval is advised. Kick Tolerance/Integrity Testing Kick Tolerance/Integrity Testing Summary Table Casing set/Interval Maximum Influx Mud Exp Pore Min LOT/FIT Volume Weight Press 9-5/8 Surface/7"Intermediate 49.7 10.5 3256 12.0 ppg (LOT) 7"Intermediate/6-1/8" hole Infinite 7 3255 12.0 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 H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Faults • A seismically visible fault is expected to be crossed and sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Fault Location MD TVDrkb Throw Direction Uncertainty Production Hole 3,985' 3,904' -.25' Down to the East +1- 300' MD Intermediate Hole 10,359' 6,320' -25' Down to the East +1- 300' MD CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources February 2,2009 ODSN-36 Permit to Drill Page 9 of 9 Page 1 of/ L Maunder, Thomas E (DOA) From: Vaughan, Alex[AIex.Vaughan@pxd.com] Sent: Tuesday, February 10, 2009 11:02 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe Subject: ODSN-36 (207-182) Cement Volumes Attachments: ODSN-36 Cementing Program.pdf; ODSN-36 Re-Permit Program for target move.pdf Tom, You are correct. The tail slurry volume was calculated incorrectly. Furthermore, it appears we miss-stated lead cement volumes due to increasing excess cement volume in this section from 30%to 60 % to insure coverage 500' above the Kuparuk. Please review the following corrected casing program. You will also find the corrected documents attached. 2/10/2009 Pioneer Natural Resources Alaska Cementing Services ODSN-36 ODSN-36 Intermediate Casing Well Conditions Casing Size&Wt. 7"26#/ft L-80 BTC Volume Excess Lead 30%,Tail 60% Hole Size 8 3/4" Mud Wt. 11.5 ppg MD 10,629' Mud PV/yP 17/22 TVD 6,390' BHST 145°F Prey.Csg: 9-5/8"40#/ft L-80 BTC BHCT 125°F Frac Gradient: 13.8 ppg @ 6,390'TVD Slurry Recommendation(mixed with seawater): Preflush/Spacer 10 bbl Water,50 bbl 12.5 ppg Dual Spacer Lead Slurry: 50.5 bbl—116 sks. Premium Cement+ 15#/sk MicroLite,+0.75%Halad-344+.2% CFR-3,+0.15%EZ Flow+0.25%SCR-100 or as required Tail Slurry: 22.0 bbl—106 sks. Premium Cement+0.5%Halad-344+.2%CFR-3,+0.25 LB/SK. Super CBL+0.5%SCR-100 or as required Displacement: 403 bbls. Mud Spacer Lead Slurry Tail Slurry Density(ppg) 8.34 / 12.5 12.5 15.8 Yield(cu ft/sk) 2.44 1.17 Sea Water requirements(gal/sk) 13.74 5.05 Thickening Time Hr:min. 3:00+ 3:00—4:00 Compressive Strength-PSI 12 hr(est.) 360 1,200 24 hr(est.) 500 1,800 Volumes based on: The desired TOC is 500' above the KUP C. Lead Slurry: Top of Lead cement—8,947' MD 1178' calculated annulus volume+60%excess. Tail Slurry: Top of Tail slurry—10,125'MD 514'calculated annulus volume+30%excess+85' shoe joint. HALLIBURTON 1 Pioneer Natural Resources Alaska Cementing Services ODS N-36 ODSN-36 termediate Casing Well Conditions Casing Size&Wt. "26#/ft L-80 BTC Volume Excess 30% Hole Size 8 " Mud Wt. 11.5 ppg MD 6,391' Mud PV/yP 17/22 TVD 10,629 BHST 145°F Prey. Csg: 9-5/8"41 ft L-80 BTC BHCT 125°F Frac Gradient: 13.8 ppg • .,390'TVD SUPERSEDED Slurr Recommendation mixed with sea •ter : Preflush/Spacer 10 bbl Water, 50 bbl .5 ppg Dual Spacer Lead Slurry: 41.5 bbl—94 sks. Pre m Cement+ 15#/sk MicroLite,+0.75%Halad-344+.2% CFR-3,+0.15%EZ Flow 0.25%SCR-100 or as required Tail Slurry: 17.5 bbl—104 sks. Premiu Cement+0.5%Halad-344+.2%CFR-3,+0.25 LB/SK. Super CBL+0.5%SCR-100 or •s required Displacement: 403 bbls. Mud Spacer Le. • Slurr Tail Slurry Density(ppg) 8.34 /12.5 1 . 15.8 Yield(cu ft/sk) 2.44 1.17 Sea Water requirements(gal/sk) 13.74 5.05 Thickening Time Hr: min. 3:00+ 3:00—4:00 Compressive Strength-PSI 12 hr(est.) 360 1,200 24 hr(est.) 500 ,800 Volumes based on: The desired TOC is 500' above the KUP C. Lead Slurry: Top of Lead cement—8,946'MD 933' calculated annulus volume+30%excess. Tail Slurry: Top of Tail slurry— 10,125'MD 500'calculated annulus volume+30%excess+85' shoe joint. HALLI BURTON 1 Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSN-36 - Slot ODS-36 ODSN-36 PN10 Plan: ODSN-36 PN10 wp12 Standard Proposal Report 30 January, 2009 rtiALLIBURTON Sperry Drilling Services • .i....i.... ... . v vwoioo 3 a oino3 o+ OZ oIm�? y �_ m v M 16' 001111111.111......._� O O A W,� N GP . C 2-___F- 2 70 #‘01100011111111...._�` OJOCO VO 'v2.,, NOT m WIWI� Q v 0 C N Oo IAD33 T aC ' ` O O Z 3 m m m m A o ::m iDmm i O. b v .5. y CN ANN m ` o0,o o -s www- c to wl0 O a N - ` C .roup2 o C II; ' ! ' s EgCpg O A^.. m t cet 90 r - o p _ co as A r W ‘k AIM i i T-?P Iti iiir Al ili�' 111, I i . g 11* _ _ , _ N0 444411.- :0.- 4. •*1I O. g)En, m c 7 mmp d C O — O f3D A'"N A O 5. N S C01 S'"S n a m a 3 a ° . . W V W . A W N + O O OW -4 . . 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This is backed up with the Sperry Sun Mud Logging gas detection system. ✓ Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 11 2/10/2009 True Vertical Depth(1500 ft/in) m 17 V Cr) C) 01 A A w W N -+ N' 0) O A Co N O O A Co N 6) Q'S O o 0 0 0 op-, o 0 0 0 0 0 0 0 o O yam' IIIIiiiiIiijiIiio Iiiiiii8 IIiiiiiiiiiiiiiIIIIIIIiiiiIiiiiIiiiiIiiiiIIii •• m 0 o W•\ y0�00 0 �Z • - o' C0 0 O O m m ,. G ZZZ� jA w o _ 2- 1 a 0 a " II o)a)coC C o m \ \ \ ,p _ O - \ \ \a ss° to °\ Oy y(D Ei \ \ \ m a 1 0' 0O o - m c \ \ \ w -4 \, O. , 0 w v \\ \\ \ m m ` w V' WI. - g •- n\ \ \ ?0^ a 0'. 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F.)iNIVO.)+OI+iD000 rn A - 0 TT 13 0 -O 0 0 0 0 0 -0 - )7i vl N FA Z Z Z Z Z Z Z Z Z O 0 0 0 0 0 0 0 0 fo�D nn2 8 - NN f. < < < < < < < < `0 N N N N N CV N N N i - CO CO V 0 0 A W N + D Produc an Well Proposed Col_ dletion Well Head: 9-5/8",5K,VetcoGray Tree: 2-7/8",5K, Horizontal Vent Valves Control Line 16"Conductor 158'MDrkb/158'TVDrkb ScSSSV @-750' GLM-3330'TVD X Nipple,2.313"ID 9-5/8",40#L-80 BTC,8.835"ID A4- 3,666'MDrkb/3,015'TVDrkb ■ 2-7/8",6.5#L-80 IBT-M 7"x 2-7/8"Packer-4,690 MDrkb/3,750'TVDrkb GLM-5510'TVD Estimated Top of Cement @ 9629' MD/-6120'TVDrkb ESP Cable 000 Sliding Sleeve or ADV I ■ ESP-10,400'MDrkb -10,629'MDrkb/6,390'TVDss 4'/2'Lined Completion 7",26#L-80 BTC-M,6.276"ID O O O OO O 00 00 00 00 ' O O O O O 00 00 00 00 , -18,731'MDrkb/6,388'TVDrkb Date: Revision By: Comments Pt O N E E R 2/2/2009 Alex Vaughan Proposed Completion ODSN-36 wp12 NA1URARRESOURCESAIASKA Producer Well Schematic Sperry Drilling Services HALLIBURTDN Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) . Project: Oooguruk Developement MD Reference: 44.54'+ 13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Project Oooguruk Developement Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70°29'46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14'45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSN-36-Slot ODS-36 Well Position +N/-S 0.0 ft Northing: 6,031,065.83 ft . Latitude: 70°29'45.399 N +EI-W 0.0 ft Easting: 469,881.69 ft . Longitude: 150° 14'46.595 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft • Wellbore ODSN-36 PN10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IG RF200510 1/8/2007 23.31 80.81 57,637 Design ODSN-36 PN10 wp12 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,634.0 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 44.5 0.0 0.0 293.08 1/30/2009 10:39:35AM Page 2 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (?) (bearin (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 3,634.0 42.77 162.93 2,991.2 2,933.2 -1,425.4 795.3 0.00 0.00 0.00 0.00 3,683.0 42.77 162.93 3,027.1 2,969.1 -1,457.2 805.1 0.00 0.00 0.00 0.00 4,232.0 51.00 162.93 3,402.0 3,344.0 -1,840.0 922.6 1.50 1.50 0.00 0.00 5,232.0 51.00 182.23 4,031.2 3,973.2 -2,607.0 1,022.5 1.50 0.00 1.93 90.00 6,732.0 51.00 249.73 4,975.1 4,917.1 -3,496.8 376.6 3.50 0.00 4.50 90.00 7,739.7 70.03 284.29 5,480.3 5,422.3 -3,516.2 -476.8 3.50 1.89 3.43 67.43 9,261.7 70.03 284.29 6,000.1 5,942.1 -3,163.0 -1,863.0 0.00 0.00 0.00 0.00 10,029.0 75.00 312.00 6,234.7 6,176.7 -2,819.7 -2,499.6 3.50 0.65 3.61 83.80 10,629.0 75.00 312.00 6,390.0 6,332.0 -2,431.9 -2,930.3 0.00 0.00 0.00 0.00 11,063.0 87.97 313.15 6,454.1 6,396.1 -2,142.1 -3,245.6 3.00 2.99 0.26 5.09 11,561.2 87.97 313.15 6,471.8 6,413.8 -1,801.6 -3,608.9 0.00 0.00 0.00 0.00 11,630.9 90.00 313.65 6,473.0 6,415.0 -1,753.8 -3,659.5 3.00 2.91 0.72 13.81 11,934.9 98.96 315.37 6,449.3 6,391.3 -1,541.6 -3,875.4 3.00 2.95 0.57 10.78 12,231.1 98.96 315.37 6,403.2 6,345.2 -1,333.3 -4,081.0 0.00 0.00 0.00 0.00 12,617.1 90.00 308.00 6,373.0 6,315.0 -1,078.0 -4,368.0 3.00 -2.32 -1.91 -140.30 12,850.8 82.99 307.71 6,387.3 6,329.3 -934.9 -4,552.1 3.00 -3.00 -0.12 -177.65 13,194.0 82.99 307.71 6,429.1 6,371.1 -726.5 -4,821.6 0.00 0.00 0.00 0.00 13,664.7 90.00 320.00 6,458.0 6,400.0 -401.8 -5,159.4 3.00 1.49 2.61 60.75 13,903.4 95.29 324.83 6,447.0 6,389.0 -212.9 -5,304.7 3.00 2.22 2.02 42.25 14,507.9 95.29 324.83 6,391.2 6,333.2 279.1 -5,651.5 0.00 0.00 0.00 0.00 14,685.5 90.00 324.24 6,383.0 6,325.0 423.5 -5,754.3 3.00 -2.98 -0.33 -173.59 14,895.9 83.69 324.30 6,394.6 6,336.6 594.0 -5,877.0 3.00 -3.00 0.03 179.39 . 15,503.3 83.69 324.30 6,461.4 6,403.4 1,084.3 -6,229.2 0.00 0.00 0.00 0.00 15,714.6 90.00 323.71 6,473.0 6,415.0 1,254.9 -6,353.2 3.00 2.99 -0.28 -5.33 15,931.4 96.34 325.16 6,461.0 6,403.0 1,430.9 -6,479.0 3.00 2.93 0.67 12.80 16,380.8 96.34 325.16 6,411.4 6,353.4 1,797.4 -6,734.1 0.00 0.00 0.00 0.00 16,713.1 90.00 317.45 6,393.0 6,335.0 2,056.1 -6,941.4 3.00 -1.91 -2.32 -129.19 16,899.1 84.42 317.45 6,402.0 6,344.0 2,192.9 -7,067.0 3.00 -3.00 0.00 180.00 17,535.8 84.42 317.45 6,464.0 6,406.0 2,659.7 -7,495.5 0.00 0.00 0.00 0.00 17,721.8 90.00 317.45 6,473.0 6,415.0 2,796.5 -7,621.1 3.00 3.00 0.00 -0.01 17,898.4 95.30 317.45 6,464.8 6,406.8 2,926.4 -7,740.3 3.00 3.00 0.00 0.00 18,730.7 95.30 317.45 6,388.0 6,330.0 3,536.9 -8,300.7 0.00 0.00 0.00 0.00 1/30/2009 10:39:35AM Page 3 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 42.00 100.0 0.38 330.00 100.0 42.0 0.2 -0.1 6,031,065.99 469,881.60 0.00 0.15 200.0 0.25 14.74 200.0 142.0 0.7 -0.2 6,031,066.55 469,881.53 0.27 0.43 I 300.0 0.31 84.95 300.0 242.0 0.9 0.1 6,031,066.70 469,881.77 0.33 0.27 400.0 1.78 136.38 400.0 342.0 -0.2 1.4 6,031,065.66 . 469,883.04 1.61 -1.31 500.0 4.31 128.16 499.8 441.8 -3.7 5.5 6,031,062.08 469,887.15 2.55 -6.50 600.0 5.36 123.47 599.5 541.5 -8.5 12.4 6,031,057.32 469,894.01 1.12 -14.69 700.0 6.26 126.63 698.9 640.9 -14.6 20.8 6,031,051.19 469,902.45 0.96 -24.86 800.0 6.35 127.23 798.3 740.3 -20.9 29.4 6,031,044.77 469,911.05 0.11 -35.30 900.0 7.16 128.42 897.6 839.6 -28.2 38.7 6,031,037.43 469,920.28 0.82 -46.69 1,000.0 8.43 131.26 996.8 938.8 -36.6 49.1 6,031,029.00 469,930.59 1.32 -59.49 1,100.0 10.66 131.89 1,095.4 1,037.4 -47.7 61.2 6,031,017.84 469,942.65 2.24 -74.98 1,200.0 14.00 132.08 1,193.1 1,135.1 -61.7 76.9 6,031,003.81 469,958.37 3.34 -94.97 1,300.0 18.93 133.03 1,289.1 1,231.1 -80.8 97.6 6,030,984.60 469,978.90 4.93 -121.43 1,400.0 22.75 134.51 1,382.5 1,324.5 -105.2 123.6 6,030,960.17 470,004.81 3.86 -154.90 1,500.0 28.33 133.21 1,472.8 1,414.8 -135.2 154.2 6,030,930.05 470,035.32 5.60 -194.84 1,600.0 32.56 131.90 1,558.9 1,500.9 -169.4 191.7 6,030,895.66 470,072.65 4.28 -242.73 1,700.0 37.13 132.13 1,641.0 1,583.0 -207.5 234.1 6,030,857.41 470,114.95 4.57 -296.72 1,800.0 38.87 132.22 1,719.5 1,661.5 -249.1 280.0 6,030,815.59 470,160.66 1.75 -355.26 1,900.0 38.58 133.49 1,797.4 1,739.4 -291.7 326.1 6,030,772.85 470,206.53 0.84 -414.30 2,000.0 37.08 136.53 1,876.3 1,818.3 -335.0 369.6 6,030,729.34 470,249.86 2.39 -471.32 2,100.0 38.02 140.70 1,955.7 1,897.7 -380.6 409.7 6,030,683.59 470,289.85 2.71 -526.16 2,200.0 39.36 147.63 2,033.8 1,975.8 -431.2 446.3 6,030,632.85 470,326.21 4.53 -579.63 2,300.0 41.01 151.16 2,110.2 2,052.2 -486.8 479.1 6,030,577.14 470,358.76 2.81 -631.57 2,400.0 40.95 152.90 2,185.7 2,127.7 -544.7 509.8 6,030,519.16 470,389.26 1.14 -682.53 2,500.0 42.74 154.91 2,260.2 2,202.2 -604.6 539.1 6,030,459.15 470,418.30 2.23 -732.96 2,600.0 45.48 156.64 2,332.2 2,274.2 -667.8 567.7 6,030,395.79 470,446.61 2.99 -784.04 2,700.0 52.09 158.34 2,398.2 2,340.2 -737.2 596.2 6,030,326.29 470,474.84 6.73 -837.47 2,800.0 56.13 162.52 2,456.4 2,398.4 -813.9 623.2 6,030,249.49 470,501.54 5.27 -892.38 2,900.0 57.23 164.05 2,511.2 2,453.2 -893.8 647.8 6,030,169.50 470,525.81 1.69 -946.33 3,000.0 56.51 166.60 2,565.3 2,507.3 -975.3 668.5 6,030,087.92 470,546.16 2.25 -997.31 3,100.0 52.53 165.82 2,623.2 2,565.2 -1,054.5 688.0 6,030,008.67 470,565.30 4.03 -1,046.25 3,200.0 48.69 165.24 2,687.1 2,629.1 -1,128.9 707.2 6,029,934.14 470,584.24 3.86 -1,093.15 3,300.0 47.21 164.11 2,754.2 2,696.2 -1,200.5 726.5 6,029,862.53 470,603.26 1.71 -1,138.95 3,400.0 46.16 162.67 2,822.7 2,764.7 -1,270.2 747.7 6,029,792.72 470,624.14 1.48 -1,185.76 3,500.0 44.09 162.92 2,893.1 2,835.1 -1,338.1 768.8 6,029,724.80 470,644.97 2.08 -1,231.77 3,600.0 42.68 163.07 2,966.2 2,908.2 -1,403.3 788.6 6,029,659.46 470,664.51 1.41 -1,275.58 3,634.0 42.77 162.93 2,991.2 2,933.2 -1,425.4 795.3 6,029,637.35 470,671.17 0.37 -1,290.45 3,665.9 42.77 162.93 3,014.6 2,956.6 -1,446.1 801.7 6,029,616.64 470,677.44 0.00 -1,304.40 9 5/8" 3,683.0 42.77 162.93 3,027.1 2,969.1 -1,457.2 805.1 6,029,605.53 470,680.80 0.00 -1,311.89 Start Dir 1.50/100'3683.00'MD,3027.10'TVD 3,700.0 43.02 162.93 3,039.6 2,981.6 -1,468.3 808.5 6,029,594.46 470,684.16 1.50 -1,319.35 3,800.0 44.52 162.93 3,111.8 3,053.8 -1,534.4 828.8 6,029,528.25 470,704.19 1.50 -1,363.95 3,900.0 46.02 162.93 3,182.2 3,124.2 -1,602.3 849.7 6,029,460.25 470,724.77 1.50 -1,409.76 4,000.0 47.52 162.93 3,250.6 3,192.6 -1,672.0 871.1 6,029,390.52 470,745.87 1.50 -1,456.75 1/30/2009 10:39:35AM Page 4 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLI BU RTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 3,259.19 4,100.0 49.02 162.93 3,317.2 3,259.2 -1,743.3 893.0 6,029,319.09 470,767.49 1.50 -1,504.87 4,200.0 50.52 162.93 3,381.8 3,323.8 -1,816.3 915.4 6,029,246.03 470,789.60 1.50 -1,554.10 4,232.0 51.00 162.93 3,402.0 3,344.0 -1,840.0 922.6 6,029,222.33 470,796.77 1.50 -1,570.06 4,300.0 51.00 164.24 3,444.8 3,386.8 -1,890.7 937.6 6,029,171.56 470,811.51 1.50 -1,603.69 4,400.0 51.00 166.17 3,507.7 3,449.7 -1,965.8 957.4 6,029,096.34 470,831.04 1.50 -1,651.39 4,500.0 51.00 168.10 3,570.7 3,512.7 -2,041.6 974.7 6,029,020.51 470,848.03 1.50 -1,697.01 4,600.0 51.00 170.03 3,633.6 3,575.6 -2,117.9 989.5 6,028,944.16 470,862.46 1.50 -1,740.48 4,700.0 51.00 171.96 3,696.5 3,638.5 -2,194.7 1,001.6 6,028,867.36 470,874.31 1.50 -1,781.76 4,800.0 51.00 173.89 3,759.4 3,701.4 -2,271.8 1,011.2 6,028,790.20 470,883.56 1.50 -1,820.79 4,900.0 51.00 175.82 3,822.4 3,764.4 -2,349.2 1,018.2 6,028,712.78 470,890.21 1.50 -1,857.54 5,000.0 51.00 177.75 3,885.3 3,827.3 -2,426.8 1,022.5 6,028,635.18 470,894.25 1.50 -1,891.96 5,100.0 51.00 179.68 3,948.2 3,890.2 -2,504.5 1,024.2 6,028,557.48 470,895.68 1.50 -1,924.02 5,200.0 51.00 181.61 4,011.1 3,953.1 -2,582.2 1,023.4 6,028,479.78 470,894.48 1.50 -1,953.67 5,232.0 51.00 182.23 4,031.3 3,973.3 -2,607.0 1,022.5 6,028,454.93 470,893.55 1.50 -1,962.65 Start Dir 3.5/100'5232.00'MD,4010.10'TVD 5,300.0 51.00 185.29 4,074.1 4,016.1 -2,659.8 1,019.1 6,028,402.23 470,889.87 3.50 -1,980.13 5,400.0 51.00 189.79 4,137.0 4,079.0 -2,736.8 1,008.9 6,028,325.25 470,879.36 3.50 -2,000.94 5,500.0 51.00 194.29 4,199.9 4,141.9 -2,812.8 992.7 6,028,249.33 470,862.84 3.50 -2,015.82 5,600.0 51.00 198.79 4,262.8 4,204.8 -2,887.3 970.5 6,028,174.95 470,840.42 3.50 -2,024.66 5,619.3 51.02 199.66 4,275.0 4,217.0 -2,901.5 965.6 6,028,160.78 470,835.42 3.50 -2,025.67 Brook 2B 5,700.0 51.00 203.29 4,325.8 4,267.8 -2,959.8 942.6 6,028,102.55 470,812.23 3.50 -2,027.42 5,800.0 51.00 207.79 4,388.7 4,330.7 -3,029.9 909.1 6,028,032.59 470,778.45 3.50 -2,024.09 5,900.0 51.00 212.29 4,451.6 4,393.6 -3,097.2 870.2 6,027,965.49 470,739.28 3.50 -2,014.67 6,000.0 51.00 216.79 4,514.5 4,456.5 -3,161.2 826.2 6,027,901.67 470,694.97 3.50 -1,999.22 6,100.0 51.00 221.29 4,577.5 4,519.5 -3,221.5 777.2 6,027,841.53 470,645.79 3.50 -1,977.86 6,200.0 51.00 225.79 4,640.4 4,582.4 -3,277.8 723.7 6,027,785.43 470,592.05 3.50 -1,950.69 6,300.0 51.00 230.29 4,703.3 4,645.3 -3,329.8 665.9 6,027,733.72 470,534.06 3.50 -1,917.90 6,400.0 51.00 234.79 4,766.2 4,708.2 -3,377.0 604.3 6,027,686.72 470,472.20 3.50 -1,879.68 6,500.0 51.00 239.29 4,829.2 4,771.2 -3,419.3 539.1 6,027,644.72 470,406.84 3.50 -1,836.28 6,600.0 51.00 243.79 4,892.1 4,834.1 -3,456.3 470.8 6,027,607.97 470,338.39 3.50 -1,787.95 6,700.0 51.00 248.29 4,955.0 4,897.0 -3,487.9 399.7 6,027,576.71 470,267.26 3.50 -1,734.99 6,732.0 51.00 249.73 4,975.1 4,917.1 -3,496.8 376.6 6,027,567.91 470,244.04 3.50 -1,717.15 6,800.0 51.95 252.52 5,017.5 4,959.5 -3,514.0 326.2 6,027,550.91 470,193.61 3.50 -1,677.56 6,900.0 53.46 256.49 5,078.1 5,020.1 -3,535.2 249.6 6,027,530.01 470,116.89 3.50 -1,615.37 6,903.2 53.51 256.62 5,080.0 5,022.0 -3,535.8 247.1 6,027,529.43 470,114.42 3.50 -1,613.33 Top Torok Sand 7,000.0 55.10 260.31 5,136.5 5,078.5 -3,551.5 170.0 6,027,514.04 470,037.33 3.50 -1,548.61 7,100.0 56.84 263.96 5,192.5 5,134.5 -3,562.8 88.0 6,027,503.06 469,955.22 3.50 -1,477.54 7,200.0 58.70 267.48 5,245.8 5,187.8 -3,569.1 3.6 6,027,497.12 469,870.87 3.50 -1,402.42 7,300.0 60.64 270.85 5,296.3 5,238.3 -3,570.3 -82.6 6,027,496.23 469,784.59 3.50 -1,323.53 , 7,353.2 61.71 272.59 5,322.0 5,264.0 -3,568.9 -129.2 6,027,497.82 469,738.02 3.50 -1,280.13 Base Torok Sand 7,400.0 62.66 274.09 5,343.8 5,285.8 -3,566.5 -170.5 6,027,500.41 469,696.72 3.50 -1,241.17 7,500.0 64.76 277.22 5,388.1 5,330.1 -3,557.6 -259.7 6,027,509.62 469,607.56 3.50 -1,155.64 1/30/2009 10:39:35AM Page 5 COMPASS 2003.16 Build 42B Sperry Drilling Services HALLI BU RTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+ 13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+ 13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 5,371.06 7,600.0 66.92 280.24 5,429.1 5,371.1 -3,543.8 -349.9 6,027,523.85 469,517.46 3.50 -1,067.25 7,700.0 69.14 283.16 5,466.5 5,408.5 -3,525.0 -440.7 6,027,543.03 469,426.76 3.50 -976.35 7,739.7 70.03 284.29 5,480.3 5,422.3 -3,516.1 -476.8 6,027,552.00 469,390.66 3.50 -939.64 End Dir 7739.70'MD,5480.30'TVD 7,800.0 70.03 284.29 5,500.9 5,442.9 -3,502.2 -531.8 6,027,566.21 469,335.80 0.00 -883.63 7,900.0 70.03 284.29 5,535.1 5,477.1 -3,479.0 -622.8 6,027,589.78 469,244.82 0.00 -790.75 8,000.0 70.03 284.29 5,569.2 5,511.2 -3,455.7 -713.9 6,027,613.35 469,153.85 0.00 -697.86 8,100.0 70.03 284.29 5,603.4 5,545.4 -3,432.5 -805.0 6,027,636.92 469,062.87 0.00 -604.98 8,200.0 70.03 284.29 5,637.5 5,579.5 -3,409.3 -896.1 6,027,660.49 468,971.90 0.00 -512.09 8,300.0 70.03 284.29 5,671.7 5,613.7 -3,386.1 -987.2 6,027,684.06 468,880.92 0.00 -419.21 8,400.0 70.03 284.29 5,705.8 5,647.8 -3,362.9 -1,078.2 6,027,707.63 468,789.95 0.00 -326.32 8,500.0 70.03 284.29 5,740.0 5,682.0 -3,339.7 -1,169.3 6,027,731.19 468,698.97 0.00 -233.44 8,600.0 70.03 284.29 5,774.1 5,716.1 -3,316.5 -1,260.4 6,027,754.76 468,607.99 0.00 -140.55 8,614.3 70.03 284.29 5,779.0 5,721.0 -3,313.2 -1,273.4 6,027,758.14 468,594.98 0.00 -127.26 Top HRZ 8,700.0 70.03 284.29 5,808.3 5,750.3 -3,293.3 -1,351.5 6,027,778.33 468,517.02 0.00 -47.67 8,800.0 70.03 284.29 5,842.4 5,784.4 -3,270.1 -1,442.6 6,027,801.90 468,426.04 0.00 45.22 8,900.0 70.03 284.29 5,876.6 5,818.6 -3,246.9 -1,533.6 6,027,825.47 468,335.07 0.00 138.10 8,986.2 70.03 284.29 5,906.0 5,848.0 -3,226.9 -1,612.1 6,027,845.78 468,256.65 0.00 218.17 Base HRZ 9,000.0 70.03 284.29 5,910.7 5,852.7 -3,223.7 -1,624.7 6,027,849.04 468,244.09 0.00 230.99 9,100.0 70.03 284.29 5,944.9 5,886.9 -3,200.5 -1,715.8 6,027,872.61 468,153.12 0.00 323.87 9,200.0 70.03 284.29 5,979.0 5,921.0 -3,177.3 -1,806.9 6,027,896.17 468,062.14 0.00 416.76 9,229.2 70.03 284.29 5,989.0 5,931.0 -3,170.5 -1,833.5 6,027,903.07 468,035.53 0.00 443.93 Kalubik Marker 9,261.7 70.03 284.29 6,000.1 5,942.1 -3,163.0 -1,863.1 6,027,910.72 468,006.01 0.00 474.07 Start Dir 3.5/100'9261.70'MD,6000.10'TVD 9,300.0 70.18 285.71 6,013.1 5,955.1 -3,153.7 -1,897.9 6,027,920.18 467,971.27 3.50 509.73 9,400.0 70.63 289.39 6,046.7 5,988.7 -3,125.3 -1,987.7 6,027,948.95 467,881.59 3.50 603.48 9,446.5 70.86 291.10 6,062.0 6,004.0 -3,110.1 -2,028.8 6,027,964.31 467,840.47 3.50 647.32 Kup C 9,500.0 71.15 293.06 6,079.4 6,021.4 -3,091.1 -2,075.7 6,027,983.51 467,793.68 3.50 697.89 9,583.3 71.63 296.09 6,106.0 6,048.0 -3,058.2 -2,147.5 6,028,016.62 467,722.06 3.50 776.78 LCU 9,600.0 71.74 296.70 6,111.3 6,053.3 -3,051.2 -2,161.7 6,028,023.73 467,707.87 3.50 792.63 9,700.0 72.39 300.31 6,142.1 6,084.1 -3,005.8 -2,245.3 6,028,069.46 467,624.47 3.50 887.32 9,800.0 73.12 303.90 6,171.7 6,113.7 -2,955.0 -2,326.2 6,028,120.53 467,543.81 3.50 981.62 9,900.0 73.90 307.45 6,200.1 6,142.1 -2,899.1 -2,404.0 6,028,176.76 467,466.17 3.50 1,075.18 10,000.0 74.74 310.98 6,227.1 6,169.1 -2,838.3 -2,478.6 6,028,237.92 467,391.85 3.50 1,167.65 10,029.0 75.00 312.00 6,234.7 6,176.7 -2,819.7 -2,499.6 6,028,256.55 467,370.96 3.50 1,194.21 End Dir 10029.00'MD,6234.70'TVD 10,100.0 75.00 312.00 6,253.1 6,195.1 -2,773.8 -2,550.5 6,028,302.64 467,320.18 0.00 1,259.09 10,200.0 75.00 312.00 6,279.0 6,221.0 -2,709.2 -2,622.3 6,028,367.56 467,248.67 0.00 1,350.46 10,300.0 75.00 312.00 6,304.8 6,246.8 -2,644.6 -2,694.1 6,028,432.47 467,177.16 0.00 1,441.83 1/30/2009 10:39:35AM Page 6 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTDN Standard Proposal Report Database: ..EDM Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,254.35 10,329.0 75.00 312.00 6,312.4 6,254.4 -2,625.8 -2,714.9 6,028,451.30 467,156.42 0.00 1,468.33 Begin 300'ESP Tanget 10,400.0 75.00 312.00 6,330.7 6,272.7 -2,579.9 -2,765.9 6,028,497.39 467,105.64 0.00 1,533.21 10,486.1 75.00 312.00 6,353.0 6,295.0 -2,524.3 -2,827.7 6,028,553.26 467,044.10 0.00 1,611.84 BCU 10,500.0 75.00 312.00 6,356.6 6,298.6 -2,515.3 -2,837.7 6,028,562.31 467,034.13 0.00 1,624.58 10,600.0 75.00 312.00 6,382.5 6,324.5 -2,450.7 -2,909.5 6,028,627.23 466,962.62 0.00 1,715.95 10,625.1 75.00 312.00 6,389.0 6,331.0 -2,434.4 -2,927.5 6,028,643.55 466,944.63 0.00 1,738.93 Nuiqsut 10,629.0 75.00 312.00 6,390.0 6,332.0 -2,431.9 -2,930.3 6,028,646.06 466,941.87 0.00 1,742.46 Start Dir 3.0/100'10629.00'MD,6390.00'TVD-7"-PN10 v12 T1A 10,700.0 77.12 312.19 6,407.1 6,349.1 -2,385.7 -2,981.4 6,028,692.45 466,890.94 3.00 1,807.59 10,800.0 80.11 312.46 6,426.8 6,368.8 -2,319.7 -3,053.9 6,028,758.74 466,818.75 3.00 1,900.14 10,900.0 83.10 312.72 6,441.4 6,383.4 -2,252.8 -3,126.7 6,028,825.97 466,746.21 3.00 1,993.37 11,000.0 86.09 312.98 6,450.9 6,392.9 -2,185.1 -3,199.7 6,028,893.96 466,673.52 3.00 2,087.04 11,063.0 87.97 313.15 6,454.1 6,396.1 -2,142.1 -3,245.6 6,028,937.10 466,627.74 3.00 2,146.17 End Dir 11063.00'MD,6454.10'ND 11,100.0 87.97 313.15 6,455.4 6,397.4 -2,116.8 -3,272.6 6,028,962.50 466,600.86 0.00 2,180.90 11,200.0 87.97 313.15 6,459.0 6,401.0 -2,048.5 -3,345.5 6,029,031.13 466,528.23 0.00 2,274.77 11,300.0 87.97 313.15 6,462.5 6,404.5 -1,980.1 -3,418.4 6,029,099.76 466,455.60 0.00 2,368.64 11,400.0 87.97 313.15 6,466.1 6,408.1 -1,911.8 -3,491.4 6,029,168.39 466,382.97 0.00 2,462.51 11,500.0 87.97 313.15 6,469.6 6,411.6 -1,843.4 -3,564.3 6,029,237.02 466,310.34 0.00 2,556.38 11,561.2 87.97 313.15 6,471.8 6,413.8 -1,801.6 -3,608.9 6,029,279.03 466,265.89 0.00 2,613.83 Start Dir 3.0/100'11561.20'MD,6471.80'ND 11,600.0 89.10 313.42 6,472.8 6,414.8 -1,775.0 -3,637.1 6,029,305.73 466,237.77 3.00 2,650.23 11,630.9 90.00 313.65 6,473.0 6,415.0 -1,753.8 -3,659.5 6,029,327.07 466,215.49 3.00 2,679.13 PN10 v12 T2 11,700.0 92.04 314.03 6,471.8 6,413.8 -1,705.9 -3,709.4 6,029,375.15 466,165.83 3.00 2,743.78 11,800.0 94.98 314.60 6,465.6 6,407.6 -1,636.2 -3,780.8 6,029,445.15 466,094.71 3.00 2,836.80. 11,900.0 97.93 315.17 6,454.4 6,396.4 -1,566.1 -3,851.2 6,029,515.54 466,024.60 3.00 2,929.05 11,934.9 98.96 315.37 6,449.3 6,391.3 -1,541.5 -3,875.5 6,029,540.16 466,000.40 3.00 2,961.01 End Dir 11934.90'MD,6449.30'ND 12,000.0 98.96 315.37 6,439.1 6,381.1 -1,495.8 -3,920.6 6,029,586.09 465,955.41 0.00 3,020.52 12,100.0 98.96 315.37 6,423.6 6,365.6 -1,425.5 -3,990.0 6,029,656.66 465,886.31 0.00 3,111.92 12,200.0 98.96 315.37 6,408.0 6,350.0 -1,355.2 -4,059.4 6,029,727.23 465,817.20 0.00 3,203.32 12,231.1 98.96 315.37 6,403.2 6,345.2 -1,333.3 -4,081.0 6,029,749.17 465,795.70 0.00 3,231.74 Start Dir 3.0/100'12231.10'MD,6403.20'ND 12,300.0 97.37 314.03 6,393.4 6,335.4 -1,285.4 -4,129.5 6,029,797.33 465,747.43 3.00 3,295.14 12,400.0 95.05 312.12 6,382.6 6,324.6 -1,217.5 -4,202.1 6,029,865.51 465,675.10 3.00 3,388.55 12,500.0 92.72 310.22 6,375.8 6,317.8 -1,151.8 -4,277.2 6,029,931.47 465,600.28 3.00 3,483.38 12,600.0 90.40 308.32 6,373.1 6,315.1 -1,088.5 -4,354.6 6,029,995.04 465,523.16 3.00 3,579.37 12,617.1 90.00 308.00 6,373.0 6,315.0 -1,078.0 -4,368.0 6,030,005.64 465,509.79 3.00 3,595.85 PN10v12T3 12,700.0 87.51 307.90 6,374.8 6,316.8 -1,027.0 -4,433.4 6,030,056.89 465,444.62 3.00 3,675.98 12,800.0 84.52 307.77 6,381.7 6,323.7 -965.8 -4,512.2 6,030,118.38 465,366.10 3.00 3,772.44 1/30/2009 10:39:35AM Page 7 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTDN Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,329.27 12,850.8 82.99 307.71 6,387.3 6,329.3 -934.9 -4,552.1 6,030,149.45 465,326.30 3.00 3,821.29 End Dir 12850.80'MD,6387.30'TVD 12,900.0 82.99 307.71 6,393.3 6,335.3 -905.1 -4,590.7 6,030,179.48 465,287.80 0.00 3,868.54 13,000.0 82.99 307.71 6,405.5 6,347.5 -844.3 -4,669.2 6,030,240.50 465,209.53 0.00 3,964.57 13,100.0 82.99 307.71 6,417.7 6,359.7 -783.6 -4,747.8 6,030,301.52 465,131.27 0.00 4,060.61 13,194.0 82.99 307.71 6,429.1 6,371.1 -726.6 -4,821.6 6,030,358.88 465,057.70 0.00 4,150.88 Start Dir 3.0/100'13194.00'MD,6429.10'TVD 13,200.0 83.08 307.87 6,429.9 6,371.9 -722.9 -4,826.3 6,030,362.55 465,053.00 2.98 4,156.64 13,300.0 84.55 310.50 6,440.6 6,382.6 -660.1 -4,903.3 6,030,425.66 464,976.22 3.00 4,252.14 13,400.0 86.04 313.11 6,448.8 6,390.8 -593.7 -4,977.6 6,030,492.39 464,902.21 3.00 4,346.52 13,500.0 87.53 315.72 6,454.5 6,396.5 -523.8 -5,048.9 6,030,562.54 464,831.20 3.00 4,439.51 13,600.0 89.03 318.32 6,457.5 6,399.5 -450.7 -5,117.1 6,030,635.92 464,763.36 3.00 4,530.85 13,664.7 90.00 320.00 6,458.0 6,400.0 -401.8 -5,159.4 6,030,685.02 464,721.27 3.00 4,588.95 PN10 v12 T4 13,700.0 90.78 320.71 6,457.8 6,399.8 -374.6 -5,181.9 6,030,712.30 464,698.85 3.00 4,620.33 13,800.0 93.00 322.73 6,454.5 6,396.5 -296.1 -5,243.8 6,030,790.99 464,637.27 3.00 4,708.04 13,900.0 95.22 324.76 6,447.3 6,389.3 -215.7 -5,302.8 6,030,871.64 464,578.62 3.00 4,793.82 13,903.4 95.29 324.83 6,447.0 6,389.0 -212.9 -5,304.7 6,030,874.42 464,576.68 2.98 4,796.70 End Dir 13903.40'MD,6447.00'TVD 14,000.0 95.29 324.83 6,438.1 6,380.1 -134.3 -5,360.1 6,030,953.26 464,521.60 0.00 4,878.49 14,100.0 95.29 324.83 6,428.8 6,370.8 -52.9 -5,417.5 6,031,034.88 464,464.58 0.00 4,963.17 14,200.0 95.29 324.83 6,419.6 6,361.6 28.5 -5,474.8 6,031,116.50 464,407.56 0.00 5,047.84 14,300.0 95.29 324.83 6,410.4 6,352.4 109.9 -5,532.2 6,031,198.12 464,350.54 0.00 5,132.51 14,400.0 95.29 324.83 6,401.2 6,343.2 191.3 -5,589.6 6,031,279.73 464,293.52 0.00 5,217.18 I 14,500.0 95.29 324.83 6,391.9 6,333.9 272.7 -5,646.9 6,031,361.35 464,236.50 0.00 5,301.86 14,507.9 95.29 324.83 6,391.2 6,333.2 279.1 -5,651.4 6,031,367.80 464,231.99 0.00 5,308.55 Start Dir 3.0/100'14507.90'MD,6391.20'ND 14,600.0 92.55 324.52 6,384.9 6,326.9 354.1 -5,704.6 6,031,442.97 464,179.18 3.00 5,386.80 14,685.5 90.00 324.24 6,383.0 6,325.0 423.5 -5,754.3 6,031,512.63 464,129.69 3.00 5,459.83 PN10 v12 T5 14,700.0 89.56 324.24 6,383.1 6,325.1 435.3 -5,762.8 6,031,524.44 464,121.26 3.00 5,472.24 14,800.0 86.56 324.27 6,386.4 6,328.4 516.4 -5,821.2 6,031,605.77 464,063.22 3.00 5,557.74 14,895.9 83.69 324.30 6,394.6 6,336.6 594.0 -5,877.0 6,031,683.57 464,007.77 3.00 5,639.46 End Dir 14895.90'MD,6394.60'TVD 14,900.0 83.69 324.30 6,395.0 6,337.0 597.3 -5,879.3 6,031,686.89 464,005.40 0.03 5,642.94 15,000.0 83.69 324.30 6,406.0 6,348.0 678.0 -5,937.3 6,031,767.83 463,947.74 0.00 5,727.94 15,100.0 83.69 324.30 6,417.0 6,359.0 758.7 -5,995.3 6,031,848.78 463,890.08 0.00 5,812.94 15,200.0 83.69 324.30 6,428.0 6,370.0 839.5 -6,053.3 6,031,929.72 463,832.41 0.00 5,897.93 15,300.0 83.69 324.30 6,439.0 6,381.0 920.2 -6,111.3 6,032,010.67 463,774.75 0.00 5,982.93 15,400.0 83.69 324.30 6,450.0 6,392.0 1,000.9 -6,169.3 6,032,091.61 463,717.09 0.00 6,067.92 15,500.0 83.69 324.30 6,461.0 6,403.0 1,081.6 -6,227.3 6,032,172.56 463,659.43 0.00 6,152.92 15,503.3 83.69 324.30 6,461.4 6,403.4 1,084.3 -6,229.2 6,032,175.23 463,657.52 0.00 6,155.73 Start Dir 3.0/100'15503.30'MD,6461.40'ND 15,600.0 86.58 324.03 6,469.6 6,411.6 1,162.4 -6,285.6 6,032,253.55 463,601.45 3.00 6,238.23 15,700.0 89.56 323.76 6,472.9 6,414.9 1,243.1 -6,344.5 6,032,334.52 463,542.89 3.00 6,324.05 1/30/2009 10:39:35AM Page 8 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTOI'V Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'©58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,415.00 15,714.6 90.00 323.71 6,473.0 6,415.0 1,254.9 -6,353.2 6,032,346.36 463,534.28 3.00 6,336.65 PN10 v12 T6 15,800.0 92.50 324.28 6,471.1 6,413.1 1,324.0 -6,403.3 6,032,415.59 463,484.41 3.00 6,409.85 15,900.0 95.42 324.95 6,464.2 6,406.2 1,405.3 -6,461.1 6,032,497.14 463,426.98 3.00 6,494.87 15,931.4 96.34 325.16 6,461.0 6,403.0 1,430.9 -6,479.0 6,032,522.81 463,409.20 3.00 6,521.36 End Dir 15931.40'MD,6461.00'TVD 16,000.0 96.34 325.16 6,453.4 6,395.4 1,486.9 -6,517.9 6,032,578.93 463,370.48 0.00 6,579.13 16,100.0 96.34 325.16 6,442.4 6,384.4 1,568.4 -6,574.7 6,032,660.72 463,314.04 0.00 6,663.34 1 16,200.0 96.34 325.16 6,431.4 6,373.4 1,650.0 -6,631.5 6,032,742.52 463,257.60 0.00 6,747.55 I 16,300.0 96.34 325.16 6,420.3 6,362.3 1,731.6 -6,688.3 6,032,824.31 463,201.16 0.00 6,831.76 16,380.8 96.34 325.16 6,411.4 6,353.4 1,797.5 -6,734.2 6,032,890.40 463,155.56 0.00 6,899.80 Start Dir 3.0/100'16380.80'MD,6411.40'TVD 16,400.0 95.97 324.71 6,409.3 6,351.3 1,813.1 -6,745.1 6,032,906.07 463,144.66 3.01 6,916.02 16,500.0 94.07 322.38 6,400.6 6,342.6 1,893.2 -6,804.3 6,032,986.42 463,085.80 3.00 7,001.87 16,600.0 92.16 320.07 6,395.1 6,337.1 1,971.1 -6,866.8 6,033,064.50 463,023.60 3.00 7,089.90 16,700.0 90.25 317.75 6,393.0 6,335.0 2,046.4 -6,932.5 6,033,140.10 462,958.21 3.00 7,179.88 16,713.1 90.00 317.45 6,393.0 6,335.0 2,056.1 -6,941.4 6,033,149.83 462,949.39 3.00 7,191.83 PN10 v12 T7 16,800.0 87.39 317.45 6,395.0 6,337.0 2,120.1 -7,000.1 6,033,214.03 462,890.93 3.00 7,270.93 16,899.1 84.42 317.45 6,402.0 6,344.0 2,192.9 -7,066.9 6,033,287.11 462,824.40 3.00 7,360.96 End Dir 16899.10'MD,6402.00'TVD 1 16,900.0 84.42 317.45 6,402.1 6,344.1 2,193.5 -7,067.6 6,033,287.77 462,823.80 0.03 7,361.77 17,000.0 84.42 317.45 6,411.9 6,353.9 2,266.9 -7,134.9 6,033,361.35 462,756.80 0.00 7,452.43 17,100.0 84.42 317.45 6,421.6 6,363.6 2,340.2 -7,202.2 6,033,434.94 462,689.80 0.00 7,543.09 17,200.0 84.42 317.45 6,431.3 6,373.3 2,413.5 -7,269.5 6,033,508.52 462,622.80 0.00 7,633.75 17,300.0 84.42 317.45 6,441.0 6,383.0 2,486.8 -7,336.8 6,033,582.11 462,555.80 0.00 7,724.40 17,400.0 84.42 317.45 6,450.7 6,392.7 2,560.1 -7,404.1 6,033,655.69 462,488.80 0.00 7,815.06 17,500.0 84.42 317.45 6,460.5 6,402.5 2,633.5 -7,471.4 6,033,729.27 462,421.80 0.00 7,905.72 17,535.8 84.42 317.45 6,463.9 6,405.9 2,659.7 -7,495.5 6,033,755.62 462,397.82 0.00 7,938.18 Start Dir 3.01100'17535.80'MD,6463.90'TVD 17,600.0 86.35 317.45 6,469.1 6,411.1 2,706.8 -7,538.7 6,033,802.93 462,354.74 3.00 7,996.46 17,700.0 89.35 317.45 6,472.9 6,414.9 2,780.5 -7,606.3 6,033,876.80 462,287.48 3.00 8,087.48 17,721.8 90.00 317.45 6,473.0 6,415.0 2,796.5 -7,621.1 6,033,892.93 462,272.79 3.00 8,107.35 PN10 v12 T8 17,800.0 92.35 317.45 6,471.4 6,413.4 2,854.1 -7,673.9 6,033,950.72 462,220.17 3.00 8,178.55 17,898.4 95.30 317.45 6,464.8 6,406.8 2,926.4 -7,740.3 6,034,023.30 462,154.09 3.00 8,267.97 End Dir 17898.40'MD,6464.80'ND 17,900.0 95.30 317.45 6,464.7 6,406.7 2,927.6 -7,741.4 6,034,024.47 462,153.01 0.00 8,269.42 18,000.0 95.30 317.45 6,455.5 6,397.5 3,001.0 -7,808.7 6,034,098.09 462,085.98 0.00 8,360.12 18,100.0 95.30 317.45 6,446.2 6,388.2 3,074.3 -7,876.1 6,034,171.71 462,018.95 0.00 8,450.82 18,200.0 95.30 317.45 6,437.0 6,379.0 3,147.7 -7,943.4 6,034,245.33 461,951.92 0.00 8,541.52 18,300.0 95.30 317.45 6,427.8 6,369.8 3,221.0 -8,010.7 6,034,318.94 461,884.89 0.00 8,632.23 18,400.0 95.30 317.45 6,418.5 6,360.5 3,294.4 -8,078.1 6,034,392.56 461,817.86 0.00 8,722.93 1 18,500.0 95.30 317.45 6,409.3 6,351.3 3,367.7 -8,145.4 6,034,466.18 461,750.83 0.00 8,813.63 18,600.0 95.30 317.45 6,400.1 6,342.1 3,441.1 -8,212.7 6,034,539.80 461,683.79 0.00 8,904.33 1/30/2009 10:39:35AM Page 9 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,332.83 18,700.0 95.30 317.45 6,390.8 6,332.8 3,514.4 -8,280.1 6,034,613.41 461,616.76 0.00 8,995.03 . 18,730.7 95.30 317.45 6,388.0 6,330.0 3,536.9 -8,300.7 6,034,636.02 461,596.18 0.00 9,022.87 I Total Depth at 18730.70'MD,6388.00'TVD-PN10 v12 T9 - Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (?) (bearing (ft) (ft) (ft) (ft) (ft) PN10 v12 T8 0.00 0.00 6,473.0 2,796.5 -7,621.1 6,033,892.93 462,272.79 -plan hits target -Point PN10 v12 T3 0.00 0.00 6,373.0 -1,078.0 -4,368.0 6,030,005.64 465,509.79 -plan hits target -Point PN10 v12 T2 0.00 0.00 6,473.0 -1,753.8 -3,659.5 6,029,327.07 466,215.49 -plan hits target -Point PN10 v12 T6 0.00 0.00 6,473.0 1,254.9 -6,353.2 6,032,346.36 463,534.28 -plan hits target -Point PN10 v12 T7 0.00 0.00 6,393.0 2,056.1 -6,941.4 6,033,149.83 462,949.39 -plan hits target -Point PN10 v12 T4 0.00 0.00 6,458.0 -401.8 -5,159.4 6,030,685.02 464,721.27 -plan hits target -Point PN10 v12 T5 0.00 0.00 6,383.0 423.5 -5,754.3 6,031,512.63 464,129.69 11 -plan hits target -Point PN10 v12 T1A 0.00 0.00 6,390.0 -2,431.9 -2,930.3 6,028,646.06 466,941.87 -plan hits target -Point PN10 v12 T9 0.00 0.00 6,388.0 3,536.9 -8,300.7 6,034,636.02 461,596.18 -plan hits target -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,665.9 3,014.6 9 5/8" 9.625 12.250 10,629.0 6,390.0 7" 7.000 8.750 1/30/2009 10:39:35AM Page 10 COMPASS 2003.16 Build 428 Sperry Drilling Services HALLI BU RTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN-36-Slot ODS-36 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.54'+13.5'@ 58.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-36 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-36 PN10 Design: ODSN-36 PN10 wp12 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (bearing) 3,502.7 2,895.0 Tuffaceous Shales 0.00 8,614.3 5,779.0 Top HRZ 0.00 6,903.2 5,080.0 Top Torok Sand 0.00 7,353.2 5,322.0 Base Torok Sand 0.00 9,583.3 6,106.0 LCU 0.00 I 10,625.1 6,389.0 Nuiqsut 0.00 10,486.1 6,353.0 BCU 0.00 9,446.5 6,062.0 Kup C 0.00 9,229.2 5,989.0 Kalubik Marker . 0.00 3,353.9 2,791.0 Violet 1 fault 0.00 2,709.4 2,404.0 Top West Sak 0.00 1,731.6 1,666.0 Base of Permafrost 0.00 5,619.3 4,275.0 Brook 2B 0.00 8,986.2 5,906.0 Base HRZ 0.00 Plan Annotations Measured Vertical Local Coordinates , Depth Depth +N/-S +E/-W . (ft) (ft) (ft) (ft) Comment 3,683.0 3,027.1 -1,457.2 805.1 Start Dir 1.50/100'3683.00'MD,3027.10'TVD 5,232.0 4,031.3 -2,607.0 1,022.5 Start Dir 3.5/100'5232.00'MD,4010.10'TVD 7,739.7 5,480.3 -3,516.1 -476.8 End Dir 7739.70'MD,5480.30'TVD 9,261.7 6,000.1 -3,163.0 -1,863.1 Start Dir 3.5/100'9261.70'MD,6000.10'TVD 10,029.0 6,234.7 -2,819.7 -2,499.6 End Dir 10029.00'MD,6234.70'TVD 10,329.0 6,312.4 -2,625.8 -2,714.9 Begin 300'ESP Tanget 10,629.0 6,390.0 -2,431.9 -2,930.3 Start Dir 3.0/100'10629.00'MD,6390.00'TVD 11,063.0 6,454.1 -2,154.9 -3,231.9 End Dir 11063.00'MD,6454.10'TVD 11,561.2 6,471.8 -2,142.1 -3,245.6 Start Dir 3.0/100'11561.20'MD,6471.80'TVD 11,934.9 6,449.3 -1,801.6 -3,608.9 End Dir 11934.90'MD,6449.30'TVD 12,231.1 6,403.2 -1,541.5 -3,875.5 Start Dir 3.0/100'12231.10'MD,6403.20'TVD 12,850.8 6,387.3 -1,333.3 -4,081.0 End Dir 12850.80'MD,6387.30'TVD 13,194.0 6,429.1 -934.9 -4,552.1 Start Dir 3.0/100'13194.00'MD,6429.10'TVD 13,903.4 6,447.0 -726.6 -4,821.6 End Dir 13903.40'MD,6447.00'TVD 14,507.9 6,391.2 -212.9 -5,304.7 Start Dir 3.0/100'14507.90'MD,6391.20'TVD 14,895.9 6,394.6 279.1 -5,651.4 End Dir 14895.90'MD,6394.60'TVD 15,503.3 6,461.4 594.0 -5,877.0 Start Dir 3.0/100'15503.30'MD,6461.40'TVD 15,931.4 6,461.0 1,084.3 -6,229.2 End Dir 15931.40'MD,6461.00'TVD 16,380.8 6,411.4 1,430.9 -6,479.0 Start Dir 3.0/100'16380.80'MD,6411.40'TVD I 16,899.1 6,402.0 1,797.5 -6,734.2 End Dir 16899.10'MD,6402.00'TVD 17,535.8 6,463.9 2,192.9 -7,066.9 Start Dir 3.0/100'17535.80'MD,6463.90'TVD 17,898.4 6,464.8 2,659.7 -7,495.5 End Dir 17898.40'MD,6464.80'TVD 18,730.7 6,388.0 2,926.4 -7,740.3 Total Depth at 18730.70'MD,6388.00'TVD 1/30/2009 10:39:35AM Page 11 COMPASS 2003.16 Build 428 oe �n 1 u nti 1 mb i -° 4 0 E, 5iI El 11,4 g _ 0 T `, .. a - Z C Z - � A DI I Z — 1 § g F Oz ®X 0 4 -- ®Z O x l 11 ., m1'® ro, 11 �e 4I — O O �o I� lliiioi Z.:l D4 04 Di izm - f 1 ©X-LEegf OX *4-- I I I n ®O m O O i 111191W :1 T 1 I 1 _I i,i� 111111 11 o A ■ 1 �I!.- 1 T IWO I. ■ ' .• ® .4- - i ti il ©Q* A©® ® Sop - d'S'S ® B .1 mj 91 $ gx @ e®Z ®Z®g O " § 1 gi i II _ = _ s0 1/ --1-1 lir il , ., ,. g ( E,. ,,,.,. ,. , . 2 g 5i ao I U I A I W I r.) I - Installing of RCD Flow Diverter Body: • Lift and place RFD body onto top flange of RIG BOP stack using safest method available to ensure Body & fittings are not damaged. • Nipple up any adapter spools, studded adapters • Install all required valves and flow line components as required. • Install equalization lines as required. • Check alignment of the BOP stack to ensure the stack is in alignment with the Halliburton RFD. • Pressure test BOP to oil company policy. Installation of Bearing Assembly: • Run pipe into hole two stands off bottom or to company program. • Install stabbing mandrel to bottom of stand, Grease stabber, and stab through bearing. • Lower stand with bearing assembly and through the rotary table. • Lower drill string until bearing assembly is seated properly in the RFD body. • Install oil supply lines • Start up HPU and start drilling. Change RCD Bearing Assembly Procedure 02/09/2008 • Good communication between the RCD Operator and the drill floor is CRITICAL. Clear instructions must be relayed between the RCD Operator (working on the RCD beneath the drill floor) and the Driller, MPD Supervisor and air hoist operator. • In preparation for changing out a bearing seal assembly, ensure the 6 ft lifting slings,stabbing stand and starting mandrel are all on the drill floor • The RCD 5000 is a passive head, meaning it closes solely on well bore pressure. • It is rated for 3500psi at 50RPM in a dynamic state and 5000psi in static mode. • To change out the RCD Bearing Assembly the stack should be in a clean and safe working condition with a STURDY WORK PLATFORM from which to work off. NOTE: If the bearing assembly is pulled, but not being changed out, and the forward plan is to re-run it, it must always be positioned at the bottom of a stand for racking back, or removed completely. l. Position the element in the centre of the top single,and stop rotating. 2. Stop injection. 3. Close the Annular. 4. Bleed off standpipe pressure as per Connection Procedure. 5. Monitor wellhead pressure. 6. Bleed off pressure between annular and rotating head through MPD choke. Bleed off remaining pressure through to Rig shakers. 7. Open bleed valve on rotating head body,to confirm there is no trapped pressure. CONFIRM 0 PSI WITH MPD SUPERVISOR Note: Do not unlatch bearing assembly without checking for trapped pressure. 8. Stop cooling system, and remove circulating and pressure lines on the rotating head assembly. 9. Open clamp on rotating head body. 10. Remove the rotary table split bushing. Note: NEVER Connect lanyard to ANY portion of the RCD Note: NEVER put your body between the RCD and the rotating table 11. Install 6 ft lifting sling on rotating head assembly lifting eyes. 12. Slowly lift drill pipe,tagged line and seal bearing assembly approximately 3 ft above table. Move bearing assembly directly below top tool joint. 13. Reinstall rotary table split bushing. 14. Set drill pipe slips. Remove elevators. 15. Install 18 ft lifting slings thru the bell eyes,hook slings on the rotating head assembly lifting eyes and remove rotating head assembly. 16. Screw top drive into the pipe. Strip out single thru the Annular. 17. Break connection on the first single. Screw starting mandrel on the single. 18. Position bearing assembly into 3 ft by 16"stabbing casing on rotary table next to stump. 19. Lubricate the starting mandrel and inside of rubber,then push the single through the rubber until the mandrel is completely through the rubber. Change RCD Bearing Assembly Procedure 02/09/2008 20. Remove starting mandrel to make up top drive and single to drill string. 21. Pull out of the slips and remove split table bushing to allow the rotating head assembly to pass through the rotary table. BE CAREFUL TO NOT DAMAGE HYDRAULIC CONNECTIONS. 22. Lower the drill string down stopping to position the anti-rotation block RCD clamp. (If this is not in the correct position the clamp can't be closed properly). 23. Finish lowering the rotating head assembly in to the bowl and close clamp. 24. Connect lubricating lines to the rotating head. 25. Restart HCU and confirm differential pressure is 150-200psi higher than well bore pressure.. 26. Pressure up to below BOP pressure, slowly with the cement pump below the RCD via the primary MPD line. Note: Ensure pressures are equalized on the pressure gauges and they don't exceed rotating head limitations (5000 psi). 27. Inflow test the RCD element,seals and housing. 28. Open the annular. 29. Continue with MPD operations. r • a �z m0 Zr z to a o m.O.F. �' m5. 2g 0 i C 111111111Lli-11:` 0 $ 3 0 c:- gN .. 7 y • •• •• 'S m �' m • • • • Z K7 CO CO Q co °' � f o c� Z jf v� @co $ > o a 11 � Z� v „ � E c m 2 c c s 5. M +n(0-R z sA d v C �- . �� o MffCm _ n 31 Er' um, c CD N s 7 EN a Ts C (7 -i � � co 8 73 C7 � � y M N H cim - fr • ca r7 • N i 0 r* a:WVIlfirl' 4 3.0185' O@D Db n . 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D5 3M•E:O.P. a i pl_ Roods lo•Cdo . .Fl 44 a ' •• 7.6 ?i v p7/a ' 1 Bosis of Locotion E'er' • / /A'k, r.EN / , '� - DS-3H West Monument '� % •. as �, 1 • ' Coordinates i••R *>9.� :: N 6001016.61 ' "" Ate: o E AS8081.23 57/...KED P1 INFCRM},'DON ONLY p • _ = -- n -I ._Ref.. Lownsbury & Assoc. W p , Drawing No. r ri ° "' r -��� NSK 6.01—d672 ���p-�E • _. ....- __..., • O. ~• . - - - ----- __ S1.06.PIPfle -)ft11-1,1o. -- - ...--- •:----:._ - -- ------ -------,--k?.tilvdg-(N) i Y X I 0,051,151,32 409,920,46 70 29 40,24160 150 14 45,4640 - 5056 107 15,50 -4-65,915;52 - 70 25 0,19252 - 5-0-7i4-46,60921--- 3040 1082 10 6051J41,59 4559)05970 2614364-- 150 14 45.7557-$-' 5025 1087 13,60 • 4 , 6;01;1- 6:4 46990567-- 770 25 40.0945 150 14 4,U7°9 5020 1092 13150 6.,(.*1,13 ,.45- --465A0,14 7() 29 46,04555 - 150 14-46,04252--5016 • 140---;14,60 6 - 0,05f,126,51 459,695,50 70 29 4,m60 1 1",i 144C 1671:35 3010 1102 13,40 iiii 7---- 0,0571,115,75 459,5557,15 70 25 45:5709- 150 14 4655679 2997 1115 15,50 8 - -50-3f,105,73 ----4.06713.21 70 29 45,52192 150 14 45.70503 2992 1120 1$,50 9 6,05-1,-103./6--465;675:,-26 70 29 45.77)54 150-11 45.6,4514 2957 1125 15,50 ---10 6;051,096,75 . 469,605,56 70 2546,72256 150 1440,99179 2962 --114-0 15,50 11---- .5,051,095,54 465,565,59 - . 7.0 25 45,07556. 150 14 A7.13750 2977 1135 15,50- !1.1_043.0.a •49P,58 47 - -70 2945.62496 18014 47:28174 2972 1140 -13- -6,051,070,MP-469,6 ,}3f 70 299 .-407 1W-1-4 47,05256 ----2960 1152. 14 6,051,01109 459,040,57 70 29 4$-,442 15014 47Ti9170 ---2955 '11-57 15 --- - 6,051,006,15 - 459,655.96 70 25 46,4005$ 150 14 41.54166- 2950 11-62 15:60- . 16 6,051,00,15 - 409,851,04 - 70 25 45:55145- 160 14.46,0858O -2945 1167 15,50 -17- 6,05'1,056,25 459,526,11 - 70 29 45,30277- 150 14 40:23O2 t----MD- '11 72 15,50-- • 18 603105-1:27 4556:21--,16-- 70 25-425555 150 14 46,57455 25:55 • 1177 • 15,50 __.;.9-- - 6,-05101,62 ---459606,50 - 7-0 3-4,1-Z 6-6----1-60-i44fao 2922 - 11 o-f-- 10 20 6;051,055,50 4C9,6034 -.ion 46.47611 1 $:;) 14 46:5°Q6-1--.2917 1194 I-5-,50 21 6,031,02e,53. •4.69,798627- 70 29 45,02.90150-171 4-5:05.55.2 2912 1190 15,50- -22- 6,01,023-, 6: --407 a,--67 ' 70 29 44,55014 150)4-49:16144 - 2907 1204 14: 0 • • 26 6,051,016.57 •459,756.76 70 29 44,55067 150 14 45,52557 2902 , 1209 1$-,50 • 24n2$4-4,t3W,E4 -1-50 14 45,49-50 2597. • •1214 15,50 • . : ..,--ATio;;;„,..•-•-•••,...7,5, 1 . - -7" - ar:C'j;",--- -4:1-17 14,- . , i • I • :.•. : 9 7 ii* 0 _..4 * .-. . • ? tre.A .P;Nip GTD*evis :14):_jif • :if...a.4027-.::z I 446 1No alum 1 4 44.- %. •-•':P or 1 49 p ..•...0... 40....r. :."'.11%4 -4 . ,i,-..e.fe, -!!.-. %.!orts z 1 ad PA.1.1' air "%1, rli. 1 , 1 -..tX.Z• k--'-'s"'' ...; 7 Notes; - :',I :i::7•7':: .7' 1: ricyctrvr4 ore t,oeed on 6F MC4r1 SCO Levol, _ i. _ 2, Coordinotcf. ore loceed Qn AlC,5k0 mote none Nod 27, Zon-e 4, 3, Al1 cone 9 re within Protrooted Section 11, Pioneer Nclurol Reg9uces JOE NAME: Ocpv vroc prm it Conciv.ctor . DRAWN 5Y; DL CHECKED BY: MJD ' LOCATION; ProtroctedStctign 11 SCALE; NVA - Townf-hip 13 North 1 . Ronve 7 ro4t DATE; 7-12-07 urnict mcridign • • NA,tiu-(5-- )OE3 INO, !HET . .. .. _ . )ESCRIPTION: ik*-built Coordinote,5 ()f)204 3 of 4 • Ale ke Siete Plene • Section Line Offset -We11`14., Y X L;tice-{ A- -c 0it::ee-;>Nj=_FS p-gid-El 25 6,031,128.32 469,943.64 70 29 46.01630 150 14 44.77930 3013 1055 7, 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 45.06695 ' 300 1065 .13.50 28 6,031,113.39 469,92E86• 70 29 45.66887 150 14 45.21260 2997 . 1070 13.50 29.- 6,031,108.44 460,923.95 , 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 4E9,906.38 70 29 45.6-1431 150 14 45.87163 2975 1092. 13.50 32 6,031,025.68 469,901.39 70 29 45.89523 150 14 46.01793 2970 1097 13.50 33• 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 1 2965 1102 _13.50 . 34 • 6,031,075.73 469,891.57 70 29 45.49698 1150 14 46.30581 2960 . 1106 13.50 35 6,031,070.76 4£9,E86.60 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 ' • a , 3,"1-0..,.... - 69,8-C9. ' --0-29-45.27251 10-1-4--46-9-6 . 2(117 11_ 13.50 • 386,031,047.99 4864.14 70 29 45.22304 150 14 47.10995 2932 1134• 13.50 39 } £9,6,031,043.03 469,659.20 70 29 45.17406 150 14 47.25478 2927 • 1139 13.50 40 6,031,038.10 469,654.21 70 29 45.12537 150 14 47.40108 2922 .•1144 13.50 • 41 6,031,033.05 469,649.29 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 47.6E925 2912 1154, 13.50 • 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2699 1166 13.50 44 6,031,010.49 . 469,826.79 70 29 44.E5272 150 14 48.20493 2E94. 1171 • 13.50 45 - 6,031,005.53 4E9,821.86 70 29 44.60373 150 14 48.34946 2689 1176 13.50 46 6,031,000.54 4E9,816.94 70 29 44.75446 150 14 48.49369 - 2884 1181 13.50 •47 6,030,C95.50 469,811.98 70 2944.70469 150 14 48.63910 2579 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 • 1191 • 13.50 • OF Q( �1i SURVEYORS CERTIFICATE-• -. 'sE, ....•,••4Vo 1 ---.r,y •_ _ _ � 1 HEREBY CERTIFY THAT I AM o*1'94Q1)-1 - s •� �'? 1 PROPERLY REGISTERED-ANCf----"--- -- ao l 4 a 1 H 0 LICENSED TO FRAC710E LAND - .,,-cet ' = �•'� "f �... I SURVEYING IN 7HE STATE OF 5 •... • • . . . __.- ALASKA AND THAT THIS PLAT /iX REPRESENTS A SURVEY DONE BY '" s=- `' :y.4 Ne.Af i� .".-'4•3 ME OR UNDER MY SUFERVISION 'r,�. �j 's�a•ti••.« 4 AND THAT I BELIEVE THAT ALL " ` - r y �L: ��1t�orr„ItNA '"°� DIMENSIONS AND OTHER DETAILS 1 '�, '$�•=. 11.�,,,,,d ARE CORRECT AS SUEMITTED TO - ..r , ?' ME BY NANUO. INC. AS OF JULY . 12TH, 2007. Pioneer Noturol Resouces JOE NAME:' Oocouruk Drill Site Conductors DRAWN BY: BL I CHECKED BY: MJD. L OCATION: Protrocted Section 11 SCALE: N/A Township 13 North Ronne 7 East DATE: 7-12-07 Umiot Meridian . • NANUQ JOB NO. SHEET • ►ESCRIPTION: • As-built Cocrdinotes05204 4 of 4 TRANSMITTAL LETTER CHECKLIST WELL NAME 7J3v PTD# 20 7 — 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 function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing _ program. Rev:7/13/2007 Y 7 k(h To co n m0 m o L. c 0 N N a) m -o, ' rn Z c c-N c: c m, N m .5 m a o. w m C 2 Q a) . � o. C c'c0 a, f0 of . n . `� C'l 3 7. 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O' N N' �' �' ° c' 0' +O. o' o' C' a0j o' o N O �' N co C _C m o N a , C, W Ep 05 1- N aa' N' N: �: „: O, 7: 7: a C. a C: p' O: e' .N.. .fp' Y' a ay �' 0' -0 (6' E O) O' ' V)' '-' 7' C' °' O' U a Q U, O), �� • O O Of N N VN,, fa0, •t.., r a), a 0) OS N' �' rn '0' p' N' oS C U. ?�: N: :�: 'p: p. N. c: L, lL W c 3 A C, IS a ) U N, C co a. a. a. v. w a a y: N N >. • rn CD -C' N' E a L (Ti O Us O O .fl C• '0 C' E was W N 2 ),, a?: N °., ° , o• L: c. c: •,..--, Cl) CNi: c ° 0 '0 O 'v) __ 3: • .4 0, C o. N m •c N. c. w 7. 3 3 8 (0 N '. f0 v 7 >' O O, '0. `° O. -O .2 d, a y' N' -• c. .0 3 ''' o C; N'O C, a) a 00 a 0, o` 0 C) �. `m 0 - o C, )), N, o, o, - p) (°' a`. (o: r. 0) 6: O: '3• N. c 0 m 0 a �, N, 7 - •U. '> N, N a -. N. a V: -0, N' > > 3 C aN a N , W W. a). `, y .0 ' a 2: N �, J >, d a, *c N m N 7 0 0. a E aa, co,cy. 3, �' o 0; c I- i- 2' a v. 'o 0 `a 0 O L; ° °• a U,' aa`) m, .co 0, a2, 0, m ai M, c a: -J, D, �; �, CO �, O, O a a, v, �; Q a z; c), co U c) c�; c), Q, — Q o', m m c.), �', N, 2, a o, �, (n, c), a w w , 03 °• o e- N CO V• 'f) CO N. CO o) 0 ,- N M V• u) CO I-- CO O) 0 i' E 4- N CO V' 'O co h co 0 O N N N (N N N N N N N CO CO CO CO M �M co co CO 0 O NN NO c O N O O O) O c a a--- yC N N O Z n i •C O•' Or.p ao N >, N(V .c N O E o \�� E a C a W r) a , �(� I CI- Q Q N ill Q H C) Q w Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 2:32 PM To: 'Franks, James' Subject: RE: General question: Well name change? (PTD 207-182) Look at 20 AAC 25,015(b)(1). From the information you provided, it appears that a new permit application is needed, Call or message with any questions.. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks©pxd.com] Sent: Monday, October 20, 2008 2:16 PM To: Maunder, Thomas E (DOA) Subject: RE: General question: Well name change? (PTD 207-182) Lots-certainly 710,000' lateral difference for the toe of the well and-200'ND. I don't have specific numberc, but I can get them. We are changing pool horizons, the original well is on the east side of the fault block and the new well is on the west side, the new well would be a producer and the old well was an injector...hmmm, could I change anything else?0 Sorry for this,...again„. James Franks Sr. Drilling Engineer Pioneer Natural Resources Alaska 907,34'3 2179 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 20, 2008 2:10 PM To: Franks, James Subject: RE: General question: Well name change? (PTD 207-182) James, What is the relative BHL change(laterally and vertically)? Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks@pxd.com] Sent: Monday, October 20, 2008 1:40 PM To: Maunder, Thomas E (DOA) Subject: General question: Well name change? (PTD 207-182) Tom, Question: How do I go about changing the name of a permitted well? I would like to change the name from ODSK-36i to ODSN-36- I know you do not care about the "i"-a new permit for the new BHL will be requested this spring. Am I correct in guessing that this request for a name change would be done with a 10-403 and checking the 'other' box? 7/5/2009 VO '�`'C9 T Page 2 of 2 Background: Pioneer Natural Resources permitted a well we called ODSK-36i (PTD 207-182) back at the end of last year and drilled and cased the surface hole under this name and permit to drill#. Since then, we have re- evaluated the placement of the injection point and have mode this Kuparuk injector to another slot. As such, it leaves this slot and surface casing open for a Nuiqsut Producer that we plan on drilling after the 1st of next year (on the current schedule). By changing the name to ODSN-36, it will help Pioneer Natural Resources and the AOGCC with sorting of data and noting the specific pool the well is in. Thanks for your time. fames James Franks Sr. 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. 7/5/2009 Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 16, 2008 3:04 PM To: 'Vaughan, Alex' Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: RE: Current Oooguruk Well Status as of 10/16/2008 Alex, et al, Thanks much for the updated information. Looking at the information and cross checking our files, I only found one well that may need some paperwork filed; ODSN-39. If no activity is likely on this well until springtime, it is appropriate for Pioneer to file a 404 with attachments for the operational SD as was done with K-35, K-36 and N- 34. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan@pxd.com] Sent: Thursday, October 16, 2008 2:09 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: Current Oooguruk Well Status as of 10/16/2008 Tom, Well Name PTD Completion Date- Comment Status ODSDW 01-44 207-140 1/27/2008 Active Disposal Well ODSK-35 207-181 2/12/2008 Surface Casing Set --$ ODSK-36i 207-182 2/4/2008 Surface Casing Set ODSK-33 207-183 4/29/2008 Active Kuparuk Producer ODSN-34i 207-184 2/17/2008 Surface Casing Set ODSN-31 208-003 n/a Not Spudded ODSN-32 208-004 n/a Not Spudded ODSN-40 208-039 8/1/2008 Active Nuiqsut Producer ODSN-39i 208-040 5/7/2008 Surface Casing Set ODSN-45i 208-100 10/15/2008 Intermediate Casing Set, temporarily abandoned, likely to be side tracked ODSN-43 208-139 n/a Not Spudded ODSK-41 208-147 n/a Not Spudded, Spud 10/16/2008 ODSK-38 208-148 n/a Not Spudded ODSN-37 n/a n/a Not Spudded The following is the current schedule as of 10/16/2008. We will be submitting the ODSN-37 Surface Casing Depth Change Sundry middle of next week. Drill Start Das Drill End Date y Date 10/20/2008 Page 2 of 3 ODSN-45i - IN13 - S,l -AOGCC approved 8/2/209;, 74.0 Jut1 /2bt18 ODSK-41 - Kup F (Horiz) -S 6.4 10/21/2008 ODSK-38i - Kup D (Slant) S 10/2112008 5.8 10/274908 ODSN-37- PN8 -S 10/2712008 5.7 11/2/2008 ODSK-38i - Kup D (Slant) - P,C 11/2/2008 15.1 11/17/2008 ODSN-37- PN8 - 1 11/17/2008 13.0 11/30/2008 ODSK-41 - Kup F (Horiz) I,P,C 11/30/2008 32.9 1/2/2009 Alex Vaughan Operations Drilling Engineer NEER 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. 744,144, P°e P66/4 Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer j o e.poly a�(.zlpxd.co m Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 14, 2008 10:01 AM To: Maunder, Thomas E (DOA); Polya, Joe Subject: RE: Current Oooguruk Well Status - Again Joe, I know you have been busy with ODSN-45, but I would appreciate if you or one of your staff could fill out the table below. Thanks in advance. Tom Maunder, PE AOGCC 10/20/2008 Page 3 of 3 From: Maunder, Thomas E (DOA) Sent: Friday, October 03, 2008 12:00 PM To: Polya, Joe Subject: Current Oooguruk Well Status Joe, As you know, I am reviewing the permit applications for ODSK-41 and -38. In the course of that review, I have prepared a list of the permits issued to date for the Oooguruk project. I realize that Pioneer has encountered drilling difficulties that have resulted in halting operations on some of the wells. Also, halting operations was planned due to the seasonal drilling restriction for some of the Kuparuk wells. Would you or one of the engineers complete the following table for the ODS wells? I have included the information I have available. It is possible that I have not seen all the paperwork that has been filed. I am particularly interested in wells that have been spudded and then operations halted. I expect that we will exchange a few messages to get things all filled out. Call or message with any questions. Tom Maunder, PE AOGCC Well Name PTD Completion Date- Comment Status ODSDW 01-44 207-140 1/27/08 WDSP1 ODSK-35 207-181 ODSK-36 207-182 ODSK-33 207-183 4/29/08 1-oil Initial production well. ODSN-34 207-184 ODSN-31 208-003 ODSN-32 208-004 ODSN-40 208-039 8/1/08 1-oil ODSN-39 208-040 ODSN-45 208-100 ODSN-43 208-139 ODSK-41 208-147 Permit under review ODSK-38 208-148 Permit under review Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 10/20/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, May 30, 2008 1:40 PM To: 'Kathy Campoamor' Cc: 'Hazzard, Vance'; Polya, Joe Subject: Operations Summary Detail Kathy, I am reviewing the 404s recently submitted for the OSDs on ODSK-36 and ODSN-34. In the future, please send the detailed hour breakdown. Since further work will be accomplished on these wells, there is not a need to send the detailed summary at this time. Call or message with any questions. Tom Maunder, PE AOGCC 5/30/2008 I"[CI,CIVCLJ STATE OF ALASKA MAY 2 8 2008 ALASKA OIL AND GAS CONSERVATION COMMIaSION REPORT OF SUNDRY WELL OPERATIONSIaska Oil & Gas Cons. Commission Anchorage 1.Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown s • Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development ❑ Exploratory❑ 207-182 • 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service E 6.API Number: Anchorage,AK 99501 50-703-20561-00 • 7.KB Elevation(ft): 9.Well Name and Number: 58.04' ODSK-36i • 8.Property Designation: 10.Field/Pool(s): ADL 355036 • Oooguruk Kuparuk Undef • 11.Present Well Condition Summary: Total Depth measured 3683 feet Plugs(measured) N/A true vertical 3027 feet Junk(measured) N/A Effective Depth measured 3664 feet true vertical 3013 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 106' Surface 3625' 9-5/8" 3666' 3015' Intermediate Production Liner Perforation depth: Measured depth: True Vertical depth: Tubing:(size,grade,and measured depth) 2-7/8", 6.5# L-80 IBT-M 1897'MD Packers and SSSV(type and measured depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure • Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run X Exploratory❑ Development ❑ Service Q Daily Report of Well Operations X 16.Well Status after work: Oil❑ Gas ❑ WAG I1 GINJ ❑ WINJ ❑ WDSPL ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Joe Polya,343-2111 Prepared By:Kathy Campoamor,343-2183 Printed Name Joe.Pfolya / I Title Sr.Drilling Engineer Signature V ps1'/ J "1 p�_ �� 502 '�//�0 ` Phone 343-2111 • Date ©j/7,0/CF .r Form 10-404 Revised 04/20060 RIGINAL 8MS BR- JUN 0 ) 2008 ,SOal Only "� 5I S ,7:;'u and ngi�- sId. Pioneer Natural Resources Alaska Inc ODSK-361 Permit#207-182 Operations Summary _Rig:Nabors#19AC PIONEER Spud Date:01/30/08 NATURAL RESOURCES Drilling Total Measured Mud Weight Date Progress(ft) Depth(ft) (ppg) Description of Operations 1/28/2008 0 0 0.00' RD&PREPARE PAD FOR RIG MOVE TO ODSK-36i.MOVE&SPOT RIG.RU LINES,OUTSIDE STAIRS EQUIPMENT&ORGANIZE PAD.RIG ACCEPTED 1800 HRS.NU 21-1/4"DIVERTER SYSTEM. NU DIVERTER SYSTEM.HOIST 2-50'SECTIONS OF 16 DIVERTER LINE&MU TO KNIFE VALVE. 1/29/2008 0 0 9.00 RECONSTRUCT DIVERTER LINE SUPPORT BRACKETS.TOOK ON 500bbIs SPUD MUD TO RIG PITS FROM RSC.UNTHAW FROZEN WATER LINES.PERFORM DIVERTER FUNCTION TEST-OK.STATE WAIVED WITNESS.FILL&CHECK DIVERTER&MUD LINES.PU BHA#1 TOOLS&PREPARE TO SPUD WELL.LOAD PIPE SHED WITH 9-5/8"CASING. 1/30/2008 1383 1383 9.30 PU&MU BHA#1&RIH.CIRCULATE RISER&LINES.RU WLRELINE UNIT&HANG SHEAVES.DRILL 12-1/4" SURFACE HOLE.POOH 2 STANDS HWDP&PU/MU REST OF BHA#1&ORIENT.RIH&GYRO SURVEY. CONTINUE TO DRILL AHEAD T/1383'. 1/31/2008 1931 3314 9.50 DRILL 12-1/4"SURFACE HOLE F/1,383'T/3,314'.SURVEY AS REQUIRED w/EM MWD.ALL 9-5/8"CASING STRAPPED&IN PIPE SHED.TOTAL OF 50 JTS OF 2-7/8"TUBING STAGED FOR KILL STRING. DRILL F/3314'T/3646.CIRC HOLE FOR GEOLOGIST TO EXAMINE SAMPLES TO CORRELATION.DRILL F/3646' 2/1/2008 369 3683 9.50 T/3683'.CIRC&COND FOR WIPER TRIP.POOH FOR GAMMA RAY.TIGHT SPOT @ 3590'.CONTINUE TO POOH T/3216'.PUMP DRY JOB,TIGHT SPOT©2040'.POOH T/200'.TIH F/200'T/1882'.CIRC&COND TIGHT SPOT AT 1882'.TIH F/1882'T/1924',TIGHT SPOT.WASH&REAM F/1924'T/3602'.SURVEY @ 2682',2779', 2875'.NOTE:TVD CHANGE PER GEOLOGISO FORMATIONS COMING IN nFFOFR WASH&REAM F/3663'T/3683'.CIRC&COND HOLE PUMPING SWEEPS.POOH,HIT TIGHT SPOTS.WENT 2/2/2008 0 3683 9.60 BACK TO BOTTOM.CIRC&COND HOLE,PUMP SWEEP. POOH&WORK THROUGH TIGHT SPOTS.CIRC& COND,PUMP DRY JOB.POOH,LD BHA.RU CASING EQUIPMENT,MAKE DUMMY RUN WITH CASING HANGER/LANDING JT PU&RUN 9-5/8"CASING.CHECK FLOAT EQUIPMENT&RUN CASING T/1282'. RUN 9-5/8"CASING F/1882'T/3619'.PU/MU HANGER&LANDING JT&LAND.MU CEMENT HEAD,BREAK 2/3/2008 0 3683 9.50 CIRC.CIRC&COND WELL.TEST LINES j&CEMENT CASING WITH 324bbIs,10.7ppg LEAD&42bbls 15.9ppg • TAIL.DROP TOP PLUG&PUMP 10bbls WATER.RD CASING TOOLS&LANDING JT.FLUSH&CLEAN WELL, POOH. 2/4/2008 0 3683 8.50 ND DIVERTER SYSTEM.SPOT&INSTALL WELLHEAD EQUIPMENT IN WELL BAY.RUN 2-7/8"TUBING T/1903', • RILDS.NU TREE&TEST.TEST 9-5/8"CASING TO 3500psi FOR 30 MIN. FREEZE PROTECT WELL WITH DIESEL.RD&PREPARE •- - V• - - y' I - . Pioneer Natural Resources Alaska Inc. 1 ODSK-36i Ops Summary for 10-404 • Halliburton Company Survey Report Company: Pioneer Date: 3/10/2008 Time: 02:41:26 Page: 1 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSK-36,True North Site: Dooguruk ODS Vertical(TVD)Reference: ODSK-36 58.0 Well: ODSK-36 Section(VS)Reference: Well(0.00N,0.00E,151.08Azi) Wellpath: ODSK-36i Survey Calculation Method: Minimum Curvature Db: Oracle I Field: Pioneer ASP Zone 4 I Map System:US State Plane Coordinate System 1927 Map Zone: Alaska,Zone 4 1 Geo Datum: NAD27(Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSK-36 Slot Name: Well Position: +N/-S -84.37 ft Northing: 6031065.83 ft Latitude: 70 29 45.399 N +E/-W -38.87 ft Fasting: 469881.69 ft Longitude: 150 14 46.595 W Position Uncertainty: 0.00 ft Wellpath: ODSK-36i Drilled From: Well Ref. Point Tie-on Depth: 44.54 ft Current Datum: ODSK-36 Height 58.04 ft Above System Datum: Mean Sea Level Magnetic Data: 2/4/2008 Declination: 22.69 deg Field Strength: 57617 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From(TVD) +N/-S +E/-W Direction ft ft ft deg 44.54 0.00 0.00 151.08 Survey Program for Definitive Wellpath Date: 11/3/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft i 100.00 263.00 ODSK-36 Gyro(100.00-263.00) CB-GYRO-SS Camera based gyro single shot 305.49 3634.04 ODSK-36 MWD+Sag+IIFR+MS(305.4 MWD+Sag+CA+IIFR+MBWD+Sag+CA+IIFR+MS i Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 44.54 0.00 0.00 44.54 -13.50 0.00 0.00 6031065.83 469881.69 TIE LINE 100.00 0.38 330.00 100.00 41.96 0.16 -0.09 6031065.99 469881.60 CB-GYRO-SS 173.00 0.34 6.40 173.00 114.96 0.58 -0.19 6031066.41 469881.50 CB-GYRO-SS 263.00 0.12 82.32 263.00 204.96 0.86 -0.07 6031066.69 469881.63 CB-GYRO-SS 305.49 0.34 85.09 305.49 247.45 0.88 0.10 6031066.71 469881.80 MWD+Sag+CA+IIFR+MS 395.69 1.67 137.26 395.67 337.63 -0.06 1.26 6031065.76 469882.95 MWD+Sag+CA+IIFR+MS 489.49 4.21 129.08 489.34 431.30 -3.24 4.86 6031062.57 469886.54 MWD+Sag+CA+IIFR+MS 580.19 5.08 122.30 579.74 521.70 -7.48 10.84 6031058.30 469892.50 MWD+Sag+CA+IIFR+MS 671.09 6.36 126.84 670.19 612.15 -12.65 18.27 6031053.10 469899.91 MWD+Sag+CA+IIFR+M$ 764.09 6.03 126.15 762.65 704.61 -18.62 26.34 6031047.10 469907.95 MWD+Sag+CA+IIFR+M 859.46 6.88 128.79 857.41 799.37 -25.16 34.84 6031040.54 469916.42 MWD+Sag+CA+IIFR+M 948.89 7.50 128.01 946.14 888.10 -32.11 43.61 6031033.55 469925.17 MWD+Sag+CA+IIFR+M 1043.47 9.23 133.51 1039.71 981.67 -41.13 53.98 6031024.49 469935.49 MWD+Sag+CA+IIFR+MS 1139.86 11.67 130.99 1134.49 1076.45 -52.85 66.94 6031012.72 469948.41 MWD+Sag+CA+IIFR+MS 1236.31 15.41 132.58 1228.25 1170.21 -67.92 83.75 6030997.58 469965.16 MWD+Sag+CA+IIFR+MS 1286.85 18.40 133.47 1276.60 1218.56 -77.96 94.48 6030987.50 469975.85 MWD+Sag+CA+IIFR+MS 1 1332.90 20.25 132.03 1320.05 1262.01 -88.29 105.68 6030977.12 469987.00 MWD+Sag+CA+IIFR+MS 1429.60 23.87 135.45 1409.66 1351.62 -113.45 131.85 6030951.86 470013.06 MWD+Sag+CA+IIFR+MS 1477.42 27.27 133.74 1452.79 1394.75 -127.92 146.55 6030937.33 470027.71 MWD+Sag+CA+IIFR+M 1526.07 29.56 132.65 1495.58 1437.54 -143.76 163.43 6030921.42 470044.52 MWD+Sag+CA+IIFR+M 1623.06 33.50 131.69 1578.23 1520.19 -177.79 201.03 6030887.25 470081.98 MWD+Sag+CA+IIFR+M 1719.39 38.04 132.23 1656.37 1598.33 -215.44 242.88 6030849.43 470123.67 MWD+Sag+CA+IIFR+M 1816.39 39.04 132.22 1732.24 1674.20 -256.05 287.64 6030808.64 470168.26 MWD+Sag+CA+IIFR+MS 1913.59 38.51 133.70 1808.02 1749.98 -297.53 332.19 6030766.99 470212.63 MWD+Sag+CA+IIFR+MS 2008.16 36.95 136.81 1882.82 1824.78 -338.60 372.93 6030725.75 470253.21 MWD+Sag+CA+IIFR+MS 1 2104.63 38.08 140.89 1959.35 1901.31 -382.83 411.55 6030681.37 470291.64 MWD+Sag+CA+IIFR+MS 2201.79 39.39 147.75 2035.18 1977.14 -432.18 446.92 6030631.89 470326.81 MWD+Sag+CA+IIFR+MS 2298.10 41.01 151.13 2108.74 2050.70 -485.71 478.49 6030578.24 470358.16 MWD+Sag+CA+IIFR+MS 2395.99 40.88 152.82 2182.69 2124.65 -542.33 508.63 6030521.50 470388.07 MWD+Sag+CA+1IFR+MS Halliburton Company Survey Report Company: Pioneer Date: 3/10/2008 Time: 02:41:26 Page: 2 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSK-36,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSK-36 58.0 Well: ODSK-36 Section(VS)Reference: Well(0.00N,0.00E 151.08Azi) Welipath: ODSK-36i Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lad Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2491.69 42.54 154.78 2254.13 2196.09 -599.46 536.72 6030464.26 470415.93 MWD+Sag+CA+11FR+MS 2587.89 44.85 156.23 2323.68 2265.64 -659.94 564.26 6030403.68 470443.21 MWD+Sag+CA+IIFR+MS 2634.69 47.29 157.78 2356.15 2298.11 -690.96 577.41 6030372.60 470456.24 MWD+Sag+CA+1IFR+M$ 2684.49 51.29 157.87 2388.62 2330.58 -725.91 591.66 6030337.60 470470.34 MWD+Sag+CA+IIFR+MS 2732.32 53.75 159.28 2417.72 2359.68 -761.25 605.51 6030302.21 470484.05 MWD+Sag+CA+IIFR+M 2780.97 55.96 162.61 2445.73 2387.69 -798.84 618.48 6030264.57 470496.87 MWD+Sag+CA+IIFR+M 2828.33 56.38 162.38 2472.10 2414.06 -836.36 630.32 6030227.01 470508.55 MWD+Sag+CA+IIFR+M$ 2877.90 57.18 163.23 2499.26 2441.22 -875.98 642.57 6030187.34 470520.65 MWD+Sag+CA+IIFR+M 2974.20 57.45 166.81 2551.27 2493.23 -954.25 663.51 6030108.99 470541.27 MWD+Sag+CA+I1FR+MS 3070.46 53.94 166.00 2605.52 2547.48 -1031.53 682.19 6030031.65 470559.63 MWD+Sag+CA+I1FR+M 3166.76 49.33 165.38 2665.27 2607.23 -1104.68 700.84 6029958.43 470577.97 MWD+Sag+CA+11FR+MS 3263.52 47.48 164.96 2729.50 2671.46 -1174.63 719.35 6029888.42 470596.21 MWD+Sag+CA+11FR+MS 3360.89 46.77 162.67 2795.76 2737.72 -1243.15 739.23 6029819.82 470615.81 MWD+Sag+CA+IIFR+Ma 3457.75 45.27 162.67 2863.02 2804.98 -1309.68 759.99 6029753.21 470636.29 MWD+Sag+CA+IIFR+MS 3554.25 42.57 163.25 2932.52 2874.48 -1373.67 779.61 6029689.15 470655.65 MWD+Sag+CA+11FR+M 3634.04 42.77 162.93 2991.19 2933.15 -1425.41 795.34 6029637.35 470671.17 MWD+Sag+CA+11FR+M 3683.00 42.77 162.93 3027.13 2969.09 -1457.19 805.10 6029605.53 470680.80 PROJECTED to TD ODSK-36i Batched Surface Casing Proposed Completion Well Head: 9-5/8",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor L 162'MDrkb/106'TVDss Diesel to 1897'MD 2-7/8"6.5#L-80 IBT-M Tubing 1897 MD/1800'TVDrkb Seawater 9 5/8",40#L-80 BTC,8.835"ID 3664'MDrkb/3013'TVDrkb TD of 12-W Hole @ 3683'MDrkb/3027'TVDrkb Date: Revision By: Comments rtit) 2/5/2008 JDF Batched Surface Casing ODSK-36i Batched Surface Casing Schematic PIONEER NAEURAL RESOURCES Page 1 of 1 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, April 05, 2008 12:44 PM To: 'Franks, James' Cc: Polya, Joe; Hazzard, Vance Subject: RE: Surface holes drilled to date - PTD (207-181), (207-182), (207-184) James, You are correct. A summary of the well operations conducted so far should be included as well. A sundry will need to be filed when operations resume on the wells. Call or message with any questions. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks©pxd.com] Sent: Friday, April 04, 2008 10:58 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: Surface holes drilled to date - PTD (207-181), (207-182), (207-184) Tom, As the ODSK-33 well has drug on, the later startup, the approaching restricted drilling season and no-flow ruling, these wells will need to be left in a suspended position until next winter. Below are the estimated times for re- entry. All the wells have surface casing set, a kill string in the well to below the permafrost, a tree installed and freeze protected with diesel. ODSK-35—(207-181)— 11/4/08 DSK-36i—(207-182)— 11/22/08 ODSN-34i—(207-184)— 12/31/08 We certainly wish that we could get back into them now, but are not going to be able to do so. From our phone conversation, we will generate a 10-404 and check the box for Operational Shutdown and include the survey and a schematic of the current well construction. Thanks for your time. Please let me know if this does not adequately reflect our phone conversation. 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. 4/5/2008 rage 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 08, 2008 9:28 AM To: 'Franks, James' Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207-184: Diverter Waiver Request for ODSN-34i v1 b'sx _ James, I just talked to Joe regarding the request. I am not sure. My review is only part of what occurs at the Commission. The review will start with Steve Davies the geologist and as Joe can attest, he is most thorough. I do have one request that will help my review. Could you send copies of the daily reports for the surface hole sections or at least the operational details? The only details I really don't need and do remove ifl get them is cost information. Thanks in advance. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks@pxd.com] Sent: Friday, February 08, 2008 8:49 AM To: Maunder, Thomas E (DOA) Cc: Polya,Joe; Hazzard, Vance Subject: RE: PTD 207-184: Diverter Waiver Request for ODSN-34i Tom, Following the ODSK-35 surface hole, we will be drilling the ODSN-34i surface hole. The next operation would be to drill the ODSK-33 well to production interval TD, so we have another surface hole to drill following the ODSN- 34i surface hole. If I update the information and submit a request for a diverter waiver for the ODSK-33 well, do you think that request might be possible to review? Estimate spudding that well -2/17 or so... Thanks for your time. james From: Maunder,Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 08, 2008 8:13 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207-184: Diverter Waiver Request for ODSN-34i James, et al, I will not be possible to turn this request around for the spud of ODSN-34. It should be planned to employ the diverter. If I understand the schedule, ODSN-34 should be the last surface hole for a while deeper sections are drilled. That break should give time to analyze your request. Call or message with any questions. Tom Maunder, PE AOGCC 2/8/2008 Yage 2 of 2 From: Franks, James [mailto:James.Franks@pxd.com] Sent: Friday, February 08, 2008 6:29 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: PTD 207-184: Diverter Waiver Request for ODSN-34i Tom, Attached to this note, please find a request for a diverter waiver on the ODSN-34i well—our next surface hole to drill and suspend. In the request, I have included the mud logging data for the surface holes of ODSDW01-44 and ODSK-36i. I will be leaving town this afternoon, so communications on this issue should be through Joe Polya, whom I have cc'd to this e-mail. Joe is currently on the slope and can be reached at 907-670-6649 or via e-mail. Thank you for your time and consideration on this issue. 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. 2/8/2008 Page 1 of Maunder, Thomas E (DOA) From: Franks, James[James.Franks@pxd.com] Sent: Friday, February 08, 2008 11:35 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe Subject: Oooguruk Diverter Waiver Request-Operational Summaries Attachments: 1-44 ops summary.pdf; K-36i ops summary.pdf; K-35 ops summary.pdf Tom, .910'1--V-k0 aph–‘%a airsh-`4s\ This should cover the operations summaries you wanted to see on the diverter waiver request. Take care, rr (� james 1►C�t� ' n `�r-S3' 4\ J c \ c i\t > csS v7Gc 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. 2/8/2008 ( Operations Summary Report ,iv- Name Contractor Rig Number Rig Release Date * ODSK-36i NABORS DRILLING 19 AC Job Category Spud Date Start Date End Date 1 , 'DEVELOPMENT DRILL 1/30/2008 1/28/2008 Operations Report 1 ' Report Start Date 'Report End Date 1/28/2008 1/29/2008 Start Time End rine I Dur(hrs) Op 1 - Step 1 Phase FM Comment 1 00:00 06:30 6.50 LOCATN PP Level pad/set rig mats.Start moving rig to well ODSK-36i. 06:30 10:00 3.50 MOB PP Final spotting of rig over well.Level sub&pit modules.Clean up pad. 110:00 11:00 1.00 MOB PP RU utility lines and stairs. 11:00 1112:00 1.00'SFTY CP Held Arktos evacuation drill for Island. • 12:00 18:00 6.00!MOB T 1PP RU utilitiy lines to RSC. Some lines froze/HES working on them.Install berm under CCU.Spot beaverslide base and lower slide.Install pipe shed skate ramp,walkways&stairs. 18:00 00:00 T 6.00 BOPS PP NU riser&spacer spools.Held PJSM.NU surface Annular preventer&knife valve. Report Start Date Report End Date 1/29/2008 1/30/2008 Start Time End Time KMall Op i Step Phase I P/N ( Comment i 00:00 '13:30 13.501 BOPS PP NU 21-1/4"Diverter System.Install air boot on riser,&install mouse hole. i Hook up Hyd.lines to bag&knife valve.RU&MU turnbuckles.Change out kill line hose,&put heater trunk on knife valve,clean up cellar.Install 16" Diverter line w/crane,(had to cut loose&re-position diverter line brackets on top of well houses for line up),&clamp same.Function test Annular-knife valve.Install enviromental seal in rig cellar to well bay. Air up conductor air boot seal. 1 • • 113:30 20:00 6.50!MOB ;PN Moving 9-5/8"casing w/crane&staging.Un-thawing Seawater/Potable water , lines f/tank farm.Take on 500 bbls Spud mud to pits from RSC.PU BHA tools• to rig floor.Load pipe shed w/9-5/8"casing. 20:00 20:30 050 BOPS PP .Perform Diverter test per AOGCC requirements.Function bag/knife valve, (ok).Perform Accumulator test,(ok).All alarms/lights,and monitor's checked, (ok). ' 20:30 '22:30 2.00 MOB PN Continue to use crane to unload 9-5/8"casing from storage and stage for rig. . Continue to thaw out Sea/Potable lines,(insulate same&get heater trunks on pipe way).Re-configure staging area Herculite under CCU on rig for Guzzler trucks.Continue to haul mud from RSC to DS#4. i :Report S�2:0 :00:00 1.50 BHA T— IPP :PU&MU BHA#1 w/1.5 degree bent Motor&new MXL-1 12-1/4"bit/RIH. ' A Date Report End Date 1/30/2008 1/31/2008 • Start Time I End Time I Dur(Firs) I Op I Step l Phase PM f Comment -- 00:00 02:00 2.00 BHAPP Held PJSM-PU/MU BHA#1 (Steerable)-MU 1 std HWDP&Top Drive.Fill hole&check equipment for leaks,(ok). 02:00 ;03:00 ! 1.001BHA _ PP RU Gyro Wire line equipment,(hang sheaves,&install survey barrel). '03:00 06:30 • 3.50'DRLG `PP !Wash&Ream f/58-153',(Conductor shoe).Drill 12-1/4"Surface Hole, , i 1153-221',&CBU,(Blow down Top Drive).UP WT=46K,DN WT=48K,ROT • WT=48K.Pumping 450gpm=540psi,WOB=2-6K,TQ on=1K. 06:30 107:30 1 1.00 --- -- — — P (Install — TRIP , PP POOH 2 stds HWDP to MU rest of BHA#1. 1 07:30 �10:30 3.00 BHA PP MU rest of BHA#1 components, EM MWD into HOC&orient).TIH 2x I ,HWDP to Drill. 10:30 122:45 12.25!DRLG PP Drill 12-1/4"Surface Hole f/221-264'.LD single&Gyro survey,(15 min's). Drill ahead 264-1,383'@ 450psi,RPM=130,WOB=10-250K,TQ=1-2K, UP=58K,ROT=60K.Drilling 12-1/4"Surface hole.TADT=9.06hrs/ART= ! 4.34hrs&AST=4.72hrs 22:45 00:00 1.251 DEVSUR • PP Total Survey time while Drilling 12-1/4"Surface hole. Total of 4x Gyro surveys,(released©447').RD same while drilling ahead.EM surveys deemed good by Town MWD representative. Report Start Date Report End Date I 1/31/2008 2/1/2008 00:00 Time 1 00 End Time X 11.00 DRLG M Step Phase j PPDrill 12-1/4"Surface Hole,1,383-2,444'« ent 60gp =2,480psi off&150-200psi 1 ; Differential pressure.WOB=10-25K,80rpm=2K ft#'s off&4K ft#'s on • Torque.Up Wt=112K,Dwn Wt=88K,&Rot Wt=92K.ADT=6.23hrs,ART= 2.25hrs,AST=3.98hrs i ;11:00 .12:00 1.00'DEVSUR PP Total time for surveying,1,383-2,444',on every stand drilled down. www.peloton.com Page 1/3 Report Printed: 2/8/2008 �=`. 1�`' Operations Summary Report Start Tune l End Time t- Dur(hrs) ' Op 1 Step T Phase I PIN 7, Comment 12:00 23:00 11.00 i DRLG PP Drill 12-1/4"Surface Hole,2,444.0'-3314'w/65ogpm=2,480psi off& 150-200psi Differential pressure.WOB=10-25K,80rpm=2K ft#'s off&4K ft#'s on Torque.Up Wt=112K,Dwn Wt=88K,&Rot Wt=92K.ADT=6.23hrs, ART=2.25hrs,AST=3.98hrs Geology changed Target TVD from 2,998',to 3,030'©the Casing landing ' depth of 3,683'MD.The target changed was confirm ODE/Town Geologist, and change made©3,025'MD©19:17 hrs. 23:00 00:00 1.00 DEVSUR PP Total time for surveying,f/2,444'-3,314',on every stand drilled down. Operations Report _— J Report Start Date Report End Date 2/1/2008 2/2/2008 _ Start Time 1 End Time 1_ Dur(hrs) 7 Op 1 Step I— Phase PM Comment ' 00:00 '04:30 4.50 DRLG IPP Drill 12-1/4"Surface Hole,3,314'-3,646'w/650gpm=2,800psi on,2,500psi off,' 150-200psi Differential pressure.WOB=10-25K,80rpm=3K ft#'s off,5K ft#'s on Torque.Up Wt=118K,Dwn Wt=98K, Rot Wt=95K.04:30 05:00 0.50 CIRSMP PP Circ hole for geologist to examine samples for correlation. 05:00 '05:30 0.50 DRLG PP Drill 12-1/4"Surface Hole,3,646'-3,683'w/650gpm=2,500psi on,2,800 off& 150-200psi Differential pressure.WOB=10-25K,80rpm=3K ft#'s off&5K ft#'s on Torque.Up Wt=118K,Dwn Wt=98K,&Rot Wt=95K.ADT=3.36hrs, ART=2.38hrs,AST=.98hrs.Survey time=20 min. 05:30 07:30 ' 2.00 CIRCPP Circulate&Condition hole for wiper trip.Pump 65bb1 high vis sweep,circ.2 ! IBU until shakers cleaned up. 07:30 :16:00 ' 8.50!TRIP IPP 'POOH f/3683'-3605'Gama Ray @150 fph.Tight spot @3590',pulled 50k over,pump out ski.Cont POOH t/3216',pulling good.Pump dry job,tight spot @2040',pump out of hole to 200'@ 500gpm;50 rpm;115spm;1200psi;Blow I down top drive. :71600 .17:30 1.50:TRIP PP TIH w/HWDP&DP f/200'-1882'. 17:30 :18:30 1.00!CIRC PP Circ&Cond tight spot @ 1882'.500gpm;80rpm;1100psi. 18:30 ;19:00 0.50;TRIP PP TIH f/1882'-1924;tight spot. 19:00 ;00:00 5.00 RMWASH PP Wash&Ream f/1924'-3602'@ 500gpm;75rpm;1850psi.Survey @ 2682', I 2779',2875'. Report Start Date Report End Date — — 2/2/2008 2/3/2008 Start Time 1 End Time I Dur(hrs) 1 Op Step H Phase 1 PIN r Comment _ 00:00 00:30 0.50 i RMWASH PP Wash&Ream to BTM f/3663'-3683'. 00:30 '05:00 4.50!CIRC PP Circ&Cond hole circ @650gpm/moving pipe constantly.Pump 60 bbl weighted 12.6ppg-130vis sweep,pump 70 bbl high vis 200+sweep, 05:00 :07:00 2.00 TRIP :PN POOH 4 stds t/3295',tight.Work tight spot @3517'&3462'-pull 25K over. Work tight spot @3400'&3325'-pull 50K over.Pump out U 3295'.TIH back to I ! 3683'. UP WT=125K,DN=90K. 07:00 08:00 1.00''CIRC PN Circulate/Condition hole,pump 50 bbl/20#ppb Walnut+1 bag SAPP Sweep j II ! @ 700gpm/2800psi. 08:00 09:30 1.50 TRIP _ PP POOH,hit tight spots @ 3268'-3235',pulled 50K over working up&down, final PU WT 25K over.POOH to 2734'.MU Top drive. ! 09:30 ;10:00 0.501 CIRC :PP Circulate&Condition hole/pump 25 bbl dry job. : 10:00 ;12:00 2.00 STRIP IPP ,POOH(/2734'-180'.Hole took proper fill,no excess drag. 12:00 '14:30 2.50 BHA PP Stand back DC&MWD,retreive tool out of MWD.Break off bit and stand I ,back rest of BHA. II 14:30 19:30 5.00 CSG PP :PU/RU 9-5/8"casing tools&equipment,change out bales.PU/MU Casing fill ! l up tool.PU/MU 9-5/8"landing jt/hanger and make dummy run. 19:30 00:00 4.501 CSG PP PU 9-5/8"casing shoe jt,middlle jt,float collar jt and baker lock.MU to 8400 FT lbs.Fill/check float equipment.Run 9-5/8"casing to 1282'. !Report Start Date Report End Date 2/3/2008 2/4/2008 'Start Time(End Time 1 Dur(hrs) I Op Step Phase ; PM [ Comment ent 00:00 05:00 5.00 CSG i PP Run 9-5/8"casing f/1892'to 3619'.PU landing Jt&land casing shoe© 3665'.UP VVt=195K,DN WT=95K. y —---. _ ,hose to circulate. , 05:00 06:00 1.00 CSG PP Install cement lines,RD Franks tool.Blow down Top Drive,RU cement head/ 1 06:00 ,10:00 4.00 CIRC PP Break circulation w/ng pumps&reciprocate casing while establishing BPM I i w/step rate.Establish&hold each rate for 3-5 minutes before increasing to I ' ,next.Staged up to 1 BPM very slowly in 1/4&1/2 BPM increases.2 BPM= 300psi,3 BPM=500psi,4 BPM=550psi,5 BPM=750psi,6 BPM=1100psi,7 1 BPM=1350psi,8 BPM=1750psi.No loss circulation. www.peloton.com -- - - Page 2/3 Report Printed: 2/8/2008 k�.. Operations Summary Report 7 — — — Start Time(End Time I Dur(hrs) I Op Step Phase PIN Comment —1 i 10:00 14:00 ; 4.00 CSG PP PJSM for cementjob.Pump 5 BBLS H2O.Test lines to 3000psi si&chart. OK) i Pump 5 bbls fresh H2O,Pump 40 BBLS of 10ppg Spacer,324 BBLS of 10.7 ppg Lead Cmt.Drop Btm plug.Pump 42 BBLS of 15.9ppg Tail.Drop Top plug.Pump 10 BBLS of H2O.Switch to rig pump&displace cement w/ seawater @ 8bpm 1500-2000psi.Bump plug w/2630 stks,500 psi.CIP @ . 1340 HR.Recovered 70 bbls 10.7ppg cement. 14:00 118:00 4.00 CSG PP RD cement head,landing Jt,elevaters-spiders.CIO Bales.Flush&clean riser.Clean up&Clear Rig floor. .18:00 120:00 2.00 CSG PP RU Cellar w/pump for Seawater.TIH w/21 Stds DP @ 2023'to displace fluid by metal displacement only. 20:00 00:00 I 4.00 TRIP i PP POOH f12023'.Prepare to ND Diverter system. 1 Operations Report ----- , Report Start Date Report End Date 2/4/2008 1 2/5/2008 Start Time 1 End Time Our(hrs) I Op i Step _j Phase 1 PIN ; Comment 00:00 106:30 6.50 BOPS PP IND diveter system,remove equipment f/cellar.Pull landing jt&LD.Finish ND of diveter system!surface stack. 06:30 09:00 1 2.50 BOPS PP 1 PU and spot Vetco Grey multi-bowl in well bay for next well.Spot top valve for; i tree in well bay and test multi-bowl to 5000psi for 10 min.Clean up well bay. 11 09:00 710:00 1.00 TUBING PP RU to run 2-7/8"tubing. Hold PJSM. i ' 10:00 '14:00 4.00[TUBING PP Run 2-7/8"6.5#IBT-m to 1903' 14:00 17:00 3.00'TUBING • - PP MU VetcoGrey tubing hanger and land. RILDS. Test the hanger to 5000 psi- good. LD the landing joint and RD the tubing running equipment. Clear the floor 11 ,17:00 20:00 3.00 WLHEAD PP PJSM.NU tree/test void to 5000psi w/Vetco Grey hand. RU all lines for 11 1 casing test/well displacement of diesel for freeze protection. 20:00 21:00 1.00 CSG PP PJSM/line pumps on seawater and pump and confirm circ to pits!check lines.Close top valve on tree and pump down 9-5/8"x 2-7/8"annulus 8 bbls • @ 1/2 to 1 bbl min to 3500 psi on 9-5/8"casing test.Held for 30 min/Charted. (OK)Bleed off. 21:00 ,23:00 1 2.001 DPLACE PP Line up Nabors pump#1 w/diesel.Line up all valves f/tree and pump 155 bbls diesel @ 1-2 bbl min by reversing down 9-5/8"x 2-7/8"annulus and up i inside of tubing to Nabors pits,monitoring pit volume returned and volume pumped by gauging diesel tank.Shut down diesel&flushed pumps w/4 bbls. I i (Clear pump&lines).1 bbl of diesel returned to pits.Let equalize/shut both I valves.Blow down,ND lines. 23:00 00:00 1.00:WLHEAD PP ND all lines,clear/clean well bay area and cellar.Prepare for rig move to next I well#ODSK-35. RIG RELEASED @ 24:00 hr. 1 I it i • www.peloton.com — — Page 3/3 Report Printed: 2/8/2008 . 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. 9 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 01, 2008 2:08 PM To: 'Franks, James' Cc: Hazzard, Vance; Polya, Joe; OoogurukDrillingSupervisor Subject: RE: PTD 207-182 ODSK-36i Thanks James, I will put a copy of this message in the ODSK-36 file. Would you list the other wells that will be similarly equipped? Call or message with any questions. Tom Maunder, PE From: Franks, James [mailto:James.Franks@pxd.com] Sent: Friday, February 01, 2008 10:41 AM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Polya, Joe; OoogurukDrillingSupervisor Subject: PTD 207-182 ODSK-36i Tom, From a previous conversation between you and I, you asked that I send you a note if we were going to leave a kill string in the ODSK-36i surface casing for the time that it is suspended (permit approved without a kill string in place)...we are going to do just that. The plan would be as below and is similar to the next couple wells: 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 3683' MD/ 2995' 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 will 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 2-7/8" 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 2-7/8"tubing circulation string. 7. ND Diverter and NU wellhead. 8. RIH with enough 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 35 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. 2/1/2008 Page 2 of 2 We are currently at TD of the well at 3683' MD and performing a wiper trip prior to pulling out of the hole and running our casing. Please let me know if there is anything else you need or if you have any questions or comments. 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. 2/1/2008 70 n , , M J 7 Li-AA SARAH PALIN,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COM11IISSION 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-36i Pioneer Natural Resources Alaska Inc. Permit No: 207-182 Surface Location: 2951' FSL, 1117' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 834' FSL, 3637' FEL, SEC. 2, 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 (90 6.9-3607 (pager). 4trma • Chai - .n DATED this// day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. Page 1 of 1 Maunder, Thomas E (DOA) From: Franks, James [James.Franks@pxd.com] Sent: Friday, December 07, 2007 5:16 PM To: Maunder, Thomas E (DOA) Subject: ODSK-36i Tom, Sorry I missed you this afternoon. I wanted to be able to apologize for the last minute request for permit on the ODSK-36 well. There is a little story here and it has to do with the well orientation. Based on informal conversations with CP on the Fiord, our group found out that they had early water break through with their wells oriented perpendicular to their predominant fault structure. As such, at the beginning of this week, we decided that we should change our orientation to drill parallel to the Kuparuk fault structure (sound a bit familiar?:)) Our well planner did one heck of a job to rearrange the surface slots in such a short timeframe, but suffice it to say I did not even have a well path until this morning. That is my story and I am sticking to it. Due to the need to batch drill the surface holes for our development, I will likely be dropping off a couple more next week, fully with the understanding that you are going to be going on vacation on the 21st and I may not see them prior to your departure. What is the saying, poor planning on my part does not constitute a crisis on your part—something like that. In any case, if you see this prior to heading out for the weekend, have a good one and if you see this on your return to the office, I hope you had a good one. I am also going to be around until the 21st, so if there is anything you need from me, give a shout. Thanks in advance for the assistance. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907-343-2179 9/2/2009 PIONEER RECE1VFD NATURAL RESOURCES ALASKA,INC. December 7, 2007 C 0 ?HI AIsIII o f ii ; i is R 4otntnissinn Aofr State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK-36i Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM X = 469881.69, Y = 6031065.83, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a service well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be an injection well in the Oooguruk-Kuparuk formation. PNRA requests the permit to drill based on Pool Rules and an Area Injection Order turned in, but has yet to be approved. As indicated in the attachments, the drilling program will entail drilling a directional 121/4' surface hole to approximately 3,345' 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 8,154' MD / 6,053' TVDrkb. The horizontal injection interval will be drilled to 13,129' MD / 6,143' TVDrkb, the final TD of the well. The proposed casing program will utilize 9%" surface casing, 7" intermediate casing and 4 'A" slotted liner injection casing. The completion will utilize 3 IA" tubing. PNRA requests allowance to deviate from 20 AAC 25.412 (b) in setting the packer within 200' MD from the injection interval. PNRA requests to set the packer in the intermediate casing in a section covered by cement in the annulus and at an angle of —65 degrees to facilitate wireline and slick line operations. For this well, the set depth of the packer would be —900' MD / 150' TVD above the injection interval. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). ORIGINAL 700 G STREET, STE.600 • ANCHORAGE,ALASKA 99501 • MAIN: (907)277-2700 Alaska Oil & Gas Conservation Commission December 7, 2007 Page 2 of 3 PIONEER NATURAL RESOURCES ALASKA,INC. 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13). 4) A summary of drilling hazards per 20 AAC 25.005 (c) (4). r 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) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 7) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 8) The drilling fluid program as required by 20 AAC 25.033 is attached in this Application for Permit to Drill package. 9) Complete logging and mud logging operations are planned and descriptions are attached. 10) 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 joe.polya@pxd.com 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 7, 2008. If you have any questions or require further information, please contact Joe Polya at 907/343-2111. 700 G STREET, STE. 600 • ANCHORAGE,ALASKA 99501 • MAIN: (907)277-2700 Alaska Oil & Gas Conservation Commission December 7, 2007 Page 3 of 3 i7,. PIONEER NATURAL RESOURCES ALASKA,INC. Sincerely, Joe Polya Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: fDSD 1-44 Well File 700 G STREET,STE.600 •ANCHORAGE,ALASKA 99501 •MAIN: (907)277-2700 A: r :Vie ,` „, } Weekly Operations Report =... ODSK-36i PIONEER Permit No.#207-182 NATUf4AL fiESOUHCES Weekly Activities February 4, 2008 2/4/2008 3683' ND DIVERTER SYSTEM. SPOT& INSTALL WELLHEAD EQUIPMENT IN WELL BAY. RUN 2-7/8" TUBING T/1903', RILDS. NU TREE&TEST.TEST 9-5/8" CASING TO 3500psi FOR 30 MIN. FREEZE PROTECT WELL WITH DIESEL. RD& PREPARE FOR RIG MOVE. RIG RELEASED @ 2400 HRS. � u'" la 2/i i(vg rice Ha 'a'11) Date D ing Superintendent Pioneer Natural Resources, Alaska, Inc. VV,.. :- Weekly Operations Report ODSK-36i PIONEER Weekly Activities January 28 - February 3, 2007 1/28/2008 0' RD& PREPARE PAD FOR RIG MOVE TO ODSK-36i.MOVE&SPOT RIG. RU LINES,OUTSIDE STAIRS EQUIPMENT&ORGANIZE PAD.RIG ACCEPTED @ 1800 HRS.NU 21-1/4°DIVERTER SYSTEM. 1/29/2008 0' NU DIVERTER SYSTEM.HOIST 2-50'SECTIONS OF 16 DIVERTER LINE&MU TO KNIFE VALVE. RECONSTRUCT DIVERTER LINE SUPPORT BRACKETS.TOOK ON 500bbIs SPUD MUD TO RIG PITS FROM RSC.UNTHAW FROZEN WATER LINES.PERFORM DIVERTER FUNCTION TEST-OK, STATE WAIVED WITNESS.FILL&CHECK DIVERTER&MUD LINES.PU BHA#1 TOOLS&PREPARE TO SPUD WELL.LOAD PIPE SHED WITH 9-5/8°CASING. 1/30/2008 1383' PU&MU BHA#1 &RIH.CIRCULATE RISER&LINES. RU WLRELINE UNIT&HANG SHEAVES. DRILL 12-1/4°SURFACE HOLE. POOH 2 STANDS HWDP&PU/MU REST OF BHA#1 &ORIENT. RIH&GYRO SURVEY.CONTINUE TO DRILL AHEAD T/1383'. 1/31/2008 3314' DRILL 12-1/4"SURFACE HOLE F/1,383'T/3,314'.SURVEY AS REQUIRED w/EM MWD.ALL 9-5/8" CASING STRAPPED&IN PIPE SHED.TOTAL OF 50 JTS OF 2-7/8"TUBING STAGED FOR KILL STRING. 2/1/2008 3683' DRILL F/3314'T/3646.CIRC HOLE FOR GEOLOGIST TO EXAMINE SAMPLES TO CORRELATION. DRILL F/3646'T/3683'.CIRC&COND FOR WIPER TRIP.POOH FOR GAMMA RAY.TIGHT SPOT @ 3590'.CONTINUE TO POOH T/3216'. PUMP DRY JOB,TIGHT SPOT @ 2040'.POOH T/200'.TIH F/200'T/1882'.CIRC&COND TIGHT SPOT AT 1882'.TIH F/1882'T/1924',TIGHT SPOT.WASH&REAM F/1924'T/3602'.SURVEY @ 2682',2779',2875'.NOTE:TVD CHANGE PER GEOLOGIST DUE TO FORMATIONS COMING IN DEEPER. 2/2/2008 3683' WASH&REAM F/3663'T/3683'.CIRC&COND HOLE PUMPING SWEEPS. POOH,HIT TIGHT SPOTS. WENT BACK TO BOTTOM.CIRC&COND HOLE,PUMP SWEEP. POOH&WORK THROUGH TIGHT SPOTS.CIRC&COND, PUMP DRY JOB.POOH,LD BHA.RU CASING EQUIPMENT,MAKE DUMMY RUN WITH CASING HANGER/LANDING JT.PU&RUN 9-5/8"CASING.CHECK FLOAT EQUIPMENT& RUN CASING T/1282'. 2/3/2008 3683' RUN 9-5/8'CASING F/1882'T/3619'. PU/MU HANGER&LANDING JT&LAND.MU CEMENT HEAD, BREAK CIRC.CIRC&COND WELL.TEST LINES&CEMENT CASING WITH 324bb1s, 10.7ppg LEAD& 42bbls 15.9ppg TAIL.DROP TOP PLUG&PUMP 10bbls WATER.RD CASING TOOLS&LANDING JT. FLUSH&CLEAN WELL,POOH. 1 t / ��/ 1 At z ce Ha I'a WADate 6ling Superinte t "ioneer Natural Resources,Alaska,Inc. RECFIVE S STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION DEC v 7 7007 PERMIT TO DRILL i t 20 AAC 25.005` Alaska Oil & 1 a'; *i nU. Commission la. Type of Work: ib. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposed Alit,it,fr ugd Drill 0 Redrill ❑ Stratigraphic Test ❑ Service 0 Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 151 Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 - ODSK -36i 3. Address: 6. Proposed Depth: 12. Field /Pool(s): L 700 G Street, Suite 600 Anchorage, AK 99501 MD: 13129' ' TVD: 6143' ' ,p°i ° `" 4a. Location of Well (Governmental Section): 7. Property Designation: Oooguruk Undef) Surface: 2951' FSL, 1117 FEL, Sec. 11, T13N, R7E, UM - ADL 355036 / A Al> /• 4 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2642' FSL, 272' FEL, Sec. 11, T13N, R7E, UM 417497 1/7/2008 Total Depth: - T Y `t <0 9. Acres in Property: 14. Distance to Nearest 834' FSL, 3637 FEL, Sec. '1 (, T13N, R7E, UM 5760 Property: 14390' • 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 54. 4 15. Distance to Nearest Well Surface: x- 469881.69 - y- 6031065.83 ' Zone- ASP 4 ' (Height above GL): 2.66 feet Within Pool: N/A i. it 652 16. Deviated wells: N/A Kickoff depth: $045. tifetoit 68 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 7 Pee6rees Downhole: 3056 psig Surface: 2396 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 3288' Surface Surface 3345' - 2806' . 532 sx Permafrost 'L'; 173 sx Class 'G' 8 -3/4" 7" 26# L -80 BTC -M 8098' Surface Surface 8154' - 6053' - 318 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 IBT -M 5125' 8004' 6051' 13129' - 6143' ‘ 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 Ei Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat EI Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program is 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 ( ` Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: z /' ( 2 50- 74!) - 5 f - d a Date: '-• /1 05? requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:[ Other: VA, `T 4 Cc ,1-4.ccrA c \. Samples req'd: Yes Nog Mud log req'd: Yes❑ Nog S � r� �\ H measures: Yes Nog Directional svy req'd: Yes[✓ No❑ 1 4C - 00 vs OQ � V' :k`cAc? -,.1Cam` ��U� Mc. c��.� ` sc01 - �4 e \�.c� pK�ok \ ` Its _ - la sus c�c� W�c \\ � c\r�c .- € k �acccc b \o- A RCa c .14 , � 1 / APPROVED BY THE COMMISSION DATE: /w/�-'b� If,' , COMMISSIONER Form 10-401 Revised 12/2005 Submi ' D u p lic at e • Oooguruk Well Plan Summary: Permit to Drill ODSK -36i — Kuparuk Injection Well Surface Location: 2950.6' FSL, 1116.7' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection - X = 469881.69 1 Y = 6031065.83 Target: 2642.1' FSL, 271.9' FEL, Sec 11, T13N, R7E, UM X = 470725.49 1 Y = 6030753.75 1 6,053' TVDrkb Bottom Hole Location: 833.8' FSL, 3636.6' FEL, Sec 11, T13N, R7E, UM X = 467372.49 Y = 6034239.79 1 6,143' TVDrkb AFE Number: TBD Est. Start Date: January 7, 2008 1 Rig: Nabors 19AC Operating days: 4.7 days Drill Surface and Suspend 17.3 days Drill Intermediate, Production and Complete TD: 13,129 MD / 6,143 TVDrkb Objective: Kuparuk 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Ultra -slim hole — Injector 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 4,500 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: 3056 psi @ 5997' TVDss • Maximum surface pressure: 2396 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3056 psi @ 5997' TVDss • • Maximum surface pressure: 2396 psi @ surface / (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) - Planned BOP test pressure: 4500 psi (annular to 3000 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i Permit To Drill O R 1 G I N A L 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 12.5 ppg 7" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 13.0 ppg Drilling Fluids Program: Surface Hole Mud Properties: 12 -1/4" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 —15 unrestricted Final 9.2 -9.6 70 -100 25 — 35 15 — 25 10 — 15 <12 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: Not requested on this well. 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 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, V ODSDW1-44 Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i 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 Production Hole: 8 - /a" 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: TVD Pore Press. EMW Formation Tops MD (rkb) (psi) (ppg) Comments Base Permafrost 1636 1600 Top West Sak 2509 2309 1019 8.7 Base of fluvial sands Tuffaceous Shales 3577 2939 Hue Shale 4946 3970 Top Torok Sand 5995 4996 2234 8.7 Top of Disposal Zone Base Torok Sand 6294 5264 Base of Disposal Zone Top HRZ 7010 5775 Base HRZ 7238 5888 Top Kuparuk C 8154 6053 3056 9.8 Base Kuparuk C N/A 6124 Not penetrated Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i Permit To Drill Page 3 of 9 Logging Program: 12 -1/4" Section: Drilling: Mud logging � 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 / Sonic (for cement bond evaluation only) Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Casing Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 65# H40 Welded 101.5' Surface 157.7' / 157.7' 12 - 9 -5/8" 40# L60 BTC 3288' Surface 3345' / 2806' 8 -3/4' 7" 26# L80 BTC -M 8098' Surface 8154' / 6053' 6 -1/8" 4 -1/2" 12.6# L -80 IBT -M 5125' 8004' 13129' / 6143' Slotted Tubing 3 -1/2" 9.3# L80 TSHP 7300' Surface 7356' / 5935' Casing Properties Size Weig Grade ID Drift ID Conn. Internal Collapse Tensile ht Yield (psi) Strength (psi) Joint 1 Body 16" 109# H -40 14.67" 15.062" 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 7, 2007 ODSK -36i Permit To Drill Page 4 of 9 1 • 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: 2845' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 393 bbls / 532 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 37 bbls / 173 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 152 bbls Diesel 96 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: 1659' of open hole with 30% excess Lead TOC: 5495' MD (500' MD above top of disposal interval) Tail: 1000' of open hole with 30% excess, plus 85' shoe track Tail TOC: -7154' MD (1000' above the shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Lead 58 bbls / 137 sx of 12.5 ppg Premium "G" + adds. 2.36 cf /sk, 13.38 gps water req. Tail 35 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 'h 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 7, 2007 ODSK -36i 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 36 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 35 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 , - -3345' 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 - Port Collar may be run based on hole conditions at Company Rep discretion. Displace the cement with seawater / diesel freeze protection fluids to freeze protect the well to -2000' TVD. 5. Ensure floats are holding. WOC. ND Diverter and NU Wellhead and Tree - test. 6. Temporarily suspend the well. RDMO to slot 35 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: Batch Drill Intermediate Hole and Set Intermediate Casing 1. MIRU to ODSK -36. RU circulation lines and ensure the well is dead. 2. ND Tree and NU BOPE. Test BOPE to 250/4500 psi. 3. 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. 4. Test the 9 -5/8" casing to 3,500 psi for 30 min. 5. 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. r 6. Drill 8 -3/4" intermediate hole to casing point at -8154' MD/ 6053' TVDrkb. Circulate and condition the drilling fluid to run casing. 7. Run and cement the 7 ", 26# intermediate casing. 8. MU 6 -1/8" directional drilling, MWD /LWD assembly. RIH and cleanout to landing collar. 9. Pressure test the 7" casing to 4,500 psi for 30 min. 10. Displace the well over to production hole drilling fluid. 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. Drill the 6 -1/8" production hole to TD at - 13129' MD/ 6143' TVDrkb. 13. Circulate and condition the hole to run liner. POH. 14. Run 4 -1/2" Slotted liner on 4" DP 15. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine. POH. Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i Permit To Drill Page 6 of 9 • 16. MU completion and RIH. 17. Land the tubing and RILDS. Install TWC. 18. ND BOPE, NU tree and test to 5,000 psi. 19. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 20. Drop ball and rod and allow to seat. Pressure test the tubing to 4,500 psi - chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 4,500 psi - chart and hold for 30 minutes. Bleed off pressure. 21. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 22. RD Slickline. RDMO to next well. Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i 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 IA 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. • Continue pumping long enough to confirm formation break down. Do not exceed 2 bbl injected after break down. • 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 7, 2007 ODSK -36i Permit To Drill Page 8 of 9 i • 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 i 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 f perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. • Place any anticipated or risk weighted info dealing with well control here. Lost Circulation /Breathing /Formation Stability • Lost circulation is not expected, but if encountered, consult the Lost Circulation Decision Tree. • Breathing maybe seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. • 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 67 bbls 10.2 3084 12.5 ppg (LOT) 7" Intermediate / 6 -1/8" hole Infinite 10.2 3084 14.0 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 CONSULT THE ODS DATA SHEET AND WELL PLAN FOR ADDITIONAL INFORMATION Pioneer Natural Resources Last Revised: December 7, 2007 ODSK -36i Permit To Drill Page 9 of 9 1 • I lit PIONEER Well Planning - Pioneer - Oooguruk g Oooguruk Developement Oooguruk Drill Site ODSK -36i - Slot ODS -36 ODSK -36i KupD Plan: ODSK -36i KupD wp01 Standard Planning Report - Geographic 06 December, 2007 HALLIBURT©N Drilling and Formation Evaluation II WELL DETAILS: ODSK -36i REFERENCE INFORMATION HA Co-ordinate (N/E) Reference: Well ODSK -36i - Slot ODS- 36, True North 1 Ground Level: 13.5 Vertical (TVD) Reference: 56' RKB @ 56.00 :, 4 + +N/ -S +L/ - Northing Lasting Latittude Longitude Slot Measured Depth Reference: 56' RKB @ 56.00 4 - - ""' Sperry Drilling Services 0.0 0.0 6031065.83 469881.69 70.496 - 150.246 ODS -36 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO- ORDINATES) CASING DETAILS Name TVD +N / -S +E / -W Northing Easting Shape TVD MD Name Size Project: Oooguruk Developement KupD T1 6053.0 - 308.7 845.1 6030753.75 470725.49 Point 2806.0 3344.8 9 5/8" 9 -5/8 53.0 8153.7 r 7 Site: Oooguruk Drill Site KupD T2 6056.4 -77.1 737.3 6030985.77 470618.55 Point 6 13129.0 41/2" 4-1/2 well: ODSK -36i KupD T3 6057.1 788.0 . 278.0 6031852.59 470162.89 Point KupD T4 6070.3 1520.5 -168.4 6032586.81 469719.43 Point Wellbore: ODSK -36i KupD KupD T5 6097.6 2418.7 - 1303.7 6033489.52 468587.95 Point Plan: ODSK -361 KupD wp01 KupD T6 6132.1 2957.0 - 2170.4 6034031.35 467723.55 Point COMPANY DETAILS: Well Planning - Pioneer - Ooogumk KupD T7 6142.8 3164.1 - 2522.3 6034239.79 467372.49 Point Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Waming Method: Rules Based _ Start Dir 1.00/100' 300.00' MD, 300.00' TVD - • SECTION DETAILS - - - " Start Dir 2.00/100' 800.00' MD, 799.40' TVD Sec MD Inc Azi TVD +N / -5 +E/ -W DLeg TFace VSec Target 0 - - - 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 - - ' - - - - 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 DDI = 6.69 _ _ _ -' Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 3 800.0 5.00 130.00 799.4 -14.0 16.7 1.00 130.00 -21.7 _ 4 1050.0 10.00 130.00 1047.1 -35.0 41.7 2.00 0.00 -54.2 600 - - ' _ _ _ 5 1693.2 29.29 130.00 1650.0 -173.3 206.6 3.00 0.00 -268.6 - - ' - - - " " End Dir 1693.20' MD, 1650.00' TVD 6 1807.8 29.29 130.00 1750.0 -209.4 249.5 0.00 0.00 -324.5 - " ' 7 2103.2 35.00 130.00 2000.0 -310.4 369.9 1.93 0.00 -481.0 " " " - ' " 8 2815.1 55.12 151.27 2503.1 -703.9 671.4 3.50 44.95 -972.5 - 1200 " Start Dir 1.93/100' 1807.80' MD, 1750.00' TVD 9 3833.9 55.12 151.27 3085.7 - 1436.8 1073.1 0.00 0.00 - 1774.7 5° _ _ - - 10 7953.7 89.24 335.00 6050.4 -489.9 929.7 3.50 - 173.62 - 1003.8 - - - _ _ _ - - - - - - 11 8153.7 89.24 335.00 6053.0 -308.7 845.1 0.00 0.00 -815.9 KupD Ti - - - - - - - " Start Dir 3.5/100' 2103.20' MD, 2000.00' ND 12 8155.3 89.20 335.02 6053.0 -307.2 844.5 3.00 150.25 -814.4 - - - - - - _ _ _ _ _ 13 8382.6 89.20 335.02 6056.2 -101.2 748.5 0.00 0.00 -600.8 1800- 3 ,, - _ _ _ _ _ - - - - - - - 14 8409.2 90.00 335.00 6056.4 -77.1 737.3 3.00 -1.71 -575.8 KupD T2 - - - - - - 15 8505.9 89.96 332.10 6056.4 9.5 694.2 3.00 -90.88 -484.1 End Dir 2815.10' MD, 2503.10' TVD 16 9273.3 89.96 332.10 6057.0 687.7 335.1 0.00 0.00 249.3 _ - - - - - _ - - 17 9388.7 90.00 328.64 6057.1 788.0 278.0 3.00 -89.26 360.6 KupD T3 c , 2400 9 5/8" - - 18 9479.1 89.12 331.20 6057.8 866.2 232.7 3.00 108.96 448.0 L in n - ss _ _ Start Dir 3.5/100 3833.90 MD, 3085.70 ND 19 9874.8 89.12 331.20 6063.8 1212.9 42.2 0.00 0.00 827.8 ,_ _ _ _ 20 10248.2 88.92 320.00 6070.3 1520.5 -168.4 3.00 -91.12 1194.2 KupD T4 21 10697.2 88.98 306.53 6078.5 1827.4 -494.6 3.00 -89.85 1641.9 L _ - ` _ - - - " - - 22 11540.7 88.98 306.53 6093.5 2329.4 - 1172.3 0.00 0.00 2476.1 D. 3000- _ _ - - - - - 23 11699.6 88.06 301.85 6097.6 2418.7 - 1303.7 3.00 - 101.17 2632.1 KupD T5 a) a Start Dir 3.0/100' 8382.60' MD, 6056.20' TVD 24 11700.8 88.05 301.88 6097.7 2419.3 - 1304.7 3.00 107.80 2633.3 - 25 12671.0 88.05 301.88 6130.7 2931.4 - 2128.0 0.00 0.00 3577.5 (0 - '' 26 12720.5 88.51 300.47 6132.1 2957.0 - 2170.4 3.00 -72.20 3625.6 KupD T6 O 3600 - 06-0 ' 27 13129.0 88.51 300.47 6142.8 3164.1 - 2522.3 0.00 0.00 4020.9 KupD T7 r - End Dir 7953.70' MD, 6050.40' TVD ,' End Dir 8505.90' MD, 6056.40 TVD - , Start Dir 3.0/100' 9273.30' MD, 6057.00' TVD - H 4200 10" Start Dir 3.0/100 8153.70 MD, 6053.00' TVp' = 4200 Start Dir 3.0/100' 9874.80' MD, 6063.90' TVD - "' I End Dir 8155.3' MD, 60,53.00' TVD -' - 4800 1 � _ End Dir 9479.10' MD, 6057.80' ND - - - End Dir 10697.20' MD, 6078.50' TVD - 4800 - - - Start Dir 3.0/100' 11540.70' MD, 6093.50' TVD _ - I - ' - - - - 5400 "§3 - - - - - - End Dir 11700 MD 6097.70' ND - 5400 - - Start Dir 3.0/100' 12671.00' MD, 6130.70' TVD 6000 � 'I_ -- - 6000 - - - - End Dir 12720.50 MD,6132.20 TVD - ' I - - Total Depth at 13129.00' MD, 6142.80' TVD • 6600 = I KupD T1 KupD T2 I KupD T3 KupD T4 KupD T5 f KupD T6 KupD T7 4 1 / 2 " ODSK -36i KupD wp01 -6600 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I F I I H I I F I F l l I l l I r l I I r I I I I I l I - I I I I I I I f I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I I I I I l l 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 315.00bearing (1500 ft/in) WELL DETAILS: ODSK -36i REFERENCE INFORMATION I? Ground Level: 13.5 Co-ordinate (N/E) Reference: Wet ODSK -36i - Slot ODS -36, True North H A L L i B lJ RTO N Vertical (TVD) Reference: 56' RKB (a] 56.0ft +N/ -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 56' RKB @ 56.Oft Sperry Drilling Services 0.0 0.0 6031065.83 469881.69 70.496 - 150.246 ODS -36 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO- ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Ooogutuk Name TVD +N / -S +E/ -W Northing Easting Shape Calculation Method: Minimum Curvature KupD T1 6053.0 - 308.7 845.1 6030753.75 470725.49 Point Error System: ISCWSA Project: Oooguruk Developement KupD T2 6056.4 -77.1 737.3 6030985.77 470618.55 Point Scan Method: Tray. Cylinder North Site: Oooguruk Drill Site KupD T3 6057.1 788.0 278.0 6031852.59 470162.89 Point Error Surface: Elliptical Conic KupD T4 6070.3 1520.5 -168.4 6032586.81 469719.43 Point Warning Method: Rules Based Well: ODSK -36i KupD T5 6097.6 2418.7 - 1303.7 6033489.52 468587.95 Point Wellbore: ODSK -36i KupD KupD T6 6132.1 2957.0 - 2170.4 6034031.35 467723.55 Point Plan: ODSK -36i KupD wp01 KupD T7 6142.8 3164.1 - 2522.3 6034239.79 467372.49 Point CASING DETAILS D D I =6.69 TVD MD Name Size 3200- 1 ODSK -36i KupD wp01 2806.0 3344.8 9 5/8" 9 -5/8 - 4 1/2" _ /. ■ - _ _ _ _ _ - - Total Depth at 13129.00' MD, 6142.8V TVD 61 13129.0 4 1/2" 4 - 1/2 1 i - - - - End Dir 12720.50' MD,6132.20' TVD 2800- KupD ' I - Start Dir 3.0 /100' 12671.00' MD, 6130.70' TVD SECTION DETAILS IKupD 111 I End Dir 11700.80' MD, 6097.70' TVD Sec MD Inc Azi TVD +N / -5 +E/ -W DLeg TFace VSec Target . 2400- _ _ _ _ _ - - - 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 _ , / I 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 - - - _ _ _ _ 3 800.0 5.00 130.00 799.4 -14.0 16.7 1.00 130.00 -21.7 - IKupD TS Start Dir 3.0/100' 11540.70' MD, 6093.50' TVD 4 1050.0 10.00 130.00 1047.1 -35.0 41.7 2.00 0.00 -54.2 - 5 1693.2 29.29 130.00 1650.0 -173.3 206.6 3.00 0.00 -268.6 2000- 6 1807.8 29.29 130.00 1750.0 -209.4 249.5 0.00 0.00 -324.5 End Dir 10697.20' MD, 6078.50' TVD 7 2103.2 35.00 130.00 2000.0 - 310.4 369.9 1.93 0.00 -481.0 - 8 2815.1 55.12 151.27 2503.1 -703.9 671.4 3.50 44.95 -972.5 9 3833.9 55.12 151.27 3085.7 - 1436.8 1073.1 0.00 0.00 - 1774.7 1600- I 10 7953.7 89.24 335.00 6050.4 -489.9 929.7 3.50 - 173.62 - 1003.8 - - - 11 8153.7 89.24 335.00 6053.0 - 308.7 845.1 0.00 0.00 -815.9 KupD T1 12 8155.3 89.20 335.02 6053.0 - 307.2 844.5 3.00 150.25 -814.4 KupD T' I 13 8382.6 89.20 335.02 6056.2 -101.2 748.5 0.00 0.00 -600.8 1200- Start Dir 3.0 /100' 9874.80' MD, 6063.90' TVD 14 8409.2 90.00 335.00 6056.4 -77.1 737.3 3.00 -1.71 -575.8 KupD T2 15 8505.9 89.96 332.10 6056.4 9.5 694.2 3.00 - 90.88 -484.1 c. - 16 9273.3 89.96 332.10 6057.0 687.7 335.1 0.00 0.00 249.3 o - 17 9388.7 90.00 328.64 6057.1 788.0 278.0 3.00 -89.26 360.6 KupD T3 C 0 -End Dir 9479.10' MD, 6057.80' TVD 18 9479.1 89.12 331.20 6057.8 866.2 232.7 3.00 108.96 448.0 .-' 800- - - 19 9874.8 89.12 331.20 6063.8 1212.9 42.2 0.00 0.00 827.8 _ KupD -j' I _ _ _ _ 20 10248.2 88.92 320.00 6070.3 1520.5 -168.4 3.00 -91.12 1194.2 KupD T4 'j Start Dir 3.0/100' 9273.30' MD, 6057.00' TVD 21 10697.2 88.98 306.53 6078.5 1827.4 -494.6 3.00 -89.85 1641.9 Start Dir 1.00 /100' 300.00' MD, 300.00' TVD 22 11540.7 88.98 306.53 6093.5 2329.4 - 1172.3 0.00 0.00 2476.1 p 400- - - - 23 11699.6 88.06 301.85 6097.6 2418.7 - 1303.7 3.00 - 101.17 2632.1 KupD T5 _ - -. , 24 11700.8 88.05 301.88 6097.7 2419.3 - 1304.7 3.00 107.80 2633.3 - Start Dir 2.00/100' 800.00' MD, 799.40' TVD End Dir 8505.90' MD, 6056.40' TVD 25 12671.0 88.05 301.88 6130.7 2931.4 - 2128.0 0.00 0.00 3577.5 _ - ' - - - _ _ _ KupD T1 26 12720.5 88.51 300.47 6132.1 2957.0 - 2170.4 3.00 -72.20 3625.6 KupD T6 0 _ _ 27 13129.0 88.51 300.47 6142.8 3164.1 - 2522.3 0.00 0.00 4020.9 KupD 17 Cl) - Start Dir 3.00 /100' 1050.00' MD, 1047.10' TVD - - _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - IKupD TI I I ,, 7" Start Dir 3.0/100' 8382.60' MD, 6056.20' TVD -400- End Dir 1693.20' MD, 1650.00' TVD , , - - ' Q _ - _ _ _ - - - - t - - -400 ti - - - - - - - - End Dir 815 5.3' MD, 6053.00' TVD - _ Start Dir 1.93/100' 1 807.80' MD, 1750.00' TVD Start Dir 3.0/100' 8153.70' MD, 6053.00' TVD - - b --800 _ - ' �� End Dir 7953.70' MD, 6050.40' TVD _ _ St Dir 3.5/100' 2103.20' MD, 2000.00' TVD 9 5/9" - - -1200- _ -1200 - End Dir 2815.10' MD, 2503.10' TVD � _ -1600- - - - 55 - -1600 - - Start Dir 3.5/100' 3833.90' MD, 3085.70' TVD _ 50p - -2000- - -2000 I i I I I I f l I I i I l l l i r r l I i l l I l i t l 1 l 1 1 1 1 i ITl i i i I I I I I - I I i I I I I l I T r i l I l l i r 1 i i i i I I l i l l r l i l l l l r I I I I i I 1 i i I I I I I I I I I i i 1 i i i -2800 -2400 -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 West( - )/East( +) (1000 ft/in) 40 • Halliburton Company HALLi6URTOty _— Planning Report - Geographic Drilling and Formation PIONEER .Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True i Well: ODSK -36i Survey Calculation Method: Minimum Curvature , Wellbore: ODSK -36i KupD Design: ODSK -36i KupD 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 -36i - Slot ODS -36 Well Position +N /-S 0.0 ft Northing: 6,031,065.83 ft ' Latitude: 70.496 +E / -W 0.0 ft Easting: 469,881.69 ft / Longitude: - 150.246 Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSK -36i KupD Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 1/8/2007 23.31 80.81 57,637 Design ODSK -36i KupD wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 0.0 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) (bearing) 0.0 0.0 0.0 315.00 12/6/2007 6 :25:56PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Planning Report - Geographic Drilling and Formation PIQN118 Evaluation Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -36i KupD Design: ODSK -36i KupD 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) ( ? /100ft) ( ?/100ft) ( ?/100ft) ( ?) Target 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.00 0.00 800.0 5.00 130.00 799.4 -14.0 16.7 1.00 1.00 0.00 130.00 1,050.0 10.00 130.00 1,047.1 -35.0 41.7 2.00 2.00 0.00 0.00 1,693.2 29.29 130.00 1,650.0 -173.3 206.6 3.00 3.00 0.00 0.00 1,807.8 29.29 130.00 1,750.0 -209.4 249.5 0.00 0.00 0.00 0.00 2,103.2 35.00 130.00 2,000.0 -310.4 369.9 1.93 1.93 0.00 0.00 2,815.1 55.12 151.27 2,503.1 -703.9 671.4 3.50 2.83 2.99 44.95 3,833.9 55.12 151.27 3,085.7 - 1,436.8 1,073.1 0.00 0.00 0.00 0.00 7,953.7 89.24 335.00 6,050.4 -489.9 929.7 3.50 0.83 -4.28 - 173.62 8,153.7 89.24 335.00 6,053.0 -308.7 845.1 0.00 0.00 0.00 0.00 KupD T1 8,155.3 89.20 335.02 6,053.0 -307.2 844.5 3.00 -2.60 1.49 150.25 8,382.6 89.20 335.02 6,056.2 -101.2 748.5 0.00 0.00 0.00 0.00 8,409.2 90.00 335.00 6,056.4 -77.1 737.3 3.00 3.00 -0.09 -1.71 KupD T2 8,505.9 89.96 332.10 6,056.4 9.5 694.2 3.00 -0.05 -3.00 -90.88 9,273.3 89.96 332.10 6,057.0 687.7 335.1 0.00 0.00 0.00 0.00 9,388.7 90.00 328.64 6,057.1 788.0 278.0 3.00 0.04 -3.00 -89.26 KupD T3 9,479.1 89.12 331.20 6,057.8 866.2 232.7 3.00 -0.97 2.84 108.96 9,874.8 89.12 331.20 6,063.8 1,212.9 42.2 0.00 0.00 0.00 0.00 10,248.2 88.92 320.00 6,070.3 1,520.5 -168.4 3.00 -0.05 -3.00 -91.12 KupD T4 10,697.2 88.98 306.53 6,078.5 1,827.4 -494.6 3.00 0.01 -3.00 -89.85 11,540.7 88.98 306.53 6,093.5 2,329.4 - 1,172.3 0.00 0.00 0.00 0.00 11,699.6 88.06 301.85 6,097.6 2,418.7 - 1,303.7 3.00 -0.58 -2.94 - 101.17 KupD T5 11,700.8 88.05 301.88 6,097.7 2,419.3 - 1,304.7 3.00 -0.92 2.86 107.80 12,671.0 88.05 301.88 6,130.7 2,931.4 - 2,128.0 0.00 0.00 0.00 0.00 12,720.5 88.51 300.47 6,132.2 2,957.0 - 2,170.4 3.00 0.92 -2.86 -72.20 KupD T6 13,129.0 88.51 300.47 6,142.8 3,164.1 - 2,522.3 0.00 0.00 0.00 0.00 KupD T7 i 12/6/2007 6:25:56PM Page 3 COMPASS 2003.16 Build 428 an Halliburton Company HALLIBURTON • 0 P lanning Report - Geographic Drliiing and Formation MAW Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Welibore: ODSK -36i KupD Design: ODSK -36i KupD wp01 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N /-$ +E/-W Northing Easting (ft) ( ?) (bearing) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 0.0 0.00 0.00 0.0 0.0 0.0 6,031,065.83 469,881.69 70.496 - 150.246 100.0 0.00 0.00 100.0 0.0 0.0 6,031,065.83 469,881.69 70.496 - 150.246 200.0 0.00 0.00 200.0 0.0 0.0 6,031,065.83 469,881.69 70.496 - 150.246 300.0 0.00 0.00 300.0 0.0 0.0 6,031,065.83 469,881.69 70.496 - 150.246 Start Dir 1.001100' 300.00' MD, 300.00' TVD 400.0 1.00 130.00 400.0 -0.6 0.7 6,031,065.27 469,882.36 70.496 - 150.246 500.0 2.00 130.00 500.0 -2.2 2.7 6,031,063.58 469,884.35 70.496 - 150.246 600.0 3.00 130.00 599.9 -5.0 6.0 6,031,060.76 469,887.68 70.496 - 150.246 700.0 4.00 130.00 699.7 -9.0 10.7 6,031,056.82 469,892.34 70.496 - 150.246 800.0 5.00 130.00 799.4 -14.0 16.7 6,031,051.75 469,898.33 70.496 - 150.246 'Start Dir 2.00/100' 800.00' MD, 799.40' TVD 900.0 7.00 130.00 898.8 -20.7 24.7 6,031,045.00 469,906.31 70.496 - 150.246 1,000.0 9.00 130.00 997.8 -29.7 35.4 6,031,036.01 469,916.93 70.496 - 150.246 1,050.0 10.00 130.00 1,047.1 -35.0 41.7 6,031,030.68 469,923.23 70.496 - 150.246 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 1,100.0 11.50 130.00 1,096.3 -41.0 48.8 6,031,024.66 469,930.35 70.496 - 150.246 1,200.0 14.50 130.00 1,193.7 -55.4 66.1 6,031,010.13 469,947.52 70.496 - 150.246 1,300.0 17.50 130.00 1,289.8 -73.2 87.2 6,030,992.33 469,968.56 70.496 - 150.246 1,400.0 20.50 130.00 1,384.4 -94.1 112.1 6,030,971.31 469,993.41 70.496 - 150.245 1,500.0 23.50 130.00 1,477.1 -118.2 140.8 6,030,947.12 470,022.00 70.496 - 150.245 1,600.0 26.50 130.00 1,567.7 -145.3 173.2 6,030,919.83 470,054.26 70.496 - 150.245 1,693.2 29.29 130.00 1,650.0 -173.3 206.6 6,030,891.67 470,087.55 70.495 - 150.245 End Dir 1693.20' MD, 1650.00' TVD 1,700.0 29.29 130.00 1,656.0 -175.5 209.1 6,030,889.52 470,090.09 70.495 - 150.245 1,800.0 29.29 130.00 1,743.2 -206.9 246.6 6,030,857.92 470,127.44 70.495 - 150.244 1,807.8 29.29 130.00 1,750.0 -209.4 249.5 6,030,855.46 470,130.35 70.495 - 150.244 Start Dir 1.93/100' 1807.80' MD, 1750.00' TVD 1,900.0 31.08 130.00 1,829.7 -239.2 285.0 6,030,825.52 470,165.74 70.495 - 150.244 2,000.0 33.01 130.00 1,914.4 -273.3 325.7 6,030,791.26 470,206.23 70.495 - 150.244 2,100.0 34.94 130.00 1,997.4 -309.2 368.5 6,030,755.17 470,248.89 70.495 - 150.243 2,103.2 35.00 130.00 2,000.0 -310.4 369.9 6,030,753.99 470,250.29 70.495 - 150.243 Start Dir 3.5/100' 2103.20' MD, 2000.00' TVD 2,200.0 37.46 133.94 2,078.1 -348.7 412.4 6,030,715.54 470,292.60 70.495 - 150.243 2,300.0 40.13 137.55 2,156.0 -393.6 456.0 6,030,670.47 470,336.08 70.495 - 150.243 2,400.0 42.90 140.78 2,230.9 -443.7 499.3 6,030,620.13 470,379.16 70.495 - 150.242 2,500.0 45.75 143.69 2,302.4 -499.0 542.1 6,030,564.71 470,421.67 70.495 - 150.242 2,600.0 48.67 146.33 2,370.4 -559.1 584.1 6,030,504.42 470,463.46 70.494 - 150.242 2,700.0 51.64 148.74 2,434.4 -623.9 625.3 6,030,439.48 470,504.37 70.494 - 150.241 2,800.0 54.66 150.95 2,494.4 -693.1 665.4 6,030,370.14 470,544.25 70.494 - 150.241 2,815.1 55.12 151.27 2,503.1 -703.9 671.4 6,030,359.30 470,550.17 70.494 - 150.241 End Dir 2815.10' MD, 2503.10' TVD 2,900.0 55.12 151.27 2,551.6 -765.0 704.9 6,030,298.09 470,583.39 70.494 - 150.241 3,000.0 55.12 151.27 2,608.8 -836.9 744.3 6,030,226.00 470,622.52 70.494 - 150.240 3,100.0 55.12 151.27 2,666.0 -908.8 783.7 6,030,153.91 470,661.65 70.493 - 150.240 3,200.0 55.12 151.27 2,723.2 -980.8 823.2 6,030,081.83 470,700.79 70.493 - 150.240 3,300.0 55.12 151.27 2,780.4 - 1,052.7 862.6 6,030,009.74 470,739.92 70.493 - 150.239 3,344.8 55.12 151.27 2,806.0 - 1,084.9 880.2 6,029,977.46 470,757.44 70.493 - 150.239 9 518" 3,400.0 55.12 151.27 2,837.6 - 1,124.7 902.0 6,029,937.65 470,779.05 70.493 - 150.239 3,500.0 55.12 151.27 2,894.8 - 1,196.6 941.4 6,029,865.56 470,818.18 70.493 - 150.239 3,600.0 55.12 151.27 2,952.0 - 1,268.5 980.9 6,029,793.47 470,857.31 70.492 - 150.238 3,700.0 55.12 151.27 3,009.1 - 1,340.5 1,020.3 6,029,721.38 470,896.45 70.492 - 150.238 3,800.0 55.12 151.27 3,066.3 - 1,412.4 1,059.7 6,029,649.29 470,935.58 70.492 - 150.238 12/6/2007 6:25:56PM Page 4 COMPASS 2003.16 Build 42B 1 0 Halliburton Company HALLIBURTON Planning Report - Geographic Drillin and Formation PIONEER Evaluation • Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB © 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Wel!bore: ODSK -36i KupD Design: ODSK -36i KupD 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 3,833.9 55.12 151.27 3,085.7 - 1,436.8 1,073.1 6,029,624.85 470,948.84 70.492 - 150.238 Start Dir 3.5/100' 3833.90' MD, 3085.70' TVD 3,900.0 52.82 150.95 3,124.6 - 1,483.6 1,098.9 6,029,577.95 470,974.47 70.492 - 150.237 4,000.0 49.34 150.42 3,187.4 - 1,551.4 1,137.0 6,029,509.97 471,012.27 70.492 - 150.237 4,100.0 45.87 149.84 3,254.8 - 1,615.5 1,173.8 6,029,445.79 471,048.77 70.492 - 150.237 4,200.0 42.40 149.18 3,326.6 - 1,675.5 1,209.1 6,029,385.65 471,083.84 70.491 - 150.236 4,300.0 38.93 148.43 3,402.4 - 1,731.2 1,242.8 6,029,329.78 471,117.35 70.491 - 150.236 4,400.0 35.47 147.55 3,482.1 - 1,782.5 1,274.8 6,029,278.38 471,149.17 70.491 - 150.236 4,500.0 32.02 146.52 3,565.2 - 1,829.1 1,305.0 6,029,231.65 471,179.18 70.491 - 150.236 4,600.0 28.58 145.26 3,651.5 - 1,870.9 1,333.3 6,029,189.76 471,207.27 70.491 - 150.235 4,700.0 25.15 143.69 3,740.7 - 1,907.7 1,359.5 6,029,152.86 471,233.34 70.491 - 150.235 4,800.0 21.75 141.67 3,832.4 - 1,939.3 1,383.6 6,029,121.10 471,257.29 70.491 - 150.235 4,900.0 18.37 138.94 3,926.4 - 1,965.8 1,405.5 6,029,094.59 471,279.03 70.491 - 150.235 5,000.0 15.05 135.04 4,022.1 - 1,986.8 1,425.0 6,029,073.44 471,298.47 70.491 - 150.235 5,100.0 11.84 129.05 4,119.4 - 2,002.5 1,442.1 6,029,057.71 471,315.56 70.490 - 150.234 5,200.0 8.84 118.89 4,217.8 - 2,012.7 1,456.8 6,029,047.48 471,330.21 70.490 - 150.234 5,300.0 6.37 99.83 4,316.9 - 2,017.3 1,469.0 6,029,042.77 471,342.38 70.490 - 150.234 5,400.0 5.23 66.44 4,416.4 - 2,016.5 1,478.7 6,029,043.60 471,352.03 70.490 - 150.234 5,500.0 6.21 32.12 4,515.9 - 2,010.0 1,485.7 6,029,049.98 471,359.11 70.490 - 150.234 5,600.0 8.62 12.06 4,615.1 - 1,998.1 1,490.2 6,029,061.88 471,363.60 70.490 - 150.234 5,700.0 11.59 1.42 4,713.5 - 1,980.8 1,492.0 6,029,079.25 471,365.49 70.491 - 150.234 5,800.0 14.80 355.20 4,810.9 - 1.958 :0 1,491.2 6,029,102.03 471,364.76 70.491 - 150.234 5,900.0 18.11 351.18 4,906.8 - 1,929.9 1,487.7 6,029,130.13 471,361.42 70.491 - 150.234 6,000.0 21.48 348.38 5,000.9 - 1,896.6 1,481.6 6,029,163.45 471,355.48 70.491 - 150.234 6,100.0 24.88 346.31 5,092.8 - 1,858.2 1,473.0 6,029,201.87 471,346.97 70.491 - 150.234 6,200.0 28.31 344.71 5,182.2 - 1,814.9 1,461.7 6,029,245.24 471,335.91 70.491 - 150.234 6,300.0 31.75 343.43 5,268.8 - 1,766.8 1,448.0 6,029,293.39 471,322.35 70.491 - 150.234 6,400.0 35.20 342.38 - 5,352.2 - 1,714.1 1,431.7 6,029,346.16 471,306.33 70.491 - 150.235 6,500.0 38.66 341.50 5,432.1 - 1,656.9 1,413.1 6,029,403.34 471,287.92 70.491 - 150.235 6,600.0 42.13 340.74 5,508.2 - 1,595.6 1,392.1 6,029,464.72 471,267.19 70.492 - 150.235 6,700.0 45.60 340.07 5,580.3 - 1,530.4 1,368.9 6,029,530.08 471,244.21 70.492 - 150.235 6,800.0 49.07 339.48 5,648.1 - 1,461.4 1,343.4 6,029,599.16 471,219.07 70.492 - 150.235 6,900.0 52.55 338.95 5,711.3 - 1,388.9 1,315.9 6,029,671.70 471,191.86 70.492 - 150.236 7,000.0 56.02 338.47 5,769.6 - 1,313.3 1,286.5 6,029,747.45 471,162.68 70.492 - 150.236 7,100.0 59.50 338.02 5,823.0 - 1,234.8 1,255.1 6,029,826.12 471,131.65 70.493 - 150.236 7,200.0 62.98 337.60 5,871.1 - 1,153.6 1,222.0 6,029,907.40 471,098.88 70.493 - 150.236 7,300.0 66.47 337.21 5,913.8 - 1,070.1 1,187.3 6,029,991.01 471,064.48 70.493 - 150.237 7,400.0 69.95 336.84 5,950.9 -984.7 1,151.0 6,030,076.62 471,028.60 70.493 - 150.237 7,500.0 73.43 336.49 5,982.3 -897.5 1,113.4 6,030,163.92 470,991.36 70.493 - 150.237 7,600.0 76.92 336.15 6,007.9 -809.0 1,074.6 6,030,252.59 470,952.90 70.494 - 150.237 7,700.0 80.40 335.82 6,027.5 -719.4 1,034.7 6,030,342.29 470,913.36 70.494 - 150.238 7,800.0 83.89 335.49 6,041.2 -629.2 993.9 6,030,432.68 470,872.90 70.494 - 150.238 7,900.0 87.37 335.17 6,048.8 -538.6 952.3 6,030,523.43 470,831.67 70.494 - 150.238 7,953.7 89.24 335.00 6,050.4 -489.9 929.7 6,030,572.20 470,809.25 70.495 - 150.239 End Dir 7953.70' MD, 6050.40' TVD 8,000.0 89.24 335.00 6,051.0 -448.0 910.1 6,030,614.23 470,789.86 70.495 - 150.239 8,100.0 89.24 335.00 6,052.3 -357.3 867.8 6,030,705.02 470,747.97 70.495 - 150.239 8,153.7 89.24 335.00 6,053.0 -308.7 845.1 6,030,753.75 470,725.49 70.495 - 150.239 Start Dir 3.0/100' 8153.70' MD, 6053.00' TVD - 7" - KupD T1 8,155.3 89.20 335.02 6,053.0 -307.2 844.5 6,030,755.22 470,724.81 70.495 - 150.239 End Dir 8155.3' MD, 6053.00' TVD 8,200.0 89.20 335.02 6,053.7 -266.7 825.6 6,030,795.81 470,706.11 70.495 - 150.240 8,300.0 89.20 335.02 6,055.1 -176.1 783.4 6,030,886.61 470,664.26 70.495 - 150.240 1216/2007 6 :25 :56PM Page 5 COMPASS 2003.16 Build 428 •- . ..` Halliburton Company HALLIIBURTON Planning Report - Geographic Drilling and Formation MALLS Evaluation Database: ..EDM_Alaska Local Co.ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Weltbore: ODSK -36i KupD Design: ODSK -36i KupD wp01 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth +N /4 +E/ -W Northing Easting (ft) (T) (bearing) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 8,382.6 89.20 335.02 6,056.2 -101.2 748.5 6,030,961.61 470,629.69 70.496 - 150.240 Start Dir 3.0/100' 8382.60' MD, 6056.20' TVD 8,400.0 89.72 335.01 6,056.4 -85.4 741.1 6,030,977.41 470,622.41 70.496 - 150.240 8,409.2 90.00 335.00 6,056.4 -77.1 737.3 6,030,985.77 470,618.55 70.496 - 150.240 KupD T2 8,500.0 89.96 332.28 6,056.4 4.3 696.9 6,031,067.27 470,578.57 70.496 - 150.241 8,505.9 89.96 332.10 6,056.4 9.5 694.2 6,031,072.50 470,575.84 70.496 - 150.241 End Dir 8505.90' MD, 6056.40' TVD 8,600.0 89.96 332.10 6,056.5 92.6 650.2 6,031,155.83 470,532.15 70.496 - 150.241 8,700.0 89.96 332.10 6,056.6 181.0 603.4 6,031,244.38 470,485.72 70.496 - 150.241 8,800.0 89.96 332.10 6,056.7 269.4 556.6 6,031,332.94 470,439.29 70.497 - 150.242 8,900.0 89.96 332.10 6,056.7 357.8 509.8 6,031,421.50 470,392.86 70.497 - 150.242 9,000.0 89.96 332.10 6,056.8 446.1 463.0 6,031,510.05 470,346.42 70.497 - 150.242 9,100.0 89.96 332.10 6,056.9 534.5 416.2 6,031,598.61 470,299.99 70.497 - 150.243 9,200.0 89.96 332.10 6,057.0 622.9 369.4 6,031,687.16 470,253.56 70.498 - 150.243 9,273.3 89.96 332.10 6,057.0 687.7 335.1 6,031,752.07 470,219.53 70.498 - 150.244 Start Dir 3.0/100' 9273.30' MD, 6057.00' TVD 9,300.0 89.97 331.30 6,057.0 711.2 322.4 6,031,775.63 470,206.97 70.498 - 150.244 9,388.7 90.00 328.64 6,057.1 788.0 278.0 6,031,852.59 470,162.89 70.498 - 150.244 KupD T3 9,400.0 89.89 328.96 6,057.1 797.6 272.2 6,031,862.27 470,157.08 70.498 - 150.244 9,479.1 89.12 331.20 6,057.8 866.2 232.7 6,031,930.98 470,117.91 70.498 - 150.244 End Dir 9479.10' MD, 6057.80' TVD 9,500.0 89.12 331.20 6,058.1 884.5 222.7 6,031,949.33 470,107.92 70.498 - 150.244. 9,600.0 89.12 331.20 6,059.6 972.1 174.5 6,032,037.14 470,060.11 70.499 - 150.245 9,700.0 89.12 331.20 6,061.2 1,059.7 126.3 6,032,124.94 470,012.31 70.499 - 150.245 9,800.0 89.12 331.20 6,062.7 1,147.4 78.2 6,032,212.75 469,964.50 70.499 - 150.246 9,874.8 89.12 331.20 6,063.9 1,212.9 42.1 6,032,278.43 469,928.74 70.499 - 150.246 Start Dir 3.0/100' 9874.80' MD, 6063.90' TVD 9,900.0 89.10 330.45 6,064.2 1,234.9 29.9 6,032,300.48 469,916.55 70.499 - 150.246 10,000.0 89.05 327.45 6,065.9 1,320.6 -21.7 6,032,386.33 469,865.33 70.500 - 150.246 10,100.0 88.99 324.45 6,067.6 1,403.4 -77.7 6,032,469.37 469,809.69 70.500 - 150.247 10,200.0 88.94 321.45 6,069.4 1,483.2 -137.9 6,032,549.39 469,749.78 70.500 - 150.247 10,248.2 88.92 320.00 6,070.3 1,520.5 -168.4 6,032,586.81 469,719.43 70.500 - 150.248 KupD T4 10,300.0 88.92 318.45 6,071.2 1,559.7 -202.3 6,032,626.17 469,685.76 70.500 - 150.248 10,400.0 88.93 315.44 6,073.1 1,632.7 -270.5 6,032,699.48 469,617.82 70.500 - 150.248 10,500.0 88.95 312.44 6,075.0 1,702.1 -342.5 6,032,769.15 469,546.12 70.501 - 150.249 10,600.0 88.96 309.44 6,076.8 1,767.6 -418.0 6,032,834.96 469,470.88 70.501 - 150.250 10,697.2 88.98 306.53 6,078.5 1,827.4 -494.6 6,032,895.07 469,394.55 70.501 - 150.250 End Dir 10697.20' MD, 6078.50' TVD 10,700.0 88.98 306.53 6,078.6 1,829.1 -496.9 6,032,896.74 469,392.30 70.501 - 150.250 10,800.0 88.98 306.53 6,080.4 1,888.6 -577.2 6,032,956.57 469,312.21 70.501 - 150.251 10,900.0 88.98 306.53 6,082.1 1,948.1 -657.5 6,033,016.41 469,232.12 70.501 - 150.252 11,000.0 88.98 306.53 6,083.9 2,007.6 -737.9 6,033,076.24 469,152.02 70.501 - 150.252 11,100.0 88.98 306.53 6,085.7 2,067.2 -818.2 6,033,136.07 469,071.93 70.502 - 150.253 11,200.0 88.98 306.53 6,087.5 2,126.7 -898.6 6,033,195.90 468,991.83 70.502 - 150.254 11,300.0 88.98 306.53 6,089.3 2,186.2 -978.9 6,033,255.73 468,911.74 70.502 - 150.254 11,400.0 88.98 306.53 6,091.0 2,245.7 - 1,059.3 6,033,315.57 468,831.65 70.502 - 150.255 11,500.0 88.98 306.53 6,092.8 2,305.2 - 1,139.6 6,033,375.40 468,751.55 70.502 - 150.256 11,540.7 88.98 306.53 6,093.5 2,329.4 - 1,172.3 6,033,399.75 468,718.96 70.502 - 150.256 Start Dir 3.0/100' 11540.70' MD, 6093.50' TVD 11,600.0 88.64 304.78 6,094.8 2,364.0 - 1,220.5 6,033,434.50 468,670.93 70.502 - 150.256 I 12/6/2007 6:25:56PM Page 6 COMPASS 2003.16 Build 428 . Halliburton Company HALLIBURTON , *, P lanning Report - Geographic Drilling .ad Forean PIONEER EV Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Welibore: ODSK -36i KupD Design: ODSK -36i KupD 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 11,699.6 88.06 301.85 6,097.6 2,418.7 - 1,303.7 6,033,489.52 468,587.95 70.503 - 150.257 KupD T5 11,700.0 88.06 301.86 6,097.6 2,418.9 - 1,304.0 6,033,489.72 468,587.63 70.503 - 150.257 11,700.8 88.05 301.88 6,097.7 2,419.3 - 1,304.7 6,033,490.14 468,586.96 70.503 - 150.257 End Dir 11700.80' MD, 6097.70' TVD 11,800.0 88.05 301.88 6,101.0 2,471.7 - 1,388.9 6,033,542.84 468,502.99 70.503 - 150.258 11,900.0 88.05 301.88 6,104.4 2,524.4 - 1,473.7 6,033,595.97 468,418.35 70.503 - 150.258 12,000.0 88.05 301.88 6,107.8 2,577.2 - 1,558.6 6,033,649.10 468,333.71 70.503 - 150.259 12,100.0 88.05 301.88 6,111.2 2,630.0 - 1,643.5 6,033,702.22 468,249.07 70.503 - 150.260 12,200.0 88.05 301.88 6,114.6 2,682.8 - 1,728.3 6,033,755.35 468,164.43 70.503 - 150.260 12,300.0 88.05 301.88 6,118.0 2,735.6 - 1,813.2 6,033,808.47 468,079.79 70.503 - 150.261 12,400.0 88.05 301.88 6,121.4 2,788.4 - 1,898.0 6,033,861.60 467,995.15 70.504 - 150.262 12,500.0 88.05 301.88 6,124.8 2,841.2 - 1,982.9 6,033,914.73 467,910.51 70.504 - 150.262 12,600.0 88.05 301.88 6,128.2 2,894.0 - 2,067.8 6,033,967.85 467,825.87 70.504 - 150.263 12,671.0 88.05 301.88 6,130.7 2,931.4 - 2,128.0 6,034,005.57 467,765.77 70.504 - 150.264 Start Dir 3.0/100' 12671.00' MD, 6130.70' TVD 12,700.0 88.32 301.05 6,131.6 2,946.6 - 2,152.7 6,034,020.80 467,741.11 70.504 - 150.264 12,720.5 88.51 300.47 6,132.2 2,957.0 - 2,170.4 6,034,031.35 467,723.55 70.504 - 150.264 End Dir 12720.50' MD,6132.20' TVD - KupD T6 12,800.0 88.51 300.47 6,134.2 2,997.3 - 2,238.9 6,034,071.92 467,655.22 70.504 - 150.265 12,900.0 88.51 300.47 6,136.8 3,048.0 - 2,325.0 6,034,122.95 467,569.27 70.504 - 150.265 13,000.0 88.51 300.47 6,139.4 3,098.7 - 2,411.2 6,034,173.98 467,483.33 70.504 - 150.266 1 13,100.0 88.51 300.47 6,142.0 3,149.4 - 2,497.3 6,034,225.01 467,397.38 70.505 - 150.267 13,128.9 88.51 300.47 6,142.8 3,164.1 - 2,522.2 6,034,239.76 467,372.54 70.505 - 150.267 4 1/2" 13,129.0 88.51 300.47 6,142.8 3,164.1 - 2,522.3 6,034,239.79 467,372.49 70.505 - 150.267 KupD T7 12/6/2007 6:25:56PM Page 7 COMPASS 2003.16 Build 428 s Halliburton Company HALLIBURTON Planning Report - Geographic Drilling and Formation P14AUS Evaluation Database: ..EDM Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -36i Survey Calculation Method: Minimum Curvature Welibore: ODSK -36i KupD Design: ODSK -36i KupD 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 KupD T4 0.00 0.00 6,070.3 1,520.5 -168.4 6,032,586.81 469,719.43 70.500 - 150.248 - plan hits target - Point KupD T3 0.00 0.00 6,057.1 788.0 278.0 6,031,852.59 470,162.89 70.498 - 150.244 - plan hits target - Point KupD T5 0.00 0.00 6,097.6 2,418.7 - 1,303.7 6,033,489.52 468,587.95 70.503 - 150.257 - plan hits target - Point KupD T6 0.00 0.00 6,132.2 2,957.0 - 2,170.4 6,034,031.35 467,723.55 70.504 - 150.264 - plan hits target - Point KupD T1 0.00 0.00 6,053.0 -308.7 845.1 6,030,753.75 470,725.49 70.495 - 150.239 - plan hits target - Point KupD T2 0.00 0.00 6,056.4 -77.1 737.3 6,030,985.77 470,618.55 70.496 - 150.240 - plan hits target - Point KupD T7 0.00 0.00 6,142.8 3,164.1 - 2,522.3 6,034,239.79 467,372.49 70.505 - 150.267 - plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( °) ( ") 3,344.8 2,806.0 9 5/8" 9 -5/8 12 -1/4 8,153.7 6,053.0 7" 7 8 -1/2 13,128.9 6,142.8 4 1/2" 4 -1/2 6 -1/8 12/6/2007 6 :25:56PM Page 8 COMPASS 2003.16 Build 42B Halliburton Company HALLrBURTON P lanning Report - Geographic Drilling and Formation C24NSEB Evaluation Database: . ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -36i - Slot ODS -36 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' RKB @ 56.0ft Project: Oooguruk Developement MD Reference: 56' RKB @ 56.0ft Site: Oooguruk Drill Site North Reference: True Weil: ODSK -36i Survey Calculation Method; Minimum Curvature Welibore: ODSK -36i KupD Design: ODSK -36i KupD wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E/ -W (ft) (ft) (ft) (ft) Comment 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 800.0 799.4 -14.0 16.7 Start Dir 2.00/100' 800.00' MD, 799.40' TVD 1,050.0 1,047.1 -35.0 41.7 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 1,693.2 1,650.0 -173.3 206.6 End Dir 1693.20' MD, 1650.00' TVD 1,807.8 1,750.0 -209.4 249.5 Start Dir 1.93/100' 1807.80' MD, 1750.00' TVD 2,103.2 2,000.0 -310.4 369.9 Start Dir 3.5/100' 2103.20' MD, 2000.00' TVD 2,815.1 2,503.1 -703.9 671.4 End Dir 2815.10' MD, 2503.10' TVD 3,833.9 3,085,7 - 1,436.8 1,073.1 Start Dir 3.5/100' 3833.90' MD, 3085.70' TVD 7,953.7 6,050.4 -489.9 929.7 End Dir 7953.70' MD, 6050.40' TVD 8,153.7 6,053.0 -308.7 845.1 Start Dir 3.0/100' 8153.70' MD, 6053.00' TVD 8,155.3 6,053.0 -307.2 844.5 End Dir 8155.3' MD, 6053.00' TVD 8,382.6 6,056.2 -101.2 748.5 Start Dir 3.0/100' 8382.60' MD, 6056.20' TVD 8,505.9 6,056.4 9.5 694.2 End Dir 8505.90' MD, 6056.40' TVD 9,273.3 6,057.0 687.7 335.1 Start Dir 3.0/100' 9273.30' MD, 6057.00' TVD 9,479.1 6,057.8 866.2 232.7 End Dir 9479.10' MD, 6057.80' TVD 9,874.8 6,063.9 1,212.9 42.1 Start Dir 3.0/100' 9874.80' MD, 6063.90' TVD 10,697.2 6,078.5 1,520.5 -168.4 End Dir 10697.20' MD, 6078.50' TVD 11,540.7 6,093.5 1,827.4 -494.6 Start Dir 3.0/100' 11540.70' MD, 6093.50' TVD 11,700.8 6,097.7 2,329.4 - 1,172.3 End Dir 11700.80' MD, 6097.70' TVD 12,671.0 6,130.7 2,418.7 - 1,303.7 Start Dir 3.0/100' 12671.00' MD, 6130.70' TVD 12,720.5 6,132.2 2,419.3 - 1,304.7 End Dir 12720.50' MD,6132.20' TVD 13,129.0 6,142.8 2,931.4 - 2,128.0 Total Depth at 13129.00' MD, 6142.80' TVD 12/6/2007 6:25:56PM Page 9 COMPASS 2003.16 Build 42B UK% PROGRAM Well Punning - Pioneer - Oooguruk [ I ANT!•COL.LWSION SETTINGS note; )90$ -0! 40100:00:00 Validated*. Yet VorOonl 1 Calculation Method. Minimum Curvature interpoi9tton Method: MO, interval: 25.0 Error System: ISCWSA Depth Minot, From: 0.0 To 13508:3 t)optd Prom DNp1D To SurvsyfPlan Tool Scan Method: Tray. Cylinder North Centro Oietencv: 1550,8 0.0 2000.0 t)05K -361 KupD orpOJ Cit- GYRO -$S i Error Surface: Elliptical Conic Reference: Pion: 008K^361 Kupn wpOl 2000.0 13500.3 ORSK -361 kopl) 31p01 MWI4-SAtii{'A lir n +M Warning Method: Rules Based IODSN•10l 1St# 00i iI IS) 005114 Pe 10 104 1 It/DSN•ni 1N`, CPDO ,' - - -1000.4.2 Pa{ I INt s . Ioi1eN•S4i IN� , 1 005,14 a Pe¢, IODSN 31,PIV$ 1000440 PN1 1 IODSN•111 e1 1 1-1 1°13014, P"„ -o _ _ _ - 000N.2911Ni `� \ 7' 1 y } " ° �4 From Color To MD L 3 kr 1 1 1 , � a dGSN•1G PN l �t r r D8N 8 P$ Cdq 1 its !OWN 12 P51 s • • 1 1 1 .vJ " `1 1 0 250 _ SK•7 7 S1 ` � • � 1 t v i 0� 4 `M rr a ra k �' ., 1 -" 9.T; , .'ro ) S'`+�"°`,4 I 250 - 750 OD$ 1 �� .... L ►� C� "r �S" ` t " + " � i . A �i �4tISN97 c a d R < 1 ODSN•111 151. a s '4 , y .+ 60 s 1+ .,0. . 5 00 750 �,,.. • D3N 1S P i : ,12. t r " 750 0 QO$)t 35 Pull ',c °/, F a "+. - - - ' ' ` +. -..1 `' ' 1000 1250 « , ,y � $ 7,. • 7- N 25: iN ObSN•13 PS1 COQ N`.p f y . "T + Wwa t 80 1250 1500 OGSN•12 PS1 /7 1. 354 sr • I00$4461 !Si 4t 1750 "- 2000 1 r' M•30 F '4".''' R {tD ,N a 2000 _..- 2___22 2 2250 , y � CKJSN.14fiSU ' ; 2250 2500 / "`'r, ) - } , y. / 2500 2750 ik. 2 r'/ . ,, ; .f 11 I(t3ShIr PS'1i��f ''S^r �� 2750 - - -._._ .. 3000 1003 2 1 � ' '. $1f -0.li lfupf� 1 � , r � r r 1 ' �� ^e 3000 4000 270 � r ',,.:\q"'" �� � � OD 90 2 i 6 . � :� 1tl 2. ,il , 90 4000 5000 3" ' 4 ' t e 1 / `.0 ,i"A 6.41.,.0.; e rt; , 5000 6000 1 j g s .� v ..„+ ti !, 6000 7000 1 1 " t ' S CI ,. � � � � ' 1 tM3$DW1 Olmf sa Pl r f j 7000 8000 "0 f r t: N . , � 7 t9 - 9000 10000 8000 9000 Ic'osti +�, e � > , ' ^ I 1' �, ., 4 ! ii9 , ... ff / L1L751 kfl ;y ' ". - 120 11000 12000 ° " r a s ,y ] { � . .! 10000 11000 : { ( (Ot)SN -all INt 2 1 ' , r ' I1 1 ! , + . 120 12000 130 0 y 1 ' V t • ' , • A' 1 3000 14000 p „< l 4 :,, ' 150 t''� 14000 - 15000 210 y , firr'+ . , 15000 16 ' `°""' 009N-431 Ite14 , , i .'.;✓ 16000 17000 ODSN 40 r N1 180 . 17000 - 18000 I00SN -40 PN14 ODSN45 PNtilzio 150 18040 .. -_._. Travelling Cylinder Azimuth (TFO+ !Dearing) vs Centre to Centre Separation 140 it/inJ 1.1 19000 20000 180 20000 . ", ".'. 21000 21000 0 SECTION 507265 850 MD 3,44 AA 1VD 411.0 .HW OL. 1744. 73. 144991 1 00 000 000 00 0.0 00 000 0.00 0.0 2 200.0 000 000 1000 0.0 00 000 000 00 3 000.0 500 12000 799.4 -140 137 1.00 1060 -21.7 Travelling Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation 1100 ft/in1 4 10609 19.99 17060 1047.1 -960 41.7 2E0 Dm 442 5 103.2 2929 130.00 1050.0 -114.4 205.6 30 060 406.3 6 1007.5 2920 13000 1750.0 -30.4 2490 000 060 4445 7 2103.2 3500 13000 2000.0 -310.4 300 1 A9 000 4410 NAO 27 ASP Zone 4 : WELL DETAILS: ODSK-361 a ui.9 2ii 16 t1 3 -1:27 lmii aro 0.00 -177.7 10 7933.4 0224 336.00 00504 4529 0202 3.0 -173.0 .10059 11 0153.4 024 336.00 001.0 -300.7 045.1 0.00 000 413.9 5)4071 Ground Level: 13.5 12 0150.9 0420 33602 053.0 307.4 8445 3.0 14745 414.5 +N /-S +E/ -W Northing Esating • Ladttt9de Longitude Slot 14 64 900 3 6 -1 -77.1 73373 3.03 .1.71 4 KM. 72 0.0 0.0 6031065.83 469881.69 70.496 - 150.246 ODS-36 15 6567 59.96 332.10 0066.4 95 042 3.0 4095 484.1 16 5273.2 0.90 332.10 6067.0 076 335.9 0.0 000 249.4 17 93065 90.00 329.64 067.1 705.0 2750 360 4026 360.0 195013 10 547.8 5212 331.20 09674 05.1 2325 3.0 1094 .0 REFERENCE INFORMATION 20 102420 44.x2 333 800. Isms -15.11 MOD - 91..11 + 642 wsou 21 106006 06.06 300.63 075.5 1427.4 4949 3.0 4990 1641.9 Coordinate (N /E) Reference: Well ODSK36l • SIotODB -36. True North 2 I me4 8600 3.2555 �7 2 ai - 133 i:m -10im 60:1 1054376 • Vertical (TVD) Reference: 56° RKB la 560R a 11 60 842 201 4 5337 24123 -212/90 260 1 0 2 3677.6 Section (VS) Reference: Slot • OD536i0.6N. 9.91:1 26 137203 551 30047 61321 2957.4 -21704 300 -73.02 3525.0 6154075 Measured Depth Reference: 56' kKB a 56.0ft 27 135000 591 300 .47 6152.0 3360,5 -29452 00 0.00 43802 1441677 Calculation Method: Minimum Curvature ' • X Y TVD Dist from Ref Well at TVD Ref Well: ODSK -361 KupD wp01 470726.12 6030752.38 6053 ODSN -10i 1S9 wp08 470645.39 6031816.18 6053 1066.86 ODSN -37 PN8 wp08 469726.08 6030365.72 6053 1072.19 ODSN -32i IN7 wp10 470732.68 6031506.69 6053 321.56 ODSDW1 -44 Disposal 469818.51 6031016.65 6053 657.46 Plugged Back... • 40 1. McEVOY TYPE C 3 1/8' -5000 PSI GATE VALVE I 2. McEVOY TYPE C 2 9/16' -5000 PSI GATE VALVE 3. %TACO 2 1/16 -10000 PSI REMOTE CHOKE CHOKE MANIFOLD SCHEMATIC 4. THORNHILL- CRAVER 3 1/8' -5000 PSI MANUAL CHOKE NABORS ALASKA RIG 1 9AC 5. FLANKED TEE 2 or X 2 I/16' X 2 1/16' -5000 PSI 6. 5 WAY FLOW BLOCK 3 1/e X 3 I/r X 2 1/16' X 2 1/16 X 2 1 /16' -5000 PSI 7. 5 WAY FLOW BLOCK 3 1/8" X 3 I /8' X 3 1/r X 3 1/8' X 2 1/16' -5000 PSI 3° 8. 4 WAY FLOW BLOCK 2 1/16" X 2 1/16 X 2 or X 2 1/16" -5000 PSI T 9. 2 1/16' -5000 PSI SENSOR BLOCK 10. 2 1/16 10,000PS1 X 2 1/16' -5000 PSI SPOOL Sepqi q OR A 12. 3 % X X 2 2 1 1/16 -5000 PSI SPOOL 13. 3 1/8' -5000 PSI X 2 1/16' -5000 PSI SPOOL 15 2 14. 2 1/16' - 10,000 PSI X 2 1/16' -5000 PSI DOUBLE STUD ADAPTOR 15 15. 2 1/16' -5000 PSI TARGET RANGE 16. 3 1/8' -5000 PSI TARGET RANGE 3° p 20 17. 3 1/8" -5000 PSI X 2 1 /16' -5000 PSI DOUBLE STUD ADAPTOR AL, © 18. 3 1/8' X 3 1/8 5000 PSI SPOOL 19. 3 WAY FLOW BLOCK 3 1/8' X 3 1/8' X 3 1/8' -5000 PSI - 1 I 4 ` INE 2 I, 20. 5 WAY F LOW BLOCK 2 9/16 X 2 9/16" X 2 9/16' X 2 9/16" X 2 9/16' -5000 PSI • op 3" TD I is l° P kE 2 - -ba- 6,,, ,.. ..-- .....--4.0* o J 3 Eei O 13 � � © 6 d ,6 • A Nabors Akan IV:: — 1."1"= roT- "' NABORS ALASKA RIG MC as CHOKE MANIFOLD SCHEMATIC 6/14/07 TER REtiASED NO IPDNED P. DNERWII T.c REED ®° T.C. REED r - 19.42_0009 1 0t 1 I 1 )( I i HYDRIL 11" 5k PSI GK ANNULAR BOP 3' -11" SCREWED HEAD FLANGED BOTTQM CONNECTION ( 47 3/4 LENGTH _ - -- ----- i----- - - - - -p 11- 50001 4' -7" r FL ANGED HYDRIL 13'-10k _� — — — — DOUBL LENGTH ENTOR 3 1 /8" 5000 # HCR VA LVE • 111 3 1/8" 50001 HCR VALVE 3 " CHOKE LINE I i 11 - . II 11 i •'• 2 KILL L NE 3z2 3 1/8" 5000 GATE VALVE 1 i 1 -- L 3" 50001 GATE VALVE __— HYDRIL 11" 5k PSI 3'_4• E----- • - - - -- i — — — — — HYDRAULIC RAM SINGLE GATE FLANGED C I — 1___. i i II ...__E 41 3/4 LENGTH NABORS ALASKA RIG 19AC BOP STACK CONFIGURATION . • h OffAbp a �csn�"°." r 4�Dr� 107- 1 M103 -R7 maw WOKS Awn ma 1910 RaA BLON --OV/ PREMIER STACK COARCEOKON IMAK7 A Nit A RINSED INSED / D I/DIIED I ROMS RES ALSTON -ORE NNW A Im. bin Z' WI - mowsInaNIA I ""' AL 1004 O R An II C ODIO on of t • I ill! go '` I g I N 1. - ��� ' 1I 0MEI " it 1 ; ii ! 1 1 i 1, N I = Hg 3 c i o r 1 ...... _.1 j g . la L I I J. i Y i 0 I NO il . . + i. . . . 1 I lIti 419 I ii - f 1 '�' • :::: ■ i .-] f - - (t> - �z a — � , �_ � MU . 4 i i i L i 1 Legend 41. , • L ; .+ ;►". As —built Conductor k o � h , ill b 0 Prob.t catkin # ' y • 1 $ °1^f ■ 0 0 w ° ryg y t, e • • Location Map GRAPHIC SCALE .,`I• a • i ' u i ° ° �� +� a R, 1 , •% e 4. AE j e« •e. . 4.1 • ts p. •i • 0 • _ .,��� • 4 0 0.* f . N .� ; 4 ,1 • ;4111111,0 0 ° • ; $.0r �, / iiip G. Darn : .f 1q 0 , d'� No. 4110.5 • J4Ji • ry a , 4 � � pe• e•••Me X10 •s 1 k VF ESS10NAL le 1 • ° 0 k'` b 0 t ft, 0 b us : e 0 0 0 fi G1 y .1 T � t __ 0 0 .,�. • 0 0 Pioneer Natural Reseuoes JOB NAME: Oooguruk Drill Site DRAWN BY: BL I CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: 1 %.30' Township 13 North Range 7 East DATE: 7 -12 -07 Notes: umkt Meridian NANUQ JOB NO. SHEET Coordinates are listed on sheets 3 and 4 DESCRIPTION: Alaska Nad 27, Zone 4 Conductor As — built Plan 05204 I of 4 1 0 0 -- . i co 3 3 1 ti r r I _ it i ^•district Boundry 1 I ! \ ! . SE Corner of i c t \ o00cURUK sTE Protracted Section111 • It 7 8 a o I, - �f ft Coordinates !. N 6028111.04 > y 1 i E 470989.01 ' I • A • $ P'- 4 �� Ref AK BLM .s I o: j i * ` f Harrison . Bay Tract! "A" ' 101 -24\ Record �. I�ro i: � ; � `. ,' 4j r wi • 1 r....... ,.. : \ • v,- �- '9' . >7 x • , . : AC1 s a i- 12 4s Offshor i fc =599 Jk es •4 y � � • eor Share 1«road =3.S 2" mks , � 1 3 i fr.... _' I n a A , - t 1 La ii A a /��..1rp' 1 ' w -1� Tundra Scarce i I Is r - s � m as s r % s P1 • - Roods to-Lob • - / /�` Bas of Location (7i Fa � EN West Monument ts -• PI i , Coordinates s N 6001016.61 E 498081.23 STAKED Pi INFORMIA liON ONLY kir - • * ,-,. It a *a 9 m :. I Ref. Lownsbury & Assoc. W • ;:4 I c Drawing No. rte.. NSK 6.01 —d672 1f •; ` 0 N • •,J . ••• 1 i t r 0 .`; h . taa 21,1 • flip G. Davis • ? ' V � % a sew I No. 4110-S . : ab/ 5 t - "" '-. , ,-. OF FSSIOMPO . 41 ' Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North . Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 --- - - -- ____ _AO _ Ala$ka State Plane - Section Line ()ftef -- -- ' Well No, Latitocie (N) 1,,Qn9itude. (W) -- Pad [j __ _ ___ _ _ _ ___ _ 1 0,001,151.32 409,920,45 70 29 46.24160 150 14 45,46463 3035 1077 13,50 2 0,03 409,915.02 70294619252 150j4 4560.922 303Q 1082 13. 4 6,031,14130 469,910:59 70 4671435415 0 14 45,7 --- 4 10 1 4 6,031,136.46 469,905,67 70 29 40.094$6 150 14 45.89799 3020 1092 13.60 5 - 6,031,131746 -- -- 469,900,74 7 0 - 2048.04538 - 150 14 . 3015 - 100 - 13,50 6 0,031,126,51 469,895,80 70 29 45,99060 150 14 40,18735 3010 1102 13,50 7 6,031,113,73 409,883.13 70 29 45,57039 1501440:55879 2997 1115 13;50 8 8,031,108,73 469,873.21 70 29 4562102 130 14 40,7030.3 2992 1120 13,50 9 6,031,103.75 469,873,26 70 29 45.77184 100 14 46.84314 2967 1125 13,5 10 6,031,098.79 409,868,06 70 29 4 5 , 72280 100 14 46,99179 2982 1130 13,50 NEM 0,001,093,84 469663.39 70 29 45,67398 150 14 47,13750 2977 MEM 13,50 -1101W1111 • e , i; ;.;: • f . : • ? O2 - 4 62490 - 1501447.28174 2972 1140 13,50 -- 6,031,07006 ---- 469,845,61 ------ 702945,4064 ---- 130 14 47.05288 2960 1152 1450. 6,031,071 09 4 6 9 , 840 . 37 70 20 4044932 15014 2955 1157 13,0 15 6,031,060.15 469,835,96 70 29445,40053 150 1 47,94165 2950 1162 13,50 ----- -- 6,001,061.18 469,831,04 70 29 150 14 43.0858 ti 1161 - 13,50 17 0,031,056,25 409,826,11 70 2945,30271 15Q 1448,2304r 2940 11 1150 18 6,W1,051.27 469,621,16 70 29 45,25309 150 14 46,37495 2935 1177 --- 0 489,808,50 70 200J - 2 1189Q 20 6, osi,QS.Z50 460,e03, 59 70 20 45.07511 150 1 - 2:917 119 i 21 0,031,026:53 - 46_9,796,62 70 2 45490a 14 4 2912 119 13,50 -- n 6,031,02358 460,793,67 70 29 44,96 014 -- 15014 49,181:44 29 - 1 - 2 - 0 - 47 - 1 23 6,031016,57 --- 469,7e6,76 70 29 iw 14 49,3237 - 2902 1209 1350 24 6,031;0f3,00 469,733,6T 70 29 44,86159 150 14 49,40900 2897 1214 13,50 ,..a■Z OF 44,9411% , 4..S. , . ...u4. r-J r4...- 41.1 i if lir 9 P•I ••• so •• • ,..........• • • _ -,-- • 4 • •• - „.0101:011- i I • • 13 - (2,1 Doris : i t .. .4 f 0 -- .-= Philip G. Dor ---,....:..,, ...„.„. • li' I. No. 4110.$ Q . 4070 IV. ' - .A, ,--. - ; 1 ' di V Se A 49 p • *3 . A , . :::: li, AZ . ,%- Re2tts: `.-,i 1_ levetions c_ire .bcised on 8P Mn Sec LeVei. 2 Coorefinotes ore based on A1.1<s? State Plane No 27, Zone 4, . 3, All conclvotors ore within Protroctecl Section 11. - Pioneer Nit:tura! Reeowces , 309 NAME: oQoguruk Drill Site Conductors DRAWN BY: Bt. CHECKED BY: MA) LOCATION: prgtrgcted Section ii SCALE' N/A Township 13 Ngrth . _ . Range 7 Eet DATE: 7-12-07 Urniet Meridian _____ .._ __ NANUQ JOB NO. -SHEET DESCRIPT101■1: As-built ce,.ordincte 05204 3 of 4 ____ Alaska. State Plane Section Line Offset - - WeII -No: Y X -Lat-it - - - , • • •' • ; &h. FEt Pad Elev. 25 6,031,128.32 ' 469, 943.64 70 29 46.01630 150 14 44.77930 ' 3013 1055 13.50 26 6,031,123.35 469, 938.69 70 29 45:96722 150 14 44.92442 ' 3008 1060 13.50 27 6,031,118.33 469, 933.76 70 29 45.91765 ' 150 14 45.06895 ' 300 1065 13.50 _ 28 6,031,113.39 469,928.86 70 29 45.86887 150 14 45.21260 2997 1070 , 13.50 29. " 6,031,108.44 469,923.95 70 29 45.81999 , 150 14 45.35655 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50 31 6, 031, 090.65 469, 906.38 70 29 45.64431 150 14 45.87163 2975 1092 13.50 32 6, 031, 085.68 T 469, 901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 ,/ 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 ' 1116 ' 13.50 0 29 45 andahh 7 .... 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6, 031, 043.03 469, 859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 13.50 41 6,031,033.05 469,849.29 70 29 45.07551 , 150 14 47.54530 2917 1149 ' 13.50 42 6, 031, 028.13 469, 844.38 70 29 45.02692 150 14 47.68925 2912 1154 13.50 43 6, 031, 015.46 469, 831.70 70 29 44.90180 ' 150 14 48.06099 2899 1166 13.50 44 ' 6, 031, 010.49 469, 826.79 70 29 44.85272 _ 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 ' 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 469,811.98 70 29'44.70469 150 14 48.63910 2879 1186 ' 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 . .� �F1�L x `a SURVEYOR'S CERTIFICATE i � �. . ' - __ °S' .j-. � � .. _.. I .- HEREBY CERTIFY THAT I AM V, •'• _ V Ai PROPERLY REGISTERED AND % �` r T a LICENSED TO PRACTICE LAND _, "' SURVEYING IN THE STATE OF . . ` . ALASKA AND THAT Ti-IUS PLAT ,7, ;,./.--4,. ' -, ; , Ij 0 • . il G. Davis o I REPRESENTS A SURVEY DONE BY �' cif e 4i ias . 5J 4440 ME OR AN D THAT ALL Y: *l k, p o E i s ta N t V . 4 / DIMENSIONS AND OTHER DETAILS 5 4 y ' „ 7 l‘q�,,,,, ARE CORRECT AS SUBMITTED TO _' __ ME BY NANUQ, INC. AS OF JULY '-'2--.-..:::_.- 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD, LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 • • ODSK -36i Kuparuk Injection Well Proposed Completion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 16" Conductor Alf 1 162' MDrkb / 106' TVDss 3 -1/2" ScSSSV, 2.813" ID © -750' 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3345' MDrkb / 2806' TVDrkb � 3 -1/2 ", 9.3# L -80 TSHP Estimated Top of Cement @ 5495' MD / -4511' TVDrkb 3 -1/2" MMG GLM @ 7240' MD / 5889' TVDrkb X Nipple, 2.813" ID v 7" x 4 -1/2" Packer ©- 7270'MD / 5902' TVDrkb ■ XN Nipple, 2.725" ID Nogo ■ @ 7300' MD, 66 degrees 8154' MDrkb / 6053' TVDrkb 4 -1/2" Slotted Liner 7 ", 26# L -80 BTC -M, 6.276" ID 13129' MDrkb / 6142' TVDrkb Date: Revision By: Comments 12/7/2007 JDF Proposed Completion itiOi ODSK -36i Injector Well Schematic PIONEER NATURAL RI - Page 1 of 1 • • Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Thursday, January 10, 2008 1:39 PM To: Maunder, Thomas E (DOA) Subject: ODSK -361 Tom, No one to blame but me. The TD of the well is in Section 2. Very sorry. I hate making stupid mistakes... RCS Pc*� c O V \ \ james fkr-o•covs. IB James Franks Drilling Engineer c c�� 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 III II Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, January 09, 2008 9:59 PM To: Franks, James Subject: RE: ODSK -36i Thanks James. I know how things can go. I will add this information to the packets. Tom Maunder, PE AOGCC Original Message From: Franks, James [mailto:James.Franks @pxd.com] Sent: Wed 1/9/2008 5:25 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe Subject: ODSK -36i e Tom, \ nSCc Cs C) \ ci, ) ) \ZLC0.\-- Apparently 114 1 1 [...I am not going to hand deliver today: -). ,tr'T.-- Attached is a view of the traveling cylinder for the ODSK -36i well and a spreadsheet outlining the wells within a mile of the injection point for that well. Also attached is the traveling cylinder for the ODSK -35 well. Thanks for your time. Any questions, just give a shout. 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 • Page 1 of 2 Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] 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 al 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 -32i 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- 32i 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 will©. 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 Days Drill End Date y 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 Page 2 of 2 ODSN -39i - Batch Drill Surface IN11 4/14/2008 l 3.7 4/18/2008 ODSN -38 - Batch Drill Surface PN10 4/18/2008 3.6 4/21/2008 ODSN -40 - PN12 - I,P,C 4/21/2008 23.1 5/14/2008 ODSN -391 - IN11 - I,P,C 5/14/2008 20.9 6/4/2008 ODSN -37 - Batch Drill Surface PN8 _ 6/4/2008 3.6 6/8/2008 ODSN -31 - Batch Drill Surface PN6 6/8/2008 1 3.7 6/11/2008 ODSN -30 - Batch Drill Surface PN5 6/11/2008 3.9 6/15/2008 ODSN -29i - Batch Drill Surface IN4 6/15/2008 4.2 6/19/2008 ODSN -30 - PN5 - I,P,C 6/19/2008 20.4 7/10/2008 _ ODSN -43i - IN13 - SIP,C 7/10/2008 27.0 8/6/2008 ODSN -45 - PN14 - S,I,P,C 8/6/2008 31.7 9/6/2008 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 %< 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 prior 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 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 0 3,6 PTD# 242)7 - 7E 2-- Development E. 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 function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non - Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 7/13/2007 WELL PERMIT CHECKLIST Field & Pool 000GURUK, KUPARUK UNDEF OIL - 576100 Well Name: 000GURUK KUP ODSK -36 Program SER .WeII bore seg ❑ PTD#: 2071820 Company PIONEER NATURAL RESOURCES ALASKA INC. Initial Class/Type _ SER / PEND GeoArea 973 Unit 11550 On/Off Shore -erroardrekAnnular Disposal ❑ Administration 11 Permit fee attached NA 11 Lease n appropriate Yes Entire well in AOL 355036 3 Unique well_ name _and number Yes 14 _Well located in_a_ defined _pool No Pool rule in progress, AIO_applicationreceived. _Currently Oooguruk- Kuparuk Undef pool. 115 Weltlocated proper distance from drilling unit boundary Yes 6 Welllocated proper distance from other wells Yes 17 Sufficient acreage available in_driiling unit Yes 8 if deviated, is weilbore plat_inciuded Yes 119 Operator only affected party Yes 10 Operator hes_appropriate bond inforce Yes 11 Permit can be issued without conservation order Yes Appr Date 112 Permit can be issued without edministrative_approval Yes SFD 1/4/2008 ' Can permit be approved before 15- dey_wait Yes 14 Welllocated within aree and strata authorized by Injection Order # (put10# in comments) (For No AIO application _received. • 115 All wells_within 1 /4_rnite area of review identified (For service well only) Yes ODSDW - 01-44 OOSK -35 16 Pre - produced injector; duration of pre production less than 3 months_ (For service well only) No Well will be produced only to clean out drilling fluids. 17 _Nor►oonyen, gas _conforms to AS31,05030(j,1.A),(j,2.A -D) NA Engineering 118 Conductor string_provlded Yes 19 Surface casing_protects all_known U$DWs Yes Surface location is offshore. No known USDWs. 120 CMT v_oi adequate_ to circuiate_on conductor & surf csg Yes 1121 CMT vol adequate to tie- inlong string to surf csg No Planned TOO 500' above disposal zone. X22 CMT_will cover all knownproductive horizons No Slotted liner completion planned. 123 Casing designs adequate for C, T, B & permafrost Yes 1124 Adequate tankage_or reserve pit Yes Rig is equipped with steel pits. No reserve pit planned. All waste to_approved disposal well. 25 i f a_ re- drill, has_ a 10-403 for abendonment been approved NA 126 Adequatewetlbore separation proposed Yes Traveling cylinder path_ calculated._ Gyros and _magnetic ranging planned in_ surface section. 27 if_diverter_req_uired, does it meet regulations Yes Appr Date X28 Drilling fluid_ prograrn schematic_& equiplist adequate No Maximum expected formation pressure 9.8 EMW. Mud weight planned up to 11,0 ppg. TEM 1/10/2008 29 BOPEs,_dothey _meet regulation Yes t y,� ;30 BOPE_press rating appropriate; test to (put psig in comments) Yes MA$P calculated at 23 rpsi_ 4500_psi_BOP testplanned. �°+ 31 Choke _manifold complies w /API_ RP -53 (_May 84) Yes 32 Work will occur without operation shutdown No Surface section will be batch drilled._ Plan is to drill remainder of well this winter season. 1 ! 33 Js presence of H2$ gas probable No H2S has not been reported in any offset wells. 134 _Mechanical condition of wells within AOR verified (For service well only Yes No other weals currently exist in AOR._ Any future wells_will be evaluated. Geology 1 35 Permit can be issued _Wit/ hydrogen sulfide measures Yes Not expected. Well will be mud logged and H2$ sensors will be operational. 136 Data_presented on potential overpressurezon_es Yes Expected r_eservoirp_ressure is 9.8PP_G EMW; will be drilled with_10,4_ppg mud. Appr Date 137 Seismic analysis of shallow gas zones NA SFD 1/4/2008 38 Seabed condition survey (if off-shore) NA 139 Contact name /phone for weekiy_prog_ress reports [exploratory only] NA Geologic Engineering Public Date Commissioner: Date: Co issioner Date C• sioner ,ji,rs / // 06 ,, DT, 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. END OF WELL REPORT ODSN-36 Oooguruk Development Surface Data Logging Services TABLE OF CONTENTS General Information Daily Summary Morning Reports Bit Record Mud Record Show Reports Formation Tops Survey Report Days vs. Depth Digital Data including: ASCII with C-Ratio End of Well Report ADI EMF & Log Viewer Mud, Engineering & Gas Ratio Logs Logs for PB1, PB2 & ODSN-36 Combination Mud Engineering Gas Ratio GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-36 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20561-00 Sperry Job Number: AK-AM-5556280 / AK-AM-6519888 Job Start Date: 28 Jan 2008 – 4 Feb 2008 25 Feb 2009 – 24 Apr 2009 18 Jul 2009 – 13 Aug 2009 Spud Date: 30 Jan 2008 Total Depth: Surface Section drilled to 3683'MD, 3026’TVD Intermediate Section to 10625’ MD, 6398’TVD Production Section to 17525’ MD, 6379’ TVD Rig Release Date: 14 Aug 2009 North Reference: True Declination: 22.700° Dip Angle: 80.878° Total Field Strength: 57617 nT Date Of Magnetic Data: 28 Jan 2008 Wellhead Coordinates N: North 70° 29’ 45.40” Wellhead Coordinates W: West 150° 14’ 46.60“ Drill Floor Elevation 44.54’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: Colby Marks, Boyd Piercey, Eugene Payne, Tom Mansfield, Wayne Hermanson, Danny Kane, Dan Sherwood Company Geologist: Jacque Ledbetter, Paul Cozma, Jim Stewart, Mindaugas Kuzminskas Company Representatives: Rod Klepzig, Jim Brown, Nick Scales, Joey Cortez, Vic Parsell, Joe Polya SSDS Unit Number: 123 DAILY SUMMARY 01/28/2008 Prepare and move rig to ODSK – 36i. Level modules and clean up pad. Rig up utilities and stairs. Held Arktos evacuation drill. Rig up utility lines to RSC. Thaw frozen lines and install berm under CPU. Spot beaver slide base and lower slide. Install skate ramp, walkways and stairs. Nipple up riser, spacer spools, surface annular preventer and knife valve. 01/29/2008 Nipple up 21-1/4” diverter system. Installed air boot on riser and install mouse hole. Hook up hydraulics to bag and knife valve. Rig and make up turnbuckles. Change out kill line hose and put heater trunk on knife valve and cleaned cellar. Install 16” diverter line and clamp it. Function test annular knife valve. Install environmental seal in rig cellar to well bay, air up conductor and air boot seal. Move casing and thaw lines from tank farm. Transfer 500bbls spud mud to pits. Pick up BHA and load pipe shed with 9-5/8” casing. Perform diverter test, function bag/knife valve. Perform accumulator test and check alarms lights and monitors. Reconfigure staging area Herculite under CCU on rig for Guzzler trucks. Hold pre job safety meeting before picking up BHA #1. Pick up and make up BHA #1 with a 1.5° bent motor and new MXL – 1 12-1/4” bit then run it in hole. 01/30/2008 .Make up 1 stand heavy weight drill pipe and top drive. Hole was filled and a check for leaks was performed. Gyro line was picked up. Wash and ream from 58’ to 153’ to the conductor shoe. Drilling 12-1/4” hole from 221 to 264’. A single was laid down and the gyro survey was performed, two stands were pulled and remainder of BHA was made up and run in hole. Drilling 12-1/4” hole from 264 to 1,383’. 01/31/2008 Drill 12-1/4” hole from 1,384’ to 2,444’ with 650gpm, 2,480psi off and differential pressure observed at 150 – 200psi. WOB observed at 10 – 25klbs, 80 RPM, 2k-ft lbs off and 4f#s on torque. Up weight =88K, rot weight = 92K. ADT = 6.23 hours, ART = 2.5 hours and AST = 3.98 hours. Total time for surveying 1383’ to 2444’ on every stand drilled down. Drilling commenced from 2444’ to 3314’ with 650gpm, 2480psi off and 150 – 200psi differential pressure. WOB observed at 10 – 25K, 80 RPM = 2K ft#s off and 4K ft#s on torque. Up weight = 112K, down weight = 88K, and ROT weight = 92K. ADT = 6.23 hours, ART = 2.25 hours, AST = 3.98 hours. Total time for surveying, 2444’ – 3314’ on every stand drilled down. 02/01/2008 Drill 12.25” surface hole from 3314’ to 3646’ with 650gpm, 2800psi on and 2500psi off and a 150 to 200 differential pressure. WOB was observed at 10 to 25K, RPM of 80, 3Kft #s off and 5 Kft#s on torque. UP weight of 118K and down weight of 98K and a ROT weight of 95K. Circulate the hole to examine cuttings samples for correlation. Continue drilling section to TD of 3683 with same drilling parameters as before. ADT = 3.36 hours, ART = 2.38 hours and AST = 0.98 hours. Survey time = 20 minutes. The hole was then circulated and conditioned for wiper trip. A 65 bbl high viscosity sweep was circulated for two bottoms up until shakers cleaned up. POOH to 3605’ and run gamma at 150 feet per hour. A tight spot was encountered at 3590’ and 50K was needed to pull it. Continue POOH 3216’ and pump dry job. Another tight spot was encountered at 2040’ and it was necessary to pump out of the hole to 200’ at 500gpm, 50 RPM, 1200psi. Blow down the top drive. TIH with heavy weight drill pipe and drill from 200’ to 1882’. The hole was again circulated and conditioned with a tight spot encountered at 1882’, with 500gpm, 80 RPM, 100 psi. Continue to TIH to 1924’ through another tight spot. Wash and ream from 1924’ to 3602 ft at 500gpm, 75 RPM, 1850psi. Surveys taken at 2682’, 2779’, 2875’. 02/02/2008 Wash and ream to bottom from 3663’ to 3683’. The hole was circulated and conditioned using 650gpm while stroking the pipe. A 60bbl weighted, 130 viscosity sweep was pumped followed by a 70 bbl high viscosity 200+ sweep. Pull 4 stands out of hole to 3295’, pulling tight from 3517’ to 3462’, with 25K. Continue POOH with additional tight spots from 3400’ to 3325’ using 50 K. Pump out to 3295’ and trip back into hole to 3683’ with up weight of 125K and down weight of 90K. The hole was again circulated and conditioned with 50bbl of 20ppb walnut and 1 bag of SAPP sweep at 700gpm and 2800psi. POOH with tight spots at 3268’ to 3235’, pulling 50K over, working up and down. Final pick up weight 25K over. Continue to POOH to 2734’ and make up top drive. Circulate and condition hole again and pump a 25bbl dry job. POOH from 2734’ to 180’ with the hole taking proper fill and with no excess drag. MWD tools and drill collars were stood back and tools were retrieved from MWD. The bit was then broken off and stood back with the rest of the BHA. Pick up and rig up 9 5/8” casing tools and equipment and change out the bales. Pick up and make up casing fill up tool, landing joint and hanger, then make a dummy run. Pick up casing shoe, middle joint, float collar and baker lock, making up to 8400ft #s. Fill and check float equipment and commence running 9 5/8” casing to 1282’. 02/03/2008 Run 9 5/8” casing to 3619’. Pick up landing joint and land casing shoe at 3665’ with up weights of 195K and down weights of 95K. Cement lines were installed and Franks tools were rigged down. Blow down the top drive, and rig up cement head and hose to circulate. Break circulation with rig pumps and reciprocate casing while establishing BPM with step rate. Establish and hold rate for 3 to 5 minutes before increasing to next rate. It was staged up to 1bpm slowly in ¼ to ½bpm increases. 2bpm = 300psi, 3bpm = 500psi, 4bpm = 550psi, 5bpm = 750psi, 6bpm = 1100psi, 7bpm = 1350psi and 8bpm = 1750psi was observed with no lost circulation. A pre job safety meeting was held prior to the cement job. Pump 5 bbls of water. Test lines to 3000 psi and chart. Pump 5 bbls fresh water, followed by 40bbls of 10ppg spacer, 324bbls of 10.7ppg lead cement. Drop bottom plug and pump 42bbls of 15.9ppg tail cement and drop the top plug. Pump 10bbls of water. Switch to rig pump and displace cement with seawater at 8 bpm with 1500 to 2000psi observed. Bump plug with 2360 strokes and 500psi. CIP at 13:40. 70 bbls of 10.7 ppg cement was recovered. Rig down cement head, landing joint, elevators and spiders. C/O bales, flush and clean riser. The rig floor was then cleared and cleaned. Rig up to cellar with pump for seawater. Trip in hole with 21 stands drill pipe to 2023’ to displace fluid by metal displacement only. POOH and prepare to nipple down diverter system. 02/04/2008 Nipple down diverter system and remove equipment from cellar. Pull landing joint and lay down. Finish nippling down diverter system and surface stack. Pick up and spot Vetco Grey multi bowl in well bay for next well. Spot top valve for tree in well bay and test multi bowl to 5000psi for 10 minutes and clean up well bay. Rig up 2 7/8” tubing equipment, hold a pre job safety meeting and run tubing to 1903’. Make up Vetco Grey tubing hanger and land same. RILDS. Test hanger to 5000psi for 10 minutes. Lay down landing joint and rig down tubing running equipment. Hold another pre job safety meeting before nippling up tree, test void to 5000psi with Vetco Grey hand. Rig up all lines for casing test and displace well to diesel for freeze protection. Hold pre job safety meeting. Line pumps on seawater and pump and confirm circulation to pits and check lines. Close top valve on tree and pump down 9 5/8” x 2 7/8” annulus, 8 bbls at ½ to 1 bpm to 3500 psi on the casing test. Hold for 30 minutes with a good test confirmed. Line up Nabors pump #1 with diesel. Line up all valves from tree and pump 155 bbls diesel at 1 – 2 bpm by reversing down the 9 5/8” x 2 7/8” annulus and up inside of tubing to Nabors pits, monitoring pit volume returned and volume pumped by gauging diesel tanks. Shut down diesel and flushed pumps with 4 bbls. Pumps and lines were then cleaned. 1 bbl of diesel returned to pits. Let equalize and shut ion both valves. Lines were then blown down and nippled down. Well bay area and cellar was then cleaned and preparations to move the rig were performed. Rig was released at 24:00. This well was initially drilled to a Surface TD of 3683’ and suspended. The name has been changed from ODSK 36i to ODSN 36. 02/25/2009 Move rig from well ODSN-34i to ODSN-36. Circulate out 155bbls of freeze protect diesel. Nipple down tree. Nipple up BOPE. POOH, lay down 1,900’ of 2-7/8" tubing. Run in hole with 5" drill pipe. POOH with 5" drill pipe inspecting hardbanding. Lay down bad hardbanding and replace with new 5”. 02/26/2009 POOH and lay down 40 joints of drill pipe with bad hardbanding. Test BOPs as per AOGCC permit to 250psi low & 3,500psi high. Tested 2 each 5" drill pipe rams, blind rams, manual choke and kill, HCR choke and kill, 14 choke manifold valves, floor safety valve, floor dart valve, upper and lower TD IBOP valves. Annular tested to 250-2,500 psi. Accumulator test, 3,100 psi initial, 1min 42sec recovery time, 3,100psi final pressure. AOGCC, PI, John Crisp waived witnessing test. Make up and run in hole with 8-3/4" bottom hole assembly. Run in hole to 3,529'MD. 02/27/2009 Drill out cement and float equipment. Change over mud system to 9.2ppg LSN mud. Drill 20' of new 8-3/4" open hole to 3,703'MD. Perform LOT at 3,015'TVD with 790 psi surface pressure = 14.25ppg MWE. MWD/LWD/Geo-pilot failure to communicate. Trip for BHA to reset parameters in MWD/LWD tools. Trip BHA to bottom at 3,703' and prepare for drilling. Both trips out and in the hole went well with the hole taking and giving back proper displacement. Gas values were minimal with a maximum amount of 53 units observed. 02/28/2009 Drill and survey 8-3/4" hole per well plan #12, (3,703'MD-5,614'MD). At or near 5092’MD we encountered a sand stringer which saw a peak gas value of 2669 units over a background level of 169 units. This was the maximum amount observed and gas values averaged 145 units for the day. 03/01/2009 Drill and survey 8-3/4" Open Hole Section from 7,322'MD to 7,417'MD, (called TD by Well Site Geologists). Observed base of Torok formation at 7,334'. CBU 4x's per well plan, and rack back 1 stand every hr. Well bore appeared clean, and run in hole to bottom, (flow check static). Blow down top drive and POOH on elevators, 7,417'-4,650'. Gas values maxed out for the day at 756 units at 6978’MD, while averaging 158 units for the day. 03/02/2009 Drill and survey 8-3/4" open hole section per well plan #12, to 7,417'MD, (Base Torok at 7,334'MD). Circulate bottoms up 4x and run in hole to bottom. Flow check, (Static), and POOH on elevators to 3,620'MD. Circulate bottoms up 1.5x and slip/cut drilling line. Service rig and top drive system, crown. Pre job safety meeting, change out RCD element per MPD Rep. Run in hole to 7,417'MD and stage up circulation. Perform 400 bbls dilution and raise mud weight to 10.5ppg. Perform Dynamic FIT to 12.5ppg EMW and continue to drill 8-3/4" hole section, 7,417'MD-7,986'MD, maintaining 12.5ppg ECD with MPD. 03/03/2009 Drill and survey 8-3/4" open hole section per well plan #12, to 7,986'MD-9,691'MD, (Top HRZ at 8,659'MD). Observed top of Kuparuk 'C' formation at 9,522'MD. Lost 40% returns while drilling. Unable to drill ahead with current loss rate. RCD building mud volume. Loss rate at 300bph. Contact ODS Senior Drilling Engineer and discuss options. Decision made to short trip drill string and build mud volume in attempt to regain full circulation. Work pipe, and build mud volume. Prepare to trip drill string to 8,600'MD. Gas values continued to follow the normal trend for this interval with a maximum gas of 1622 units, an average of 350 units and connection gas averaging 300plus units over background gas. 03/04/2009 POOH, 9,691'MD-8,555'MD, with some issues, (no swabbing-but lost 40bbls to hole). Build volume at rig pits and RSC, while losing 90bph to hole with MPD trying to maintain 12.2-12.5ppg ECD. Reduce to ½bpm pump rate with minimum back pressure and well bore static on losses. Build 40 #/bbl high-viscosity sweep BaraCarb/BaraFibre/Steel Seal pill and run in hole 9,407'. Wash-ream 9,407'-9,636’MD and spot 50 bbls LCM pill. Allow to soak while applying back pressure with MPD, (11.69ppg ECD). Clean out to 9,691' and drill to 9,754'MD, losses at 150bph at 550gpm = 19.1% loss rate. Mix and spot 50bbls high-viscosity /40+ #/bbl LCM pill and POOH to 8,555'MD. Build volume and circulate with 300-400gpm, (no losses-75bph at 500gpm). Decision made for DOB2C pill if unable to maintain drilling 12.5ppg ECD. Run in hole to 9,754' without issues and drill 9,754’-9,805'MD, with manageable losses to 9,795', where open Micro Fractures and 200bph losses from 550 gpm and 12.5ppg ECD. POOH to 8,550'MD, work on TDS (Change out I-BOP valve) and continue building mud volume. With minimal returns, gas values fluctuated with intermittent flow. Gas values were observed with a maximum of 3223 units on bottoms up after tripping back into the hole and an average value for the day at 150 units. 03/05/2009 Continue to build volume at RSC and rig pits, in preparation for spotting DOB2C LCM slurry. Once able to ensure enough mud volume for operation, assembly was run in hole, 8,550'MD- 9,240'MD. Wash ream 9,240'MD-9,450'MD, due to slight tight hole encountered. Establish 1- 4bpm circulation rates, and loss rate, with no losses at 1bpm and 75bph loss rate at 4bpm. Consult town superintendent and ODE with results and overview calculated volumes final time. Line up on HT Cement pump and flush lines with LVT and pressure test to 2,500psi, (ok). Pump 15bbls LVT, 22.5bbls DOB2C slurry, (including 66 sacks Premium Cement and 50bbls Sea Mud Gel = 62 sacks) /20bbls LVT. Displace with 106.6bbls fresh mud. Close MPD RCD and go through Kill Line with mud pumps, after ensuring line clear. Spot DOB2C slurry with 2:1 ratio mud LCM pill with 4bpm mud at 850-1,100psi and 2bpm = 1,100-1,400psi with 500psi well head pressure MPD, for 60bbls total mud, (136.6bbl pumped). Switched to 1:1 ratio at 2bpm each, but pressures were begging to exceed maximum, per program schedule, so had to drop 1:1 ratio back to 1bpm, (+/-1,400psi on DP side, and 1,100psi annular at 2bpm rate). With the rates dropped to 1bpm = 600psi annular side and 1,280psi on DP side. Continue with 1:1 for 20bbls total mud pumped, (154.6bbls), with DOB2C LCM slurry in place at 13:06hrs. Read and record pressures with ISIP of DP = 1,050psi, annular = 600psi, and well head pressure= 520psi. FSIP after 10 minutes= DP= 675psi, Annular = 430psi, and WHP = 480psi. Strip out of hole and displace .8bbls/std, (= 8-9 strokes per stand.), while maintaining 480psi WHP on MPD. Stand #1 was 385-400klbs and tight, and stand #2 was 380klbs. Seemed to get better on next stand with normal 350-375klbs, and continued to POOH to 8,540'MD, where able to apply 11ppg ECD on MPD, and circulate at 100-150gpm without losses. Waited until 21:30hr to give DOB2C LCM slurry time to cure. A dynamic FIT of 550gpm, with 12.5ppg ECD on MPD was then performed without losses recorded. Decision made to run in hole after finding out MWD had quit pulsing, (had 500-700psi extra pressure from possible plugged nozzles). Gas values during the trip were observed upwards of 3000 units averaging 150 for the day, with higher amounts appearing to be associated with packoff episodes. 03/06/2009 Pull up out of packed off hole, 9,122'MD-8,936'MD. Ream wash, 8,936'MD-9,320'MD, (experiencing pack offs and tight hole). MPD RCD element failing - lower seal). POOH, 9,320'MD-8,543'MD. Bleed off Annulus pressure, (no open Kuparik "C"), remove Gray Lock and change out RCD element per HES. Test same, (ok). Run in hole 8,543'MD-9,320'MD, without issues. Ream wash, 9,320'MD-9,661'MD, some (losses occurred at 9,520'MD and then healed up - currently +/-10BPH with 550gpm flow and 12.5ppg ECD). Gas values topped the 5000 mark at 5250 units and continue to be associated with packoff episodes. The daily average was observed at 220 units. 03/07/2009 Continue to ream/wash 9,775'-9,809'MD. Once on bottom, POOH to 8,540' without issues. Prepare for spotting DOB2C LCM slurry. Run in hole 8,540'-9,465'MD. Establish 1-4bpm circulation rates, and loss rate, with 42bph at 1bpm and 138bph loss rate at 4bpm, with 12.5ppg ECD. Consult Town ODE with results and overview procedure. Line up on HT Cement pump and flush lines with LVT and pressure test to 3,000psi, (ok). Pump 15bbls LVT/25bbls DOB2C Slurry, (incl. 66 sacks Premium Cement. and 50 #/sack Sea Mud Gel = 62 sacks)/20 LVT. Displace with 103bbls fresh mud. Close MPD RCD and go through Kill Line with mud pumps, after ensuring line clear. Spot DOB2C Slurry with 2:1 ratio mud/LCM pill with 4bpm mud at 980-1,100psi and 2bpm = 887-1,132psi with 550psi well head pressure MPD, for 50bbls total mud, (128 BBL pumped). Switched to 1:1 ratio at 2bpm each, with pressures at 725psi on drill pipe side, and 1,100-1,280psi Annular at 2bpm). Continue with 1:1 for 20bbls total mud pumped, (148bbls), with DOB2C LCM Slurry In place at 17:07hrs. Read and record pressures with ISIP of drill pipe = 960psi, annular = 647psi, and well head pressure = 540psi. FSIP after 5 minutes: drill pipe = 642psi, annular = 642psi, and well head pressure = 510psi. POOH and top of first stand, pulled pump at 2,100psi, 430gpm, for 144 strokes to clear tools of pill. Strip out of hole and displace .8 bbls/stand, (= 8-9 strokes per stand.), while maintaining 550psi well head pressure on MPD and continued to POOH to 8,540’MD; where able to apply 12.5ppg ECD on MPD, and circulate at 100- 300gpm without losses. Cut back to 150gpm, but experience pack off 7 lost 26bbls. Consult town ODE after establishing no losses with12.5ppg ECD. POOH 8,540'-5,709'MD without issues. Gas values for the day maxed out at 521 while maintaining an average of 300 units. With only partial returns, possum belly levels were too low to provide sufficient flow in the gas trap, as such gas readings fluctuated with the flow. 03/08/2009 Continue to POOH with BHA #3, 5,709'-2,450'MD. Spot 22bbl high-viscosity fresh H2O pill, 2,450'-2,050'MD. POOH to 2,050'MD, and spot 130bbls of 17.0ppg kill weight mud, 2,050'- 340'MD. Flow check, (Well Static), pre job safety meeting, and retrieve RCD element per MPD Rep. Install tripping nipple and continue pulling out of hole to 559'MD. Rack back heavy weight drill pipe, lay down jar, and rack back 1x stand of non magnetic flex monel. Pre job safety meeting and recover nuke sources. Plug into MWD, but battery dead. Lay down MWD and Geo Pilot, after breaking off bit. Change out batteries from new tool to old and recover A-Cal and CTN data. Slip and cut drilling line and service rig. Once MWD was ready, pick up and make up BHA #4, with re-run 8-3/4" bit from BHA #3, and fresh 7600 series Geo Pilot. Pick up accordingly and after initializing MWD probe run in hole to +/-2,000'MD, install RCD Element/bearing assembly. No notable gas values were observed for the day with limited pumping. 03/09/2009 Circulate out and capture 100bbls of 17.0ppg kill fluid, (had pumped 130bbls), at 150gpm = 580psi, (hold 12.5ppg ECD with MPD). RIH from 2,050'-3,665'MD. Circulate out rest of contaminated 17.0ppg kill mud, (cut to 12.0-12.3ppg), and 20bbls Hi-Viscosity fresh H2O pill. Run in hole, and manage running speeds, as losses increase with the cold mud, also coming out .3- .7ppg over 10.7ppg MW, (hold 12.3ppg ECD). Run in hole with BHA #4, 3,665'-5,766'MD, and fill drill pipe, and check MWD. Again have to get heavy cold mud out, prior to getting enough flow rate to check tools. Control running speed, as losses occur if to fast. Pull 5 stands to confirm no balling up of bit, (still had 14bph losses). Continue to run in hole slowly, 5,957'-7,203'MD. Circulate bottoms up at reduced rate and stage to 450gpm, while getting 4x Azimuth surveys for Sperry for IFR/Cass modeling. Attempt to shut down but unable to get dart valves to seat closed, (took approx. 45 minutes). Run in hole, 7,203'-7,965'MD, and again stage up to 400gpm = 2,100psi, and take 4x more surveys for Sperry Sun modeling. Continue to run in hole, 7,965'- 8,400'MD, but unable to circulate at fast enough rate, (hole trying to pack off-abandon survey attempts). Able to continue to running in hole, 8,400'-9,280'MD, but unable to regain circulation, until pulled back to 8,925'MD. Stage up to 450-550gpm, with some packing off seen, and ream 8,925'-9,170'MD. With frequent pack off incidents and limited pumping gas values fluctuated with a maximum of 4918 units observed. 03/10/2009 Wash and ream in the hole from 9,160' to 9,367'MD. Raise flow rate to 300gpm, but pack off. Ream slowly while continuing to circulate and attempt to raise rate to 550gpm, but hole kept packing off. Circulation was established with 325klbs pick up weight and 95klbs slack off weight. TDS RPM 70-120 with 15-28k-ftlbs torque. Hole packed off tight at 9,367'MD, and worked pipe to establish circulation, continue attempting to raise circulation rate up to 550gpm, unsuccessful. When pump rate was over 320gpm hole would immediately pack off and stall rotary. Attempt to work pipe to clean up hole, (free from 9,350' to 9,367'MD), but anytime pipe was moved the hole would pack off. Work pipe through tight hole from 9,367' up to 9,320'MD with 375klbs pick up weight to regain circulation and rotary. Establish circulation with 550gpm at 2,850psi and 110 RPM at 18-25k-ftlbs torque. Pick up weight 175klbs, rotary weight 150klbs, slack off weight 140klbs. Wash and ream from 9,320' to 9,483'MD with no pack off problems at 400gpm with 2,050psi, 115RPM with 20-27k-ftlbs torque. Hole appeared to be cleaning up nicely but then packed off at 9,483'MD. Work pipe through tight hole after pack off and attempt to establish circulation from 9,483' to 9,390'MD, gained partial circulation at 9,390'MD but hole packing off badly, attempt to establish circulation at 9,390'MD and work tight hole from 9,390'MD to 9,401'MD with severe pack off issues at 120 - 140 RPM with 18-28k-ftlbs torque, 325klbs pick up weight and 100klbs slack off weight. Establish circulation and work pipe through tight hole from 9,390' to 9,401’MD, established circulation at 9,390'MD and staged pumps up to 550gpm at 3,000psi, 120RPM with 20k-ftlbs torque. Wash and ream from 9,401' to 9,655'MD at 550gpm with 3,300psi with lots of pack off problems, 70-140RPM with 18-28k-ftlbs torque. Pumped 30bbl high-viscosity pill at 9,435'MD and had a 15-20% increase in cutting with sweep back. Tagged DOB2C pill at 9,504'MD. DOB2C pill taking up to 30klbs weight on bit could not pull up from 9,655'MD. Work pipe free with 400klbs pick up weight, pull up to 9,635'MD, with hole packing off. Ream down from 9,635'-9,702'MD, with 550gpm at 3,300psi. 03/11/2009 Wash and ream from 9,682' to 9,810'MD, with lots of pack off problems. Once get on bottom, rotary drilling from 9,810'-9,856'MD, with no pack off problems or other hole issues. Had to change RCD element, due to leaky bottom bearing seal. POOH 1 stand. Close annular preventer and line up on rig pumps through kill line to maintain 550psi for 12.5 EMW on annulus, while changing out RCD bearing. Changed out without any issues and test same, (OK). Bleed off pressures between annular preventer and RCD element. Resume rotary drilling in 8-34" hole section 9,856'-10,287'MD, with no pack off problems or other hole issues, and maintaining 12.5 EMW using MPD equipment. Hole packed off while drilling at 10,287'MD, due to 40bbl high - viscosity sweep being circulated across Torok sand, unable to circulate or rotate pipe. Picked up string to 10,255'MD to regain circulation, staged up pumps back to 575gpm and ream back to bottom at 10,287'MD. Continue rotary drilling and surveying, 8-3/4" hole section,10,287'- 10,519'MD, with no pack off problems or other hole issues, while maintaining 12.5 EMW with MPD equipment. 03/12/2009 Drill 8-3/4" hole section to "TD" at 10,635'MD. Circulate high-viscosity sweep surface-surface with no significant increase of cuttings. Continue to circulate bottoms up 3x while reciprocating drill pipe. Begin back reaming out of the hole, 10,545'-10,295'MD. Encounter tight hole with pack off events and lots of top drive stalling if pulled to fast. Continue back reaming out of hole slowly, but with full rates, 10,295'-10,140'MD. Begin packing off more frequently, with difficulties establishing full circulation rates, and pump out with 10,140'-9,706MD. Encountered tight spot where unable to circulate, or go up/down. Continue to work tight pipe, (Consult Town ODE). Gas values were limited with limited flow during pack off but maximum values of 337units were observed. 03/13/2009 Packed off at 9,706'MD and unable to regain circulation. Unable to get movement up or down, or rotation. Drilling jars able to fire on up stroke but unable to fire downward. Slack off weight = 50klbs, pick up weight = 450klbs. Work torque up 28k-ftlbs attempting to rotate. Attempt to circulate while holding the 12.5ppg EMW with the MPD and prepare for back off services. While attempting to pump during these operations, no returns were observed, therefore no gas values for the day. 03/14/2009 Rig up e-line lubricator. Troubleshoot E-line unit, wait on parts for unit and change out same. Rig E-line unit and tools. Run in hole with free point/CCL to 5,500'MD. Attempt free point calibration - failed. Pull out the hole from 5,500'MD. Troubleshoot free point tools. Work stuck pipe while Halliburton E-line hands get some sleep due to not having any relief. 03/15/2009 Run in hole with string shot 9,394' wireline measured, apply left hand torque and fire same unsuccessful in back off attempt. POOH and rerun string shot, tagged up at 8,320' wireline measured unable to get down. POOH and rig down e-line equipment. Establish circulation and attempt to back off pipe with left hand torque, unsuccessful. While pumping wireline down, circulation was regained and a bottoms up gas of 800 plus units was observed. 03/16/2009 Circulate bottoms up at 400gpm. Hole packed off. Regain circulation at 84gpm with 50% returns. Run in hole with CCl/String Shot. Fired shot at 9,394' wireline measured. Worked pipe and back- off string. String free with 390klbs up weight and 65klbs down weight. POOH with wireline. Gas values maxed out at 265 units and averaged 12 units for the day while circulating. 03/17/2009 POOH with wireline. POOH with drill string. Rig up test equipment and test 2 each 5" pipe rams, blind rams, choke and kill HCR's, manual kill and choke, 14 choke manifold valves, IBOP, floor safety valve and dart valve to 250psi low and 3,500psi high, annular to 250psi low and 2,500psi high. Start time 22:00hrs 3/17/09, finish time 02:00hrs 3/18/09. Test witnessed by AOGCC representative Bob Noble. Gas values for the day while circulating were observed at a maximum of 680 and a daily average of 80 units. 03/18/2009 Test BOPE as per drilling permit. AOGCC PI, Bob Noble, witnessed BOPE test. Pick up and make up clean out BHA. Run in hole to 3,666'MD. Circulate out 17.0ppg mud. Run in hole to 6,500'MD. Gas values for the day were observed running at an average of 90 units and a maximum of 1360 units at 5600’MD. 03/19/2009 Wash and ream from 8,306' to 8,335'MD. Observed rig pump mud end leaking fluid. Inspected pump and discovered crack in suction side. POOH to 9-5/8" shoe at 3,666'MD holding 12.5 EMW with MPD for pump repairs. Gas values averaged 80 units and a maximum of 417 units. 03/20/2009 Wash and ream through open hole from 8,306' to 8,680'MD. Tight hole sections were encountered in this area slowing the process with a number of pack off situations. Gas values maxed out at 3168 and averaged 600 units while pumping. 03/21/2009 Wash and ream thru open hole from 8,680' to 9,438'MD. Several pack offs occurred and different parameters were used to combat it to free the drillstring and regain circulation. Losses for the day were 115 bbls and gas values were observed at 450 average, with a maximum of 2650 units. 03/22/2009 Wash down to top of fish at 9,442'MD. Circulate bottoms up to clean hole. Gas values for the day maxed out at 4162 and averaged 350 units for the day. 03/23/2009 POOH on elevators from 9,438'MD to surface. Lay down clean out BHA. Make up fishing assembly and run in hole. No gas values were observed for the day as pumping was held to a minimum. Losses were minimal at 64bbls and the trip out took the exact fill calculated. 03/24/2009 Make up fishing assembly, run in hole with fishing BHA to 9,442'MD. Work drill string in attempt to recover fish without success. POOH to prepare to cement and plug back. Previous section will be considered PB1. Gas values while pumping were observed at an average of 550 and a maximum of 3085 units. Losses for the day occurred while pumping and totaled 84bbls, while the trip in and out appeared to show proper displacements. 03/25/2009 Lay down Fishing BHA. Change out lower rams from 5" – to 4". Tested to 250-3,500psi. Run in hole and set 55.8bbls of 15.8ppg Class "G" cement abandonment plug from 9,420' - to 8,920'MD. Gas values while pumping averaged 330 and maxed out at 2985 units, with no losses observed for the day. 03/26/2009 Spot 55.8bbls (265 sacks) 15.8ppg Class"G" cement abandonment plug from 9,420' - to 8,920'MD. POOH to 7,150'MD. Spot 55.8bbls (310 sacks) 17ppg Class "G" cement sidetrack plug from 7,150' - to 6,650'MD. POOH test BOPE's. Annular tested to 250 - 2,500psi, 2 each, 5" pipe rams, choke and kill HCR's, choke and kill manuals, 14 each choke manifold valves, floor safety valve, dart valve, TD IBOP tested to 250 - 3,500psi. Witness of test waived by AOGCC rep John Crisp. Perform drill pipe maintenance. Limited pumping resulted in no losses and limited gas values. 03/27/2009 Circulate and condition mud at 5,479'MD. Pump rate at 400gpm, 1,100psi. Take 4 survey check shots with MWD. Run in hole to 6,130'MD. Circulate and condition mud. Pump rate at 380gpm1,130psi. Take 4 survey check shots with MWD. Run in hole to 6,522'MD. Make up top drive. Break circulation. Wash and ream to top of cement at 6,644'MD. Drill off cement plug from 6,644' to 6,725'MD. Pump rate at 550gpm, 2,350psi rotate at 120RPM with 15-20klbs weight on bit. Gas averaged 100 and maxed out at 250 units. No losses were recorded for the day. 03/28/2009 Drill and survey 8-3/4" open hole from 7,287' to 7,304'MD. Wellsite Geologist observed base of Torok sands at 7,295'MD. Mix and pump 60bbl high-viscosity sweep. Wiper trip from 7,304' to 6,715'MD, Pick up weight 225klbs, slack off weight 135klbs, hole in good condition. Perform new mud dilution. Remove trip nipple, set RCD element. Drill ahead from 7,304'MD while holding a 12.5ppg ECD with MPD. Gas values ranged from an average of 135 to a Maximum of 352 units. No losses to the hole were observed during the day. 03/29/2009 Drill 8-3/4" hole from 7,287' to 8,070'MD. No losses were observed for the past 24 hour period, while gas values averaged 115 and maxed out at 518 units. 03/30/2009 Drill 8-3/4" hole from 8,070' to 9,184'MD. Circulate and condition hole. Make wiper trip, POOH from 9,184' to 8,738'MD. Losses were minimal for the day at 20 bbls, while gas values averaged 235 and a maximum of 2403 units was observed. 03/31/2009 Continue to back ream out of hole, 8,738'-8,426'MD with tight spots at 8,738' and 8,535'MD. POOH on elevators, 8,426'-7,952'MD with 50klbs over pull. Service rig and TDS, and run in hole with assembly, 7,952'-9,080'MD without incidents. Wash/ream, 9,080'-9,184'MD with packing off occurring, continue to ream and stage up to drilling rates. Drill 9,184'-9,286', where experienced 400-600psi total pressure loss. Check pumps, (ok), and determine down hole losses. POOH, but had to back ream 9,286'-9,173'MD. POOH on elevators with10-20klbs normal over pull (some 50- 60klbs spots), after pumping 30bbls of 17.0ppg MW in drill pipe, (wash above floats). POOH on elevators to 3,136'MD. 04/01/2009 Pump 104bbls of 17.0ppg mud. Well static. Pull RCD element, set trip nipple. POOH continue looking for wash out in drill string. Locate wash out in box end on joint of heavy weight drill pipe below jars. Lay down washed drilling jar and heavy weight drill pipe, and questionable looking HWDP. Down load MWD and change out same. RIH with BHA #9 497'-2,212'MD. Install RCD bearing and Element per Sperry. Circulate bottoms up and capture 120bbls kill weight mud. Run in hole to casing shoe and circulate bottoms up out high-viscosity sweep pill, (Sperry having to go to manual on bearing hydraulic control). Run in hole to +/-5,000'MD and circulate bottoms up (stage up), to 550gpm. Run in hole to 7011'MD without problems (RCD bearing failed), have to change out same and flush out system with new hydrolic oil. 04/02/2009 Continue to circulate at 350gpm while waiting on MPD to flush hydraulic system oil. Change out RCD bearing assembly, (closed Annular Preventer-Non well control event). Run in hole 7,046'- 8,564'MD, (encounter bridge at 8,564'MD with 50klbs down weight). POOH to 8,516'MD and establish circulation, stage up to 550gpm, (Hole packing off, etc.), circulate bottoms up. Ream 8,516'-9,226'MD, where pack off and tight hole were encountered. Re-establish circulation, and continue to ream with hole troubles, 9,226'-9,265'MD. Gas values while tripping in saw an average of 269 and a maximum of 1491units. Losses were minimal for the day and related to pack off events. 04/03/2009 Wash and ream from 9,265' to 9,286'MD. Once on bottom, drill 8-3/4" hole section from 9,286' to 9,348'MD, where high mud losses were experienced, (up to 100% w/12.5ppg ECD maintain on MPD). Mixed and spotted a Hi-vis 60bbl LCM pill of 80#/bbl with Steel Seal, Barafiber, and BaraCarb 50. Pulled back to 9,226'MD and performed Weekly BOPE function test per AOGCC requirement. Staged up to 12.1ppg ECD with 86bph loss rate and 12.3ppg ECD= 150bph losses. RIH to 9,348' and drill 8-3/4" hole section to base of Kuparuk @ 9,498'MD, (Drilled 9,348' POOH to 9,300' and prepare for DOB2C LCM pill #3. Once ready, POOH to +/-8,300'MD/PJSM/and RIH to 9,298'MD. Consult Town Supt. and ODE w/results and overview calculated volumes final time. Line up on HT Cement pump and flush lines w/LVT and pressure test to 3,000psi, (ok). Pump 15bbls LVT/22.5bbls DOB2C Slurry, (incl. 66 sk's Premium Cmt. and 50 Sea Mud Gel= 62 sk's)/20bbls LVT. Displace w/104bbls Fresh mud. Close MPD RCD and go through Kill Line w/Mud pumps, after ensuring line clear. Spot DOB2C Slurry w/2:1 ratio mud/LCM pill w/4BPM mud @ 560-1,000psi w/550psi WHP MPD, for 60bbls Total Mud, (151bbl pumped, w/15bbls LVT left in string). DOB2C LCM Slurry In Place @ 14:42hrs. Read and Record pressures w/ISIP of DP= 950psi, Ann.= 575psi, and WHP= 550psi. FSIP after 5 min.'s= DP= 485psi, Ann.= 265psi, and WHP= 341psi. Strip out of hole and displace .8bbl/std, (= 8-9 strokes per std.), while maintaining 550psi WHP on MPD, (pumped 10bbls @ 380gpm on Std. #1 out). POOH to 8,090' and Est. 600gpm rate @ 12.5ppg ECD, (tools working fine). Wait on pill to 8:00pm and RIH to 9,026', but unable to circ. POOH to 8,847' and ream to 8,910'. 04/04/2009 Wash and ream in the hole from 8,910' to 9,509', 500-600gpm at 2,300-3,200psi, 60-140 RPM at 18-28K torq, P/U wt 325K, S/O wt 100K, Rot wt 160k. Losses at 20-200bph with 11.7-12.5 EMW. Back ream out the hole from 9,509' to 9,226', 600gpm at 3,300 psi, 105 RPM at 18-22k torq, P/U wt 175K, S/O wt 150K, Rot wt 160K. Losses at 90bph with 11.7 EMW. Pull out the hole from 9,226' to 8,085', P/U wt 335k, S/O wt 85k. Trip in the hole from 8,085' to 9,300', P/U wt 300k, S/O wt 105K. Tight spots at 8,857' and 9,005' 40-50K drag at these depths. Spot DOB2C pill #4 per program, Line up on HT Cement pump and flush lines w/LVT and pressure test to 3,000psi, (ok). Pump 15bbls LVT/25bbls DOB2C Slurry, /20bbls LVT. Displace w/104bbls fresh mud. Close MPD RCD and go through Kill Line w/Mud pumps. Spot DOB2C Slurry w/2:1 ratio mud/LCM pill w/4 BPM mud @ 560-1,000psi w/550psi WHP MPD, for 60bbls Total Mud, (151bbls pumped, w/15bbls LVT left in string). DOB2C LCM slurry in Place @ 16:46hrs. Read and Record pressures w/ISIP of DP= 850psi, Ann.= 575psi, and WHP= 550psi. FSIP after 5 min.'s= DP= 480psi, Ann.= 265psi, and WHP= 450psi.Pull out the hole from 9,300' to 8,085', P/U wt 325K, S/O wt 100K. Stage up pumps to 550gpm with 3,500psi, (plugged jet/tools ok). CBU and reciprocate pipe. After bottoms up slowed pumps to 450gpm with 2,450psi and wait on DOB2C pill. 60-100 RPM at 19- 22K torq, Rot wt 160K, S/O wt 150K, P/U wt 170K, maintaining 12.5ppg EMW with no losses. 04/05/2009 Ream 8,942'-9,230'MD, w/550gpm= 2,900psi, 80-110 RPM's on TDS= 19-28K torq. off bottom, 160K RotWt, PuWt= 325-405K, SoWt= 75-100K. Seeing numerous Pack off attempts, Stalling out TDS, and Pipe sticking attempts. Attempt to back ream 9,230'-8,974', but unable to to circulate (pack off event). POOH to 8,974' and Est. and Stage circulation from 50gpm- 500gpm w/2,550psi, and continue to ream 8,974'-9,096'MD, lost 400 psi at 9,096'. Inspect all surface equipment, but found communication between annulus and drill pipe apparent D.P. or BHA washout. Transfer 60bbls of 15.5ppg mud from RSC to rig, weight up same to 17.0ppg, spot 30bbls in the drill pipe to overcome the 525psi being held on the annulus by MPD equipment. 04/06/2009 Wash and ream in the hole from 8,910' to 9,509', with 500-600gpm at 2,300-3,200psi, 60-140 RPM at 18-28K torque. Pick up weight of 325K, slack off weight of 100K and rotating weight of 160K. Losses at 20-200bph with 11.7-12.5 EMW. Back ream out the hole from 9,509' to 9,226', 600gpm at 3,300psi, 105 RPM at 18-22K torque, P/U wt 175K, S/O wt 150K, Rot wt 160K. Mud losses at 90bph with 11.7 EMW. Pull out of the hole from 9,226' to 8,085', P/U wt 335K, S/O wt 85k. Trip in the hole from 8,085' to 9,300', P/U wt 300K, S/O wt 105K. Tight spots at 8,857' and 9,005' 40-50K drag at these depths. Spot DOB2C pill #4 per program, line up on HT Cement pump and flush lines w/LVT and pressure test to 3,000psi, (ok). Pump 15bbls LVT/25bbls DOB2C Slurry, /20bbls LVT. Displace w/104bbls Fresh mud. Close MPD RCD and go through Kill Line w/Mud pumps. Spot DOB2C Slurry w/2:1 ratio mud/LCM pill w/4bpm mud @ 560- 1,000psi w/550psi WHP MPD, for 60bbls Total Mud, (151 BBL pumped, w/15bbls LVT left in string). DOB2C LCM Slurry In Place @ 16:46hrs. Read and Record pressures w/ISIP of DP= 850psi, Ann.= 575psi, and WHP= 550psi. FSIP after 5 min.'s= DP= 480psi, Ann.= 265psi, and WHP= 450psi. Pull out the hole from 9,300' to 8,085', P/U wt 325K, S/O wt 100K. Stage up pumps to 550gpm with 3,500psi, (plugged jet/tools ok). CBU and reciprocate pipe. After bottoms up slowed pumps to 450gpm with 2,450 psi and wait on DOB2C pill. 60-100 RPM at 19-22K torque, Rot wt 160K, S/O wt 150K, P/U wt 170K, maintaining 12.5ppg EMW with no losses. 04/07/2009 PJSM. Remove RCD bearing and install trip nipple. Pull out the hole from 1,800' to the BHA. Laydown BHA and download MWD data. Switch rig to generator power to perform step down of ODS transformer, (unsuccessful). Switch back after receive OK from Op's. Trip in the hole and laydown all 5" drill pipe in 20 stand intervals. 04/08/2009 Finish laying down 5" drill pipe from derrick 1x1 into pipe shed. Set test plug and test BOPE per AOGCC requirements, with 250psi low/2,500psi high on Annular Preventer and 3,500psi high on all other rams, valves, choke manifold, floor valves, (chart same 5min each test). Function test Koomey system 1min and 45sec (ok). Test and record gas alarms in NAD log book. Blow down choke manifold and line valve for drilling. Pull test plug and shut Blind rams, Slip and Cut drilling line and perform maintenance on TDS, grease blocks and crown, (finish welding for MPD). Open Blind Rams. Pick up and RIH 75 jts 5" DP and rack back in derrick. P/U and M/U BHA #10, 8- 3/4" Bit w/ Geo Pilot assembly. Test MWD, OK and continue to RIH with same. Pick up 11 Jts 5" fresh HWDP and fresh 5" DP to 1,344' MD. 04/09/2009 RIH w/fresh 5" drill pipe from pipe shed from 1,344' to 2,200'MD. Remove trip nipple and install RCD bearing. Stage pumps up slowly to 450gpm and circulate out 17.0ppg weighted pill. Increasing backside pressure with MPD equipment to maintain 12.5ppg EMW on bottom. RIH with fresh 5" drill pipe from pipe shed from 2,200' to 3,638'MD. Circulate bottoms up. Continue Trip in the hole and pick up 5" drill pipe from pipe shed from 3,638' to 5,272'MD. Stage pumps up slowly to 550gpm, and CBU. Take 4 rotational check shot surveys. Trip in the hole picking up 5" drill pipe from pipe shed from 5,272' to 6,774'MD. Establish circulation at 6,740' stage pumps up slowly to 550gpm, and CBU. Take 4 rotational check shot surveys. Attempt to trip in the hole, but stacked out with 60K at 6,745', wash and ream from 6,745' to 6,808'MD, (with numberous pack off events and tight hole, stalling the top drive). Take MWD survey at 6,774' and had 0.6° more inclination (56.39) and more than 4° (247.22) of left hand turn than surveys taken at this depth previously. Pull out the hole from 6,808' to 6,716' (above open hole side track), down link Geo-pilot to 120 GTF Right and 100% deflection to try and ream into original sidetrack. Ream from 6,716' to 6,808'MD, but unable to chase into correct well bore. Pull out of the hole from 6,808' to 6,338'MD, to get rest of pipe management performed and consult Town ODE. 04/10/2009 Trip in the hole to 6,719'. Make LWD “Mad Passs” from 6,719' to 6,808'. Drilling side track #2 from 6,808' to 6,973'. Make wiper trip through side track #2. Drilling from 6,973' to 7,481'. 04/11/2009 Directional drill 8-3/4” hole from 7,481' to 8,476'. 04/12/2009 Directional drill 8-3/4” hole from 8,476' to 9,420'. Circulate hole clean with sweeps. Back ream out of the hole from 9,321' to 9,090'. 04/13/2009 Backream to 8,381'. Circulate bottoms up. Run in hole to 9,420'. Drill 8-3/4” hole from 9,420' to 9,622'. Started loosing fluid at 9,500'. Spot 25bbl DOB2C LCM pill at 9,490'. POOH to 8,665. Circulate bottoms up. 04/14/2009 Wash and ream from 9,530' to 9,621'. Make 5 stand wiper trip to ensure hole quality prior to DOB2C pill. Pull out the hole from 9,621' to 9,418'. Circulate while waiting on cement unit to prepare for DOB2C pill. 04/15/2009 Back ream from 9,418' to 9,137'MD. Circulate and ream from 9,137'MD to 9,608' MD. Spot 30 bbl DOB2C pill to control fluid losses. Ream to bottom at 9,622'MD. Drill 8-3/4" hole from 9,622'MD to 9,958' MD with fluid losses decreasing from initial 40bph down to 15bph. 04/16/2009 Drill 8-3/4" hole from 9,958'MD to 10,390'MD. Pump rate 600gpm at 3,850psi, WOB 35/45k, RPM at 135, Tq 15/19k. Continue adding LCM to mud system to control loss rate at 15-20bph. 04/17/2009 Drill 8-3/4" hole from 10,390'MD to 10,625'MD. POOH while back reaming from 10,625'MD to 10,170'MD. Note: Work through tight spots with stalling and pack-off’s at 10,274'MD, 10,253'MD, 10,240'MD, 10,214’MD and 10,195'MD. Fluid loss rate ranged from 8-15bph. 04/18/2009 POOH while back reaming from 10,170'MD to 9,682'MD. Work through numerous stall out, pack- off’s and tight hole. Note: Largest loss occurred on pack-off at 9,980'MD with fluid loss rate in excess of 80bph. Average loss rate was 20 – 25bph. 04/19/2009 POOH while back reaming from 9,682'MD to 8,959'MD. POOH on elevators from 8,959'MD to 8,759'MD. Wash and ream from 8,759'MD to 9,231'MD. Work through numerous stall out, pack- offs and tight hole. Note: Loss rate was variable and ranged from 20 to 30bph to a number of higher loss rated to 80bph at 9,350'MD and 9,226'MD. 04/20/2009 Run in hole wash and ream to bottom at 10,625'MD. Circulate and weight up mud system to 12.8ppg. Losses varied from 10 to 30bbls per hour. 04/21/2009 POOH from 10,625'MD to surface. Test BOPE with 7” rams to prepare for casing run. 04/22/2009 Complete BOPE test. Run 7" casing to 3600’MD, break circulation and pump one bottoms up. Continue to run in hole to 8,398'MD. The trip did not give proper displacement back and losses upwards of 60bbls per hour were observed. 04/23/2009 Run 7" casing to 10,618'MD & land same. Circulate mud system to 12.6ppg cement 7" casing with 68.8bbls (161sx) lead slurry cement at 12.5ppg followed by 22.9bbls (109sx) tail slurry at 15.8ppg. Install and test 7" packoff. Run 74 joints 2-7/8" kill string. Freeze protect 7" x 9-5/8" annulus with 110 bbls of diesel. Nipple down MPD and BOPE. Released Rig from operations on well ODSN at 24:00 hrs. 04/24/2009 Run 7" casing to 10,618'MD & land same. Circulate mud system to 12.6ppg cement 7" casing with 68.8bbls (161sx) lead slurry cement at 12.5ppg followed by 22.9bbls (109sx) tail slurry at 15.8ppg. Install and test 7" packoff. Run 74 joints 2-7/8" kill string. Freeze protect 7" x 9-5/8" annulus with 110bbls of diesel. Nipple down MPD and BOPE. Released Rig from operations on well ODSN-36 at 24:00 hrs. 07/18/2009 Move substructure and pits off ODSN-31 and move to ODSN-36. Spot sub, pits and level same. Held Frac Operations Safety Meeting with Schlumberger, Nabors, Nanuq, Halliburton, Operations and ACRS Drilling Support. Lower all rig stairs and secure all rig Exit routes. Position MPD Support units. Construct spill berms where needed. Connect all rig support lines in PUTZ and HUTZ. Load pipe shed with 81 Jts 4" Dp. P/U 36 jts and stand back in derrick. R/U circulating lines to displace freeze protect from well. 07/19/2009 R/U circulating lines to tubing head and IA for freeze protect displacement. Circulate out 74 bbls diesel (freeze protect) from tubing and IA at 4bpm with 650psi. Taking diesel returns to Flowback Tank. Set TWC. N/D Production Tree. M/U Riser and BOPE's. Connect choke and kill lines. R/U MPD landing. Install Rotating Head Assy. R/U Katch Kan and MPD circulating lines. Install trip nipple. R/U 2-7/8" Tbg handling equipment. Pull TWC. M/U 2-7/8" Ldg Jt. BOLDS. Pull Vetco Gray Hgr to rig floor with 75K. B/O Hgr and L/D Hgr and Ldg Jt. PUW 55K, SOW 50K. 20K over pull to unseat Hgr. POH f/ 2,400' w/ 2-7/8" 6.5# L-80 I-BTC Tbg. L/D 75 Jts. Tbg, 1 ea. XO and Tbg Hgr. NOTE: Tested 14 choke manifold valves to 250psi low & 3,500psi high w/ water while POH w/ Tbg. Held all test 5 min low / 5 min high and charted same. R/D Tbg handling equipment. Removed Tbg from pipeshed and bundled same. C/O bottom pipe rams f/ 4-1/2" - t/ 4". Install Vetco Gray test plug. R/U test equipment. Attempt to test annular. Kill line failed at factory swedged fitting. C/O Kill line. Test BOPE's as per AOGCC permit requirements. Tested 14 Choke Manifold valves while POH w/ 2-7/8" Tbg. Tested Annular to 250 psi low / 2,500psi high. Upper and lower 4" pipe rams, Kill & Choke HCR's, Manual Kill & choke valves, Floor Safety valve, Dart valve, Upper and Lower TD IBOP to 250psi low / 3,500psi high. Tested Blind rams t/ 250psi low / 4,500psi high. All low / high tests held 5min each. All tests charted. Witness of test waived by AOGCC rep. Chuck Scheve. R/D BOPE test equipment and remove test joint. Remove Trip Nipple and install RCD Test Plug. 07/20/2009 Test MPD. Test 7" csg t/ 4,500psi. P/U BHA #11. RIH 4,803'. Discovered wrong program installed in MWD. POH w/ BHA #11. Installed proper program in MWD and test same. RIH w/ BHA #12 3,342'. 07/21/2009 RIH w/ BHA #12 - 10,475', tagged cement stringer (filling Dp every 2,500'). Installed MPD RCD. Displaced seawater with 8.75ppg Quikdril-M WBM. Clean out cement stringers t/ 10,526'. Drill cement, float equipment, clean out shoe track, 7" shoe and 7' of 8-3/4" old hole t/ 10,625'. Drill new 6-1/8" hole f/ 10,625' - t/ 10,645'. 7/22/2009 Drill f/ 10,825'- t/ 10,833'. Change out RCD bearing. Drill f/ 10,833' - t/ 11,037'. Ream f/ 11,020' - t/ 11,037', (dog leg). Drill f/ 11,037' - t / 11,269'. CBU x 2. POH t/ 11,075'. 7/23/2009 Short trip to 7" shoe at 10,618'. Service Top Drive. RIH to 11,269', no issues, no fill. Drill f/ 11,269' - t / 11,954'. Time Drill f/ 11,954' - t/ 11,972'. Drill f/ 11,972' - t/ 11,992'. 7/24/2009 Drill f/ 11,992' - t/ 12,006'. Time Drill f/ 12,006' - t/ 12,008'. Drill f/ 12,008' - t/ 12,523'. Service Rig. Drill f/ 12,523' - t/ 13,177'. 7/25/2009 Drill f/ 13,177' - t/ 13,297'. Service Top Drive. Drill f/ 13,297' - t/ 13,875'. Service Top Drive. Drill f/ 13,875' - t/ 14,262'. 7/26/2009 Drill f/ 14,252' - t/ 14,323'. Time Drill f/ 14,312' - t/ 14,323'. Drill f/ 14,323' - t/ 14,358'. Service Top Drive. Functioned BOPE's as per AOGCC regulations. Drill f/ 14,358' - t/ 14,770'. Time Drill f/ 14,770' - t/ 14,771'. 7/27/2009 Time Drill f/ 14,771' - t/ 14,797'. Drill f/ 14,797' - t/ 14,841'. Serviced Top Drive. Drill f/ 14,841' - t/ 15,025'. Time Drill f/ 15,025’ – t/ 15,027’. Drill f/ 15,025' - t/ 15,027'. 7/28/2009 Time Drill f/ 15,027' - 15,038'. Drill f/ 15,038' - 15,130'. Service Top Drive. Drill f/ 15,130' - t/ 15,613'. Service Top Drive. Drill f/ 15,613' - t/ 15,868'. Time Drill f/ 15,868' - t/ 15,871'. 7/29/09 Drill 6 1/8” hole to 15789’. Rig breaker tripped on 13.8 KV line. Circ. Well clean from 15879’, lay down drill pipe to 15806’. Circ. btms. up from 15806’. Restore shore power. POOH from 15806’ to 12419’. Back ream from 12419’ to 12260’. POOH from 12260’ to 11807’. 7/30/09 POOH from 11807’ to 11045’, Spot 30bbl hi vis spacer at 11045’, POOH to 10425’, displace well to 10.1 brine from 10425’ 340bbls. Remove RCD head and install trip nipple. POOH from 10425’ to BHA. Lay down BHA remove nuclear sources and recover data from tools, lay down BHA, level up rig, and pull wear bushing. 7/31/09 Rig service, Test BOPs to 250psi low 3500psi high upper and lower rams inner and outer choke and kill valves, choke manifold. test annular to 250psi low 2500psi high. Witness waved by AOGCC Rep. JOHN CRISP, P/U 6 1/8 BHA, repair accumulator, P/U 6 1/8 BHA, RIH with drill pipe. 8/1/09 RIH to 1059’, slip and cut drilling line. Install RCD head, RIH to 11060’. Pump 30bbl spacer and 50bbl spacer. Displace well from 11060’ with 8.6 mud from 10.1 brine. RIH to 11425’. Geo Pilot failed. POOH to 11040’ and pump 25bbl spacer. POOH to 10540’ displace well to 10.1 brine from 8.6 mud. Remove RCD and install trip nipple. POOH with 4 inch drill pipe to BHA. Lay down BHA. 8/2/09 Rig service, P/U 6 1/8 BHA. Repair TDS. P/U 6 1/8 BHA. RIH to10500’. Install RCD head and RIH to 11092’. Pump 30bbl spacer and 50bbl spacer to displace the well from 11092’ from 10.1 brine to 8.6 mud. RIH to 11750’. Wash and ream from 11750' to 15186' MD. 8/3/09 Wash and Ream from 12345’ to 15872’. Drill 6 1/8 hole to 15916’. Rig service, Drill 6 1/8 hole. 8/4/09 Time Drill at 1 ft/hr from 16114’ to 16118’ with 195gpm, 1500psi, 60 RPM, 10K torque, 10K WOB. Drill 6 1/8 hole from 16118’ to 16206’ with 225gpm, 1950psi, 100 RPM, 17K Torque on bottom, 13K off bottom and 10 WOB, P/U wt 305, Rot wt 152. Drill 6 1/8 hole from 16206’ to 16888’ with 240gpm, 2080psi, 115/100 RPM, 16K torque, 5 WOB, P/U wt 310, rot wt 150. Rig service TDS and equip. Drill 6 1/8 hole from 16688’ to 16772’ with 240gpm, 2080 psi, 60/100 RPM, 16K torque, 8/10 WOB, P/U wt 310, Rot wt 170. Time drill at 1 ft/hr from 16772’ to 16775’ with 195gpm, 1650psi, 60/100 RPM, 13K torque, 8/10 WOB, P/U wt 310, Rot wt 170. 8/5/09 Control time drill at 1.5 ft hr from 16775’ to 16781’ with 195gpm, 1600psi, 13K torque, 12/20 WOB. Drill 6 1/8 hole from 16781’ to 17008’ with 240gpm, 2100psi, 60/110 RPM, 15/18K torque, 10/20 WOB, P/U wt 330, Rot wt.170. Control time drill from 17008’ to 17017’ at 1 ft/hr with 195gpm, 1630psi, 60 RPM, 13/16K torque on bottom, 13K torque off bottom, WOB 3/16K, P/U/wt 330, Rot 152. Drill 6 1/8 hole from 17017’ to 17095’ with 240gpm, 2100psi, 110 RPM, 16/17K torque, 6/8K WOB, P/U wt 320, Rot wt 150, P/U wt 170, S/O rot 125. Control time drill from 17095’ to 17096’ at 1 ft/hr with 195gpm, 1630psi, 60 RPM, 15/16K torque. 8/6/09 Drill 6 1/8" hole to 17,363', service rig. Drill 6 1/8" hole to 17,525’, TD. Circ. well clean from 17,525'-17,460'MD, (1x CBU), POOH to 17,460'MD, & continue to CBU 2x Circulations, (Surf. - Surf.). 8/7/09 Circ well clean from 17,525'MD, Back ream Lateral section, 17,525'-10,600'MD. Service rig, TDS, grease crown, & Circ Hi vis Sweep, (30bbls from10,611'MD to surface - lots of cuttings). No abnormal losses or gains other than pipe displacement. Low gas reading due to varying flow rates while reaming, max gas seen for the 24 hour period was 475 units, averaging 137 units. 8/8/09 Function test BOPs with no problems. Service rig, & RIH w/BHA #14, 10,600'-12,245'MD, where had to start to ream/wash from 12,245' to 17,473MD, due to drag down, (15 RPM & 50gpm). Circ. well clean, (22K strokes w/360bbls calculated wash out). Displace open hole to 8.6ppg mud, w/5.5% fresh NSX lubes, from 17,460', w/600bbls. Reduced drag from 385K to 325K, rotary dropped 5K from 20K, to 15K. POOH from 17,460'-17,325'MD on elevators & no issues. No losses or gains observed to the hole. Max gas recorded during the past 24 hours was 1633 units, while showing an average background gas while circulating of 272 units. 8/9/09 POOH from 17,170'-11,090'MD, w/o difficulties. Est. circ. & spot 30bbls Hi-vis Brine 10.2ppg spacer at 11,045'MD, (chased w/10.2ppg Kill Wt Brine). POOH to +/-10,600', & displace well from +/-10,500' to Surface w/10.2ppg non vis Brine, (experienced a leaking element @ 2,000 strokes left on Displacement. Finish displacement & remove RCD head and install trip nipple, after ensuring well bore @ 0psi pressure. Slip and cut drilling line to avoid having to perform later & POOH to BHA #14 tools. Had to LD std. #10 as rabbit had not past thru, (re-drop rabbit in rest of DP & HWDP, - OK). PJSM/Remove nuclear sources, down load MWD data, LD BHA #14 MWD/Geo Pilot tools (signs of slight over torque down hole & 1/4" of wear on NM Flex's. Clear/Clean floor of tools & equipment, Pull wear bushing, install test plug, & C-O lower rams to standard 4 1/2 ram blocks. Max gas was 194 units. Currently preparing to run liner. 8/10/09 Test BOPE per AOGCC requirements, (Mr. Jeff Jones waived witness for state). Pull & LD Test plug & install wear ring/RILDS. RU to & run 189 jts of 4-1/2" Liner/Jewelry per program, MU running tools, Scaper/Magnetic, JB assembly. SLM DP from derrick & RIH w/Liner to 11,090' where have to rotate past wash area. Continue to RIH w/o issues to 14,340'MD, where negative wt. reached & necessary to rotate liner in hole to 14,345'MD. No gas to report. Surface Data Logging After Action Review Employee Name: Colby Marks Date: 8/13/2009 Well: ODSN-36 Hole Section: Production What went as, or better than, planned: Needed to determine an accurate lag time before displacing well with kill mud. Dropped calcium carbide "bomb", and watched for expected peak on chromatagraph. Made needed adjustment and found that we were very close to what our previous numbers had shown. Difficulties experienced: Still some slight flooding of gas trap anytime a shaker screen is being changed or if MPD leaves back pressure pump running.. Recommendations: Dan Sherwood rigged up pulley system in a way that all the weight was being lifted evenly, this seemed to help a great deal. Maybe a better pulley and cables could improve this setup even further. Innovations and/or cost savings: N/A Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $3,500.00 Eugene Payne / Boyd C. Piercey Note: Finish Rig move, Clean tanks, thaw water lines to rig, Prepare to spud ODSK-36i TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd (Pm) % Avg Flow in (gpm) 00 0 Size Pioneer Natural Res.1 ODSK-36i Oooguruk 0 North Slope 0 Daily Charges Nabors 19AC PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 01/28/2008-5:00 Flow Rate (spm) Prepare to spud AK-AM-0005556280 Jim/Gus $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $7,000.00 100 Tri cone 12.25" 0.70 Eugene Payne / Boyd C. Piercey Note: Prepare to spud ODSK-36i, RIH Commence drilling new well TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 2070 TuffSst Silt Cly Clyst Sh Lst 10 Siltst Coal GvlSd 120 11 55 (Pm) % 34000185 9.0 9.0 150 0.1 Avg Flow in (gpm) 3 2 4 210 83.0 57.0 83.0 312 Size Pioneer Natural Res.2 ODSK-36i Oooguruk 0 North Slope 0 Daily Charges Nabors 19AC 4.3 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 01/29/2008-5:00 Flow Rate (spm) 450 105 Drilling AK-AM-0005556280 Jim/Gus 515 $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 02/3/2008-5:00 Flow Rate (spm) Finalize 36i AK-AM-0005556280 Jim/Gus $3,500.00 cP (lb/100ft2) (mg/l) (lbs/bbl) 4.3 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.7 ODSK-36i Oooguruk 3683 North Slope 0 Daily Charges Nabors 19AC Avg Flow in (gpm) (Pm) % 320003683 9.5 50 0.2 6.3 2-3-WT-A-E-2-FD-TD 12 26 3683 3563 20 80 Siltst Tri cone 25.9 12012.25 0.70 Coal GvlSd Cly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type Eugene Payne / Boyd C. Piercey Note: Run Casing, Cement casing, Prepare for move to next hole 100 Total Charges $24,500.00 150 Casing Run 9.635 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 100 Total Charges $21,000.00 Eugene Payne / Boyd C. Piercey Note: POOH, tight spot @3400', rig up to run casing, run casing TG Type 3627 3673 44 2 196 1 0 0 0 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh Lst 80 Siltst Tri cone 25.9 12012.25 0.70 Coal GvlSd 2-3-WT-A-E-2-FD-TD 16 28 3683 3563 20 (Pm) % 320003683 9.6 9.6 74 0.2 7.3 Avg Flow in (gpm) 0 2 44 3628 Size Pioneer Natural Res.6 ODSK-36i Oooguruk 3683 North Slope 0 Daily Charges Nabors 19AC 4.3 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 02/2/2008-5:00 Flow Rate (spm) Run 9.625 Casing AK-AM-0005556280 Jim/Gus $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 02/1/2008-5:00 Flow Rate (spm) 0 0 Cleaning Hole AK-AM-0005556280 Jim/Gus 0 $3,500.00 cP (lb/100ft2) (mg/l) (lbs/bbl) 4.3 PV YP Alkal Md Cor Solids 949 6 0 020893683265 Size Pioneer Natural Res.5 ODSK-36i Oooguruk 3683 North Slope 13 Daily Charges Nabors 19AC Avg Flow in (gpm) 0 7 113 1834 45.9 79.1 3680 (Pm) % 320003683 9.5 9.5 105 0.3 6.3 120 42 19 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 3670 3683 44 29 3688 37 4 0 0 BG 1543 1487 83 71 9576 10 2 0 0 WTG 733 782 43 23 3373 0 0 0 0 WTG 1863 1924 113 37 4861 4 0 0 0 WTG 0 WTG Eugene Payne / Boyd C. Piercey Note: Drilled to 3683, pumped sweep, POOH worked through tight spot, pumped dry job, circulated RIH to 3683' from 1920', pump sweep prepare to POOH. Total Charges $17,500.00 100 Tri cone 12.25" 0.70 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $14,000.00 100 Tri cone 12.25" 0.70 Eugene Payne / Boyd C. Piercey Note: Continue Drilling 0 BG BG BG 3412 3601 36 27 3638 8 0 0 0 BG 2447 3411 33 15 2173 0 0 0 0 BG 1964 2446 66 32 4200 0 0 0 0 Type 1771 1963 59 29 3994 0 0 0 0 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 107515 TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 120 16 37 (Pm) % 330002510 9.4 9.5 124 0.3 Avg Flow in (gpm) 17 24 66 2095 60.1 190.5 554.9 2069 Size Pioneer Natural Res.4 ODSK-36i Oooguruk 3662 North Slope 2077 Daily Charges Nabors 19AC 3602 3655 42 29 3816 26 0 0 4.3 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 01/31/2008-5:00 Flow Rate (spm) 645 151 Drilling AK-AM-0005556280 Jim/Gus 2971 $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $10,500.00 100 Tri cone 12.25" 0.70 Eugene Payne / Boyd C. Piercey Note: Continue Drilling 0 BG 0 BG BG BG 1031 1190 199 99 12363 0 0 0 0 BG 838 1001 156 67 8104 0 0 0 0 BG 568 814 95 45 5374 0 0 0 0 Type 282 500 18 1940 0 0 0 0 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 90 10 TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 120 16 33 (Pm) % 300001415 9.4 9.3 97 0.2 Avg Flow in (gpm) 22 43 199 1611 210.0 209.2 552.5 1682 Size Pioneer Natural Res.3 ODSK-36i Oooguruk 1770.1 North Slope 1585 Daily Charges Nabors 19AC 1334 1383 146 61 7460 0 0 0 1510 1770 64 35 4530 0 0 0 4.3 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 01/30/2008-5:00 Flow Rate (spm) 499 116 Drilling AK-AM-0005556280 Jim/Gus 1426 $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $28,217.00 Eugene Payne / Boyd C. Piercey Note: Run 2 7/8" tubing, Displace with inhibitor, prepare for rig move TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd (Pm) % 320003683 8.5 Avg Flow in (gpm) Size Pioneer Natural Res.8 ODSK-36i Oooguruk 3683 North Slope 0 Daily Charges Nabors 19AC 4.3 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 02/4/2008-5:00 Flow Rate (spm) Finalize 36i AK-AM-0005556280 Jim/Gus $3,500.00 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $32,344.37 Boyd Piercy/Colby Marks Ran 2nd Stage cement. Freeze protect well. Rig down and move rig over to OSDN-36i. Leveling rig at time of report. TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd (Pm) % Avg Flow in (gpm) Size Pioneer Natural Res.8 ODSN-36 Oooguruk North Slope Daily Charges Nabors 19AC PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 02/25/2009-5:00 Flow Rate (spm) Level Rig AK-AM-0005556280 Rod/Nick $4,127.37 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/03/2009-05:00 Flow Rate (spm) 621 177 Tripping AK-AM-0005556280 Jim/Nick 3424 $4,873.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids 145563 6069 1833 65292199691 1622 277 68050 3671 1455 59291239219 738 400 Size Pioneer Natural Res.16 ODSN-36 Oooguruk 8296 North Slope 1395 Daily Charges Nabors 19AC Avg Flow in (gpm) 0 350 1622 9339 0.0 89.4 189.0 9640 (Pm) % 21,0007891 10.5 10.5 48 9.5 3683 19 22 Siltst Coal GvlSdCly Clyst Sh Lst 1010 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 80 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8296 8461 576 276 52419 2773 1149 514 217 CG 8461 8556 826 322 72944 3757 1591 691 271 CG 8556 8745 1483 665 126135 7203 2950 1141 397 CG 8745 9123 829 574 73564 4010 1235 623 346 CG 224 CG 234 GP Boyd Piercy/Colby Marks Note: Daily charges have changed Drilled through Kuparuk C, started taking major losses. Performing wiper trip to 8600'MD to build mud volume Losses from 21:00 hrs - 01:00 was 1051 bbls Total Charges $40,307.04 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/3/2009-5:00 Flow Rate (spm) 621 177 Tripping AK-AM-0005556280 Jim/Nick 3424 $4,873.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.15 ODSN-36 Oooguruk 8296 North Slope 879 Daily Charges Nabors 19AC Avg Flow in (gpm) 166 150 308 7588 97.5 87.9 197.0 7906 (Pm) % 21,0007891 10.5 10.5 48 9.5 3683 19 22 Siltst Coal GvlSdCly Clyst Sh Lst 2050 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 30 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 7417 7417 711 140 66448 3002 1309 658 271 TG Boyd Piercy/Colby Marks Note: Daily charges have changed Drilled to 7417', then POOH for wiper trip. Weighted up mud to 10.5 ppg. Performed dynamic FIT to 12.5 ppg EMW. Drilling ahead at report time. Total Charges $35,443.75 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $30,570.46 2 Security PDC 8.75 0.902 Boyd Piercy/Colby Marks Note: Daily charges have changed Drilled ahead to Base of Torok. POOH for wiper trip at report time. GP GP 7100 7417 534 360 45225 2744 1261 583 235 Type 5966 7100 756 145 62359 3659 1562 682 260 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 530 TuffSst Silt Cly Clyst Sh Lst 65 Siltst Coal GvlSd 3683 13 18 (Pm) % 21,0007322 9.2 9.2 48 5.4 Avg Flow in (gpm) 0 158 756 6978 90.6 214.0 6999 Size Pioneer Natural Res.14 ODSN-36 Oooguruk 7417 North Slope 1451 Daily Charges Nabors 19AC 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/2/2009-5:00 Flow Rate (spm) Tripping AK-AM-0005556280 Jim/Nick $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/1/2009-5:00 Flow Rate (spm) 501 141 Drilling AK-AM-0005556280 Jim/Nick 1593 $4,873.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.13 ODSN-36 Oooguruk 5966 North Slope 1929 Daily Charges Nabors 19AC Avg Flow in (gpm) 30 145 2669 5090 148.0 113.0 211.0 5628 (Pm) % 20,5005422 9.3 9.3 45 5.9 3683 16 19 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 4037 2669 145 221829 7840 3274 1035 216 GP Boyd Piercy/Colby Marks Note: Daily charges have changed Pumping sweeps every 500'. Drilling ahead at report time Total Charges $25,697.17 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 02/28/2009-5:00 Flow Rate (spm) 501 141 Drilling AK-AM-0005556280 Jim/Nick 1593 $5,491.53 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.12 ODSN-36 Oooguruk 4037 North Slope 354 Daily Charges Nabors 19AC Avg Flow in (gpm) 30 15 60 4010 148.0 136.0 223.0 3931 (Pm) % 210003703 9.3 9.3 43 0.1 5.9 3683 13 16 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type Boyd Piercy/Colby Marks Drill 20' of new formation and perform FIT to 14.2 ppg. Could not downlink to Geo Pilot, POOH to reconfigure MWD tools. RIH and shallow pulse test MWD. Continue to bottom. Drilling ahead at report time. Total Charges $21,442.12 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $15,950.59 2 Security PDC 8.75 0.902 Boyd Piercy/Colby Marks Finished laying down bad drill pipe. Test BOP stack. M/U BHA and RIH to 1500'. Perform shallow pulse test for MWD. Washed and reamed from 3434' to 3529'. Drill float equipment. Displacing sea water with LSND mud at report time TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 3683 11 15 (Pm) % 210003683 9.3 9.3 43 5.9 Avg Flow in (gpm) Size Pioneer Natural Res.11 ODSN-36 Oooguruk 3683 North Slope 0 Daily Charges Nabors 19AC 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 02/27/2009-5:00 Flow Rate (spm) 445 127 Drill Cement AK-AM-0005556280 Rod/Nick 951 $5,491.53 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 02/26/2009-5:00 Flow Rate (spm) POOH AK-AM-0005556280 Rod/Nick $4,965.77 cP (lb/100ft2) (mg/l) (lbs/bbl) PV YP Alkal Md Cor Solids Size Pioneer Natural Res.10 ODSN-36 Oooguruk North Slope Daily Charges Nabors 19AC Avg Flow in (gpm) (Pm) % 200003683 8.7 8.7 28 1.322 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type Boyd Piercy/Colby Marks Note: Change in daily charges for changeout Mansfield for Piercy Nipple up. RIH to lay down bad drill pipe. POOH at report time to lay down bad drill pipe Total Charges $37,310.14 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/03/2009-05:00 Flow Rate (spm) 621 177 Building Volume AK-AM-0005556280 Jim/Joe 3424 $4,566.75 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.16 ODSN-36 Oooguruk 9691 North Slope 114 Daily Charges Nabors 19AC Avg Flow in (gpm) 0 150 3223 9691 0.0 60.6 164.0 9779 (Pm) % 21,0009805 10.7 10.7 62 0.2 9.9 3683 20 30 Siltst Coal GvlSdCly Clyst Sh Lst 3015 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 55 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9691 9805 3223 150 280751 12796 4632 1571 452 TG Ream back to bottom and drill to 9805' with losses approx. 150-170 bbl/hr. POOH to 8550' to build volume. Static losses approx. 24-30 Boyd Piercy/Colby Marks bbl/hr. Preparing for Gunk squeeze @ report time. Note: Daily charges have changed POOH to 8555' to build volume after encountering losses though the Kup C. Pumped LCM pill and wait 15 min. Ream back to bottom and drill to 9754'. Pump 2nd LCM pill. Continued to epxperience losses, POOH to 8555' to build volume Total Charges $44,883.79 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $97,685.65 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Tom Mansfield Established circulation with 400 gpm and partial loss of returns (50-60%). Spotted 55 bbl, 10.7+ ppg Black Magic SFT pill. Rigged up and ran wireline string shot and collar locator. String shot at 9394', collar locator at 9397'. Fired shot and backed off. Pull wireline. Spot 17 ppg pill in drill pipe with max gas of 265 units. Begin POOH tight. TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 10 20 TuffSst Silt Cly Clyst Sh Lst 70 Siltst Coal GvlSd 9810 10635 825 17 2210635 10.80 10.80 55 (Pm) % 22,000 0.10 11.4 3.5 PV YP Nabors 19AC Avg Flow in (gpm) 7 12 265 Size Pioneer Natural Res.29 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/17/2009-05:00 Flow Rate (spm) 81 23 Fishing AK-AM-0005556280 Rodney/Joey 1100 $4,260.21 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/16/2009-05:00 Flow Rate (spm) 42 12 Circulating! AK-AM-0005556280 Rodney/Joey 500 $3,034.05 Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 83268 2274 623 224860 70 Size Pioneer Natural Res.28 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Nabors 19AC Avg Flow in (gpm) 16 70 860 B.U. (Pm) % 22,000 0.10 11.4 3.5 PV YP 10635 10.80 10.80 55 9810 10635 825 17 22 Siltst Coal GvlSdCly Clyst Sh Lst 7020 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 TypeC2C3 C4 Tot C5 TotDepthMax Average C1 82 BU 860 units gas on bottoms up. Initially losing approx. 125 bbls/hr, slowed to approx 30 bbl/hr. 25 Boyd Piercey / Tom Mansfield Ran wireline for freepoint with stringshot. Set at 9394'. Work torque into drill string. Fired shot. No back-off. Pull out wireline tools and re-run. Could not get tool to set depth. Pull tool. R/U to circulate. Circulation established with Total Charges $93,113.74 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $90,079.69 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Tom Mansfield Waiting to run freepoint. TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 10 20 TuffSst Silt Cly Clyst Sh Lst 70 Siltst Coal GvlSd 9810 10635 825 21 2910635 10.80 10.80 55 (Pm) % 22,000 0.10 11.4 3.5 PV YP Nabors 19AC Avg Flow in (gpm) Size Pioneer Natural Res.27 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/15/2009-05:00 Flow Rate (spm) wait on wireline AK-AM-0005556280 Rodney/Joey $3,034.05 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/14/2009-05:00 Flow Rate (spm) Rig up wireline AK-AM-0005556280 Rodney/Joey $3,647.13 Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) Size Pioneer Natural Res.26 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Nabors 19AC Avg Flow in (gpm) (Pm) % 22,000 0.10 11.4 3.5 PV YP 10635 10.80 10.80 52 9810 10635 825 20 31 Siltst Coal GvlSdCly Clyst Sh Lst 7020 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 TypeC2C3 C4 Tot C5 TotDepthMax Average C1 25 Boyd Piercey / Tom Mansfield Tight hole, packing off. Pull to 9690'. Stuck pipe. Unable to circulate. Work stuck pipe. Hole taking minor losses (approx 5 bbls/hr). Waiting on wireline unit to freepoint stuck pipe. Total Charges $87,045.64 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $83,395.51 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Tom Mansfield Backream with high torque and pack off problems to 9660 with minor seepage (approx 10 bbl/hr) and losses due to. pack-offs. Encounter very tight conditions around 9660' (in Kuparuk C). Work and jar pipe. Replace MPD element. 147 GP Type 10550 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 10 20 TuffSst Silt Cly Clyst Sh Lst 70 Siltst Coal GvlSd 9810 10635 825 22 2710635 10.80 10.80 57 (Pm) % 22,000 0.13 11.7 Nabors 19AC Avg Flow in (gpm) 150 337 Size Pioneer Natural Res.25 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges 10635 240 190 19432 1043 538 291 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/13/2009-05:00 Flow Rate (spm) Chg MPD element AK-AM-0005556280 Jim/Joey $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/12/2009-05:00 Flow Rate (spm) 576 164 TD for 7" CSG AK-AM-0005556280 Jim/Joey 3360 $4,873.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids 19432 1043 538 2911055010635 240 190 8966 487 281 1741035510550 120 140 Size Pioneer Natural Res.24 ODSN-36 Oooguruk 10635 North Slope 779 Daily Charges Nabors 19AC Avg Flow in (gpm) 150 130 280 10348 na 53.2 140.9 10048 (Pm) % 22,00010455 10.75 10.75 54 0.13 10.9 9810 10635 825 16 27 Siltst Coal GvlSdCly Clyst Sh Lst 7020 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9810 9865 202 145 17262 755 379 266 152 GP 9865 10200 196 135 15032 676 326 206 114 BG 10200 10345 292 125 9270 471 254 169 94 BG 10345 10355 280 180 21511 1109 527 287 153 GP 99 BG 147 GP 25 Boyd Piercey / Tom Mansfield Drilling ahead from 9810' with varying minor losses (5-20 bbls/hr). Pumping sweeps every stand until TD. Reached TD for 7" CSG at 2:35 am. Pump 40 bbl HiVis sweep. Start POOH backreaming 1 stand per hour. Total Charges $78,522.22 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $73,648.93 2rr2 Security PDC 8.75 0.902 1 25 Boyd Piercey / Tom Mansfield Washed and reamed to 9519' with tight hole and pack off problems. Pulled to 9400'. Washed and reamed back to bottom at 9810'. Began drilling new hole at 03:00. BG Type 9810 9856 146 138 10813 595 346 259 153 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 9810 46 37 34 (Pm) % 22,0009810 10.70 10.70 54 0.1 11.4 Avg Flow in (gpm) 142 138 3350 7:32 66.9 61.1 119.0 9820 Size Pioneer Natural Res.23 ODSN-36 Oooguruk 9856 North Slope 46 Daily Charges Nabors 19AC 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/11/2009-05:00 Flow Rate (spm) 313 89 Drilling ahead AK-AM-0005556280 Jim/Joey 1834 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/10/2009-05:00 Flow Rate (spm) 313 89 Working Pipe AK-AM-0005556280 Jim/Joey 1834 $4,873.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.22 ODSN-36 Oooguruk 9810 North Slope Daily Charges Nabors 19AC Avg Flow in (gpm) na na 4918 19:22 (Pm) % 22,000981010.75 10.75 48 0.1 10.4 3683 11 26 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8925 8925 4918 86 386139 15574 4392 1267 317 GP off. TOOH to 8925'. Packed off. Worked pipe from 8925' to 8990'. RIH to 9170'. Worked pipe. RIH to 9360'. Working pipe with tight Boyd Piercey/Tom Mansfield hole and packing off. Max gas of 4918 units. Circulated out heavy trip pill mud at 3600'. RIH to 7965'. Hole taking 30-40 bbl/hr mud at 6075'. CBU. 11.3 ppg mud to surface. Losses stopped. RIH to 8050' and circulated with no losses. Float in string stuck open. RIH to 9206'. Packed Total Charges $68,778.64 2rr2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $63,905.35 2 Security PDC 8.75 0.902 Boyd Piercey/Tom Mansfield RIH to 1984' and rig up MPD equipment. Circulate 17 ppg kill pill out of hole at 2000'. RIH to 3630'. Fill pipe and circulate out more 17 ppg kill mud. Max gas of 72 units. Charges have been changed for 03/08/09 to reflect the absence of John Patton from the SOA to 3647.13 for the day. Pulled to 2450' and spotted 35 bbl high vis fresh water gel pill. Pulled to 2050' and spotted a 130 bbl 17 ppg kill pill. POOH. Hole took 44 bbls during trip out. L/D BHA. Slipped and cut drilling line. P/U new BHA. RIH to 559'. Shallow pulse test MWD. GP Type 3622 3622 72 30 5661 262 100 47 13 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 3683 14 27 (Pm) % 22,0009805 10.7 10.7 48 0.1 9.9 Avg Flow in (gpm) na na 72 Size Pioneer Natural Res.21 ODSN-36 Oooguruk 9805 North Slope Daily Charges Nabors 19AC 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/09/2009-05:00 Flow Rate (spm) 552 158 Tripping AK-AM-0005556280 Jim/Joe 2050 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/08/2009-05:00 Flow Rate (spm) 544 155 Tripping AK-AM-0005556280 Jim/Joe 2960 $3,647.13 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.20 ODSN-36 Oooguruk 9805 North Slope Daily Charges Nabors 19AC Avg Flow in (gpm) na na 511 (Pm) % 22,000980510.7 10.7 49 0.3 9.9 3683 15 26 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9809 9809 511 300 49018 1712 568 226 83 GP 9460'. Circulated with a max gas of 511 units. Hole taking 100 bbls/hr. Circulated across top of hole. Losses decreased to 40 bbls/hr. Boyd Piercey/Tom Mansfield Mixed and pumped cement / gunk squeeze. Losses stopped. Pulled to 8555'. Circulated at 240 gpm. Hole packed off with a loss rate of 15-20 bbls/hr and no static losses. POOH from with tight spots at 7025' and 6047'. Continued reaming with intermittent packing off and tight hole conditions from 9650' to 9805'. Mud loss averaging 40 bbls/hr. Max gas of 318 units. Drilled 5' of new hole and pulled out to 8400'. Removed Grey valve. Floats holding. RIH to Total Charges $59,032.06 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/07/2009-05:00 Flow Rate (spm) 544 155 Reaming to Bottom AK-AM-0005556280 Jim/Joe 2960 $4,876.29 cP (lb/100ft2) (mg/l) (lbs/bbl) 3.5 PV YP Alkal Md Cor Solids Size Pioneer Natural Res.19 ODSN-36 Oooguruk 9805 North Slope Daily Charges Nabors 19AC Avg Flow in (gpm) 132 150 5250 (Pm) % 22,000980510.7 10.7 48 0.2 10.9 3683 17 30 Siltst Coal GvlSdCly Clyst Sh Lst TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9303 9303 5250 4200 390368 16019 4709 1321 353 WTG to 9300' and washed and reamed. Max bottoms up gas of 5250 units with gas cut mud at flow line to 10.2 ppg. Reamed to 9522' and Boyd Piercey/Tom Mansfield lost 62 bbls at top of Kup C. Loss rate slowed but continued at approx 35-40 bbl/hr. Continued reaming with intermittent packing off and tight hole conditions from 9650'. TOOH from 9122' to 8936'. Packed off. Washed and reamed to 9320' and established circulation at 550 gpm. Packed off at 8945', 8975', 9045', 9060', 9135', and 9265'. MPD rotary bearing leaking. POH to 8500' and changed same. RIH Total Charges $55,390.93 2 Security PDC 8.75 0.902 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $49,450.54 2 Security PDC 8.75 0.902 Boyd Piercy/Colby Marks Note: Daily charges have changed Built volume.RIH to 9450' and pump LVT/cement pill. Wait for pill to set. Circulate with no losses. Attempted to turn on MWD tools. Floats failed. Working through tight spots and pack off at report time. WTG Type 9805 9805 2559 150 210887 7579 2180 688 180 C2 C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) TuffSst Silt Cly Clyst Sh LstSiltst Coal GvlSd 3683 17 25 (Pm) % 21,0009805 10.7 10.7 61 0.1 9.9 Avg Flow in (gpm) 162 150 2559 Size Pioneer Natural Res.18 ODSN-36 Oooguruk 9805 North Slope Daily Charges Nabors 19AC 3.5 PV YP Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/06/2009-05:00 Flow Rate (spm) 544 155 Reaming to Bottom AK-AM-0005556280 Jim/Joe 3323 $4,566.75 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $100,719.70 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Tom Mansfield POOH tight to 5040'. Pipe wet. Pump 6 bbl 17 ppg pill. Pull to 2200' and circulate surface to surface. Pump 33 bbl HiVis gel pill and chase with 36 bbls 17 ppg mud. Pull to 1800' and continue to pump 77 bbls of 17 ppg mud. Chase with 12 bbls 10.8 ppg mud. Rig down MPD and test BOPs. Prepare to M/U BHA. TypeC2C3 C4 Tot C5 TotDepthMax Average C1 Gas Breakdown Gas (units)Chromatograph (ppm) 10 20 TuffSst Silt Cly Clyst Sh Lst 70 Siltst Coal GvlSd 9810 10635 825 17 2210635 10.80 10.80 55 (Pm) % 22,000 0.10 11.4 3.5 PV YP Nabors 19AC Avg Flow in (gpm) 80 680 Size Pioneer Natural Res.30 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 03/18/2009-05:00 Flow Rate (spm) Fishing AK-AM-0005556280 Rodney/Joey $3,034.05 Customer:Report #: Well:Date: Area:04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air POOH AK-AM-0005556280 Jim/Joey $4,873.29 (lbs/bbl) (Pm) % 04/6/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 49 ODSN-36 Oooguruk 9509 0 580 4104 Circ @ 8969 0.0 0.05 12.1 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 9509 10.80 10.80 52 9286 20 33 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot Circ 8969 4104 750 361583 13368 4235 1412 751 TG Boyd Piercey / Colby Marks Reamed down to 9240', hole tight and packing off. Worked pipe to 8975'. Increased lube and reamed to 9096. Lost 400psi due to possible pipe washout, pumped dry job and POOH hole. POOH at report time. Total Charges $188,383.99 9 Security PDC 8.75 .924 Customer:Report #: Well:Date: Area:04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $183,510.70 9 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Reamed back down to 9509'. Hole still taking 100bbl/hr losses. POOH to 8100' to mix second gunk pill. Pumped second gunk pill. POOH to 8085' to let pill set. RIH to bottom at report time, reaming and washing due to pack off and tight spots. TGCirc9317 1380 750 121706 7748 3606 1603 1142 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9286 14 269509 10.80 10.80 48 0.05 10.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 0.0 225 1380 48 ODSN-36 Oooguruk 9509 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/5/2009-05:00 0 469 134 Washing/Reaming AK-AM-0005556280 Jim/Joey 1815 $4,873.29 Customer:Report #: Well:Date: Area:04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 469 134 Washing/Reaming AK-AM-0005556280 Jim/Joey 1815 $4,873.29 (lbs/bbl) (Pm) % 04/4/2009-05:00 161 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 47 ODSN-36 Oooguruk 9509 225 1815 0.0 80.5 251.0 9491 0.10 12.2 3.7 PV YP 28,000 Alkal Md Cor Solids (mg/l) 9509 10.80 10.80 48 9286 17 26 Cly Clyst Sh Lst 60 TuffCoal GvlSd Sst Silt 20 Depth Max Average 20 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot Circ 9011 1815 215 166293 7554 2656 1101 796 TG to bottom, encountering pack off and still taking losses ranging from 30-70 bbl/hr depending upon pack off and flow rate. Boyd Piercey / Colby Marks Washing and reaming, as well as building volume at report time. Drilled ahead to 9509 with average losses of 300bl/hr or more.Mixed and pumped LVT/Gunk pill. Pumped pill down hole and POOH to 8100' and waited on pill to set. RIH and attempt tp circulate at 9028, packed off. Washing and reaming Total Charges $178,637.41 9 Security PDC 8.75 .924 Customer:Report #: Well:Date: Area:04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $173,764.12 9 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Trip in hole after POOH to check for washout. Drill ahead to approx 9348'MD, encountered losses, pump 80bbl LCM pill. Rack back one stand allow pill to soak. TG TG Circ 9011 1491 92443 3851 1323 534 417 754Circ9240 1290 C1 553 TypeC2C3 C4 Tot C5 Tot 111882 5138 1843 Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9286 16 229286 10.80 10.80 48 0.05 12.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 0.0 52.7 125.0 9343 269 1491 9011 45 ODSN-36 Oooguruk 9348 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/3/2009-05:00 62 630 180 RIH AK-AM-0005556280 Jim/Joey 3250 $5,627.85 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $168,136.27 8 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Found wash out at first heavy weight below jars. Picked up BHA and shallow test same. Install RCD at 2212' Continue RIH taking check shot surveys up to 7000'. Swap out RCD bearing. RIH to 8521 at report time, slowly brining pump rate up and circulating. TGCirc8519 1419 100 134267 6068 2143 804 507 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 6654' 14 229286 10.80 10.80 50 12.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 0.0 125 1419 45 ODSN-36 Oooguruk 9286 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/2/2009-05:00 531 150 RIH AK-AM-0005556280 Jim/Joey 2756 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 501 142 POOH AK-AM-0005556280 Jim/Nick 2643 $4,873.29 (lbs/bbl) (Pm) % 04/1/2009-05:00 102 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 44 ODSN-36 Oooguruk 9286 0 280 807 9184 0.0 80.0 117.0 9205 12.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 9286 10.80 10.80 48 6654' 13 21 Cly Clyst Sh Lst 60 TuffCoal GvlSd Sst Silt Depth Max Average 40 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 9184 807 295 78456 4069 1652 785 626 WTG Boyd Piercey / Colby Marks Drilled ahead from 9184 to 9286. 400 psi loss in pump pressure; floats not holding. Decision was made to POOH. POOH at report time. Total Charges $163,262.98 8 Security PDC 8.75 .924 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 574 GP66818 3570 1465 70785509050 690 266 Total Charges $158,389.69 8 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Drilled to 9184'. Reamed out of hole to 8990, due to tight spots and pack off. Finish POOH to 8045'. RIH to 9059 and encountered pack off. Washing and reaming to bottom at report time. 1679 GP2438 GP GP 9050 9184 587 300 52559 3456 1590 809 672 GP 8394 8450 628 310 60943 3413 1320 541 392 74284508550 773 251 C1 512 TypeC2C3 C4 Tot C5 Tot 83833 4561 1803 Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 6654' 15 249184 10.80 10.80 48 12.2 3.7 PV YP 28,000 Alkal Md Cor Solids (mg/l) 0.0 79.8 202.0 8809 294 235 2403 43 ODSN-36 Oooguruk 9184 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst 184628 12678 5598275Circ9184 2403 (lbs/bbl) (Pm) % 03/31/2009-05:00 790 501 142 Washing/Reaming AK-AM-0005556280 Jim/Nick 2643 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $153,516.40 8 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Installed RCD bearing, drilled ahead from 7305'-8394'. Pumping hi vis sweep every 500'. Drilling ahead at report time GP73058394 518 115 51573 2702 1018 415 326 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 6654' 16 247980 10.80 10.80 47 10.8 3.7 PV YP 26,000 Alkal Md Cor Solids (mg/l) 103.0 57.3 193.0 8243 213 115 518 8243 42 ODSN-36 Oooguruk 8394 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/30/2009-05:00 1089' 617 165 Drilling AK-AM-0005556280 Rodney/Nick 3247 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $148,643.11 Boyd Piercey / Colby Marks Reamed to 6645' and tagged cement. Confirmed sidetrack at 6654'. Drilled from 6654'-7305'. POOH to kick point. Began mud swap and dilution.Finish mud swap, installing RCD head at report time GP66547305 382 135 36737 1957 828 420 338 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 15 217237 10.80 10.80 48 13.0 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 44.8 125.0 7006 96 135 382 7000 41 ODSN-36 Oooguruk 7305 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/29/2009-05:00 651' 549 156 Install RCD AK-AM-0005556280 Rodney/Nick 2328 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $143,769.82 Boyd Piercey / Colby Marks Finish laying down old DP. Pick up BHA #8 and RIH with same. Shallow pulse test. Slipped and cut drill line. Continue RIH, encountering pack off, work through accordingly.Took 4 surveys. Washing and reaming looking for top of cement and conditioning mud at report time. C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 15 236750 10.80 10.80 49 12.0 3.5 PV YP 21,500 Alkal Md Cor Solids (mg/l) 120 110 200 40 ODSN-36 Oooguruk 6750? Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/28/2009-05:00 0 549 156 Wash/Ream AK-AM-0005556280 Rodney/Nick 2328 $4,873.29 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $137,976.91 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Colby Marks Pumnped cement kick off plug at 7150'. Changed rams and tested BOP stack. Laying down bad drill pipe at report time C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9810 10635 825 15 2410635 10.80 10.80 50 11.0 3.5 PV YP 21,500 Alkal Md Cor Solids (mg/l) 0 39 ODSN-36 Oooguruk 10635 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/27/2009-05:00 0 Lay Down Bad DP AK-AM-0005556280 Rodney/Nick $3,647.13 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air RIH AK-AM-0005556280 Rodney/Nick $3,647.13 (lbs/bbl) (Pm) % 03/26/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 38 ODSN-36 Oooguruk 10635 0 330 2985 9.9 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 10635 10.80 10.80 50 9810 10635 825 14 24 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 25 Boyd Piercey / Colby Marks Note: Daily charges decreased as there is no longer an ADT on the ticket POOH with no fish and layed down BHA. Tested BOPs. TIH and set cement plug for abandonment at 9420'. Circulating before setting second plug at Torok at report time. Total Charges $134,329.78 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $130,682.65 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Colby Marks Note: Daily charges decreased as there is no longer an ADT on the ticket RIH and fishing attempt @ 9450'. Unsuccessful. Decision was mad to POOH to set cement plug and sidetrack. Currently POOH at report time. C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9810 10635 825 17 2710635 10.80 10.80 53 10.4 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 0 550 3085 37 ODSN-36 Oooguruk 10635 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/25/2009-05:00 0 RIH AK-AM-0005556280 Rodney/Nick $3,340.59 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air RIH AK-AM-0005556280 Rodney/Nick $4,566.75 (lbs/bbl) (Pm) % 03/24/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 36 ODSN-36 Oooguruk 10635 0 11.0 3.5 PV YP 21,000 Alkal Md Cor Solids (mg/l) 10635 10.80 10.80 53 9810 10635 825 16 27 Cly Clyst Sh Lst 70 TuffCoal GvlSd Sst Silt 10 Depth Max Average 20 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 25 Boyd Piercey / Colby Marks POOH. M/U fishing BHA and RIH. Once at casing shoe, displaced 17.0 ppg mud out of hole with lighter mud. Displacing 17ppg mud at time of report. Total Charges $128,568.22 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $124,001.47 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Colby Marks Washed and reamed to top of fish. Circulate until hole is clean. POOH at report time. GPcirc at 9414 4870 350 409158 17562 6055 2071 1115 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average 20 Gas Breakdown Gas (units)Chromatograph (ppm) 10 Coal GvlSd Sst Silt Cly Clyst Sh Lst 70 Tuff 9810 10635 825 18 2810635 10.80 10.80 53 11.0 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 0 350 4870 35 ODSN-36 Oooguruk 10635 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/23/2009-05:00 0 POOH AK-AM-0005556280 Rodney/Nick $4,566.75 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Wash/Ream AK-AM-0005556280 Rodney/Nick $4,566.75 (lbs/bbl) (Pm) % 03/22/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 34 ODSN-36 Oooguruk 10635 0 450 2650 10.7 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 10635 10.80 10.80 51 9810 10635 825 21 30 Cly Clyst Sh Lst 70 TuffCoal GvlSd Sst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 Depth Max Average 20 C1 TypeC2C3 C4 Tot C5 Tot circ at 9294 2650 650 234506 13823 4025 1052 850 GP 25 Boyd Piercey / Colby Marks Circulating/reaming to topof fish. Ecnountering pack offs frequently and working accordingly. Washing and reaming at report time. Total Charges $119,434.72 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $114,867.97 2rr2 100-125Security PDC 8.75 0.902 15.5 25 Boyd Piercey / Colby Marks Washing and reamin to fish. Circulating and conditioning mud. Encountering numerous packoffs, working pipe and adjusting pumps accordingly. Still reaming at report time. GPcirc at 8750 3628 650 334325 15025 5667 2038 1040 C1 TypeC2C3 C4 Tot C5 Tot 10 Depth Max Average Sst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 20 TuffCoal GvlSdCly Clyst Sh Lst 70 9810 10635 825 18 2710635 10.80 10.80 53 10.3 3.5 PV YP 22,000 Alkal Md Cor Solids (mg/l) 246 600 3628 33 ODSN-36 Oooguruk 10635 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 03/21/2009-05:00 0 Wash/Ream AK-AM-0005556280 Rodney/Nick $4,566.75 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air POOH to shoe AK-AM-0005556280 Rodney/Nick $5,321.31 (lbs/bbl) (Pm) % 03/20/2009-05:00 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) 32 ODSN-36 Oooguruk 10635 0 Daily Charges Nabors 19AC Avg na 80 417 10.2 3.5 PV YP 21,000 Alkal Md Cor Solids (mg/l) 10635 10.80 10.80 52 9810 10635 825 19 28 Sd Cly Clyst Sh Lst 7020 TuffCoal GvlSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 Depth Max Average C1 120 TypeC2C3 C4 Tot C5 Tot 32331 1510 540 208circ at 7960 303 GP circ at 6500 1000 98988 3572 1049 324 162 GP 25 Boyd Piercey / Tom Mansfield Washed and reamed to 7960' and circulated at 550 gpm. Packed off at 7965' w/ losses at 2 BPM. Circulate and ream at 8291'. Pump problems. POOH to shoe for pump repairs. Additional Charge for mudlogger changeout. Total Charges $110,301.22 2rr2 100-125Security PDC 8.75 0.902 15.5 circ at 8291 417 165 GP44752 1726 552 231 Customer:Report #: Well:Date: Area:05:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 03/19/2009-05:00 Flow Rate (spm) 532 151 RIH for clean-out AK-AM-0005556280 Rodney/Nick 1960 $4,260.21 Alkal Md Cor Solids cP (lb/100ft2) (mg/l) (lbs/bbl) 80644 2126 501 1433666 846 Size Pioneer Natural Res.31 ODSN-36 Oooguruk 10635 North Slope 0 Daily Charges Nabors 19AC Avg Flow in (gpm) 135 90 1363 5160' (Pm) % 22,000 9.9 3.5 PV YP 10635 10.80 10.80 52 9810 10635 825 17 26 Siltst Coal GvlSdCly Clyst Sh Lst 7020 TuffSst Silt Gas Breakdown Gas (units)Chromatograph (ppm) 10 Type circ at C2 C3 C4 Tot C5 TotDepthMax Average C1 162 circ at 5160 1363 137997 4332 1145 325 155 WTG circ at 6500 1000 98988 3572 1049 324 WTG 68 WTG was 12.6 ppg. RIH to 6500' and circulated bottoms up with a Max gas of 1000 units. Maximum mud weight measured at flowline was 25 Boyd Piercey / Tom Mansfield 11.7 ppg. Hole attempting to pack of around 6450' accompanied with 45 bbl mud loss. Wash and ream in hole to approx 7275' at. report time w/ 135 units gas. John Patton added to daily charges for today. RIH to shoe and circulated 3X B/U with a Max gas of 846 units. Maximum mud weight measured at flowline was 13.6 ppg. RIH to 5160' and circulated bottoms up with a Max gas of 1363 units. Maximum mud weight measured at flowline Total Charges $104,979.91 2rr2 100-125Security PDC 8.75 0.902 15.5 Customer:Report #: Well:Date: Area:04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $193,257.28 9 Security PDC 8.75 .924 Boyd Piercey / Colby Marks Found pipe washout in 3 different sections of drillpipe. POOH completely due to bad drill pipe. Laying down heavy weight drill pipe at report time. C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9286 19 309509 11.10 11.10 56 0.05 14.2 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 0.0 0 150 1180 50 ODSN-36 Oooguruk 9509 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/7/2009-05:00 0 POOH AK-AM-0005556280 Jim/Joey $4,873.29 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 497 138 Short Trip AK-AM-0005556280 Rod/Nick 2700 $4,873.29 (lbs/bbl) (Pm) % 04/19/2009-05:00 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 62 ODSN-36 Oooguruk 10625' 92 101 1546 10008 0.0 0.0 0.0 12.7 3.6 PV YP 30 Alkal Md Cor Solids (mg/l) 10625 10.80 10.80 52 6740 15 27 Cly Clyst Sh Lst 75 TuffCoal GvlSd Sst Silt 10 Depth Max Average 15 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 10008 1546 TG Eugene Payne / Wayne Hermanson Continue to backream out of the hole while experiencing packoffs and stalling on every stand. Adding LCM @ 1 min/sack to keep consistent flow of material downhole. Total Charges $250,793.56 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 497 138 Drilling AK-AM-0005556280 Rod/Nick 2700 $4,873.29 (lbs/bbl) (Pm) % 04/18/2009-05:00 184' Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 61 ODSN-36 Oooguruk 10445' 130 113 210 10587 0.0 22.0 126.0 10604 12.7 3.6 PV YP 30 Alkal Md Cor Solids (mg/l) 10629 10.80 10.80 52 6740 15 30 Cly Clyst Sh Lst 75 TuffCoal GvlSd Sst Silt 10 Depth Max Average 15 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 10430 10629 210 113 9867 479 246 152 150 BG small pack off's and stalling. Eugene Payne / Wayne Hermanson T/D Well Interval @ 10629'MD / 6399.42'TVD. Circulated BU and began backreaming out of the hole. Currently, Bit @ 10030' and circulating at 600+/- GPM. Rotating 120RPM's and losses to the hole are between 5-20 BPH. Encountering Total Charges $245,165.71 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 572 163 Drilling AK-AM-0005556280 Rod/Nick 3500 $4,873.29 (lbs/bbl) (Pm) % 04/17/2009-05:00 403' Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 60 ODSN-36 Oooguruk 10445' 104 113 243 10365 12.0 21.0 122.0 10210 12.9 3.5 PV YP 30 Alkal Md Cor Solids (mg/l) 10397 10.80 10.80 53 6740 17 30 Cly Clyst Sh Lst 75 TuffCoal GvlSd Sst Silt 10 Depth Max Average 15 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 10007 10430 243 113 9749 487 265 163 154 BG Eugene Payne / Tom Mansfield Continue to drill 8.75" section. ROP has slowed to 10-15 ft/hr. Maintaining LCM in active system @ 1 min/sack. Losses currently holding steady @ 20 bbl/hr. RSC mixing mud ahead of time for dilution and weight up. Total Charges $240,292.42 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $235,419.13 10 Security PDC 8.75 .934 Eugene Payne / Tom Mansfield Continue to drill 8.75" section. Losses have slowed from 100-200 bbls/hr to 10-40 bbls/hr. TG BG 9621 762 231962110007 243 145 C1 192 TypeC2C3 C4 Tot C5 Tot 12612 734 397 Depth Max Average 10 Gas Breakdown Gas (units)Chromatograph (ppm) 5 Coal GvlSd Sst Silt Cly Clyst Sh Lst 85 Tuff 6740 17 309621 10.80 10.80 53 0.10 10.8 4.1 PV YP 25 Alkal Md Cor Solids (mg/l) 24.0 46.7 87.0 9936 118 132 762 9621 59 ODSN-36 Oooguruk 10042' Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/16/2009-05:00 421' 696 170 Drilling AK-AM-0005556280 Rod/Nick 3500 $4,873.29 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 630 178 Circulating AK-AM-0005556280 Rod/Joey 3500 $4,873.29 (lbs/bbl) (Pm) % 04/15/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 58 ODSN-36 Oooguruk 9621' 110 415 1320 9621 0.0 0.0 0.0 0 0.10 10.8 3.5 PV YP 25 Alkal Md Cor Solids (mg/l) 9621 10.80 10.80 53 6740 17 30 Cly Clyst Sh Lst 65 TuffCoal GvlSd Sst Silt 10 Depth Max Average 25 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 9621 1320 135596 5320 1859 746 513 TG Eugene Payne / Tom Mansfield RIH to 8600'. Wash through gunk/cement pill. Reamed to 9500' and encountered severe losses. Preparing to pump gunk pill. Total Charges $230,545.84 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $225,672.55 10 Security PDC 8.75 .934 Eugene Payne / Tom Mansfield RIH. Ream last stand to bottom. Drill ahead. Lost partial returns at 9501'. Pump 70 bbl LCM pill while drilling. Drill to 9622'. Back ream to 9326'. Pump Gunk Squeeze at 9490' and POOH to 8665'. Circulate and condition at 8570'. Start to RIH. STG BG 9420 1100 105111 6133 2909 1428 1222 44294219621 735 282 C1 457 TypeC2C3 C4 Tot C5 Tot 22599 1397 751 Depth Max Average 25 Gas Breakdown Gas (units)Chromatograph (ppm) 10 Coal GvlSd Sst Silt Cly Clyst Sh Lst 65 Tuff 6740 17 349621 10.80 10.80 54 0.10 10.8 3.5 PV YP 25 Alkal Md Cor Solids (mg/l) 0.0 46.7 133.0 9570 76 311 1100 9420 57 ODSN-36 Oooguruk 9621' Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/14/2009-05:00 201' 630 178 Drilling AK-AM-0005556280 Rod/Joey 3500 $4,873.29 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 630 178 Drilling AK-AM-0005556280 Rod/Joey 3500 $4,873.29 (lbs/bbl) (Pm) % 04/13/2009-05:00 695' Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 56 ODSN-36 Oooguruk 9420 0 321 2224 9129 0.0 60.7 194.9 9330 0.10 12.8 3.5 PV YP 25 Alkal Md Cor Solids (mg/l) 9340 10.75 10.75 53 6740 16 34 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 957 TypeC2C3 C4 Tot C5 Tot 67255 4847 2274 112593509360 776 466 SG 8664 9350 2224 290 25510 1641 844 448 380 BG Eugene Payne / Tom Mansfield Continue to drill to 9420' with minimal cuttings on shaker. Circulate BU and pumped hi vis sweep with 20-30% increase seen at shakers. Pull 1 stand and pump another sweep with same results. Continue to POOH. Total Charges $220,799.26 10 Security PDC 8.75 .934 9360 9420 356 275 529 BG22921 1587 880 530 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $215,925.97 10 Security PDC 8.75 .934 Eugene Payne / Tom Mansfield Continue to drill 8.75" hole section. Running water at 30-40 bbls/hr and pumping 70 bbl hi vis sweeps every 250'. BG BG 7665 8403 281 130 10198 592 299 180 188 41084038664 582 373 C1 337 TypeC2C3 C4 Tot C5 Tot 34247 2070 897 Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 6740 17 388552 10.85 10.90 54 0.10 11.6 3.5 PV YP 26 Alkal Md Cor Solids (mg/l) 65.0 97.8 198.0 8670 305 211 582 8477 55 ODSN-36 Oooguruk 8725 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/12/2009-05:00 1027' 630 178 Drilling AK-AM-0005556280 Rod/Joey 3330 $4,873.29 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 630 180 Drilling AK-AM-0005556280 Jim/Joey 3000 $4,873.29 (lbs/bbl) (Pm) % 04/11/2009-05:00 958 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 54 ODSN-36 Oooguruk 7698 113 130 308 7228 59.0 61.0 198.5 7163 0.05 11.5 3.5 PV YP 27,000 Alkal Md Cor Solids (mg/l) 7533 10.75 10.80 48 6740 15 27 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 6740 7665 308 130 10335 677 358 222 214 BG Eugene Payne / Tom Mansfield Continue to drill 8.75" hole section. Perform 80% fluid dilution in active system. Experiences 500 psi pressure loss due to plugged off pump screen. Fix problem and continue to drill. Total Charges $211,052.68 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $204,953.23 10 Security PDC 8.75 .934 Eugene Payne / Tom Mansfield RIH to 2200 ' & circ out 90 bbls of 12.5 ppg mud. RIH to 3600' and circulate BU. RIH to 5100' and CU. RIH to 6725' and circulate BU, with a mud weight of 11.5 ppg. Re-name ODSN-36 to ODSN-36PB2 and prepare to sidetrack at 6740'. Current well name is ODSN-36. TG51971835 C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 9509 16 259509 10.90 11.10 54 0.05 12.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 0.0 0 126 1835 5197 53 ODSN-36 Oooguruk 6740 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (lbs/bbl) (Pm) % 04/10/2009-05:00 0 RIH AK-AM-0005556280 Jim/Joey $3,647.13 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air RIH AK-AM-0005556280 Jim/Joey $3,647.13 (lbs/bbl) (Pm) % 04/9/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 52 ODSN-36 Oooguruk 9509 0 40 388 2119 0.0 0.05 12.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 9509 10.90 11.95 50 9509 19 27 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 2119 388 40 TG Eugene Payne / Tom Mansfield Laying down old drill pipe and pick up new 5" DP. Make up and RIH to 2119'. Circulate out 17 ppg kill mud. Total Charges $201,306.10 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Laydown DP AK-AM-0005556280 Jim/Joey $4,873.29 (lbs/bbl) (Pm) % 04/8/2009-05:00 0 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 51 ODSN-36 Oooguruk 9509 0 0.0 0.05 13.6 3.7 PV YP 30,000 Alkal Md Cor Solids (mg/l) 9509 11.10 11.10 53 9286 15 30 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot Boyd Piercey / Colby Marks Rigged down MPD and POOH lay down BHA. RIH 20-30 Stands at a time and laydown the same. Laying down drill pipe at report time. Total Charges $198,130.57 9 Security PDC 8.75 .924 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides Lime Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 544 155 Short Trip AK-AM-0005556280 Rod/Nick 3050 $4,260.21 (lbs/bbl) (Pm) % 04/20/2009-05:00 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 63 ODSN-36 Oooguruk 10625' 217 167 1626 8909 0.0 0.0 0.0 13.6 3.5 PV YP 31 Alkal Md Cor Solids (mg/l) 10625 11.10 11.10 54 6740 21 30 Cly Clyst Sh Lst 75 TuffCoal GvlSd Sst Silt 10 Depth Max Average 15 Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 8909 1626 168590 6260 1787 603 540 TG Eugene Payne / Wayne Hermanson While backreaming out of hole, losses of 70-80 bbls/hr were encountered, before slowing to 10-18 bbls/hr Continue to RIH to 9600'. Once at 9600' a gunk squeeze will be pumped. Max gas observed was 1626 units. Total Charges $255,053.77 10 Security PDC 8.75 .934 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Total Charges $268,445.67 Daniel Sherwood / Tom Mansfield Move rig to ODNS-36, spot sub and level, level pits, R/U rig and RSC huts and lines. P/U dp and load pipe shed. Rack 4" dp in derrick . Prepare to displace diesel freeze protect w/ seawater. Currently N/U at the time of report. C1 TypeC2C3 C4 Tot C5 TotDepthMax Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 51 68.80 40 3.0 3.5 PV YP 18k 11.00 Alkal Md Cor Solids (mg/l) n/a n/a n/a n/a n/a n/a n/a n/a 64 ODSN-36 Oooguruk 10,625' md Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (Pm) % 07/19/2009-04:00 0 0 N/U Bop's AK-AM-0006519888 J. Brown / R. Klepzig 0 $3,371.17 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 0 0 P/U BHA AK-AM-000651988 J. Brown / R. Klepzig 0 $4,733.57 (Pm) % 07/20/2009-04:00 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 65 ODSN-36 Oooguruk 10,625' md n/a n/a n/a n/a n/a n/a n/a n/a 2.4 3.5 PV YP 21.5K 10.90 Alkal Md Cor Solids (mg/l) 8.75 38 10625' 51 3 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 2 7/8" landing jt. And bolds pull hanger B/O X-over and L/D. POOH w 2 7/8" kill string. L/D TBG tongs and rotary. Change out bottom Daniel Sherwood / Tom Mansfield pipe rams and install kill line. Install test plug and discover kill line is leaking. Change out kill line . Finish testing BOP's and gas alarms. Pressure test csg Sperry recorded a 4.5 bbl gain, currently P/U BHA at the time of report. Install RCD landing, MPD lines,Katch Kan and trip nipple. P/U tools, and R/U to to pulll and pump down on TBG. TWC M/U Total Charges $273,179.24 11 Hycalog RSRE613DA8 6.125 0.389 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 0 0 P/U BHA AK-AM-000651988 J. Brown / R. Klepzig 0 $4,733.57 (Pm) % 07/20/2009-04:00 Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 65 ODSN-36 Oooguruk 10,625' md n/a n/a n/a n/a n/a n/a n/a n/a 2.4 3.5 PV YP 21.5K 10.90 Alkal Md Cor Solids (mg/l) 8.75 38 10625' 51 3 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot 2 7/8" landing jt. And bolds pull hanger B/O X-over and L/D. POOH w 2 7/8" kill string. L/D TBG tongs and rotary. Change out bottom Daniel Sherwood / Tom Mansfield pipe rams and install kill line. Install test plug and discover kill line is leaking. Change out kill line . Finish testing BOP's and gas alarms. Pressure test csg Sperry recorded a 4.5 bbl gain, currently P/U BHA at the time of report. Install RCD landing, MPD lines,Katch Kan and trip nipple. P/U tools, and R/U to to pulll and pump down on TBG. TWC M/U Total Charges $273,179.24 11 Hycalog RSRE613DA8 6.125 0.389 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 0 0 RIH AK-AM-0006519888 J. Brown / R. Klepzig 0 $3,371.17 (Pm) % 07/21/2009-04:00 0' Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 66 ODSN-36 Oooguruk 10,625' md n/a n/a n/a n/a n/a n/a n/a n/a 2.3 3.5 PV YP 22k 11.20 Alkal Md Cor Solids (mg/l) 8.75 41 10625' 71 5 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 TypeC2C3 C4 Tot C5 Tot Max gas detected was 30ppm. Continue to POOH and Correct dowload issue, Begin RIH, filling dp every thirty stnds. Sperry observed Daniel Sherwood / Tom Mansfield correct displacement RIH. Currently RIH with a bit depth of 8365' the time of report. RIH to 4800' and discover MWD tool was incorrectly downloaded. While circ @ 4800' md Sperry detected H2S @ 1321 stks. Total Charges $275,226.39 11 Hycalog RSRE613DA8 6.125 0.389 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 219 62 Drilling Ahead AK-AM-0006591888 J. Brown / R. Klepzig 1460 $4,733.57 (Pm) % 07/21/2009-04:00 354' Siltst Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 66 ODSN-36 Oooguruk 10,979' 406.0 272.0 841.0 10800.0 103.9 78.8 214.0 10885.0 1.9 3.5 PV YP 21k 10.30 Alkal Md Cor Solids (mg/l) 8.70 8.80 39 10625'354 51 3 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 221 TypeC2C3 C4 Tot C5 Tot 62950 3107 1440 6361071210720 618 615 POG/FG 10685 10690 564 417 60131 3055 1215 450 156 POG/FG 10868 10882 498 416 52387 2285 884 363 147 FG remaing float equipment and cmnt and 20' new formation to 10,645'. Reciprocate pipe and POOH to 10, 590. FIT to 13 ppg @ 1350 spp 6.-20 Sperry recorded 13 ppm H2S gas @ 10,625' bit depth. Daniel Sherwood / Tom Mansfield Sperry recorded. RIH to btm and drill ahead to KD of 10785' and change HPU hose fittings for MPD. Continue to drill ahead to 10,833 and c/o RCD bearing. Finish repair and drill ahead POG from bearing change was recorded at 413U @ 3045 stks. Drilling breaks occ from (10,735-10,740) (10,795-10,815 associated with a GP of 841U). No losses or gains to the hole were recorded, currently drilling ahead with a bit depth of 10,979. Continue to RIH observing correct displacement. Begin rotating and washing down @ 10,382' md to 10,370' Continue to RIH to 10,400 rotate and kt to max 14k w. circ at 205 gpm. Continue to RIH to 10,528' tag float collar and d/o Total Charges $279,960.96 11 40-100Hycalog RSRE613DA8 6.125 0.389 6.17 10798 10816 841 722 233 GP 70423 3454 1466 608 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 451 WTG170847 8411 3640 13531126902:25-02:35 1754 860 Total Charges $284,694.53 11 40-100Hycalog RSRE613DA8 6.125 0.389 19.12 6.-20 Daniel Sherwood / Tom Mansfield increased ROP to 11,269 avg of 69 ft/hr. B/U sample revealed f -v f gr, rd-sb rd w srtd pred qtz, lt br -tn cl, trsl sd. Circ and reciprocate and begin wiper trip to shoe. 24 bbl gain in #5 due to water left on in centerfuge. Obs 4.68 bbls disp 5 stds TOH, 7.72 bbls 5 stnds TIH. Tag btm and cont drilling WTG of 1754 U was recorded @ 1754 stks, continue to drill ahead to a current bit depth of 11,395' w avg ROP of 85.5' hr Drill from 10,979' to 11,037' p/u off btm rack one stnd in derrick and take survey due to last survey dev. Decesion is made to ream cont to ream to 11,037' md drill to 11,080' w avg ROP of 68.9 f/hr and tag poss siderite stgr. Cont to drill to 11,208 w avg ROP of 25.8' f/hr. Then drill from 11,210-11,225' @ 36.2 f/hr a slight inc in gas was recorded. Cont to drill to 11,255 and FG POG 11320 11336 350 372 38400 1730 683 269 106 FG 11091 11093 365 174 14744 820 389 208 103 2071125411269 285 254 C1 94 TypeC2C3 C4 Tot C5 Tot 26879 1235 490 Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) Coal GvlSd Sst Silt Cly Clyst Sh Lst Tuff 10625'770 51 511,269' 8.75 8.85 39 0.10 2.4 3.5 PV YP 20k 9.50 Alkal Md Cor Solids (mg/l) 115.7 59.9 160.6 11374.0 188.3 131.0 1754.0 3162 stks 68 ODSN-36 Oooguruk 11,395' Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg Siltst (Pm) % 07/23/2009-04:00 416' 222 63 Drilling Ahead AK-AM-0006591888 J. Brown / R. Klepzig 1700 $4,733.57 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) SPP (psi) Gas (units) Gallons/stroke Mud Data:Density (ppg) Viscosity HTHP Chlorides PH Depth in out (sec/qt) (cc/30 min) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 194 55 Drilling Ahead AK-AM-0006591888 J. Brown / R. Klepzig 1483 $4,733.57 (Pm) % 07/24/2009-04:00 638.46' 6751198011999 716 540 114680 6394 2976 74738 3561 1616 11900 11930 1191 1052 881 91428 4802 2165 11695 11718 780 11843 11849 915 11730 11750 857 Siltst 713 79793 4016 1737 88369 1884 779 592 Size Pioneer Natural Res. North Slope Flow in (gpm) cP (lb/100ft2) Flow Rate (spm) Daily Charges Nabors 19AC Avg 69 ODSN-36 Oooguruk 12033.46' 157.0 483.0 1190.0 11909.0 17.6 26.3 234.2 11666.0 0.10 2.1 3.5 PV YP 17k 10.20 Alkal Md Cor Solids (mg/l) 11,269' 8.70 8.80 37 10625'1408.46 51 3 Cly Clyst Sh Lst TuffCoal GvlSd Sst Silt Depth Max Average Gas Breakdown Gas (units)Chromatograph (ppm) C1 188 TypeC2C3 C4 Tot C5 Tot 72199 2999 1139 4651151411520 654 619 GP 11459 11462 317 301 34722 1501 594 246 97 CG 11589 11652 829 699 86918 4203 1738 686 256 FG 274 GP/FG GP FG/GP 353 1294 265 GP 454 926 279779 708 CG @ 11,462 lag depth of 339U over bg of 214U. Cont to drill ahead to 11,570' w reduction in WOB of 6K and ROP of 48 ft/hr. Drill ahead to 6.-20 No losses or gains were recorded to the formation. Daniel Sherwood / Tom Mansfield 11,663 w ROP 114 ft/hr then drilling break to 11,669 avg 180 ft/hr w no corresponding gas peak. Cont to dril to 11,775' w avg ROP of 123.9 ft/hr. Drill from 11,775 to 11,785 w avg ROP 50.2 ft/ hr and reduced WOB of 5k. Drill ahead to 11,890 w avg ROP of 126.3 f/hr Then from 11,890 to 11,949' tag siderite strg encountering a conn @ 11,848 lag depth of 915U over bg of 750. Begin time drilling to 11,972' then drill to 12,000' w rop of 91.8' hr with an correlating gas peak of 716 U .Then continue to drill to a current depth of 12,033.46' Monitor three lube jobs pumped while drilling from 11,395' to 11,442 w/ avg ROP of 109.8 ft/hr. Then from 11,440 to 11,460 w avg ROP of 52 ft/ hr w 10k reduction in WOB. Cont to drill to 11,568' w avg ROP of 113 ft/hr one conn gas recorded Total Charges $289,428.10 11 40-100Hycalog RSRE613DA8 6.125 0.389 40.1 11562 11570 498 444 159 GP55242 2407 946 387 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Recycled Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air R.O.P. (ft/hr) Gas (units) Flow In (gpm) 485 567 1824 12593' 45.0 12147' Drilling 6.125" Hole 2.1 $298,366.52 mg/l 2204 3.517 Total Charges: 4.9 62-122 4784 2164 796 FBG Gas Breakdown 9393 88322 4623 2057 SPP (psi) Gallons/stroke Flow In (spm) 215 61 13312' 2687' 1824 1549 162568 1090 849 12070' 12595' 12430'12500' 12570' 12285' 12135' 12330' 794 13010'13100' 990 782 12965'13005' 903 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 13312' 70 7/25/2009-04:00 North Slope 1279' HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 79.3 201.6 Size RSRE613D 6.125" 0.389 Sd -9 Cht 8.70 8.90 39 56.22 Lst TuffSst Silt Siltst GvlCoalShClyst Gas (units)Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 875 598 731 86802 4393 1984 94151 4963 2244 FBG883 331 1018 402 FBG911 450 Continued drilling 6 1/8" production hole from 12033' to 13312' MD (6347' TVD) as of 04:00 cut-off time. ROP varied Danny Kane/Tom Mansfield been a function of ROP coupled with the PWD EMW on bottom; MPD is currently holding 20-25psi (minimum) backpressure on the well as the drilling ECDs are sufficient enough to keep above a 9.70ppg at the casing shoe and the PWD EMW is clearly a function the higher ECDs to date. Drilling ROP has been reduced by ~40% since 13175' MD when a 300psi increase in the standpipe pressure was observed; subsequent attempts to return the standpipe pressure to previous background levels have all failed. of cuttings load during higher ROP events. No connection gasses have been observed and no losses have been observed with 13104' 1100 15 3-2010625' Type 388 C4 Tot may have been burying the bit face in the formation. After new drilling parameters per bit rep were applied, ROP was limited throughout and few sideritic concretions were observed within the drilled interval. ROP increased drastically once WOB was FBG lowered after Hycalog bit representative suggested the earlier WOB stacking w/ low ROP (and fluctuating standpipe pressure) Cor Solids (lb/100ft2 16k % YP ml/30min API Filt pH Chlorides 9.10 101894 6035 FBG 2865 1207 primarily by the increasing on-bottom torque across the interval. Lube pills circulated throughout the system have decreased the drilling torque in the short term, but the long term trends shows the torque inevitably rises. Drilled formation gas has primarily J. Polya/R. Klepzig 447 1140 FBG 111119 5895 2591 1026 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Recycled Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air were added to the Active Mud System with results seen at ~14150' MD whereas the drilling torque dropped to a 13kftlb average with ROP increasing to 160fph+. Encountered a siderite stringer at 14308' MD and are currently time-drilling stringer at 1-3fph. The J. Polya/R. Klepzig 446 820 FBG 80897 4369 1976 932 4034 FBG 1914 941 Cor Solids (lb/100ft2 21k % YP ml/30min API Filt pH Chlorides 10.60 Type 436 C4 Tot MD before the drilling torque maxed out at 20kftlbs at 13995' MD whereas ROP was limited by the high torque. Four lube mixes until the plugged jet on the bit from the day before became unplugged (350psi drop in Standpipe Pressure at 14030' MD immed. FBG after a GeoPilot downlink). ROP was then limited by the greatly increased drilling torque that started rising substantially at 13780' 14070' 1100 12 3-2210625' 697 30536 2011 Danny Kane/Tom Mansfield drilled formation gas has been a function of ROP and the drilling ECDs on bottom. One connection-ream gas was observed at 14069' MD and there have been no losses observed to the hole. The wellbore washout appears to have increased significantly our current annular correction is 130bbls [through 14315' MD, 130bbls = 8.59" avg OD over Open-Hole Section]. Current SPP, ECD, & torque fluctuations suggest that cuttings beds may be forming on the low side with our time-drilling low rotary and flow. within the past 30 hours observed both through a greater than normal cuttings load and through our increasing annular correction; Continued drilling 6 1/8" hole to 14315' MD/6376' TVD. Initially the drilling ROP was highly erratic and inconsistent CRG374 FBG926 427 1412 697 FBG1688 599 526 FBG 785 683 697 75434 4141 1926 102784 6255 3066 C5 TotDepthMaximum Average C1 C2 C3 Gas (units)Chromatograph (ppm) TuffSst Silt Siltst GvlCoalShClystSd -5 Cht 8.70 8.85 39 74.58 Avg 61.3 257.7 Size RSRE613D 6.125" 0.389 HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV 14315' 71 7/26/2009-04:00 North Slope 1003' Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 1294 13905'13970' 1020 795 13811'13870' 1734 14069'14069' 354 [BG] 274 13356' 13775' 13640'13680' 13725' 13535' 13390' 13580' 1141 919 107100 748 593 70481 14315' 3690' Lst Gallons/stroke Flow In (spm) 193 55 14170'14260' 2096 1656 1167 5820 161544 8684 3865 188115 10853 5553 2470 62-138 2634 1237 557 FBG Gas Breakdown Time Drilling Stringer 1.9 $303,100.09 mg/l 1673 3.517 Total Charges: 4.2 SPP (psi) R.O.P. (ft/hr) Gas (units) Flow In (gpm) 230 828 2096 14239' 1.0 14057' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to fr to to to to to to 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, RG - Recycled Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air continues this trend, torque is expected to reach 20kftlbs by 15580' MD. Standpipe pressure is also trending upwards steadily with increased measured depth and there was another standpipe incident observed within the drilled interval--at 14334' MD, the J. Polya/R. Klepzig 311 616 CG 53334 3478 1946 1012 2615 FBG 1334 683 Cor Solids (lb/100ft2 15k % YP ml/30min API Filt pH Chlorides 11.50 Type 445 C4 Tot averaging 7-8kftlbs and the torque while normal drilling appears to be steadily increasing with increasing depth; if the torque ROP of 2.5fph). Drilling thereafter continued averaging 50-65fph until another siderite stringer was encountered at 14767' MD. FBG Currently drilling stringer at 14775' MD / 6388' TVD averaging 1.6fph. Drilling torque while time-drilling has been a non-issue 14753' 1100 12 3-2210625' 1143 84629 4888 Danny Kane/Tom Mansfield SPP increased 250psi immediately after a GeoPilot downlink and then decreased 270psi at 14772' MD (5 minutes after GeoPilot downlink and also on a time-drilling transition). Drilled formation gas has been a product of ROP and ECDs where they were 9.76ppg) connection at 14358' MD; no other connection gasses observed. Our annular correction continues to increase and now is 170bbls for the open-hole section [equates to an average open-hole diameter of 8.93" distributed over the 4150' MD open hole.] high enough to hinder gas breakout. There was an early connection gas and a connection gas associated with a low-EMW (avg Continued drilling siderite stringer first encountered at 14308' MD and finally breached stringer at 14330' MD (average FBG487 ECG908 395 1022 591 FBG1362 454 329 FBG 678 (BG) 319 430 66664 3488 1808 61786 3918 2076 C5 TotDepthMaximum Average C1 C2 C3 Gas (units)Chromatograph (ppm) TuffSst Silt Siltst GvlCoalShClystSd -5 Cht 8.75 8.90 37 95.5 Avg 22.0 158.2 Size RSRE613D 6.125" 0.389 HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV 14775' 72 7/27/2009-04:00 North Slope 460' Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 866 14566'14587' 659 550 14481'14550' 1050 14690'14740' 927 749 14336' 14388' 14358'12751' 14384' 14358' 14357' 14358' 1744 1462 164251 473 (BG) 383 46356 14775' 4150' Lst Gallons/stroke Flow In (spm) 180 51 14745'14767' 627 493 2418 8859 10507 5709 2765 65035 2879 1244 654 62-138 4171 1677 559 FBG Gas Breakdown Time Drilling Stringer 2.7 $307,833.66 mg/l 1534 3.517 Total Charges: 4.4 SPP (psi) R.O.P. (ft/hr) Gas (units) Flow In (gpm) 139 663 1744 14388' 1.3 14379' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to fr to to to to to 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, RG - Recycled Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air R.O.P. (ft/hr) Gas (units) Flow In (gpm) 92 637 1402 14974' 1.4 14961' Time Drilling Stringer 2.1 $312,567.23 mg/l 1590 3.517 Total Charges: 4.8 SPP (psi) 62-138 1248 589 263 CG Gas Breakdown 2683 127734 7898 4000 Gallons/stroke Flow In (spm) 182 52 15032' 4407' Lst 481 (BG) 435 14558 607 467 59006 14773' 14950' 14845'14877' 14950' 14799' 14795' 14840' 1103 14955'15012' 1402 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 15032' 73 7/28/2009-04:00 North Slope 257' HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 12.6 155.6 Size RSRE613D 6.125" 0.389 Sd -6 Cht 8.70 8.85 37 115.83 TuffSst Silt Siltst GvlCoalShClyst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 455 376 136 47136 2699 1276 FBG583 237 673 FBG1770 Continued drilling siderite stringer first encountered at 14767' MD at an average ROP of 2.14fph before breaching at Danny Kane/Tom Mansfield time drilling with no problems. Drilled formation gas has been primarily ROP related with occasional high ECDs hindering gas breakout. A small connection gas (46units over BG) was observed during the 14950' MD while removing the pup joint with min after the time-drilling that occurred from 14767' to 14797' MD, suggesting possible development of cuttings beds with the lower RPM & flow rate; previous drilling intervals (including all time-drilling) have shown wash-out and annulus correction increases. 9.59 & avg 9.84ppg pumps off EMWs. No losses have been observed. Of interest is that the annulus correction decreased 15025' 1100 13 3-2510625' Type 122 C4 Tot MD the installation of a pup joint to drill further (to space the tooljoint out of the RCD element) was required. After installing, ROP 14797' MD. Continued drilling ahead at 40-60fph while encountering slight WOB stacking and increasing torque from BHA interactions with the siderite stringer. WOB stacking and torque (to 17-18kftlbs) significantly increased thereafter and at 14879' Cor Solids (lb/100ft2 17k % YP ml/30min API Filt pH Chlorides 8.70 3498 FBG 1766 836 stepped up from 70fph to 105-120fph with WOB 10-15klbs and torque dropping back to 13kftlbs average. Continued drilling at 130fph ROP until a hard spot was first encountered at 15012' MD with time drilling starting at 15024' MD. At report cut-off time, still J. Polya/R. Klepzig 331 228 FBG 22558 1192 543 251 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: Current 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) fr to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air stringer ledge while backreaming and restarted timed drilling. Drilled torque steadily increased throughout the section with lube pills intermittently abating the torque; fine solids have increased within the mud and increasing the drilling torque with the rig J. Polya/R. Klepzig 750 244 FBG 24127 1156 498 292 6779 CG 3678 1804 Cor Solids (lb/100ft2 17k % YP ml/30min API Filt pH Chlorides 8.60 Type 169 C4 Tot MD; WOB stacking (stabs hanging up) w/ torque increasing to 19kftlbs+ necessitated backreaming at 15872' MD. Lost drilled 15038' MD. After leaving stringer, geology decision made to drill parallel to hard streak where ROP increased to an average of FBG 100-150fph before turning up at 15435' MD and finally intercepting a siderite stringer at 15866' MD. Initiated time-drilling at 15868' 15870' 1100 11 3-3210625' 2081 60469 3833 2034 1197 124002 7619 Danny Kane/Tom Mansfield centrifuge out of order for the past 40 hours (RSC centrifuging batches of mud throughout). Drilled formation gas has been ROP & ECD dependent with the background gas increasing ~40% while time drilling with the lower ECD (10.00ppg vs 10.14ppg). One currently 200bbls for an average hole diameter of 8.81" over the 5253' MD open-hole section. The cuttings load after the last high ROP section was ~0.39ppg and all signs indicate no problems with the wellbore integrity and it appears to be cleaning well. connection gas was observed and no losses/gains observed. Our annulus correction factor has started rising again and is Continue drilling siderite stringer first encountered at 15024' MD at an average ROP of 1.56fph before breaching at FBG908 FBG1224 476 1844 849 FBG1995 798 844 FBG 647 RG 1101 850 (BG) 131 107270 6118 2846 114687 6975 3621 C5 TotDepthMaximum Average C1 C2 C3 Gas (units)Chromatograph (ppm) TuffSst Silt Siltst GvlCoalShClystSd -6 Cht 8.80 8.90 36 135.02 Avg 44.1 200.4 Size RSRE613D 6.125" 0.389 HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV 15878' 74 7/29/2009-04:00 North Slope 846' Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 1128 15543'15610' 1301 1165 15425'15460' 1472 15666'15708' 1392 1273 15871'15871' 691 (BG) 391 15034' 15378' 15135'15215' 15330' 15040' 15034' 15070' 1563 1236 144172 1201 941 101038 15878' 5253' Lst Gallons/stroke Flow In (spm) 183 52 15810'15865' 1181 1098 4017 8430 132090 7881 4018 102575 6481 3405 1826 62-138 4369 2147 864 FBG Gas Breakdown Time Drilling Stringer 3.1 $317,300.80 mg/l 1564 3.517 Total Charges: 4.4 SPP (psi) R.O.P. (ft/hr) Gas (units) Flow In (gpm) 233 968 1563 15372' 1.2 15712' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to fr fr to to 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, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 5 212 640 15879' 0.0 15879' Trip Out 1.1 $322,034.37 mg/l 3.517 Total Charges: 4.3 SPP (psi) 62-138 530 275 107 BG Gas Breakdown 45776 1869 851 456 514 1044 59839 2287 923 15879'13750' 405 285 Gallons/stroke Flow In (spm)0 15879' 5254' Lst 221 21977 15872' 9.57ppg Bit Depth Origin 15850' 15877' 15879'15800' 396 318 15879'9.35ppg 203 430 15850'15700' 640 460 15850'13575' 536 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 15879' 75 7/30/2009-04:00 North Slope 1' HTHP (ml/30 min) Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 0.4 0.4 Size RSRE613D 6.125" 0.389 Sd -5 Cht 8.55 8.55 36 139.14 TuffSst Silt Siltst GvlCoalShClyst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 309 69080 3110 1313 176 EPOG 196 POG BG131 577 164 EPOG428 222 Attempted to continue side-drilling siderite stringer at 15879' MD; extremely low ROPs observed with WOB stacking Danny Kane/Tom Mansfield The 9.64ppg EMW event produced little gas, but the 9.57ppg EMW event produced two gas peaks; one at ~13600' MD (TVD high point at revert) and one at bottom's up which suggest the pore pressure is closer to 9.57ppg EMW. Before tripping out, the rig lost ~13600' MD & bottom's up. In the 5 minutes before the MPD backpressure pump was back up, the WHP had increased through a minor volumetric (<1bbl) formation influx. Trip out has met multiple tight spots and currently displacing -- slight losses observed. highline power while time drilling with 240psi WHP, resulting in another Pumps Off EMW of ~9.35ppg and two gas peaks at 294 43534 1929 913 480 19577 979 15879' 1100 12 3-3210625' Type 361 C4 Tot was benign although the lower drilling ECDs (10.0ppg) increased the background levels 40-50%. There were multiple pumps off and slowly rising drilling torque observed. Pipe buckling was unlikely and the drilling team decided to initiate a bit trip under the POG suspicions of an undergauged bit causing BHA stabilizers to hang up on the potentially undergauge hole. Drilled formation gas Cor Solids (lb/100ft2 16k % YP ml/30min API Filt pH Chlorides 10.50 FBG gas peaks. First, while installing a pup joint in the drillstring at 15879' MD, the pumps were turned off twice with Pumps Off EMWs of 9.64ppg & 9.57ppg respectively. No volumetric influxes observed, but background gas increased with open-hole lag to surface. J. Polya/V. Parsell 349 32339 1644 834 567 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 0 22 338 10450' N/A N/A Testing BOPE 4.0 $326,767.94 mg/l 28 3.517 Total Charges: - SPP (psi) 2-6-BT-N-X-I-WT-PR Gas Breakdown Gallons/stroke Flow In (spm) 0 0 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 15879' 76 7/31/2009-04:00 North Slope 0' Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 HTHP (ml/30 min) Sd - 10625' 15879' - Cht 10.10 10.10 27 0 TuffSst Silt Siltst GvlCoalShClyst Lst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 Finished displacing the 8.55ppg WBM with 10.1ppg brine within the casing shoe at ~10450' MD. Circulated out the Danny Kane/Tom Mansfield showed a 1-1.5bbl/hr seep for the duration of the trip. Once on surface, the seep has abated with pit volumes holding steady. 62-138 15879' 139.14 5254' - 3-32 15879' 15879' 0' TypeC4 Tot in, laying down joints with worn hard-banding as needed. Removed MWD nuke sources, downloaded tools, and broke down WBM/brine interface and ceased circulation once a steady 10.1ppg brine was measured coming out of the annulus. After flow checking well, proceeded to remove MPD RCD head and install trip nipple. Continue tripping out to surface racking back stands Cor Solids (lb/100ft2 158k % YP ml/30min API Filt pH Chlorides 8.50 BHA #12. Performed top drive maintenance, leveled rig, and currently testing BOPE. Max gas while tripping was 338 units with the background gas quickly dropping off to minimum levels once the 10.1ppg brine was circulated around. Losses while tripping J. Polya/V. Parsell 1200 1100 Security FMF3641Z Hycalog RSRE613D Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1200 1100 Security FMF3641Z Hycalog RSRE613D until ~8600' MD (within 7" Casing) where the displacement started coming up 1-2bbls short of calculated off the trip tank (closed pipe displacement). PVT monitoring showed the real loss to be ~1bbl/5 stands with the remainder attributed to a leaking float. J. Polya/V. Parsell Cor Solids (lb/100ft2 160k % YP ml/30min API Filt pH Chlorides 8.50 TypeC4 Tot was static with no losses or gains observed during the BOPE test & building BHA #13. The trip in showed proper displacement single in 78 joints. Fill pipe & shallow pulse test MWD tools. Run in stands racked back and fill pipe/pulse test every 25 stands run in. Once at 10509' MD, fill pipe/pulse test, perform slip & cut, and are now currently installing MPD RCD element. The hole 62-138 15879' 139.14 5254' - 3-32 15879' 15879' 0' Danny Kane/Tom Mansfield Finish BOPE test & make-up BHA #13. Load MWD tools & load nuclear sources. Continue building BHA #13 and C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 27 0 TuffSst Silt Siltst GvlCoalShClyst HTHP (ml/30 min) Sd - 10625' 15879' - Cht 10.15 10.15 cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 15879' 77 8/1/2009-04:00 North Slope 0' Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 Gallons/stroke Flow In (spm) 0 0 2-6-BT-N-X-I-WT-PR Gas Breakdown Installing RCD Element 3.8 $331,501.51 mg/l 28 3.517 Total Charges: - SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 0 1 5 N/A N/A N/A Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 0 26 446 N/A N/A N/A Repair Top Drive 3.8 $336,235.08 mg/l 29 3.517 Total Charges: - SPP (psi) Rerun Bit for BHA #13 Gas Breakdown Gallons/stroke Flow In (spm) 0 0 11420'11420' Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 15879' 78 8/2/2009-04:00 North Slope 0' Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 HTHP (ml/30 min) Sd - 15879' 15879' - Cht 10.15 10.15 27 0 TuffSst Silt Siltst GvlCoalShClyst Lst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 Tripped in to the sump at 11050' MD & displaced the 10.15ppg brine in the annulus with 8.65ppg WBM. Observed Danny Kane/Tom Mansfield wellhead pressure when real-time PWD data was interrupted by numerous downlink attempts to revive GeoPilot (used recorded PWD data to confirm influx and there were no known pit additions within the 25min influx interval). Background gas doubled when with 10.15ppg brine at 10500' MD. Tripped to surface with steady 3bbl/hr losses observed from stands 40 to the BHA (12bbls less than expected displacement). Current losses at 0.5bbls/hr while troubleshooting top drive that broke while making up BHA #13. lag from 11050' to 10620' MD surfaced--possibly drilling fluid lost reentered wellbore. Spotted spacer at the sump and displaced 15879' 00 ' - 15879' 15879' 0' Type 181 C4 Tot GeoPilot at 11445' MD (at same time jars fired while pulling up 251klbs). Attempts to revive the GeoPilot failed with a max reaming gas during the displacement averaged 54 units with a peak of 163 units. Tripped on elevators until a tight spot was encountered at 11420' MD. First attempted to work pipe, then reamed, and finally started washing & reaming. Lost communication with the Cor Solids (lb/100ft2 160k % YP ml/30min API Filt pH Chlorides 8.50 RG gas of 446 units. Before tripping to the sump to start displacement (~09:03), there was a three barrel influx observed in the Active Pits when the drilling ECD dropped to a 9.62ppg average over a 25 minute interval (w/ 9.52ppg minimum); MPD was raising the J. Polya/V. Parsell 446 50196 1791 787 416 1300 1200 Security FMF3641Z Security FMF3641Z Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) at at at at at at to to to 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, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1300 1200 Security FMF3641Z Security FMF3641Z during the displacement was 720 units over an average 250 units that originated between the sump and the 7" casing shoe. The observed In/Out volume was 481stks over the calculated volume and with the surface volume correction applied, the hole has ~18 J. Polya/V. Parsell 229 TBG 5585 190 62 30 3659 BG 1582 693 Cor Solids (lb/100ft2 160k % YP ml/30min API Filt pH Chlorides 8.50 Type 0 C4 Tot at 11040' MD, installed the RCD element, and displaced the 10.15ppg brine in the hole with 8.75ppg WBM. Max gas observed resumed building BHA #13 and continued tripping to bottom, stopping to fill pipe & shallow-pulse test MWD tools every 25 stands while observing net losses of 4bbls in the trip to the 7" casing shoe. Once at the casing shoe, continued tripping in to the sump 15879' 00' - 15879' 15879' 0' Danny Kane/Tom Mansfield bbl washout equating to an average 8.98" hole diameter from the sump to the casing shoe. Continued tripping and had to start washing/reaming stands because of increasing drag at 11600' MD (just beyond the sump). Trip gas increased with previously The hole appears to be taking the proper fill with no losses and current cuttings load while tripping are 3-6bbls/hr. Currently working pipe and circulating at full-rate through a tight spot at 14320' MD with elevated erratic torque and packing off occurring. uncirculated open-hole lag to surface (beyond the sump) and has averaged 400-800 units with no major fluctuations observed. Finish troubleshooting and repairing top drive while observing steady losses of 0.5bbls/hr. Upon completion, TGP301 117 290 TGP838 720 (TBG) 212 51 80357 2723 878 C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 27 0 TuffSst Silt Siltst GvlCoalShClyst HTHP (ml/30 min) Sd - 15879' 15879' - Cht 10.15 10.15 cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 15879' 79 8/3/2009-04:00 North Slope 0' Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 (TBG) 59112350'02:15 808 5000' 01:15 11750'00:03 12000' 11040' 20:25 20:57 701 (TBG) 361 72151 843 (TBG) 401 89676 Gallons/stroke Flow In (spm) 220 63 3570 83199 3791 1822 Rerun Bit for BHA #13 1798 851 295 TGP Gas Breakdown Trip In / Work Tight Spot 3.8 $340,968.65 mg/l 1724 3.517 Total Charges: - SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 763 26 843 11750' (Trip) N/A N/A Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) at at at to to to to to to 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, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 213 412 1060 16063' 1.0 16070' Drill 6.125" Production 3.8 $345,702.22 mg/l 1906 3.517 Total Charges: - SPP (psi) 47-102 Rerun Bit for BHA #13 Gas Breakdown 16826 737 478 336 2293 22769 1658 1045 16111'16117' 190 130 Gallons/stroke Flow In (spm) 235 67 967 89145 14300' 15875'09:27 15000' 05:40 08:03 16020'16065' 1060 576 206 15940'16010' 607 456 15880'15915' 279 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 16196' MD/6345' TVD 80 8/4/2009-04:00 North Slope 317' Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 6.125 0.389 22.4 168.4 Size 6.125 0.389 HTHP (ml/30 min) Sd - 15879' 15879' - Cht 10.15 10.15 27 14.13 TuffSst Silt Siltst GvlCoalShClyst Lst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 917 (BG) 467 (BG) 670 83292 4499 2507 57366 2960 1458 181 FBG FBG404 TGP1336 526 747 280 FBG640 314 Reamed and circulated to clean-out tight spot at 14320' MD; a noticeably higher cuttings load was unloaded at Danny Kane/Tom Mansfield had established its cutting pattern, contol-drilling of the siderite stringer at 15879' MD resumed. Continued drilling ahead with variable ROP of 20-100fph until encountering a siderite stringer at 16107' MD. Time-drilled the stringer at an average ROP of 1.35 16195' MD (currently working pipe to mitigate). Drilled gas is correlating with the ROP and no connection gasses have been observed. The hole appears to be in good condition with MPD holding a 9.95-10.00ppg EMW with no losses/gains observed. fph until breaching the stringer at 16118' MD. Drilling resumed with fairly steady ROPs of 50-120fph until the WOB stacked up at 1052 100552 5001 15879' 00 ' - 4-1915879' 16196' 317' Type 466 C4 Tot and 15000'-15500' MD had increased cuttings loads proving that cuttings had fell out and collected in these downhole sumps in bottom's up strokes from the tight spot suggesting the packing-off was cuttings-bed related. Max trip gas of 1090 units was FBG observed with the aforementioned cuttings load and the average trip gas was 650 units. Both downhole sumps at 14650' MD Cor Solids (lb/100ft2 160k % YP ml/30min API Filt pH Chlorides 8.50 4588 TGP 2387 1241 the last trip out. Once 1x bottom's up had been circulated at 15875' MD, background gas fell back to an average 120 units and MPD had to increase the WHP 100psi after 2x bottom's up to maintain a 9.98ppg EMW (0.30ppg trip-in cuttings load) . Once the bit J. Polya/V. Parsell 520 1090 TGB 104268 5535 2788 1292 1300 1200 Security FMF3641Z Security FMF3641Z Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1300 1200 Security FMF3641Z Security FMF3641Z klbs and flow 235-240gpm. There was a large spike in mud out density as a ~0.35ppg cuttings load (over background) unloaded at surface (shakers confirmed load) at 20:40. The cuttings load was created by a rotary drop fr 100 to 80rpm with the cuttings J. Polya/V. Parsell 502 1351 FBG 124089 6790 3345 1673 5270 FBG 2475 1207 Cor Solids (lb/100ft2 31k % YP ml/30min API Filt pH Chlorides 9.50 Type 696 C4 Tot (time-drilling start at 16772' MD). Drilling torque before the stringer had initially climbed before settling at 16kftlbs with WOB 5-10 were caused by cuttings beds development with lower rotary & flow rates. After backreaming to clean the hole (cuttings observed FBG at surf.), the stringer was breached and drilling continued averaging 70fph before encountering another hard spot at 16765' MD 16775' 00 ' 13 4-1915879' 16783' 904' 1875 120970 6385 Danny Kane/Tom Mansfield originating fr ~13650' to 16000' MD (from revert point (latter half) into the following sump); the wellbore placement was confirmed with the ECD rise coming at the correct stroke count for the 13650' MD lag to enter the vertical wellbore section. Drilled formation but our annulus correction has increased to 285bbls (Surf. Vol. Corr. = 45bbls, Open Hole Washout = 240bbls (8.81" Avg OD)) and will be pending a possible increase when normal-ROP drilling resumes (time-drilling lag had greater than normal cuttings load). gas has remained consistent and ROP-dependent throughout the interval with no abnormalties to report. No losses to the hole, Drilled stringer fr 16196' to 16198' MD at an average ROP of 0.75fph; high torque & stacking WOB while time-drilling FBG543 FBG1249 482 1413 644 FBG1477 563 1201 598 1085 113623 5854 2698 118292 6422 2999 C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 38 33.9 TuffSst Silt Siltst GvlCoalShClyst HTHP (ml/30 min) Sd - 15879' 15879' 7 Cht 8.75 8.85 cP PV Avg 6.125 0.389 29.7 122.5 Size 6.125 0.389 16783' MD/6324' TVD 81 8/5/2009-04:00 North Slope 587' Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $5,571.91 AK-AM-0006591888 1085 16600'16685' 1271 923 16500'16580' 1311 16690'16748' 1281 992 16220' 16485' 16376'16380' 16400' 16305' 16275' 16375' 967 719 89380 1010 658 100864 Gallons/stroke Flow In (spm) 198 56 2842 4880 118016 6456 2990 47-120 Rerun Bit for BHA #13 2369 1233 548 FBG Gas Breakdown Time Drilling 1.6 $351,274.19 mg/l 1543 3.517 Total Charges: 4.8 SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 190 842 1362 16196' 2.3 16204' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1300 1200 Security FMF3641Z Security FMF3641Z continue to time drill to current depth of 17,100 md. No losses to the hole have been recorded. No connection gasses were detected as well. Current annulus correction is 279 bbsl open hole and approx 45 bbls surface correction. J. Brown/V. Parsell 481 1181 FBG/GP 111571 5715 2701 1342 5376 FBG 2454 1212 Cor Solids (lb/100ft2 26k % YP ml/30min API Filt pH Chlorides 9.50 Type 550 C4 Tot 17,018 md then drill to 17, 094 with and avg ROP of 76.4 ft/hr. Tag additional stringer at 17,094' md and resume time drilling drilling to 17,007' md tagging another siderite stringer. Drilling breaks occurred from 16887' to 16,904' w an avg Rop of 76.7 ft/hr with no associated gas peak. Avg ROP for section drilled before tagging siderite stringer was 25.92' hr time drill through stringer to 17096' 00 ' 16 4-1915879' 17100' 1221' Daniel Sherwood / Tom Mansfield Continue to time drill to 16,792' md with an avg rop of 2.57 ft/hr.Then break out if siderite sringer and continue normal FBG570 279 325 262 1046 28665 1611 902 C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 38 56.28 TuffSst Silt Siltst GvlCoalShClyst HTHP (ml/30 min) Sd - 15879' 15879' 8 Cht 8.75 8.75 cP PV Avg 6.125 0.389 16.2 102.4 Size 6.125 0.389 17100' MD/6330' TVD 82 8/6/2009-04:00 North Slope 387' Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 16804' 17094' 17043'17073' 17074' 17018' 16834' 17040' 1121 796 109140 1171 1005 116429 Gallons/stroke Flow In (spm) 197 56 5045 47-120 Rerun Bit for BHA #13 2325 1140 458 FBG Gas Breakdown Time Drilling 2.2 $356,007.76 mg/l 1561 3.517 Total Charges: 4.8 SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 174 754 1181 16824' 1.5 17077' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air pipe. Begin to ream and pump out of hole packing off at 17,121' md with max spp of 2314 lbs recorded. Continue to ream and drill to a final TD of 17,525' md 6380 tvd. Sperry observed a 22 bbl calculated loss from 6 AM to final TD. Once connection gas drill to 17,411' md 6365' tvd w avg rop of 16.53 ft/hr when shale increase in gamma api and drilling rate indicate a shale. Continue w avg Rop of 32.52 ft/hr. Resume time drilling till stringer is breached at 17,332' Resume normal drilling parameters and surface correction. No losses to the hole while backreaming have been observed and bg gas levels have remained under 200U. pump out of hole with a current depth of 16,371' at the time of report. Current annulus adjustment is 331 bbls open hole and 45 Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 129 479 Drilled Gas 864.0 17310' N/A 17503' Backream and Pump Out 1.9 $360,741.33 mg/l 1935 3.517 Total Charges: 4.2 SPP (psi) Rerun Bit for BHA #13 1614 870 376 CG Gas Breakdown 649 64687 3556 1785 974 2044 3320 62023 3310 1639 4284 17332'17363' 671 669 Gallons/stroke Flow In (spm) 236 67 563 64110 671 524 64074 17103' 17174' 17159'17164' 17170' 17121' 17117' 17143' 17516'17525' 287 239 17267'17329' 864 639 510 17225'17267' 760 758 17195'17224' 628 Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 17525' MD/6379' TVD 82 8/6/2009-04:00 North Slope 425' Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 6.125 0.389 26.6 91.7 Size 6.125 0.389 HTHP (ml/30 min) Sd - 15879' 15879' 6 Cht 8.70 8.70 67.86 TuffSst Silt Siltst GvlCoalShClyst 47-120 Lst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 540 452 403 53331 2646 1299 73207 3852 1891 437 FBG 213 FBG FBG444 FBG711 315 978 382 FBG881 416 Continue to time drill to 17,103' md break out of stringer and resume normal drilling. Continue to drill to 17,330' md Daniel Sherwood / Tom Mansfield 1038 27581 1290 661 409 83289 17525' 00 ' 14 4-1915879' 17525' 1646' 36 Type 306 C4 Tot FBG 3403 FBG 1668 Cor Solids (lb/100ft2 22k % YP ml/30min API Filt pH Chlorides 9.50 895 was observed @ 629U over 424U BG. Rack back one stand and circulate and reciprocate approx 2x btms up Sperry calculated to 18,025 stks. At approx 17,408' increase in SPP was observed several times with max of 2296 lbs recorded. While circ and recip J. Brown/V. Parsell 393 534 FBG 53956 2676 1279 694 1300 1200 Security FMF3641Z Security FMF3641Z Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1300 1200 Security FMF3641Z Security FMF3641Z observed. Pumped 4857 stks and prepared to TIH. Begin TIH on elevators to 11,830' and encounter tight hole. Ream through and continue to RIH washing and reaming as necessary. Currently RIH with a bit depth of 13,112 md' at the time of report. Low gas J. Brown/V. Parsell POOH Cor Solids (lb/100ft2 22k % YP ml/30min API Filt pH Chlorides 9.40 TypeC4 Tot 17525' 00 ' 12 4-1915879' 17525' 1646' 36 Daniel Sherwood / Tom Mansfield Continue to pump and backream out of hole to casing shoe. At 15,926 packoff w/ max SPP of 2357 lbs entire stnd TG743 289 475 137 44517 23222 1583 C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 67.86 TuffSst Silt Siltst GvlCoalShClyst 47-120 HTHP (ml/30 min) Sd - 15879' 15879' 6 Cht 8.70 8.70 cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 17525' MD/6379' TVD 84 8/8/2009-04:00 North Slope N/A Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 4:00 16372' 23:40 10512' Gallons/stroke Flow In (spm) 679 22 Rerun Bit for BHA #13 Gas Breakdown Wash and Ream to BTM 1.8 $365,474.90 mg/l 657 3.517 Total Charges: 4.4 SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 14 137 POOH 475.0 POOH N/A N/A readings are due to the low flow rates while reaming and are not a good reflection of actual readings. to POOH reaming and pumping to shoe. Pump 40 bbl high vis sweep, heavy cuttings load across shakers while cir sweep was ] encounter tight spot recorded max hookload of 342 K overpull of 190k with no changes in pipe pressure. Worked free and cont showed increased SPP pressure and max hookload of 173K. 15,895' max SPP of 2241 lbs. Cotinue to POOH to 13,688' md and Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air tight spot recorded @ 17,322 md w 404k hk load. Tight @ 14,621' md rotate through w/ 8k torque.13,666' rot through with 9k torque and 9807 stks with no detected carbide on the chromatograph. Sperry had estimated 379 bbls of total correction 45 bbls barrels carbide gradually disolving in drilling fluids. An abnormal peak with normal C1-C5 was observed with max gas occuring at 435U as abnormal peak on chromatograph. Very gradual detection occurred occurred over a period of 10-15 min due to hole properties report is 13,100' md. Max gas recorded while circulating was 1633 Units, no losses or gains to the hole were observed. Current bit depth at the time of Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) 2 272 RIH/CIRC 1633.0 POOH N/A N/A POOH 1.0 $371,046.87 mg/l 0 3.517 Total Charges: 4.3 SPP (psi) Rerun Bit for BHA #13 594 327 151 TG Gas Breakdown 237 3458 1148 7838 Gallons/stroke Flow In (spm) 0 0 58 22012 4:00 16480' 8:15 11:25 15140' 13112' 8:15 15139' 14:10 23:05 1633 473 16709'14454 504 233 12:00 14:10 Daily Charges Nabors 19AC $5,571.97 AK-AM-0006591888 17525' MD/6379' TVD 85 8/9/2009-04:00 North Slope N/A Pioneer Natural Res. ODSN-36 Oooguruk cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 HTHP (ml/30 min) Sd - 15879' 15879' 5 Cht 8.55 8.90 67.86 TuffSst Silt Siltst GvlCoalShClyst 47-120 Lst Gas (units) Chromatograph (ppm) C5 TotDepthMaximum Average C1 C2 C3 236 68 21758 1150 592 48606 2659 1378 TG/BU444 TG334 162 711 291 Continue to ream and wash to bottom. Sperry conducted a fluid caliper test, carbide was first detected @ 11,238 stks Daniel Sherwood / Tom Mansfield 1343 156415 17525' 00 ' 12 4-1915879' 17525' 1646' 36 TypeC4 Tot TG Cor Solids (lb/100ft2 19k % YP ml/30min API Filt pH Chlorides 10.50 surface and 334 open hole wahshout while drilling. Carbide test revealed 394.8 bbls of total correction 45 bbls estimated surface and 334 bbls washout.(est hole dia. 9.8") Continue to circ and recip and then pump 665 bbls 8.6 ppg mud. Begin POOH first J. Brown/V. Parsell RIH 1300 1200 Security FMF3641Z Security FMF3641Z Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 265 1300 1200 Security FMF3641Z Security FMF3641Z 372 hole however well was declared static at surface and after kill mud was pumped. Gas data is reflective of circulating times while pumping spacer and kill mud. Currently preparing for liner run. J. Brown/V. Parsell 210 164 TG 14635 823 425 Cor Solids (lb/100ft2 % YP ml/30min API Filt pH Chlorides Type 135 C4 Tot 1033 TG 545 No mud data 00 ' 4-1915879' 17525' 1646' Daniel Sherwood / Tom Mansfield Continue to POOH to 12,689' md tight rotate through w/ 7k max torque. Tight @ 11,758' md roate through w/ 6k max torque 32 C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 67.86 TuffSst Silt Siltst GvlCoalShClyst 47-120 HTHP (ml/30 min) Sd - 15879' 15879' Cht cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 17525' MD/6379' TVD 86 8/10/2009-04:00 North Slope N/A Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 6:52 7:35 8:45 7:08 194 31 19046 Gallons/stroke Flow In (spm) 0 0 1-3-BT-S-X-NO-TD Rerun Bit for BHA #13 Gas Breakdown Prep for Liner Run $375,780.44 mg/l 0 3.517 Total Charges: SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) N/A 31 While Cir 194.0 8:08:30 N/A N/A deem static and cont to POOH. Lay down BHA and R/U and test BOP's. Sperry recorded a 9.88 bbl loss over entire trip out of the by Sperry 1748 stks. Continue to POOH to 10,532' md and displace with 10.2 ppg brine total of 5680 stks. Flow check well and torque. POOH to 11,057' and pump 16bbl hi vis spacer and chase w/ brine and leave 3bbls hi vis brine in DP. Total stks recorded Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP&Gas: 24 hr Max Max @ ft Pump & Flow Data:R = ROTATING Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas, RG - Ream Gas, F-- - Formation…, E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 1300 1200 Security FMF3641Z Security FMF3641Z J. Brown/V. Parsell Cor Solids (lb/100ft2 % YP ml/30min API Filt pH Chlorides TypeC4 Tot No mud data 00 ' 4-1915879' 17525' 1646' Daniel Sherwood / Tom Mansfield Begin running liner to 6996.56' md then hang off and begin running on 4" drill pipe. Begin rotating 14,340' md C5 TotDepthMaximum Average C1 C2 C3 Lst Gas (units) Chromatograph (ppm) 67.86 TuffSst Silt Siltst GvlCoalShClyst 47-120 HTHP (ml/30 min) Sd - 15879' 15879' Cht cP PV Avg 6.125 0.389 N/A N/A Size 6.125 0.389 17525' MD/6379' TVD 87 8/11/2009-04:00 North Slope N/A Pioneer Natural Res. ODSN-36 Oooguruk Daily Charges Nabors 19AC $4,733.57 AK-AM-0006591888 Gallons/stroke Flow In (spm) 0 0 1-3-BT-S-X-NO-TD Rerun Bit for BHA #13 Gas Breakdown Running Liner $380,514.01 mg/l 0 3.517 Total Charges: SPP (psi) Current R.O.P. (ft/hr) Gas (units) Flow In (gpm) N/A N/A N/A N/A N/A N/A available. Current depth at the time of report is 16,757' md. Sperry has observed proper displacement of fluids and no new gas data is WE L L N A M E : OD S N - 3 6 , O D S N 3 6 P B 1 , O D S N - 3 6 P B 2 LO C A T I O N : Oooguruk OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : North Slope MU D C O : Ba r o i d ST A T E : Alaska RI G : Na b o r s 1 9 A C SP U D : 1- J a n - 0 8 SP E R R Y J O B : AK - A M - 0 0 0 6 5 1 9 8 8 8 TD : 10 - J u l - 0 9 BI T RE C O R D BH A # B i t # B i t T y p e B i t Si z e De p t h In De p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 10 0 1 H u g h e s M X L - 1 1 2 . 2 5 5 8 3 6 8 3 3 6 2 5 2 6 . 3 2 0 . 6 9 9 13 7 . 7 30 30 - 8 4 1 8 3 3 4 2 8 - 7 0 7 2- 3 - W T - A - E - 2 - S D - T D TD S u r f a c e S e c t i o n @ 0 5 : 1 7 , 0 1 - F e b - 0 8 20 0 2 S e c u r i t y D B S F S F X 4 6 3 Z 8 . 7 5 3 6 8 3 3 7 0 3 2 0 0 . 3 0 0 . 9 0 2 66 . 7 20 84 - 1 0 9 1 5 9 9 5 0 6 - 5 4 6 0- 0 - N O - A - X - I - N O - D T F LO T T e s t , R e r u n B i t f o r R u n 3 0 0 30 0 2 r r 1 S e c u r i t y D B S F S F X 4 6 3 Z 8 . 7 5 3 7 0 3 9 8 1 0 6 1 0 7 5 4 . 9 0 0 . 9 0 2 11 1 . 2 20 - 3 0 15 0 2 6 7 7 5 1 0 - 6 6 0 1- 1 - N O - A - X - I - N O - H P PO O H f o r M W D F a i l u r e , R e r u n B i t f o r R u n 4 0 0 40 0 2 r r 2 S e c u r i t y D B S F S F X 4 6 3 Z 8 . 7 5 9 8 1 0 1 0 6 3 5 8 2 5 1 5 . 5 1 0 . 9 0 2 53 . 2 25 - 3 0 13 9 3 5 7 7 4 1 0 - 5 8 3 B i t L o s t i n H o l e L o s t R e t u r n s & B i t L o s t I n H o l e 50 0 3 S e c u r i t y D B S Q H C 1 R 8 . 7 5 0 0 0 0 . 0 0 1 . 1 1 4 0. 0 N/ A N / A N / A N / A 1- 1 - N O - A - X - I - N O - B H A Cl e a n O u t R u n f o r F i s h i n g O p e r a t i o n s 60 0 4 S e c u r i t y D B S F S F X 4 6 3 Z Z 8 . 7 5 6 6 5 4 9 2 8 6 2 6 3 2 4 2 . 7 2 0 . 9 2 4 61 . 6 30 1 4 0 3 5 9 3 1 8 8 - 6 5 3 1- 2 - B T - S - X - I - N O - D S F Si d e t r a c k ( O l d W e l l b o r e R e n a m e d O D S N - 3 6 PB 1 ), POOH Washout, Rerun Bit for Run 700 70 0 4 r r 1 S e c u r i t y D B S F S F X 4 6 3 Z Z 8 . 7 5 9 2 8 6 9 5 0 9 2 2 3 2 . 0 1 0 . 9 2 4 11 0 . 9 24 1 2 1 3 4 6 2 1 4 1 - 6 2 8 3- 3 - B T - A - X - I - E R - D S F PO O H f o r W a s h o u t , R e r u n B i t f o r R u n 8 0 0 80 0 5 S e c u r i t y D B S F S F X 4 6 3 Z Z 8 . 7 5 9 5 0 9 9 5 0 9 0 0 . 0 0 0 . 9 2 4 0. 0 N/ A N / A N/ A N / A Re r u n B i t f o r R u n 9 0 0 Un a b l e t o E n t e r O D S N - 3 6 P B 1 S i d e t r a c k 90 0 5 r r 1 S e c u r i t y D B S F S F X 4 6 3 Z Z 8 . 7 5 6 7 4 0 1 0 6 2 5 3 8 8 5 8 6 . 4 2 0 . 9 2 4 45 . 0 31 1 4 9 40 5 0 5 2 0 - 6 6 1 8 - 7 - R O - N - X - I - B T - T D Si d e t r a c k ( O l d W e l l b o r e R e n a m e d O D S N - 3 6 PB 2 ), TD Intermediate @ 16:48 17-Apr-09 10 0 0 6 H y c a l o g R S R E 6 1 3 D A 8 6 . 1 3 1 0 6 2 5 1 0 6 2 5 0 0 . 0 0 0 . 3 8 9 0. 0 N/ A N / A N/ A N / A 0- 0 - N O - A - X - I - N O - D T F PO O H f o r M W D E r r o r , R e r u n B i t f o r R u n 1 1 0 0 11 0 0 6 r r 1 H y c a l o g R S R E 6 1 3 D A 8 6 . 1 3 1 0 6 2 5 1 5 8 7 9 5 2 5 4 1 3 9 . 1 4 0 . 3 8 9 37 . 8 3- 3 2 6 2 - 1 3 8 26 1 7 1 8 0 - 2 3 4 2- 6 - B T - N - X - I - W T - P R PO O H f o r B i t 12 0 0 7 S e c u r i t y D B S F M F 3 6 4 1 Z 6 . 1 3 1 5 8 7 9 1 5 8 7 9 0 0 . 0 0 0 . 3 8 9 0. 0 N/ A N / A N/ A N / A Re r u n B i t f o r R u n 9 0 0 PO O H f o r G e o P i l o t 13 0 0 7 r r 1 S e c u r i t y D B S F M F 3 6 4 1 Z 6 . 1 3 1 5 8 7 9 1 7 5 2 5 1 6 4 6 6 7 . 8 8 24 . 0 35 1 4 5 27 0 0 2 3 0 T D W e l l @ 1 7 5 2 5 ' WE L L N A M E : OD S N - 3 6 , P B 1 , P B 2 LO C A T I O N : Oo o g u r u k OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : No r t h S l o p e MU D C O : Ba r o i d ST A T E : Al a s k a RI G : Na b o r s 1 9 A C SP U D : 26 - J a n - 0 9 SP E R R Y J O B : AK - A M - 6 5 1 9 8 8 8 TD : 10 - J u l - 0 9 W a t e r - a n d O i l - B a s e d M u d R e c o r d Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Wa t e r / O i l Sd P m p H M B T P f / M f C h l o r H a r d ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % m g / l C a + + 28 - J a n 0 - - - - - - - -- - -- - - - - - 29 - J a n 0 9 . 0 0 1 6 0 1 1 5 5 1 4 / 1 9 / - - 77 . 0 / 6 6 . 0 -- -/ 9 7 . 0 xx 0 . 1 0 8 . 4 - 0 . 0 5 / 1 . 0 0 3 4 . 0 8 8 0 30 - J a n 1 4 1 5 9 . 4 0 9 7 1 6 3 3 1 3 / 1 9 / - 1 6 . 0 65 . 0 / 4 9 . 0 1/ - - -/ 9 4 . 0 3. 0 0 0 . 2 0 8 . 1 - 0 . 1 0 / 0 . 6 0 3 0 . 0 1 0 8 0 31 - J a n 3 2 0 0 9 . 4 0 1 2 4 1 6 3 7 1 8 / 3 0 / - 1 0 . 0 69 . 0 / 5 3 . 0 1/ - - -/ 9 4 . 0 2. 0 0 0 . 2 5 8 . 5 1 4 . 0 - / 0 . 8 0 3 3 . 0 1 1 0 0 1- F e b 3 6 8 3 9 . 5 0 1 0 5 1 9 4 2 2 5 / 4 1 / 4 5 1 0 . 2 80 . 1 / 6 1 . 0 1/ - 6 . 3 -/ 9 2 . 0 2. 0 0 0 . 2 3 8 . 3 1 4 . 0 0 . 1 5 / 0 . 8 3 3 2 . 0 8 4 0 2- F e b 3 6 8 3 9 . 6 0 7 4 1 6 2 8 1 5 / 2 3 / 2 5 8 . 0 60 . 0 / 4 4 . 0 1/ - 7 . 3 -/ 9 2 . 0 1. 0 0 0 . 2 0 8 . 2 1 3 . 5 0 . 1 8 / 0 . 8 5 3 2 . 0 8 4 0 3- F e b 3 6 8 3 9 . 5 0 5 0 1 2 2 6 1 0 / 1 7 / - 9 . 5 50 . 0 / 3 8 . 0 1/ - 6 . 3 -/ 9 2 . 0 1. 0 0 0 . 1 5 8 . 0 1 3 . 0 - / 0 . 8 0 3 2 . 0 8 4 0 4- F e b 3 6 8 3 8 . 5 0 -/ 9 9 . 0 32 . 0 25 - F e b 3 6 8 3 8 . 7 0 2 8 2 2 1 / 2 / - 6. 0 / 4 . 0 1. 3 -/ 9 7 . 6 0. 0 1 - 8 . 0 - - / 0 . 4 5 2 0 . 0 8 0 0 26 - F e b 3 6 8 3 9 . 3 0 4 3 1 1 1 5 5 / 7 / - 5 . 8 37 . 0 / 2 6 . 0 1/ - 5 . 9 3/ 9 0 - 0 . 0 5 9 . 0 - . 0 5 / . 8 5 2 1 . 0 4 0 0 27 - F e b 3 7 0 3 9 . 3 0 4 3 1 3 1 6 6 / 7 / - 5 . 2 42 . 0 / 2 9 . 0 1/ - 5 . 9 4/ 8 9 0. 0 5 0 . 0 5 9 . 1 2 . 5 . 0 5 / . 8 5 2 1 . 0 4 8 0 28 - F e b 5 4 2 2 9 . 2 5 4 5 1 6 1 9 8 / 1 2 / - 4 . 8 51 . 0 / 3 5 . 0 1/ - 5 . 9 5/ 8 8 0. 1 0 - 8 . 4 1 0 . 0 . 0 5 / . 8 0 2 0 . 5 4 4 0 1- M a r 7 3 2 2 9 . 2 0 4 8 1 3 1 8 5 / 7 / - 5 . 4 44 . 0 / 3 1 . 0 1/ - 5 . 4 4. 5 / 8 9 0. 1 0 - 8 . 8 1 2 . 5 . 0 2 / . 7 5 2 1 . 0 4 0 0 2- M a r 7 8 9 1 1 0 . 5 0 4 8 1 9 2 2 1 1 / 2 2 / - 5 . 6 60 . 0 / 4 1 . 0 1/ - 9 . 5 5. 5 / 8 4 0. 1 0 - 8 . 5 1 2 . 5 . 0 5 / . 8 0 2 1 . 0 4 0 0 3- M a r 9 5 9 7 1 0 . 7 0 4 8 2 0 2 3 8 / 1 9 / - 5 . 4 63 / 4 3 / 3 6 / 2 6 / 1 0 / 8 1/ - 9 . 5 5. 0 / 8 4 . 5 0. 1 0 - 8 . 8 1 0 . 0 0 . 0 5 / 0 . 8 0 2 1 . 0 4 4 0 4- M a r 9 8 0 5 1 0 . 7 0 6 2 2 0 3 0 1 2 / 2 4 / - 5 . 2 70 / 5 0 / 4 1 / 3 2 / 1 3 / 1 1 1/ - 9 . 9 3. 0 / 8 6 - 0 . 2 0 1 0 . 0 - 0 . 0 5 / 0 . 5 0 2 1 . 0 4 8 0 5- M a r 9 8 0 5 1 0 . 7 0 6 1 1 7 2 5 7 / 1 1 / - 4 . 4 59 / 4 2 / 3 2 / 2 2 / 9 / 7 1/ - 9 . 9 2. 0 / 8 7 - 0 . 1 0 9 . 6 2 . 0 0 . 1 / 0 . 8 0 2 1 . 0 8 0 0 6- M a r 9 8 0 5 1 0 . 7 0 4 8 1 7 3 0 9 / 1 7 / - 4 . 8 64 / 4 7 / 4 0 / 3 0 / 1 2 / 1 0 1/ - 1 0 . 9 3. 0 / 8 5 0. 2 0 0 . 2 0 9 . 7 7 . 5 0 . 1 0 / 1 . 0 0 2 2 . 0 7 2 0 7- M a r 9 8 0 5 1 0 . 7 0 4 9 1 5 2 6 9 / 1 4 / - 4 . 0 56 / 4 1 / 3 4 / 2 6 / 1 0 / 8 1/ - 9 . 9 4. 0 / 8 5 0. 1 0 0 . 3 0 1 0 . 1 5 . 0 0 . 1 0 / 1 . 3 0 0 2 2 . 0 8 0 0 8- M a r 9 8 1 0 1 0 . 7 0 4 8 1 4 2 7 8 / 1 3 / - 4 . 2 55 / 4 1 / 3 4 / 2 6 / 1 0 / 8 1/ - 9 . 9 4. 0 / 8 5 0. 1 0 0 . 1 0 9 . 5 4 . 0 0 . 1 0 / 1 . 0 0 2 2 . 0 7 6 0 9- M a r 9 8 1 0 1 0 . 7 5 4 8 1 1 2 6 9 / 1 7 / - 5 . 2 48 / 3 7 / 3 1 / 2 4 / 9 / 7 1/ - 1 0 . 4 4. 0 / 8 4 . 5 0. 2 5 0 . 1 0 9 . 5 1 0 . 0 0 . 0 5 / 1 . 6 0 2 2 . 0 6 8 0 10 - M a r 9 8 1 0 1 0 . 7 0 5 4 3 7 3 4 1 1 / - / - 5 . 6 10 8 / 7 1 / 5 0 / 3 9 / 1 5 / 1 1 2/ - 1 1 . 4 4. 0 / 8 3 . 5 0. 2 5 0 . 1 0 9 . 6 1 6 . 0 0 . 0 5 / 1 . 5 0 2 2 . 0 7 6 0 11 - M a r 1 0 4 5 5 1 0 . 7 5 5 4 1 6 2 7 1 2 / 2 1 / - 4 . 6 59 / 4 3 / 3 5 / 2 5 / 9 / 7 2/ - 1 0 . 9 4. 2 / 8 3 . 8 0. 2 5 0 . 1 3 9 . 2 1 5 . 0 0 . 0 9 / 1 . 8 2 2 2 . 0 7 8 0 12 - M a r 1 0 6 3 5 1 0 . 8 0 5 7 2 2 2 7 9 / 3 2 / - 5 . 4 71 / 4 9 / 3 9 / 2 7 / 1 1 / 9 2/ - 1 1 . 7 4. 5 / 8 2 . 7 0. 2 5 0 . 1 3 9 . 6 1 6 . 5 0 . 1 0 / 1 . 5 0 2 2 . 0 7 6 0 13 - M a r 1 0 6 3 5 1 0 . 8 0 5 2 2 0 3 1 1 2 / 3 1 / - 5 . 4 71 / 5 1 / 4 1 / 3 0 / 1 0 / 8 2/ - 1 1 . 4 4. 5 / 8 3 0. 2 5 0 . 1 0 9 . 0 1 6 . 0 0 . 0 6 / 1 . 3 0 2 2 . 0 7 6 0 14 - M a r 1 0 6 3 5 1 0 . 8 0 5 5 2 1 2 9 1 3 / 2 5 / - 4 . 7 71 / 5 0 / 4 1 / 3 0 / 1 0 / 8 2/ - 1 1 . 4 4. 5 / 8 . 3 - 0 . 1 0 9 . 0 1 6 . 0 0 . 0 5 / 1 . 6 0 2 2 . 0 6 8 0 15 - M a r 1 0 6 3 5 1 0 . 8 0 5 5 1 7 2 2 1 3 / 2 5 / - 4 . 7 56 / 3 9 / 3 2 / 2 4 / 9 / 8 2/ - 1 1 . 4 4. 5 / 8 . 3 - 0 . 1 0 9 . 0 1 6 . 0 0 . 0 5 / 1 . 4 0 2 2 . 0 6 4 0 16 - M a r 1 0 6 3 5 1 0 . 7 0 5 1 1 4 2 3 9 / 2 3 / - 3 . 8 51 / 3 7 / 3 0 / 2 3 / 8 / 7 1/ - 9 . 9 3. 0 / 8 6 . 0 - 0 . 2 5 1 0 . 0 8 . 0 0 . 6 0 / 1 . 8 0 2 2 . 0 8 0 0 17 - M a r 1 0 6 3 5 1 0 . 8 0 7 6 1 8 2 8 1 3 / 2 2 / - 5 . 0 64 / 4 6 / 3 9 / 3 0 / 1 1 / 9 2/ - 9 . 9 3. 0 / 8 6 . 0 - 0 . 1 5 9 . 7 4 . 0 0 . 1 1 / 1 . 6 3 2 2 . 0 7 6 0 18 - M a r 1 0 6 3 5 1 0 . 8 0 5 2 1 7 2 6 1 3 / 1 8 / - 5 . 2 60 / 4 3 / 3 2 / 2 6 / 1 0 / 8 2/ - 9 . 9 3. 0 / 8 6 . 0 0. 1 0 - 9 . 0 5 . 5 0 . 0 5 / 1 . 6 8 2 2 . 0 5 0 0 19 - M a r 1 0 6 3 5 1 0 . 8 0 5 1 1 9 2 8 1 0 / 2 1 / - 5 . 6 66 / 4 7 / 3 9 / 2 9 / 1 1 / 9 2/ - 1 0 . 2 4. 8 / 8 4 . 0 0. 1 0 - 9 . 1 1 1 . 0 0 . 1 0 / 1 . 4 5 2 1 . 0 8 0 0 20 - M a r 1 0 6 3 5 1 0 . 8 0 5 3 1 8 2 7 1 3 / 2 9 / - 6 . 2 63 . 0 / 4 5 . 0 2/ - 1 0 . 3 4. 0 / 8 4 . 6 0. 1 0 - 9 . 0 1 5 . 0 0 . 0 8 / 1 . 5 0 2 2 . 0 7 2 0 21 - M a r 1 0 6 3 5 1 0 . 8 0 5 1 2 1 3 0 1 2 / 2 5 / - 5 . 8 72 . 0 / 5 1 . 0 2/ - 1 0 . 7 6. 8 / 8 1 . 5 12 . 0 0 - 9 . 0 1 2 . 5 . 1 0 / 1 . 1 0 2 2 . 0 7 2 0 22 - M a r 1 0 6 3 5 1 0 . 8 0 5 3 1 8 2 8 1 4 / 2 8 / - 6 . 0 64 . 0 / 4 6 . 0 2/ - 1 1 . 0 7. 0 / 8 1 . 0 0. 1 0 - 9 . 0 1 2 . 5 . 0 8 / 1 . 3 0 2 2 . 0 7 2 0 23 - M a r 1 0 6 3 5 1 0 . 8 0 5 3 1 6 2 7 1 6 / 2 8 / - 6 . 2 59 . 0 / 4 3 . 0 2/ - 1 1 . 0 7. 0 / 8 1 . 0 0. 1 0 - 8 . 4 1 5 . 0 . 0 5 / 1 . 5 0 2 1 . 0 7 4 0 24 - M a r 1 0 6 3 5 1 0 . 8 0 5 3 1 7 2 7 1 3 / 2 2 / - 5 . 8 61 . 0 / 4 4 . 0 2/ - 1 0 . 4 4. 5 / 8 4 . 0 0. 1 0 - 8 . 5 1 1 . 5 . 0 5 / 1 . 4 0 2 2 . 0 6 2 0 25 - M a r 1 0 6 3 5 1 0 . 8 0 5 0 1 4 2 4 8 / 1 8 / - 5 . 8 52 . 0 / 3 8 . 0 2/ - 9 . 9 6. 0 / 8 3 . 0 0. 1 0 - 8 . 5 1 2 . 5 . 0 5 / 1 . 5 0 2 2 . 0 6 4 0 26 - M a r 1 0 6 3 5 1 0 . 8 0 5 0 1 5 2 4 9 / 2 0 / - 5 . 6 54 . 0 / 3 9 . 0 2/ - 1 1 . 0 6. 0 / 8 2 . 0 0. 1 0 - 8 . 1 1 2 . 5 - / 1 . 5 0 2 1 . 5 7 6 0 27 - M a r 6 7 5 0 1 0 . 8 0 4 9 1 5 2 3 8 / 1 4 / - 5 . 6 53 . 0 / 3 8 . 0 2/ - 1 2 . 0 6. 0 / 8 1 . 0 0. 1 0 - 8 . 0 1 2 . 5 - / 1 . 6 5 2 1 . 5 7 6 0 28 - M a r 7 2 3 7 1 0 . 8 0 4 8 1 5 2 1 1 3 / 3 2 / - 6 . 0 51 . 0 / 3 6 . 0 2/ - 1 3 . 0 5. 0 / 8 1 . 0 0. 1 0 - 9 . 1 1 5 . 0 . 0 5 / 2 . 4 0 2 2 . 0 1 2 0 0 29 - M a r 7 9 8 0 1 0 . 8 0 4 7 1 6 2 4 1 0 / 2 0 / - 5 . 4 56 . 0 / 4 0 . 0 2/ - 1 0 . 8 6. 0 / 8 2 . 0 0. 1 0 - 8 . 7 1 0 . 0 . 0 5 / 1 . 6 0 2 6 . 0 1 4 0 0 30 - M a r 9 1 8 4 1 0 . 8 0 4 8 1 5 2 4 1 6 / 3 6 / - 5 . 8 54 . 0 / 3 9 . 0 2/ - 1 2 . 2 5. 5 / 8 1 . 0 0. 1 0 - 8 . 6 1 5 . 0 . 0 5 / 1 . 6 0 2 8 . 0 1 4 4 0 31 - M a r 9 2 8 6 1 0 . 8 0 4 8 1 3 2 1 1 3 / 2 6 / - 6 . 0 47 . 0 / 3 4 . 0 2/ - 1 2 . 6 6. 0 / 8 0 . 0 0. 1 0 - 8 . 6 1 7 . 5 . 0 5 / 1 . 6 0 3 0 . 0 1 4 4 0 1- A p r 9 2 8 6 1 0 . 8 0 5 0 1 4 2 2 1 6 / 3 6 / - 6 . 4 50 . 0 / 3 6 . 0 2/ - 1 2 . 6 5. 5 / 8 0 . 5 0. 1 0 - 8 . 6 1 7 . 5 . 0 5 / 1 . 9 0 3 0 . 0 1 4 4 0 2- A p r 9 2 8 6 1 0 . 8 0 4 8 1 6 2 2 1 6 / 4 2 / - 6 . 8 54 . 0 / 3 8 . 0 2/ - 1 2 . 6 5. 0 / 8 1 . 0 0. 2 0 - 8 . 5 1 7 . 5 . 0 5 / 2 . 3 3 0 . 0 1 1 6 0 Remarks New Well, Cleaning Tanks, Thaw Pipe Prepare to Spud Drilling Drilling Drill to 3683', POOH, Circulate POOH, R/U to Run Casing Run Casing Finish 36i, Prepare Rig Move Test BOPE M/U BHA, RIH & Drill Cement FIT Test 14.2ppg, POOH for MWD Drilling Drilling Drilling, Wiper Trip Drilling Building Volume Reaming Reaming Tripping Nipple Up BOPE Working Pipe Reaming Drilling Backreaming to Top HRZ R/U Wireline Waiting on Wireline Fishing Fishing Test BOPE RIH for Clean Out Condition Mud & Circulate Washing & Reaming Reaming to Fish Washing & Reaming to Fish TIH w/ Fishing BHA Prepare to Run Cement Cement Abandonment Plug Tripping Circulate & Condition Drilling Drilling Reaming POOH Reaming/Change RCD Reaming OD S N - 3 6 P B 1 O D S N - 3 6 P B 2 Pa g e 1 o f 2 WE L L N A M E : OD S N - 3 6 , P B 1 , P B 2 LO C A T I O N : Oo o g u r u k OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : No r t h S l o p e MU D C O : Ba r o i d ST A T E : Al a s k a RI G : Na b o r s 1 9 A C SP U D : 26 - J a n - 0 9 SP E R R Y J O B : AK - A M - 6 5 1 9 8 8 8 TD : 10 - J u l - 0 9 W a t e r - a n d O i l - B a s e d M u d R e c o r d OD S N - 3 6 P B 1 O D S N - 3 6 P B 2 3- A p r 9 5 0 9 1 0 . 8 0 4 8 1 7 2 6 1 3 / 3 2 / - 6 . 0 60 . 0 / 4 3 . 0 2/ - 1 2 . 2 4. 0 / 8 2 . 5 0. 1 0 - 8 . 4 1 2 . 5 . 0 5 / 2 . 1 0 2 8 . 0 1 4 0 0 4- A p r 9 5 0 9 1 0 . 8 0 4 8 1 4 2 6 1 0 / 2 2 / - 5 . 2 54 . 0 / 4 0 . 0 2/ - 1 0 . 6 4. 0 / 8 4 . 0 0. 1 0 - 8 . 3 8 . 0 . 0 5 / 2 . 1 0 3 0 . 0 1 0 4 0 5- A p r 9 5 0 9 1 0 . 8 0 5 2 2 0 3 3 1 5 / 3 2 / - 6 . 0 73 . 0 / 5 3 . 0 2/ - 1 2 . 1 6. 0 / 8 0 . 5 0. 1 0 - 8 . 4 1 2 . 5 0 . 0 5 / 2 . 1 0 3 0 . 0 9 6 0 6- A p r 9 5 0 9 1 0 . 8 0 5 6 1 9 3 0 1 3 / 3 3 / - 6 . 4 68 . 0 / 4 9 . 0 2/ - 1 4 . 2 6. 0 / 7 8 . 5 - 0 . 0 5 8 . 3 1 5 . 0 0 . 0 5 / 2 . 1 0 3 0 . 0 9 2 0 7- A p r 9 5 0 9 1 1 . 1 0 5 3 1 5 3 0 1 2 / 2 2 / - 6 . 2 60 . 0 / 4 5 . 0 2/ - 1 3 . 6 6. 0 / 7 9 . 0 - 0 . 0 5 8 . 4 1 5 . 0 0 . 0 5 / 2 . 1 0 3 0 . 0 1 0 0 0 8- A p r 9 5 0 9 1 0 . 8 0 5 0 1 9 2 7 1 2 / 2 3 / - 6 . 5 65 . 0 / 4 6 . 0 2/ - 1 2 . 6 6. 0 / 8 0 . 0 0. 1 0 0 . 1 5 8 . 5 1 4 . 0 . 0 5 / 2 . 0 0 3 0 . 0 1 0 0 0 9- A p r 9 5 0 9 1 0 . 9 0 5 4 1 6 2 5 1 5 / 2 7 / - 7 . 2 57 . 0 / 4 1 . 0 2/ - 1 2 . 7 6. 0 / 8 0 . 0 0. 0 0 0 . 1 5 9 . 0 1 6 . 0 . 1 0 / 2 . 5 0 2 8 . 0 1 4 0 0 10 - A p r 7 5 3 3 1 0 . 7 5 4 8 1 5 2 7 1 0 / 1 7 / - 6 . 0 57 . 0 / 4 2 . 0 2/ - 1 1 . 5 2. 0 / 8 5 . 2 0. 0 0 0 . 0 5 8 . 8 7 . 5 0 . 1 0 / 1 . 6 0 2 7 . 0 9 6 0 11 - A p r 8 5 5 2 1 0 . 8 5 5 4 1 7 3 8 1 4 / 2 9 / - 6 . 4 72 . 0 / 5 5 . 0 2/ - 1 1 . 6 5. 2 / 8 2 . 0 0. 0 0 0 . 1 0 8 . 8 1 1 . 5 0 . 0 5 / 2 . 2 0 2 6 . 0 9 6 0 12 - A p r 9 3 4 0 1 0 . 7 5 5 3 1 6 3 4 1 8 / 4 2 / - 6 . 0 66 . 0 / 5 0 . 0 2/ - 1 2 . 8 6. 0 / 8 0 . 0 0. 2 5 0 . 1 0 8 . 8 1 6 . 0 0 . 0 5 / 2 . 5 0 2 5 . 0 9 6 0 13 - A p r 9 6 2 1 1 0 . 8 0 5 4 1 7 3 4 1 2 / 2 2 / - 5 . 4 68 . 0 / 5 1 . 0 2/ - 1 0 . 8 4. 0 / 8 4 . 0 0. 1 0 0 . 1 0 8 . 7 1 0 . 0 0 . 0 5 / 2 . 5 0 2 5 . 0 1 0 0 0 14 - A p r 9 6 2 1 1 0 . 8 0 5 3 1 7 3 0 1 3 / 2 8 / - 5 . 7 64 . 0 / 4 7 . 0 2/ - 1 0 . 0 3. 0 / 8 5 . 0 0. 0 0 0 . 0 5 8 . 7 1 0 . 0 2 . 2 0 / - 2 4 . 0 9 6 0 15 - A p r 9 9 7 8 1 0 . 8 0 5 2 1 5 3 0 1 0 / 1 9 / - 6 . 2 60 . 0 / 4 5 . 0 2/ - 1 1 . 7 5. 8 / 8 1 . 2 0. 1 0 0 . 1 5 9 . 0 1 2 . 0 0 . 1 0 / 1 . 5 0 2 8 . 0 8 4 0 16 - A p r 1 0 3 9 7 1 0 . 8 0 5 3 1 7 3 0 1 3 / 2 6 / - 6 . 4 64 . 0 / 4 7 . 0 2/ - 1 2 . 9 7. 6 / 7 8 . 2 0. 1 0 - 8 . 3 1 2 . 9 0 . 0 5 / 1 . 5 5 3 0 . 0 9 6 0 17 - A p r 1 0 6 2 5 1 0 . 8 0 5 2 1 5 3 0 1 2 / 2 9 - 6 . 6 60 . 0 / 4 5 . 0 2/ - 1 2 . 7 8. 0 / 7 8 . 0 0. 1 0 - 8 . 6 1 5 . 0 0 . 0 5 / 1 . 6 5 3 0 . 0 1 0 4 0 18 - A p r 1 0 6 2 5 1 0 . 8 0 5 3 1 6 2 7 1 2 / 2 6 / - 6 . 6 57 . 0 / 4 2 . 0 2/ - 1 2 . 7 7. 4 / 7 8 . 6 0. 1 0 - 8 . 4 1 5 . 0 0 . 0 5 / 1 . 5 0 3 0 . 0 1 0 4 0 19 - A p r 1 0 6 2 5 1 1 . 1 0 5 4 2 1 3 0 1 0 / 2 4 / - 6 . 0 72 . 0 / 5 1 . 0 2/ - 1 3 . 6 6. 0 / 7 9 . 0 0. 1 0 - 8 . 5 1 0 . 0 0 . 0 5 / 1 . 5 5 3 1 . 0 1 0 8 0 20 - A p r 1 0 6 2 5 1 1 . 1 0 5 2 1 4 2 7 1 0 / 2 2 / - 5 . 4 55 . 0 / 4 1 . 0 2/ - 1 4 . 6 6. 0 / 7 8 . 0 0. 1 0 - 8 . 5 1 0 . 0 0 . 0 5 / 1 . 5 0 3 1 . 0 1 0 8 0 21 - A p r 1 0 6 2 5 1 2 . 8 0 5 5 1 8 2 3 1 4 / 2 9 / - 5 . 2 59 . 0 / 4 1 . 0 2/ - 1 8 . 7 5. 0 / 7 5 . 0 0. 1 0 - 8 . 4 7 . 5 0 . 0 5 / 1 . 4 0 3 1 . 5 1 1 2 0 22 - A p r 1 0 6 2 5 1 2 . 4 0 4 9 1 8 2 7 1 6 / 2 8 / - 5 . 2 63 . 0 / 4 5 . 0 2/ - 1 7 . 6 5. 0 / 7 6 . 0 0. 1 0 - 8 . 1 7 . 5 - / 1 . 5 0 3 1 . 5 1 1 2 0 23 - A p r 1 0 6 1 8 1 1 . 8 0 4 2 1 4 1 9 1 2 / 2 0 / - 6 . 8 47 . 0 / 3 3 . 0 2/ - 1 5 . 6 4. 0 / 7 9 . 0 0. 1 0 - 8 . 2 7 . 5 - / 1 . 3 0 3 1 . 0 9 6 0 18 - J u l 1 0 6 2 5 8 . 8 0 4 0 5 1 6 5 / 6 / - 4 . 6 26 / 2 1 / 1 7 / 1 3 / 6 / 5 - 3 . 0 5. 0 / 9 1 . 0 - - 1 1 . 0 2 . 0 0 . 1 0 / 1 . 5 0 1 8 . 0 2 0 0 19 - J u l 1 0 6 2 5 8 . 7 5 3 8 5 1 3 5 / 6 / - 5 . 2 23 / 1 8 / 1 5 / 1 1 / 6 / 5 - 2 . 4 5. 0 / 9 1 . 5 - 0 . 1 0 1 0 . 9 2 . 5 0 . 1 5 / 1 . 9 0 2 1 . 5 3 2 0 20 - J u l 1 0 6 2 5 8 . 7 5 4 3 7 1 5 5 / 6 / - 4 . 6 29 / 2 2 / 1 9 / 1 5 / 6 / 5 - 2 . 5 5. 0 / 9 1 . 5 - 0 . 1 0 1 1 . 2 2 . 5 0 . 1 5 / 2 . 2 0 2 2 . 0 2 8 0 21 - J u l 1 0 7 8 5 8 . 7 0 3 9 5 1 3 5 / 6 / - 4 . 4 23 / 1 8 / 1 4 . 5 / 1 1 / 5 / 4 1/ - 2 . 5 6. 0 / 9 1 . 0 0. 1 0 0 . 0 5 1 0 . 3 2 . 5 0 . 1 0 / 1 . 5 0 2 1 . 0 5 6 0 22 - J u l 1 1 2 4 9 8 . 7 5 3 9 5 1 5 6 / 8 / - 4 . 4 25 / 2 0 / 1 7 / 1 4 / 7 / 6 1/ - 2 . 4 5. 0 / 9 1 . 5 0. 1 0 0 . 1 0 9 . 5 2 . 0 0 . 1 0 / 1 . 5 0 2 0 . 0 3 2 0 23 - J u l 1 1 9 6 7 8 . 7 0 3 7 5 1 3 5 / 7 / - 4 . 7 23 / 1 8 / 1 5 / 1 2 / 6 / 5 1/ - 2 . 1 5. 0 / 9 2 . 0 0. 1 0 0 . 1 0 1 0 . 2 2 . 0 0 . 1 0 / 1 . 4 0 1 7 . 0 3 6 0 24 - J u l 1 3 1 0 4 8 . 7 0 3 9 9 1 5 6 / 1 0 / - 4 . 9 33 / 2 4 / 2 1 / 1 7 / 7 / 5 . 5 1/ - 2 . 1 5. 0 / 9 2 . 0 0. 1 0 0 . 0 5 9 . 1 3 . 5 0 . 1 0 / 1 . 1 0 1 6 . 0 4 4 0 25 - J u l 1 4 0 7 0 8 . 7 0 3 9 5 1 2 4 / 6 / - 4 . 2 22 / 1 7 / 1 4 / 1 0 / 5 / 4 1/ - 1 . 9 5. 5 / 9 1 . 5 0. 1 0 0 . 2 0 1 0 . 6 2 . 5 0 . 1 5 / 2 . 8 0 2 1 . 0 6 0 26 - J u l 1 4 7 5 3 8 . 7 5 3 7 5 1 2 5 / 7 / - 4 . 4 22 / 1 7 / 1 4 / 1 0 . 5 / 5 / 4 1/ - 2 . 7 5. 5 / 9 1 . 0 0. 1 0 0 . 3 0 1 1 . 5 4 . 0 0 . 2 5 / 2 . 0 0 1 5 . 0 8 0 27 - J u l 1 5 0 2 5 8 . 7 0 3 6 6 1 3 5 / 7 / - 4 . 8 25 / 1 9 / 1 6 / 1 2 / 5 / 4 1/ - 2 . 1 5. 5 / 9 1 . 5 0. 1 0 - 8 . 7 4 . 0 0 . 1 5 / 1 . 8 0 1 7 . 0 2 4 0 28 - J u l 1 5 8 7 0 8 . 8 0 3 6 6 1 1 5 / 7 / - 4 . 4 23 / 1 7 / 1 5 / 1 1 / 5 / 4 1/ - 3 . 1 5. 5 / 9 0 . 5 0. 1 0 - 8 . 6 4 . 2 0 . 1 0 / 1 . 6 0 1 7 . 0 1 2 0 29 - J u l 1 5 8 7 9 8 . 5 5 3 6 5 1 2 5 / 7 / - 4 . 3 22 / 1 7 / 1 4 / 1 1 / 5 / 4 1/ - 1 . 1 5. 5 / 9 2 . 5 0. 1 0 0 . 1 0 1 0 . 5 0 . 2 0 . 0 5 / 0 . 8 0 1 6 . 0 1 4 0 30 - J u l 1 5 8 7 9 1 0 . 1 0 2 7 - - - - - - 4 . 0 -/ 8 7 . 0 - - 8 . 5 - - 1 5 8 . 0 - 31 - J u l 1 5 8 7 9 1 0 . 1 5 2 7 - - - - - - 3 . 8 -/ 8 7 . 0 - - 8 . 5 - - 1 6 0 . 0 - 1- A u g 1 5 8 7 9 1 0 . 1 5 2 7 - - - - - - 3 . 8 -/ 8 7 . 0 - - 8 . 5 - - 1 6 0 . 0 - 2- A u g 1 5 8 7 9 8 . 7 5 3 6 5 1 0 5 / 7 / - 4 . 6 20 / 1 5 / 1 3 / 1 0 / 5 / 4 1/ - 1 . 2 5. 5 / 9 1 . 4 0. 1 0 0 . 1 0 1 0 . 4 0 . 2 0 . 0 5 / 0 . 8 0 3 6 . 0 1 2 0 3- A u g 1 6 1 1 2 8 . 7 5 3 7 6 1 5 6 / 9 / - 4 . 6 27 / 2 1 / 1 9 / 1 5 / 6 / 5 1/ - 1 . 5 5. 5 / 9 1 . 3 0. 1 0 0 . 1 0 9 . 6 1 . 5 0 . 0 5 / 1 . 0 0 3 3 . 0 1 6 0 4- A u g 1 6 7 7 5 8 . 7 5 3 8 7 1 3 6 / 9 / - 4 . 8 27 / 2 0 / 1 7 / 1 4 / 6 / 5 1/ - 1 . 6 5. 5 / 9 1 . 3 0. 1 0 0 . 0 5 9 . 5 2 . 0 0 . 0 2 / 1 . 1 0 3 1 . 0 1 6 0 5- A u g 1 7 0 9 6 8 . 7 5 3 8 8 1 6 7 / 9 / - 4 . 8 27 / 2 1 / 1 8 / 1 5 / 7 / 6 1/ - 2 . 2 6. 5 / 9 0 . 0. 1 0 0 . 1 0 9 . 5 1 . 5 . 2 / 2 . 6 2 6 . 0 1 2 0 6- A u g 1 7 5 2 5 8 . 7 0 3 6 6 1 4 7 / 9 / - 4 . 2 26 / 2 0 / 1 7 / 1 4 / 6 / 5 1/ - 1 . 9 6. 0 / 9 0 0. 1 0 0 . 1 0 9 . 5 2 . 5 . 0 5 / 1 . 8 2 2 . 0 1 0 0 7- A u g 1 7 5 2 5 8 . 7 0 3 6 6 1 2 6 / 8 / - 4 . 4 24 / 1 8 / 1 5 / 1 2 / 6 / 5 1/ - 1 . 8 6. 0 / 9 0 0. 1 0 0 . 1 0 9 . 4 2 . 5 . 0 5 / 1 . 4 2 3 . 0 1 4 0 8- A u g 1 7 5 2 5 8 . 5 5 3 6 5 1 2 5 / 7 / - 4 . 3 22 / 1 7 / 1 4 / 1 1 / 5 / 4 1/ - 1 . 0 5. 5 / 9 2 . 5 0. 1 0 0 . 1 0 1 0 . 5 2 . 5 . 0 5 / . 8 0 1 9 . 0 1 4 0 9- A u g 1 7 5 2 5 1 0 . 2 0 2 9 7 . 4 /8 5 14 0 . 0 10 - A u g 1 7 5 2 5 1 0 . 2 0 2 9 7 . 4 85 . 0 14 0 . 0 11 - A u g 1 7 5 2 5 1 0 . 2 0 2 9 7 . 7 /8 5 13 5 . 0 12 - A u g 1 7 5 2 5 1 0 . 2 0 7 . 7 /8 5 13 5 . 0 13 - A u g 17 5 2 5 1 0 . 2 0 Reaming Reaming Reaming POOH POOH RIH Prepare to Drill Drilling Drilling Drilling, Short Trip Hole Issues Hole Issues Drilling Drilling TD Hole Section, POOH Back Reaming Reaming, Condition Hole Reaming, Condition Hole POOH RIH w/Casing Cement Casing Rig Up & Rig Down Drilling Tripping Drilling Drilling Drilling Drilling Drilling Drilling Drilling Drilling Drilling Testing BOPE Drilling Backreaming TrippingTrip In Trip In Trip In Drilling Run Completion String Wireline/rig moveTrippingC/O BOPs Run Casing Run TubingDrilling Pa g e 2 o f 2 Well Name: Depth (MD) to ft Location:(TVD) to ft Operator:Show Report No. Report Prepared By: Date/Time: Report Delivered To: 1 %Hydrocarbon Ratios Depth ft Gas x Units Mud Chlorides (1000's) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 % Depth ft Gas x Units Mud Chlorides (1000's) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 %Hydrocarbon Ratios Depth ft Gas x Units Mud Chlorides (1000's) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (1000's) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas x Oil Water Non-Producible Hydrocarbons Show Reports 60 129 369 162 582 25 131 Interpretation:Chromatograph gas in air analysis from gas trap at possum belly. All four samples occurred from two Pumps Off Gas 410 16 294 162 514 399 23957 45 3110 15700 69080 47103 2066 1044 275 21977 37862 16 96 247 23 16 60 156 664153 13575 536 923 530 393 2287 1044 428 640 59839 21977 events at 15879' MD; the first was at 9.57ppg EMW (install pup joint) and the second 9.35ppg EMW (lost power to rig) which resulted in a 30 minor observable influx in the Nuiqsut reservoir. Chromatograph analysis doesn't represent heavier hydrocarbons which would shift the curves towards the gas-oil/oil interface. Observed gasses were from TVD high point at ~13600' MD revert and from bottom's up. 164 16 1243 530 783 577 275 1313 43534 19577 302 45776 19577 26199 13750 39615800 176 480 294 186 1929 979 950 851 337 456 29 1869 979 890 514 78 196 131 65 107 57 222 107 115 405 913 29-Jul-09 15879 15879 6376 1 6376 ODSN-36 North Slope, Alaska Pioneer Natural Resources Danny Kane 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Marker MD INC AZ TVD TVDSS PROG TVD PROG SS +/- to WP16 Comments Top of Permafrost 844' 6.74 128.36 842 784.0 na na Estimated Base of Permafrost 1,728' 38.13 132.23 1663 1605.1 1,656' 1,600' 5 Estimated Top West Sak 2,710' 52.60 158.62 2404 2346.3 2,365' 2,309' 37 Violet 1 Fault 3,480' 44.65 162.80 2879 2820.7 na na Hue Shale 3,550' 42.69 163.22 2929 2871.4 2,947' 2,891' -20 Tuffaceous Shale 3,625' 42.75 162.97 2985 2926.5 2,995' 2,939' -12 SCP 3,666' 42.77 162.93 3015 2956.5 2,995' 2,939' 18 Brook 2B 5,613' 50.27 195.29 4268 4211.9 4,273' 4,217' -5 Sidetrack # 1 KOP 6,654' 50.49 244.24 4926 4869.8 4,987' 4,931' Sidetrack # 2 KOP 6,740' 54.34 248.91 4978 4921.7 na na Torok Top 6,920' 56.40 252.95 5078 5021.8 5,072' 5,016' 6 Torok Base 7,357' 58.19 269.72 5316 5259.6 5,315' 5,259' 1 Top HRZ 8,429' 71.38 301.00 5781 5725.2 5,790' 5,734' -9 Base HRZ 8,870' 73.90 303.31 5910 5853.8 5,919' 5,863' -9 Possible Fault 9,127' 74.69 304.38 5978 5922.1 na na Kalubik Marker 9,214' 73.86 304.44 6002 5945.7 5,999' 5,943' 3 Top Kup C 9,458' 73.04 303.34 6073 6016.7 6,071' 6,015' 2 LCU 9,617' 72.99 302.51 6119 6063.2 6,120' 6,064' -1 BCU 10,422' 74.09 302.52 6345 6288.6 6,336' 6,280' 9 Top Nuiqsut 10,562' 75.07 302.96 6383 6326.3 6,374' 6,318' 8 Nuiq_1 10,589' 75.50 303.04 6389 6333.2 6,381' 6,325' 8 Tops for ODSN-36 (wp23) Marker MD INC AZ TVD TVDSS PROG TVD PROG SS +/- to WP23 Comments ICP 10,618' 75.49 303.05 6397 6340.5 6,386' 6,330' 10 TD for ICP 10,625' 75.49 303.05 6398 6342.2 na na Flow_1::Flow_2_D1 10,753' 79.97 302.57 6425 6368.9 Flow_2::Flow_3_D1 10,771' 79.99 302.77 6428 6372.0 Flow_3::Flow_4_D1 10,814' 80.04 303.26 6436 6379.4 Flow_4::Flow_5_D1 10,826' 80.06 303.39 6438 6381.5 Fault 10,990' 85.19 309.53 6460 6404.0 ~6' DTSE T1 (Invert #1) 11,089' 90.00 311.15 6465 6408.5 6459 6402.3 6 T2 12,000' 95.01 295.79 6410 6354.3 6455 6398.8 -45 Flow_5::Flow_4_U1 12,033' 95.05 296.60 6408 6351.4 Flow_4::Flow_3_U1 12,100' 94.96 298.52 6402 6345.5 Flow_3::Flow_2_U1 12,183' 95.12 300.38 6394 6338.2 Flow_2::Flow_1_U1 12,217' 95.00 301.51 6391 6335.2 T3 12,600' 92.93 309.49 6366 6309.9 6401 6344.8 -35 Poss fault in Zone 5 13,040' 91.35 318.13 6355 6298.4 ~7' DTSE T4 (Revert #1) 13,624' 90.00 317.90 6339 6283.2 6391 6335.2 -52 Flow_1::Flow_2_D2 14,072' 86.18 322.56 6362 6305.3 Flow_2::Flow_3_D2 14,107' 85.61 322.63 6364 6307.8 Flow_3::Flow_4_D2 14,305' 86.17 320.31 6377 6321.2 Flow_4::Flow_5_D2 14,328' 85.03 319.82 6379 6322.9 T5 (Invert #2a) 14,670' 90.00 324.98 6391 6335.0 6437 6380.9 -46 begin Zone 5 tangent T6 (Invert #2b) 15,451' 90.00 328.36 6384 6327.5 6429 6372.9 -45 end Zone 5 tangent Flow_5::Flow_4_U2 15,948' 94.15 322.26 6368 6311.7 Flow_4::Flow_3_U2 15,995' 94.07 322.67 6365 6308.5 Flow_3::Flow_2_U2 16,255' 93.37 322.22 6345 6289.2 Flow_2::Flow_1_U2 16,320' 93.75 321.63 6341 6285.2 T7 16,400' 93.35 320.79 6336 6279.9 6361 6305.2 -25 T8 (Revert #2) 16,884' 90.00 317.80 6315 6258.8 6341 6285.0 -26 Flow_1::Flow_2_D3 17,122' 84.04 318.18 6329 6272.7 Flow_2::Flow_3_D3 17,132' 83.65 318.39 6330 6273.7 Flow_3::Flow_4_D3 17,208' 82.29 319.25 6339 6283.1 Flow_4::Flow_5_D3 17,225' 82.00 319.44 6342 6285.4 Nuiqsut Base 17,455' 82.48 320.22 6371 6314.5 9.6' TVD penetration T9 Total Depth 17,525' 82.48 320.22 6380 6323.7 6401 6345.0 -21 planned 18,669' Tops for ODSN-36 (wp16) 24 August, 2009 Oooguruk Developement Oooguruk Drill Site ODSN-36 PB1 Permit to Drill: 207-182 API: 50-703-20561-70 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB1 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Developement Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-36 - Slot ODS-36 ft ft 0.0 0.0 6,031,065.83 469,881.69 13.5Wellhead Elevation:ft0.0 70° 29' 45.399 N 150° 14' 46.595 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) ODSN-36 PB1 Model NameMagnetics IGRF200510 3/23/2009 22.33 80.81 57,727 Phase:Version: Audit Notes: Design ODSN-36 PN10 PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:42.7 293.080.00.042.7 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 8/21/2009 Survey Date CB-GYRO-SS Camera based gyro single shot100.0 263.0 ODSN-36 PN10 PB1 Gyro (ODSN-36 PB 3/13/2009 12 MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station305.5 10,581.7 ODSN-36 PN10 PB1 MWD (ODSN-36 P 3/13/2009 12 MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.7 0.00 0.00 42.7 0.0 0.0-13.5 6,031,065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 0.2 -0.143.8 6,031,066.0 469,881.6 0.7 0.15 CB-GYRO-SS (1) 173.0 0.34 6.40 173.0 0.6 -0.2116.8 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS (1) 263.0 0.12 82.32 263.0 0.9 -0.1206.8 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS (1) 305.5 0.34 85.09 305.5 0.9 0.1249.3 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS (2 395.7 1.67 137.26 395.7 -0.1 1.3339.5 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS (2 489.5 4.21 129.08 489.3 -3.2 4.9433.1 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS (2 580.2 5.08 122.30 579.7 -7.5 10.8523.5 6,031,058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS (2 671.1 6.36 126.84 670.2 -12.6 18.3614.0 6,031,053.1 469,899.9 1.5 -21.77 MWD+SAG+CA+IIFR+MS (2 764.1 6.03 126.15 762.6 -18.6 26.3706.4 6,031,047.1 469,907.9 0.4 -31.53 MWD+SAG+CA+IIFR+MS (2 859.5 6.88 128.79 857.4 -25.2 34.8801.2 6,031,040.5 469,916.4 0.9 -41.91 MWD+SAG+CA+IIFR+MS (2 948.9 7.50 128.01 946.1 -32.1 43.6889.9 6,031,033.6 469,925.2 0.7 -52.70 MWD+SAG+CA+IIFR+MS (2 1,043.5 9.23 133.51 1,039.7 -41.1 54.0983.5 6,031,024.5 469,935.5 2.0 -65.78 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:17:23PM COMPASS 2003.16 Build 71 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB1 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,139.9 11.67 130.99 1,134.5 -52.8 66.91,078.3 6,031,012.7 469,948.4 2.6 -82.30 MWD+SAG+CA+IIFR+MS (2 1,236.3 15.41 132.58 1,228.2 -67.9 83.71,172.0 6,030,997.6 469,965.2 3.9 -103.67 MWD+SAG+CA+IIFR+MS (2 1,286.8 18.40 133.42 1,276.6 -77.9 94.51,220.4 6,030,987.5 469,975.9 5.9 -117.48 MWD+SAG+CA+IIFR+MS (2 1,332.9 20.25 132.03 1,320.0 -88.3 105.71,263.8 6,030,977.1 469,987.0 4.1 -131.83 MWD+SAG+CA+IIFR+MS (2 1,429.6 23.87 135.45 1,409.7 -113.4 131.91,353.5 6,030,951.9 470,013.1 4.0 -165.77 MWD+SAG+CA+IIFR+MS (2 1,477.4 27.27 133.74 1,452.8 -127.9 146.61,396.6 6,030,937.3 470,027.7 7.3 -184.97 MWD+SAG+CA+IIFR+MS (2 1,526.1 29.56 132.65 1,495.6 -143.7 163.41,439.4 6,030,921.4 470,044.5 4.8 -206.71 MWD+SAG+CA+IIFR+MS (2 1,623.1 33.50 131.69 1,578.2 -177.8 201.01,522.0 6,030,887.3 470,082.0 4.1 -254.64 MWD+SAG+CA+IIFR+MS (2 1,719.4 38.04 132.23 1,656.4 -215.4 242.91,600.2 6,030,849.4 470,123.7 4.7 -307.90 MWD+SAG+CA+IIFR+MS (2 1,816.4 39.04 132.22 1,732.2 -256.0 287.61,676.0 6,030,808.7 470,168.3 1.0 -364.99 MWD+SAG+CA+IIFR+MS (2 1,913.6 38.51 133.70 1,808.0 -297.5 332.21,751.8 6,030,767.0 470,212.6 1.1 -422.23 MWD+SAG+CA+IIFR+MS (2 2,008.2 36.95 136.81 1,882.8 -338.6 372.91,826.6 6,030,725.8 470,253.2 2.6 -475.82 MWD+SAG+CA+IIFR+MS (2 2,104.6 38.08 140.89 1,959.3 -382.8 411.61,903.1 6,030,681.4 470,291.7 2.8 -528.68 MWD+SAG+CA+IIFR+MS (2 2,201.8 39.39 147.75 2,035.2 -432.2 446.91,979.0 6,030,631.9 470,326.8 4.6 -580.57 MWD+SAG+CA+IIFR+MS (2 2,298.1 41.01 151.13 2,108.7 -485.7 478.52,052.5 6,030,578.3 470,358.2 2.8 -630.59 MWD+SAG+CA+IIFR+MS (2 2,396.0 40.88 152.82 2,182.7 -542.3 508.62,126.5 6,030,521.5 470,388.1 1.1 -680.52 MWD+SAG+CA+IIFR+MS (2 2,491.7 42.54 154.78 2,254.1 -599.4 536.72,197.9 6,030,464.3 470,415.9 2.2 -728.76 MWD+SAG+CA+IIFR+MS (2 2,587.9 44.85 156.23 2,323.7 -659.9 564.32,267.5 6,030,403.7 470,443.2 2.6 -777.80 MWD+SAG+CA+IIFR+MS (2 2,634.7 47.29 157.78 2,356.1 -690.9 577.42,299.9 6,030,372.6 470,456.2 5.7 -802.06 MWD+SAG+CA+IIFR+MS (2 2,684.5 51.29 157.87 2,388.6 -725.9 591.72,332.4 6,030,337.6 470,470.3 8.0 -828.87 MWD+SAG+CA+IIFR+MS (2 2,732.3 53.75 159.28 2,417.7 -761.2 605.52,361.5 6,030,302.2 470,484.1 5.7 -855.47 MWD+SAG+CA+IIFR+MS (2 2,781.0 55.96 162.61 2,445.7 -798.8 618.52,389.5 6,030,264.6 470,496.9 7.2 -882.13 MWD+SAG+CA+IIFR+MS (2 2,828.3 56.38 162.38 2,472.1 -836.3 630.32,415.9 6,030,227.0 470,508.6 1.0 -907.73 MWD+SAG+CA+IIFR+MS (2 2,877.9 57.18 163.23 2,499.3 -876.0 642.62,443.1 6,030,187.4 470,520.7 2.2 -934.54 MWD+SAG+CA+IIFR+MS (2 2,974.2 57.45 166.81 2,551.3 -954.2 663.52,495.1 6,030,109.0 470,541.3 3.1 -984.49 MWD+SAG+CA+IIFR+MS (2 3,070.5 53.94 166.00 2,605.5 -1,031.5 682.22,549.3 6,030,031.7 470,559.6 3.7 -1,031.96 MWD+SAG+CA+IIFR+MS (2 3,166.8 49.33 165.38 2,665.3 -1,104.7 700.82,609.1 6,029,958.5 470,578.0 4.8 -1,077.79 MWD+SAG+CA+IIFR+MS (2 3,263.5 47.48 164.96 2,729.5 -1,174.6 719.42,673.3 6,029,888.4 470,596.2 1.9 -1,122.24 MWD+SAG+CA+IIFR+MS (2 3,360.9 46.77 162.67 2,795.8 -1,243.1 739.22,739.6 6,029,819.8 470,615.8 1.9 -1,167.39 MWD+SAG+CA+IIFR+MS (2 3,457.7 45.27 162.67 2,863.0 -1,309.7 760.02,806.8 6,029,753.2 470,636.3 1.5 -1,212.57 MWD+SAG+CA+IIFR+MS (2 3,554.2 42.57 163.25 2,932.5 -1,373.7 779.62,876.3 6,029,689.2 470,655.7 2.8 -1,255.71 MWD+SAG+CA+IIFR+MS (2 3,634.0 42.77 162.93 2,991.2 -1,425.4 795.32,935.0 6,029,637.4 470,671.2 0.4 -1,290.46 MWD+SAG+CA+IIFR+MS (2 3,686.7 43.44 161.54 3,029.6 -1,459.6 806.32,973.4 6,029,603.1 470,682.0 2.2 -1,313.99 MWD+SAG+CA+IIFR+MS (2 3,740.0 44.21 162.62 3,068.1 -1,494.8 817.73,011.9 6,029,567.9 470,693.2 2.0 -1,338.23 MWD+SAG+CA+IIFR+MS (2 3,783.5 44.72 161.58 3,099.1 -1,523.8 827.13,042.9 6,029,538.9 470,702.5 2.0 -1,358.20 MWD+SAG+CA+IIFR+MS (2 3,878.2 44.25 161.84 3,166.7 -1,586.8 847.93,110.5 6,029,475.8 470,723.1 0.5 -1,402.07 MWD+SAG+CA+IIFR+MS (2 3,972.8 44.56 162.68 3,234.3 -1,649.8 868.03,178.1 6,029,412.7 470,743.0 0.7 -1,445.32 MWD+SAG+CA+IIFR+MS (2 4,068.1 46.87 164.02 3,300.8 -1,715.2 887.63,244.6 6,029,347.3 470,762.2 2.6 -1,488.90 MWD+SAG+CA+IIFR+MS (2 4,164.0 49.70 166.27 3,364.6 -1,784.3 905.93,308.4 6,029,278.0 470,780.2 3.4 -1,532.87 MWD+SAG+CA+IIFR+MS (2 4,257.7 50.65 168.64 3,424.7 -1,854.6 921.53,368.5 6,029,207.7 470,795.6 2.2 -1,574.81 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:17:23PM COMPASS 2003.16 Build 71 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB1 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,351.7 50.91 170.49 3,484.1 -1,926.2 934.73,427.9 6,029,136.0 470,808.5 1.5 -1,615.00 MWD+SAG+CA+IIFR+MS (2 4,446.8 52.02 172.32 3,543.4 -1,999.8 945.83,487.2 6,029,062.4 470,819.3 1.9 -1,654.06 MWD+SAG+CA+IIFR+MS (2 4,541.3 52.94 173.13 3,600.9 -2,074.1 955.33,544.7 6,028,988.1 470,828.5 1.2 -1,691.91 MWD+SAG+CA+IIFR+MS (2 4,635.8 53.17 172.12 3,657.7 -2,149.1 965.03,601.5 6,028,913.1 470,837.9 0.9 -1,730.22 MWD+SAG+CA+IIFR+MS (2 4,730.9 51.72 172.49 3,715.6 -2,223.7 975.13,659.4 6,028,838.4 470,847.7 1.6 -1,768.77 MWD+SAG+CA+IIFR+MS (2 4,826.3 52.12 173.04 3,774.5 -2,298.2 984.53,718.3 6,028,763.9 470,856.8 0.6 -1,806.66 MWD+SAG+CA+IIFR+MS (2 4,919.9 52.67 176.70 3,831.6 -2,372.1 991.23,775.4 6,028,690.0 470,863.1 3.2 -1,841.72 MWD+SAG+CA+IIFR+MS (2 5,013.4 51.64 177.77 3,889.0 -2,445.8 994.73,832.8 6,028,616.3 470,866.4 1.4 -1,873.90 MWD+SAG+CA+IIFR+MS (2 5,108.7 50.87 180.12 3,948.6 -2,520.1 996.13,892.4 6,028,542.0 470,867.5 2.1 -1,904.29 MWD+SAG+CA+IIFR+MS (2 5,204.8 52.37 179.20 4,008.3 -2,595.5 996.63,952.1 6,028,466.6 470,867.6 1.7 -1,934.25 MWD+SAG+CA+IIFR+MS (2 5,299.1 51.17 181.09 4,066.7 -2,669.5 996.44,010.5 6,028,392.5 470,867.1 2.0 -1,963.13 MWD+SAG+CA+IIFR+MS (2 5,395.2 50.26 184.27 4,127.5 -2,743.8 992.94,071.3 6,028,318.3 470,863.4 2.7 -1,989.06 MWD+SAG+CA+IIFR+MS (2 5,491.6 49.33 189.57 4,189.8 -2,816.9 984.14,133.6 6,028,245.3 470,854.2 4.3 -2,009.56 MWD+SAG+CA+IIFR+MS (2 5,586.7 50.07 194.04 4,251.3 -2,887.8 969.24,195.1 6,028,174.4 470,839.1 3.7 -2,023.72 MWD+SAG+CA+IIFR+MS (2 5,679.3 50.76 199.12 4,310.3 -2,956.1 948.94,254.1 6,028,106.2 470,818.5 4.3 -2,031.78 MWD+SAG+CA+IIFR+MS (2 5,773.9 50.69 203.95 4,370.3 -3,024.3 922.04,314.1 6,028,038.2 470,791.3 4.0 -2,033.75 MWD+SAG+CA+IIFR+MS (2 5,868.4 51.20 209.30 4,429.8 -3,089.8 889.14,373.6 6,027,972.7 470,758.2 4.4 -2,029.21 MWD+SAG+CA+IIFR+MS (2 5,962.8 52.70 212.82 4,488.0 -3,153.4 850.84,431.8 6,027,909.3 470,719.6 3.3 -2,018.87 MWD+SAG+CA+IIFR+MS (2 6,058.1 50.71 217.72 4,547.1 -3,214.5 807.64,490.9 6,027,848.4 470,676.2 4.5 -2,003.12 MWD+SAG+CA+IIFR+MS (2 6,151.9 50.37 223.81 4,606.7 -3,269.3 760.44,550.5 6,027,793.8 470,628.7 5.0 -1,981.15 MWD+SAG+CA+IIFR+MS (2 6,246.5 50.36 228.36 4,667.0 -3,319.8 708.04,610.8 6,027,743.5 470,576.1 3.7 -1,952.72 MWD+SAG+CA+IIFR+MS (2 6,341.8 49.80 232.42 4,728.2 -3,366.4 651.74,672.0 6,027,697.2 470,519.7 3.3 -1,919.20 MWD+SAG+CA+IIFR+MS (2 6,437.5 51.82 235.29 4,788.7 -3,410.1 591.84,732.5 6,027,653.7 470,459.6 3.1 -1,881.23 MWD+SAG+CA+IIFR+MS (2 6,532.2 50.20 239.91 4,848.3 -3,449.5 529.74,792.1 6,027,614.5 470,397.4 4.2 -1,839.58 MWD+SAG+CA+IIFR+MS (2 6,627.0 50.55 243.97 4,908.8 -3,483.9 465.34,852.6 6,027,580.4 470,332.8 3.3 -1,793.76 MWD+SAG+CA+IIFR+MS (2 6,722.4 50.73 248.72 4,969.3 -3,513.5 397.74,913.1 6,027,551.1 470,265.1 3.9 -1,743.21 MWD+SAG+CA+IIFR+MS (2 6,817.1 51.37 252.54 5,028.9 -3,537.9 328.24,972.7 6,027,527.0 470,195.6 3.2 -1,688.88 MWD+SAG+CA+IIFR+MS (2 6,912.4 53.72 257.22 5,086.8 -3,557.6 255.35,030.6 6,027,507.6 470,122.5 4.6 -1,629.44 MWD+SAG+CA+IIFR+MS (2 7,007.5 53.75 261.25 5,143.1 -3,571.9 179.95,086.9 6,027,493.6 470,047.1 3.4 -1,565.77 MWD+SAG+CA+IIFR+MS (2 7,102.4 56.05 264.91 5,197.7 -3,581.2 102.95,141.5 6,027,484.6 469,970.1 4.0 -1,498.56 MWD+SAG+CA+IIFR+MS (2 7,197.7 58.25 268.37 5,249.4 -3,585.8 23.05,193.2 6,027,480.3 469,890.2 3.8 -1,426.88 MWD+SAG+CA+IIFR+MS (2 7,293.4 60.42 272.29 5,298.2 -3,585.3 -59.35,242.0 6,027,481.1 469,807.9 4.2 -1,350.96 MWD+SAG+CA+IIFR+MS (2 7,387.6 62.80 274.69 5,343.0 -3,580.3 -142.05,286.8 6,027,486.5 469,725.2 3.4 -1,272.93 MWD+SAG+CA+IIFR+MS (2 7,482.7 64.46 278.99 5,385.3 -3,570.1 -226.65,329.1 6,027,497.0 469,640.7 4.4 -1,191.10 MWD+SAG+CA+IIFR+MS (2 7,577.5 66.65 282.14 5,424.5 -3,554.3 -311.45,368.3 6,027,513.2 469,555.9 3.8 -1,106.87 MWD+SAG+CA+IIFR+MS (2 7,672.6 68.89 285.02 5,460.5 -3,533.6 -396.95,404.3 6,027,534.2 469,470.5 3.7 -1,020.07 MWD+SAG+CA+IIFR+MS (2 7,767.1 70.92 286.56 5,492.9 -3,509.4 -482.35,436.7 6,027,558.7 469,385.3 2.6 -932.10 MWD+SAG+CA+IIFR+MS (2 7,863.1 71.19 286.17 5,524.1 -3,483.8 -569.45,467.9 6,027,584.7 469,298.2 0.5 -841.87 MWD+SAG+CA+IIFR+MS (2 7,957.2 71.79 283.99 5,554.0 -3,460.6 -655.65,497.8 6,027,608.2 469,212.2 2.3 -753.53 MWD+SAG+CA+IIFR+MS (2 8,051.8 71.24 283.34 5,584.0 -3,439.5 -742.75,527.8 6,027,629.7 469,125.1 0.9 -665.06 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:17:23PM COMPASS 2003.16 Build 71 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB1 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,146.7 70.20 283.81 5,615.3 -3,418.4 -829.85,559.1 6,027,651.1 469,038.1 1.2 -576.70 MWD+SAG+CA+IIFR+MS (2 8,241.7 69.73 283.24 5,647.9 -3,397.5 -916.65,591.7 6,027,672.4 468,951.4 0.7 -488.65 MWD+SAG+CA+IIFR+MS (2 8,335.9 70.20 283.66 5,680.1 -3,377.0 -1,002.75,623.9 6,027,693.3 468,865.5 0.7 -401.42 MWD+SAG+CA+IIFR+MS (2 8,431.1 70.68 283.56 5,712.0 -3,355.9 -1,089.95,655.8 6,027,714.8 468,778.3 0.5 -312.91 MWD+SAG+CA+IIFR+MS (2 8,525.8 70.31 283.16 5,743.6 -3,335.2 -1,176.75,687.4 6,027,735.7 468,691.6 0.6 -224.93 MWD+SAG+CA+IIFR+MS (2 8,620.8 70.45 283.07 5,775.5 -3,314.9 -1,263.85,719.3 6,027,756.4 468,604.6 0.2 -136.83 MWD+SAG+CA+IIFR+MS (2 8,715.7 71.72 285.77 5,806.3 -3,292.6 -1,350.85,750.1 6,027,779.1 468,517.7 3.0 -48.05 MWD+SAG+CA+IIFR+MS (2 8,811.1 69.83 284.97 5,837.7 -3,268.7 -1,437.65,781.5 6,027,803.3 468,431.0 2.1 41.19 MWD+SAG+CA+IIFR+MS (2 8,905.6 71.26 281.99 5,869.2 -3,247.9 -1,524.35,813.0 6,027,824.4 468,344.4 3.3 129.02 MWD+SAG+CA+IIFR+MS (2 8,998.8 71.25 283.69 5,899.1 -3,228.3 -1,610.35,842.9 6,027,844.4 468,258.4 1.7 215.89 MWD+SAG+CA+IIFR+MS (2 9,093.5 70.79 284.37 5,929.9 -3,206.6 -1,697.25,873.7 6,027,866.4 468,171.7 0.8 304.34 MWD+SAG+CA+IIFR+MS (2 9,188.3 71.31 285.20 5,960.7 -3,183.7 -1,783.95,904.5 6,027,889.7 468,085.1 1.0 393.03 MWD+SAG+CA+IIFR+MS (2 9,282.1 70.96 289.08 5,991.0 -3,157.6 -1,868.75,934.8 6,027,916.1 468,000.4 3.9 481.26 MWD+SAG+CA+IIFR+MS (2 9,377.6 69.82 293.06 6,023.1 -3,125.3 -1,952.65,966.9 6,027,948.8 467,916.6 4.1 571.17 MWD+SAG+CA+IIFR+MS (2 9,471.7 69.61 297.16 6,055.8 -3,087.8 -2,032.55,999.6 6,027,986.6 467,836.9 4.1 659.38 MWD+SAG+CA+IIFR+MS (2 9,566.9 70.27 297.91 6,088.4 -3,046.5 -2,111.86,032.2 6,028,028.2 467,757.8 1.0 748.49 MWD+SAG+CA+IIFR+MS (2 9,662.0 71.32 297.99 6,119.7 -3,004.4 -2,191.26,063.5 6,028,070.7 467,678.6 1.1 838.02 MWD+SAG+CA+IIFR+MS (2 9,756.2 70.77 298.58 6,150.3 -2,962.1 -2,269.66,094.1 6,028,113.2 467,600.3 0.8 926.76 MWD+SAG+CA+IIFR+MS (2 9,813.7 71.17 299.23 6,169.1 -2,935.9 -2,317.26,112.9 6,028,139.7 467,552.8 1.3 980.83 MWD+SAG+CA+IIFR+MS (2 9,917.2 71.04 301.92 6,202.6 -2,886.1 -2,401.56,146.4 6,028,189.8 467,468.8 2.5 1,077.90 MWD+SAG+CA+IIFR+MS (2 10,011.7 71.30 305.21 6,233.1 -2,836.6 -2,476.06,176.9 6,028,239.6 467,394.4 3.3 1,165.86 MWD+SAG+CA+IIFR+MS (2 10,107.1 72.54 309.37 6,262.7 -2,781.7 -2,548.26,206.5 6,028,294.8 467,322.5 4.3 1,253.75 MWD+SAG+CA+IIFR+MS (2 10,201.5 75.05 311.55 6,289.0 -2,722.9 -2,617.16,232.8 6,028,353.8 467,253.8 3.5 1,340.20 MWD+SAG+CA+IIFR+MS (2 10,297.8 76.13 312.47 6,313.0 -2,660.5 -2,686.46,256.8 6,028,416.5 467,184.8 1.5 1,428.42 MWD+SAG+CA+IIFR+MS (2 10,392.3 76.38 313.43 6,335.5 -2,597.9 -2,753.66,279.3 6,028,479.3 467,117.9 1.0 1,514.73 MWD+SAG+CA+IIFR+MS (2 10,488.1 76.13 313.59 6,358.2 -2,533.8 -2,821.16,302.0 6,028,543.7 467,050.6 0.3 1,601.98 MWD+SAG+CA+IIFR+MS (2 10,581.7 76.32 313.91 6,380.5 -2,471.0 -2,886.76,324.3 6,028,606.8 466,985.3 0.4 1,687.01 MWD+SAG+CA+IIFR+MS (2 10,635.0 76.32 313.91 6,393.1 -2,435.1 -2,924.06,336.9 6,028,642.9 466,948.1 0.0 1,735.39 PROJECTED to TD 8/24/2009 2:17:23PM COMPASS 2003.16 Build 71 Page 5 24 August, 2009 Oooguruk Developement Oooguruk Drill Site ODSN-36 PB2 Permit to Drill: 207-182 API: 50-703-20561-71 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB2 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Developement Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-36 - Slot ODS-36 ft ft 0.0 0.0 6,031,065.83 469,881.69 13.5Wellhead Elevation:ft0.0 70° 29' 45.399 N 150° 14' 46.595 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) ODSN-36 PB2 Model NameMagnetics IGRF200510 4/9/2009 22.31 80.81 57,729 Phase:Version: Audit Notes: Design ODSN-36 PN10 PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:6,627.0 293.000.00.042.7 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 8/21/2009 Survey Date CB-GYRO-SS Camera based gyro single shot100.0 263.0 ODSN-36 PN10 PB1 Gyro (ODSN-36 PB 3/13/2009 12 MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station305.5 6,627.0 ODSN-36 PN10 PB1 MWD (ODSN-36 P 3/13/2009 12 MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station6,654.5 9,381.3 ODSN-36 PN10 MWD PB2 (ODSN-36 P 4/9/2009 12: MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.7 0.00 0.00 42.7 0.0 0.0-13.5 6,031,065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 0.2 -0.143.8 6,031,066.0 469,881.6 0.7 0.15 CB-GYRO-SS (1) 173.0 0.34 6.40 173.0 0.6 -0.2116.8 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS (1) 263.0 0.12 82.32 263.0 0.9 -0.1206.8 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS (1) 305.5 0.34 85.09 305.5 0.9 0.1249.3 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS (2 395.7 1.67 137.26 395.7 -0.1 1.3339.5 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS (2 489.5 4.21 129.08 489.3 -3.2 4.9433.1 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS (2 580.2 5.08 122.30 579.7 -7.5 10.8523.5 6,031,058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS (2 671.1 6.36 126.84 670.2 -12.6 18.3614.0 6,031,053.1 469,899.9 1.5 -21.76 MWD+SAG+CA+IIFR+MS (2 764.1 6.03 126.15 762.6 -18.6 26.3706.4 6,031,047.1 469,907.9 0.4 -31.52 MWD+SAG+CA+IIFR+MS (2 859.5 6.88 128.79 857.4 -25.2 34.8801.2 6,031,040.5 469,916.4 0.9 -41.89 MWD+SAG+CA+IIFR+MS (2 948.9 7.50 128.01 946.1 -32.1 43.6889.9 6,031,033.6 469,925.2 0.7 -52.68 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:18:21PM COMPASS 2003.16 Build 71 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB2 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,043.5 9.23 133.51 1,039.7 -41.1 54.0983.5 6,031,024.5 469,935.5 2.0 -65.75 MWD+SAG+CA+IIFR+MS (2 1,139.9 11.67 130.99 1,134.5 -52.8 66.91,078.3 6,031,012.7 469,948.4 2.6 -82.27 MWD+SAG+CA+IIFR+MS (2 1,236.3 15.41 132.58 1,228.2 -67.9 83.71,172.0 6,030,997.6 469,965.2 3.9 -103.63 MWD+SAG+CA+IIFR+MS (2 1,286.8 18.40 133.42 1,276.6 -77.9 94.51,220.4 6,030,987.5 469,975.9 5.9 -117.43 MWD+SAG+CA+IIFR+MS (2 1,332.9 20.25 132.03 1,320.0 -88.3 105.71,263.8 6,030,977.1 469,987.0 4.1 -131.78 MWD+SAG+CA+IIFR+MS (2 1,429.6 23.87 135.45 1,409.7 -113.4 131.91,353.5 6,030,951.9 470,013.1 4.0 -165.69 MWD+SAG+CA+IIFR+MS (2 1,477.4 27.27 133.74 1,452.8 -127.9 146.61,396.6 6,030,937.3 470,027.7 7.3 -184.89 MWD+SAG+CA+IIFR+MS (2 1,526.1 29.56 132.65 1,495.6 -143.7 163.41,439.4 6,030,921.4 470,044.5 4.8 -206.61 MWD+SAG+CA+IIFR+MS (2 1,623.1 33.50 131.69 1,578.2 -177.8 201.01,522.0 6,030,887.3 470,082.0 4.1 -254.52 MWD+SAG+CA+IIFR+MS (2 1,719.4 38.04 132.23 1,656.4 -215.4 242.91,600.2 6,030,849.4 470,123.7 4.7 -307.75 MWD+SAG+CA+IIFR+MS (2 1,816.4 39.04 132.22 1,732.2 -256.0 287.61,676.0 6,030,808.7 470,168.3 1.0 -364.82 MWD+SAG+CA+IIFR+MS (2 1,913.6 38.51 133.70 1,808.0 -297.5 332.21,751.8 6,030,767.0 470,212.6 1.1 -422.03 MWD+SAG+CA+IIFR+MS (2 2,008.2 36.95 136.81 1,882.8 -338.6 372.91,826.6 6,030,725.8 470,253.2 2.6 -475.59 MWD+SAG+CA+IIFR+MS (2 2,104.6 38.08 140.89 1,959.3 -382.8 411.61,903.1 6,030,681.4 470,291.7 2.8 -528.42 MWD+SAG+CA+IIFR+MS (2 2,201.8 39.39 147.75 2,035.2 -432.2 446.91,979.0 6,030,631.9 470,326.8 4.6 -580.26 MWD+SAG+CA+IIFR+MS (2 2,298.1 41.01 151.13 2,108.7 -485.7 478.52,052.5 6,030,578.3 470,358.2 2.8 -630.23 MWD+SAG+CA+IIFR+MS (2 2,396.0 40.88 152.82 2,182.7 -542.3 508.62,126.5 6,030,521.5 470,388.1 1.1 -680.10 MWD+SAG+CA+IIFR+MS (2 2,491.7 42.54 154.78 2,254.1 -599.4 536.72,197.9 6,030,464.3 470,415.9 2.2 -728.28 MWD+SAG+CA+IIFR+MS (2 2,587.9 44.85 156.23 2,323.7 -659.9 564.32,267.5 6,030,403.7 470,443.2 2.6 -777.26 MWD+SAG+CA+IIFR+MS (2 2,634.7 47.29 157.78 2,356.1 -690.9 577.42,299.9 6,030,372.6 470,456.2 5.7 -801.49 MWD+SAG+CA+IIFR+MS (2 2,684.5 51.29 157.87 2,388.6 -725.9 591.72,332.4 6,030,337.6 470,470.3 8.0 -828.26 MWD+SAG+CA+IIFR+MS (2 2,732.3 53.75 159.28 2,417.7 -761.2 605.52,361.5 6,030,302.2 470,484.1 5.7 -854.82 MWD+SAG+CA+IIFR+MS (2 2,781.0 55.96 162.61 2,445.7 -798.8 618.52,389.5 6,030,264.6 470,496.9 7.2 -881.45 MWD+SAG+CA+IIFR+MS (2 2,828.3 56.38 162.38 2,472.1 -836.3 630.32,415.9 6,030,227.0 470,508.6 1.0 -907.00 MWD+SAG+CA+IIFR+MS (2 2,877.9 57.18 163.23 2,499.3 -876.0 642.62,443.1 6,030,187.4 470,520.7 2.2 -933.76 MWD+SAG+CA+IIFR+MS (2 2,974.2 57.45 166.81 2,551.3 -954.2 663.52,495.1 6,030,109.0 470,541.3 3.1 -983.62 MWD+SAG+CA+IIFR+MS (2 3,070.5 53.94 166.00 2,605.5 -1,031.5 682.22,549.3 6,030,031.7 470,559.6 3.7 -1,031.01 MWD+SAG+CA+IIFR+MS (2 3,166.8 49.33 165.38 2,665.3 -1,104.7 700.82,609.1 6,029,958.5 470,578.0 4.8 -1,076.75 MWD+SAG+CA+IIFR+MS (2 3,263.5 47.48 164.96 2,729.5 -1,174.6 719.42,673.3 6,029,888.4 470,596.2 1.9 -1,121.13 MWD+SAG+CA+IIFR+MS (2 3,360.9 46.77 162.67 2,795.8 -1,243.1 739.22,739.6 6,029,819.8 470,615.8 1.9 -1,166.20 MWD+SAG+CA+IIFR+MS (2 3,457.7 45.27 162.67 2,863.0 -1,309.7 760.02,806.8 6,029,753.2 470,636.3 1.5 -1,211.31 MWD+SAG+CA+IIFR+MS (2 3,554.2 42.57 163.25 2,932.5 -1,373.7 779.62,876.3 6,029,689.2 470,655.7 2.8 -1,254.37 MWD+SAG+CA+IIFR+MS (2 3,634.0 42.77 162.93 2,991.2 -1,425.4 795.32,935.0 6,029,637.4 470,671.2 0.4 -1,289.07 MWD+SAG+CA+IIFR+MS (2 3,686.7 43.44 161.54 3,029.6 -1,459.6 806.32,973.4 6,029,603.1 470,682.0 2.2 -1,312.56 MWD+SAG+CA+IIFR+MS (2 3,740.0 44.21 162.62 3,068.1 -1,494.8 817.73,011.9 6,029,567.9 470,693.2 2.0 -1,336.76 MWD+SAG+CA+IIFR+MS (2 3,783.5 44.72 161.58 3,099.1 -1,523.8 827.13,042.9 6,029,538.9 470,702.5 2.0 -1,356.70 MWD+SAG+CA+IIFR+MS (2 3,878.2 44.25 161.84 3,166.7 -1,586.8 847.93,110.5 6,029,475.8 470,723.1 0.5 -1,400.49 MWD+SAG+CA+IIFR+MS (2 3,972.8 44.56 162.68 3,234.3 -1,649.8 868.03,178.1 6,029,412.7 470,743.0 0.7 -1,443.67 MWD+SAG+CA+IIFR+MS (2 4,068.1 46.87 164.02 3,300.8 -1,715.2 887.63,244.6 6,029,347.3 470,762.2 2.6 -1,487.18 MWD+SAG+CA+IIFR+MS (2 4,164.0 49.70 166.27 3,364.6 -1,784.3 905.93,308.4 6,029,278.0 470,780.2 3.4 -1,531.07 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:18:21PM COMPASS 2003.16 Build 71 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB2 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,257.7 50.65 168.64 3,424.7 -1,854.6 921.53,368.5 6,029,207.7 470,795.6 2.2 -1,572.93 MWD+SAG+CA+IIFR+MS (2 4,351.7 50.91 170.49 3,484.1 -1,926.2 934.73,427.9 6,029,136.0 470,808.5 1.5 -1,613.04 MWD+SAG+CA+IIFR+MS (2 4,446.8 52.02 172.32 3,543.4 -1,999.8 945.83,487.2 6,029,062.4 470,819.3 1.9 -1,652.01 MWD+SAG+CA+IIFR+MS (2 4,541.3 52.94 173.13 3,600.9 -2,074.1 955.33,544.7 6,028,988.1 470,828.5 1.2 -1,689.77 MWD+SAG+CA+IIFR+MS (2 4,635.8 53.17 172.12 3,657.7 -2,149.1 965.03,601.5 6,028,913.1 470,837.9 0.9 -1,727.98 MWD+SAG+CA+IIFR+MS (2 4,730.9 51.72 172.49 3,715.6 -2,223.7 975.13,659.4 6,028,838.4 470,847.7 1.6 -1,766.45 MWD+SAG+CA+IIFR+MS (2 4,826.3 52.12 173.04 3,774.5 -2,298.2 984.53,718.3 6,028,763.9 470,856.8 0.6 -1,804.25 MWD+SAG+CA+IIFR+MS (2 4,919.9 52.67 176.70 3,831.6 -2,372.1 991.23,775.4 6,028,690.0 470,863.1 3.2 -1,839.21 MWD+SAG+CA+IIFR+MS (2 5,013.4 51.64 177.77 3,889.0 -2,445.8 994.73,832.8 6,028,616.3 470,866.4 1.4 -1,871.31 MWD+SAG+CA+IIFR+MS (2 5,108.7 50.87 180.12 3,948.6 -2,520.1 996.13,892.4 6,028,542.0 470,867.5 2.1 -1,901.59 MWD+SAG+CA+IIFR+MS (2 5,204.8 52.37 179.20 4,008.3 -2,595.5 996.63,952.1 6,028,466.6 470,867.6 1.7 -1,931.46 MWD+SAG+CA+IIFR+MS (2 5,299.1 51.17 181.09 4,066.7 -2,669.5 996.44,010.5 6,028,392.5 470,867.1 2.0 -1,960.25 MWD+SAG+CA+IIFR+MS (2 5,395.2 50.26 184.27 4,127.5 -2,743.8 992.94,071.3 6,028,318.3 470,863.4 2.7 -1,986.08 MWD+SAG+CA+IIFR+MS (2 5,491.6 49.33 189.57 4,189.8 -2,816.9 984.14,133.6 6,028,245.3 470,854.2 4.3 -2,006.48 MWD+SAG+CA+IIFR+MS (2 5,586.7 50.07 194.04 4,251.3 -2,887.8 969.24,195.1 6,028,174.4 470,839.1 3.7 -2,020.54 MWD+SAG+CA+IIFR+MS (2 5,679.3 50.76 199.12 4,310.3 -2,956.1 948.94,254.1 6,028,106.2 470,818.5 4.3 -2,028.50 MWD+SAG+CA+IIFR+MS (2 5,773.9 50.69 203.95 4,370.3 -3,024.3 922.04,314.1 6,028,038.2 470,791.3 4.0 -2,030.37 MWD+SAG+CA+IIFR+MS (2 5,868.4 51.20 209.30 4,429.8 -3,089.8 889.14,373.6 6,027,972.7 470,758.2 4.4 -2,025.72 MWD+SAG+CA+IIFR+MS (2 5,962.8 52.70 212.82 4,488.0 -3,153.4 850.84,431.8 6,027,909.3 470,719.6 3.3 -2,015.29 MWD+SAG+CA+IIFR+MS (2 6,058.1 50.71 217.72 4,547.1 -3,214.5 807.64,490.9 6,027,848.4 470,676.2 4.5 -1,999.43 MWD+SAG+CA+IIFR+MS (2 6,151.9 50.37 223.81 4,606.7 -3,269.3 760.44,550.5 6,027,793.8 470,628.7 5.0 -1,977.36 MWD+SAG+CA+IIFR+MS (2 6,246.5 50.36 228.36 4,667.0 -3,319.8 708.04,610.8 6,027,743.5 470,576.1 3.7 -1,948.84 MWD+SAG+CA+IIFR+MS (2 6,341.8 49.80 232.42 4,728.2 -3,366.4 651.74,672.0 6,027,697.2 470,519.7 3.3 -1,915.23 MWD+SAG+CA+IIFR+MS (2 6,437.5 51.82 235.29 4,788.7 -3,410.1 591.84,732.5 6,027,653.7 470,459.6 3.1 -1,877.17 MWD+SAG+CA+IIFR+MS (2 6,532.2 50.20 239.91 4,848.3 -3,449.5 529.74,792.1 6,027,614.5 470,397.4 4.2 -1,835.43 MWD+SAG+CA+IIFR+MS (2 6,627.0 50.55 243.97 4,908.8 -3,483.9 465.34,852.6 6,027,580.4 470,332.8 3.3 -1,789.53 MWD+SAG+CA+IIFR+MS (2 6,654.5 50.49 244.25 4,926.3 -3,493.2 446.24,870.1 6,027,571.2 470,313.6 0.8 -1,775.58 MWD+SAG+CA+IIFR+MS (3 6,686.3 52.76 246.15 4,946.0 -3,503.6 423.54,889.8 6,027,560.9 470,291.0 8.5 -1,758.81 MWD+SAG+CA+IIFR+MS (3 6,782.2 55.63 251.00 5,002.1 -3,531.9 351.24,945.9 6,027,532.8 470,218.5 5.1 -1,703.29 MWD+SAG+CA+IIFR+MS (3 6,876.6 54.28 253.85 5,056.4 -3,555.3 277.55,000.2 6,027,509.8 470,144.8 2.9 -1,644.61 MWD+SAG+CA+IIFR+MS (3 6,971.2 51.61 257.61 5,113.4 -3,573.9 204.45,057.2 6,027,491.5 470,071.6 4.2 -1,584.58 MWD+SAG+CA+IIFR+MS (3 7,067.0 49.92 260.74 5,174.0 -3,587.9 131.55,117.8 6,027,477.8 469,998.7 3.1 -1,522.97 MWD+SAG+CA+IIFR+MS (3 7,162.4 51.25 265.73 5,234.6 -3,596.5 58.45,178.4 6,027,469.4 469,925.5 4.3 -1,459.01 MWD+SAG+CA+IIFR+MS (3 7,256.9 51.60 270.98 5,293.5 -3,598.6 -15.45,237.3 6,027,467.6 469,851.7 4.4 -1,391.90 MWD+SAG+CA+IIFR+MS (3 7,351.9 52.02 274.61 5,352.3 -3,595.0 -90.05,296.1 6,027,471.6 469,777.1 3.0 -1,321.85 MWD+SAG+CA+IIFR+MS (3 7,446.3 52.16 277.90 5,410.3 -3,586.9 -164.05,354.1 6,027,480.0 469,703.2 2.8 -1,250.54 MWD+SAG+CA+IIFR+MS (3 7,540.7 53.71 281.06 5,467.2 -3,574.5 -238.35,411.0 6,027,492.7 469,629.0 3.1 -1,177.32 MWD+SAG+CA+IIFR+MS (3 7,636.1 55.23 283.24 5,522.6 -3,558.1 -314.25,466.4 6,027,509.4 469,553.1 2.4 -1,101.07 MWD+SAG+CA+IIFR+MS (3 7,732.2 57.41 287.13 5,575.9 -3,537.1 -391.35,519.7 6,027,530.7 469,476.1 4.1 -1,021.87 MWD+SAG+CA+IIFR+MS (3 7,827.4 58.66 290.28 5,626.3 -3,511.2 -467.85,570.1 6,027,556.9 469,399.7 3.1 -941.35 MWD+SAG+CA+IIFR+MS (3 8/24/2009 2:18:21PM COMPASS 2003.16 Build 71 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 PB2 Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,922.1 61.18 292.40 5,673.8 -3,481.4 -544.15,617.6 6,027,587.0 469,323.6 3.3 -859.45 MWD+SAG+CA+IIFR+MS (3 8,017.1 63.37 294.18 5,718.0 -3,448.1 -621.35,661.8 6,027,620.6 469,246.5 2.8 -775.37 MWD+SAG+CA+IIFR+MS (3 8,112.6 66.23 295.66 5,758.6 -3,411.7 -699.75,702.4 6,027,657.3 469,168.3 3.3 -689.02 MWD+SAG+CA+IIFR+MS (3 8,206.7 68.61 297.90 5,794.8 -3,372.6 -777.25,738.6 6,027,696.8 469,090.9 3.4 -602.34 MWD+SAG+CA+IIFR+MS (3 8,301.6 71.18 300.93 5,827.4 -3,328.8 -854.85,771.2 6,027,740.9 469,013.5 4.0 -513.80 MWD+SAG+CA+IIFR+MS (3 8,395.5 73.48 302.46 5,855.9 -3,281.8 -930.95,799.7 6,027,788.2 468,937.6 2.9 -425.37 MWD+SAG+CA+IIFR+MS (3 8,491.2 75.57 304.79 5,881.4 -3,230.7 -1,007.75,825.2 6,027,839.6 468,861.0 3.2 -334.73 MWD+SAG+CA+IIFR+MS (3 8,586.2 76.26 308.29 5,904.6 -3,175.9 -1,081.75,848.4 6,027,894.7 468,787.2 3.6 -245.17 MWD+SAG+CA+IIFR+MS (3 8,682.1 76.92 310.09 5,926.8 -3,116.9 -1,154.05,870.6 6,027,953.9 468,715.2 2.0 -155.59 MWD+SAG+CA+IIFR+MS (3 8,775.5 76.90 312.06 5,948.0 -3,057.1 -1,222.65,891.8 6,028,014.0 468,646.8 2.1 -69.11 MWD+SAG+CA+IIFR+MS (3 8,871.6 76.28 315.95 5,970.3 -2,992.2 -1,289.85,914.1 6,028,079.2 468,579.9 4.0 18.14 MWD+SAG+CA+IIFR+MS (3 8,965.7 76.26 317.19 5,992.6 -2,925.8 -1,352.75,936.4 6,028,145.8 468,517.3 1.3 101.92 MWD+SAG+CA+IIFR+MS (3 9,060.8 76.03 319.07 6,015.4 -2,857.1 -1,414.35,959.2 6,028,214.8 468,456.0 1.9 185.51 MWD+SAG+CA+IIFR+MS (3 9,155.1 75.76 320.26 6,038.4 -2,787.4 -1,473.55,982.2 6,028,284.7 468,397.1 1.3 267.24 MWD+SAG+CA+IIFR+MS (3 9,250.0 76.85 322.70 6,060.8 -2,715.2 -1,530.96,004.6 6,028,357.1 468,340.0 2.7 348.28 MWD+SAG+CA+IIFR+MS (3 9,291.4 76.74 322.11 6,070.3 -2,683.3 -1,555.56,014.1 6,028,389.1 468,315.5 1.4 383.39 MWD+SAG+CA+IIFR+MS (3 9,381.3 77.95 319.13 6,090.0 -2,615.5 -1,611.16,033.8 6,028,457.1 468,260.1 3.5 461.10 MWD+SAG+CA+IIFR+MS (3 9,509.0 77.95 319.13 6,116.6 -2,521.1 -1,692.96,060.4 6,028,551.9 468,178.8 0.0 573.22 PROJECTED to TD 8/24/2009 2:18:21PM COMPASS 2003.16 Build 71 Page 5 24 August, 2009 Oooguruk Developement Oooguruk Drill Site ODSN-36 Permit to Drill: 207-182 API: 50-703-20561-00 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Developement Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-36 - Slot ODS-36 ft ft 0.0 0.0 6,031,065.83 469,881.69 13.5Wellhead Elevation:ft0.0 70° 29' 45.399 N 150° 14' 46.595 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) ODSN-36 Model NameMagnetics IGRF200510 2/25/2009 22.36 80.81 57,724 Phase:Version: Audit Notes: Design ODSN-36 PN10 Surveys 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:6,740.0 293.080.00.042.7 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 8/21/2009 Survey Date CB-GYRO-SS Camera based gyro single shot100.0 263.0 ODSN-36 PN10 PB1 Gyro (ODSN-36 PB 3/13/2009 12 MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station305.5 6,627.0 ODSN-36 PN10 PB1 MWD (ODSN-36 P 3/13/2009 12 MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station6,654.5 6,740.0 ODSN-36 PN10 MWD PB2 (ODSN-36 P 4/9/2009 12: MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station6,782.0 17,423.2 ODSN-36 Surveys _ MWD (ODSN-36)3/20/2009 12 MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.7 0.00 0.00 42.7 0.0 0.0-13.5 6,031,065.8 469,881.7 0.0 0.00 UNDEFINED 100.0 0.38 330.00 100.0 0.2 -0.143.8 6,031,066.0 469,881.6 0.7 0.15 CB-GYRO-SS (1) 173.0 0.34 6.40 173.0 0.6 -0.2116.8 6,031,066.4 469,881.5 0.3 0.41 CB-GYRO-SS (1) 263.0 0.12 82.32 263.0 0.9 -0.1206.8 6,031,066.7 469,881.6 0.4 0.40 CB-GYRO-SS (1) 305.5 0.34 85.09 305.5 0.9 0.1249.3 6,031,066.7 469,881.8 0.5 0.25 MWD+SAG+CA+IIFR+MS (2 395.7 1.67 137.26 395.7 -0.1 1.3339.5 6,031,065.8 469,882.9 1.6 -1.18 MWD+SAG+CA+IIFR+MS (2 489.5 4.21 129.08 489.3 -3.2 4.9433.1 6,031,062.6 469,886.5 2.7 -5.74 MWD+SAG+CA+IIFR+MS (2 580.2 5.08 122.30 579.7 -7.5 10.8523.5 6,031,058.3 469,892.5 1.1 -12.90 MWD+SAG+CA+IIFR+MS (2 671.1 6.36 126.84 670.2 -12.6 18.3614.0 6,031,053.1 469,899.9 1.5 -21.77 MWD+SAG+CA+IIFR+MS (2 764.1 6.03 126.15 762.6 -18.6 26.3706.4 6,031,047.1 469,907.9 0.4 -31.53 MWD+SAG+CA+IIFR+MS (2 859.5 6.88 128.79 857.4 -25.2 34.8801.2 6,031,040.5 469,916.4 0.9 -41.91 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 948.9 7.50 128.01 946.1 -32.1 43.6889.9 6,031,033.6 469,925.2 0.7 -52.70 MWD+SAG+CA+IIFR+MS (2 1,043.5 9.23 133.51 1,039.7 -41.1 54.0983.5 6,031,024.5 469,935.5 2.0 -65.78 MWD+SAG+CA+IIFR+MS (2 1,139.9 11.67 130.99 1,134.5 -52.8 66.91,078.3 6,031,012.7 469,948.4 2.6 -82.30 MWD+SAG+CA+IIFR+MS (2 1,236.3 15.41 132.58 1,228.2 -67.9 83.71,172.0 6,030,997.6 469,965.2 3.9 -103.67 MWD+SAG+CA+IIFR+MS (2 1,286.8 18.40 133.42 1,276.6 -77.9 94.51,220.4 6,030,987.5 469,975.9 5.9 -117.48 MWD+SAG+CA+IIFR+MS (2 1,332.9 20.25 132.03 1,320.0 -88.3 105.71,263.8 6,030,977.1 469,987.0 4.1 -131.83 MWD+SAG+CA+IIFR+MS (2 1,429.6 23.87 135.45 1,409.7 -113.4 131.91,353.5 6,030,951.9 470,013.1 4.0 -165.77 MWD+SAG+CA+IIFR+MS (2 1,477.4 27.27 133.74 1,452.8 -127.9 146.61,396.6 6,030,937.3 470,027.7 7.3 -184.97 MWD+SAG+CA+IIFR+MS (2 1,526.1 29.56 132.65 1,495.6 -143.7 163.41,439.4 6,030,921.4 470,044.5 4.8 -206.71 MWD+SAG+CA+IIFR+MS (2 1,623.1 33.50 131.69 1,578.2 -177.8 201.01,522.0 6,030,887.3 470,082.0 4.1 -254.64 MWD+SAG+CA+IIFR+MS (2 1,719.4 38.04 132.23 1,656.4 -215.4 242.91,600.2 6,030,849.4 470,123.7 4.7 -307.90 MWD+SAG+CA+IIFR+MS (2 1,816.4 39.04 132.22 1,732.2 -256.0 287.61,676.0 6,030,808.7 470,168.3 1.0 -364.99 MWD+SAG+CA+IIFR+MS (2 1,913.6 38.51 133.70 1,808.0 -297.5 332.21,751.8 6,030,767.0 470,212.6 1.1 -422.23 MWD+SAG+CA+IIFR+MS (2 2,008.2 36.95 136.81 1,882.8 -338.6 372.91,826.6 6,030,725.8 470,253.2 2.6 -475.82 MWD+SAG+CA+IIFR+MS (2 2,104.6 38.08 140.89 1,959.3 -382.8 411.61,903.1 6,030,681.4 470,291.7 2.8 -528.68 MWD+SAG+CA+IIFR+MS (2 2,201.8 39.39 147.75 2,035.2 -432.2 446.91,979.0 6,030,631.9 470,326.8 4.6 -580.57 MWD+SAG+CA+IIFR+MS (2 2,298.1 41.01 151.13 2,108.7 -485.7 478.52,052.5 6,030,578.3 470,358.2 2.8 -630.59 MWD+SAG+CA+IIFR+MS (2 2,396.0 40.88 152.82 2,182.7 -542.3 508.62,126.5 6,030,521.5 470,388.1 1.1 -680.52 MWD+SAG+CA+IIFR+MS (2 2,491.7 42.54 154.78 2,254.1 -599.4 536.72,197.9 6,030,464.3 470,415.9 2.2 -728.76 MWD+SAG+CA+IIFR+MS (2 2,587.9 44.85 156.23 2,323.7 -659.9 564.32,267.5 6,030,403.7 470,443.2 2.6 -777.80 MWD+SAG+CA+IIFR+MS (2 2,634.7 47.29 157.78 2,356.1 -690.9 577.42,299.9 6,030,372.6 470,456.2 5.7 -802.06 MWD+SAG+CA+IIFR+MS (2 2,684.5 51.29 157.87 2,388.6 -725.9 591.72,332.4 6,030,337.6 470,470.3 8.0 -828.87 MWD+SAG+CA+IIFR+MS (2 2,732.3 53.75 159.28 2,417.7 -761.2 605.52,361.5 6,030,302.2 470,484.1 5.7 -855.47 MWD+SAG+CA+IIFR+MS (2 2,781.0 55.96 162.61 2,445.7 -798.8 618.52,389.5 6,030,264.6 470,496.9 7.2 -882.13 MWD+SAG+CA+IIFR+MS (2 2,828.3 56.38 162.38 2,472.1 -836.3 630.32,415.9 6,030,227.0 470,508.6 1.0 -907.73 MWD+SAG+CA+IIFR+MS (2 2,877.9 57.18 163.23 2,499.3 -876.0 642.62,443.1 6,030,187.4 470,520.7 2.2 -934.54 MWD+SAG+CA+IIFR+MS (2 2,974.2 57.45 166.81 2,551.3 -954.2 663.52,495.1 6,030,109.0 470,541.3 3.1 -984.49 MWD+SAG+CA+IIFR+MS (2 3,070.5 53.94 166.00 2,605.5 -1,031.5 682.22,549.3 6,030,031.7 470,559.6 3.7 -1,031.96 MWD+SAG+CA+IIFR+MS (2 3,166.8 49.33 165.38 2,665.3 -1,104.7 700.82,609.1 6,029,958.5 470,578.0 4.8 -1,077.79 MWD+SAG+CA+IIFR+MS (2 3,263.5 47.48 164.96 2,729.5 -1,174.6 719.42,673.3 6,029,888.4 470,596.2 1.9 -1,122.24 MWD+SAG+CA+IIFR+MS (2 3,360.9 46.77 162.67 2,795.8 -1,243.1 739.22,739.6 6,029,819.8 470,615.8 1.9 -1,167.39 MWD+SAG+CA+IIFR+MS (2 3,457.7 45.27 162.67 2,863.0 -1,309.7 760.02,806.8 6,029,753.2 470,636.3 1.5 -1,212.57 MWD+SAG+CA+IIFR+MS (2 3,554.2 42.57 163.25 2,932.5 -1,373.7 779.62,876.3 6,029,689.2 470,655.7 2.8 -1,255.71 MWD+SAG+CA+IIFR+MS (2 3,634.0 42.77 162.93 2,991.2 -1,425.4 795.32,935.0 6,029,637.4 470,671.2 0.4 -1,290.46 MWD+SAG+CA+IIFR+MS (2 3,686.7 43.44 161.54 3,029.6 -1,459.6 806.32,973.4 6,029,603.1 470,682.0 2.2 -1,313.99 MWD+SAG+CA+IIFR+MS (2 3,740.0 44.21 162.62 3,068.1 -1,494.8 817.73,011.9 6,029,567.9 470,693.2 2.0 -1,338.23 MWD+SAG+CA+IIFR+MS (2 3,783.5 44.72 161.58 3,099.1 -1,523.8 827.13,042.9 6,029,538.9 470,702.5 2.0 -1,358.20 MWD+SAG+CA+IIFR+MS (2 3,878.2 44.25 161.84 3,166.7 -1,586.8 847.93,110.5 6,029,475.8 470,723.1 0.5 -1,402.07 MWD+SAG+CA+IIFR+MS (2 3,972.8 44.56 162.68 3,234.3 -1,649.8 868.03,178.1 6,029,412.7 470,743.0 0.7 -1,445.32 MWD+SAG+CA+IIFR+MS (2 4,068.1 46.87 164.02 3,300.8 -1,715.2 887.63,244.6 6,029,347.3 470,762.2 2.6 -1,488.90 MWD+SAG+CA+IIFR+MS (2 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,164.0 49.70 166.27 3,364.6 -1,784.3 905.93,308.4 6,029,278.0 470,780.2 3.4 -1,532.87 MWD+SAG+CA+IIFR+MS (2 4,257.7 50.65 168.64 3,424.7 -1,854.6 921.53,368.5 6,029,207.7 470,795.6 2.2 -1,574.81 MWD+SAG+CA+IIFR+MS (2 4,351.7 50.91 170.49 3,484.1 -1,926.2 934.73,427.9 6,029,136.0 470,808.5 1.5 -1,615.00 MWD+SAG+CA+IIFR+MS (2 4,446.8 52.02 172.32 3,543.4 -1,999.8 945.83,487.2 6,029,062.4 470,819.3 1.9 -1,654.06 MWD+SAG+CA+IIFR+MS (2 4,541.3 52.94 173.13 3,600.9 -2,074.1 955.33,544.7 6,028,988.1 470,828.5 1.2 -1,691.91 MWD+SAG+CA+IIFR+MS (2 4,635.8 53.17 172.12 3,657.7 -2,149.1 965.03,601.5 6,028,913.1 470,837.9 0.9 -1,730.22 MWD+SAG+CA+IIFR+MS (2 4,730.9 51.72 172.49 3,715.6 -2,223.7 975.13,659.4 6,028,838.4 470,847.7 1.6 -1,768.77 MWD+SAG+CA+IIFR+MS (2 4,826.3 52.12 173.04 3,774.5 -2,298.2 984.53,718.3 6,028,763.9 470,856.8 0.6 -1,806.66 MWD+SAG+CA+IIFR+MS (2 4,919.9 52.67 176.70 3,831.6 -2,372.1 991.23,775.4 6,028,690.0 470,863.1 3.2 -1,841.72 MWD+SAG+CA+IIFR+MS (2 5,013.4 51.64 177.77 3,889.0 -2,445.8 994.73,832.8 6,028,616.3 470,866.4 1.4 -1,873.90 MWD+SAG+CA+IIFR+MS (2 5,108.7 50.87 180.12 3,948.6 -2,520.1 996.13,892.4 6,028,542.0 470,867.5 2.1 -1,904.29 MWD+SAG+CA+IIFR+MS (2 5,204.8 52.37 179.20 4,008.3 -2,595.5 996.63,952.1 6,028,466.6 470,867.6 1.7 -1,934.25 MWD+SAG+CA+IIFR+MS (2 5,299.1 51.17 181.09 4,066.7 -2,669.5 996.44,010.5 6,028,392.5 470,867.1 2.0 -1,963.13 MWD+SAG+CA+IIFR+MS (2 5,395.2 50.26 184.27 4,127.5 -2,743.8 992.94,071.3 6,028,318.3 470,863.4 2.7 -1,989.06 MWD+SAG+CA+IIFR+MS (2 5,491.6 49.33 189.57 4,189.8 -2,816.9 984.14,133.6 6,028,245.3 470,854.2 4.3 -2,009.56 MWD+SAG+CA+IIFR+MS (2 5,586.7 50.07 194.04 4,251.3 -2,887.8 969.24,195.1 6,028,174.4 470,839.1 3.7 -2,023.72 MWD+SAG+CA+IIFR+MS (2 5,679.3 50.76 199.12 4,310.3 -2,956.1 948.94,254.1 6,028,106.2 470,818.5 4.3 -2,031.78 MWD+SAG+CA+IIFR+MS (2 5,773.9 50.69 203.95 4,370.3 -3,024.3 922.04,314.1 6,028,038.2 470,791.3 4.0 -2,033.75 MWD+SAG+CA+IIFR+MS (2 5,868.4 51.20 209.30 4,429.8 -3,089.8 889.14,373.6 6,027,972.7 470,758.2 4.4 -2,029.21 MWD+SAG+CA+IIFR+MS (2 5,962.8 52.70 212.82 4,488.0 -3,153.4 850.84,431.8 6,027,909.3 470,719.6 3.3 -2,018.87 MWD+SAG+CA+IIFR+MS (2 6,058.1 50.71 217.72 4,547.1 -3,214.5 807.64,490.9 6,027,848.4 470,676.2 4.5 -2,003.12 MWD+SAG+CA+IIFR+MS (2 6,151.9 50.37 223.81 4,606.7 -3,269.3 760.44,550.5 6,027,793.8 470,628.7 5.0 -1,981.15 MWD+SAG+CA+IIFR+MS (2 6,246.5 50.36 228.36 4,667.0 -3,319.8 708.04,610.8 6,027,743.5 470,576.1 3.7 -1,952.72 MWD+SAG+CA+IIFR+MS (2 6,341.8 49.80 232.42 4,728.2 -3,366.4 651.74,672.0 6,027,697.2 470,519.7 3.3 -1,919.20 MWD+SAG+CA+IIFR+MS (2 6,437.5 51.82 235.29 4,788.7 -3,410.1 591.84,732.5 6,027,653.7 470,459.6 3.1 -1,881.23 MWD+SAG+CA+IIFR+MS (2 6,532.2 50.20 239.91 4,848.3 -3,449.5 529.74,792.1 6,027,614.5 470,397.4 4.2 -1,839.58 MWD+SAG+CA+IIFR+MS (2 6,627.0 50.55 243.97 4,908.8 -3,483.9 465.34,852.6 6,027,580.4 470,332.8 3.3 -1,793.76 MWD+SAG+CA+IIFR+MS (2 6,654.5 50.49 244.25 4,926.3 -3,493.2 446.24,870.1 6,027,571.2 470,313.6 0.8 -1,779.82 MWD+SAG+CA+IIFR+MS (3 6,686.3 52.76 246.15 4,946.0 -3,503.6 423.54,889.8 6,027,560.9 470,291.0 8.5 -1,763.08 MWD+SAG+CA+IIFR+MS (3 6,740.0 54.34 248.91 4,977.9 -3,520.1 383.64,921.7 6,027,544.6 470,251.0 5.1 -1,732.86 MWD+SAG+CA+IIFR+MS (3 6,782.0 56.23 247.91 5,001.8 -3,532.8 351.54,945.6 6,027,532.0 470,218.9 4.9 -1,708.31 MWD+SAG+CA+IIFR+MS (4 6,845.5 56.70 249.78 5,037.0 -3,551.9 302.14,980.8 6,027,513.1 470,169.4 2.6 -1,670.36 MWD+SAG+CA+IIFR+MS (4 6,940.8 56.32 253.84 5,089.5 -3,576.7 226.75,033.3 6,027,488.6 470,093.9 3.6 -1,610.70 MWD+SAG+CA+IIFR+MS (4 7,035.0 56.91 256.56 5,141.4 -3,596.8 150.65,085.2 6,027,468.8 470,017.7 2.5 -1,548.59 MWD+SAG+CA+IIFR+MS (4 7,128.1 56.74 259.29 5,192.3 -3,613.1 74.45,136.1 6,027,452.8 469,941.5 2.5 -1,484.88 MWD+SAG+CA+IIFR+MS (4 7,221.9 57.22 264.10 5,243.4 -3,624.4 -3.35,187.2 6,027,441.8 469,863.7 4.3 -1,417.80 MWD+SAG+CA+IIFR+MS (4 7,317.4 57.73 268.15 5,294.8 -3,629.9 -83.65,238.6 6,027,436.7 469,783.4 3.6 -1,346.03 MWD+SAG+CA+IIFR+MS (4 7,411.0 58.81 271.86 5,344.0 -3,629.9 -163.25,287.8 6,027,437.0 469,703.8 3.6 -1,272.83 MWD+SAG+CA+IIFR+MS (4 7,502.9 60.16 274.23 5,390.7 -3,625.6 -242.35,334.5 6,027,441.6 469,624.8 2.7 -1,198.44 MWD+SAG+CA+IIFR+MS (4 7,597.8 61.52 277.72 5,437.0 -3,617.0 -324.75,380.8 6,027,450.5 469,542.4 3.5 -1,119.19 MWD+SAG+CA+IIFR+MS (4 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,692.3 61.80 280.85 5,481.8 -3,603.6 -406.75,425.6 6,027,464.3 469,460.4 2.9 -1,038.49 MWD+SAG+CA+IIFR+MS (4 7,786.1 62.15 282.77 5,525.9 -3,586.6 -487.85,469.7 6,027,481.6 469,379.4 1.8 -957.26 MWD+SAG+CA+IIFR+MS (4 7,881.1 62.69 285.84 5,569.9 -3,565.8 -569.45,513.7 6,027,502.7 469,297.9 2.9 -874.03 MWD+SAG+CA+IIFR+MS (4 7,977.6 64.10 288.51 5,613.1 -3,540.3 -651.75,556.9 6,027,528.5 469,215.7 2.9 -788.29 MWD+SAG+CA+IIFR+MS (4 8,071.4 65.72 291.71 5,652.9 -3,511.1 -731.55,596.7 6,027,558.1 469,136.0 3.5 -703.44 MWD+SAG+CA+IIFR+MS (4 8,163.5 67.27 293.75 5,689.6 -3,478.5 -809.45,633.4 6,027,591.0 469,058.3 2.6 -619.02 MWD+SAG+CA+IIFR+MS (4 8,256.7 69.52 296.07 5,724.0 -3,442.0 -888.05,667.8 6,027,627.8 468,979.9 3.3 -532.40 MWD+SAG+CA+IIFR+MS (4 8,352.5 70.71 299.04 5,756.6 -3,400.3 -967.95,700.4 6,027,669.8 468,900.2 3.2 -442.57 MWD+SAG+CA+IIFR+MS (4 8,447.8 71.55 301.48 5,787.4 -3,354.9 -1,045.75,731.2 6,027,715.6 468,822.5 2.6 -353.15 MWD+SAG+CA+IIFR+MS (4 8,540.1 73.44 302.05 5,815.2 -3,308.5 -1,120.65,759.0 6,027,762.2 468,747.8 2.1 -266.08 MWD+SAG+CA+IIFR+MS (4 8,636.8 73.05 301.77 5,843.0 -3,259.6 -1,199.25,786.8 6,027,811.5 468,669.5 0.5 -174.64 MWD+SAG+CA+IIFR+MS (4 8,729.7 73.19 301.76 5,870.0 -3,212.7 -1,274.85,813.8 6,027,858.6 468,594.0 0.2 -86.70 MWD+SAG+CA+IIFR+MS (4 8,825.4 73.44 302.92 5,897.5 -3,163.7 -1,352.25,841.3 6,027,907.9 468,516.8 1.2 3.72 MWD+SAG+CA+IIFR+MS (4 8,919.5 74.42 303.74 5,923.5 -3,114.0 -1,427.75,867.3 6,027,957.9 468,441.5 1.3 92.71 MWD+SAG+CA+IIFR+MS (4 9,012.2 74.72 303.61 5,948.2 -3,064.5 -1,502.15,892.0 6,028,007.7 468,367.3 0.4 180.53 MWD+SAG+CA+IIFR+MS (4 9,108.4 74.86 304.36 5,973.4 -3,012.6 -1,579.15,917.2 6,028,059.9 468,290.6 0.8 271.70 MWD+SAG+CA+IIFR+MS (4 9,203.1 74.01 304.47 5,998.8 -2,961.1 -1,654.35,942.6 6,028,111.8 468,215.6 0.9 361.12 MWD+SAG+CA+IIFR+MS (4 9,296.8 73.05 304.59 6,025.4 -2,910.1 -1,728.45,969.2 6,028,163.0 468,141.7 1.0 449.22 MWD+SAG+CA+IIFR+MS (4 9,390.6 72.72 304.23 6,053.0 -2,859.4 -1,802.35,996.8 6,028,214.0 468,068.0 0.5 537.13 MWD+SAG+CA+IIFR+MS (4 9,486.2 73.18 302.97 6,081.0 -2,808.9 -1,878.46,024.8 6,028,264.9 467,992.1 1.3 626.96 MWD+SAG+CA+IIFR+MS (4 9,580.2 72.79 302.59 6,108.5 -2,760.2 -1,954.06,052.3 6,028,313.8 467,916.7 0.6 715.54 MWD+SAG+CA+IIFR+MS (4 9,674.7 73.31 302.39 6,136.1 -2,711.7 -2,030.26,079.9 6,028,362.7 467,840.7 0.6 804.71 MWD+SAG+CA+IIFR+MS (4 9,769.9 73.04 302.55 6,163.6 -2,662.8 -2,107.16,107.4 6,028,411.9 467,764.0 0.3 894.63 MWD+SAG+CA+IIFR+MS (4 9,863.3 73.17 303.41 6,190.8 -2,614.1 -2,182.16,134.6 6,028,460.8 467,689.2 0.9 982.66 MWD+SAG+CA+IIFR+MS (4 9,956.6 73.18 302.97 6,217.8 -2,565.2 -2,256.86,161.6 6,028,510.0 467,614.7 0.5 1,070.56 MWD+SAG+CA+IIFR+MS (4 10,050.6 73.42 303.26 6,244.8 -2,516.0 -2,332.36,188.6 6,028,559.5 467,539.5 0.4 1,159.26 MWD+SAG+CA+IIFR+MS (4 10,146.8 74.15 303.62 6,271.7 -2,465.1 -2,409.36,215.5 6,028,610.7 467,462.6 0.8 1,250.12 MWD+SAG+CA+IIFR+MS (4 10,241.0 74.72 303.65 6,296.9 -2,414.9 -2,484.96,240.7 6,028,661.3 467,387.3 0.6 1,339.33 MWD+SAG+CA+IIFR+MS (4 10,335.1 74.91 302.89 6,321.6 -2,365.0 -2,560.96,265.4 6,028,711.5 467,311.5 0.8 1,428.77 MWD+SAG+CA+IIFR+MS (4 10,429.5 74.02 302.49 6,346.9 -2,315.9 -2,637.36,290.7 6,028,760.8 467,235.2 1.0 1,518.37 MWD+SAG+CA+IIFR+MS (4 10,524.6 74.47 302.84 6,372.7 -2,266.5 -2,714.46,316.5 6,028,810.6 467,158.4 0.6 1,608.65 MWD+SAG+CA+IIFR+MS (4 10,588.3 75.49 303.05 6,389.2 -2,233.0 -2,766.16,333.0 6,028,844.2 467,106.9 1.6 1,669.28 MWD+SAG+CA+IIFR+MS (4 10,651.9 76.53 302.31 6,404.6 -2,199.7 -2,818.06,348.4 6,028,877.7 467,055.1 2.0 1,730.09 MWD+SAG+CA+IIFR+MS (4 10,748.8 79.97 302.52 6,424.3 -2,148.9 -2,898.06,368.1 6,028,928.9 466,975.2 3.6 1,823.68 MWD+SAG+CA+IIFR+MS (4 10,846.9 80.08 303.63 6,441.3 -2,096.2 -2,979.06,385.1 6,028,982.0 466,894.5 1.1 1,918.84 MWD+SAG+CA+IIFR+MS (4 10,897.8 81.60 304.79 6,449.4 -2,067.9 -3,020.66,393.2 6,029,010.4 466,853.0 3.7 1,968.17 MWD+SAG+CA+IIFR+MS (4 10,942.9 83.16 306.52 6,455.4 -2,041.8 -3,056.96,399.2 6,029,036.6 466,816.8 5.1 2,011.83 MWD+SAG+CA+IIFR+MS (4 10,991.6 85.26 309.64 6,460.3 -2,011.9 -3,095.16,404.1 6,029,066.6 466,778.8 7.7 2,058.62 MWD+SAG+CA+IIFR+MS (4 11,038.4 87.19 309.80 6,463.4 -1,982.1 -3,131.06,407.2 6,029,096.6 466,743.0 4.1 2,103.33 MWD+SAG+CA+IIFR+MS (4 11,134.5 92.50 312.35 6,463.7 -1,919.0 -3,203.36,407.5 6,029,160.0 466,670.9 6.1 2,194.63 MWD+SAG+CA+IIFR+MS (4 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 11,233.0 94.29 314.99 6,457.8 -1,851.1 -3,274.56,401.6 6,029,228.2 466,600.0 3.2 2,286.74 MWD+SAG+CA+IIFR+MS (4 11,328.9 92.92 313.35 6,451.8 -1,784.4 -3,343.16,395.6 6,029,295.1 466,531.7 2.2 2,376.02 MWD+SAG+CA+IIFR+MS (4 11,426.3 91.56 309.58 6,448.0 -1,720.0 -3,416.06,391.8 6,029,359.8 466,459.0 4.1 2,468.35 MWD+SAG+CA+IIFR+MS (4 11,522.4 91.50 303.69 6,445.4 -1,662.7 -3,493.16,389.2 6,029,417.5 466,382.2 6.1 2,561.72 MWD+SAG+CA+IIFR+MS (4 11,618.9 93.48 300.05 6,441.2 -1,611.8 -3,574.96,385.0 6,029,468.7 466,300.6 4.3 2,656.92 MWD+SAG+CA+IIFR+MS (4 11,716.0 95.89 297.12 6,433.3 -1,565.5 -3,660.06,377.1 6,029,515.3 466,215.8 3.9 2,753.30 MWD+SAG+CA+IIFR+MS (4 11,812.4 94.58 295.71 6,424.5 -1,522.8 -3,745.96,368.3 6,029,558.3 466,130.1 2.0 2,849.07 MWD+SAG+CA+IIFR+MS (4 11,908.2 93.78 295.45 6,417.5 -1,481.6 -3,832.16,361.3 6,029,599.9 466,044.0 0.9 2,944.53 MWD+SAG+CA+IIFR+MS (4 12,005.2 95.08 295.81 6,410.0 -1,439.7 -3,919.26,353.8 6,029,642.1 465,957.1 1.4 3,041.12 MWD+SAG+CA+IIFR+MS (4 12,102.1 94.96 298.58 6,401.5 -1,395.6 -4,005.16,345.3 6,029,686.6 465,871.4 2.8 3,137.41 MWD+SAG+CA+IIFR+MS (4 12,198.7 95.15 300.73 6,393.0 -1,348.0 -4,088.76,336.8 6,029,734.5 465,787.9 2.2 3,233.02 MWD+SAG+CA+IIFR+MS (4 12,294.8 94.34 304.83 6,385.1 -1,296.2 -4,169.26,328.9 6,029,786.7 465,707.7 4.3 3,327.40 MWD+SAG+CA+IIFR+MS (4 12,391.4 93.97 309.02 6,378.1 -1,238.3 -4,246.26,321.9 6,029,844.8 465,630.9 4.3 3,420.88 MWD+SAG+CA+IIFR+MS (4 12,487.8 93.16 309.15 6,372.1 -1,177.7 -4,320.96,315.9 6,029,905.8 465,556.5 0.9 3,513.36 MWD+SAG+CA+IIFR+MS (4 12,585.8 92.98 309.41 6,366.8 -1,115.7 -4,396.66,310.6 6,029,968.1 465,481.0 0.3 3,607.34 MWD+SAG+CA+IIFR+MS (4 12,682.1 92.61 309.94 6,362.1 -1,054.3 -4,470.76,305.9 6,030,029.8 465,407.2 0.7 3,699.56 MWD+SAG+CA+IIFR+MS (4 12,778.8 90.94 308.97 6,359.1 -992.9 -4,545.36,302.9 6,030,091.5 465,332.9 2.0 3,792.24 MWD+SAG+CA+IIFR+MS (4 12,875.1 90.51 312.57 6,357.9 -930.0 -4,618.26,301.7 6,030,154.6 465,260.2 3.8 3,883.97 MWD+SAG+CA+IIFR+MS (4 12,971.7 91.44 317.11 6,356.3 -861.9 -4,686.76,300.1 6,030,223.0 465,192.0 4.8 3,973.66 MWD+SAG+CA+IIFR+MS (4 13,066.8 91.31 318.53 6,354.0 -791.5 -4,750.56,297.8 6,030,293.7 465,128.5 1.5 4,060.00 MWD+SAG+CA+IIFR+MS (4 13,164.8 91.93 316.95 6,351.2 -719.0 -4,816.46,295.0 6,030,366.4 465,062.9 1.7 4,149.01 MWD+SAG+CA+IIFR+MS (4 13,261.0 91.44 316.92 6,348.4 -648.7 -4,882.16,292.2 6,030,437.0 464,997.5 0.5 4,237.00 MWD+SAG+CA+IIFR+MS (4 13,357.6 91.69 316.90 6,345.7 -578.2 -4,948.16,289.5 6,030,507.8 464,931.8 0.3 4,325.36 MWD+SAG+CA+IIFR+MS (4 13,453.2 91.81 317.16 6,342.8 -508.3 -5,013.16,286.6 6,030,577.9 464,867.0 0.3 4,412.63 MWD+SAG+CA+IIFR+MS (4 13,549.8 91.31 316.96 6,340.2 -437.6 -5,078.96,284.0 6,030,648.9 464,801.5 0.6 4,500.87 MWD+SAG+CA+IIFR+MS (4 13,647.6 89.58 318.20 6,339.4 -365.4 -5,144.96,283.2 6,030,721.3 464,735.9 2.2 4,589.84 MWD+SAG+CA+IIFR+MS (4 13,744.0 87.11 318.76 6,342.2 -293.2 -5,208.86,286.0 6,030,793.7 464,672.3 2.6 4,676.90 MWD+SAG+CA+IIFR+MS (4 13,839.6 86.49 319.72 6,347.6 -220.9 -5,271.16,291.4 6,030,866.3 464,610.2 1.2 4,762.60 MWD+SAG+CA+IIFR+MS (4 13,935.6 86.50 321.17 6,353.4 -147.1 -5,332.16,297.2 6,030,940.4 464,549.5 1.5 4,847.68 MWD+SAG+CA+IIFR+MS (4 14,033.1 86.81 322.49 6,359.1 -70.6 -5,392.26,302.9 6,031,017.1 464,489.7 1.4 4,932.96 MWD+SAG+CA+IIFR+MS (4 14,129.2 85.25 322.67 6,365.8 5.6 -5,450.56,309.6 6,031,093.5 464,431.8 1.6 5,016.46 MWD+SAG+CA+IIFR+MS (4 14,226.2 86.75 321.78 6,372.5 82.1 -5,509.86,316.3 6,031,170.2 464,372.8 1.8 5,100.97 MWD+SAG+CA+IIFR+MS (4 14,312.2 86.12 320.17 6,377.9 148.8 -5,563.86,321.7 6,031,237.1 464,319.0 2.0 5,176.82 MWD+SAG+CA+IIFR+MS (4 14,330.1 84.88 319.77 6,379.3 162.4 -5,575.36,323.1 6,031,250.8 464,307.6 7.3 5,192.71 MWD+SAG+CA+IIFR+MS (4 14,417.9 88.79 320.05 6,384.1 229.5 -5,631.86,327.9 6,031,318.1 464,251.5 4.5 5,270.93 MWD+SAG+CA+IIFR+MS (4 14,515.7 87.66 322.28 6,387.2 305.6 -5,693.06,331.0 6,031,394.4 464,190.5 2.6 5,357.13 MWD+SAG+CA+IIFR+MS (4 14,613.0 88.47 324.60 6,390.5 383.7 -5,751.06,334.3 6,031,472.8 464,132.9 2.5 5,441.11 MWD+SAG+CA+IIFR+MS (4 14,709.0 91.07 325.24 6,390.8 462.2 -5,806.16,334.6 6,031,551.5 464,078.1 2.8 5,522.58 MWD+SAG+CA+IIFR+MS (4 14,770.7 90.32 323.20 6,390.1 512.3 -5,842.26,333.9 6,031,601.7 464,042.2 3.5 5,575.41 MWD+SAG+CA+IIFR+MS (4 14,796.6 93.07 323.00 6,389.3 533.0 -5,857.76,333.1 6,031,622.5 464,026.7 10.6 5,597.82 MWD+SAG+CA+IIFR+MS (4 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-36 ODSN-36 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Design:ODSN-36 PN10 Surveys Database:EDM 2003.16 Single User Db MD Reference:42.7' + 13.5' @ 56.2ft (Nabors 19AC) North Reference: Well ODSN-36 - Slot ODS-36 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 14,805.4 93.36 322.81 6,388.8 540.0 -5,863.16,332.6 6,031,629.6 464,021.5 3.9 5,605.46 MWD+SAG+CA+IIFR+MS (4 14,899.8 91.49 323.23 6,384.8 615.4 -5,919.86,328.6 6,031,705.1 463,965.0 2.0 5,687.17 MWD+SAG+CA+IIFR+MS (4 14,998.6 91.38 322.70 6,382.4 694.2 -5,979.36,326.2 6,031,784.2 463,905.9 0.5 5,772.80 MWD+SAG+CA+IIFR+MS (4 15,024.7 89.82 321.49 6,382.1 714.8 -5,995.36,325.9 6,031,804.8 463,889.9 7.6 5,795.63 MWD+SAG+CA+IIFR+MS (4 15,042.6 90.02 320.94 6,382.1 728.8 -6,006.56,325.9 6,031,818.9 463,878.7 3.3 5,811.46 MWD+SAG+CA+IIFR+MS (4 15,094.6 89.96 317.17 6,382.1 768.0 -6,040.66,325.9 6,031,858.3 463,844.9 7.3 5,858.18 MWD+SAG+CA+IIFR+MS (4 15,190.2 89.71 316.01 6,382.4 837.4 -6,106.36,326.2 6,031,927.9 463,779.5 1.2 5,945.79 MWD+SAG+CA+IIFR+MS (4 15,288.7 90.02 321.02 6,382.6 911.2 -6,171.56,326.4 6,032,002.0 463,714.5 5.1 6,034.73 MWD+SAG+CA+IIFR+MS (4 15,385.2 89.27 326.84 6,383.2 989.2 -6,228.36,327.0 6,032,080.1 463,658.1 6.1 6,117.53 MWD+SAG+CA+IIFR+MS (4 15,481.1 90.33 329.04 6,383.6 1,070.5 -6,279.26,327.4 6,032,161.6 463,607.5 2.5 6,196.25 MWD+SAG+CA+IIFR+MS (4 15,577.9 91.01 330.66 6,382.4 1,154.2 -6,327.86,326.2 6,032,245.5 463,559.2 1.8 6,273.76 MWD+SAG+CA+IIFR+MS (4 15,673.6 90.57 328.19 6,381.1 1,236.6 -6,376.56,324.9 6,032,328.1 463,510.9 2.6 6,350.87 MWD+SAG+CA+IIFR+MS (4 15,770.9 91.38 324.04 6,379.5 1,317.3 -6,430.76,323.3 6,032,409.1 463,457.0 4.3 6,432.40 MWD+SAG+CA+IIFR+MS (4 15,880.4 95.04 321.82 6,373.3 1,404.5 -6,496.66,317.1 6,032,496.5 463,391.5 3.9 6,527.18 MWD+SAG+CA+IIFR+MS (4 15,974.9 93.79 322.44 6,366.1 1,478.9 -6,554.46,309.9 6,032,571.1 463,334.0 1.5 6,609.55 MWD+SAG+CA+IIFR+MS (4 16,073.5 95.17 323.55 6,358.4 1,557.4 -6,613.66,302.2 6,032,649.8 463,275.1 1.8 6,694.71 MWD+SAG+CA+IIFR+MS (4 16,170.1 93.86 325.21 6,350.7 1,635.7 -6,669.76,294.5 6,032,728.4 463,219.3 2.2 6,777.07 MWD+SAG+CA+IIFR+MS (4 16,266.4 93.30 321.81 6,344.7 1,713.0 -6,726.86,288.5 6,032,805.9 463,162.5 3.6 6,859.92 MWD+SAG+CA+IIFR+MS (4 16,362.5 94.11 321.48 6,338.5 1,788.2 -6,786.46,282.3 6,032,881.3 463,103.3 0.9 6,944.15 MWD+SAG+CA+IIFR+MS (4 16,458.0 92.18 319.73 6,333.3 1,861.8 -6,846.96,277.1 6,032,955.2 463,043.1 2.7 7,028.71 MWD+SAG+CA+IIFR+MS (4 16,554.3 93.62 318.87 6,328.4 1,934.8 -6,909.66,272.2 6,033,028.4 462,980.7 1.7 7,114.98 MWD+SAG+CA+IIFR+MS (4 16,651.3 91.44 316.37 6,324.1 2,006.3 -6,974.86,267.9 6,033,100.1 462,915.7 3.4 7,203.05 MWD+SAG+CA+IIFR+MS (4 16,749.0 92.76 317.34 6,320.5 2,077.5 -7,041.66,264.3 6,033,171.7 462,849.2 1.7 7,292.43 MWD+SAG+CA+IIFR+MS (4 16,810.4 93.62 317.65 6,317.1 2,122.7 -7,083.16,260.9 6,033,217.0 462,808.0 1.5 7,348.26 MWD+SAG+CA+IIFR+MS (4 16,844.8 91.67 317.75 6,315.5 2,148.1 -7,106.16,259.3 6,033,242.5 462,785.0 5.7 7,379.45 MWD+SAG+CA+IIFR+MS (4 16,941.1 87.60 317.88 6,316.2 2,219.4 -7,170.86,260.0 6,033,314.1 462,720.7 4.2 7,466.89 MWD+SAG+CA+IIFR+MS (4 16,988.0 86.94 317.16 6,318.4 2,254.0 -7,202.56,262.2 6,033,348.8 462,689.1 2.1 7,509.57 MWD+SAG+CA+IIFR+MS (4 17,035.7 85.19 316.66 6,321.7 2,288.8 -7,234.96,265.5 6,033,383.6 462,656.8 3.8 7,553.08 MWD+SAG+CA+IIFR+MS (4 17,074.6 85.90 317.18 6,324.7 2,317.1 -7,261.56,268.5 6,033,412.1 462,630.4 2.3 7,588.60 MWD+SAG+CA+IIFR+MS (4 17,133.9 83.57 318.43 6,330.1 2,360.9 -7,301.16,273.9 6,033,456.0 462,590.9 4.5 7,642.24 MWD+SAG+CA+IIFR+MS (4 17,230.6 81.90 319.50 6,342.4 2,433.2 -7,364.16,286.2 6,033,528.6 462,528.2 2.0 7,728.53 MWD+SAG+CA+IIFR+MS (4 17,289.0 83.18 318.54 6,349.9 2,476.9 -7,402.16,293.7 6,033,572.5 462,490.4 2.7 7,780.61 MWD+SAG+CA+IIFR+MS (4 17,326.0 83.10 319.62 6,354.4 2,504.7 -7,426.16,298.2 6,033,600.3 462,466.5 2.9 7,813.62 MWD+SAG+CA+IIFR+MS (4 17,423.2 82.48 320.22 6,366.6 2,578.4 -7,488.26,310.4 6,033,674.3 462,404.7 0.9 7,899.64 MWD+SAG+CA+IIFR+MS (4 17,525.0 82.48 320.22 6,379.9 2,656.0 -7,552.86,323.7 6,033,752.1 462,340.5 0.0 7,989.42 PROJECTED to TD 8/24/2009 2:16:16PM COMPASS 2003.16 Build 71 Page 7 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 0 1 02 03 04 05 06 07 08 09 0 Rig Days Me a s u r e d D e p t h Prognosed Actual Oooguruk ODSN-36, ODSN-36PB1, & ODSN-36PB2 Days -vs- Depth Start 12-1/4" Surface On Bot: 03:45 - 31-Jan-08 Original hole drilled to 3,683' (28-Jan-08 to 4-Feb-08) and was suspended. The hole was continued from 25-Feb-09 drilling from 3,683' to 10635'. The BHA was lost in the hole and cement plugs set. The hole was sidetracked starting at 6,654'. Drilling continued to 10,232' where 7" casing was run and cemented on April 23, 2009 after fighting lost circulation and pack-off's. Note: the first hole was designated ODSN- 36PB1, second hole was designated ODSN-36PB2 and the final hole was designated ODSN-36. The rig moved back over ODSN-36 on July 18, 2009 to drill and complete the production section to a total measured TD 12-1/4" Surface 3683' MD / 3027' TVD Off Bot: 05:17 - 01-Feb-08 Set 9.625" Surface Casing 3665' MD / 3014' TVD Suspend Well 04-Feb-08 Reenter Well 24-Feb-09 [Renamed ODSN-36] Start 8-3/4" Intermediate On Bot: 05:44 - 27-Feb-09 Set 7" Intmed. Casing 10618' MD / 6396' TVD Set Two Cement Plugs to Control Severe Losses POOH for MWD Detection 9815' MD / 6169' TVD Off Bot: 08:20 08-Mar-09 On Bot: 03:07 10-Mar-09 Drill 8.75" Intermediate to: 10635' MD / 6400' TVD Off Bot: 02:38 12-Mar-09 Lose Stuck BHA In Hole Sidetrack for Stuck BHA KOP: 6654' MD / 4925' TVD On Bot: 02:47 28-Mar-09 Rename Abandoned Wellbore ODSN-36 PB1 POOH Drillstring Washout 9286' MD / 6022' TVD Off Bot: 09:51 31-Mar-09 On Bot: 01:18 03-Apr-09 POOH Drillstring Washout 9509' MD / 6087' TVD Off Bot: 07:51 03-Apr-09 Unable to Reenter Wellbore Sidetrack - Unable to Reenter Prev. Sidetrack KOP: 6808' MD / 5016' TVD On Bot: 03:58 10-Apr-09 Rename Abandoned Wellbore ODSN-36 PB2 Treat Severe Losses TD 8-3/4" Intermediate 10629' MD / 6399' TVD Off Bot: 16:49 - 17-Apr-09 Start 6-1/8" Production On Bot: 15:04 - 21-Jul-09 POOH for Low ROP Trip In & GeoPilot Fails POOH & Trip Back In 15879' MD / 6373' TVD Off Bot: 08:47 29-Jul-09 On Bot: 12:37 03-Aug-09 TD well on 8/6/2009 at a measured depth of 17,525'
