Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
210-093
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 T40700ODSN-17 50703206220000 210093 6/14/2025 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' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] ODSN-17 (PTD 210-093) Date:Wednesday, January 29, 2025 1:28:24 PM Attachments:V2_ODSN-17_SSSV_remediation_Procedure(Jan-2025).docx From: Ryan Rupert <ryan.rupert@hilcorp.com> Sent: Tuesday, January 28, 2025 12:08 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Sara Hannegan <shannegan@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: [EXTERNAL] ODSN-17 (PTD 210-093) Here’s the revised procedure. Thanks, Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, January 27, 2025 4:10 PM To: Ryan Rupert <ryan.rupert@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] ODSN-17 (PTD 210-093) Good afternoon Ryan. Hope things are well. Reviewing your application for ODSN-17 K -valve. Due to past field testing issues we are requiring a testing procedure in sundry applications for all K-Valves that include the following details. Please update your procedure and send back to me. Closure calculations (included) use of calibrated test gauge (suitable range and accuracy) time to bleed down to dome pressure (where K-valve is supposed to function) and that time should be limited to something reasonable like 10-15 minutes acceptance criteria (close within 4 minutes once reach the dome pressure) how you will demonstrate the valve is closed and holding pressure Thanks, Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. SSSV Repair Well: Oooguruk ODSN-17 Well Name: ODSN-17 API Number: 50-703-20622-00-00 Current Status: Under Eval GL producer Permit to Drill Number: 210-093 First Call Engineer: Ryan Rupert (907) 301-1736 (c) Second Call Engineer: Keith Lopez (907) 903-5432 (c) Maximum Expected BHP: 2,631 psi @ 6,082’ TVD 2022 SBHP (<8.4ppg) Max. Potential Surface Pressure: 2023 psi Using 0.1 psi/ft Version #2 updated 1/28/25 to include K-valve testing specifics Brief Well Summary ODSN-17 is a Nuiqsut formation producer. In 2017, an ESP was installed. That pump failed in 2018. The well had been on GL after that. The well is currently shut in due to multiple failed SSSV tests. Attempts have been made to get the SSSV functioning by brush & flushing, exercise tool, and the BlueSpark tool. None of these remediations have been successful, and it appears that the valve is stuck in the open position. To reestablish SSSV integrity, Hilcorp aims to lockout the valve, and install a surface controlled WL-SSSV. If parts are not readily available, a subsurface controlled SSSV (K-valve) will be installed per below. The goal of this project is to remediate the existing stuck open TRSSSV install a subsurface controlled SSSV. Pertinent wellbore information: - Deviation o Max down to ESP at 13,809’ MD: 79 degrees at 13,800’ MD o Max down to GLM #1 at 11,493’ MD: 71 degrees (sail angle from 3300-11,500’ MD) o Max down to SSSV at 2163’ MD: 31 degrees - TRSSSV: o 2-7/8” Halliburton NE o Set at 2163’ MD (2097’ TVD) - History o 2017 RWO: Installed new ESP Passed MIT-IA against packer at 2641’ MD o June-2021: First signs of SSSV having issues. Won’t pass closure test o May-2022: Confirmed SSSV flow tube stuck open Ran BlueSpark tool to rattle / free SSSV flow tube (no success) o June-2022: ran SSSV exercise tool (no movement) o April-2024: Brush SSSV, and attempt closure test (no luck) Set TTP at 2163’ MD in SSSV profile o January-2025: TTP pulled and well brought online for 14 days Under Eval to design K-valve SSSV Repair Well: Oooguruk ODSN-17 SSC-SSSV Suitability Evaluation: Well historic parameters: Production 450bopd / 110bwpd / 250mcfd Fgas / 800mcfd GL FTP 290 psig Flowing WHT 50 F This safety valve will be setup targeting a trip pressure of ~145 psig. This matches the low pressure pilots of the SSV’s. This will be under the well’s normal FTP range of 280 - 320psi FTP. Trip pressure needs to be >25% of FTP to be in compliance, so anything above 80psi trip pressure will be in compliance. Lockout / WL-SSSV procedure 1. MIRU SL and PT PCE to 2500 high / 250psi low 2. RIH and lockout TRSSSV profile per vendor: a. Locks the hold open sleeve permanently in open position b. Communicates area between sealbores with existing hydraulic control line 3. RIH and set 2-7/8” WL-SSSV in profile at 2163’ MD 4. RDMO 5. Conduct a SVS test of surface and subsurface components within 5 days after stabilized flow Subsurface controlled SSSV install (in lieu of lockout / WL-SSSV) 1. MIRU SL and PT PCE to 2500 high / 250psi low 2. RIH and set the subsurface controlled subsurface safety valve in profile at 2163’ MD 3. RDMO 4. Conduct a SVS test of surface and subsurface components per 20 AAC 25.265 within 5 days after stabilized flow a. Ensure a calibrated pressure gauge of suitable range and accuracy is used (GB 10-004) i. Current calibration labeled or alternate documentation ii. Suitable range is defined as actual readings within the middle third of the gauge’s scale iii. Suitable accuracy is defined as a gauge capable of measuring pressures at 1% or less of the gauge’s scale b. Ensure time to bleed well down to actuation pressure is less than or equal to 15 minutes c. Ensure SSSV has closed (evidenced by no flow) not later than 4 minutes after tubing pressure reaches 145psi d. Continue to bleed SITP to <100psi, and then block in tubing e. A passing test will be evidenced by a stabilized flat-line pressure response Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Halliburton K-valve Subsurface Safety valve product sheet 4. Subsurface controlled SSSV calculations 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Re-establish SSSV Integrity 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 19,947 See Schematic Casing Collapse Conductor NA Surface 3,180psi Intermediate 1 3,090psi Tie-Back 5,410psi Intermediate 2 5,410psi Upper Liner 7,500psi Lower Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3,276' 7" 14,106' 6,186' 7,240psi Ryan Rupert 6,290'4-1/2" 6,178'-6,258' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 14,059'-19,689' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355036, ADL0355038 210-093 ODSN-17 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-703-20622-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 6,382 19,695 6,258 2,023 NUIQSUT OIL NUIQSUT OIL 158' 158' 6.4# / L-80 TVD Burst 13,753' 8,430psi MD NA 7,240psi 5,830psi 5,750psi 3,285' 5,365' 5,320' 4,660' 10,978' 115' 16 11-3/4" 9-5/8" 4,621' 7"10,806' 6,481' 907-777-8503 ryan.rupert@hilcorp.com Operations Manager February 10, 2025 19,695'5,430' 2-7/8" 6,258' Perforation Depth MD (ft): OOOGURUK 2-7/8"x7" WFT Hydrow II ESP Packer and 2-7/8" NE TRSV 2641' MD / 2471' TVD and 2163' MD / 2097' TVD NA 20,940' 10,844' 6,987' 4-1/2" yy Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-035 By Grace Christianson at 12:16 pm, Jan 27, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.01.27 09:14:08 - 09'00' Sara Hannegan (2519) 1:50 pm, Jan 29, 2025 JJL 1/29/25 A.Dewhurst 31JAN25 DSR-1/31/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.03 10:17:15 -09'00'02/03/25 RBDMS JSB 020425 SSSVRepair Well:OoogurukODSNͲ17 WellName:ODSNͲ17APINumber:50Ͳ703Ͳ20622Ͳ00Ͳ00 CurrentStatus:UnderEvalGLproducerPermittoDrillNumber:210Ͳ093 FirstCallEngineer:RyanRupert(907)301Ͳ1736(c) SecondCallEngineer:KeithLopez(907)903Ͳ5432(c) MaximumExpectedBHP:2,631psi@6,082’TVD 2022SBHP(<8.4ppg) Max.PotentialSurfacePressure:2023psiUsing0.1psi/ft Version#2updated1/28/25toincludeKͲvalvetestingspecifics BriefWellSummary ODSNͲ17isaNuiqsutformationproducer.In2017,anESPwasinstalled.Thatpumpfailedin2018.Thewell hadbeenonGLafterthat.ThewelliscurrentlyshutinduetomultiplefailedSSSVtests.Attemptshavebeen madetogettheSSSVfunctioningbybrush&flushing,exercisetool,andtheBlueSparktool.Noneofthese remediationshavebeensuccessful,anditappearsthatthevalveisstuckintheopenposition.Toreestablish SSSVintegrity,Hilcorpaimstolockoutthevalve,andinstallasurfacecontrolledWLͲSSSV.Ifpartsarenot readilyavailable,asubsurfacecontrolledSSSV(KͲvalve)willbeinstalledperbelow. ThegoalofthisprojectistoremediatetheexistingstuckopenTRSSSVinstallasubsurfacecontrolledSSSV. Pertinentwellboreinformation: Ͳ Deviation o MaxdowntoESPat13,809’MD:79degreesat13,800’MD o MaxdowntoGLM#1at11,493’MD:71degrees(sailanglefrom3300Ͳ11,500’MD) o MaxdowntoSSSVat2163’MD:31degrees Ͳ TRSSSV: o 2Ͳ7/8”HalliburtonNE o Setat2163’MD(2097’TVD) Ͳ History o 2017RWO: InstallednewESP PassedMITͲIAagainstpackerat2641’MD o JuneͲ2021:FirstsignsofSSSVhavingissues.Won’tpassclosuretest o MayͲ2022: ConfirmedSSSVflowtubestuckopen RanBlueSparktooltorattle/freeSSSVflowtube(nosuccess) o JuneͲ2022:ranSSSVexercisetool(nomovement) o AprilͲ2024: BrushSSSV,andattemptclosuretest(noluck) SetTTPat2163’MDinSSSVprofile o JanuaryͲ2025:TTPpulledandwellbroughtonlinefor14daysUnderEvaltodesignKͲvalve SSSVRepair Well:OoogurukODSNͲ17 SSCͲSSSVSuitabilityEvaluation: Wellhistoricparameters: Production450bopd/110bwpd/250mcfdFgas/800mcfdGL FTP290psig FlowingWHT50F Thissafetyvalvewillbesetuptargetingatrippressureof~145psig.Thismatchesthelowpressurepilotsof theSSV’s.Thiswillbeunderthewell’snormalFTPrangeof280Ͳ320psiFTP.Trippressureneedstobe>25% ofFTPtobeincompliance,soanythingabove80psitrippressurewillbeincompliance. Lockout/WLͲSSSVprocedure 1. MIRUSLandPTPCEto2500high/250psilow 2. RIHandlockoutTRSSSVprofilepervendor: a. Lockstheholdopensleevepermanentlyinopenposition b. Communicatesareabetweensealboreswithexistinghydrauliccontrolline 3. RIHandset2Ͳ7/8”WLͲSSSVinprofileat2163’MD 4. RDMO 5. ConductaSVStestofsurfaceandsubsurfacecomponentswithin5daysafterstabilizedflow SubsurfacecontrolledSSSVinstall(inlieuoflockout/WLͲSSSV) 1. MIRUSLandPTPCEto2500high/250psilow 2. RIHandsetthesubsurfacecontrolledsubsurfacesafetyvalveinprofileat2163’MD 3. RDMO 4. ConductaSVStestofsurfaceandsubsurfacecomponentsper20AAC25.265within5daysafter stabilizedflow a. Ensureacalibratedpressuregaugeofsuitablerangeandaccuracyisused(GB10Ͳ004) i. Currentcalibrationlabeledoralternatedocumentation ii. Suitablerangeisdefinedasactualreadingswithinthemiddlethirdofthegauge’sscale iii. Suitableaccuracyisdefinedasagaugecapableofmeasuringpressuresat1%orlessof thegauge’sscale b. Ensuretimetobleedwelldowntoactuationpressureislessthanorequalto15minutes c. EnsureSSSVhasclosed(evidencedbynoflow)notlaterthan4minutesaftertubingpressure reaches145psi d. ContinuetobleedSITPto<100psi,andthenblockintubing e. ApassingtestwillbeevidencedbyastabilizedflatͲlinepressureresponse Attachments: 1. CurrentWellSchematic 2. ProposedWellSchematic 3. HalliburtonKͲvalveSubsurfaceSafetyvalveproductsheet 4. SubsurfacecontrolledSSSVcalculations SSSV Repair Well: Oooguruk ODSN-17 Well Name:ODSN-17 API Number:50-703-20622-00-00 Current Status:Under Eval GL producer Permit to Drill Number:210-093 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Maximum Expected BHP:2,631 psi @ 6,082’ TVD 2022 SBHP (<8.4ppg) Max. Potential Surface Pressure: 2023 psi Using 0.1 psi/ft Brief Well Summary ODSN-17 is a Nuiqsut formation producer. In 2017, an ESP was installed. That pump failed in 2018. The well had been on GL after that. The well is currently shut in due to multiple failed SSSV tests. Attempts have been made to get the SSSV functioning by brush & flushing, exercise tool, and the BlueSpark tool. None of these remediations have been successful, and it appears that the valve is stuck in the open position. To reestablish SSSV integrity, Hilcorp aims to lockout the valve, and install a surface controlled WL-SSSV. If parts are not readily available, a subsurface controlled SSSV (K-valve) will be installed per below. The goal of this project is to remediate the existing stuck open TRSSSV install a subsurface controlled SSSV. Pertinent wellbore information: - Deviation o Max down to ESP at 13,809’ MD: 79 degrees at 13,800’ MD o Max down to GLM #1 at 11,493’ MD: 71 degrees (sail angle from 3300-11,500’ MD) o Max down to SSSV at 2163’ MD: 31 degrees - TRSSSV: o 2-7/8” Halliburton NE o Set at 2163’ MD (2097’ TVD) -History o 2017 RWO: Installed new ESP Passed MIT-IA against packer at 2641’ MD o June-2021: First signs of SSSV having issues. Won’t pass closure test o May-2022: Confirmed SSSV flow tube stuck open Ran BlueSpark tool to rattle / free SSSV flow tube (no success) o June-2022: ran SSSV exercise tool (no movement) o April-2024: Brush SSSV, and attempt closure test (no luck) Set TTP at 2163’ MD in SSSV profile o January-2025: TTP pulled and well brought online for 14 days Under Eval to design K-valve SSSV Repair Well: Oooguruk ODSN-17 SSC-SSSV Suitability Evaluation: Well historic parameters: Production 450bopd / 110bwpd / 250mcfd Fgas / 800mcfd GL FTP 290 psig Flowing WHT 50 F This safety valve will be setup targeting a trip pressure of ~145 psig. This matches the low pressure pilots of the SSV’s. This will be under the well’s normal FTP range of 280 - 320psi FTP. Trip pressure needs to be >25% of FTP to be in compliance, so anything above 80psi trip pressure will be in compliance. Lockout / WL-SSSV procedure 1. MIRU SL and PT PCE to 2500 high / 250psi low 2. RIH and lockout TRSSSV profile per vendor: a. Locks the hold open sleeve permanently in open position b. Communicates area between sealbores with existing hydraulic control line 3. RIH and set 2-7/8” WL-SSSV in profile at 2163’ MD 4. RDMO 5. Conduct a SVS test of surface and subsurface components within 5 days after stabilized flow Subsurface controlled SSSV install (in lieu of lockout / WL-SSSV) 1. MIRU SL and PT PCE to 2500 high / 250psi low 2. RIH and set the subsurface controlled subsurface safety valve in profile at 2163’ MD 3. RDMO 4. Conduct a SVS test of surface and subsurface components within 5 days after stabilized flow Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Halliburton K-valve Subsurface Safety valve product sheet 4. Subsurface controlled SSSV calculations ODSN-17 Wellbore Schematic 6-1/8” Upper Lateral TD at 20,940' MD / 6,290' TVD 16" 11-3/4" 7" 7" Tieback 9-5/8" 6-1/8” L1 Lower Lateral TD at 19,695' MD / 6,258' TVD SSSV GL GL GLM #3 DGLV GLM #1 5/16" OV Pre-Installed D E F K GL G H GLM #2 DGLV L J I 2-7/8" Tubing FINAL as of 10-23-2017, edited 1-24-2025 A B C Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 109#, H-40 NA Surface 158' NA 11-3/4" Surface 60#, L-80, Hydril 521 10.772" Surface 4,660' NA 9-5/8" Intermediate 1 40#, L-80, Hydril 521 8.835" 4,497' 10,978' 0.0758 7" Int 2 Tieback 26#, L-80, BTC-M 6.276" Surface 10,844' 0.0383 7" Intermediate 2 26#, L-80, Hydril 521 6.276" 10,830' 14,106' 0.0383 4-1/2" Upper Liner 12.6#, L-80, Hydril 521 3.958" 13,953' 20,940' NA 4-1/2" Lower Liner 12.6#, L-80, Hydril 521 3.958" 14,265' 19,695' NA 3-1/2" Upper Tubing 9.2#, L-80, TC-II (2 joints) 2.992" 35' 100' 0.0087 2-7/8" Lower Tubing 6.4#, L-80, IBT-M 2.441" 100' 13,753' 0.0058 TUBING DETAIL CASING DETAIL No. Upper Completion Equipment MD(ft) TVD(ft) ID (in) A GE Tubing Hanger 34 34 2.9500 B 3-1/2" 9.2# L-80 TC-II Tubing (2 joints) 35 35 2.992 C 3-1/2" 9.2# L-80 TC-II X 2-7/8" 6.4# IBT-M XO 100 100 2.441 D 2-7/8" 'NE' TRSSV IBT-M Box x Pin - Control line to surface 2,163 2,097 2.313 E 2-7/8" x 1" GLM #3 KBMG IBT-M Box x Pin 2,542 2,402 2.366 F 2-7/8" x 7" WFT Hydrow II ESP Packer with Packer Vent Valve IBT-M Box x Pin 2,641 2,471 2.359 G 2-7/8" x 1" GLM #2 KBMG IBT-M Box x Pin 2,761 2,550 2.366 H 2-7/8" "X" Nipple (2.313" ID) EUE Box x Pin 2,861 2,613 2.313 I 2-7/8" x 1" GLM #1 KBMG IBT-M Box x Pin 11,493 5,530 2.366 J "XN" 2.313" 2.205" No-Go IBT-M Box x Pin 11,593 5,563 2.205 K Auto Diverter Valve 13,806 6,132 NA L ESP Pump Assembly 13,809 6,133 NA End of Assembly 13,864 6,143 Lost Downhole 2017 RWO: - Qty 2 ESP seal Clamp Brackets - Qty 1 ½” Sheared Bolt - Qty 1 Half Test Plug O-Ring 10.85" OD x ½” dia. Chemical Injection Valve (Annular Injection) @ 13,804' MD 3/8" Control Line to Surface 1/4” Control Line to top of 1 st Seal ODSN-17 Wellbore Schematic 6-1/8” Upper Lateral TD at 20,940' MD / 6,290' TVD 16" 11-3/4" 7" 7" Tieback 9-5/8" 6-1/8” L1 Lower Lateral TD at 19,695' MD / 6,258' TVD SSSV GL GL GLM #3 DGLV GLM #1 5/16" OV Pre-Installed D E F K GL G H GLM #2 DGLV L J I 2-7/8" Tubing PROPOSED 1-24-2025 A B C Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 109#, H-40 NA Surface 158' NA 11-3/4" Surface 60#, L-80, Hydril 521 10.772" Surface 4,660' NA 9-5/8" Intermediate 1 40#, L-80, Hydril 521 8.835" 4,497' 10,978' 0.0758 7" Int 2 Tieback 26#, L-80, BTC-M 6.276" Surface 10,844' 0.0383 7" Intermediate 2 26#, L-80, Hydril 521 6.276" 10,830' 14,106' 0.0383 4-1/2" Upper Liner 12.6#, L-80, Hydril 521 3.958" 13,953' 20,940' NA 4-1/2" Lower Liner 12.6#, L-80, Hydril 521 3.958" 14,265' 19,695' NA 3-1/2" Upper Tubing 9.2#, L-80, TC-II (2 joints) 2.992" 35' 100' 0.0087 2-7/8" Lower Tubing 6.4#, L-80, IBT-M 2.441" 100' 13,753' 0.0058 TUBING DETAIL CASING DETAIL No. Upper Completion Equipment MD(ft) TVD(ft) ID (in) A GE Tubing Hanger 34 34 2.9500 B 3-1/2" 9.2# L-80 TC-II Tubing (2 joints) 35 35 2.992 C 3-1/2" 9.2# L-80 TC-II X 2-7/8" 6.4# IBT-M XO 100 100 2.441 D 2-7/8" 'NE' TRSSSV (to be locked out, and WL-SSSV installed)2,163 2,097 2.313 E 2-7/8" x 1" GLM #3 KBMG IBT-M Box x Pin 2,542 2,402 2.366 F 2-7/8" x 7" WFT Hydrow II ESP Packer with Packer Vent Valve IBT-M Box x Pin 2,641 2,471 2.359 G 2-7/8" x 1" GLM #2 KBMG IBT-M Box x Pin 2,761 2,550 2.366 H 2-7/8" "X" Nipple (2.313" ID) EUE Box x Pin 2,861 2,613 2.313 I 2-7/8" x 1" GLM #1 KBMG IBT-M Box x Pin 11,493 5,530 2.366 J "XN" 2.313" 2.205" No-Go IBT-M Box x Pin 11,593 5,563 2.205 K Auto Diverter Valve 13,806 6,132 NA L ESP Pump Assembly 13,809 6,133 NA End of Assembly 13,864 6,143 Lost Downhole 2017 RWO: - Qty 2 ESP seal Clamp Brackets - Qty 1 ½” Sheared Bolt - Qty 1 Half Test Plug O-Ring 10.85" OD x ½” dia. Chemical Injection Valve (Annular Injection) @ 13,804' MD 3/8" Control Line to Surface 1/4” Control Line to top of 1 st Seal 9-26 Subsurface Safety Equipment STORM CHOKE® K Safety Valves Halliburton STORM CHOKE® K safety valves are ambient- type, wireline-retrievable valves with the largest flow area of all direct-controlled safety valves on the market. They are ideally suited for high-volume, low-pressure wells. These valves are normally closed and precharged with a set dome pressure. When the well’s flowing pressure drops below the predetermined dome-pressure charge due to a rupture in flowline or surface equipment, the dome pressure and main valve spring close the valve, shutting in the well below the earth’s surface. This valve contains a detent mechanism to provide a positive snap-action closure at the predetermined disaster rate of the valve. Its bore is not restricted by a flow bean. The valve is designed to resist pressure surges. A metal- to-metal poppet valve and seat comprise the valve’s primary closure mechanism. The K valve is ideal for protecting wells with declining bottomhole pressure. This valve closes in situations where a pressure decline would not activate a valve with a flow bean. To reopen the valve, the operator must fully equalize pressure either by applying pressure in the tubing from the surface or by an equalizing prong. The valve will reopen when the tubing pressure acting on the internal piston area overcomes the dome charge. Applications • Wells with declining bottomhole pressure • High-volume, low-pressure wells • Wells with no provisions for surface-controlled valves Features • Poppet closure • Large ports with capacity for high-volume wells • Designed to resist pressure surges Benefits • Installed and retrieved under pressure by wireline methods • Adaptable to any Halliburton lock mandrel • Can be located in any Halliburton landing nipple Lock Mandrel Equalizing Sub Top Sub Valve Piston Spring Rod Valve Body Detent Mechanism Dome Pressure Chamber HAL22099STORM CHOKE® K Safety Valve Subsurface Safety Equipment 9-27 Ambient Safety Valves (Poppet-Type Closure) Nominal Size Compatible Lock Mandrel OD ID Top Thread (Box) in.mm in.mm in.mm 2 50.80 1.875 S 1.750 44.45 0.650 16.51 1 3/16 -14 UNS 1.875 X1.750 44.45 0.970 24.64 1 3/8 -14 UN 2 1/2 63.50 2.313 S 2.170 55.12 1.250 31.75 1 3/16 -12 UN 2.313 X 2.160 54.86 1.380 32.51 1 3/4 -12 UN 3 1/2 88.90 2.750 X 2.500 63.50 1.620 41.15 2 1/4 -12 SLB 4 101.60 3.313 X 3.120 79.25 2.120 53.85 2 3/4 -12 SLB 4 1/2 114.30 3.813 X 3.500 88.90 2.250-2.41 57.15-61.21 3 1/16 -12 SLB 5 127.00 4.125 X 3.880 98.55 2.41 61.21 3 1/4-12.5 SLB 5 1/2 139.70 4.562 X 4.440 112.78 2.880 73.15 4 -12-SLB 7 177.8 5.750 X 5.400 137.16 3.50 88.90 4 15/16-8 SLB Ordering Information Specify: nipple bore and lock profile, service (standard, %H2S, %CO2, amines), pressure and temperature requirements, flowing pressure at closing rate, necessity of API monogramming or other certification requirements. Part Number Prefix: poppet-closure—22KX, KS Date: 01/26/25 Test Data Test Date ??? Gross Fluid Rate 560 BLPD Flowing Well Head Pressure 300 psi Flowing Well Head Temperature 50 deg F GOR 556 scf/bbl TGLR 1875 scf/bbl Flowing Pressure Calculations Based on Hagedorn and Brown Multiphase Flow Correlation "K" Valve Setting Depth TVD 2097 ft Flowing Tubing Pressure (Pwh) 145 psi Flowing Tubing Pressure @ 2097' TVD 361 psi Valve set to close at 145 psi Pwh Closing Tubing Pressure @ 2097' tvd 361 psi "K" Valve Test Rack Set Pressure at 60 deg F 293 psi 2 7/8" 1.211 NOTE: Well needs to flow at > 145 psi Pwh Valve set to close @ < 145 psi Pwh "K" Valve Calculation Sheet ODSN-17 Valve Size & Volume Ratio From:Rixse, Melvin G (OGC) To:PB Wells Integrity Cc:Wyatt Rivard; Keith Lopez; Lau, Jack J (OGC); Regg, James B (OGC) Subject:20241230 0911 APPROVAL TO POP for K Valve Evaluation - 14 days: ODSN-17 (PTD# 210093) 14 day temporary flowback under evaluation for K valve Date:Monday, December 30, 2024 9:14:44 AM Ryan, Hilcorp is approved to flow test well ODSN-17 without a SSSV for 14 days for K valve design. 24/7 monitoring to be available to assure well integrity. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). Cc Rivard, Lopez, Lau, Regg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 27, 2024 12:54 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Keith Lopez <Keith.Lopez@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: ODSN-17 (PTD# 210093) 14 day temporary flowback under evaluation for K valve Mel, Please see answers below and let me know if AOGCC requires more information. 1. Reservoir pressure. ~2700 psi 2. Latest integrity test information. MIT-IA Passed to 2500 psi on 10/09/17 3. Latest well schematic might be helpful. See attached 4. Monitoring plan if bypassing SSSV. The SSV will be performance tested within 5 days of POP. Operator is on site 24/7 in the control room adjacent to the well bay and performs x2 daily monitoring. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Thanks, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, December 27, 2024 11:50 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Keith Lopez <Keith.Lopez@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; jim.regg <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: ODSN-17 (PTD# 210093) 14 day temporary flowback under evaluation for K valve Ryan, AOGCC would like some more information: 1. Reservoir pressure. 2. Latest integrity test information. 3. Latest well schematic might be helpful. 4. Monitoring plan if bypassing SSSV. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 27, 2024 11:14 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Rixse, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Keith Lopez <Keith.Lopez@hilcorp.com> Subject: ODSN-17 (PTD# 210093) 14 day temporary flowback under evaluation for K valve All, Producer ODSN-17 (PTD# 210093) is not operable due to tubing retrievable SSSV that does not hold DP. Previous slickline attempts to repair the valve have been unsuccessful. With AOGCC approval, we would like to flow the well for up to 14 days, obtain rate & flowing pressure data to inform a K valve design. Please reply with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _Rigless Operation Plug set Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 19,947 feet N/A feet true vertical 6,382 feet N/A feet Effective Depth measured 19,695 feet 2633'/13,969' feet true vertical 6,258 feet 2,466'/6,162' feet 7,240 psi 5,410 psi 7,240 psi 5,410 psi 8,430 psi 7,500 psi Perforation depth Measured depth 14,059-19,689 feet True Vertical depth 6,178-6,258 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 13,753' 6110' Packers and SSSV (type, measured and true vertical depth)HES/WFT/WFT TRSVESP Packer//LTP 2007'/1960' 2,633'/2,466' 13,969'/6,162' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Oooguruk - Nuiqsut Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci 4/17/2024 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3300 324-128 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A N/AN/A N/A N/AN/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355036 / ADL 355038 Oooguruk - Nuiqsut Oil Pool Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-093 / 210-140 50-703-20622-00-00 3700 Centerpoint Drive, Suite 500, Anchorage, AK 99503 3. Address: ODSN-17 N/A Length 115' 4,621' 158'Conductor Surface Intermediate-1 16" 11-3/4" Size 158' 9-5/8" 4-1/2" measured TVD Lower Liner 6,481' 5,430' Casing Structural 3,231' - 5,365' 6,210' - 6,258' 4,660' 14,265' - 19,695' Plugs Junk measured Collapse N/A 3,180 psi 3,090 psi 7,500 psi N/A 5,830 psi 5,750 psi 8,430 psi Upper Liner Tie Back Intermediate-2 10,830' - 14,106' 13,953' - 20,940' 4,660'3,285' Burst 10,844'5,320' 5,316' - 6,186' 6,159' - 6,290' 10,806' 3,276' 6,987'4-1/2" 7" 7" p k ft t Fra O s O 210 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov gio Iannucci O ti P j t M By Grace Christianson at 1:32 pm, Apr 19, 2024 RBDMS JSB 042324 DSR-4/23/24 Well Name: ODSN-17 Wellbore Name: Original Hole Well Code: 26121 Job: RIGLESS WCEI Level: N/A Daily Report Date: 3/19/2024 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 55.77 Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) -24.0 Wind NE @ 10 MPH Days LTI (days) 1,535.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Repair Halliburton Generator and continue with Wireline operations per procedure. 24h Summary Receive well from Production group. Lay out containment and spot wireline equipment. Hold lift meeting with ENI HSE, Worley, LRS, Production Operator, and Halliburton. Pre job safety meeting with all personnel. Review detail operating procedure for wire line rig up/rig down. Perform EIP walk down with Production Operator. Install lock on lock box. Perform Closure test on TRSV. Halliburton Wireline Unit Generator shut down. Waiting on Halliburton Mechanic for repairs. Operation at 07.00 Waiting for mechanic to repair Halliburton Generator. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 17:30 20:30 3.00 3.00 PROD- MAN R 12 P Tubing pressure 1135 psi, Annuli A 1624 psi, Annuli B 2 psi. Move in and spot equipment (Halliburton, Worley Crane, and Little Red) Receive Well hand over from Production and perform EIP walk Down. Perform closure test on TRSV. Bleed tubing from 1135 psi to 720 PSI and Monitor for 30 Min. Tubing pressure after 30 min 1016 psi gain 296 psi. 20:30 00:00 3.50 6.50 PROD- MAN R 24 U Halliburton Wireline unit generator shut down won’t stay running. Standby waiting on Mechanic. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Co. Man Paul.Dillon@external.eni.com 907-685-0710 Company Representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Company Representative Tommy Farris ASRC Energy Services SOA niksoa@eni.com 907-670-6606 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Joe Hladick ASRC Energy Services HSE joehladick@external.eni.com 907-670-6622 Well Name: ODSN-17 Wellbore Name: Original Hole Well Code: 26121 Job: RIGLESS WCEI Level: N/A Daily Report Date: 3/20/2024 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 55.77 Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) -17.0 Wind NE @ 10 MPH Days LTI (days) 1,536.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Continue with Wireline operations per procedure. 24h Summary Halliburton Mechanic arrive to ODS and Repair Generator on Slickline unit. Obtain Well head pressures Tubing 1032 psi, Annuli A 1624 psi, Annuli B 2 psi. Rig up second Swab valve and Halliburton PCE equipment and pressure test. Operation at 07.00 Run in hole with 2.32" No Go centralizer and flapper checker to TRSV. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 18:00 18.00 18.00 PROD- MAN R 25 TS03 Equipment Repair, Haliburton mechanic arrived on location at 14:45 HR trouble shoot and Repair Generator issues. 18:00 19:00 1.00 19.00 PROD- MAN R 1 P Pre job safety meeting. Obtain PTW from Production operator. Obtain SITP 1032 psi, Annuli A 1624 psi, Annuli B 2 psi. 19:00 22:00 3.00 22.00 PROD- MAN R 12 P Bleed off pressure from closed swab valve. Swab valve not holding pressure, Vault grease swab valve. Verify swab valve is holding pressure. Remove tree cap. Installed secondary swab valve and wireline valves. Rig up pressure control equipment. Function test wireline valves, good test. Prepare 2.34" gauge ring BHA. 22:00 00:00 2.00 24.00 PROD- MAN R 12 P Pick up lubricator and stab onto well. Pressure test lubricator to 500 PSI for 5 minutes and 3500 PSI for 10 minutes, good test. Halliburton apply 5000 psi on control line and open TRSV. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Company Representative Tommy Farris ASRC Energy Services SOA niksoa@eni.com 907-670-6606 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Joe Hladick ASRC Energy Services HSE joehladick@external.eni.com 907-670-6622 Well Name: ODSN-17 Wellbore Name: Original Hole Well Code: 26121 Job: RIGLESS WCEI Level: N/A Daily Report Date: 3/21/2024 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 55.77 Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Clear Temperature (°F) 8.0 Wind E @ 8 MPH Days LTI (days) 1,537.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Final report. No further operations. 24h Summary Halliburton Mechanic arrive to ODS and Repair Generator on Slick line unit. Rig up second Swab valve and Halliburton PCE equipment and pressure test. Run in hole and set XX plug in TRSV 2132 SLM and Pressure test. Vault installed TWC in tubing Hanger profile. Pressure test and no flow test TWC. Install Tree cap Pressure test. Rig down and move to next well. Operation at 07.00 Final report. No further operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 PROD- MAN R 15 P Slick line Run #1: 2.34" Gauge Cutter, 1.500" spang jars, 1.500" oil jars and weight bars. Run in hole with 2.34" Gauge Cutter to 70’ SLM tagged up. Pull up into lubricator with Slick line. Pumped 2 bbl. LVT with little red to see if there was ice plug @70’ ICP 950 at 2 bbl. Pumped, tubing pressure increased to 1150 psi. Run back in and tagged at 70’ SLM pulled back up into PCE. Operations to pump 20 bbl. diesel at 1 bbl. a minute. ICP 950 psi with a max pressure 1350 psi with 4 bbl. Pressure dropped to 850 psi continue to pump 20 bbl. diesel. Run in hole with 2.34 gauge cutter tagged at 70’ SLM. Pull out of hole. 06:00 10:00 4.00 10.00 PROD- MAN R 15 P Slick line Run #2: 2.32 Gauge Cutter with brush, 1.500" spang jars, 1.500" oil jars and weight bars. Run in hole with 2.32 Gauge Cutter with Brush to 70’ SLM. Observed slight bobble, worked area 6 times clean entry. Continue in hole to 1,022’ SLM tagged obstruction, work area for 30 min down to 1,133 SLM. Spang jars not working correctly. Pull out of the hole to surface clean spang jars. Trip in hole to 1,133’. Working 2.32 GR-Brush from 1,133 slm to 1,332 slm. Broke through obstruction NO- GO at 2,132’slm in the TRSV profile. Pumped 5 bbl. diesel flush tubing. Trip out of the hole. Break and lay down 2.32 GR and brush BHA. 10:00 14:30 4.50 14.50 PROD- MAN R 12 P Make up 2.31 XX Plug. Trip in hole in the controlled position to 2,132 slm set XX plug in the TRSV X profile. Trip out of the hole lay down running tools. Test XX Plug from 2,132 slm to surface with 3,500 psi for 30 min. After 30 min pressure dropped to 3,458 psi. Good test. Bleed off tubing pressure to 0 psi. Rig down Halliburton tools and PCE. 14:30 16:30 2.00 16.50 PROD- MAN R 12 P Pick up Lubricator Install TWC valve in tubing Hanger Profile. Fill Tree with Diesel and test to 3,500 psi 15 min. Good test. Bleed well head pressure down to 0 psi. Conduct a 30 min No-Flow test to confirm no flow above and below TWC valve. Good test. 16:30 18:00 1.50 18.00 PROD- MAN R 1 P Cleanup location. Prepare handover certificate and hand well to Production group. Perform walk down with Production Operator. Remove lock on lock box. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-685-0710 Company Representative Tommy Farris ASRC Energy Services SOA niksoa@eni.com 907-670-6606 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Joe Hladick ASRC Energy Services HSE joehladick@external.eni.com 907-670-6622 ODSN-17 Well Completion 6-1/8” Upper Lateral TD at 20,940' MD / 6,290' TVD 16" Conductor 11-3/4" 60# L- 80 Hydril 521 Surface Casing @ 4,660' MD / 3,285' TVD 7" 26# L-80 Hydril 521 Intermediate 2 Casing @ 14,106' MD / 6,186' TVD 7" 26# L-80 BTC-M Intermediate 2 Tie-Back Casing @ 10,844' MD / 5,320' TVD 9-5/8" 40# L- 80 Hydril 521 Intermediate 1 Casing @ 10,978' MD / 5,365' TVD 6-1/8” L1 Lower Lateral TD at 19,695' MD / 6,258' TVD 60 17 18 19 20 21 22 23 25 33 44 58 59 62 67 77 88 SSSV GL GL GLM #3 DGLV GLM #1 5/ 16" OV Pre-Installed G K O HH GL S W GLM #2 DGLV II EE AA 2-7/8" 6.4# L- 80 IBT-M Tubing (Upper Completion) Chemical Injection Valve (Annular Injection) @ 13,804' MD 3/8" Control Line to Surface 1/4” Control Line to top of 1st Seal FINAL 10-23-17 Lost Downhole 2017 RWO: - Qty 2 ESP seal Clamp Brackets -Qty 1 ½” Sheared Bolt - Qty 1 Half Test Plug O-Ring 10.85" OD x ½” dia. ODSN-17 Well Completion 6-1/8” Upper Lateral TD at 20,940' MD / 6,290' TVD 16" Conductor 11-3/4" 60# L- 80 Hydril 521 Surface Casing @ 4,660' MD / 3,285' TVD 7" 26# L-80 Hydril 521 Intermediate 2 Casing @ 14,106' MD / 6,186' TVD 7" 26# L-80 BTC-M Intermediate 2 Tie-Back Casing @ 10,844' MD / 5,320' TVD 9-5/8" 40# L- 80 Hydril 521 Intermediate 1 Casing @ 10,978' MD / 5,365' TVD 6-1/8” L1 Lower Lateral TD at 19,695' MD / 6,258' TVD 60 17 18 19 20 21 22 23 25 33 44 58 59 62 67 77 88 SSSV GL GL GLM #3 DGLV GLM #1 5/ 16" OV Pre-Installed G K O HH GL S W GLM #2 DGLV II EE AA 2-7/8" 6.4# L- 80 IBT-M Tubing (Upper Completion) Chemical Injection Valve (Annular Injection) @ 13,804' MD 3/8" Control Line to Surface 1/4” Control Line to top of 1st Seal RHC-M Installed FINAL 10-23-17 Lost Downhole 2017 RWO: - Qty 2 ESP seal Clamp Brackets -Qty 1 ½” Sheared Bolt - Qty 1 Half Test Plug O-Ring 10.85" OD x ½” dia. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: _Rigless Operation__ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No ODSN-17 9. Property Designation (Lease Number):10. Field: Oooguruk Nuiqsut Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,947'6,382' 19,695' 6,258' 2181 N/A N/A Casing Collapse Structural Conductor N/A Surface 3,180 psi Intermediate 1 3,090 psi Tie-Back 5,410 psi Intermediate 2 5,410 psi Upper Liner 7,500 psi Lower Liner 7,500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci 3/1/2024 Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4-1/2"6,987' Perforation Depth MD (ft): 13,953' - 20,940' 14,059'-19,689'6,178'-6,258'2-7/8" 158'16"115' TVD Burst 13,753' MD N/A158' 6,159' - 6,290' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355036 / ADL 355038 210-093/210-140 3700 Centerpoint Drive, Suite 500, Anchorage, AK 99503 50-703-20622-00-00 Eni US Operating Co. Inc. AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 2007/1960' 2,633'/2,466' 13,969'/6,162' Perforation Depth TVD (ft): 6.4#, L-80, IBT-M Will perfs require a spacing exception due to property boundaries? Current Pools: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Proposed Pools: 5,430'4-1/2"14,265' - 19,695'6,210' - 6,258'8,430 psi Subsequent Form Required: Suspension Expiration Date: Well Operations Project Manager March 6th, 2024 HES/ WFT /WFT 10,806'7"10,844' 4,621'11-3/4"4,660' 3,276'7"10,830' - 14,106'5,316' - 6,186'7,240 psi 6,481'9-5/8"4,497' - 10,978'3,231' - 5,365'5,750 psi Nuiqsut Oil Pool Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 5,320'7,240 psi 3,285'5,830 psi 8,430 psi m n P s 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov o Iannucci 324-128 By Grace Christianson at 9:17 am, Mar 04, 2024 DSR-3/4/24 10-404 Mar 04, 2024 March 6th, 2024 SFD 3/4/2024 X VTL 03/06/2024 SFD JLC 3/6/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.06 11:13:49 -09'00'03/06/24 RBDMS JSB 030724 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone (907) 865-3300 March 1st, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for ODSN-17 Rig-Less Intervention Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Rig-Less work Sundry for well ODSN- 17 ODSN-17 is a producer well in Oooguruk. The well was first completed in August 2010 and was placed on production. A rig workover was carried out in 2017 because of a failed ESP and the well was put back on production. Well LV currently shut down because of a failed TRSSV. The objective of this intervention is to set a XX plug in X nipple at 2861 MD. The estimated date for beginning this work is March 6th, 2024. Please find attached, for the review of the Commission, forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager y, pg March 6th, 2024 ODSN-17 Rig-Less Operation –Proposal Summary and Wellbore Schematic PTD#: 210-093/210-140 Current Status Well ODSN-17 is currently shutdown. Scope of Work The scope of work is to set a XX plug in X nipple. General Well Info Reservoir Pressure/TVD: the ODSN-17 Maximum Anticipated Surface Pressure (MASP) assuming a 0.1 psi/ft wellbore gradient from the 7” casing shoe at 6,186 ft. TVD to surface is 2,181 psi ODSN-17 MASP (3/1/24) 7" Cashing Shoe 6,186 ft. TVD BHP 2,800 psi Gradient 0.1 psi/ft MASP 2,181 psi Wellhead type/pressure rating: Vault P.C, MB-233/5000 psi BOP configuration: Rig less Slickline unit BOPE. Well type: Producer Estimated start date: March 6 th, 2024 Intervention Unit: Slickline Unit Senior Drilling Engineer: Amjad Chaudhry Amjad.chaudhry@eni.com Well Operations Project Manager: Giorgio Iannucci Giorgio.Iannucci@eni.com Procedure Summary 1. RU Slickline 2. Drift the TBG to 2961’ which is 100’ below X nipple at 2861’ MD. 3. Set an XX plug in the X nipple at 2861’ MD. Test for integrity to 3500 psi. 4. Set the TWC in the wellhead. 5. Once set, pressure test on the TWC to 3500 psi. 6. RD Slickline. 7. Hand the well over to production. Below the current schematic of the well: Planned Completion will be the same Well head Schematic rM%hi La I r Ls v STATE OF ALASKA NOV Q 9 Z017 AL.OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet❑ Other: Run ESP CI 2.Operator Caelus Natural Resources Alaska,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development El Exploratory❑ 210-093/210-140 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20622-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 355038 ODSN-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 19,947 feet Plugs measured N/A feet true vertical 6,382 feet Junk measured N/A feet Effective Depth measured 19,695 feet Packer measured See attached,pg.3 feet true vertical 6,258 feet true vertical See attached,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4,621' 11-3/4" 4,660' 3,285' 5,830 psi 3,180 psi Intermediate 1 6,481' 9-5/8" 10,978' 5,365' 5,750 psi 3,090 psi Tie-Back 10,806' 7" 10,844' 5,320' 7,240 psi 5,410 psi Intermediate 2 3,276' 7" 14,106' 6,186' 7,240 psi 5,410 psi Upper Liner 6,987' 4-1/2" 20,940' 6,290' 8,430 psi 7,500 psi Lower Liner 5,430' 4-1/2" 19,695' 6,258' 8,430 psi 7,500 psi Perforation depth Measured depth See attached, pg.2 feet SCANNED a1 1 � True Vertical depth See attached, pg.2 feet NOV t Tubing(size,grade,measured and true vertical depth) 2-7/8",6.4# L-80,IBT-M 13,864'MD 6,143'TVD Packers and SSSV(type,measured and true vertical depth) See attached,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 233 163 0 898 542 Subsequent to operation: 310 111 17 370 422 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations (] Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 317-246 Authorized Name Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Co ' etion Engineer Contact Email: rami.iasser(a�caelusenergy.com_ Authorized Signature: / 301 Date: II/' IFf Contact Phone: 907-343-2182 Form 10-404 Revised 4/2117 e P-/3 /7 � Submit Original Only • 116'3(/`7 R.EEiVi S L \- 3'v l d Lul7 • • Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations Well: ODSN-17 Upper Lateral Top(MD) Top (TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,059 6,178 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,274 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,543 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,762 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,966 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,173 6,213 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,376 6,220 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,581 6,223 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,782 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,988 6,217 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,210 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,415 6,227 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,619 6,236 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,824 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,029 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,236 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,442 6,230 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,647 6,228 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,851 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,053 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,275 6,251 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,480 6,239 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,683 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,886 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,090 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,297 6,265 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,501 6,262 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,702 6,258 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,907 6,256 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,114 6,246 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,321 6,256 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,525 6,270 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,729 6,278 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,894 6,287 • • Lower Lateral Top(MD) Top(TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,453 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,756 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,958 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,167 6,213 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,374 6,220 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,795 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,996 6,217 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,203 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,409 6,227 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,614 6,236 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,820 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,027 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,227 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,434 6,231 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,854 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,058 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,263 6,252 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,468 6,240 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,670 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,876 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,078 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,280 6,265 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,486 6,263 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,689 6,258 • • Attachment 3 AOGCC Form 10-404 Sundry Report Box 11 - Packers & SSSV Well: ODSN-17 SSSV MD TVD HES WellStar TRSV w/ "X" Profile 2,163 2,097 PACKERS 2-7/8" x 7" WFT Hydrow II ESP Packer 2,641 2,471 WFT "NTH" Liner Top Packer 13,969 6,162 Oil Swell Packer 14,364 6,219 •CAELUOperations Summary Report- State• Well Name: ODSN-17/ODSN-17L1 Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 7/30/2017 7/31/2017 20,952.0 00:00 7/30/17-00:00 7/31/17 (SBHPS/Pre-RWO) *Complete well handover from Ops to Wells. *MIRU HES Slickline w/.125 wire. *Drifted w/2.34"gauge ring to locked-out TRSV @ 1,977'slm. *Pulled 2-7/8"FXE SSSV from locked-out TRSV©1,977'slm. *RIH with 2.34"No-Go flapper checker assembly.Tag TRSV @ 1,977'slm.Verify flapper is open. *Ran Spartek dual tandem gauges as per program. 1st stop-10 min in lubricator 2nd stop-20 min at 13,676'slm 3rd stop-20 min at 13,476'slm 4th stop-10 min stop in lubricator. *Verify good data.HES will send finalized report to Caelus reservoir team. *Drifted w/2.25"cent&2.30"gauge ring to X-nipple @ 9,860'slm. *Made 2 attempts to set X-catcher sub in X-nipple©9,860'slm.Pulled catcher sub back out of hole due to poor action. *Discuss plan forward w/Wells Superintendent. *LRS pumped 40 bbls of diesel down tubing. *Pulled 1.5"Orifice GLV(RK)from GLM#1 @ 9,751'slm. *Set 1.5"Dummy GLV(RK)in GLM#1 @ 9,751'slm. *Pulled 1.5"Dummy GLV(RK)from GLM#2 @ 2,377'slm. 7/31/2017 8/1/2017 20,952.0 00:00 7/31/17-00:00 8/1/17 (SBHPS/Pre-RWO) *Flag run.RIH w/2-7/8"Xline,locate X-nipple @ 2,490'slm/2,519'MD.RIH 138.5'to 2628' slm/2,657'MD.This is center of first full tubing joint below WFT Hydrow II Packer(Jt#348). Flag Wire. *Standby for memory tools to arrive at ODS to complete program. *PJSM w/Wells Group Supervisor,Ops,SLB,&HES.Make"All Call"for explosive operations in Well Bay#2.Secure area. *RIH SLB Efire w/1.52"x 10'gun(4 spf,41 total shots of.25").Run through arming&firing sequence.Pull up to flag @ 2628'slm/2,657'MD.Adjust depth to put center of perf gun @ 2,657.89'MD. *Fire perf gun 2,652'-2,662'MD.First full tubing joint(Jt#348)below WFT Hydrow II Packer= 2,642'-2,673'MD. *Make"All Call"for explosive operations in Well Bay#2.Secure area. 8/1/2017 8/2/2017 20,952.0 00:00 8/1/17-00:00 8/2/17 (Pre-RWO) *SLB Efire made 2 attempts to fire stringshot across WFT Hydrow II Packer.Efire tool did not fire on both attempts. *Discuss plan forward w/Anchorage team. *Standby for HES Maxfire memory tool&stringshot to arrive©ODS. *RIH w/HES Maxfire memory tool&stringshot w/bow spring centralizer.Run down to flag and adjust depth=top of stringshot @ 2,633'MD.Fire stringshot across WFT Hydrow II Packer. *Drifted w/2-7/8"BLB&2.32"gauge ring to TRSV @ 1980'slm. *Set 2-7/8"FXE(SER#FXE P-10)in Locked-Out TRSV @ 1980'slm. *Perform closure test on SSSV.Monitor for 15 min.Good test. *Control line integrity for positive test but doesn't want to bleed to zero. *Discuss control line w/Wells Group Superintendent.Decision to let v-packing swell through the night and check in morning. *LRS freeze protected IA w/80 bbls of diesel. *Secure well.RDMO HES Slickline. 8/2/2017 8/3/2017 20,952.0 00:00 8/2/17-00:00 8/3/17 (Pre-RWO) *Troubleshoot control line integrity.Control line holds positive pressure but will not bleed to zero. *Mix up 3 cans of GX sealant w/hydraulic oil. *Bleed at hydraulic oil off control line until it swapped to gas. *Perform closure test on SSSV.Bleed tubing pressure above flapper from 1100 psi to 3 psi. Monitor for 30 minutes.Flapper holding solid.Control line pressure is 600 psi and will not bleed to zero indicating lower packing stack on SSSV is possibly leaking. *Pressure control line up to 4500 psi w/GX treated hydraulic oil. *Maintain 4500 psi on control line and monitor through the night to let GX sealant cure downhole. Page 1/4 Report Printed: 11/8/2017 Operations Summary Report- State• CAELL Well Name: ODSN-17/ODSN-17L1 Alaska Hart Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gat) Summary 8/3/2017 8/4/2017 20,952.0 00:00 8/3/17-00:00 8/4/17 (Pre-RWO) *Continue monitoring control line pressure. Maintain 4500 psi on control line and monitor to let GX sealant cure downhole. *Discuss plan forward w/Anchorage team. *Maintain 4500 psi on control line and monitor through the night to let GX sealant cure downhole. 8/4/2017 8/5/2017 20,952.0 00:00 8/3/17-00:00 8/4/17 (Pre-RWO) *Attempt to bleed control line to zero.Control line slowly pressures back up to 800 psi.GX sealant did not seal leak point. *Perform closure test on FXE SSSV.Bleed tubing pressure from 1000 psi to 60 psi.Monitor pressures for 30 minutes.Good closure test. *Vetco installed BPV in tubing hanger.Hang BPV sign on flowline. *Complete well handover from Wells Group to Operations. Well Status:T x IA freeze protected w/diesel to 2500',GLM#1 @ 9,757'MD has 1.5"Dummy GLV installed.GLM#2 @ 2,434'MD has empty pocket.Shot holes in first full tubing joint below packer @ 2,652'—2,662'. Shoot string shot across WFT Hydrow II Packer @ 2,633'—2,638'MD. 2-7/8"FXE installed in locked-out TRSV @ 2,007'MD.BPV installed in tubing hanger. 10/2/2017 10/3/2017 20,952.0 8.50,Accept ria from ODSN-04 to ODSN-17 10/3/2017.00:00 , MIRU on ODSN-17 -Bleed and monitor well tubing and IA pressures Bullhead IA with 100bbl w/8.5ppg seawater c") �� Bullhead tubing with 596bb1 w/8.5ppg seawater �{( -Bleed and monitor well tubing and IA pressures Bullhead tubing and IA with 650bbls seawater � -Bleed and monitor well tubing and IA pressures Build 9ppg brine while bleeding tubing and IA back to OPS flowback tank 10/3/2017 10/4/2017 20,952.0 9.00 Flowback well to OPS flowback tank while building 9ppg brine Bullhead 650bb1 at 6bpm Shut in and monitor pressure for 2hrs: Bleed back remaining well pressure to OPS flowback tank and flowback trailer until dead -Monitor for 30min to confirm dead well,OK Install BPV,Close PW,Close TRSSSV NU Tree,Install test dart,NU BOPE Attempt to shell test BOPE,Failed -Replace VG seal between top of riser and BOPE stack Test BOPE per sundry#317-246 -2-7/8"x 5"VBR's,Annular,&Valves pressure tested to:250psi low,3500psi high -Test Joints:2-7/8",4" -Result:All tests prior to midnight passed. -The following two tests which were finished after midnight and passed --Lower IBOP&Manual choke --Lower VBR with 4"test joint -AOGCC:Test witness Waved by AOGCC rep Guy Cook at 10/2/2017 17:59 Page 2/4 Report Printed: 11/8/2017 Operations Summary Report- State Well Name: ODSN-17/ODSN-17L1 CAE LL S ,taska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 10/4/2017 10/5/2017 20,952.0 9.00 Complete BOPE test -Lower IBOP&Manual choke -Lower VBR with 4"test joint -Tested to:250psi low,3500psi high -All tests passed -Tested per sundry#317-246 -AOGCC:Test witness waved by AOGCC rep Guy Cook at 10/2/2017 17:59 Pull test dart and BPV -Well went on vacuum after pulling BPV 0 Pull tubing hanger and packer ,�(,, POOH w/2-7/8"6.4#L-80 IBT-M ESP completion from 13,717'to 12,914' V Back lash drill line -Re-spool drill line and cut and slip due to drill line damage Significant ice build-up on upper third of mast,drill line,and torque tube. -Remove ice from mast. POOH w/2-7/8"ESP completion from 12,914'to 11,113' Fill hole 5bbls/30min plus 150%displacement 10/5/2017 10/6/2017 20,952.0 9.00 POOH with 2-7/8"6.4#L-80 IBT-M ESP Completion from 11,113'to 79' LD ESP from 79'to surface and close blinds Clean rig floor and hold a well control drill 10/6/2017 10/7/2017 20,952.0 9.00 Install 6-3/8"wear bushing PU and MU cleanout BHA on 4"DP from surface to 2,650' -Circ and Cond hole POOH with cleanout BHA from 2,650'to surface and RB cleanout BHA Remove 6-3/8"wear bushing Prep to run 2-7/8"ESP completion MU ESP from surface to 99' -DGU not functioning Troubleshoot DGU -Mobilize replacement DGU from Deadhorse via boat 10/7/2017 10/8/2017 20,952.0 9.00 RIH w/2-7/8"6.4#L-80 IBT-M ESP completion from 67'to 7,712' Cont filling hole w/5bbls/30min Circ 22bbls at 2bpm at 7,231' -12bbl to gain returns 10/8/2017 10/9/2017 20,952.0 9.00 RIH w/2-7/8"6.4#L-80 IBT-M ESP completion from 7,712'to 13,830' -MU Weatherford ESP packer and TRSSSV Page 3/4 Report Printed: 11/8/2017 • Operations Summary Report- Stat• CAEUJS Name: ODSN-17/ODSN-17L1 Ataska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(tblgal) Summary 10/9/2017 10/10/2017 20,952.0 9.00 Finish ESP and control line penetrations through tubing hanger Land tubing hanger w/43klbs at hanger&RILDS Pressure test tubing hanger body seals to 5000psi/10min Fill tubing with 6bbls and drop 1-5/16"ball and rod from surface Pressure tubing up to 1000psi and check for surface leaks,None Increase pressure to 3500psi and attempt to pressure test,Failed with 200psi pressure drop Troubleshoot failed tubing pressure test Pressure test 2-7/8"x 7"IA to 1000psi to confirm Locker set with tubing opgt Good RU HAL slickline on lubricator,RIH and unseat ball and rod POOH with ball and rod 100' �f..� -Bullhead 32bbls @ 4.5bpm, RIH 100'with ball and rod and reseat on RHC-M Pressure test 2-7/8"tubing to 3500psi/30min,charted,Passed Attempt to shear off ball and rod with slickline POOH with slickline to surface -Ball and rod still attached and tubing with 3bbls and drop ball and rod from surface Build and maintain 1500psi on tubing with test pump. -IA unable to maintain 1500psi without test pump Pressure test 2-7/8"x 7"IA to 2500psi/30min,charted,Passed J� Bleed tubing pressure down to shear DCK valve in GLM#3 t/Y RD HAL slickline Install TWC Pressure test TWC from below down IA to 1500psi/10min,charted,failed -Pressure test likely failed due to ball and rod -Discuss with Drilling Manager. Decision to continue per program if fluid is not visually leaking past TWC Vacuum fluid out of stack and confirm fluid is not visually leaking past TWC ND BOPE,Close TRSSSV,Terminate control lines 10/10/2017 10/11/2017 20,952.0 9.00 ND BOPE&riser,NU Tree Test tree void to 5000psi/5min Test tree to 5000psi/5min Pull TWC with lubricator Circ 101bbIs diesel freeze protection @/bpm down 2-7/8"x 7"IA and up 2-7/8"tubing Install TWC RDMO ODSN-17 to ODSN-16 Pull BPV on lubricator Bullhead 650bbIs 8.5 filtered/treated seawater down tubing and IA Shut in and monitor tubing and IA -30min,Initial:2000psi,Final 300psi Open tubing and IA to OPS flow back tank -30min,Initial:250psi,Final"100psi Begin building 800bbIs of 9ppg brine Release rig from ODSN-17 on 10/10/2017 at 23:59 10/20/2017 10/21/2017 20,952.0 9.00 00:00 10/20/17-00:00 10/21/17(Post-RWO) *Complete well handover from Ops to Wells Group. *GE pulled TWC utilizing hydraulic lubricator. *MIRU HES Slickline w/.125 wire. *Pulled Ball&Rod from X-nipple @ 2,828'slm. *Pulled 1"DCK Shear Valve(BEK)from GLM#3 @ 2,518'slm. *Set 1"Dummy GLV(BK)in GLM#3 @ 2,518'slm. *No pressure on IA to perform negative test on IA. *Pulled RHC plug from X-nipple @ 2,834'slm. *Secure well.RDMO HES Slickline. *Complete well handover from Wells to Ops. Page 4/4 Report Printed: 11/8/2017 • • ODSN-17 Well Completion FINAL 10-23-17 No. Upper Completion Equipment MD(ft) TVD(ft) Tubing Hanger 31 33 .41BT-1 Pin x 3-1;2„ 0.2#TC-Il Pin 1-iu Cio-ai J 16" L L-80 9.2#tubing joint TC II Box x Pin Joints) : 0 Conductor GLM#3 iiii! 1£0 TC-II Box x 2-7.8"6,48IBT-11 Pin C'rossoiter DGLV iiii — _ - - -'=L-80 IBT-M Tubing 0 0 IBT r1 151?Pi t+ i,.,lit.Box x Pin Cgi �0 IBT-1l Box x Pin -Control line , r R 0 x x Pin GLM#2 c S 1 = . - -80 IBT-M Tubing DGLV • ....80 IBT-f.1 15ft Pup Joint Box x Pin $ ILI t. ;"GLM#3 KBMG IBT-U Box x Pin _ - A L 2-7.8"6.481-80 1BT-11 15ft Pup Joint Box x Pin U 2-718 6.48 L-80 IBT-M Tubing 11-3/4"60#L- N 2-7+8"6.48 L-80 IBT-M 15ft Pup Joint Box x Pin 2-7/8"6.5#L- 80 C 278"x7"WFTHydrowIIESP Packer n.i€bPacker Vent Valve IBT-LI Box x , ,i'1 Hydril 521 P 2-18'"6.441-80 1BT-fol 5ft Pup Joint Box x Pin 80 IBT-M Ci 2-7/8 6.4#1...-80 IBT-M Tubing Tubing Surface R 2-7T8"6.4#1-80 IBT-M 15ft Pup Joint Box x Pin (Upper Casing S 2-7'8"x 1"GUI#2 KBMG IBT-P,i Box x Pin 2761 2550 Completion) @ 4,660' MD/ T 2-78"6.481-80 18T-M1 15ft Pup Joint Box x Pin 3,285'TVD U 2-7/8'6.48 L-80 IBT-M Tubing V 15 ft. 2-718"6.48 IBT-U Box x 2-7/8"6.48 EUE Pin 1-80 Crossover Pup Joint Box x Pin 7"26#L-80 W 2-7/8""X"Nipple(1313"ID)EUE Box x Pin 2861 2613 BTC-M X 15ft. 2-718"6.44 EUE Box x 2-7J8"6.48IBT-M Pin L-80 Crossover Pup Joint Box x Pin Intermediate 2 Y 2-7/8"6.4#L-80 IBT-M Tubing Z 2-718"6.48 L-80 1BT-M 15ft Pup Joint Box x Pin GLM#1 5/ Tie-Back AA 2-7t8"x 1"GLM#1 KBMG IBT-M Box x Pin . 11493 5530 16"OV GL j 0 Casing BB 2-18"6.48 L-80 IBT-M 15ft Pup Joint Box x Pin Pre-Installed:;:; @ 10,844' MD/ CC 2-7/8'6.4#L-80 IBT-81 Tubing 5,320'TVD DD 15 ft. 2-7/8"6.44 IBT-1I Box x 2-718"6.4#EUE Pin 1-80 Crossover Pup Joint Box x Pin EE fI"2313"2.205"No-Go t8T-MBoxxPin 11593 5563 FF 15 ft. 2-778"6.4#EUE Box x2-718"6.4#IBT-M Pin 1-80Crossover Pup JointBoxx Pin .. GG 2-718"6.48 L-80 IBT fwl Tubing HH Auto Diverter Valve 13806 6132 II ESP Pump Assembly 13809 6133 9-5/8"40#L- End of Assembly 13864 6143 80 Hydril 521 (®i Intermediate 1 Chemical Injection Valve(Annular Casing spi.® Injection)@ 13,804'MD @ 10,978' 3/8"Control Line to Surface MD/5,365' • 1/4" Control Line to top of 1st Seal TVD » CQ ie Lost Downhole 2017 RWO: -Qty 2 ESP seal Clamp Brackets 4 9 -Qty 1 '/2"Sheared Bolt 7"26#L-80 -Qty 1 Half Test Plug O-Ring 10.85"OD x'/2"dia. Hydril 521 ;1 Intermediate \ 2 Casing \ \ @ 14,106' \ \ 20 MD/6,186' � '�` e6-1/8" Upper Lateral TD TVD i z, at 20,940'MD/6,290'TVD • `rT 25 33 - ---i,44 58 1., 8,� u 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I 22 \ 01 \ �� UP_ \ 60 \ o T o 0 0 o T o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 / 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .',2_,), 6-1/8" L1 Lower Lateral TD at 10--———0 0 19,695'MD/6,258'TVD • • ODSN-1 7 Well Completion FINAL 10-23-17 iii !ili INo. Upper Lateral Equipment MD(ft) ND(ft) , I )k17 WFT PBR Tie Back Sleeve 1511 13 953 6 159 ''' 18 WFr"NTH' Liner Top Pkr 13,969 6..162 J 16" ' Conductor 19 WFT"PHR"Rotating Hyd Set Liner Hanger 13,972 6.163 GLM#3 '€ '�"" O 20 4-1/2"12.601 L-80 Hydril Pupjt 411(Ported wt 6 1/2 holes) 14.059 6.178 DGLV ii — © 21 Weatherford Sliding Sleeve 14,269 6,211 22 4-1/2"1260#L80 Hydril Pupjt Olt(Parted w!6 1/2 holes) 14.274 6.212 E• 23 Oil Swell Packer 14364 6219 • 24 4-112" 12.601#L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 14.543 6.219 GLM#2 G ,J S 25 Resman Tracer Pup 14.709 6.219 Dcl.0 IX X 26 4-112" 12.60#L-80 Hydril Pupjt 41t(Ported WI 6 1/2 holes) 14.762 6.218 0 27 4-1/2"12.60#L-80 Hydril Pupjt 41(Ported w/6 112 holes) 14,966 6,212 28 4-1,/2"12.60#L-80 Hydril Pupjt 4R(Ported w16 1/2 holes) 15,173 6.213 11-3/4"60#L- 29 4-1/2"12.60#L-60 Hydril Pupjt 41t(Ported w/6 1/2 holes) 15.376 6,220 2-7/8"6.5#L 80 30 4-1/2"12.60#L-80 Hydril Pupjt 41(Ported wi 6 1/2 holes) 15,581 6,223 80 IBT-M Hydril 521 31 4-1/2"12.60#L-80 Hydril Pupjt 41(Ported w/6 1/2 holes) 15.782 6,219 Tubing Surface 32 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported w/6 1/2 holes) 15.988 6,217 (Upper Casing 33 Resman Tracer Pup 15.995 6.217 Completion) ©4,660'MD/ 34 4-1/2"12.60#L-80 Hydril Pupjt 41(Ported w1 6 1/2 holes) 16,210 6,218 3,285'TVD 35 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported w/6 1/2 holes) 16,415 6,227 36 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported wi 6 1/2 holes) 16,619 6,236 7"26#L-80 37 4-112"1260#L-80 Hydril Pupjl 411(Ported wi 6 1/2 holes) 16,824 6,244 BTC-M 38 4-112"12.60#L-80 Hydril Pupjt 411(Ported w/6 1/2 holes) 17,029 6 244 Intermediate 2 39 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported w/6 1/2 holes) 17,236 6.235 Tie-Back 40 4-1/2"12.60#L-80 Hydril Pupjt 411(Ported w/6 1/2 holes) 17,442 6,230 GLM#1 5/ Casing 41 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported w/6 1/2 hales) 17,647 6.228 16"OV J nn 42 4-1/2"12.60#L-80 Hydril Pupil'41[(Ported w/6 1/2 holes Pre-Installe @ 10,844' MD/ Pl ) 17,851 6,243 III 5,320'TVD 43 4-1/2"12.60#L-80 Hydril Pupjt Oft(Ported w!6 1/2 holes) 18,053 6,254 44 ResmanTracerPup 18,182 6,254 45 4-1/2" 12.60#L-80 Hydril Pupjt Oft(Ported w/6 112 holes) 18,275 6,251 rI 46 4-1/2"1260#L-80 Hydril Pupjt 41t(Ported w/6 1/2 holes) 18,480 6,239 47 4-1/2"12.60#L-80 Hydric Pupjt 411(Ported w/6 112 holes) 18,683 6,235 48 4-1/2"12.60#L80 Hydril Pupjt 41t(Ported w/B 1/2 holes) 18,886 6,243 9-5/8"40#L- 49 4-1/2"12.60#L-80 Hydril Pupjt 411(Ported w/6 1/2 boles) 19,090 .6,254 ® 80 Hydril 521 ' r • Chemical 50 4-1/2"12.60#L-80 Hydnl Pupjt Oft(Ported w/6 1/2 holes) 19,297 6.265 Intermediate 1 Injection 51 4-1/2"12.60#L-80 Hydril Pupjt 41t(Ported wI6 1/2 holes) 19,501 6,262 Casing .u..® Valve 52 4-1/2"12.60#L-80 Hydril Pupjt 41(Ported w/6 1/2 toles) 19,702 6 258 © 10,978' (Annular 53 4-12" 12.60#L-80 Hydril Pupjt 41t(Ported w/6 1/2 holes) 19,907 6.256 MD/5,365' 0 Injection)@ 54 4-1/2" 1260#L-80 Hydnl Pupjt 411(Ported w/6 1/2 holes) 20,114 6,246 TVD 13,804'MD 55 4-1/2"12 60#L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 20,321 6,256 3/8"Control 56 4-1/2"12.60#L-80 Hydra Pupil Oft(Ported w/6 1/2 hales) 20,525 6270 ( ] s Line to 57 4-1/2"1260#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 20,729 6,278 =' Surface 58 4-1/2"12.60#L-80 Hydril Pupjt 411(Ported w/6 1/2 holes) 20,894 6.287 g 1/4" Control 59 Liner Shoe(PLUGGED)w/4-1/2"Hydril 521 20,939 6 289 7"26#L-80lill Line to top of End c Assen n , 20,940 6 290 Hydril 521 1st Seal Intermediate 1 2 Casing 1 \ Lost Downhole 2017 RWO: @ 14,106' \ ` 20 -Qty 2 ESP seal Clamp Brackets MD/6,186' �� Qty 1 Y:"Sheared Bolt 6-1/8" Upper Lateral TD TVD r \ zi 23 -Qty 1 Half Test Plug 0-Ring 10,85"OD x /2"dia, at 20,940'MD/6,290'TVD I \N. \` 33 44 58 _——1 44941,4--0 1 I ) \ °° 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 I I o 0 0 0 0 0 0 0 0 0 0� 00 0, 0 0 0 0 0 0 0 0 0 0 1 22 \�� ° 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 �1 ��_ __. ___,. 1 60 —, 1 .., 1 0 o 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 \J ‘\ o o 0 0 0 0 0 0 0 0 0 0 0 o y 0 0 0 0 0 0 / 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 as I 6-1/8" L1 Lower Lateral TD at – sz ––––0 " 19,695'MD/6,258'TVD i IP ODSN-17 Well Completion FINAL 10-23-17 No. Lower Lateral Equipment MD(ft) TVD(ft) 60 WeatherfardAluminum Billet 14 265 6210 .. 16" 61 4-1/2' 12 60#L-80 Hydril Pupjt 411(Ported wi 6 1i2 holes) 14 453 6.219 GLM#3 € ••• v O Conductor 62 Resman Tracer Pup 14 665 6 219 • Ill 63 4-1t2' 12 60#L-80 Hydril Pupjt 41/(Ported w/6 1/2 holes) 14 756 6.218 DGLV ii,i, ©.: 64 4-1!2" 12.60#L-60 Hydril Pupjt 4ft(Ported wi 6 1 r2 holes) 14 958 6 212 a. 65 4-1;2" 12 60#L-80 Hydril Pupjt 4ft(Ported-1,,6 1±'2 holes) 15 167 6 213 11111' 1 ►l�' 66 4-1;2` 12 60#L-80 Hydnl Pupjt 411(Ported:v,6 1,2 holes) 1 374 6 220 0 67 Resman Tracer Pup 151143 6 224 GLM#2 a 68 4-12' 12 60#L-80 Hydril Pupjt 411(Ported;r,,+6 1.2 holes) 15 795 6 219 DGLV 0 © 69 4-112' 12 60#L-80 Hydril Pupjt 4ft(Ported wi 6 1;2 holes) 15.996 6.217 Al © '. 70 4-1r2' 12.60#L-80 Hydril Pupjl 411(Ported wi 6 1/2 holes) 16,203 6.218 71 4-1/2' 12.60#L-80 Hydril Pupjt 41t(Ported wi 6 1/2 holes) 16.409 6.227 11-3/4"60#L- 72 4-1}2` 12.60#L-80 Hydril Pupjt 41/(Ported w/6 1/2 holes) 16614 6,236 2-7/8"6.5#L. 80 73 4-112 12 60#L-80 Hydril Pupjt 411(Ported w/6 1/2 holes) 16 820 6,244 80 IBT-M Hydril 521 74 4-1/2' 12 60#L-80 Hydril Pupjt 411(Ported wi 6112 holes) 17.027 6 244 Tubing Surface 75 4-112' 12.60#L-80 Hydril Pupjt 411(Ported wI 6 1/2 holes) 17.227 6.235 (Upper Casing 76 4-12 12 60#L-80 Hydril Pupjt 411(Ported w/61/2 holes) 17,434 6.231 Completion) @ 4,660'MD/ 77 Resman Tracer Pup 17,643 6.228 3,285'TVD 78 4-1/2' 12 60#L-80 Hydril Pupjt 4ft(Ported w/61/2 holes) 17.854 6.243 79 4-1/2' 12 60#L-80 Hydril Pupjt 411(Ported wi 6 1/2 holes) 18,058 6254 7"26#L-80 80 4-1/2' 12 60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 18,263 6.252 BTC-M 81 4-1/2' 12.60#L-80 Hydril Pupjt 411(Ported ori 61/2 holes) 18,468 6,240 Intermediate 2 82 4-1/2' 12.60#L-80 Hydril Pupjt 411(Ported w/61/2 holes) 18.670 6.235 GLM#1 5/ Tie-Back 83 4-1/2' 12.60#L-80 Hydril Pupjt 411(Ported w/6 1/2 holes) 18.876 6.243 16"OV ^^ Casing 84 4-1/2' 12.60#L-80 Hydril Pupjt 411(Ported ori 61/2 holes) 19,078 6.254 a J 0 85 4-1/2' 12-60#L-8O Hydril P t (Ported w/61/2 holes);;@ 10,844'MD/ Y upl 4ft fP 19,280 6,265 5,320'TVD 86 4-112" 12.60#L-80 Hydril Pupjt 4ft(Ported w/61/2 holes) 19,486 6 263 ii 87 4-1/2' 12.60#L-80 Hydril Pupjt 4ft(Ported w/61/2 holes) 19,689 6.258 88 liner Shoe(PLUGGED)w/4-1/2"Hydril 521 19,694 6.258 Errol of Assembly 19,695 6.258 EE A 9-5/8"40#Lam - 80 Hydril 521 2167 Intermediate 1 Chemical Injection Valve(Annular Casing ,r'', ® Injection)@ 13,804'MD @ 10,978' 3/8"Control Line to Surface MD/5,365' 0 1/4"Control Line to top of 1st Seal TVD 0 » iii410411 18 Lost Downhole 2017 RWO: `' -Qty 2 ESP seal Clamp Brackets is -Qty 1 Y"Sheared Bolt 7"26#L-80':'i -Qty 1 Half Test Plug 0-Ring 10.85"OD x Y:"dia. Hydril 521 Intermediate t 2 Casing 1 \ @ 14,106' \ \ 20 MD/6,186' \ 6-1/8" Upper Lateral TD TVD zi ....0, at 20,940'MD/6,290'TVD • 84.1 # 25 33 44 58 --- I 1 T, u 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 0 0 0 0 0 0 1 1 I �° 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 22 `a, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 01 1 60 \ r^ o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o \ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 88 sz ---- s� 1 6-1/8"L1 Lower Lateral TD at 19,695'MD/6,258'TVD tioFTB • � �//7 ,'87 THE STATE Alaska Oil and Gas -�� - of LAsKA Conservation Commission _:_ 333 West Seventh Avenue `� ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 SFA ;9 Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser Senior Staff Completion Engineer Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 SCANNED JUL L 0 0 2017 Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-17 Permit to Drill Number: 210-093 Sundry Number: 317-246 Dear Mr. Jasser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this day of June, 2017. RBDMS tc. JUN 2 6 2017 RECEIVED • 0 JUN 13 201? STATE OF ALASKA P`/S e(Z d r; , l� ALASKA OIL AND GAS CONSERVATION COMMISSION C " APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend El Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run ESP El• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Numb Caelus Natural Resources Alaska,LLC i Exploratory ❑ Development I]. 210-093(.210-140 " I. t i 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 50-703-20622-00-00 1 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-17 - Will planned perforations require a spacing exception? Yes ❑ No I] 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 355038 ' Oooguruk-Nuiqsut Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19,947' 6,382' 19,695' 6,258' 1,715 psi 17 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4,621' 11-3/4" 4,660' 3,285' 5,830 psi 3,180 psi Intermediate 1 6,481' 9-5/8" 4,497'-10,978' 3,231'-5,365' 5,750 psi 3,090 psi Tie-Back 10,806' 7" 10,844' 5,320' 7,240 psi 5,410 psi Intermediate 2 3,276' 7" 10,830'-14,106' 5,316'-6,186' 7,240 psi 5,410 psi Upper Liner 6,987' 4-1/2" 13,953'-20,940' 6,159'-6,290' 8,430 psi 7,500 psi Lower Liner 5,430' 4-1/2" 14,265'-19,695' 6,210'-6,258' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attachment pg.2 'A See attachment pg.2 2-7/8" 6.4#,L-80, IBT-M 13,753' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 4 12.Attachments: Proposal Summary D Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development CI• Service ❑ 14.Estimated Date for 15.Well Status after proposed work. 10/6/2017 Commencing Operations: OIL II WINJ ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Com_pllleeti�on Eng inene-r (�/ Contact Email: rami.iasserancaeluseneray.com Authorized Signature: --����P^"tiJASSG/ Date: ` /�Z'/7 Contact Phone: 907-343-2182 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3c7-2'1L Plug Integrity ❑ BOP Test 17 Mechanical Integrity Test ❑ Location Clearance ❑ : ( 12d 1 VI Other: i 3500 n Si C t —T s f'"' Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS LL. IA L 6 2017 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /t.:..) —Li(i 9 / APPROVED BY Approved by: ( y�Fh COMMISSIONER THE COMMISSION Date: 6 - 2,0_ /7 fis3t$I7--- #I/ 17 G f -J7 Submit Form and Form 10-403 Revised 4/2017 OR App�veld iq1jO[.: valid for 1 months from the date of approval. Attachments in Duplicate r 0 CAEL1JS June 8, 2017 RECEIVED JUN 1 3 Li,/ State of Alaska AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-17 Sundry Application for ESP Change-Out REF: Approved Permit to Drill #'s 210-093 & 210-140 Caelus Natural Resources Alaska, LLC. (CNRA) submits an Application for Sundry to replace a failed 2-7/8" ESP on ODSN-17 with a new 2-7/8" ESP Upper Completion. See the proposed plan attachments and supporting documentation. Sincerely, i<jeiat,_ -Far guai JaSSer i Jasser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting Information cc: ODSN-17 Well File • • 2 ODSN-17 Procedure Summary: Pre-Rig: 1. Pull OV from GLM #1 2. Install DV in GLM #1 3. Pull DV from GLM #2 4. Shoot holes in tubing below packer 5. Bleed gas from tubing and IA 6. Bullhead Freeze Protect tubing with 20 bbl. diesel 7. Bullhead Freeze Protect IA with 100 bbl. diesel 8. Set BPV 9. Test Pack-offs to 5000psi 10. Close ScSSSV Rig Work: 1. MIRU N19AC 2. Pull BPV 3. Open ScSSSV 4. Bullhead IA with 100 bbl. treated/filtered seawater 5. Bullhead Tubing with 350 bbl. treated/filtered seawater 6. Close ScSSSV and PVV 7. Set BPV and test dart 8. ND Tree/ NU BOPE 9. Test BOPE to 250psi low/3500psi high, annular to 2500psi 10. Pull BPV and test dart 11. Bullhead Tubing with 350 bbl. treated/filtered seawater 12. Monitor fluid level or confirm well on vacuum 13. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 14. BOLDS 15. Break tubing hanger free 16. Continue to pull and release packer 17. Allow elements relax 18. Monitor fluid level or confirm well on vacuum 19. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 20. POOH with 2-7/8" ESP string and LD 21. RIH with bit, scraper and magnets to 2900' MD - 250' MD below packer setting depth 22. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 23. POOH Cleanout BHA 24. PU and RIH with 2-7/8" ESP upper completion as per attached schematic, with OV installed in GLM#1 25. Drop Ball-Rod 26. Set packer 27. Pressure test tubing to 3500psi, Pressure test IA to 3500psi 28. Shear SOV in GLM#3 29. Freeze protect tubing and IA with diesel to 2,500' TVD 30. Close ScSSSV 31. Set BPV, test from below 32. ND BOPE/NU Tree 33. RDMO N19AC A • 3 Post Rig (Slick-line): 1. Pull Ball-Rod 2. Pull SOV from GLM#3 3. Set DV in GLM#3 4. Pull RHC Reservoir Pressures: Nuiqsut Pressure: 2,350 psi at 6,350' TVD after 30 days of shut-in = 0.37 psi/ft. = 7.1 ppge Maximum surface pressure: 2,350 psi at 6,350' TVD reservoir pressure with 0.1 psi/ft. gas gradient = 1,715 psi MASP ODSN-17 Nuiqsut Bottomhole Pressure Build Up 3,500 —2010 Initial Pressure 3,000 —Seawater-Seawater(8.55 ppge) —LVT/Diesel(6.8 ppge) 2,500 05/06/15 PBU u1 ovo 2,000 —03/24/16 PBU Q ai ••• Expected Pressure Build Up 3 14 1,500 p U, 3 'c 1,000 z 500 0 0 5 10 15 20 25 30 Shut-in Time,Days 0 1 4 Original Well Schematic: ODSN-17 Well Completion Final 6/29/2015 I No. Upper Completion Equipment MD(ftj TVD(ft1 I'""' =ILL) , 16"Conductor I Vetco ay Tubing Hanger 34 34 ': CGx ) 2 2-7'8"0 4*L-80 ET-M Tubing tapperpinned open 3 HES Well StarTRScSSSV-Controlhnc ; C,00 1,560 GLM z -FXE Installed 4 2-71`0.40 L-80 BT-M Tubing Dom — 0 5 2.718"x 1.5"'GL M#2 2,400 2,296 Ver. C 2-71r 6.40 L40 BT-M Tubing O 7 HES 2-7/8""X"Nipple*2w2313ID 2,519 2,385 FR 8 2-71"8.40 L-80 BT-M Trbrg Z g 9 WET Hydro II Pacrer 2,633 2,466 10 2-78"8.4*L-80 BT-M Tutrg ,$ O ZL 11 2-711"x 1.5"GLM*1 9 757 1 965 12 2- .'8'"8.40 L-80 BT-M Tubing 11-3/4"60#L-80 13 HES 2-7/8""X"Nipple*1 w231- In 9,869 5,002 Hydril 521 Surface Casing 14 2-713"0 4r L-80 BT-M Tubing @ 4,660'MD/3,285'TVD 15 Auto Diva-ter Vale;ADV) 13,883 0,108 10 ESP Pump Assembly 13.092 0,110 End cl Asse i bN 13,753 0 122 GLM#1 1/4"OV JO , E 3 7"26#L-80 BTC-M Intermediate 2 Tie-Back Casing @ 10,844'MD/5,320'TVD 9-5/8"40#L-80 Hydril 521 Intermediate 1 Casing ® @ 10,978'MD/5,365'TVD 0 0 0 7"26#L-80 Hydril 521 0 Intermediate 2 Casing @ 14,106'MD/6,186'TVD 1 \ \ \ 20 \i\ 6-1/8 Upper Lateral TD \ 410;A---62Q, 0at 20.940'MD/6,290'TVD i \\ �, ` I•, 25 0 0--—— I AI 1 \I\ ' (i)g_ Al' 111111111111111111111111111111111111111111111111111111K — \ 60 \ 0 0 0 0 0 0 o o a o 0 a o a a s a a a 0 I _/ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1r \ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O I z \ - I 6-1/8"L1 Lower Lateral TD at 19,695'MD/6,258'TVD • • 5 Proposed Well Schematic: ODSN-17 Well Completion DRAFT 5/15/2017 I Na UpperCompieti E@I,i "'f PM(ft) ft A l 16"Conductor A GE Tubing Hanger 34 34 I B 2-7/8`6.43 L-80 BT-U Tubing rt 0 2-718"'NE'TRSVw/2.313"X" Profile-15'Pup Top&Bon, GLM# III C Control line to surface 1 2,086 SOV — 0 D 2-7/8"6.4#L-80 IB Tubing G E 2-7/8"x 1" GLM#3 BK-6 latch,KBMG v+/ 11'Pup Top&Bottom 2,550 2,407 21 E 0 F 2-7/8"6.44 L-80 6T-M Tubing GLM#, o— , J 'G 2-7`8"x 7"IMFT HydrowII ESP Packer 2,650 2.477 DGLV H 2-7/8"6.4#L-80 6T-M Tubing IS F � I 2-7,'8"x 1" GLM#2 BK-6 latch. KBMG uv 11'Pup Top&Bottom 2,750 2.543 �J J 1 1-3/4"60#L-80 J 2-7/8"6.4#L-80 6T-M Tubing Hydril 521 K "X" Nipple 2.313"w'15'Pup Top&Bottom 2.850 2.6116 Surface Casing L 2-7/8"6.4#LSO BT-M Tubing @ 4,660'MD/ M 2-7/8"x 1" GLM#1 BK-5 latch, KBMG wl 11'Pup Top&Bottom 11,400 5.500 2-7/8" 6.5# 3,285'TVD N 2-7/8"6.4#L-8013T-M Tubing L-80 IBT-M 0 2-7118"Chemical Injection Valve(Anrwluslr>jection)vd If'Puc: 1 11,500 5,63. Tubing P 27/8"6.4#L-80BT41 Tubing (Upper Q "XN"2.313"2.205"No-Go vd15'Pup Top&Bottom 11,600 5,566 Completion) R 2-7/8"6.4#L-80 CT-M Tubing S Auto Direrter Value 13,683 6.108 T ESP Pump Assembly 13.692 6,110 End at Assembly 13.753 6.122 ,LM#1 77---J 0 DGLV J 7"26#L-80 BTC-M Intermediate 2 Tie- Back Casing @ 10,844'MD/ Chemical 5,320'TVD Injection I - Valve (Annular 0 9-5/8"40#L-80 Injection) ® 0 Hydril 521 Intermediate 1 Casing Io0 @10,978'MD/ 5,365'TVD 0 O 17 0 7"26#L-80 L �s Hydril 521 Intermediate A 2 Casing 1 @ 14,106' 1 u MD/6,186' 1 0 TVD I� \ 0 6-1/8"Upper Lateral TD I �' at 20,940'MD/6,290'TVD ��� Ci 2510- 41 0--——I f"\ 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 —0 0 0 0 0 0 0 I I ® 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o a o I .� 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ®I 1 \ I \ 1 \ 0 — . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 \ 1 6-1/8"L1 Lower Lateral TD at 19,695'MD/6,258'TVD • ! Attachment 2 I, O�GLd5A441tflu, /w^M,2x66G7f7bX %#Z.,,m,9�9/i /H�9�969P4,L/� THhMi1/6YQRLYAP✓5d%93ZO✓�d d9k'SCFGX ioa u✓mnm a.>.v.r'�v< ntnmry vn,a rtnw.m+dmawmauw r.;xmewwri ar✓rueaa»m6a AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-17 Upper Lateral Top (MD) Top(TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,059 6,178 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,274 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,543 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,762 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,966 e 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,173 6,213 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,376 6,220 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,581 6,223 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,782 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,988 6,217 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,210 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,415 6,227 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,619 6,236 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,824 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,029 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,236 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,442 6,230 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,647 6,228 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,851 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,053 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,275 6,251 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,480 6,239 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,683 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,886 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,090 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,297 6,265 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,501 6,262 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,702 6,258 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,907 6,256 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,114 6,246 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,321 6,256 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,525 6,270 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,729 6,278 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 20,894 6,287 410 S Lower Lateral Top(MD) Top(TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,453 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,756 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 14,958 6,212 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,167 6,213 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,374 6,220 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,795 6,219 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 15,996 6,217 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,203 6,218 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,409 6,227 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,614 6,236 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 16,820 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,027 6,244 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,227 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,434 6,231 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 17,854 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,058 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,263 6,252 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,468 6,240 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,670 6,235 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 18,876 6,243 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,078 6,254 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,280 6,265 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,486 6,263 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 19,689 6,258 • • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-17 SSSV MD TVD HES WellStar TRSV w/ "X" Profile 2,007 1,960 PACKERS WFT Hydro II Packer 2,633 2,466 WFT"NTH" Liner Top Packer 13,969 6,162 Oil Swell Packer 14,364 6,219 • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-17 Permit to Drill: 210-093 API: 50-703-20622-00-00 Sperry Drilling Services Definitive Survey Report 20 October, 2010 HALL JBURTO1 Sperry Drilling Services • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.00 ft Northing: 6,031,056.25ft Latitude: 70°29'45.303 N +E/-W 0.00 ft Easting: 469,826.11 ft Longitude: 150° 14'48.230 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-17 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I G RF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 PN13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 206.29 Survey Program Date 10/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,105.00 ODSN-17 Gyro(ODSN-17) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 8/26/2010 1: 1,154.91 4,612.64 ODSN-17 MWD 1 (ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8/27/2010 t 4,710.05 10,949.10 ODSN-17 MWD 2(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/7/2010 12: 11,042.53 14,070.86 ODSN-17 MWD 3(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/21/2010 1: 14,156.32 19,909.97 ODSN-17 MWD 4(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/4/2010 t Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,056.25 469,826.11 0.00 0.00 UNDEFINED 100.00 0.35 5.53 100.00 43.80 0.18 0.02 6,031,056.43 469,826.13 0.61 -0.16 SR-Gyro-SS(1) 172.00 0.78 357.31 172.00 115.80 0.88 0.01 6,031,057.13 469,826.13 0.61 -0.80 SR-Gyro-SS(1) 218.00 0.77 11.51 217.99 161.79 1.50 0.06 6,031,057.75 469,826.18 0.42 -1.37 SR-Gyro-SS(1) 264.00 0.67 32.05 263.99 207.79 2.03 0.27 6,031,058.28 469,826.38 0.60 -1.94 SR-Gyro-SS(1) 310.00 0.51 59.03 309.99 253.79 2.36 0.58 6,031,058.61 469,826.70 0.69 -2.38 SR-Gyro-SS(1) 356.00 1.45 98.70 355.98 299.78 2.38 1.33 6,031,058.63 469,827.45 2.41 -2.73 SR-Gyro-SS(1) 399.00 1.30 100.16 398.97 342.77 2.21 2.35 6,031,058.45 469,828.47 0.36 -3.03 SR-Gyro-SS(1) 445.00 1.49 102.67 444.95 388.75 1.99 3.45 6,031,058.23 469,829.57 0.43 -3.31 SR-Gyro-SS(1) 493.00 1.12 103.85 492.94 436.74 1.74 4.51 6,031,057.97 469,830.63 0.77 -3.56 SR-Gyro-SS(1) 10/20/2010 10:42:51AM Page 2 COMPASS 2003.16 Build 42F • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development ND Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (7) (7) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 539.00 0.59 88.47 538.94 482.74 1.64 5.19 6,031,057.87 469,831.30 1.25 -3.77 SR-Gyro-SS(1) 585.00 0.57 339.47 584.93 528.73 1.86 5.34 6,031,058.09 469,831.46 2.05 -4.03 SR-Gyro-SS(1) 631.00 2.15 303.65 630.92 574.72 2.55 4.54 6,031,058.78 469,830.66 3.74 -4.30 SR-Gyro-SS(1) 679.00 2.89 299.16 678.87 622.67 3.64 2.74 6,031,059.88 469,828.86 1.59 -4.48 SR-Gyro-SS(1) 725.00 4.49 297.38 724.78 668.58 5.03 0.13 6,031,061.28 469,826.26 3.49 -4.57 SR-Gyro-SS(1) 775.00 5.09 297.86 774.60 718.40 6.97 -3.57 6,031,063.23 469,822.57 1.20 -4.67 SR-Gyro-SS(1) 821.00 6.25 296.89 820.38 764.18 9.06 -7.61 6,031,065.34 469,818.54 2.53 -4.75 SR-Gyro-SS(1) 870.00 6.52 296.43 869.07 812.87 11.50 -12.48 6,031,067.80 469,813.68 0.56 -4.78 SR-Gyro-SS(1) 916.00 6.47 297.18 914.78 858.58 13.85 -17.12 6,031,070.17 469,809.04 0.21 -4.83 SR-Gyro-SS(1) 964.00 6.72 300.83 962.46 906.26 16.52 -21.94 6,031,072.86 469,804.24 1.02 -5.09 SR-Gyro-SS(1) 1,010.00 7.59 303.62 1,008.10 951.90 19.58 -26.78 6,031,075.94 469,799.41 2.04 -5.69 SR-Gyro-SS(1) 1,059.00 8.84 304.73 1,056.60 1,000.40 23.52 -32.57 6,031,079.90 469,793.64 2.57 -6.66 SR-Gyro-SS(1) 1,105.00 10.33 306.26 1,101.95 1,045.75 27.97 -38.80 6,031,084.38 469,787.43 3.29 -7.89 SR-Gyro-SS(1) 1,154.91 10.97 306.14 1,151.00 1,094.80 33.42 -46.25 6,031,089.85 469,780.01 1.28 -9.48 MWD+IFR2+MS+sag(2) 1,249.75 12.79 310.01 1,243.81 1,187.61 45.49 -61.57 6,031,101.99 469,764.73 2.09 -13.51 MWD+IFR2+MS+sag(2) 1,345.36 14.25 306.47 1,336.77 1,280.57 59.29 -79.14 6,031,115.86 469,747.21 1.75 -18.10 MWD+IFR2+MS+sag(2) 1,441.50 16.46 305.59 1,429.47 1,373.27 74.25 -99.74 6,031,130.90 469,726.68 2.31 -22.39 MWD+IFR2+MS+sag(2) 1,535.55 17.50 301.22 1,519.42 1,463.22 89.34 -122.67 6,031,146.08 469,703.82 1.75 -25.76 MWD+IFR2+MS+sag(2) 1,630.45 18.59 302.17 1,609.66 1,553.46 104.79 -147.68 6,031,161.63 469,678.88 1.19 -28.53 MWD+IFR2+MS+sag(2) 1,696.70 18.80 298.73 1,672.41 1,616.21 115.54 -165.98 6,031,172.46 469,660.62 1.69 -30.07 MWD+IFR2+MS+sag(2) 1,757.05 18.77 298.18 1,729.55 1,673.35 124.80 -183.06 6,031,181.78 469,643.57 0.30 -30.80 MWD+IFR2+MS+sag(2) 1,852.52 20.92 295.54 1,819.34 1,763.14 139.41 -211.98 6,031,196.50 469,614.71 2.44 -31.09 MWD+IFR2+MS+sag(2) 1,947.56 25.06 292.03 1,906.82 1,850.62 154.28 -245.97 6,031,211.51 469,580.79 4.59 -29.37 MWD+IFR2+MS+sag(2) 2,042.11 27.21 292.05 1,991.70 1,935.50 169.91 -284.57 6,031,227.29 469,542.26 2.27 -26.28 MWD+IFR2+MS+sag(2) 2,137.05 30.84 291.63 2,074.70 2,018.50 187.03 -327.32 6,031,244.59 469,499.58 3.83 -22.69 MWD+IFR2+MS+sag(2) 2,232.35 31.42 292.38 2,156.28 2,100.08 205.50 -373.00 6,031,263.24 469,453.98 0.73 -19.01 MWD+IFR2+MS+sag(2) 2,327.45 35.63 292.98 2,235.54 2,179.34 225.76 -421.45 6,031,283.69 469,405.63 4.44 -15.72 MWD+IFR2+MS+sag(2) 2,422.51 38.40 290.54 2,311.44 2,255.24 246.93 -474.60 6,031,305.08 469,352.57 3.30 -11.16 MWD+IFR2+MS+sag(2) 2,517.34 42.48 288.71 2,383.60 2,327.40 267.55 -532.53 6,031,325.93 469,294.72 4.48 -3.98 MWD+IFR2+MS+sag(2) 2,613.42 46.37 284.64 2,452.22 2,396.02 286.75 -596.94 6,031,345.39 469,230.40. 5.02 7.33 MWD+IFR2+MS+sag(2) 2,708.38 48.97 279.31 2,516.18 2,459.98 301.24 -665.58 6,031,360.16 469,161.83 4.97 24.74 MWD+IFR2+MS+sag(2) 2,803.28 51.29 273.38 2,577.05 2,520.85 309.22 -737.91 6,031,368.43 469,089.54 5.38 49.63 MWD+IFR2+MS+sag(2) 2,899.43 54.08 268.08 2,635.35 2,579.15 310.13 -814.32 6,031,369.65 469,013.14 5.26 82.66 MWD+IFR2+MS+sag(2) 2,994.43 56.77 265.45 2,689.27 2,633.07 305.69 -892.40 6,031,365.52 468,935.05 3.63 121.23 MWD+IFR2+MS+sag(2) 3,090.16 59.62 263.56 2,739.72 2,683.52 297.88 -973.36 6,031,358.04 468,854.06 3.42 164.10 MWD+IFR2+MS+sag(2) 3,185.33 63.02 262.45 2,785.39 2,729.19 287.70 -1,056.22 6,031,348.20 468,771.17 3.72 209.92 MWD+IFR2+MS+sag(2) 3,279.10 65.81 261.16 2,825.88 2,769.68 275.63 -1,139.92 6,031,336.48 468,687.44 3.22 257.82 MWD+IFR2+MS+sag(2) 3,374.77 70.37 260.38 2,861.57 2,805.37 261.39 -1,227.50 6,031,322.59 468,599.80 4.83 309.38 MWD+IFR2+MS+sag(2) 3,469.87 72.08 259.20 2,892.18 2,835.98 245.42 -1,316.11 6,031,306.99 468,511.14 2.15 362.94 MWD+IFR2+MS+sag(2) 3,565.72 70.73 257.02 2,922.74 2,866.54 226.72 -1,405.00 6,031,288.64 468,422.18 2.57 419.09 MWD+IFR2+MS+sag(2) 10/20/2010 10:42:51AM Page 3 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-000guruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: 000guruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (7) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,661.41 70.08 255.90 2,954.84 2,898.64 205.61 -1,492.64 6,031,267.90 468,334.47 1.30 476.83 MWD+IFR2+MS+sag(2) 3,756.32 70.91 255.84 2,986.52 2,930.32 183.77 -1,579.40 6,031,246.41 468,247.63 0.88 534.84 MWD+IFR2+MS+sag(2) 3,851.14 71.00 256.41 3,017.47 2,961.27 162.28 -1,666.41 6,031,225.27 468,160.54 0.58 592.65 MWD+IFR2+MS+sag(2) 3,945.82 70.58 256.69 3,048.62 2,992.42 141.48 -1,753.37 6,031,204.83 468,073.51 0.52 649.82 MWD+IFR2+MS+sag(2) 4,041.02 71.21 257.51 3,079.78 3,023.58 121.40 -1,841.05 6,031,185.11 467,985.75 1.05 706.66 MWD+IFR2+MS+sag(2) 4,136.12 71.00 258.58 3,110.57 3,054.37 102.76 -1,929.07 6,031,166.83 467,897.66 1.09 762.36 MWD+IFR2+MS+sag(2) 4,231.28 70.01 259.27 3,142.33 3,086.13 85.53 -2,017.11 6,031,149.96 467,809.57 1.24 816.80 MWD+IFR2+MS+sag(2) 4,326.25 70.46 258.64 3,174.45 3,118.25 68.41 -2,104.83 6,031,133.19 467,721.79 0.78 871.01 MWD+IFR2+MS+sag(2) 4,421.27 70.63 258.51 3,206.10 3,149.90 50.66 -2,192.64 6,031,115.80 467,633.91 0.22 925.82 MWD+IFR2+MS+sag(2) 4,516.95 70.67 258.35 3,237.80 3,181.60 32.55 -2,281.09 6,031,098.06 467,545.41 0.16 981.23 MWD+IFR2+MS+sag(2) 4,612.64 70.46 259.48 3,269.64 3,213.44 15.20 -2,369.64 6,031,081.07 467,456.79 1.14 1,036.01 MWD+IFR2+MS+sag(2) 4,710.05 71.86 259.82 3,301.09 3,244.89 -1.36 -2,460.33 6,031,064.88 467,366.05 1.47 1,091.03 MWD+IFR2+MS+sag(3) 4,803.06 71.54 259.66 3,330.30 3,274.10 -17.09 -2,547.22 6,031,049.50 467,279.10 0.38 1,143.62 MWD+IFR2+MS+sag(3) 4,898.59 71.16 259.30 3,360.85 3,304.65 -33.61 -2,636.21 6,031,033.34 467,190.05 0.53 1,197.85 MWD+IFR2+MS+sag(3) 4,994.01 70.97 259.96 3,391.81 3,335.61 -49.86 -2,724.99 6,031,017.46 467,101.21 0.68 1,251.75 MWD+IFR2+MS+sag(3) 5,088.97 70.57 259.98 3,423.09 3,366.89 -65.47 -2,813.29 6,031,002.20 467,012.87 0.42 1,304.86 MWD+IFR2+MS+sag(3) 5,186.08 70.17 260.76 3,455.71 3,399.51 -80.78 -2,903.46 6,030,987.27 466,922.64 0.86 1,358.52 MWD+IFR2+MS+sag(3) 5,278.62 70.69 260.22 3,486.71 3,430.51 -95.18 -2,989.46 6,030,973.21 466,836.59 0.79 1,409.53 MWD+IFR2+MS+sag(3) 5,376.29 71.16 259.12 3,518.63 3,462.43 -111.74 -3,080.26 6,030,957.03 466,745.73 1.17 1,464.59 MWD+IFR2+MS+sag(3) 5,469.55 70.84 256.79 3,548.99 3,492.79 -130.13 -3,166.50 6,030,938.98 466,659.43 2.39 1,519.28 MWD+IFR2+MS+sag(3) 5,564.83 70.64 255.55 3,580.42 3,524.22 -151.63 -3,253.83 6,030,917.84 466,572.02 1.25 1,577.24 MWD+IFR2+MS+sag(3) 5,659.60 70.97 254.92 3,611.58 3,555.38 -174.44 -3,340.38 6,030,895.38 466,485.39 0.72 1,636.03 MWD+IFR2+MS+sag(3) 5,754.46 70.75 254.41 3,642.69 3,586.49 -198.14 -3,426.80 6,030,872.04 466,398.88 0.56 1,695.56 MWD+IFR2+MS+sag(3) 5,848.47 70.70 254.77 3,673.72 3,617.52 -221.72 -3,512.35 6,030,848.81 466,313.24 0.37 1,754.60 MWD+IFR2+MS+sag(3) 5,943.87 70.12 255.24 3,705.71 3,649.51 -244.98 -3,599.17 6,030,825.91 466,226.34 0.76 1,813.90 MWD+IFR2+MS+sag(3) 6,040.89 70.30 255.87 3,738.55 3,682.35 -267.75 -3,687.57 6,030,803.50 466,137.85 0.64 1,873.47 MWD+IFR2+MS+sag(3) 6,135.45 70.37 257.19 3,770.38 3,714.18 -288.49 -3,774.17 6,030,783.11 466,051.18 1.32 1,930.43 MWD+IFR2+MS+sag(3) 6,231.22 70.89 258.90 3,802.14 3,745.94 -307.20 -3,862.55 6,030,764.76 465,962.73 1.77 1,986.35 MWD+IFR2+MS+sag(3) 6,325.15 71.08 260.28 3,832.75 3,776.55 -323.25 -3,949.89 6,030,749.07 465,875.34 1.40 2,039.43 MWD+IFR2+MS+sag(3) 6,421.02 70.77 260.20 3,864.08 3,807.88 -338.61 -4,039.19 6,030,734.07 465,785.99 0.33 2,092.75 MWD+IFR2+MS+sag(3) 6,516.19 70.75 260.29 3,895.44 3,839.24 -353.83 -4,127.74 6,030,719.21 465,697.38 0.09 2,145.63 MWD+IFR2+MS+sag(3) 6,613.33 70.35 260.71 3,927.79 3,871.59 -368.95 -4,218.08 6,030,704.46 465,606.99 0.58 2,199.20 MWD+IFR2+MS+sag(3) 6,706.26 70.37 261.96 3,959.02 3,902.82 -382.14 -4,304.60 6,030,691.63 465,520.42 1.27 2,249.34 MWD+IFR2+MS+sag(3) 6,800.98 70.63 260.84 3,990.64 3,934.44 -395.49 -4,392.89 6,030,678.63 465,432.10 1.15 2,300.42 MWD+IFR2+MS+sag(3) 6,896.38 70.76 261.31 4,022.18 3,965.98 -409.46 -4,481.83 6,030,665.03 465,343.11 0.48 2,352.34 MWD+IFR2+MS+sag(3) 6,992.18 70.91 260.31 4,053.63 3,997.43 -423.91 -4,571.16 6,030,650.94 465,253.73 1.00 2,404.86 MWD+IFR2+MS+sag(3) 7,088.03 71.15 259.90 4,084.79 4,028.59 -439.49 -4,660.45 6,030,635.73 465,164.38 0.48 2,458.38 MWD+IFR2+MS+sag(3) 7,182.18 71.35 259.30 4,115.05 4,058.85 -455.58 -4,748.14 6,030,619.99 465,076.64 0.64 2,511.65 MWD+IFR2+MS+sag(3) 7,277.41 71.34 257.39 4,145.52 4,089.32 -473.81 -4,836.50 6,030,602.13 464,988.21 1.90 2,567.14 MWD+IFR2+MS+sag(3) 7,372.56 70.96 257.20 4,176.26 4,120.06 -493.61 -4,924.35 6,030,582.68 464,900.30 0.44 2,623.80 MWD+IFR2+MS+sag(3) 10/20/2010 10:42:51AM Page 4 COMPASS 2003.16 Build 42F • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 7,468.27 70.82 257.82 4,207.59 4,151.39 -513.17 -5,012.64 6,030,563.48 464,811.93 0.63 2,680.45 MWD+IFR2+MS+sag(3) 7,563.47 70.03 257.84 4,239.49 4,183.29 -532.08 -5,100.32 6,030,544.93 464,724.19 0.83 2,736.24 MWD+IFR2+MS+sag(3) 7,658.61 70.36 258.45 4,271.72 4,215.52 -550.47 -5,187.92 6,030,526.90 464,636.52 0.70 2,791.53 MWD+IFR2+MS+sag(3) 7,754.46 70.37 258.66 4,303.93 4,247.73 -568.38 -5,276.41 6,030,509.35 464,547.97 0.21 2,846.78 MWD+IFR2+MS+sag(3) 7,848.82 70.25 259.03 4,335.72 4,279.52 -585.57 -5,363.57 6,030,492.52 464,460.75 0.39 2,900.80 MWD+IFR2+MS+sag(3) 7,945.27 70.68 259.62 4,367.98 4,311.78 -602.41 -5,452.89 6,030,476.04 464,371.37 0.73 2,955.46 MWD+IFR2+MS+sag(3) 8,038.91 70.82 259.69 4,398.85 4,342.65 -618.28 -5,539.86 6,030,460.52 464,284.34 0.17 3,008.22 MWD+IFR2+MS+sag(3) 8,134.96 70.96 260.58 4,430.29 4,374.09 -633.83 -5,629.28 6,030,445.34 464,194.88 0.89 3,061.76 MWD+IFR2+MS+sag(3) 8,230.17 71.28 260.76 4,461.10 4,404.90 -648.43 -5,718.17 6,030,431.10 464,105.93 0.38 3,114.23 MWD+IFR2+MS+sag(3) 8,324.98 71.15 260.58 4,491.63 4,435.43 -662.99 -5,806.74 6,030,416.91 464,017.31 0.23 3,166.51 MWD+IFR2+MS+sag(3) 8,420.04 70.82 260.48 4,522.60 4,466.40 -677.77 -5,895.39 6,030,402.48 463,928.61 0.36 3,219.04 MWD+IFR2+MS+sag(3) 8,515.53 70.29 260.55 4,554.39 4,498.19 -692.61 -5,984.20 6,030,388.00 463,839.75 0.56 3,271.68 MWD+IFR2+MS+sag(3) 8,609.58 70.82 260.71 4,585.70 4,529.50 -707.05 -6,071.71 6,030,373.92 463,752.20 0.59 3,323.39 MWD+IFR2+MS+sag(3) 8,705.65 71.28 260.48 4,616.90 4,560.70 -721.90 -6,161.35 6,030,359.44 463,662.51 0.53 3,376.40 MWD+IFR2+MS+sag(3) 8,801.16 71.66 259.31 4,647.26 4,591.06 -737.79 -6,250.50 6,030,343.91 463,573.30 1.23 3,430.14 MWD+IFR2+MS+sag(3) 8,896.34 70.45 258.87 4,678.16 4,621.96 -754.82 -6,338.89 6,030,327.24 463,484.84 1.34 3,484.57 MWD+IFR2+MS+sag(3) 8,991.27 70.09 258.28 4,710.20 4,654.00 -772.52 -6,426.48 6,030,309.89 463,397.20 0.70 3,539.23 MWD+IFR2+MS+sag(3) 9,086.77 70.30 258.61 4,742.56 4,686.36 -790.52 -6,514.51 6,030,292.26 463,309.10 0.39 3,594.36 MWD+IFR2+MS+sag(3) 9,182.69 70.49 258.53 4,774.75 4,718.55 -808.43 -6,603.08 6,030,274.71 463,220.47 0.21 3,649.65 MWD+IFR2+MS+sag(3) 9,277.16 70.87 258.94 4,806.00 4,749.80 -825.84 -6,690.51 6,030,257.65 463,132.98 0.57 3,703.99 MWD+IFR2+MS+sag(3) 9,372.89 69.98 259.04 4,838.07 4,781.87 -843.07 -6,779.05 6,030,240.79 463,044.38 0.93 3,758.65 MWD+IFR2+MS+sag(3) 9,467.20 70.36 259.56 4,870.07 4,813.87 -859.54 -6,866.22 6,030,224.67 462,957.15 0.66 3,812.03 MWD+IFR2+MS+sag(3) 9,563.91 71.00 259.30 4,902.06 4,845.86 -876.28 -6,955.93 6,030,208.30 462,867.38 0.71 3,866.78 MWD+IFR2+MS+sag(3) 9,659.05 71.01 258.16 4,933.03 4,876.83 -893.86 -7,044.16 6,030,191.08 462,779.09 1.13 3,921.62 MWD+IFR2+MS+sag(3) 9,752.68 70.89 257.04 4,963.59 4,907.39 -912.87 -7,130.59 6,030,172.43 462,692.59 1.14 3,976.95 MWD+IFR2+MS+sag(3) 9,849.04 71.03 257.88 4,995.03 4,938.83 -932.64 -7,219.51 6,030,153.01 462,603.60 0.84 4,034.06 MWD+IFR2+MS+sag(3) 9,943.96 71.22 258.20 5,025.73 4,969.53 -951.25 -7,307.37 6,030,134.76 462,515.67 0.38 4,089.67 MWD+IFR2+MS+sag(3) 10,039.79 70.31 256.57 5,057.31 5,001.11 -971.01 -7,395.67 6,030,115.36 462,427.31 1.87 4,146.49 MWD+IFR2+MS+sag(3) 10,134.14 71.07 253.76 5,088.51 5,032.31 -993.81 -7,481.73 6,030,092.91 462,341.16 2.92 4,205.05 MWD+IFR2+MS+sag(3) 10,229.16 71.22 250.69 5,119.23 5,063.03 -1,021.26 -7,567.34 6,030,065.82 462,255.45 3.06 4,267.59 MWD+IFR2+MS+sag(3) 10,324.49 71.07 247.66 5,150.04 5,093.84 -1,053.33 -7,651.65 6,030,034.10 462,171.02 3.01 4,333.68 MWD+IFR2+MS+sag(3) 10,419.51 70.82 244.06 5,181.07 5,124.87 -1,090.05 -7,733.60 6,029,997.71 462,088.93 3.59 4,402.90 MWD+IFR2+MS+sag(3) 10,508.96 70.45 240.96 5,210.74 5,154.54 -1,128.99 -7,808.45 6,029,959.07 462,013.93 3.30 4,470.97 MWD+IFR2+MS+sag(3) 10,610.40 70.69 236.81 5,244.49 5,188.29 -1,178.42 -7,890.32 6,029,909.99 461,931.86 3.87 4,551.55 MWD+IFR2+MS+sag(3) 10,705.79 71.54 232.94 5,275.38 5,219.18 -1,230.34 -7,964.12 6,029,858.37 461,857.86 3.94 4,630.79 MWD+IFR2+MS+sag(3) 10,800.97 70.83 229.60 5,306.08 5,249.88 -1,286.69 -8,034.40 6,029,802.31 461,787.37 3.40 4,712.44 MWD+IFR2+MS+sag(3) 10,895.62 70.57 224.59 5,337.39 5,281.19 -1,347.48 -8,099.81 6,029,741.79 461,721.72 5.00 4,795.92 MWD+IFR2+MS+sag(3) 10,949.10 70.78 223.14 5,355.08 5,298.88 -1,383.87 -8,134.78 6,029,705.55 461,686.61 2.59 4,844.03 MWD+IFR2+MS+sag(3) 11,042.53 71.73 222.09 5,385.11 5,328.91 -1,448.98 -8,194.68 6,029,640.69 461,626.45 1.47 4,928.93 MWD+IFR2+MS+sag(4) 11,088.41 71.75 221.46 5,399.48 5,343.28 -1,481.47 -8,223.70 6,029,608.32 461,597.29 1.30 4,970.92 MWD+IFR2+MS+sag(4) 10/20/2010 10:42:51AM Page 5 COMPASS 200316 Build 42F • S Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development ND Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,183.91 70.74 219.27 5,430.19 5,373.99 -1,550.36 -8,282.27 6,029,539.67 461,538.45 2.42 5,058.63 MWD+IFR2+MS+sag(4) 11,279.14 71.02 215.72 5,461.39 5,405.19 -1,621.74 -8,337.02 6,029,468.53 461,483.41 3.53 5,146.87 MWD+IFR2+MS+sag(4) 11,373.84 71.41 212.82 5,491.89 5,435.69 -1,695.82 -8,387.50 6,029,394.66 461,432.64 2.93 5,235.65 MWD+IFR2+MS+sag(4) 11,469.31 71.08 209.09 5,522.60 5,466.40 -1,773.33 -8,433.99 6,029,317.35 461,385.84 3.72 5,325.73 MWD+IFR2+MS+sag(4) 11,565.32 70.57 205.46 5,554.14 5,497.94 -1,853.91 -8,475.54 6,029,236.94 461,343.97 3.61 5,416.38 MWD+IFR2+MS+sag(4) 11,660.83 72.20 201.49 5,584.64 5,528.44 -1,936.91 -8,511.57 6,029,154.10 461,307.60 4.29 5,506.76 MWD+IFR2+MS+sag(4) 11,755.15 72.84 198.69 5,612.98 5,556.78 -2,021.39 -8,542.47 6,029,069.75 461,276.37 2.91 5,596.19 MWD+IFR2+MS+sag(4) 11,850.51 73.61 195.85 5,640.51 5,584.31 -2,108.57 -8,569.57 6,028,982.69 461,248.92 2.96 5,686.35 MWD+IFR2+MS+sag(4) 11,946.56 73.95 192.22 5,667.34 5,611.14 -2,198.03 -8,591.93 6,028,893.34 461,226.20 3.65 5,776.45 MWD+IFR2+MS+sag(4) 12,042.13 73.74 188.24 5,693.94 5,637.74 -2,288.34 -8,608.23 6,028,803.10 461,209.53 4.01 5,864.65 MWD+IFR2+MS+sag(4) 12,136.56 73.79 184.72 5,720.35 5,664.15 -2,378.41 -8,618.46 6,028,713.08 461,198.94 3.58 5,949.93 MWD+IFR2+MS+sag(4) 12,231.94 74.12 183.17 5,746.72 5,690.52 -2,469.86 -8,624.76 6,028,621.67 461,192.26 1.60 6,034.71 MWD+IFR2+MS+sag(4) 12,326.15 73.47 181.03 5,773.01 5,716.81 -2,560.26 -8,628.08 6,028,531.29 461,188.58 2.29 6,117.22 MWD+IFR2+MS+sag(4) 12,421.45 73.28 179.34 5,800.28 5,744.08 -2,651.57 -8,628.38 6,028,439.99 461,187.91 1.71 6,199.22 MWD+IFR2+MS+sag(4) 12,516.10 74.76 177.01 5,826.34 5,770.14 -2,742.50 -8,625.47 6,028,349.05 461,190.45 2.84 6,279.46 MWD+IFR2+MS+sag(4) 12,612.64 75.21 175.12 5,851.35 5,795.15 -2,835.52 -8,619.07 6,028,256.02 461,196.47 1.95 6,360.02 MWD+IFR2+MS+sag(4) 12,707.53 74.31 172.56 5,876.30 5,820.10 -2,926.54 -8,609.25 6,028,164.97 461,205.92 2.77 6,437.27 MWD+IFR2+MS+sag(4) 12,797.87 74.71 170.43 5,900.43 5,844.23 -3,012.63 -8,596.38 6,028,078.84 461,218.44 2.31 6,508.76 MWD+IFR2+MS+sag(4) 12,897.12 74.83 166.63 5,926.51 5,870.31 -3,106.47 -8,577.34 6,027,984.94 461,237.10 3.70 6,584.45 MWD+IFR2+MS+sag(4) 12,993.65 75.07 163.20 5,951.58 5,895.38 -3,196.46 -8,553.08 6,027,894.86 461,260.99 3.44 6,654.38 MWD+IFR2+MS+sag(4) 13,090.13 76.50 158.81 5,975.28 5,919.08 -3,284.86 -8,522.64 6,027,806.34 461,291.07 4.65 6,720.15 MWD+IFR2+MS+sag(4) 13,183.84 76.56 155.90 5,997.12 5,940.92 -3,368.96 -8,487.55 6,027,722.11 461,325.81 3.02 6,780.01 MWD+IFR2+MS+sag(4) 13,278.88 76.22 153.10 6,019.48 5,963.28 -3,452.32 -8,447.79 6,027,638.59 461,365.23 2.89 6,837.14 MWD+IFR2+MS+sag(4) 13,373.87 76.86 151.23 6,041.60 5,985.40 -3,534.01 -8,404.66 6,027,556.74 461,408.03 2.03 6,891.27 MWD+IFR2+MS+sag(4) 13,468.91 77.43 149.40 6,062.74 6,006.54 -3,614.50 -8,358.77 6,027,476.07 461,453.58 1.97 6,943.11 MWD+IFR2+MS+sag(4) 13,564.20 77.50 146.25 6,083.43 6,027.23 -3,693.22 -8,309.24 6,027,397.16 461,502.78 3.23 6,991.75 MWD+IFR2+MS+sag(4) 13,658.27 78.51 143.53 6,102.98 6,046.78 -3,768.48 -8,256.32 6,027,321.69 461,555.39 3.03 7,035.78 MWD+IFR2+MS+sag(4) 13,753.68 78.76 142.94 6,121.78 6,065.58 -3,843.42 -8,200.34 6,027,246.54 461,611.07 0.66 7,078.16 MWD+IFR2+MS+sag(4) 13,848.63 79.02 142.71 6,140.08 6,083.88 -3,917.66 -8,144.04 6,027,172.08 461,667.06 0.36 7,119.78 MWD+IFR2+MS+sag(4) 13,944.20 79.65 142.01 6,157.77 6,101.57 -3,992.03 -8,086.68 6,027,097.48 461,724.11 0.98 7,161.05 MWD+IFR2+MS+sag(4) 14,038.97 80.15 139.71 6,174.39 6,118.19 -4,064.38 -8,027.79 6,027,024.89 461,782.70 2.45 7,199.84 MWD+IFR2+MS+sag(4) 14,070.86 80.28 139.78 6,179.81 6,123.61 -4,088.37 -8,007.49 6,027,000.83 461,802.91 0.46 7,212.35 MWD+IFR2+MS+sag(4) 14,156.32 80.88 139.42 6,193.80 6,137.60 -4,152.57 -7,952.84 6,026,936.41 461,857.28 0.82 7,245.71 MWD+IFR2+MS+sag(5) 14,220.44 83.40 139.25 6,202.56 6,146.36 -4,200.75 -7,911.46 6,026,888.07 461,898.47 3.94 7,270.56 MWD+IFR2+MS+sag(5) 14,316.88 84.70 140.27 6,212.56 6,156.36 -4,273.97 -7,849.50 6,026,814.61 461,960.12 1.71 7,308.76 MWD+IFR2+MS+sag(5) 14,412.73 87.05 142.03 6,219.45 6,163.25 -4,348.41 -7,789.53 6,026,739.93 462,019.78 3.06 7,348.95 MWD+IFR2+MS+sag(5) 14,509.50 86.93 140.06 6,224.54 6,168.34 -4,423.56 -7,728.78 6,026,664.55 462,080.22 2.04 7,389.41 MWD+IFR2+MS+sag(5) 14,606.43 85.63 137.62 6,230.83 6,174.63 -4,496.37 -7,665.13 6,026,591.48 462,143.57 2.85 7,426.49 MWD+IFR2+MS+sag(5) 14,702.36 87.24 137.26 6,236.79 6,180.59 -4,566.89 -7,600.37 6,026,520.70 462,208.03 1.72 7,461.03 MWD+IFR2+MS+sag(5) 14,798.69 85.32 136.73 6,243.04 6,186.84 -4,637.19 -7,534.81 6,026,450.15 462,273.30 2.07 7,495.02 MWD+IFR2+MS+sag(5) 10/20/2010 10:42:51AM Page 6 COMPASS 2003.16 Build 42F i Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-1 7 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (7) (7) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.15 84.88 135.41 6,251.37 6,195.17 -4,707.12 -7,467.44 6,026,379.95 462,340.38 1.42 7,527.87 MWD+IFR2+MS+sag(5) 14,991.10 86.55 135.91 6,258.46 6,202.26 -4,774.83 -7,401.27 6,026,311.98 462,406.27 1.84 7,559.27 MWD+IFR2+MS+sag(5) 15,087.91 87.61 137.74 6,263.39 6,207.19 -4,845.34 -7,335.12 6,026,241.21 462,472.12 2.18 7,593.18 MWD+IFR2+MS+sag(5) 15,184.57 89.15 139.52 6,266.13 6,209.93 -4,917.85 -7,271.27 6,026,168.45 462,535.68 2.43 7,629.90 MWD+IFR2+MS+sag(5) 15,281.17 92.06 140.87 6,265.11 6,208.91 -4,992.04 -7,209.44 6,026,094.01 462,597.20 3.32 7,669.03 MWD+IFR2+MS+sag(5) 15,377.70 94.53 140.96 6,259.56 6,203.36 -5,066.84 -7,148.68 6,026,018.98 462,657.64 2.56 7,709.18 MWD+IFR2+MS+sag(5) 15,473.31 93.97 140.24 6,252.47 6,196.27 -5,140.52 -7,088.16 6,025,945.06 462,717.86 0.95 7,748.43 MWD+IFR2+MS+sag(5) 15,570.08 94.66 139.13 6,245.19 6,188.99 -5,214.09 -7,025.73 6,025,871.24 462,779.98 1.35 7,786.74 MWD+IFR2+MS+sag(5) 15,666.72 93.79 138.14 6,238.07 6,181.87 -5,286.42 -6,962.04 6,025,798.66 462,843.37 1.36 7,823.38 MWD+IFR2+MS+sag(5) 15,699.11 94.29 137.47 6,235.79 6,179.59 -5,310.36 -6,940.34 6,025,774.64 462,864.97 2.58 7,835.23 MWD+IFR2+MS+sag(5) 15,763.33 93.98 138.70 6,231.16 6,174.96 -5,358.02 -6,897.55 6,025,726.81 462,907.56 1.97 7,859.00 MWD+IFR2+MS+sag(5) 15,859.45 89.77 141.35 6,228.01 6,171.81 -5,431.62 -6,835.86 6,025,652.97 462,968.95 5.17 7,897.66 MWD+IFR2+MS+sag(5) 15,956.26 85.75 143.74 6,231.80 6,175.60 -5,508.39 -6,777.04 6,025,575.97 463,027.45 4.83 7,940.43 MWD+IFR2+MS+sag(5) 16,052.38 85.50 144.46 6,239.13 6,182.93 -5,586.03 -6,720.84 6,025,498.11 463,083.33 0.79 7,985.14 MWD+IFR2+MS+sag(5) 16,075.59 85.25 144.49 6,241.00 6,184.80 -5,604.85 -6,707.40 6,025,479.23 463,096.69 1.08 7,996.07 MWD+IFR2+MS+sag(5) 16,148.61 84.63 142.57 6,247.44 6,191.24 -5,663.34 -6,664.17 6,025,420.57 463,139.68 2.75 8,029.36 MWD+IFR2+MS+sag(5) 16,245.48 83.83 137.34 6,257.19 6,200.99 -5,737.10 -6,602.19 6,025,346.57 463,201.36 5.43 8,068.03 MWD+IFR2+MS+sag(5) 16,342.73 84.45 139.16 6,267.12 6,210.92 -5,809.27 -6,537.77 6,025,274.15 463,265.47 1.97 8,104.20 MWD+IFR2+MS+sag(5) 16,438.75 85.94 140.04 6,275.16 6,218.96 -5,882.14 -6,475.76 6,025,201.04 463,327.18 1.80 8,142.06 MWD+IFR2+MS+sag(5) 16,501.93 85.94 139.86 6,279.63 6,223.43 -5,930.38 -6,435.21 6,025,152.64 463,367.53 0.28 8,167.35 MWD+IFR2+MS+sag(5) 16,631.38 85.69 140.63 6,289.08 6,232.88 -6,029.63 -6,352.65 6,025,053.06 463,449.68 0.62 8,219.76 MWD+IFR2+MS+sag(5) 16,728.55 86.87 140.73 6,295.38 6,239.18 -6,104.64 -6,291.20 6,024,977.81 463,510.81 1.22 8,259.80 MWD+IFR2+MS+sag(5) 16,824.70 90.02 141.69 6,297.99 6,241.79 -6,179.55 -6,231.00 6,024,902.67 463,570.71 3.42 8,300.29 MWD+IFR2+MS+sag(5) 16,920.33 85.50 138.95 6,301.73 6,245.53 -6,253.07 -6,170.01 6,024,828.91 463,631.39 5.53 8,339.18 MWD+IFR2+MS+sag(5) 16,974.67 84.45 138.27 6,306.49 6,250.29 -6,293.68 -6,134.22 6,024,788.16 463,667.01 2.30 8,359.74 MWD+IFR2+MS+sag(5) 17,017.02 86.06 139.09 6,309.99 6,253.79 -6,325.37 -6,106.36 6,024,756.35 463,694.75 4.26 8,375.81 MWD+IFR2+MS+sag(5) 17,113.13 90.70 141.48 6,312.71 6,256.51 -6,399.25 -6,044.99 6,024,682.23 463,755.80 5.43 8,414.87 MWD+IFR2+MS+sag(5) 17,209.90 94.16 143.00 6,308.61 6,252.41 -6,475.67 -5,985.80 6,024,605.58 463,814.68 3.90 8,457.16 MWD+IFR2+MS+sag(5) 17,306.33 94.65 142.70 6,301.20 6,245.00 -6,552.31 -5,927.74 6,024,528.72 463,872.43 0.60 8,500.15 MWD+IFR2+MS+sag(5) 17,402.91 92.86 140.54 6,294.88 6,238.68 -6,627.84 -5,867.91 6,024,452.95 463,931.94 2.90 8,541.37 MWD+IFR2+MS+sag(5) 17,498.38 94.66 139.65 6,288.62 6,232.42 -6,700.92 -5,806.80 6,024,379.63 463,992.75 2.10 8,579.81 MWD+IFR2+MS+sag(5) 17,595.38 95.03 139.38 6,280.42 6,224.22 -6,774.43 -5,744.04 6,024,305.87 464,055.20 0.47 8,617.93 MWD+IFR2+MS+sag(5) 17,692.24 94.47 139.73 6,272.40 6,216.20 -6,847.89 -5,681.43 6,024,232.17 464,117.51 0.68 8,656.05 MWD+IFR2+MS+sag(5) 17,788.24 94.97 139.37 6,264.50 6,208.30 -6,920.70 -5,619.35 6,024,159.12 464,179.28 0.64 8,693.83 MWD+IFR2+MS+sag(5) 17,885.08 92.55 139.76 6,258.15 6,201.95 -6,994.24 -5,556.69 6,024,085.33 464,241.64 2.53 8,732.00 MWD+IFR2+MS+sag(5) 17,981.42 94.35 140.48 6,252.36 6,196.16 -7,068.03 -5,495.03 6,024,011.29 464,302.99 2.01 8,770.85 MWD+IFR2+MS+sag(5) 18,077.59 90.39 141.35 6,248.38 6,192.18 -7,142.60 -5,434.46 6,023,936.48 464,363.25 4.22 8,810.88 MWD+IFR2+MS+sag(5) 18,174.18 87.48 139.82 6,250.17 6,193.97 -7,217.20 -5,373.15 6,023,861.64 464,424.25 3.40 8,850.60 MWD+IFR2+MS+sag(5) 18,270.78 85.50 140.62 6,256.09 6,199.89 -7,291.30 -5,311.46 6,023,787.31 464,485.63 2.21 8,889.70 MWD+IFR2+MS+sag(5) 18,367.21 86.50 141.34 6,262.81 6,206.61 -7,366.03 -5,250.90 6,023,712.33 464,545.89 1.28 8,929.88 MWD+IFR2+MS+sag(5) 10/20/2010 10:42:51AM Page 7 COMPASS 2003.16 Build 42F • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E!-W Northing Easting DLS Section (ft) (7) (7) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,464.21 84.70 140.60 6,270.26 6,214.06 -7,441.16 -5,190.00 6,023,636.97 464,606.47 2.01 8,970.26 MWD+IFR2+MS+sag(5) 18,560.44 84.44 140.10 6,279.36 6,223.16 -7,514.92 -5,128.87 6,023,562.97 464,667.30 0.58 9,009.31 MWD+IFR2+MS+sag(5) 18,656.42 86.00 139.88 6,287.36 6,231.16 -7,588.17 -5,067.38 6,023,489.47 464,728.48 1.64 9,047.75 MWD+IFR2+MS+sag(5) 18,749.65 86.93 140.42 6,293.11 6,236.91 -7,659.61 -5,007.76 6,023,417.80 464,787.81 1.15 9,085.39 MWD+IFR2+MS+sag(5) 18,814.45 86.86 139.98 6,296.62 6,240.42 -7,709.32 -4,966.34 6,023,367.93 464,829.02 0.69 9,111.61 MWD+IFR2+MS+sag(5) 18,848.29 87.55 141.37 6,298.27 6,242.07 -7,735.47 -4,944.92 6,023,341.70 464,850.33 4.58 9,125.56 MWD+IFR2+MS+sag(5) 18,881.71 86.18 140.92 6,300.10 6,243.90 -7,761.46 -4,923.99 6,023,315.63 464,871.16 4.31 9,139.59 MWD+IFR2+MS+sag(5) 18,945.12 87.92 141.91 6,303.36 6,247.16 -7,810.95 -4,884.49 6,023,265.97 464,910.45 3.16 9,166.47 MWD+IFR2+MS+sag(5) 19,036.17 86.18 138.15 6,308.05 6,251.85 -7,880.63 -4,826.10 6,023,196.07 464,968.56 4.55 9,203.07 MWD+IFR2+MS+sag(5) 19,137.27 85.38 137.60 6,315.49 6,259.29 -7,955.41 -4,758.47 6,023,121.03 465,035.87 0.96 9,240.16 MWD+IFR2+MS+sag(5) 19,235.40 85.00 137.83 6,323.72 6,267.52 -8,027.75 -4,692.68 6,023,048.43 465,101.36 0.45 9,275.87 MWD+IFR2+MS+sag(5) 19,331.91 84.51 138.86 6,332.54 6,276.34 -8,099.55 -4,628.80 6,022,976.37 465,164.94 1.18 9,311.95 MWD+IFR2+MS+sag(5) 19,428.22 85.38 140.12 6,341.02 6,284.82 -8,172.49 -4,566.49 6,022,903.19 465,226.95 1.59 9,349.74 MWD+IFR2+MS+sag(5) 19,524.49 86.56 140.02 6,347.79 6,291.59 -8,246.13 -4,504.85 6,022,829.31 465,288.28 1.23 9,388.46 MWD+IFR2+MS+sag(5) 19,621.33 85.19 138.35 6,354.76 6,298.56 -8,319.23 -4,441.72 6,022,755.96 465,351.11 2.23 9,426.03 MWD+IFR2+MS+sag(5) 19,717.32 86.56 140.15 6,361.66 6,305.46 -8,391.75 -4,379.23 6,022,683.19 465,413.30 2.35 9,463.38 MWD+IFR2+MS+sag(5) 19,813.62 83.95 140.23 6,369.63 6,313.43 -8,465.47 -4,317.79 6,022,609.23 465,474.43 2.71 9,502.25 MWD+IFR2+MS+sag(5) 19,909.97 84.88 140.35 6,379.00 6,322.80 -8,539.24 -4,256.53 6,022,535.22 465,535.39 0.97 9,541.25 MWD+IFR2+MS+sag(5) 19,947.00 84.88 140.35 6,382.31 6,326.11 -8,567.63 -4,232.99 6,022,506.73 465,558.81 0.00 9,556.28 PROJECTED to TD 10/20/201010:42:51AM Page 8 COMPASS 2003.16 Build 42F o ,c j o ° ° o m 1 w Q Q- - -o LL- Csi 1:1 UwF- I- UN CO u o m m c Z ° m o o as rn W W N n le °LL w w W W W Wu_ N .� CO O in i w E `nH a) a�° 5 E E a • u, as 0 cs c c co o 0 Z 0 CD o ° ° >0 °_J c c o) ° O ° ° 7 o W UJ F-Q F-Q it lL O 2 2 M 2 EC � I c Q o v a) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 < J U N •V N N N N N N N N N N N _� 4) N N N N N O) 0) CO O) 0)) CO Cl) O N N N N Ni N N N N N N W � ° J T- N N N N N NI II W E � c > j O - c c c c c c c c c c c d a� m a� a) a) a) m m m m m E c 0 0 a a s o. a a a a o. a n 00 U00 Jm OU 0 0 0 0 0 0 0 0 0 0 0 �o `. �- . w O c 1 m a N. N. N- i) i) co co N- N. n N. to rcl, M M d N CL 0 y rn CO rn 0 ca rn rn rn rn rn rn aye ro E LU z I tr> in to co 0 0 0 0 N N Z CD CO CO CO W CO v v v v W W Z y N U O J > Q • N Z a c v o Q 7 O C w � z a) N J 0.m 7 Om N o z°1 '1' 0 0 0 0 0 0 0 2 `� o l O 'y ' y v y O Co E SI L ISI -0 co O o N V) N to N N N U) f9 J � I' Q °' Z 4 0 0 ! j 3 j p 1 c, I— 0 '- il a G a D NO N d COW o c CO Y m IW r o o � I' -os co .. o 0 m < 8 it 3 ~ ZI w cc rt Q czt iii C.:1 ii.) oU O - NN N .M > > O . , , CO 7 z p) CC Ce Q' d' Q' E c C C C C C LE u d O O O O O 'E C 0 0 0 0 •• C E U U U ...... U p p J J J J C CO I• �• ,I • cc Z C C 0c 0c C N N 7 7 7 7 w m \)': o) �, E M ° O 0 waa °0) N w crs M 0 v E c CD o ~ Z .d d A 7 N N it ce O r C W O z N h N Q A w O m1 0\ 4- Z 2 o c `3 uE. m v R A 7 0 v r w p)� J d N Z rn '11 0 ' O u 5 �• O) O O) W : LL d 5 d ' d :. ZWJ \ ` \ ,\ ��) 1 `\ 1 U C'! H m - m or, rn OI m r% CD rn rn CD 1 ° a —y o)2_ S. o 0 O c 0 ° 0 0 0 0 d 0. Q• j O F- 3 J O H W J J J J Q' W J J J J 3 C 1 9 II C co C Z N I N o l )..,51 , Z LI a IJ aJ V) o w r O co = i m co Ce refl._) O g Z Z U CL 0 W a Z w W z > J V d N N Z d0 I l IICC w = w o J a i m O >, E C eCL ms- a) a ui I O N a ao E U0 0 Q z p co I 5r a N CCIZ cnN WO 0 I m/ Q' N , III VI O 0 Q O Q o o. 0 Z E IT) U E 1 Z I 3 N M CO IZ 0( \rz 1 01 0 wv il N O Z v , y i W oD E 0y c o > m U y° m 0E ! E 0 o C) t c o o , o a Q 0 < CC U C) PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: December 27, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7"'Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Reports X Other- Logs ❑ Agreement DETAIL QTY DESCRIPTION 4 End of Well Reports ODSN-16 (API: 50-703-20620-0000) ODSN-16L1 (API: 50-703-20620-6000) 16 Well Logs ODSN-17 (API: 50-703-20622-0000) ODSN-17L1 (API: 50-703-20622-6000) 4-Engineering Logs, 4-Gas Ratio Logs, 4- Formation Evaluation Logs (2" & 5") We request that all data be treated as confidential informati /T 19 3 j -, Received by: 6-5Da r� .:r$'0 �9Y '(-4'�Z='. r'‘.-4e".3. .d 7 1+'l�v.:'+aEor Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax a/0-04 3 0067-1. 907-343-2128 phone aio -lei/ 9c6—9-.k aro-O aoS acn -b 4I a as-zil b 1 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: November 10, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other— logs, CDs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-17 (API: 50-703-20622-0000) ODSN-17L1 (API: 50-703-20622-6000) 2 CD-Roms LWD Final Processed Data (digital graphic logs, digital data) 8 Well Logs 8 Well logs DGR, EWR-Phase 4, CTN, ALD, Horizontal Presentation (1:600, 1:240) MD, TVD logs DGR, EWR-Phase 4, CTN, ALD, Invert/Revert Sections (1:600, 1:240) MD, TVD logs We request that all data be treated as confidential inforyx TltrirY' Received by: Date: Please sign and return one copy to Pioneer Natural Reso "r lt1t., ATTN: Shannon Koh ajv_393 cz26 ,, 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax ao319 it STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q . Gas ❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q - Exploratory❑ GINJ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: _One Service ❑ Stratigraphic Test❑ I 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Pioneer Natural Resources Alaska,Inc. Aband.: 10/23/2010 210-093. 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 8/25/2010 50-703-20622-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2940'FSL, 1172'FEL,Sec. 11,T13N,R7E, UM- 10/7/2010 - ODSN-17 I Top of Productive Horizon: 8.KB(ft above MSL): 56.2' • 15.Field/Pool(s): 4100'FSL,3881'FEL,Sec. 15,T13N,R7E, UM GL(ft above MSL): 13.5' Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuiqsut Oil Pool - 4931'FSL, 133'FEL,Sec.22,T13N,R7E,UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 469826.11 y- 6031056.25 Zone-ASP 4 - 19,947'MD/6382'TVD' ADL 355036/ADL 355038 TPI: x- 461824.64 y-6026973.57 Zone-AsP 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 465558.81 y- 6022506.73 Zone-AsP 4 2007'MD/1960'TVD 417497 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) _ 854'MD/831'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: Gyro,MWD/LWD,GR,ABG/ABI, DIR,PWD,DGR, RES,ALD,CTN N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven 11-3/4" 60# L-85 HYD Surface 4660' Surface 3285' 14-1/2" 600 sx PF'L';665 sx Class'G' 21 9-5/8" 40# L-80 4497' 10,978' 3231' 5365' 11-3/4" 616 sx Class'G' HYD 521 7" 26# L-80 Surface 10,844' Surface 5320' 8-1/2" Tie-back BTC-M _ /I 7" 26# L 80 10,830' 14,106' 5316' 6186' 8-1/2" 230 sx Class'G' i- 1�6 i� 5.-,4 < ib c:__ HYD 511 4-1/2" 12.6# L-80 14,265' ✓ 19,695' / 6207' 6360' 6-1/8" Uncemented 74--- HYD 521 24.Open to production or injection? Yes[ Noll If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 2-7/8",6.5#, 13,753' Hydro II Packer CO L 80,IBT-M 2633'MD/2465'TVD See Attachment,Pg.3 I f.(f i 11-1 Ot j # .,, '26. . ACID,FRACTURE,CEMENT SQUEEZE,ETC. ( 0 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Tay 2100' Freeze protect 11-3/4'x 7"annulus w/140 bbls diesel t:.-- .,. :-1 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 11/3/2010 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/3/2010 13 Test Period 503 187 0 3" 372 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 339 297 24-Hour Rate 928 345 0 23.1 28. CORE DATA Conventional Core(s)Acquired? Yes 0 No E Sidewall Cores Acquired? Yes 0 No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytic r ç ,a ' .....„, None NOV 1 7 2010 e e iiiesiai it&Gas Cons.0 t, i Anchorage RBDMS NOV 19 `t Form 10-407 Revised 12/2009 CONTINUED ON REVERSE /4.-- /1.22 lOSubmit original only ,,,.. /f Z/),2) 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 838' 837' and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1692' 1668' Top West Sak 2408' ' 2300' Top Torok 9797' 4978' . None Top HRZ 12,244' . 5750' Top Kuparuk C 13,235'. 6009' • Top Nuiqsut 14,061' 6178' Formation at total depth: 19,947' 6382' 31. List of Attachments: Summary of Daily Drilling Operations,Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343-2186 Printed Name: Alex Vau•han Title: Operations Drilling Engineer Signature: �/� Phone: 343-2186 Date: 11/17/2010 Well Name:ODSN-17 Per o.:210-093 Prepared By:Kathy Campoamor,343-2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Pioneer Natural Resources Alaska Inc. ODSN-17 Page 3 Form 10-407, Well Completion or Recompletion Report and Log Attachment - Box #24 24. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner bra-a&41i Q Perforated Pups w/ 6-1/2" Holes @ depths listed: MD TVD 14,448' - 14,452' 6221' - 6222' 14,751' - 14,756' 6240' - 6240' 14,953' - 14,958' 6256' - 6256_ _ 15,161' - 15,166' 6265' - 6266' 15,369' - 15,373' 6260' - 6260' 15,790' - 15,794' 6229' - 6229' 15,991' -15,996' 6234' - 6235' 16,198' - 16,203' 6252' - 6253' 16,404' - 16,408' 6272' - 6273' 17,848' - 17,853' 6261' - 62&Y 18,053' - 18,057' 6249' - 6249' 18,258' - 18,262' 6255' - 6256' 18,463' - 18,468' 6270' - 6271' 18,665' - 18,670' 6288' - 6288' 18,871' - 18 875' 6300' - 6300' 19,073' - 19,078' 6311' - 6311' 19,275' - 19,280' 6327' - 6328' 19,481' - 19,486' 6345' - 6345' 19,684' - 19,689' 6359' - 6360' PI 0 N E E R perations Summary Report - Stat_ NATURAL RFSOURCFS Well Name: ODSN-17 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 8/25/2010 End Date: 10/23/2010 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 8/25/2010 8/26/2010 158.0 92.00 9.20 Accept rig at 00:00 hrs,and RU same for spud on ODSN-17.Install starting head and NU drilling riser.Change out saver sub to 4.5 I.F. RU all 5"handling tools.PU 5"DP making up stands and rack back same in derrick.Racked back 43 stands 5"D.P.Racked back 5 stands 5"HWDP with jars.Stage BHA tools on rig floor and RU Gyro survey tools.PU 14-1/2"bit#1,mud motor,X-O subs,and ABI tool.Ream 1/56'11158'to clean out 16"conductor. Drill 14-1/2"hole f/158'11250'. POOH f/250'U36'.TIH making up BHA#1 as per directional driller f/36'11172'.Wash down f/172' 11250'without rotary. 8/26/2010 8/27/2010 250.0 1,427.00 9.20_ 14-112"'fioie f/250'112 T Noticed+/-70*difference in gyro tool face and scribe line.Reseat Gyro survey 2 more times with same result,POOH with Gyro and check tattle tail-- Good surveys. Rerun Gyro again with same result. POOH 1/267'U surface checking BHA orientation.Found scribe mark to be off approximately 70*.TIH f/surface t/267'.Directional drill 14-la"-hole 1/267 t/1,677'. 8/27/2010 8/28/2010 1,677.0 1,223.00 9.40 CBU at 1,677'while rigging down Gyro equipment. POOH 1/1,677'111,201'.PU and make up EM repeater assembly 1/1,201't/1,232'.TIH 1/1,232'(/1,677'.Directional drill 14-1/2"hole 1/1,677' U2,469'.Pump 50 bbl hi-vis sweep and CBU 1.5x at 2,469'.POOH f/2,469'U1,613'.TIH f/1,613' U2,279'.Reciprocate pipe while working on hammer mill.TIH 1/2,279'U2,469'.Directional drill 14- 1/2"hole f12,469'(/2,900'. 8/28/2010 8/29/2010 2,900.0 1,523.00 9.50 Directional drill 14-1/2"hole 1/2,900'113..516'.CBU at 3,516'.POOH 1/3,516'U2,469'.Service rig and top drive.TIH 1/2,469'113,516'. Directional drill 14-1/2"hole 1/3,516'114,423'. 8/29/2010 8/30/2010 4,423.0 247.00 9.50 Directional drill 14-1/2"hole f/423'U4,670'.Circulate the hole clean with 2-50 bbl hi-vis sweeps.POOH 1/4,67(71/17-0-'.TIH f/170'114,670'.Circulate the hole clean with 2-45 bbl hi-vis sweeps.POOH 1/4,670'U1,327'.Lay down EM repeater assembly.POOH 1/1,201'11172'.Lay down 14-1/2"BHA f/172'U surface. RU 11-3/4"casing equipment.Gave 48 hr notice to AOGCC of upcoming BOP test. 8/30/2010 8/31/2010' 4,670.0 9.40 RU 11-3/4"casing equipment.Held pre job safety meeting for running'casing;with"all involved, personnel.RIH with 11-3/4"L-80 60#Hyd 521 casing f/surface 1/2,247'.Repair hydraulic line on casing tongs.RIH with 11-3/4"L-80 60#Hyd 521 casing 1/2,247'U4,615'.RD fill up tool,MU landing joint and land casing f/4,615'U4,659.8'.RU cement head and lines.Stage up rig pumps to 12 bpm and circulate hole clean.Attempt to switch over to HES for cement job-hydraulic unit on cement mixer not working.Circulate at 5 bpm while waiting on pump truck. 8/31/2010 9/1/2010 4,670.0 9.30 Circulate at 5 bpm while waiting on HES cement pump truck.Stage up pumps to 11 bpm and CBU.Circulate at 5 bpm while off loading and RU cement pump truck. Held pre job safety meeting with all involved personnel,begin pumping cement job as per cement program,pumped all of spacer,,and 392 bbls lead cement.While mixing tail cement the cement mixing tanks flash set. Bring rig pumps up pumps to 10 bpm and displace cement out the hole with 9.4 ppg WBM. Slow down pumps to 4 bpm with cement returns back to surface in order to not out run CCU pump.Circulate at 5 bpm while waiting on cement unit to be barged out.Off load and RU cement unit.Circulate at 5 bpm while cleaning set up cement from RSC injection pits. 9/1/2010 9/2/2010 4,670.0 9.20 Circulate at 5 bpm while cleaning set up cement from RSC injection pits.Stage up pumps to 12 bpm in 1 bbl increments--hole packed off.Cut pumps back to 6 bpm with multiple pack offs. Stage pumps up in 1/4 bbl increments.Max rate achievable is 6 bpm without any pack off events. PJSM w/all involved personnel.Swap over to HES,pump 20 bbls seawater,release 1st bottom plug and kick out w/last 2 bbls,test lines to 4000 psi.Load top plug,pump 60 bbls 10 ppg spacer.,,zump 442 12,015., Q0 sxl Lead Permafrost'L'cement at 10.7 ppg(w/yield of 4.15). Pump 145_Obis.(665.,sx).Jail Premlum.'G':Cementat 15.8_ppa(w/yield of 1.19).Release top plug -Kick out w/20 bbls seawater.Displace w/9.4 ppg spud mud using rig pumps 6 bpm, 1200 psi-- Hole packed off and lost returns.Slow rate to 1 bpm in attempt to regain circulation-- unsuccessful.Attempt to reciprocate pipe to gain returns--unsuccessful.Unable to reseat casing hanger.Returns came back with 312 bbls of mud pumped--cement returns to surface." Cement set up in casing and was unable to bump plug—Pressured up to 4600 psi 80%of casing burst. Needed 495 bbls to bump but could only pump 374 bbls leaving 121 bbls of cement ,; inside the casing._CIP at 20:20 hrs.Check floats--holding.RD cement head and lines and blow down same.LD landing joint.Flush cement from drilling riser with citric acid pills. Page 1/7 Report Printed: 11/11/2010 'PIONEER ,,erations Summary Report - Stati NATURAL _RIF S_OURGES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) " (ft). Mud(ii)go, Summary 9/2/2010 9/3/2010 4,670.0 0.00 9.30 Flush cement from drilling riser with citric acid pills,and split riser to break up cement with water hose._ND and lay out drilling riser.NU drilling spool and test same to 5000 psi--Good test.NU drilling riser and BOP stack. Install trip nipple and secure stack with turn buckles.Perform body, test onla.O_P_Eto 3500 psi on chart for 5 min--Good test.PU 10-5/8"BHA#2 f/surface t/590'. TIH f/590't/3,380'--tagged top of cement.Drill cement f/3,380't/3,600'. 9/3/2010 9/4/2010 4,670.0 0.00 9.50 Drill cement f13,600't14,588.'.Attempt to test casing to 3500'psi at 4,588'.Pressure up on casing h. .< and pumped in at 2600 psi.Pressure bled back to 1500 psi: Retest w max achieved pressure was 1800 psi.Test all surface equipment to 2600 psi--Good test,Perform"mock"formation L.O.T.at 4,660'MD/3,285'TVD with a 9.7 ppg mud. Leaked off.at 1030 psi and stabilized at 1000psi.EMW of leak off=15.55 ppg.CBU 1.5 times at 4;58 Oti#/4,58$ 1/590'. Tested choke manifold while POOH.AOGCC rep John Crisp witness to t'Radc aolt tiW P and le down SHA. ; ' ° 9/4/2010 9/5/2010 4,670.0 0.00 9.50 TOOH and LD 10-5/8"Milltooth Bit and Mud Motor. Remove wear bushing and install test plug. n RU.testing equipment Test Annular to 25Q psi_low/2? Q0 psi high with 5"DP.Test Upper and Lower 2-7/8"x 5"VBR's,Blind Rams,Choke and Kill Line HCR's,Choke and Kill Line Manual {, -' valves, Floor Safety valve,Dart valve,Upper IBOP, 14 Choke Manifold valves to 250 psi low/ 4500 psi high. All low and high tests held 5 min ea.All tests charted.Accumulator test,System Pressure 3100 psi,After Closer 2000 psi, Initial 200 psi recovery 26 sec's,Full recovery 1 min 39 sec's.Test witnessed by AOGCC Field Inspector John Crisp.RD testing equipment.Pull Test Plug and Install Wear Bushing. PU 11-3/4"RTTS and TIH to Test Casing. Planned to test casing in joint above FC @—4550'md;however,experienced excessive drag while TIH with RTTS at 3719'MD. Unable to get RTTS to set in casing between 3243'and 3719'MD. TOOH with RTTS and PU Clean Out Assy with PDC bit. 9/5/2010 9/6/2010 4,670.0 0.00 10.00 Finish washing apd r �t R'%md to rerpnve cement sb ;ftp i lgSj 1.,314;'c sing Circ weighted hi-vis sweep and cleaned cement cuttings from wellbore TOH f/4588 1/2374'and and TIH while PU 69 joints of 5/dnll pipe TOH andtD Ctean Out Assy ' . z _ 9/6/2010 9/7/2010 4,670.0 28.00 10.00 POOH f/3896'to the BHA at 567'.POOH laying down BHA f/567't/surface.PU RTTS and RIH on HWDP t/37Q'.TSH f/37Q'_t/4550'.Circulate 10 bbls around RTTS and set same with 20k down.Test casing to 3500 psi on chart for 30 min--Good test.POOH f/4,550'1/370'.POOH racking back HWDP and lay down RTTS f/370't/surface.PU directional 10-5/8"BHA f/surface 1/650'and shallow pulse test same.TIH f/650'1/4,588'.Drilling cement and float shoe f/4,588' 1/4,670'. Drill 10-5/8"hole f14,670'1/4,690'..13.erform F.I.T.at 4,659'MYlD/3,285'1VD with 10.0 ppg WBM to 1003 psi for EMW of 15.87 ppg_F.I.T.was witnessed by AOGCC rep John Crisp.Drill 10-5/8"hole f/4,690'1/4,698'. 9/7/2010 9/8/2010 4,698.0 1,552.00 10.00 Directional drilling 105/8"hole(/4,698 04770'.Drop 1-5/8"ball and p ,pb4ut) lt on4eaf and'sheer' ball seat to engage under reamer cutters.Raise pump rate to 75,0 gp,; o full�!',expand�utter blades and pull 10k against formation to ensure cutters engaged D)<, a grill ifll$chole f/4,770'1/5597'.Change out#2 swab on#2 mud pump.Directional';'4.— a ole f/5,597' 1/6,250' 9/8/2010 9/9/2010 6,250.0 1,490.00 9.85 Directional drill 10-5/8"hole f/6,250'1/7,740'. 9/9/2010 9/10/2010 7,740.0 1,065.00 9.80 Directional drill 10-5/8"hole f/7,740'1/8,565'.Circulate with 1 pump'while changing=out swab and liner on#2 pump.Circulate with#2 pump while changingvaives and seats in pump#1. Directional drill 10-5/8"hole f/8,565't/8,805. viz 9/10/2010 9/11/2010 8,805.0 895.00 9.80 Directional drill 10-5/8"hole f/8,805'1/8,847'.Service rig and top drive while changing out 0-ring seal in stand pipe hammer union in PUTZ. Directional dril 10-5/8"hole f/8,847'1/9,155'.Change out swab and liner on pump#2.Directional drill 10-5/8"hole f/9,155'1/9,700'. 9/11/201:0 9/12/2010 9,700.0 1,228.00 9.75 Directional drill 10-5/8"hole f/9,700'1/10,683'.Circulate at reduced rate while trouble shooting sync issues with#3 generator after losing high line power.Directional drill 10-5/8"hole f/10,683' 1/10,833'.Futtctigp t_e j ROPE es oer F{OQGC PTD--All functioned properly.Directional drill 10- 5/8"hole f/10,833'1/10,928_• Page 2/7 Report Printed: 11/11/2010 'PIONEER ,aerations Summary Report - State NATURAL RFSOURCES Start Depth : Fool/Meters.. Dens Last Start Date End Date (ftK8) (ft) Mud(Ib/gal) Summary 9/12/2010 9/13/2010 10,928.0 52.00 9.80 Directional drill 10-5/8"hole f/10,9_2.8"U10,980'.,Circulate the hole clean with 2x 45 bbls hi-vis, weighted sweeps at 12.4 ppg and make 400 bbl whole mud dilution with clean 9.8 ppg mud. Once hole was clean the derrick man was sent up to the monkey board and it was noticed that the board was damaged from the elevators being kicked out and striking the board as it went up past the board.Assess the damage and determine it is not repairable. Circulate and condition mud for one surface to surface volume every 6-8 hours to ensure mud properties are in spec for running casing. Monitor well while waiting on new monkey board to be fabricated in Dead Horse. 9/13/2010 9/14/2010 10,980.0 0.00 9.75 Monitor well while waiting on new monkey board to be fabricated in Dead Horse.Circulate and condition mud while pumping one surface to surface every 6-8 hours to ensure mud properties are in spec for running casing.Shut annular preventer and monitor well while prepping derrick to install new monkey board.Circulate and condition mud while pumping one surface to surface every 6-8 hours to ensure mud properties are in spec for running casing.Shut annular preventer and monitor well while installing new monkey board. 9/14/2010 9/15/2010 10,980.0 0.00 9.85 Shut annular preventer and monitor well while installing new monkey board.Perform magnetic particle inspection on all welds--All welds passed inspection.Circulate and condition mud with 2x bottoms up. POOH f/10,960't15,512'.Attempt to circulate at 5,512'--packed off,work pipe free and use step rate method to establish circulation. POOH f/5,512'U4,677'.Establish circulation with step rate method up to 700 gpm and pull test Rhino reamer against casing shoe with 10k over P/U wt--Good test.Circulate hole clean with 3x bottoms up strokes.Pump out the hole f/4,677'U2,393'. 9/15/2010 9/16/2010 10,980.0 0.00 10.20 Pump out of 10-5/8"hole f/2393'U681'. Pump 30 bbls H.V.sweep around.Cut drilling line. POOH. LD BHA#6. PU BHA#7.Function test Rhino reamer.RIH t/4685'.Pull test reamer at shoe w/10k over.RIH t/10885'.Circ hole clean.Open hole to 11-3/4"f/10885't/10969'(bullnose at 10,980').Pump H.V.sweep around surface to surface. NOTE:Notified AOGCC at 00:15 hrs on 09/16/10 for upcoming BOP test.At 00:30 hrs on 09/16/10,AOGCC Rep.Bob Noble waived witness of test. 9/16/2010 9/17/2010 10,980.0 0.00 10.30 Circulate H.V.sweep surface to surface.POOH(/10,980'U6,170'.RIH U6,243'.CBU.POOH (/6,243'U4,763'.Pump H.V.sweep surface to surface.Pull test rhino reamer at shoe.Pump out of hole(/4,763'U956'.Troubleshoot Top Drive link tilt problem.Continue pump out of 10-5/8" hole f/956'U BHA at 577'. LD BHA.RU to test BOPE. Install test plug. Perform Accumulator Draw Down Test: -System pressure=3000 psi -Closure pressure=2000 psi -17 seconds to obtain 200 psi increase -1:57 to obtain full system pressure -5 bottles at 1700 psi avg Change bottom rams to 9-5/8"for upcoming liner run. AOGCC Rep.Bob Noble waived witness of test at 00:30 hrs on 09/16/2010. 9/17/2010 9/18/2010 10,980.0 0.00 10.10 Test BOPE per AOGCC.$PXDrules and regulatigps.,Test BOPE w/5"test joint to 250 psi low/ 4500 psi high for 5 charted min each test.Test annular w/5"test joint to 250 psi low/2500 psi for 5 charted min each test.Test lower,_9-518",rams,to.250 psi low/4500.psi high for 5 charted min each test.Test annular w/9-5/8"test joint to 250 low/2500 high for 5 charted min each test Choke and Kill Line NCR's,Choke and Kill Line Manual valves,Floor Safety valve,Dart valve, Upper!BOP, 14 Choke Manifold valves to 250 psi low/4500 psi high for 5 charted min each test. Right to witness test waived by AOGCC Rep.Bob Noble at 00:30 hrs on 09/16/10. PU 3 DC's and 3 HWT from shed and stand back.RU&run 9-5/8"liner U6,448'.PU liner hanger_. 9/18/2010 9/19/2010 10,980.0 0.00 10.15 Run 9-5/8"40#L-80 Hyd 521 liner on 5"DP f/6,497'U10,978'(shoe depth).Drop ball and circ down.Pressure up to 3000 psi and set hanger.Circ and condition mud for cement job. Pump 10 �I`` bbls S.W. preflush.Test lines to 4000 psi.Pump 60 bbls dual spacer at 12.5 ppg.Mix Duple, cc's 128.4 bbls(665 sx)Class'G'cement at 15.8 ppg,(1.19 yield).Drop DP wiper plug-Kick out w/ \ 17 bbls seawater.Switch to rig pumps. Displace cement w/10.1 ppg LSND mud w/9 bpm,2850 psi.Slow to 3 bpm to bump plug. Bump at w/52801820hrs.stks.T.O.L.Pressure 4up497'to;3500B.O.L.psi.at Hold10978'.for 5 min.Set on chart. Bleed off. Check floats-OK. Liner Top packer at 4,519'.Test 11-3/4"x 9-5/8"to 3500 psi for 5 min.on chart.Good test.RD equipment.POOH 84,467'U873' Page 3/7 Report Printed: 11/11/2010 • P I O N E E R aerations Summary Report - Stat. NATURAL RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(Ib/gal) Summary 9/19/2010 9/20/2010 10,980.0 0.00 1.00 POOH(/873'to surface.LD liner running tool.ND BOPE,riser&drilling spool. Install wellheads &Multi bowl.Test to 5000 psi f/10 min.NU BOP&MPD equip,Change bottom rams to 2-7/8"x 5"VBR's.Test same to 250 psi low/4500 psi high for 5 charted min each test.Test choke&kill lines,MPD HCR&manual to 250 low/4500 high for 5 charted min each test. Install riser& flowline.RIH w/6 DC's&6 HWT.POOH LD same.PU 102 jts 5"DP f/shed 03,241'.Circ DP volume x 2.POOH.PU 8-1/2"drlg BHA. 9/20/2010 9/21/2010 10,980.0 20.00 10.00 PU 8-1/2"BHA#8.RIH 010,850'.Test 11-3/4"x 9-5/8" sing tto„3„5t 0,p„�Si for 30 charted min.' Good test.Tag Landing collar at 10,885'.Drill Landing Cupar 0ea049t,,to Float Collar at 10,897'.Drill same and clean out to 9-5/8"shoe at 10,977'.Drill'shoe and clean out rathole U10,980'.Drill 20'of new 8-1/2"hole 011,000'.Circulate and displace well with new 10.0 ppg LSND mud-Perform FIT,to 14.0 ppg EMW,,New MW 10.0,shoe TVD=5,372', 1120 psi= 14.0 ppg EMW.Pull trip nipple. Install RCD head. • 9/21/2010 9/22/2010 11,000.0 1,155.00 10.10 Install rotating head rubber. Install RCD. Fill lines and establish circ w/13 ppg EMW. Directional Drill 8-1/2"hole f/11,000'U12,155'. Maintain 13.0 ppg EMW w/MPD. 9/22/2010 9/23/2010 12,155.0 1,564.00 10.00 Directional drill 8-1/2"hole f/12,155'013,719'while maintaining 13.0 ppg EMW w/MPD. 9/23/2010 9/24/2010 13,719.0 384.00 10.10 Directional drill 8-1/2"_hole f/13,719'U14,103'while maintaining 13.0 ppg EMW w/MPD., Circulate hole clean with 2x 40 bbl hi-vis sweeps and 5x bottoms up strokes.Close annular preventer,trap 950 psi on annulus and change out RCD bearing--element went out.CBU at 14,103'. Back ream out the hole(/13,977'013,590'.Work pipe to clear pack off,establish circulation,and circulate bottoms up at 13,590'.Back ream out the hole f/13,590'013,311' maintaining 13.0 ppg EMW w/MPD.Close annular preventer,trap 900 psi on annulus and change out RCD bearing--Top hydraulic seal went out.Back ream out the hole f/13,311' U13,121'. 9/24/2010 9/25/2010 14,103.0 5.00 10.00 Back ream out the hole f/13,121'012,240'.Pump 40 bbl hi-vis sweep and circulate 2x bottoms up at 12,240'. POOH(/12,240'U10,978'.TIH f/10,978'U13,501'. Function test BOP's.Wash and ream in the hole(/13,501'U14,103'.Establish circulation,stage pumps up to 650 gpm and back ream out the hole(/14,103'013,691'.TIH f/13,691'U14,103'.Directional drill 8-1/2"hole f/14,103' 014,108'maintaining 12.8 ppg EMW w/MPD.Pump 2x 50 bbl low-vis sweep,65 bbl 15.0 ppg weighted sweep,50 bbl hi-vis sweep and circulate surface to surface. 9/25/2010 9/26/2010 14,108.0 12.90 Pump 50 bbl low-vis sweep,65 bbl 15.0 ppg weighted sweep,50 bbl hl vis sweep and circulate surface to surface.POOH(/14,108'U13,209'.TIH f/13,209'1/14,108'.CBU 2x.Circulate while making 800 bbl dilution with clean 11.0 ppg mud and raise mud weight to 12.8 using 18.0 ppg spike fluid.Monitor well--static,remove RCD bearing,and install trip nipple.Circulate and condition mud weight to 12.8.POOH f/14,108'02,461'. 9/26/2010 9/27/2010 14,108.0 12.70 POOH f/2,461'0558'. Rack back HWDP,lay down BHA and clear rig floor of same.Remove wear bushing and install 7"test joint with test plug.Change out bottom pipe rams from 2-7/8"A, 5"VBR's to 7"casing rams.RU test equipment,test bottom casing rams to 250 psi low/4,500 psi high on chart for 5 min each test. RD test equipment and install wear bushing.MU mule shoe,TIH picking up 6 jts of HWDP and rack back in derrick.RU 7"casing equipment and hold PJSM with all parties involved.RIH with 7"26#L-80 Hyd 511 casing f/surface 03,244'.PU and MU WFT"PHR"rotating hyd hanger,"TSP"liner top packer,"PBR"tie back sleeve,running tool and bumper jars f/3,244'03,294'.TIH f/3,294'04,436'with 7"liner on 5"drillpipe.Pump lx liner volume above 9-5/8"liner top.TIH f/4,436'07,385' with 7"liner on 5"drill pipe. 9/27/2010 9/28/2010 14,108.0 10.00 TIH f/7,385'010,900'with 7"liner.Establish circulation,stage up pumps to 3 bpm,and circulate while making up WFT cement head.TIH f/10,900't/14,106'with 7"liner.Stage up pumps in 1/4 bbl increments up to 4.5 bpm and circulate cutting mud weight back from 13.0 ppg to 10.0 ppg. Attempt to release setting tool from liner hanger-unsuccessful.Apply left hand torque to activate emergency release mechanism. Apply 6 rounds total of left hand torque to release setting tool. Circulate cutting mud weight back from 13.0 ppg to 10.1 ppg.Swap over to HES and Pump 10 bbls seawater preflush,test lines to 4000 psi. Pump 40 bbls dual spacer at 12.5 ppg,pump 48.3 bbls(23Qsx,l_Premium'G'cement at 15.8 ppg(w/1.18 yield).Drop DP wiper plug-Kick out w/..K ,17 tdt1. S;w ter. Displace cement w/10.1 ppg mud with rig pumps.Plug did not bump.Bleed off-Check floats-OK. CIP at 22:50 hrs-Full returns for entire job.Set packer with 50k dowp- wt.Top of 7",26#L-80 HYD 511 liner at 10,829'and liner shoe at 14,106'. t,„ I Page 4/7 Report Printed: 11/11/2010 P10 N E E R aerations Summary Report - Stati NATURAL RFSOURCES Start Depth Foot/Meters Dens Last StartDate End Date (ftKB) (ft) Mud(Ib/gal) Summary 9/28/2010 9/29/2010 14,108.0 10.20 Close top_pipe rams and test liner top packer to 3500 psi by pumping down the kill line.Test held 30 min on chart—Good test.Circulate 1.5x bottoms up at 10,829'. No cement returns observed at shakers.Lay down WFT cement head and lines.Slip and cut drill line.POOH f/10,809'U surface laying down 5"DP.LD liner running tool and bumper jars.MU mule shoe and TIH f/ surface t13,338'.Close blind rams and perform L.O.T.at 10..106'and/6,186'tvd. Leaked off at 1200 psi stabilized at 1050 psi for EMW of 13.2 ppg.RU 7"casing equipment and held PJSM with all involved personnel.MU tie back seal assembly and RIH with 7"L-80 26#BTC-M casing f/surface t1106'. 9/29/2010 9/30/2010 14,108.0 10.20,RIH with 77"L-80 26#BTC-M casing f/106'U10,848'. Stabbed into"PBR"„at 10.829'—18'of penetration.Close annular and test seal assembly to 2500 psi held and charted 5 min—Good test.Unsting from Seal Assembly and TOH to install space out pups.TOH 16.5 feet and experienced 100K overpull in attempt to unsting.Slacked seal assembly inside tie-back and tag up on locator to verify pipe free—unable to pull past tight spot with 100K overpull.Close annular and retest seal assembly to 2500 psi held and charted 5 min--Good test.MU 4-1/2"IF x 7"BTC crossover as drive sub and worked pipe with 6K torque while reciprocating pipe. PU and pulled into tight spot with 100K.Slack off and PU and pulled through tight spot.Continue TOH while laying down 3 joints to install space out pups.MU space out pups and one full joint,7"hanger with pup and landing joint.TIH and position seal assy-3'above tie-back with hanger below annular.Close annular and hold pre-job meeting,pressure test lines with P6 pump to 1500 psi and pump 140 bbls of diesel freeze protection into annulus while taking returns up the 7"casing., Slack off 7"while stripping through the annular to land hanger and engage seals in tie-back at 10,840'with 11'of seal assembly stung into PBR.Test seal assembly to 2500 psi on chart 30 min--Good test.RD all casing equipment and RU all 4"handling equipment while loading 4"DP in pipe shed. 9/30/2010 10/1/2010 14,108.0 10.20 Installpack off in multi-bowl and test same to 5000.psi for 10 min on chart--Good test. Install test plug and change out bottom pipe rams from 7"casing rams to 2-7/8"X 5"VBR's.Test upper and lower 2-7/8"X 5"VBR's to 250 psi low/4500 psi high.Test annular to 250 psi low/2500 psi high.All tests charted and held for 5 min per test.TIH with 7"FasDrill cement retainer f/ surface U12,443'while picking up singles from pipe shed. 10/1/2010 10/2/2010 14,108.0 10.20 TIH with 7"FasDrill cement retainer f/12,443't/13,953'.PU and MU 10'pup joint to space out FasDrill retainer at 13,960'.Set retainer and sheer off with 65k overpull.Tag retainer at 13,960' to confirm depth.Test casing to 3500 psi for 30 min on chart--Good test.Stab stinger thru FasDrill retainer,set down 20k,and test annulus to 1500 psi on chart for 5min—Good test. ' Bleed off annulus pressure and obtain injection rates at 1/2 bbl increments up to 2 bpm.PU U13,950 and break circulation with HES cement unit. Pumped 8 bbls of seawater spacer,test ' lines to 3500 psi--Good test.Pump 15_.bbls of 15.8 ppg cement(1.18 yield Premium G).Chase with 13 bbls of seawater,and shut down cement pump.Break out pup joint,insert DP wiper ball into pipe,MU same,and displace cement to stinger. Pumped 102 bbls of 10.1 ppg mud.Sting into cement retainer at 13,960'and inject cement while monitoring annulus pressure.Inject 28 bbls spotting 2 bbls of spacer below retainer.Unsting from retainer and observed 1100 psi bleed off.CBU 1.5x at 13,950'. POOH f/13,950'U7,332'.Trouble shoot and change out joy stick control for draw works.POOH f/7,332'U surface and LD setting,tool.Tested choke manifold 250 psi low/4500 psi high while POOH.Change out lower well control valve and saver sub on top drive to 4"XT-39.Test BOPE per AOGCC&PXD rules and regulations.Test BOPE w/4"test joint to 250 psi low/4500 psi high.Test annular w/4"test joint to 250psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high.All tests charted and all test held for 5 min.Right to witness waived by AOGCC Rep.Jeff Jones at 0800 hrs on 09/29/10. • 10/2/2010 10/3/2010 14,108.0 20.00 10.20 Test upper and lower 2-7/8"X 5"VBR's w/4.5"test ioint tq_a59 psi low/4500 psi high..All tests charted and all test held for 5 min.Right to witness waived by AOGCC Rep.Jeff Jones at 0800 hrs on 09/29/10.Install wear bushing.TIH with clean out 6-1/8"BHA f/surface U2,212'.Slip and cut drill line.TIH f12,212'U13,600'.Madd Dass BAT Sonic at+1-300 foh f/13.600'U13.960.Drill cement and float equipment f/13,690't114,108'. Page 5/7 Report Printed: 11/11/2010 'PIONEER ,aerations Summary Report - StatE. NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date- • -r' End Date (ftKB) 01) Mud(ibigal)' '.. ':f. : . Summary 10/3/2010 10/4/2010 14,128.0 0.00 10.20 Drill 6-1/8"hole f/14 108't/14,128'.CBU at 14,128'. Perform F.I.T.at 14,106'and/_6 yylttZl.0 2 ARO-mud xQ.741Z psi.for EMYaL S f 12.5..ppg. Pump dryjob and madd pass BAT Sonic f/14,128'1114,060'.POOH f/14,060'U surface.PU directional 6-1/8"BHA#11 t/379'and shallow test same.TIH f/379'1114,064'.Break circulation and test MWD at 14,064'.Remove trip nipple and install RCD bearing.Displace well to 7.7 ppg reconditioned OBM at 14,128'. 10/4/2010 10/5/2010, 14,128.0 1,865.00 7.80 Displace well to 7.7 ppg OBM at 14,128'.Maintain 9.8 ppg EMW using MPD equipment ry Directional drill 6-1/8"hole f114,128'1115993'. 10/5/2010 10/6/2010 15,993.0 7.90 Directional drill 6 1/8 hole f/15,933,t/16,571 Element failed on ROD,trap pressure with annular 14,099.00 and change out RCD bearing.Directional drill 6-1/8"hole f/16,571'1117,887'maintaining 10.0 ppg EMW w/MPD. 10/6/2010 1 • 0/7/2010 17,887.0 1;,964.00 8.00 Directional drill 6-1/8"•hole f/17.8137L,1{19.86,1'maintaining 10.0 ppg EMW w/:MPD, ' 10/7/2010 10/8/2010 19,851.0 96.00 8.00 Drill 6-1/8"hole to lower lateral f/19,851'to TD at 19,947'maintaining 10.1 ppg EMW w/MPD. Circulate hole clean.POOH for wiper trip f/19,947'1114,064'.Cut&slip drlg line.Service rig.RIH f/14,064'1118,890'.Wash&ream f/18,890'1119,690'to overcome negative weight.CBU x2.Spot 200 bbls new 6.9 ppg LVT in DP.Chase w/10 bbls H.V.spacer and 104 bbls 10.0 ppg MOBM. POOH stopping to spot 16 bbls 10.0 ppg MOBM every 10 stands t/15,213'. 10/8/2010 10/9/2010 19,947.0 0.00 8.10 Spot 10.0 H.V.pill across sump section at 15,213'.POOH to'14,064',DispiaceWell vt/;1 1 ppg• MOBM.POOH.LD BHA.Function test BOPE per AOGCC weekly requirements-good test.PU • 24 jts of 4"HWT f/pipeshed.Circ pipe volume.POOH stand back HWT.RU&run 4-112"12.6#L • 80 Hyd.521"plop&drop"liner 1/1,798'. , 10/9/2010 10/10/2010 19,947.0 0.00 10.10_R1UwJ 471/2"..12„6#.1.-80.Uyd..521.':pJ9pAstr.op;'liner.f/1-7.911`..t/6,4.03'..P_U Liner top billet and GS spear.-RIH w/liner on 4"DP f/5,450'1119,700' Release liner.Shoe Top-of-liner-top - -- billet at 14,265'.POOH to 7"shoe.Circ 10.1 ppg MOBM around.POOH 117,309'. -NOTE:AOGCC was notified of upcoming BOP test at 11:00 hrs.AOGCC Rep Lou Grimaldi waived witness of test at 11:30 hrs on 10/09/10. 10/10/2010 10/11/2010 14,210.0 7.90 POOH w/liner running tools f/7 903'U surface.LD tools;,PU 24 jts DP and 4 HWT from shed., Circ pipe volume.POOH stand back same Test BOPE per AOGCC&PXD rules&%regulations • r .t Test upper and lower 2-7/8"X 5"VBR's w/2-7/8"&4.5"test joints to 250 psi low/4500 psi high. Test annular w/2/7/8"&4.5"test joints to 250 psi low/2500 psi high.Test all floor valves and choke manifold to 250 psi low/4500 psi high.All tests charted and all-test held for 5 mina' Perform accumulator draw down test:Right to witness waived by AOGCC Rep.Lou Grimaldi at 11:30 hrs on 10/09/10. Install wear bushing.PU drilling 6-1/8"BHA and RIH t16159'. • • 10/11/2010 10/12/2010 14,210.0 510.00 7.85 RIH f/6,159'1114,062'.Cut&slip drlg line.Service rig.Pull trip nipple.Install ROD.Displace well to 7.8 ppg MOBM.RIH 1114,260'. PU and cut trough/sidetrack 6-1/8"hole f/14,180'1114,210' maintaining 9.8 ppg EMW w/MPD.Control drilling new 6-1/8"hole f/14,210'1114,255'.Directional drill 6-1/8"hole(/14,255'1114,720'maintaining 9.8 ppg EMW w/MPD. 10/12/2010 10/13/2010 14,720.0 2,980.00 8.05 Directional drill 6-1/8"Lateral 1 f/14,720't/17,700'maintaining 10.1 ppg EMW w/MPD. 10/13/2010 10/14/2010 17,700.0 2,437.00 8.00 Directional drill 6-1/8"Lateral 1 f/17,700'1118,306'maintaining 10.1 ppg EMW w/MPD.Circ open hole volume.Change RCD bearing.Directional drill Lateral 1 f/18,306'1120,137'. 10/14/2010 10/15/2010 20,137.0 815.00 8.10 Directional drill lateral 1 f/20,137'U TO at 20,952'.Circ hole:deanCPOOH f/wiper trip 1114,063'(inside 7"shoe).Change Top Drive wash pipe.Change RCD bearing. 10/15/2010 10/16/2010 20,952.0 0.00 8.15 RIH f/14,063'1118,306'.Wash&ream due to 0 down wt f/18,306'1120,952'maintaining 10.2 ppg EMW w/MPD. Circulate hole clean.Spot 6.9 ppg LVT in Lat.1.POOH 1114,062'(inside 7" casing).Pump 25 bbls 10.1 ppg H.V.spacer and chase w/118 bbls 10.1 ppg MOBM.RIH 1114,405'.POOH pumping 2 bpm and spotting H.V.10.1 ppg pill f/14,405'1113,780'.Displace well w/10.1 ppg MOBM f/13,780'U surface. Page 6/7 Report Printed: 11/11/2010 •P I 0NEER aerations Summary Report - Statt. NATURAL BFSOUEOFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 1 0/16/201 0 10/17/2010 20,952.0 0.00 10.10 Complete displacing well w/10.1 ppg MOBM. Pull RCD. Install trip nipple.Circ to confirm KW mud around.Observe well.POOH f/13,780'1/377'.LD BHA.RIH PU 21 jts 4"HWT f/shed. - Circulate pipe vol+.POOH stand back same.RU and run 130 jts 4-1/2"12.6#L-80 HYD 521 liner 1/5,354'. 10/17/2010 10/18/2010 20,952.0 0.00 10.00 Run 4-1/2"12.6#L-80 Hyd.521 liner t/7,124'. RIH w/liner on 4"DP..U14,061'.(7".shoe).Circulate DP volume.Obtain parameters.Continue RIH w/liner on DP 1/20,940'(shoe depth).Drop setting ball and pump down on seat.Pressure to 1500 psi.Set down 20k.Increase pressure in 500 psi increments and observe ball seat shear w/3400 psi.PU to clear setting dogs.Set down to confirm.PU and rotate down w/40 rpm.Set down 75k while rotating and observe shear/set of packer.PU to up wt.Close top rams.Attempt to test liner lap to 3500 psi.No test.Bleed off.PU and set down 75k on liner top.Attempt to pressure up to 3500 psi.No success.Pumping away at 2 bpm,1200 psi.POOH 1 stand 1/13,880'.Dispalce well w/10.0 ppg brine f/13,880'1/surface. Top of Liner @ 13,953'&Liner shoe @ 20,940'. NOTE:Function test BOPE per AOGCC weekly requirements-good test. 10/18/2010 10/19/2010 20,952.0 0.00 10.00 Displace well(/13,880'U surface w/10.0 ppg brine.Cut&slip drilling line.Circ 1/2 BU.POOH LD DP f113,880'U surface.RIH w/70 stands 4"DP f/derrick.CBU 2x to flush pipe.Displace well w/ clean 10.0 ppg brine.POOH LD DP 1/4,728'. 10/19/2010 10/20/2010 20,952.0 0.00 10.00 POOH LDDP(/4,728'U surface.RU and RIH PU 2-7/8"tubing joints V13,450'while waiting on Centrilift personnel&equip. 10/20/2010 10/21/2010 20,952.0 0.00 10.00 POOH standing back 2-7/8",tubing f/13,450'U surface.Flush stack.RU and run ESP completion f/surface 1/1,603' 10/21/2010 10/22/2010 20,952.0 0.00 10.00 RIH w/2-7/8"ESP completion f/1,603'1/10,890'.,,' 10/22/2010 10/23/2010 20,952.0 0.00 10.00 RIH w/2-7/8"6.5#L-80 IBT-M tubing f/10,890'1/11,111'. Make ESP penetration thru Hydrow II pakcer.Test packer vent valve from below to 4000 psi for 10 min-Good test. RIH w/2-7/8"6.5# L-80 IBT-M tubing f/11,111,1/13,708'.Make ESP cable and control line penetrations thru tubing hanger.Meg test ESP cable-Good test.Test control lines to 5000 psi after making penetrations. Land tubing hanger at(/13,708'013,752'. Verify and lock down tubing hanger.Test upper and lower hanger seals to 5000 psi on chart 10 min-Good test. ND BOP stack and drillnq riser., Make SSSV and GVV line penetration and test same to 5000 psi for 10 min,-Good test. Make ESP cable penetrations and meg test same-Good test. NU tree,test void and tree to 5000 psi for 10 min each test on chart-Good test. Remove test plug from tubing hanger.RU lines and reverse out manifold,test lines to 4500 psi for 5 min.Open SSSV with 3500 psi on control line and freeze protect well with 75 bbls diesel by reverse circulate pumping diesel down annulus taking returns thru tubing. 10/23/2010 10/24/2010 20,952.0 0.00 10.00 Freeze protect.well by:pumping,15-bb1S..diesel..doWIlaorW1USai jMlkinp rnturry "ttifii'1.01)41'0_13U lubricator and drop ball bar rod,allow to fall for 30 min.aethydrgAlp,pcker'by pressuring up to 3500 psi in 500 psi increments.Held 3500 psi for 15 min then bleed tubing down to 500 psi. Tested annulus to 2500 psi held 30 min on chart-Good test.Blow down all lines and RD reverse circulating manifold. RU slick line unit. Run#1,Retrieve Ball&Rod from 9,856'wlm. Run#2, Retrieve RHCM Plug Body from 9,874'wlm. Run#3,Drop catcher&Retrieve Dummy 1/GLM at 9,771'wlm.Attempt to set 1/4"OV in GLM#2 at 9,772'wlm-unsuccessful on first 3 runs with same.Modify K.O.T.by removing knuckle joint and RIH with 1/4"O.V.and work to seat same at 6,772'wlm. Rig released on ODSN 17/17L1 0,23:.59 hrs, 10/23/10 Page 7/7 Report Printed: 11/11/2010 1- . . . PIONEER EER Current Schematic - State0 Well Name: ODSN-17 NATURAL RESOURCES HORIZONTAL-Original Hole, 11/17/2010 2:22:23 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20622-00-00/50- 000GURUK DRILLING 20,952.0 F-211 703-20622-60-00 Casing Strings b ti Conductor,158.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Dept... Grade Top Connection Wt/Len(lb/ft) Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 J L_H1-1 Casing Components Top(TVD) Item# Item Des _ Top(ftKB) (ftKB) OD(in) ID(in) Com 1-7 1-1 16"Conductor 47.7 47.7 16 14.670 1-11 y Surface,4,659.8ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept.. Grade Top Connection Wt/Len(lb/ft) Surface 11 3/4 10.772 39.0 4,659.8 3,285.0 L-80 HYD 521 60.00 [1-15 c Casing Components Top(TVD) 1-1911 - (14_1 Item# Item Des Top(ftKB) (ftKB) OD(in) - ID(in) Corn 6 + �4 22 2-7 11 3/4"Surface Shoe 4,658.0 3,284.4 11 3/4 10.772 4E EbbI 4-3 Intermediate 2 Tie back,10,843.9ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) Intermediate 2 7 6.276 37.8 10,843.9 5,320.1 L-80 BTC-M 26.00 J I I2-7I Tie back 1-23 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-27 - 3-8 WFT"SHR"hold down sub 10,817.4 5,311.3 7 6.276 ,1 -3-8I 3-11 WFT Tie back seal 10,824.6 5,313.7 7 6.276 `3-11 I assembly 4 seals 55:12 1 Intermediate,10,978.0ftKB 5-2.111 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) f r 5-3 Intermediate 9 5/8 8.835 4,497.4 10,978.0 5,364.4 L-80 Hyd 521 40.00 Casing Components 1 E I4-11 Top(TVD)tem# tem Des Top(ftKB) (ftKB) _ OD(in) ID(in) Corn 1-31 4-1 Tie Back 4,497.4 3,231.2 9 5/8 8.835 1-32p71 4-2 Packer 4,519.1 3,238.4 9 5/8 8.835 I�, •'�7-2 4-3 Hanger 4,521.3 3,239.1 9 5/8 8.835 7-4 4-11 9-5/8"Drilling Liner Shoe 10,976.3 5,363.8 9 5/8 8.835 Intermediate 2 DrIg Liner,14,106.0ftKB •, I7-7 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) I Intermediate 2 7 6.276 10,835.5 14,106.0 6,186.1 L-80 Hyd 511 26.00 P- 6-1 Drlg Liner Casing Components • I6-4I Top(TVD) 6-7 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn I5-1 PBR Tie Back Sleeve 10,835.5 5,317.3 8 1/4 7.500 1 6-91 5-2 7"x9-5/8"TSP Liner Top 10,856.5 5,324.2 8 3/16 6.250 6-13 Pkr I 6-15 5-3 7"x9-5/8"PHR Rot Hyd Hgr 10,859.3 5,325.2 8 5/16 6.250 1 ,6-18 I .6-20 5-10 7"Casing Shoe 14,106.0 6,186.1 7 6.276 Ray Oil Tool 511 FS 1 .6-22 Production Plop&Drop,19,695.3ftKB 1 .6.24 Description OD(in) ID(in) Top(ftKB) Set Depth(ft_ Set Dept... Grade Top Connection Wt/Len(lb/ft) I .626 Production 4 1/2 3.958 14,265.0 19,695.3 6,360.5 L-80 HYD 521 12.60 628 Plop&Drop II' -6-30 Casing Components Top(TVD) -6 32 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 1 6-34 6-1 6"Aluminum Liner top Billet ` 14,265.0 6,207.8 4 1/2 3.958 I 6-36 l /6-39 6-4 Perforated Pup Joint 14,452.8 6,222.0 41/2 3.958 1 /6-41 1 ,6-43 1 .6-45 1 .6-47 1 .6-49 1 -6-51 1 1 -6-53 I 1 -6-55 I I _6-57 1 6-59 Page 1/3 Report Printed: 11/17/2010 PIONEERCurrent Schematic - State Well Name: ODSN-17 NATURAL RESOURCES HORIZONTAL-Original Hole, 11/17/2010 2:22:25 PM Casing Components Vertical schematic(actual) Top(TVD) Item# Item Des Top(ftKB) (ftK6) OD On) ID(In) Corn 17 'w- 6-7 Resman Tracer ROS- 14,665.3 6,235.3 41/2 3.958 132/RWS-145 T1 if 6-9 Perforated Pup Joint 14,756.0 6,240.4 4 1/2 3.958 6-11 Perforated Pup Joint 14,958.4 6,256.8 4 1/2 3.958 I 6-13 Perforated Pup Joint 15,166.5 6,266.3 4 1/2 3.958 k1-11 6-15 Perforated Pup Joint 15,373.7 6,260.4 4 1/2 3.958 [1-7 6-18 Resman Tracer#ROS- 15,543.4 6,247.8 41/2 3.958 129/RWS-142 1-11 6-20 Perforated Pup Joint 15,794.7 6,229.8 4 1/2 3.958 1 6-22 Perforated Pup Joint 15,996.2 6,235.3 4 1/2 3.958 1-151 a 6-24 Perforated Pup Joint 16,203.3 6,253.0 4 1/2 3.958 6-26 Perforated Pup Joint 16,408.8 6,273.2 4 1/2 3.958 1-19� 4-1 6-28 Perforated Pup Joint 16,613.5 6,288.0 4 1/2 3.958 6 4-2 6-30 Perforated Pup Joint 16,820.2 6,298.2 4 1/2 3.958 B - 4-3 6-32 Perforated Pup Joint 17,027.3 6,310.9 4 1/2 3.958 I 6-34 Perforated Pup Joint 17,227.3 6,307.6 4 1/2 3.958 L J 12-7 6-36 Perforated Pup Joint 17,434.1 6,293.4 4 1/2 3.958 1-231 6-39 Resman tracer#ROS- 17,642.5 6,276.7 4 1/2 3.958 127/RWS-140 11-27 i 6-41 Perforated Pup Joint 17,853.5 6,260.0 4 1/2 3.958 6-43 Perforated Pup Joint 18,057.6 6,248.9 4 1/2 3.958 11 3-8 6-45 Perforated Pup Joint 18,262.6 6,255.7 4 1/2 3.958 il Mil 6-47 Perforated Pup Joint 18,468.4 6,270.9 4 1/2 3.958 18,670.2 6,288.6 4 1/2 3.958 18,875.6 6,300.0 4 1/2 3.958 19,078.4 6,311.2 4 1/2 3.958 ® 5-2 6-49 Perforated Pup Joint 6-51 Perforated Pup Joint 5-3 (4-11 6-53 Perforated Pup Joint 6-55 Perforated Pup Joint 19,280.0 6,327.9 4 1/2 3.958 1-31 6-57 Perforated Pup Joint 19,486.3 6,345.6 4 1/2 3.958 1-326-59 Perforated Pup Joint 19,689.4 6,360.1 4 1/2 3.958 . 7 7-1 6-60 Float Shoe 19,694.1 6,360.4 7-2 ii 7-4 Production Lateral 1,20,940.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Dept... Grade Top Connection Wt/Len(Ib/ft) Production 4 1/2 3.958 13,953.3 20,940.0 L-80 HYD 521 12.60 •--117-7 Lateral 1 1 Casing Components 116-1 Item# Item Des Top(ftK6) Top(TV(ftKB)D) OD(in) ID(in) Com • 6-41 7-1 Tieback receptacle w/ 13,953.3 4 1/2' 3.958 6-7 polished bore I 6-9 7-2 NTH Liner Top packer 13,968.7 4 1/2 3.958 ( ' 6-11 7-4 PHR Liner Hanger 13,972.1 4 1/2 3.958 6-13 7-7 Perforated Pup Joint 14,058.7 4 1/2 3.958 I 6-15 7-10 Weatherford Sliding Sleeve 14,269.1 6,211.3 4 1/2 3.958 1 /6-18 I .6-20 7-11 Perforated Pup Joint 14,274.2 6,212.0 4 1/2 3.958 .6-22 7-14 Weatherford Oil Swell 14,363.8 6,219.0 4 1/2 3.958 1 .6-24 Packer 1 .6-26 I -6-28 7-17 Perforated Pup Joint 14,543.5 6,219.0 4 1/2 3.958 1• 7-20 Resman tracer#ROS- 14,709.5 6,219.0 4 1/2 3.958 .6-3� 141/RWS-151 L 6-34 7-23 Perforated Pup Joint 14,762.2 6,218.1 4 1/2 3.958 I 6-36 7-25 Perforated Pup Joint 14,966.5 6,212.8 4 1/2 3.958 1 -39 7-27 Perforated Pup Joint 15,173.5 6,213.1 4 1/2 3.958 I 1 ,6-41 7-29 Perforated Pup Joint 15,376.2 6,220.5 41/2 3.958 1 /6-43 7-31 Perforated Pup Joint 15,580.9 6,223.8 41/2 3.958 L .6-45 1 .6-47 L .6-49 L -6-51 1 -6-53 1 -6-55 t -6-57 16-59 Page 2/3 Report Printed: 11/17/2010 P t 0 N E E R Current Schematic - State Well Name: ODSN-17 • . NATURAL RESOURCES HORIZONTAL-Original Hole, 11/17/2010 2:22:26 PM Casing Components Vertical schematic(actual) Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-2 -..0.... 7-33 Perforated Pup Joint 15,781.9 6,219.7 4 1/2 3.958 7-35 Perforated Pup Joint 15,987.8 6,217.3 4 1/2 3.958 11 7-37 Resman tracer#ROS- 15,995.2 6,217.2 4 1/2 3.958 143/RWS-153 7-40 Perforated Pup Joint 16,210.3 6,218.6 4 1/2 3.958 JL-11-1I 7-42 Perforated Pup Joint 16,415.2 6,227.6 4 1/2 3.958 11-7 7-44 Perforated Pup Joint 16,618.9 6,236.5 4 1/2 3.958 I7-46 Perforated Pup Joint 16,823.7 6,244.0 4 1/2 3.958 Il-ill 7-48 Perforated Pup Joint 17,028.6 6,244.5 4 1/2 3.958 7-50 Perforated Pup Joint 17,236.4 6,235.1 4 1/2 3.958 11-15 7-52 Perforated Pup Joint 17,442.0 6,231.1 4 1/2 3.958 7-54 Perforated Pup Joint 17,647.0 6,228.3 4 1/2 3.958 11-191 75 4 1 7-56 Perforated Pup Joint 17,850.9 6,243.6 4 1/2 3.958 p _ 4-2 7-58 Perforated Pup Joint 18,053.2 6,254.2 4 1/2 3.958 4-3 7-61 Resman tracer#ROS- 18,182.4 6,254.9 4 1/2 3.958 144/RWS-154 J 2-7I 7-64 Perforated Pup Joint 18,274.8 6,251.8 4 1/2 3.958 11-23 7-66 Perforated Pup Joint 18,479.7 6,240.1 4 1/2 3.958 1 7-68 Perforated Pup Joint 18,683.3 6,235.2 4 1/2 3.958 1-27 7-70 Perforated Pup Joint 18,885.6 6,243.8 4 1/2 3.958 7-72 Perforated Pup Joint 19,089.9 6,254.6 4 1/2 3.958 1 r ili 3-8 7-74 Perforated Pup Joint 19,296.7 6,265.7 4 1/2 3.958 7-76 Perforated Pup Joint 19,501.2 6,262.4 4 1/2 3.958 ��® 7-78 Perforated Pup Joint 19,702.2 6,258.4 4 1/2 3.958 5-3 7-80 Perforated Pup Joint 19,907.5 6,255.8 4 1/2 3.958 7-82 Perforated Pup Joint 20,114.5 6,246.8 4 1/2 3.958 1 1 14-11 7-84 Perforated Pup Joint 20,321.0 6,256.2 4 1/2 3.958 1-31 7-86 Perforated Pup Joint 20,524.6 6,270.4 4 1/2 3.958 1-32 .-. 7-1 7-88 Perforated Pup Joint 20,728.8 6,278.6 4 1/2 3.958 Hf--2 7-90 Perforated Pup Joint 20,893.6 6,287.6 4 1/2 3.958 7-4 7-92 Weatherford Solid Shoe 20,938.7 Tubing Strings Tubing Description String M.. ID(in) Top(ftKB) Set Depth(f_. Set Dept... Wt(Ib/ft) Grade Top Thread • 7-71 Tubing-Production 2 7/8 2.441 35.0 13,752.6 6,122.0 6.50 L-80 IBT-M Tubing Components 1 6-1Top(ND) I6• -4 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-2 Vetco Tubing Hgr 35.0 35.0 11 2.992 6-7 1-7 Wellstar TRScSSSV 2,007.2 1,960.5 2 7/8 2.441 I 6-9 i 6-11 1-11 1 1/2"x 2 7/8"Gas Lift 2,403.2 2,296.3 2 7/8 2.441 Mandrel#1 6-13 I 6-15 1-15 X-Nipple w/2.313"ID 2,519.4 2,385.1 2 7/8 2.441 1 .6-18 1-19 Weatherford Hydrow II 2,633.2 2,465.8 2 7/8 2.441 1 .6-20 Packer 1 .622 1-23 1 1/2"x 2 7/8"Gas Lift 9,756.4 4,964.7 2 7/8 2.441 1 .6-24 Mandrel#2 w/dummy 1 .6-26 1-27 2.313"X-Nipple w/RHC-M 9,868.4 5,001.2 2 7/8 2.313 1 -6-28 plug 1 -6-30 1-31 ADV assembly 13,682.7 6,108.2 2 7/8 0.000 I. -6-32 1-32 ESP-Pump Assembly 13,692.0 6,110.1 2 7/8 0.000 1 6-34 1 6-36 1 /6-39 1 /6-41 I /6-43 1 .6-45 1 .6-47 1 .6-49 I 1 -6-51 1 -6-53 I . -6-55 r -6-57 ,6-59 Page 3/3 Report Printed: 11/17/2010 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.00 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +EI-W 0.00 ft Easting: 469,826.11 ft Longitude: 150°14'48.230 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-17 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 PN13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 206.29 I Survey Program Date 10/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,105.00 ODSN-17 Gyro(ODSN-17) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 8/26/2010 1: 1,154.91 4,612.64 ODSN-17 MWD 1 (ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8/27/2010 1: 1 4,710.05 10,949.10 ODSN-17 MWD 2(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/7/2010 12: I 11,042.53 14,070.86 ODSN-17 MWD 3(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/21/2010 1: 14,156.32 19,909.97 ODSN-17 MWD 4(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/4/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,056.25 469,826.11 0.00 0.00 UNDEFINED 100.00 0.35 5.53 100.00 43.80 0.18 0.02 6,031,056.43 469,826.13 0.61 -0.16 SR-Gyro-SS(1) 172.00 0.78 357.31 172.00 115.80 0.88 0.01 6,031,057.13 469,826.13 0.61 -0.80 SR-Gyro-SS(1) 218.00 0.77 11.51 217.99 161.79 1.50 0.06 6,031,057.75 469,826.18 0.42 -1.37 SR-Gyro-SS(1) 264.00 0.67 32.05 263.99 207.79 2.03 0.27 6,031,058.28 469,826.38 0.60 -1.94 SR-Gyro-SS(1) 310.00 0.51 59.03 309.99 253.79 2.36 0.58 6,031,058.61 469,826.70 0.69 -2.38 SR-Gyro-SS(1) 356.00 1.45 98.70 355.98 299.78 2.38 1.33 6,031,058.63 469,827.45 2.41 -2.73 SR-Gyro-SS(1) 399.00 1.30 100.16 398.97 342.77 2.21 2.35 6,031,058.45 469,828.47 0.36 -3.03 SR-Gyro-SS(1) 445.00 1.49 102.67 444.95 388.75 1.99 3.45 6,031,058.23 469,829.57 0.43 -3.31 SR-Gyro-SS(1) 493.00 1.12 103.85 492.94 436.74 1.74 4.51 6,031,057.97 469,830.63 0.77 -3.56 SR-Gyro-SS(1) 10/20/2010 10:42:51AM Page 2 COMPASS 2003.16 Build 42F . Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 539.00 0.59 88.47 538.94 482.74 1.64 5.19 6,031,057.87 469,831.30 1.25 -3.77 SR-Gyro-SS(1) 585.00 0.57 339.47 584.93 528.73 1.86 5.34 6,031,058.09 469,831.46 2.05 -4.03 SR-Gyro-SS(1) 631.00 2.15 303.65 630.92 574.72 2.55 4.54 6,031,058.78 469,830.66 3.74 -4.30 SR-Gyro-SS(1) 679.00 2.89 299.16 678.87 622.67 3.64 2.74 6,031,059.88 469,828.86 1.59 -4.48 SR-Gyro-SS(1) 725.00 4.49 297.38 724.78 668.58 5.03 0.13 6,031,061.28 469,826.26 3.49 -4.57 SR-Gyro-SS(1) 775.00 5.09 297.86 774.60 718.40 6.97 -3.57 6,031,063.23 469,822.57 1.20 -4.67 SR-Gyro-SS(1) 821.00 6.25 296.89 820.38 764.18 9.06 -7.61 6,031,065.34 469,818.54 2.53 -4.75 SR-Gyro-SS(1) 870.00 6.52 296.43 869.07 812.87 11.50 -12.48 6,031,067.80 469,813.68 0.56 -4.78 SR-Gyro-SS(1) 916.00 6.47 297.18 914.78 858.58 13.85 -17.12 6,031,070.17 469,809.04 0.21 -4.83 SR-Gyro-SS(1) 964.00 6.72 300.83 962.46 906.26 16.52 -21.94 6,031,072.86 469,804.24 1.02 -5.09 SR-Gyro-SS(1) 1,010.00 7.59 303.62 1,008.10 951.90 19.58 -26.78 6,031,075.94 469,799.41 2.04 -5.69 SR-Gyro-SS(1) 1,059.00 8.84 304.73 1,056.60 1,000.40 23.52 -32.57 6,031,079.90 469,793.64 2.57 -6.66 SR-Gyro-SS(1) 1,105.00 10.33 306.26 1,101.95 1,045.75 27.97 -38.80 6,031,084.38 469,787.43 3.29 -7.89 SR-Gyro-SS(1) 1,154.91 10.97 306.14 1,151.00 1,094.80 33.42 -46.25 6,031,089.85 469,780.01 1.28 -9.48 MWD+IFR2+MS+sag(2) 1,249.75 12.79 310.01 1,243.81 1,187.61 45.49 -61.57 6,031,101.99 469,764.73 2.09 -13.51 MWD+IFR2+MS+sag(2) 1,345.36 14.25 306.47 1,336.77 1,280.57 59.29 -79.14 6,031,115.86 469,747.21 1.75 -18.10 MWD+IFR2+MS+sag(2) 1,441.50 16.46 305.59 1,429.47 1,373.27 74.25 -99.74 6,031,130.90 469,726.68 2.31 -22.39 MWD+IFR2+MS+sag(2) 1,535.55 17.50 301.22 1,519.42 1,463.22 89.34 -122.67 6,031,146.08 469,703.82 1.75 -25.76 MWD+IFR2+MS+sag(2) 1,630.45 18.59 302.17 1,609.66 1,553.46 104.79 -147.68 6,031,161.63 469,678.88 1.19 -28.53 MWD+IFR2+MS+sag(2) 1,696.70 18.80 298.73 1,672.41 1,616.21 115.54 -165.98 6,031,172.46 469,660.62 1.69 -30.07 MWD+IFR2+MS+sag(2) I 1,757.05 18.77 298.18 1,729.55 1,673.35 124.80 -183.06 6,031,181.78 469,643.57 0.30 -30.80 MWD+IFR2+MS+sag(2) 1,852.52 20.92 295.54 1,819.34 1,763.14 139.41 -211.98 6,031,196.50 469,614.71 2.44 -31.09 MWD+IFR2+MS+sag(2) 1,947.56 25.06 292.03 1,906.82 1,850.62 154.28 -245.97 6,031,211.51 469,580.79 4.59 -29.37 MWD+IFR2+MS+sag(2) 2,042.11 27.21 292.05 1,991.70 1,935.50 169.91 -284.57 6,031,227.29 469,542.26 2.27 -26.28 MWD+IFR2+MS+sag(2) 2,137.05 30.84 291.63 2,074.70 2,018.50 187.03 -327.32 6,031,244.59 469,499.58 3.83 -22.69 MWD+IFR2+MS+sag(2) 2,232.35 31.42 292.38 2,156.28 2,100.08 205.50 -373.00 6,031,263.24 469,453.98 0.73 -19.01 MWD+IFR2+MS+sag(2) 2,327.45 35.63 292.98 2,235.54 2,179.34 225.76 -421.45 6,031,283.69 469,405.63 4.44 -15.72 MWD+IFR2+MS+sag(2) 2,422.51 38.40 290.54 2,311.44 2,255.24 246.93 -474.60 6,031,305.08 469,352.57 3.30 -11.16 MWD+IFR2+MS+sag(2) 2,517.34 42.48 288.71 2,383.60 2,327.40 267.55 -532.53 6,031,325.93 469,294.72 4.48 -3.98 MWD+IFR2+MS+sag(2) 2,613.42 46.37 284.64 2,452.22 2,396.02 286.75 -596.94 6,031,345.39 469,230.40 5.02 7.33 MWD+IFR2+MS+sag(2) 2,708.38 48.97 279.31 2,516.18 2,459.98 301.24 -665.58 6,031,360.16 469,161.83 4.97 24.74 MWD+IFR2+MS+sag(2) 2,803.28 51.29 273.38 2,577.05 2,520.85 309.22 -737.91 6,031,368.43 469,089.54 5.38 49.63 MWD+IFR2+MS+sag(2) 2,899.43 54.08 268.08 2,635.35 2,579.15 310.13 -814.32 6,031,369.65 469,013.14 5.26 82.66 MWD+IFR2+MS+sag(2) 2,994.43 56.77 265.45 2,689.27 2,633.07 305.69 -892.40 6,031,365.52 468,935.05 3.63 121.23 MWD+IFR2+MS+sag(2) 3,090.16 59.62 263.56 2,739.72 2,683.52 297.88 -973.36 6,031,358.04 468,854.06 3.42 164.10 MWD+IFR2+MS+sag(2) 3,185.33 63.02 262.45 2,785.39 2,729.19 287.70 -1,056.22 6,031,348.20 468,771.17 3.72 209.92 MWD+IFR2+MS+sag(2) 3,279.10 65.81 261.16 2,825.88 2,769.68 275.63 -1,139.92 6,031,336.48 468,687.44 3.22 257.82 MWD+IFR2+MS+sag(2) 3,374.77 70.37 260.38 2,861.57 2,805.37 261.39 -1,227.50 6,031,322.59 468,599.80 4.83 309.38 MWD+IFR2+MS+sag(2) 3,469.87 72.08 259.20 2,892.18 2,835.98 245.42 -1,316.11 6,031,306.99 468,511.14 2.15 362.94 MWD+IFR2+MS+sag(2) 3,565.72 70.73 257.02 2,922.74 2,866.54 226.72 -1,405.00 6,031,288.64 468,422.18 2.57 419.09 MWD+IFR2+MS+sag(2) 10/20/2010 10:42:51AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,661.41 70.08 255.90 2,954.84 2,898.64 205.61 -1,492.64 6,031,267.90 468,334.47 1.30 476.83 MWD+IFR2+MS+sag(2) 3,756.32 70.91 255.84 2,986.52 2,930.32 183.77 -1,579.40 6,031,246.41 468,247.63 0.88 534.84 MWD+IFR2+MS+sag(2) 3,851.14 71.00 256.41 3,017.47 2,961.27 162.28 -1,666.41 6,031,225.27 468,160.54 0.58 592.65 MWD+IFR2+MS+sag(2) 3,945.82 70.58 256.69 3,048.62 2,992.42 141.48 -1,753.37 6,031,204.83 468,073.51 0.52 649.82 MWD+IFR2+MS+sag(2) 4,041.02 71.21 257.51 3,079.78 3,023.58 121.40 -1,841.05 6,031,185.11 467,985.75 1.05 706.66 MWD+IFR2+MS+sag(2) 4,136.12 71.00 258.58 3,110.57 3,054.37 102.76 -1,929.07 6,031,166.83 467,897.66 1.09 762.36 MWD+IFR2+MS+sag(2) 4,231.28 70.01 259.27 3,142.33 3,086.13 85.53 -2,017.11 6,031,149.96 467,809.57 1.24 816.80 MWD+IFR2+MS+sag(2) 4,326.25 70.46 258.64 3,174.45 3,118.25 68.41 -2,104.83 6,031,133.19 467,721.79 0.78 871.01 MWD+IFR2+MS+sag(2) 4,421.27 70.63 258.51 3,206.10 3,149.90 50.66 -2,192.64 6,031,115.80 467,633.91 0.22 925.82 MWD+IFR2+MS+sag(2) 4,516.95 70.67 258.35 3,237.80 3,181.60 32.55 -2,281.09 6,031,098.06 467,545.41 0.16 981.23 MWD+IFR2+MS+sag(2) 4,612.64 70.46 259.48 3,269.64 3,213.44 15.20 -2,369.64 6,031,081.07 467,456.79 1.14 1,036.01 MWD+IFR2+MS+sag(2) 4,710.05 71.86 259.82 3,301.09 3,244.89 -1.36 -2,460.33 6,031,064.88 467,366.05 1.47 1,091.03 MWD+IFR2+MS+sag(3) 4,803.06 71.54 259.66 3,330.30 3,274.10 -17.09 -2,547.22 6,031,049.50 467,279.10 0.38 1,143.62 MWD+IFR2+MS+sag(3) 4,898.59 71.16 259.30 3,360.85 3,304.65 -33.61 -2,636.21 6,031,033.34 467,190.05 0.53 1,197.85 MWD+IFR2+MS+sag(3) 4,994.01 70.97 259.96 3,391.81 3,335.61 -49.86 -2,724.99 6,031,017.46 467,101.21 0.68 1,251.75 MWD+IFR2+MS+sag(3) 5,088.97 70.57 259.98 3,423.09 3,366.89 -65.47 -2,813.29 6,031,002.20 467,012.87 0.42 1,304.86 MWD+IFR2+MS+sag(3) I 5,186.08 70.17 260.76 3,455.71 3,399.51 -80.78 -2,903.46 6,030,987.27 466,922.64 0.86 1,358.52 MWD+IFR2+MS+sag(3) 5,278.62 70.69 260.22 3,486.71 3,430.51 -95.18 -2,989.46 6,030,973.21 466,836.59 0.79 1,409.53 MWD+IFR2+MS+sag(3) 5,376.29 71.16 259.12 3,518.63 3,462.43 -111.74 -3,080.26 6,030,957.03 466,745.73 1.17 1,464.59 MWD+IFR2+MS+sag(3) 5,469.55 70.84 256.79 3,548.99 3,492.79 -130.13 -3,166.50 6,030,938.98 466,659.43 2.39 1,519.28 MWD+IFR2+MS+sag(3) 5,564.83 70.64 255.55 3,580.42 3,524.22 -151.63 -3,253.83 6,030,917.84 466,572.02 1.25 1,577.24 MWD+IFR2+MS+sag(3) 5,659.60 70.97 254.92 3,611.58 3,555.38 -174.44 -3,340.38 6,030,895.38 466,485.39 0.72 1,636.03 MWD+IFR2+MS+sag(3) I 5,754.46 70.75 254.41 3,642.69 3,586.49 -198.14 -3,426.80 6,030,872.04 466,398.88 0.56 1,695.56 MWD+IFR2+MS+sag(3) 5,848.47 70.70 254.77 3,673.72 3,617.52 -221.72 -3,512.35 6,030,848.81 466,313.24 0.37 1,754.60 MWD+IFR2+MS+sag(3) 5,943.87 70.12 255.24 3,705.71 3,649.51 -244.98 -3,599.17 6,030,825.91 466,226.34 0.76 1,813.90 MWD+IFR2+MS+sag(3) 6,040.89 70.30 255.87 3,738.55 3,682.35 -267.75 -3,687.57 6,030,803.50 466,137.85 0.64 1,873.47 MWD+IFR2+MS+sag(3) 6,135.45 70.37 257.19 3,770.38 3,714.18 -288.49 -3,774.17 6,030,783.11 466,051.18 1.32 1,930.43 MWD+IFR2+MS+sag(3) 6,231.22 70.89 258.90 3,802.14 3,745.94 -307.20 -3,862.55 6,030,764.76 465,962.73 1.77 1,986.35 MWD+IFR2+MS+sag(3) 6,325.15 71.08 260.28 3,832.75 3,776.55 -323.25 -3,949.89 6,030,749.07 465,875.34 1.40 2,039.43 MWD+IFR2+MS+sag(3) 6,421.02 70.77 260.20 3,864.08 3,807.88 -338.61 -4,039.19 6,030,734.07 465,785.99 0.33 2,092.75 MWD+IFR2+MS+sag(3) 6,516.19 70.75 260.29 3,895.44 3,839.24 -353.83 -4,127.74 6,030,719.21 465,697.38 0.09 2,145.63 MWD+IFR2+MS+sag(3) 6,613.33 70.35 260.71 3,927.79 3,871.59 -368.95 -4,218.08 6,030,704.46 465,606.99 0.58 2,199.20 MWD+IFR2+MS+sag(3) 6,706.26 70.37 261.96 3,959.02 3,902.82 -382.14 -4,304.60 6,030,691.63 465,520.42 1.27 2,249.34 MWD+IFR2+MS+sag(3) 6,800.98 70.63 260.84 3,990.64 3,934.44 -395.49 -4,392.89 6,030,678.63 465,432.10 1.15 2,300.42 MWD+IFR2+MS+sag(3) 6,896.38 70.76 261.31 4,022.18 3,965.98 -409.46 -4,481.83 6,030,665.03 465,343.11 0.48 2,352.34 MWD+IFR2+MS+sag(3) 6,992.18 70.91 260.31 4,053.63 3,997.43 -423.91 -4,571.16 6,030,650.94 465,253.73 1.00 2,404.86 MWD+IFR2+MS+sag(3) 7,088.03 71.15 259.90 4,084.79 4,028.59 -439.49 -4,660.45 6,030,635.73 465,164.38 0.48 2,458.38 MWD+IFR2+MS+sag(3) 7,182.18 71.35 259.30 4,115.05 4,058.85 -455.58 -4,748.14 6,030,619.99 465,076.64 0.64 2,511.65 MWD+IFR2+MS+sag(3) 7,277.41 71.34 257.39 4,145.52 4,089.32 -473.81 -4,836.50 6,030,602.13 464,988.21 1.90 2,567.14 MWD+IFR2+MS+sag(3) 7,372.56 70.96 257.20 4,176.26 4,120.06 -493.61 -4,924.35 6,030,582.68 464,900.30 0.44 2,623.80 MWD+IFR2+MS+sag(3) 10/20/2010 10:42:51AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,468.27 70.82 257.82 4,207.59 4,151.39 -513.17 -5,012.64 6,030,563.48 464,811.93 0.63 2,680.45 MWD+IFR2+MS+sag(3) 7,563.47 70.03 257.84 4,239.49 4,183.29 -532.08 -5,100.32 6,030,544.93 464,724.19 0.83 2,736.24 MWD+IFR2+MS+sag(3) 7,658.61 70.36 258.45 4,271.72 4,215.52 -550.47 -5,187.92 6,030,526.90 464,636.52 0.70 2,791.53 MWD+IFR2+MS+sag(3) 7,754.46 70.37 258.66 4,303.93 4,247.73 -568.38 -5,276.41 6,030,509.35 464,547.97 0.21 2,846.78 MWD+IFR2+MS+sag(3) 7,848.82 70.25 259.03 4,335.72 4,279.52 -585.57 -5,363.57 6,030,492.52 464,460.75 0.39 2,900.80 MWD+IFR2+MS+sag(3) 7,945.27 70.68 259.62 4,367.98 4,311.78 -602.41 -5,452.89 6,030,476.04 464,371.37 0.73 2,955.46 MWD+IFR2+MS+sag(3) I 8,038.91 70.82 259.69 4,398.85 4,342.65 -618.28 -5,539.86 6,030,460.52 464,284.34 0.17 3,008.22 MWD+IFR2+MS+sag(3) 8,134.96 70.96 260.58 4,430.29 4,374.09 -633.83 -5,629.28 6,030,445.34 464,194.88 0.89 3,061.76 MWD+IFR2+MS+sag(3) 8,230.17 71.28 260.76 4,461.10 4,404.90 -648.43 -5,718.17 6,030,431.10 464,105.93 0.38 3,114.23 MWD+IFR2+MS+sag(3) 8,324.98 71.15 260.58 4,491.63 4,435.43 -662.99 -5,806.74 6,030,416.91 464,017.31 0.23 3,166.51 MWD+IFR2+MS+sag(3) 8,420.04 70.82 260.48 4,522.60 4,466.40 -677.77 -5,895.39 6,030,402.48 463,928.61 0.36 3,219.04 MWD+IFR2+MS+sag(3) 8,515.53 70.29 260.55 4,554.39 4,498.19 -692.61 -5,984.20 6,030,388.00 463,839.75 0.56 3,271.68 MWD+IFR2+MS+sag(3) 8,609.58 70.82 260.71 4,585.70 4,529.50 -707.05 -6,071.71 6,030,373.92 463,752.20 0.59 3,323.39 MWD+IFR2+MS+sag(3) 8,705.65 71.28 260.48 4,616.90 4,560.70 -721.90 -6,161.35 6,030,359.44 463,662.51 0.53 3,376.40 MWD+IFR2+MS+sag(3) 8,801.16 71.66 259.31 4,647.26 4,591.06 -737.79 -6,250.50 6,030,343.91 463,573.30 1.23 3,430.14 MWD+IFR2+MS+sag(3) 8,896.34 70.45 258.87 4,678.16 4,621.96 -754.82 -6,338.89 6,030,327.24 463,484.84 1.34 3,484.57 MWD+IFR2+MS+sag(3) 8,991.27 70.09 258.28 4,710.20 4,654.00 -772.52 -6,426.48 6,030,309.89 463,397.20 0.70 3,539.23 MWD+IFR2+MS+sag(3) 9,086.77 70.30 258.61 4,742.56 4,686.36 -790.52 -6,514.51 6,030,292.26 463,309.10 0.39 3,594.36 MWD+IFR2+MS+sag(3) 9,182.69 70.49 258.53 4,774.75 4,718.55 -808.43 -6,603.08 6,030,274.71 463,220.47 0.21 3,649.65 MWD+IFR2+MS+sag(3) 9,277.16 70.87 258.94 4,806.00 4,749.80 -825.84 -6,690.51 6,030,257.65 463,132.98 0.57 3,703.99 MWD+IFR2+MS+sag(3) 9,372.89 69.98 259.04 4,838.07 4,781.87 -843.07 -6,779.05 6,030,240.79 463,044.38 0.93 3,758.65 MWD+IFR2+MS+sag(3) 9,467.20 70.36 259.56 4,870.07 4,813.87 -859.54 -6,866.22 6,030,224.67 462,957.15 0.66 3,812.03 MWD+IFR2+MS+sag(3) 9,563.91 71.00 259.30 4,902.06 4,845.86 -876.28 -6,955.93 6,030,208.30 462,867.38 0.71 3,866.78 MWD+IFR2+MS+sag(3) 9,659.05 71.01 258.16 4,933.03 4,876.83 -893.86 -7,044.16 6,030,191.08 462,779.09 1.13 3,921.62 MWD+IFR2+MS+sag(3) 9,752.68 70.89 257.04 4,963.59 4,907.39 -912.87 -7,130.59 6,030,172.43 462,692.59 1.14 3,976.95 MWD+IFR2+MS+sag(3) 9,849.04 71.03 257.88 4,995.03 4,938.83 -932.64 -7,219.51 6,030,153.01 462,603.60 0.84 4,034.06 MWD+IFR2+MS+sag(3) 9,943.96 71.22 258.20 5,025.73 4,969.53 -951.25 -7,307.37 6,030,134.76 462,515.67 0.38 4,089.67 MWD+IFR2+MS+sag(3) 10,039.79 70.31 256.57 5,057.31 5,001.11 -971.01 -7,395.67 6,030,115.36 462,427.31 1.87 4,146.49 MWD+IFR2+MS+sag(3) 10,134.14 71.07 253.76 5,088.51 5,032.31 -993.81 -7,481.73 6,030,092.91 462,341.16 2.92 4,205.05 MWD+IFR2+MS+sag(3) 10,229.16 71.22 250.69 5,119.23 5,063.03 -1,021.26 -7,567.34 6,030,065.82 462,255.45 3.06 4,267.59 MWD+IFR2+MS+sag(3) 10,324.49 71.07 247.66 5,150.04 5,093.84 -1,053.33 -7,651.65 6,030,034.10 462,171.02 3.01 4,333.68 MWD+IFR2+MS+sag(3) 10,419.51 70.82 244.06 5,181.07 5,124.87 -1,090.05 -7,733.60 6,029,997.71 462,088.93 3.59 4,402.90 MWD+IFR2+MS+sag(3) 10,508.96 70.45 240.96 5,210.74 5,154.54 -1,128.99 -7,808.45 6,029,959.07 462,013.93 3.30 4,470.97 MWD+IFR2+MS+sag(3) 10,610.40 70.69 236.81 5,244.49 5,188.29 -1,178.42 -7,890.32 6,029,909.99 461,931.86 3.87 4,551.55 MWD+IFR2+MS+sag(3) 10,705.79 71.54 232.94 5,275.38 5,219.18 -1,230.34 -7,964.12 6,029,858.37 461,857.86 3.94 4,630.79 MWD+IFR2+MS+sag(3) 10,800.97 70.83 229.60 5,306.08 5,249.88 -1,286.69 -8,034.40 6,029,802.31 461,787.37 3.40 4,712.44 MWD+IFR2+MS+sag(3) 10,895.62 70.57 224.59 5,337.39 5,281.19 -1,347.48 -8,099.81 6,029,741.79 461,721.72 5.00 4,795.92 MWD+IFR2+MS+sag(3) 10,949.10 70.78 223.14 5,355.08 5,298.88 -1,383.87 -8,134.78 6,029,705.55 461,686.61 2.59 4,844.03 MWD+IFR2+MS+sag(3) 11,042.53 71.73 222.09 5,385.11 5,328.91 -1,448.98 -8,194.68 6,029,640.69 461,626.45 1.47 4,928.93 MWD+IFR2+MS+sag(4) 11,088.41 71.75 221.46 5,399.48 5,343.28 -1,481.47 -8,223.70 6,029,608.32 461,597.29 1.30 4,970.92 MWD+IFR2+MS+sag(4) 10/20/2010 10:42:51AM Page 5 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 11,183.91 70.74 219.27 5,430.19 5,373.99 -1,550.36 -8,282.27 6,029,539.67 461,538.45 2.42 5,058.63 MWD+IFR2+MS+sag(4) 11,279.14 71.02 215.72 5,461.39 5,405.19 -1,621.74 -8,337.02 6,029,468.53 461,483.41 3.53 5,146.87 MWD+IFR2+MS+sag(4) 11,373.84 71.41 212.82 5,491.89 5,435.69 -1,695.82 -8,387.50 6,029,394.66 461,432.64 2.93 5,235.65 MWD+IFR2+MS+sag(4) 11,469.31 71.08 209.09 5,522.60 5,466.40 -1,773.33 -8,433.99 6,029,317.35 461,385.84 3.72 5,325.73 MWD+IFR2+MS+sag(4) 11,565.32 70.57 205.46 5,554.14 5,497.94 -1,853.91 -8,475.54 6,029,236.94 461,343.97 3.61 5,416.38 MWD+IFR2+MS+sag(4) 11,660.83 72.20 201.49 5,584.64 5,528.44 -1,936.91 -8,511.57 6,029,154.10 461,307.60 4.29 5,506.76 MWD+IFR2+MS+sag(4) 11,755.15 72.84 198.69 5,612.98 5,556.78 -2,021.39 -8,542.47 6,029,069.75 461,276.37 2.91 5,596.19 MWD+IFR2+MS+sag(4) 11,850.51 73.61 195.85 5,640.51 5,584.31 -2,108.57 -8,569.57 6,028,982.69 461,248.92 2.96 5,686.35 MWD+IFR2+MS+sag(4) 11,946.56 73.95 192.22 5,667.34 5,611.14 -2,198.03 -8,591.93 6,028,893.34 461,226.20 3.65 5,776.45 MWD+IFR2+MS+sag(4) 12,042.13 73.74 188.24 5,693.94 5,637.74 -2,288.34 -8,608.23 6,028,803.10 461,209.53 4.01 5,864.65 MWD+IFR2+MS+sag(4) 12,136.56 73.79 184.72 5,720.35 5,664.15 -2,378.41 -8,618.46 6,028,713.08 461,198.94 3.58 5,949.93 MWD+IFR2+MS+sag(4) 12,231.94 74.12 183.17 5,746.72 5,690.52 -2,469.86 -8,624.76 6,028,621.67 461,192.26 1.60 6,034.71 MWD+IFR2+MS+sag(4) 12,326.15 73.47 181.03 5,773.01 5,716.81 -2,560.26 -8,628.08 6,028,531.29 461,188.58 2.29 6,117.22 MWD+IFR2+MS+sag(4) 12,421.45 73.28 179.34 5,800.28 5,744.08 -2,651.57 -8,628.38 6,028,439.99 461,187.91 1.71 6,199.22 MWD+IFR2+MS+sag(4) 12,516.10 74.76 177.01 5,826.34 5,770.14 -2,742.50 -8,625.47 6,028,349.05 461,190.45 2.84 6,279.46 MWD+IFR2+MS+sag(4) 12,612.64 75.21 175.12 5,851.35 5,795.15 -2,835.52 -8,619.07 6,028,256.02 461,196.47 1.95 6,360.02 MWD+IFR2+MS+sag(4) 12,707.53 74.31 172.56 5,876.30 5,820.10 -2,926.54 -8,609.25 6,028,164.97 461,205.92 2.77 6,437.27 MWD+IFR2+MS+sag(4) 12,797.87 74.71 170.43 5,900.43 5,844.23 -3,012.63 -8,596.38 6,028,078.84 461,218.44 2.31 6,508.76 MWD+IFR2+MS+sag(4) 12,897.12 74.83 166.63 5,926.51 5,870.31 -3,106.47 -8,577.34 6,027,984.94 461,237.10 3.70 6,584.45 MWD+IFR2+MS+sag(4) 12,993.65 75.07 163.20 5,951.58 5,895.38 -3,196.46 -8,553.08 6,027,894.86 461,260.99 3.44 6,654.38 MWD+IFR2+MS+sag(4) 13,090.13 76.50 158.81 5,975.28 5,919.08 -3,284.86 -8,522.64 6,027,806.34 461,291.07 4.65 6,720.15 MWD+IFR2+MS+sag(4) 13,183.84 76.56 155.90 5,997.12 5,940.92 -3,368.96 -8,487.55 6,027,722.11 461,325.81 3.02 6,780.01 MWD+IFR2+MS+sag(4) 13,278.88 76.22 153.10 6,019.48 5,963.28 -3,452.32 -8,447.79 6,027,638.59 461,365.23 2.89 6,837.14 MWD+IFR2+MS+sag(4) 13,373.87 76.86 151.23 6,041.60 5,985.40 -3,534.01 -8,404.66 6,027,556.74 461,408.03 2.03 6,891.27 MWD+IFR2+MS+sag(4) 13,468.91 77.43 149.40 6,062.74 6,006.54 -3,614.50 -8,358.77 6,027,476.07 461,453.58 1.97 6,943.11 MWD+IFR2+MS+sag(4) 13,564.20 77.50 146.25 6,083.43 6,027.23 -3,693.22 -8,309.24 6,027,397.16 461,502.78 3.23 6,991.75 MWD+IFR2+MS+sag(4) 13,658.27 78.51 143.53 6,102.98 6,046.78 -3,768.48 -8,256.32 6,027,321.69 461,555.39 3.03 7,035.78 MWD+IFR2+MS+sag(4) 13,753.68 78.76 142.94 6,121.78 6,065.58 -3,843.42 -8,200.34 6,027,246.54 461,611.07 0.66 7,078.16 MWD+IFR2+MS+sag(4) 13,848.63 79.02 142.71 6,140.08 6,083.88 -3,917.66 -8,144.04 6,027,172.08 461,667.06 0.36 7,119.78 MWD+IFR2+MS+sag(4) 13,944.20 79.65 142.01 6,157.77 6,101.57 -3,992.03 -8,086.68 6,027,097.48 461,724.11 0.98 7,161.05 MWD+IFR2+MS+sag(4) 14,038.97 80.15 139.71 6,174.39 6,118.19 -4,064.38 -8,027.79 6,027,024.89 461,782.70 2.45 7,199.84 MWD+IFR2+MS+sag(4) 14,070.86 80.28 139.78 6,179.81 6,123.61 -4,088.37 -8,007.49 6,027,000.83 461,802.91 0.46 7,212.35 MWD+IFR2+MS+sag(4) 14,156.32 80.88 139.42 6,193.80 6,137.60 -4,152.57 -7,952.84 6,026,936.41 461,857.28 0.82 7,245.71 MWD+IFR2+MS+sag(5) 14,220.44 83.40 139.25 6,202.56 6,146.36 -4,200.75 -7,911.46 6,026,888.07 461,898.47 3.94 7,270.56 MWD+IFR2+MS+sag(5) 14,316.88 84.70 140.27 6,212.56 6,156.36 -4,273.97 -7,849.50 6,026,814.61 461,960.12 1.71 7,308.76 MWD+IFR2+MS+sag(5) 14,412.73 87.05 142.03 6,219.45 6,163.25 -4,348.41 -7,789.53 6,026,739.93 462,019.78 3.06 7,348.95 MWD+IFR2+MS+sag(5) 14,509.50 86.93 140.06 6,224.54 6,168.34 -4,423.56 -7,728.78 6,026,664.55 462,080.22 2.04 7,389.41 MWD+IFR2+MS+sag(5) 14,606.43 85.63 137.62 6,230.83 6,174.63 -4,496.37 -7,665.13 6,026,591.48 462,143.57 2.85 7,426.49 MWD+IFR2+MS+sag(5) 14,702.36 87.24 137.26 6,236.79 6,180.59 -4,566.89 -7,600.37 6,026,520.70 462,208.03 1.72 7,461.03 MWD+IFR2+MS+sag(5) 14,798.69 85.32 136.73 6,243.04 6,186.84 -4,637.19 -7,534.81 6,026,450.15 462,273.30 2.07 7,495.02 MWD+IFR2+MS+sag(5) 10/20/2010 10:42:51AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.15 84.88 135.41 6,251.37 6,195.17 -4,707.12 -7,467.44 6,026,379.95 462,340.38 1.42 7,527.87 MWD+IFR2+MS+sag(5) 14,991.10 86.55 135.91 6,258.46 6,202.26 -4,774.83 -7,401.27 6,026,311.98 462,406.27 1.84 7,559.27 MWD+IFR2+MS+sag(5) 15,087.91 87.61 137.74 6,263.39 6,207.19 -4,845.34 -7,335.12 6,026,241.21 462,472.12 2.18 7,593.18 MWD+IFR2+MS+sag(5) 15,184.57 89.15 139.52 6,266.13 6,209.93 -4,917.85 -7,271.27 6,026,168.45 462,535.68 2.43 7,629.90 MWD+IFR2+MS+sag(5) 15,281.17 92.06 140.87 6,265.11 6,208.91 -4,992.04 -7,209.44 6,026,094.01 462,597.20 3.32 7,669.03 MWD+IFR2+MS+sag(5) 15,377.70 94.53 140.96 6,259.56 6,203.36 -5,066.84 -7,148.68 6,026,018.98 462,657.64 2.56 7,709.18 MWD+IFR2+MS+sag(5) 15,473.31 93.97 140.24 6,252.47 6,196.27 -5,140.52 -7,088.16 6,025,945.06 462,717.86 0.95 7,748.43 MWD+IFR2+MS+sag(5) 15,570.08 94.66 139.13 6,245.19 6,188.99 -5,214.09 -7,025.73 6,025,871.24 462,779.98 1.35 7,786.74 MWD+IFR2+MS+sag(5) 15,666.72 93.79 138.14 6,238.07 6,181.87 -5,286.42 -6,962.04 6,025,798.66 462,843.37 1.36 7,823.38 MWD+IFR2+MS+sag(5) 15,699.11 94.29 137.47 6,235.79 6,179.59 -5,310.36 -6,940.34 6,025,774.64 462,864.97 2.58 7,835.23 MWD+IFR2+MS+sag(5) 15,763.33 93.98 138.70 6,231.16 6,174.96 -5,358.02 -6,897.55 6,025,726.81 462,907.56 1.97 7,859.00 MWD+IFR2+MS+sag(5) 15,859.45 89.77 141.35 6,228.01 6,171.81 -5,431.62 -6,835.86 6,025,652.97 462,968.95 5.17 7,897.66 MWD+IFR2+MS+sag(5) 15,956.26 85.75 143.74 6,231.80 6,175.60 -5,508.39 -6,777.04 6,025,575.97 463,027.45 4.83 7,940.43 MWD+IFR2+MS+sag(5) 16,052.38 85.50 144.46 6,239.13 6,182.93 -5,586.03 -6,720.84 6,025,498.11 463,083.33 0.79 7,985.14 MWD+IFR2+MS+sag(5) 16,075.59 85.25 144.49 6,241.00 6,184.80 -5,604.85 -6,707.40 6,025,479.23 463,096.69 1.08 7,996.07 MWD+IFR2+MS+sag(5) 16,148.61 84.63 142.57 6,247.44 6,191.24 -5,663.34 -6,664.17 6,025,420.57 463,139.68 2.75 8,029.36 MWD+IFR2+MS+sag(5) 16,245.48 83.83 137.34 6,257.19 6,200.99 -5,737.10 -6,602.19 6,025,346.57 463,201.36 5.43 8,068.03 MWD+IFR2+MS+sag(5) 16,342.73 84.45 139.16 6,267.12 6,210.92 -5,809.27 -6,537.77 6,025,274.15 463,265.47 1.97 8,104.20 MWD+IFR2+MS+sag(5) 16,438.75 85.94 140.04 6,275.16 6,218.96 -5,882.14 -6,475.76 6,025,201.04 463,327.18 1.80 8,142.06 MWD+IFR2+MS+sag(5) 16,501.93 85.94 139.86 6,279.63 6,223.43 -5,930.38 -6,435.21 6,025,152.64 463,367.53 0.28 8,167.35 MWD+IFR2+MS+sag(5) 16,631.38 85.69 140.63 6,289.08 6,232.88 -6,029.63 -6,352.65 6,025,053.06 463,449.68 0.62 8,219.76 MWD+IFR2+MS+sag(5) 16,728.55 86.87 140.73 6,295.38 6,239.18 -6,104.64 -6,291.20 6,024,977.81 463,510.81 1.22 8,259.80 MWD+IFR2+MS+sag(5) 16,824.70 90.02 141.69 6,297.99 6,241.79 -6,179.55 -6,231.00 6,024,902.67 463,570.71 3.42 8,300.29 MWD+IFR2+MS+sag(5) 16,920.33 85.50 138.95 6,301.73 6,245.53 -6,253.07 -6,170.01 6,024,828.91 463,631.39 5.53 8,339.18 MWD+IFR2+MS+sag(5) 16,974.67 84.45 138.27 6,306.49 6,250.29 -6,293.68 -6,134.22 6,024,788.16 463,667.01 2.30 8,359.74 MWD+IFR2+MS+sag(5) 17,017.02 86.06 139.09 6,309.99 6,253.79 -6,325.37 -6,106.36 6,024,756.35 463,694.75 4.26 8,375.81 MWD+IFR2+MS+sag(5) 17,113.13 90.70 141.48 6,312.71 6,256.51 -6,399.25 -6,044.99 6,024,682.23 463,755.80 5.43 8,414.87 MWD+IFR2+MS+sag(5) 17,209.90 94.16 143.00 6,308.61 6,252.41 -6,475.67 -5,985.80 6,024,605.58 463,814.68 3.90 8,457.16 MWD+IFR2+MS+sag(5) 17,306.33 94.65 142.70 6,301.20 6,245.00 -6,552.31 -5,927.74 6,024,528.72 463,872.43 0.60 8,500.15 MWD+IFR2+MS+sag(5) 17,402.91 92.86 140.54 6,294.88 6,238.68 -6,627.84 -5,867.91 6,024,452.95 463,931.94 2.90 8,541.37 MWD+IFR2+MS+sag(5) 17,498.38 94.66 139.65 6,288.62 6,232.42 -6,700.92 -5,806.80 6,024,379.63 463,992.75 2.10 8,579.81 MWD+IFR2+MS+sag(5) 17,595.38 95.03 139.38 6,280.42 6,224.22 -6,774.43 -5,744.04 6,024,305.87 464,055.20 0.47 8,617.93 MWD+IFR2+MS+sag(5) 17,692.24 94.47 139.73 6,272.40 6,216.20 -6,847.89 -5,681.43 6,024,232.17 464,117.51 0.68 8,656.05 MWD+IFR2+MS+sag(5) 17,788.24 94.97 139.37 6,264.50 6,208.30 -6,920.70 -5,619.35 6,024,159.12 464,179.28 0.64 8,693.83 MWD+IFR2+MS+sag(5) 17,885.08 92.55 139.76 6,258.15 6,201.95 -6,994.24 -5,556.69 6,024,085.33 464,241.64 2.53 8,732.00 MWD+IFR2+MS+sag(5) 17,981.42 94.35 140.48 6,252.36 6,196.16 -7,068.03 -5,495.03 6,024,011.29 464,302.99 2.01 8,770.85 MWD+IFR2+MS+sag(5) 18,077.59 90.39 141.35 6,248.38 6,192.18 -7,142.60 -5,434.46 6,023,936.48 464,363.25 4.22 8,810.88 MWD+IFR2+MS+sag(5) 18,174.18 87.48 139.82 6,250.17 6,193.97 -7,217.20 -5,373.15 6,023,861.64 464,424.25 3.40 8,850.60 MWD+IFR2+MS+sag(5) 18,270.78 85.50 140.62 6,256.09 6,199.89 -7,291.30 -5,311.46 6,023,787.31 464,485.63 2.21 8,889.70 MWD+IFR2+MS+sag(5) 18,367.21 86.50 141.34 6,262.81 6,206.61 -7,366.03 -5,250.90 6,023,712.33 464,545.89 1.28 8,929.88 MWD+IFR2+MS+sag(5) 10/20/2010 10:42:51AM Page 7 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 18,464.21 84.70 140.60 6,270.26 6,214.06 -7,441.16 -5,190.00 6,023,636.97 464,606.47 2.01 8,970.26 MWD+IFR2+MS+sag(5) 18,560.44 84.44 140.10 6,279.36 6,223.16 -7,514.92 -5,128.87 6,023,562.97 464,667.30 0.58 9,009.31 MWD+IFR2+MS+sag(5) 18,656.42 86.00 139.88 6,287.36 6,231.16 -7,588.17 -5,067.38 6,023,489.47 464,728.48 1.64 9,047.75 MWD+IFR2+MS+sag(5) 18,749.65 86.93 140.42 6,293.11 6,236.91 -7,659.61 -5,007.76 6,023,417.80 464,787.81 1.15 9,085.39 MWD+IFR2+MS+sag(5) 18,814.45 86.86 139.98 6,296.62 6,240.42 -7,709.32 -4,966.34 6,023,367.93 464,829.02 0.69 9,111.61 MWD+IFR2+MS+sag(5) 18,848.29 87.55 141.37 6,298.27 6,242.07 -7,735.47 -4,944.92 6,023,341.70 464,850.33 4.58 9,125.56 MWD+IFR2+MS+sag(5) 18,881.71 86.18 140.92 6,300.10 6,243.90 -7,761.46 -4,923.99 6,023,315.63 464,871.16 4.31 9,139.59 MWD+IFR2+MS+sag(5) 18,945.12 87.92 141.91 6,303.36 6,247.16 -7,810.95 -4,884.49 6,023,265.97 464,910.45 3.16 9,166.47 MWD+IFR2+MS+sag(5) 19,036.17 86.18 138.15 6,308.05 6,251.85 -7,880.63 -4,826.10 6,023,196.07 464,968.56 4.55 9,203.07 MWD+IFR2+MS+sag(5) 19,137.27 85.38 137.60 6,315.49 6,259.29 -7,955.41 -4,758.47 6,023,121.03 465,035.87 0.96 9,240.16 MWD+IFR2+MS+sag(5) 19,235.40 85.00 137.83 6,323.72 6,267.52 -8,027.75 -4,692.68 6,023,048.43 465,101.36 0.45 9,275.87 MWD+IFR2+MS+sag(5) 19,331.91 84.51 138.86 6,332.54 6,276.34 -8,099.55 -4,628.80 6,022,976.37 465,164.94 1.18 9,311.95 MWD+IFR2+MS+sag(5) 19,428.22 85.38 140.12 6,341.02 6,284.82 -8,172.49 -4,566.49 6,022,903.19 465,226.95 1.59 9,349.74 MWD+IFR2+MS+sag(5) 19,524.49 86.56 140.02 6,347.79 6,291.59 -8,246.13 -4,504.85 6,022,829.31 465,288.28 1.23 9,388.46 MWD+IFR2+MS+sag(5) 19,621.33 85.19 138.35 6,354.76 6,298.56 -8,319.23 -4,441.72 6,022,755.96 465,351.11 2.23 9,426.03 MWD+IFR2+MS+sag(5) 19,717.32 86.56 140.15 6,361.66 6,305.46 -8,391.75 -4,379.23 6,022,683.19 465,413.30 2.35 9,463.38 MWD+IFR2+MS+sag(5) 19,813.62 83.95 140.23 6,369.63 6,313.43 -8,465.47 -4,317.79 6,022,609.23 465,474.43 2.71 9,502.25 MWD+IFR2+MS+sag(5) 19,909.97 84.88 140.35 6,379.00 6,322.80 -8,539.24 -4,256.53 6,022,535.22 465,535.39 0.97 9,541.25 MWD+IFR2+MS+sag(5) 19,947.00 84.88 140.35 6,382.31 6,326.11 -8,567.63 -4,232.99 6,022,506.73 465,558.81 0.00 9,556.28 PROJECTED to TD 10/20/2010 10:42:51AM Page 8 COMPASS 2003.16 Build 42F Page 1 of 2 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Friday, October 01, 2010 10:54 AM To: Schwartz, Guy L(DOA) Subject: RE: ODSN-17 (PTD 210-093) liner cement job Guy, Our estimate of the volume of fluid pumped past the 7" liner shoe is 28 bbl. We pumped our squeeze job this morning and operations went as planned. Let me know if you need anything else. Vern From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, September 30, 2010 3:56 PM To: Johnson, Vern Subject: RE: ODSN-17 (PTD 210-093) liner cement job III Vern, Not good to see an over-displaced cement job. Do you have a good estimate of how much the cement was overdisplaced ? Keep me posted on the squeeze operation and following FIT. IF the squeeze goes poorly we may require a cement log to evaluate the cement coverage. Don't see any problems with the OA string pressure test assuming this pipe will not see higher pressures later. It meets the required regulation of 50% of the BOP stack rating. 20 MC 25.030 (e ) Regards. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Thursday, September 30, 2010 2:27 PM To: Schwartz, Guy L (DOA) Cc: Vaughan, Alex; Campoamor, Kathy; Hazzard, Vance Subject: ODSN-17 (PTD 210-093) liner cement job Guy, As discussed,we pumped a wet shoe on our 7" liner and are preparing to pump a remedial cement squeeze. After drilling 8-1/2" hole into the Nuiqsut formation we experienced problems while tripping out of hole,so it was decided to run the intermediate casing as a liner and tie-back string instead of a longstring of casing. While displacing the liner cement job,the plugs landed early but did not hold much pressure, and pumping was continued past the estimated stroke count and shoe track volume. This has resulted in a 'wet' shoe. This was 10/1/2010 Page 2 of 2 confirmed by pumping mud from surface through the casing string. The pump in test confirmed leak off at approximately 13 ppge. We plan to remediate by setting a squeeze packer near the shoe, and squeezing 10 barrels of cement out of the shoe. Another deviation from our original plan was that after landing our 7"tieback string,we only tested the outer annulus to 2500 psi. Calculations indicate that the limiting condition for tubing movement on the tieback string was elongation during the annulus test. To mitigate potential problems with the tie back string seal assembly, it was decided to reduce the annulus test pressure. If needed the annulus could be retested to 3500 psi as originally planned, however this increases the risk of problems with the tie back string. The inner diameter of the casing string was tested successfully to 3500 psi for 30 min. Please call or email if you would like to discuss. Vern Johnson Drilling Superintendent Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 10/1/2010 ZEE [IF SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Vance Hazzard Drilling Manager Pioneer Natural Resources Alaska, Inc. 0 700 G Street, Suite 600 g..10 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-17 Sundry Number: 310-284 Dear Mr. Hazzard: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sinc-rely, 410/ om iss'. er DATED this f 9 day of September, 2010. Encl. q,11' RECEIVED STATE OF ALASKA SEP 0 3 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALA;sk mi 3 gaM u mission 20 MC 25.280 a;�1C���CI3(� Add iog' trci e 1.Type of Request: Abandon❑ Plug for Redrill El Perforate New Pool❑ Repair Well❑ Change oved Program 0 FSP Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdownarep El Re-enter Susp.Well El Stimulate❑ Alter Casing❑� L,n4, I Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development a Exploratory El 210-093 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service El 6.API Number: Anchorage,AK 99501 50-703-20622-00-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes CINo El • ODSN-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 355038 Oooguruk-Nuiqsut Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4670' 3245' 4670' 3245' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 4621' 11-3/4" 4660' 3242' 5830 3180 Intermediate 1 Intermediate 2 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)and TVD(ft): 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/13/2010 Oil 0 Gas El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name Title Vance Haard,343-2116 Drilling Manager Signatureh �^ Jy r �� hone Date 9/3/2010 Prepared By:Kathy Campoamor,343-2183 N4% COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/143 -,::: � Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: po,-1'" o p ox.s i''1 D; Lif0 7 �I GG ./ APPROVED BY 71 Approved by: i OMMISSIONER THE COMMISSION Date: ?:"1.?"—.....,/ RBDM'9 ' 11 If.- �� ,c' Y1- 0 Form 10-403 Revised 1/2010 ' 1 R I G I f\tJ A L A 7/7 Submit in Duplicat 04, PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 September 3rd, 2010 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Application for Change of Permitted Casing Program ODSN-17, Permit to Drill #210-093 Surface Location: 2945' FSL, 1167' FEL, Sec 11, T13N, R7E, UM X = 469831.04, Y = 6031061.18, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Sundry Approval for a change of casing program. This request is based on the provided summary below: Summary: PNRA has opted to drill a second lateral out of the ODSN-17 intermediate shoe. The second lateral ODSN-17L1 will be applied for in a separate Permit to Drill Application. A change to ODSN-17 lateral casing program is outlined below to utilize a plop & drop 4-1/2" liner with an kick-off billet. ODSN-17 will be completed with originally submitted ESP completion �oc string (see page 19 of 60 ODSN-17 ESP Completion — Planned)without executing originally programmed fracture stimulation program. Detail provided in the original ODSN-17 PTD will not change prior to drilling the 6-1/8" lateral to TD. Rig Activity: 4-1/2" Lateral Casing Procedure The following program follows from POOH to surface after drilling the lateral of ODSN-17 to TD. Continues from PTD#210-093 page 9 of the well program line 49. 1. Change one set of pipe rams to 4-1/2" and test BOPE as required. 2. RIH w/4-1/2" plop & drop solid production liner w/ perforated pups below an aluminum billet for kicking off to drill second lateral. 3. Release from plop & drop liner and aluminum billet. lle± '4 I) 4. POOH to intermediate shoe and set heavy weight balance brine pill. RU MPD trip nipple and POOH to surface. Continue as per approved PTD#210-093 Alaska Oil &Gas Conservation Cc ission September 3, 2010 Page 2 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 10-403 Application for Sundry Approval 20 AAC 25.280. 2) A revised summary of the drilling and completions operations. 3) A schematic of planned change to casing program. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Operations Drilling Engineer (20 AAC 25.070) 907.343.2186 alex.vaughanpxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) 907.343.2134 paul.daggettapxd.com If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, / ,,,,,,,,_?,/,,,(rt r i ance Hazzard Drilling Manager Attachments: Form 10-403 Supporting Sundry Information cc: ODSN-17 Well File ODSN-1 r Present Well Condition 16" Conductor 158' MDrkb/ 158'TVDrkb S:L 11-3/4", 60# L-80 HYD 521, 10.772" ID 3239' MDrkb/3000'TVDrkb 4660' MDrkb/3242' TVDrkb Date: Revision By: Comments 9/3/2010 KLC Surface Casing ODSN-17 Producer Well Schematic `ALRAL RES4.RCES A.;SKA ODSN- ESP Completion - PI ned Well Head: 11-3/4", 5K,VetcoGray Tree: 4-1/2",5K, Horizontal Casing Item# Item MD(ft) TVD(ft) HO A 16"Conductor158 158 B 11-3/4" 60#L-80 Hydril 521, 10.772" ID 4483 3240 A ` C 9-5/8"40#L-80 Hydril 521, 8.835" ID* 10829 5348 D 7"26#L-80 BTC-M, 6.276" ID** 13955 6147 -� � E 4-1/2" 12.6#Hydril 521 3.958" ID 19830 6217 F 2-7/8" 6.5#L-80 IBT-M 13676 6080 * Planned TOC©9256'MD **Planned TOC© 12762'MD O ili 1 VetcoGray Tubing Hanger 34 34 =' 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,000 1,954 3 GLM#1 -2-7/8"x 1-1/2" (min. 3 jts above top X nipple) 4,664 3,675 0-1 2-7/8"X Nipple 2.313" I.D. (min. 2 jts above Gas Vent 4 Valve Packer) 4,777 3,744 jo® II5 WFT 7"x 2-7/8" Gas Vent Valve Packer(max. TVD 3800') 6,035 3,750 6 GLM#2-2-7/8"x 1-1/2" (min. 2 jts above X nipple) 9,800 4,988 2-7/8"X Nipple, 2.313" ID(max. incl. 70 deg)w/RHC-M 7 Plug Body 9,900 5,021 8 Automatic Divert Valve(ADV) 13,601 6,062 9 ESP (Pump, Motor, and Jewelry) 13,611 6,065 0 End of Assembly 13,672 6,079 III I Upper Completion 1 N. Item# ItjamI MDrkb(ft)I TVDrkb(ft) 13,722 10 WFT7"x 3-1/2" Retrievable Packer 11 WFT3-1/2" Sliding Sleeve 13,747 6,092 6,100 OC 12 WFT 3 1/2" Formation Saver Valve 13,772 6,106 WLEG 13,782 6,109 0 End of Assembly 13,787 6,110 O 0 0 Lower Completion Item# Item MD(ft) TVD(ft) 13 Aluminum Kick-Off Billet tba tba O4-1/2" 12.6#L-80 Hydril 521 Liner w/4ft ported pups (ported 14 w/6 1/2 holes -spaceout-200')w/3 Resman Pups N / WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 �� 10 15 Box 19830 6217 TD 19832 6217 11 000 _ 12 N-17L ( `� 0 ()s 0 13 14 15 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 O 00 00 00 00 00 00 00 00 00 Date: Revision By: Comments PIONEER7/4/2010 jdf Planned completion II]^ RESOURCES ^ /A 7/16/2010 jay WP#09.b update ODSN-17 Producer NATURAL AIAS(A 8/09/2010 JAD WP#12.a update Well Schematic 9/3/2010 jay Add Plop&Drop Liner ESP Completion Page 1 of 2 S Schwartz, Guy L (DOA) From: Crisp, John H (DOA) Sent: Wednesday, September 08, 2010 3:04 PM To: Regg, James B(DOA) Cc: Schwartz, Guy L (DOA); Aubert, Winton G (DOA); DOA AOGCC Prudhoe Bay Subject: PNR ODSN-17 PTD Z/o —O 3 Jim, I just wanted to summarize my trip to Oooguruk Island Friday 09/03/10 evening thru Tuesday 09/07/10 morning. The reason for the trip to the Island was to witness BOP test. Due to the controversy of cement to surface on the surface casing cement job plus the cement flash setting & leaving 1200'tail cement in the surface casing the Commission required witness of the BOP test, casing test& FIT test after drilling 20' to 50' new hole. When I arrived on the Island I immediately went to the Rig Floor to review the IADC reports from the previous few days to attempt to understand how cement to surface was achieved after annulus was packed off&the tail cement flash set 1200' inside the surface casing. IADC review&conversations with Driller, WSL, Mud Engineer& Vetco Gray wellhead representative& looking at the cement samples gave me a better understanding of the situation & I agreed that with the excess lead cement pumped plus circumstances revolving around the entire cement job that it was possible to achieve cement to surface. Testing of the choke manifold was witnessed while they were POOH with their C/O assembly. My attention to the whole situation of them CIO cement was heightened due to the fact that they had accidentally drilled out their plugs&float collar&could not test their casing to 3500 psi as required. The AOGCC had agreed to allow PNR to C/O their cement to the float collar&then perform pipe management to P/U enough pipe to drill the next hole section. AOGCC did not agree to allow float collar to be drilled or casing test prior to testing BOP's. First mistake we made was to allow PNR to drill the flash set cement before testing their BOP's. PNR should have been held to the regulation 20 MC 25.035 (e) (10) (A). Granted, we grant variances to allow them to P/U DP prior to testing their BOP's. This has the possibility of accomplishing two positive things, helping with the timing for the AOGCC to witness their test plus adding possibly a couple of days before BOP test is required for them. My discussion of them drilling out their float shoe & not having casing integrity was with PNR WSL Joe Polya. Mr. Polya understood the AOGCC's concerns about accidentally drilling float equipment without permission &the attempted casing test prior to performing the high pressure low volume BOP test. We agreed that just having drilled this surface hole without secondary well control equipment or diverter the chances of having well control incident was very low, we also agreed that the chance of incident was increased by drilling out the float equipment without BOP test or casing test. My understanding was that the value for PNR to drill out rubber plugs prior to RIH with smart iron BHA was that in the past rubber had caused a failure of their Rotary Stearable drilling tools. I do believe the drilling of the float collar was unintentional. Tested BOP's&three valves in choke manifold 250-4500 psi. No failures witnessed.This Rig has proven that they have good procedures along with good people&equipment. The test started @ 0200 hrs,so much for the help with timing for the BOP test. Plan forward was to RIH with RTTS to test casing to 3500 psi. Halliburton recommended scraper run prior to RIH with RTTS. No casing scraper on the Slope for the 11 3/"casing. I witnessed RIH with RTTS to depth of approximately 3600' MD where circulation was attempted with no success. RTTS was POOH to 3380' MD (top of hard cement that was inside casing)where circulation was established. Attempt set of RTTS @ 3360' MD with no success. RTTS was POOH & L/D. Long gauge PDC bit with stabilizers was P/U & RIH reaming from 3000' MD to 4588' MD. High viscosity heavy weight sweep was pumped at 4588' MD to effectively clean the casing. D/P was stood back in derrick&then singles were P/U out of pipe shed for pipe management. C/O reaming assembly was back on bottom @ 4588' where high viscosity sweep was pumped to clean the casing. I witnessed this reaming & bottoms up of both sweeps. RTTS was RIH to a depth of 4551' MD to perform casing test. This depth effectively tested the casing connection on the first joint above the float collar. 9/8/2010 Page 2 of 2 Tested 11 3/4"surface casing to 3500 psi as per 20 AAC 25.030 (e)3700 psi initial pressure—15 minute 3657 psi—30 minute 3642 psi.5.1 bbls pumped to achieve test pressure. POOH with RTTS& RIH with smart iron rotary stearable assembly to drill 20' of new hole to perform FIT. I witnessed the Drilling assembly RIH to 4588' MD where no hard cement was found. Continue to C/O to 4660' MD where the casing shoe was found &drilled out. C/O from 4660' MD to 4670'where the transition from open hole to new hole was noticed immediately. The new hole drilled approximately 20' per hour from 4670' MD to 4690' MD. In my mind the possibility of having a good shoe test was slim. The fact that the tail cement had flash set leaving 1200'cement inside casing caused me to be very suspect of having good tail cement around the shoe. Calculated volume of tail cement that could have been circulated around the shoe was approximately 10 bbls. FIT as per 20 AAC 25.030(f). New hole drilled from 4670'to 4690'.Shoe at 4660' MD.3285'ND. I witnessed CBU at 4690'&mud weight 10 ppg in &10 ppg out. I witnessed the pumps lined up to pump down the drill string &down the kill line.Top pipe rams used for FIT.4.6 bbls 10 ppg mud pumped to a pressure of 1002 psi. Pumps were shut down @ 1002 psi&pressure was monitored for 10 minutes. Pressure after 5 minutes was 915 psi&after 10 minutes 886 psi. If I made no mistakes the FIT performed showed enough shoe&formation integrity to a mud equivalent of rounding down to 15.8 ppg. Pressure bled off&2.7 bbls were returned to trip tank. Summary: BOP test, casing test& FIT test were all successful&witnessed by AOGCC. Conclusion:AOGCC made a mistake by not requiring BOP test prior to drilling out cement inside casing. PNR made mistakes by drilling float equipment&performing Casing test prior to performing low volume high pressure BOP test. My understanding is that this surface casing design is 1000' MD deeper than on previous wells. An attempt to case off unconsolidated formations that cause difficulty drilling the next interval is the reason for more surface casing. PNR stated that Port Collar for next surface casing is under review. 9/8/2010 Page 1 of/ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, September 02, 2010 3:55 PM To: 'Johnson,Vern' Cc: Campoamor, Kathy; OoogurukDrillingSupervisor; Vaughan, Alex; Hazzard, Vance; Crisp, John H (DOA) Subject: RE: ODSN-17 BOP test(PTD 210-093) Vern, I agree with your plan forward. As per 20 ACC 25.035 (e) BOP equipment is not required before drilling out of the surface casing shoe. You are using drilling mud ( 9.2ppg ) in this cement cleanout so conditions are essentially the same as when the OH was first penetrated. Required full BOP testing can be done when you reach the float collar. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Thursday, September 02, 2010 3:42 PM To: Schwartz, Guy L (DOA) Cc: Campoamor, Kathy; OoogurukDrillingSupervisor; Vaughan, Alex; Hazzard, Vance Subject: ODSN-17 BOP test(PTD 210-093) Guy, As discussed this morning,our surface cement job did not go as planned, and we left approximately 1100 ft of cement inside casing. We currently plan to nipple up BOPs,close the blind rams to test casing and BOP connection to 3500 psi for 5 min,then pickup drillpipe and a cleanout bit, cleanout cement with a bit and 9.2 ppg drilling mud down to the top of the float collar. We will then pull out of hole and perform a full BOP test prior to running back in with a drilling BHA to drill out the shoe and perform a Leak Off Test. Let me know if you have any questions or concerns. Vem Johnson Drilling Superintendent Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell Statement of Confidentiality: 9/2/2010 SIATE [I ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Alex Vaughan Operations Drilling Manager Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-17 Pioneer Natural Resources Alaska, Inc. Permit No: 210-093 Surface Location: 2940' FSL, 1172' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 5749' FSL, 5243' FEL, Sec. 23, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and condition of this permit may result in the revocation or suspension of the permit.0Si - -ly, .toner DATED this 20 day of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALA; OIL AND GAS CONSERVATION COMM. /N JUL 1 6 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil&Gas Corti.Commission la.Type of Work: 1 b.Proposed Well Class: Development-Oil Q • Service- Winj ❑ Single Zone Q. 1c.Speci r oposed for: Drill Q. Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSN-17 • 3.Address: 700 G Street,Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 19831' ' TVD: 6217' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk- Nuiqsut Oil Pool • Surface: 2940'FSL, 1172' FEL, Sec. 11,T13N, R7E, UM ADL 355036./ADL 355038 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4195'FSL,3925' FEL,Sec. 15,T13N, R7E, UM 417497 July 26,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 5149'FSL,5243' FEL,Sec.23,T13N, R7E, UM 5760 1369' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 56.2 feet • 15.Distance to Nearest Well Open Surface: x-469826.11 • y-6031056.25• Zone-ASP 4 GL Elevation above MSL: to Same Pool: ODSN-45A is 819' 13.5 feet. away 16.Deviated wells: Kickoff depth: 200 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.07 degrees Downhole: 3168 ' Surface: 2484 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven 14-1/2" 11-3/4" 60# L-80 Hyd 521 4440' Surface Surface 4483' • 3240' 620 sx PF'L; 259 sx Class'G' 11-3/4" 9-5/8" 40# L-80 Hyd 521 6496' 4333' 3184' 10829' 5316' 411 sx Class'G' 8-1/2" 7" _ 26# L-80 BTC-M 13912' Surface Surface 13955' 6147' 197 sx Class'G' 6-1/8" 4-1/2" 12.6# L-80 Hyd 521 6026' 13805' 6113' 19831'• 6217' Uncemented 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) -Drlg Liner Intermediate 2 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): - 20. Attachments: Property Plat E BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan,343-2186 Prepared By:Kathy Campoamor,343-2183 Printed Name Alex Vaughan Title Operations Drilling Engineer -- - Signature .. - Phone 343-2186 Date 7/16/2010 Commission Use Only Permit to Drill //� API Number: Permit A rQ I� See cover letter for other Number: L-[ lit- 6 50-7CO 3- 2 ZZ cX-)-c6 Date: ) 'O requirements. Conditions of approval: If box is checked,wet may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: I Other: ,C- Lf$00 pj� BOP leJ-LSamples req'd: Yes L No Mud log req'd: Yes ❑ No[►� /) ( ;..f_6 j.t i , ) H2S measures: Yes❑ No C Directional svy req'd: Yes [."No El 2.S�� pi� /`--t h h/�N- �r" -7 d /1 1 (�(ULr T"r C-L141Ve-. 5 pe-r G. /tli 5 % 3 Ch �2� APPROVED BY THE COMMISSION DATE: ���-�a COMMISSIONER A 7-1410 GlA ,,,,,,,, J. .. _---, 7--,„...., Form 10-401 (Revised 7/2009) This permit is valid foro24 months from he date o approval(20 AAC 25.005(g)) Submit in Duplicate , Alaska OH & Gas Conservation Commission July 16th, 2010 Page 1 of 3 July 16th, 2010 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-17 Surface Location: 2945' FSL, 1167' FEL, Sec 11, T13N, R7E, UM X = 469831.04, Y = 6031061.18, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk-Nuiqsut formation. PNRA requests the Permit to Drill based on approved Pool Rules. PNRA intends to pre-produce ODSN-17 prior to the fracture stimulation which will be requested on a separate 10-403 at a later date. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: o Drill 14-1/2" to -4,483' MD/3,240'TVD and set 11-3/4"flush joint casing. • Intermediate Hole 1: o Drill 10-5/8" and under-ream while drilling (UWD) to 11-3/4" to -10,829' MD / 5,316'TVD. Run and set a 9-5/8" Flush Joint Drilling Liner. • Intermediate Hole 2: o Drill 8-1/2" to -13,955' MD /6,147' TVD and set a 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • ODSN-16 Production Hole: o Drill 6-1/8" horizontally to -19,830' MD / 6,217' TVD and set a 4-1/2" solid liner with perforated pups. • Completion: o Temporary 4-1/2"fracture stimulation string. o 2-7/8" tubing final ESP completion string with SCSSSV & GLM's. Alaska Oil & Gas Conservation Commission July 16th, 2010 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the . Intermediate 2 and Production hole sections of ODSN-17 as outlined below. • From TD of Intermediate 1 until Intermediate 2 TD o Use -9.8-10.5 ppg fluid while using MPD to control pressure from the surface to - -12.5 ppg EMW at the bottom of the hole. ■ Open formations: • Kuparuk Sands, -9.8 ppg Pore Pressure • Nuiqsut Sands, -9.8 ppg Pore Pressure • From the Intermediate 2 Shoe to TD o Use -7.2-8.2 ppg fluid while using MPD to control pressure from the surface to -9.8-10.2 ppg EMW at the bottom of the hole during connections and while . • tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. In the future, PNRA may provide information and permitting requesting annular disposal of drilling wastes on this well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: Alaska Oil & Gas Conservation Commission July 16th, 2010 Page 3 of 3 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19-AC as required by 20 AAC 25.035 (b) and (c). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be • maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Drilling Superintendent (20 AAC 25.070) 907.343.2111 vern.johnson@pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett@pxd.com The anticipated spud date for this well is July 26th, 2010. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Va.• an Operations Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-17 Well File ODSN-17 rrac String Completion — Planned Well Head: 11-3/4",5K,VetcoGray Casing Tree: 4-1/2",5K, Horizontal Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 0 B 11-3/4"60#L-80 Hydril 521, 10.772" ID 4483 3240 C 9-5/8"40#L-80 Hydril 521, 8.835" ID* 10829 5316 A ` D 7"26#L-80 BTC-M, 6.276" ID** 13955 6147 E 4-1/2" 12.6#Hydril 521 3.958" ID 19830 6217 7J * Planned TOC @ 9256'MD **Planned TOC @ 12762' MD Upper Completion Item# Item MDrkb(ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger I, 34 34 4-1/2"XXO Safety Valve Landing Nipple w/Wireline / 2 Retreivable ScSSSV 2100 750 3 GLM#1 Brou-1A GLM 4-1/2"x 1" 5300 3500 4 4 1/2"X Nipple, 3.813" ID 5400 3574 B 5 GLM#2 Brou-1A GLM 4-1/2"x 1" _ 9770 4919 6 ROC Gauge 9850 5005 7 4 1/2"XN Nipple, 3.725" ID Nogo(70 degree max) 9900 5021 End of Assembly 13802 6110 eti on 1 MD(ft) TVD(ft) 6 WFT PBR Tie Back Sleeve 15ft 13787 6110 7 WFT"NTH" Liner Top Pkr 13802 6112 C-J�JJ 8 vvFF Rotating Hyd Set Liner Hanger 13805 6112 ■ II0 4-1/2" 12.6#L-80 Hydril 521 Liner w/4ft ported pups (ported 9 w/6 1/2 holes-spaceout-200')w/3 Resman Pups _ WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 10 Box 19830 6217 (5-) TD 19832 6217 0 Cl) II II 0 6 CO 8 0 9 10 D 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 0 00 00 00 00 00 00 00 00 00 19830'MDrkb/6,217'TVDrkb Date: Revision By: Comments pioNEER 7/4/2010 jdf Planned completion 7/6/2010 TWC Added GLM and X Nipple for KO ODSN-17 Producer Well Schematic NATURAL RESOURCES ALASKA 7/16/2010 jav WP#09.b Update Frac String - Completion ODSN-17 ESP Completion - Planned Well Head: 11-3/4",5K,VetcoGray Casing Tree: 4-1/2",5K, Horizontal Item # Item MD(ft) TVD(ft) A 16" Conductor 158 158 O B 11-3/4" 60#L-80 Hydril 521, 10.772" ID 4483 3240 C 9-5/8"40#L-80 Hydril 521, 8.835" ID* 10829 5316 A D 7"26#L-80 BTC-M, 6.276" ID** 13955 6147 E 4-1/2" 12.6#Hydril 521 3.958" ID 19830 6217 -. /I F 2-7/8" 6.5#L-80 IBT-M 13676 6080 *Planned TOC @ 9256'MD **Planned TOC @ 12762'MD Upper Completion 2 Item# ` MDrkb(ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 34 34 IF / 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,000 1,954 IrA 3 GLM#1 -2-7/8" x 1-1/2" (min. 3 jts above top X nipple) 4,664 3,675 2-7/8"X Nipple 2.313" I.D. (min. 2 jts above Gas Vent 10J 4 Valve Packer) 4,777 3,744 B 5 WFT 7" x 2-7/8" Gas Vent Valve Packer(max.TVD 3800') 6,035 3,750 11 6 GLM#2-2-7/8"x 1-1/2"(min. 2 jts above X nipple) 9,800 4,988 2-7/8"X Nipple, 2.313" ID(max. incl. 70 deg)w/RHC-M • 7 Plug Body 9,900 5,021 8 Automatic Divert Valve(ADV) 13,601 6,062 9 ESP(Pump, Motor, and Jewelry) 13,611 6,065 II ® J End of Assembly 13,672 6,079 11 El 10 WFT 7"x 3-1/2" Retrievable Packer 13,722 6,092 J 11 WFT 3-1/2" Sliding Sleeve 13,747 6,100 12 WFT31/2" Formation Saver Valve 13,772 6,106 c WLEG 13,782 6,109 , 8 End of Assembly 13,787 6,110 Co O Lower Completion Item# Item MD(ft) TVD(ft) 13 WFT PBR Tie Back Sleeve 15ft 13787 6110 14 WFT"NTH" Liner Top Pkr 13802 6112 (-9 15 WFT"PHR" Rotating Hyd Set Liner Hanger 13805 6112 4-1/2" 12.6#L-80 Hydril 521 Liner w/4ft ported pups (ported �� to 16 w/6 1/2 holes-spaceout-200')w/3 Resman Pups / WFT Eccentric Solid Alum Shoe w/4-1/2 12.60 Hydril 521 411• 00 ✓ 17 Box 19830 6217 �� ® TD 19832 6217 00 0 ® ` 16 7 FUJI 00 0000 00 00 00 00 00 00 �\ 00 00 00 00 00 00 00 00 00 t 1 00 00 00 00 00 00 00 00 00 �/ 19830'MDrkb/6,217'TVDrkb PIONIEER Date: Revision By: Comments 7/4/2010 jdf Planned completion 7/16/2010 jay WP#09.b update ODSN-17 Producer NA1URALRESOURCES ALASKA well Schematic ESP Completion Permit to Drill Well Plan Summary ODSN-17 Oooguruk - Nuiqsut Lateral Production Well • Surface TD @ 4,483' MD / 3,240' TVD Drilling Liner TD @ 10,829' MD / 5,316' TVD Intermediate TD @ 13,955' MD / 6,147' TVD ODSN-17 Lateral TD @ 19,830' MD / 6,217' TVD _Surface Location: 2940' FSL, 1172' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X=469826.11 Y=6031056.25 Target: Oooguruk-Nuiqsut 4195' FSL, 3925' FEL, Sec. 15, T13N, R7E, Umiat _ X =461797.01 Y= 6027051.5 6147' TVDrkb Bottom Hole Location ODSN-17 5149' FSL, 5243' FEL, Sec. 23, T13N, R7E, Umiat X =465730.59 Y= 6022707.74 6217' TVDrkb AFE Number: TBA Est. Start Date: July 26, 2010 Rig: Nabors 19AC ' Operating days: 49 days to Drill and Complete Objective &Well Type Nuiqsut Development Well Well Design: Modified Slimhole (11-3/4"x 9-5/8" liner x 7"x 4-1/2" liner) Current Mechanical Condition: Well Bay Footing/ODS Ground Level: Elevation above MSL: 13.5' • RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' - Conductor: 158' MDrkb Pioneer Natural Resources Last Revised:July 16"',2010 ODSN-17 Permit To Drill Page 1 of 12 Well Control: Well Section Pressure Depth psi ND Basis 14-1/2" Surface Section Maximum anticipated BHP 1449 3240 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 1093 Surface 10-5/8"x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP (Based on seawater gradient of 0.4472 psi/ft) 2377 5316 Maximum surface pressure Based on BHP and a full column of gas 1793 Surface from TD @ 0.11 psi/ft) 8-1/2" Intermediate Casing Hole Section Maximum anticipated BHP Based on 9.8 ppg Oooguruk-Kuparuk pore 3133 6147 pressure) Maximum surface pressure Based on BHP and a full column of gas 2456 Surface from TD @ 0.11 psi/ft) 6-1/8" ODSN-17 Production Liner Hole Section Maximum anticipated BHP Based on 9.8 ppg Oooguruk-Nuiqsut pore (116& 6217 pressure) Maximum surface pressure Based on BHP and a full column of gas 2484 Surface from TD @ 0.11 psi/ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel Diverter(see attached schematic)—Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21-1/4"2M annular BOP 1 16"full opening knife gate valve, hydraulically actuated 16"diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11"5M single ram BOP w/studded connections Hydril 11"5M single ram BOP w/studded connections Drilling cross 11"5M x 11" 5M with 2 ea. 3-1/8"5M side outlets w/flanged connections 2 ea. 3-1/8"5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3-1/8"5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/studded connections Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 2 of 12 Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 11-3/4"Surface Shoe Rathole +20'to 50'from shoe LOT 12.5 ppg 9-5/8" Drilling Liner Shoe Rathole +20'from shoe FIT 13.5 ppg 7" Intermediate Shoe Rathole +20'from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 14-1/2" hole Spud Mud Interval Density(ppg) Viscosity(secs) YP PV 10 sec gel API FL Initial 8.8 150-200 35-50 15-25 10- 15 unrestricted Final 9.2-9.6 70-100 25-35 15-25 10- 15 <12 Drilling Liner Mud Properties: 10-5/8"x 11-3/4" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 9.8 ppg 40-60 15-25 12-20 < 12 8- 10 Intermediate Hole Mud Properties: 8-1/2" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 9.8 - 10.5 ppg 50-70 15-25 15-25 < 10 3-5 (-12.5 ppg via (8-10 HTHP) MPD) Production Hole Mud Properties: 6-1/8" hole MOBM Interval Density(ppg) Viscosity(secs) YP PV ES HTHP _ 0/W Initial to TD 7.2 -8.2 ppg'( 55-80 12 -25 10 -20 800-2000 <6 94/6 (-9.8 ppg via MPD) ' Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 3 of 12 Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. EMW Comments (psi) (p139) Base of Permafrost 1666 Top West Sak 2408 2295 1032 8.65 Base of fluvial sands Tuffaceous Shales 3455 2901 Hue2 tuff 3201 SCP 3240 Brook 2B 7621 4272 1922 8.65 Top Torok Sand 9757 4974 Base Torok Sand 10308 5153 Torok Shale 1 5306 ICP1 5316 Top HRZ 12251 5718 Base HRZ 12718 5837 Kalubik Mkr 13071 5927 Top Kup C 13266 5977 3046 9.8 LCU 13269 5978 BCU 13741 6097 Top Nuiqsut 13928 6142 3130 9.8 Production Zone ICP2 6147 ODSN-17 TD 19831 6217 Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 4 of 12 Logging Program: 14-1/2"Section: Drilling: Dir/GR Open Hole: N/A Cased Hole: N/A 10-5/8"x 11-3/4" Section: Drilling: Dir/GR/ Res Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: Dir/GR/ Res Open Hole: N/A Cased Hole: ODSN-17 6-1/8" Section: Drilling: Mud logging Dir/GR/ Res/AzDens/Neut / Dens/ PWD Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised:July 16`h,2010 ODSN-17 Permit To Drill Page 5 of 12 ODSN-17 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Hole Btm Size Tubing Length Top MDrkb/TVDrkb MDrkb 24" 16" 109# H-40 Welded 115 Surface 158 158 . 14-1/2" 11-3/4" 60# L-80 Hydril 521 4440 Surface 4483 3240 11-3/4" 9-5/8" 40# L-80 Hydril 521 6496 4333 10829 5316 8-1/2" 7" 26# L-80 BTC-M 13912 Surface 13955 6147 6-1/8" 4-1/2" 12.6# L-80 Hydril 521 6026 13805 19831 6217 Tubing 2-7/8" 6.4# L-80 IBT-BTC 13762 Surface 13805 6065 Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ' ID Yield (psi) (psi) Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductor casing 11-3/4" 60# L-80 10.772" 10.62" Hydril 521 5830 3180 1384M 1384M 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L-80 6.276" 6.151 Hydril 511 7240 5410 604 M 604 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" Hydril 521 na na 289 M 289 M Pioneer Natural Resources Last Revised:July 16`h,2010 ODSN-17 Permit To Drill Page 6 of 12 Cement Calculations: Casing Size: 11-3/4" Surface Casing-single stage Basis: Lead: 75% excess over gauge hole in permafrost+ 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3,983' MD Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10.0 ppg Dual Spacer Lead 458 bbls/620 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf/sk, 20.0 gps water req. Tail 55 bbls/259 sx of 15.9 ppg Premium "G" +adds. 1.19 cf/sk, 5.23 gps water req. Displ 482 bbls Mud Temp BHST-55° F, BHCT-60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 9-5/8" Intermediate 1 -Drilling Liner-single stage Basis: TOC: 9706' MD-The greater of 500' MD of open hole or 50'above top of Torok 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg Dual Spacer Primary 86 bbls/411 sx Premium "G" +adds. 1.17 cf/sk Displ 563 bbls mud Temp BHST- 135° F, BHCT-110° F Casing Size: 7" Intermediate 2-single stage Basis: TOC: -12761'MD-500' MD above the top of the Kuparuk 40% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 41 bbls/ 197 sx Premium "G" + adds. 1.17 cf/sk Displ 531 bbls mud Temp BHST- 165° F, BHCT-135° F This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok • disposal zone. Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDWI-44. Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 7 of 12 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16"conductor casing. 2. Nipple up spacer spools and riser. , . • 3. MU 14-1/2" Directional Drilling, MWD/LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11-3/4"surface casing. Bump the plug and bring the pressure up to 3500 psi—chart and hold for 30 minute pressure test. Send chart to ODE. . Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Riser, NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 7. MU 10-5/8"x 11-3/4" RSS, MWD/LWD(BHA will be a 10-5/8" pilot hole opened to 11-3/4"while drilling). 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 9. Drill through surface shoe, rathole +20' of new hole and perform LOT to a minimum of 12.5 ppg. 10. Drill 10-5/8"x 11-3/4" Intermediate 1 to casing point. 11. Change one set of pipe rams to 9-5/8"and test BOPE as required. 12. Run 9-5/8"drilling liner on 5" DP. Set liner hanger, release from liner and cement. 13. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 14. Release pressure and ensure floats are holding • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 15. Set liner top packer and test the liner top to 3500 psi for 5 minutes • This will check the integrity of the liner top packer to ensure isolation between the liner and the surface casing • Note the pressure test of the liner top in the morning report Note: The surface casing was pressure tested to 3500 psi for 30 minutes prior to drilling out the surface casing shoe 16. POOH w/5" DP. 17. ND BOPE, ND Drilling spool, NU Mulitbowl Wellhead, & NU BOPE and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test. • Ensure integrity of the liner and the liner top has been verified by a pressure test prior to performing this step 18. MU 8-1/2" RSS, MWD/LWD on 5" DP. RU MPD trip nipple. 19. RIH and cleanout casing to landing collar. 20. Close pipe rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi for 30 minutes --chart and send to ODE. 21. Drill through drilling liner shoe +20'of new hole and perform FIT to 13.5 ppg, 22. RD MPD trip nipple and RU bearing assembly. Drill 8-1/2" Intermediate 2 to casing point. Pioneer Natural Resources Last Revised:July 16`h,2010 ODSN-17 Permit To Drill Page 8 of 12 23. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 24. Change one set of pipe rams to 7"and test BOPE as required. Note: Intermediate casing string may be run as a 7" Iongstring or as a 7" liner with a 7" tieback string to surface depending on drilling conditions. Both options have been provided below: Option#1: 7" Longstring 25. Run and cement the 7"26# L-80 BTC-M intermediate casing. 26. Bump the plug and bring the pressure up to 3500 psi—hold for 5 minute pressure test. Release pressure and ensure floats are holding. 27. LD 5" DP Option#2: 7" Liner with Tie-Back Option 28. Run 7", 26# L-80 Hydril 511 intermediate liner on 5" DP. Set liner hanger, release from liner and cement. Bump the plug and bring the pressure up to 3500 psi—hold for 5 minute pressure test. • This will provide a quick integrity test of the 7" liner. • Note the pressure test in the morning report. 29. Release pressure and ensure floats are holding. • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe. 30. Set liner top packer and test the 9-5/8" liner and 7" liner top packer to 3500 psi for 30 minutes. • This will check the integrity of the 7"liner top packer to ensure isolation between the 7" liner and the 9-5/8"drilling liner. • Note the pressure test of the liner top in the morning report 31. Run 7", 26# L-80 BTC intermediate tie-back to 7"liner-hanger seal bore and space out. 32. Displace diesel freeze protection down 7"annulus to 2,000'tvd with annular preventer closed. 33. Strip through annular preventer and sting into 7" liner-hanger seal bore and land tie-back casing. 34. Pressure test seal assembly to 3500 psi—hold &chart for 30 minutes. 35. Pressure test 7"tie back annulus 3500 psi—hold and chart for 30 minutes. 36. Set and test 7" pack-off. 37. RU MPD trip nipple& PU 4" DP as needed to TD the Production hole section. 38. RIH to landing collar and w/4" DP & mill tooth cleanout bit. 39. Change pipe rams to 4"and test BOPE to 250/4500 psi—Notify AOGCC 48 hours in advance of test. 40. Pressure test casing to 3500 psi—chart and hold for 30 minute pressure test unless previously done in Option #2. Send chart to ODE. 41. Drill through Intermediate 2 shoe and POH w/cleanout assembly. 42. MU 6-1/8" RSS, MWD/LWD drilling assembly on 4" DP and RIH. 43. RD MPD trip nipple and RU bearing assembly. 44. Displace to drill-in-fluid for production lateral. 45. Drill rathole +20' of new hole and perform FIT to 12.5 ppg. 46. Drill 6-1/8" lateral production hole to TD. • Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 9 of 12 47. Circulate and condition hole to run liner. 48. POH to intermediate shoe and set heavy weight balance brine pill. Cont POH to surface. 49. Change one set of pipe rams to 4-1/2"and test BOPE as required. (----- 50. RIH w/4-1/2"solid production liner w/perforated pups from 150' inside the intermediate shoe to TD. N.,.-' yo3 51. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and se...-1".3POOH. 3/a-2.III 52. MU and RIH w/4-1/2"fracture completion string w/GLM's, &SSSV nipple with blanking sleeve. (444 ) W 53. Space out, Land the tubing and RILDS. Install TC. J 54. Pressure test tubing hanger and seals. 55. ND BOPE, NU tree and test to 5,000 psi. Pull TWC. 56. Secure well & release rig. Post-Riq Work 1. Flowback well with gaslift. ' ,`(►',, nedLiel. 2. Fracture stimulate well a u ffU 4a3 ski Complete ODSN-17 1. MIRU ODSN-17. 2. Pull 4 '/2'fracture completion string. 3. MU and RIH w/2-7/8" production completion w/ FSV, ESP, packer, GLM, SCSSSV. 4. Space out, Land the tubing and RILDS. Install TWC. 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. RDMO to next well. Post-Riq Work 1. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 2. RD Slickline. Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 10 of 12 Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1/4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in/out. Pull up into the casing shoe. 5. Perform a Leak Off Test(or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit)with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT/FIT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25—0.50 bpm. Maintain a constant rate. • Record the pressure for every 1/4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. Note: For FIT, do not take to leak off • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the LOT/FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised:July 16th,2010 ODSN-17 Permit To Drill Page 11 of 12 ODSN-17 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened • awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. . Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. • 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. Kick Tolerance/Integrity Testing Kick Tolerance/ Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press 11-3/4" Surface/ 760 bbls 9.8 ppg 2377 12.5 ppg (LOT) 10-50 x 11-3/4" 9-5/8" Drilling Liner/ Infinite 9.8-10.5 ppg 3133 13.5 ppg (FIT), 8-1/2" (12.5 EMW w/MPD) ODSN-17 7.2-8.2 ppg 7" Intermediate/ Infinite (g 8_10.2 EMW w/MPD) . 3168 . 12.5 ppg (FIT) 6-1/8" 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 • Two seismic faults with expected throws of 20' may be encountered around 9,750' -10,500' • MD. Losses may be associated with these faults. • CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) This permit covers ODSN-17 spud to installation of 4-1/2" fracture stimulation string. PNRA intends to pre-produce ODSN-17 prior to the fracture stimulation which will be • requested on a separate 10-403 at a later date. Pioneer Natural Resources Last Revised:July 16`h,2010 ODSN-17 Permit To Drill Page 12 of 12 -I 3D View In X• DWI ODSN.t1 PHI)mad'opt*0(OLSN-17/OLSH-17 DN13 mg) 0 ____........ - ... 500 3000 t►500 I Y 6000 ! 1500 f x000 —OOp --, 00 I I © it .esen 1 n X sQno $OO J 17CN13mod>,p09.b 3.5oa 40•0osow 1-44,oDsow 1-44 Disposal,0050W 1-44 ptsposai VO 0 %500 Eau ■o■ �T' ' �� � ■ O �miO®moo ■■IImi�� - O 4Il - F17446$21111r111 =MIN 111Wrillitilill — -��51i-��►a.■\ O ® ,� Y ,_ El ifi,1„ .. Z 0 N 0 /4 . II I if V , I'd.. ., ,,,,q in 1 , _ 8 1 MN 11111111111111111 Ell • ■ji�►t, I. .4 Mai = III csi N 111 S- _ L FzD r ■� ■ - ._..�.�_K.— -- ., , , :a►1Ei■.o 00 _ i!D Ca1g► 1I■U� I 1 M . ;� wM ®! �� a■O elm, IFI UI�i/1111111 e■ . ► a - �• II MI■��■■■11IL�,■■E■�= •r _ 1 ' + v Lo iiIIIIOI I _ ■I11�1■111ML81 U ° = JuIIIt W _. - -_Ea -.__-_ - O . ___ o + 0 c?i i . rt • LI III.1■■■ �; �r. ` -� M MIMEu? a� 1111.1.1 — LI) Mil_ Y1 Lecin is. 0 ` ISI f i_ o 0 - L. csi 0 0 O O ;E'$P 'jt _!!P_ 'I I 3 I I i CI In I Z - W Z o.r . • ' a W cc O r • ' z cm W = 7 LCj a° O N 0 -.1 N N. I I I � I I I I 1111 I I I I I I I I I I I I 1111 I I I I I I I I I I I I I I I I I I I I I I I I O O O O O O O O O O O O O H 4') O cs,C[) O U) O LL7 O U) O U) O ^/�1. H N- U) Ci' C C- V N- CD N- I) N- C ^.L� Z (will 009 6)(+)43�aN/(-)4hoS Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-17 - Slot ODS-17 ODSN-17 PN13 mid Plan: ODSN-17 PN13 mid wp09.b Standard Proposal Report 12 July, 2010 HALLIBURTON Sperry Drilling Services ly go 0 C --N Z I- I- 1-- 1- I-- I- C- - UU v _ Erna U . N. > .. > > 0 O o p a a a o �i o 0 0 ',8 8 , (o 0 0) 0) (E 0) 0) o z z 2.0 Ozz 9 Z ZZZZZZ °^ U c a� ?0"! _ a a a a a a a rn � 000MO)0m700M0MVNmmmM000 0Mm0M00)00 "0 .E3ia�'ugm S� O —o GO7N7mmM7ml�a7a MOI�NOM MO7m0MN70NOm _ '2 a w 'm-o�V 7mm0mmro��MmVOV V �NM�m _ `U,A,)0 oi _ N - Z00U > �N N077nr0Om ON�LL)m0000�N�NMM SNF u)S' 2i n 0 I"' e,4 ciU ' -__-NMMM777777mOmmrrrm C t 'C _1Z 0 0 N 3a. - 0000M000000000)o N o n o,00\001)m OO RJ O M 00o '>:v r - o Omom • $0000000070No�o�o�o0 omm0000000000 N w� o in 0 E --v_ �, 3N7 N7 FOOcO,)O NOOON vO MOM�O m000�0a 70o001V OniO V)00 = k 0 C m rya ❑ O�ca N \\•� - _ _ __ J z Ee" 0o ii g:t Oo00oo00$4on00000Qp000000000000 � 0 c' 0 N o o a - o m00000Ow000 OMOOONO 000000000000 3 N v p ^ O ❑ W r O y y y e w OGG,-ONNI-OMMOMOM040MOMOf`'MOMMOMMOt`MO z U „� O 0 p� '- p R444_ a J L .S m_ 0 N 2 0� Z ',a_`,' ^r� >OO NNr'20) 0mOM-ONOr7M OLL)MY'irmNr Nl(1�00 1] ��N ( O) N 06 -E W �'' ,a W 3007(00700)ON me•C)N NNn70 rp N0000m 700y(007.N 0 N N d ❑ O �'�EU 0 I� �mmONNo (V�ONIMO'iN.-r(OIC)a.-00000.-c004 O J o'�a ❑ (0 n ) O _N 2'e�3 0 + ,'�Y7I�ao ao wmwmwnnnnn�n(o(o u,u�u,vy - 3 c�7 a 2 0 0 @ I- _ p ! H (/)OO(00)0)0*m0)(0m(07 N Inmm00)O m.-Ow 00)100 0)0000 M I ~O Z - U '£ U OO7N7m MaamnO MOn(VONp M0�00MNVONOO Cry O ❑ I 2 - W Z 0�0�Na�mOmwn Om 70)m 70770 Nor) (0 7' 0\ 'p 0 - O (� + ANN 77rrNMCOi"o'R TM/O)(oo(o(Nor�N�M �o I- rn I- \ W II i 0 —o a .Q Z- o ,m\ c°`o \ I I I - 0) f.000,-MOo4�ONOpMm(N-mm NmC)•-NU')NWI NO'N04 .0 O ` \ I I I + r.000, 0m=MN-1-'2Oa 0) 00toOU)(IN- w o ❑ - w ..-0,,,,,..-........0m,,000.00, C 1 1 II M (41(0VW Wmn 40)OMM Va r 00•-.-0000NNN NNN Q) Q� 30 M ❑ r \ M+ N N w m m m m m m m m m m m m m m m m m m m m 0 3 •G , C 0) IIt 11 0 �� OOOOOOOOONNNNnn OOOOmmOmmnmmOrrnnn a- a + ❑ Iii 75 \ III • = O OIL V00000000000mmMMNN00(+)(+)a 777a4ww N000 O•. \ \ \ 1 II N ?.+ 6000600 OM co06(ni o(�ff O O O O 01f)NN m NO n n n mm mm 0) 0 I� 7 _ _Ur0 MM MMMMON NNN(V(VNnn 770)MM(0(0(0(0(0(0MM MMM ;= (y E �p co \ I1 \\ II II�� - O 8gg 00000000 m•-00NON N-,-NNMMO m0O r r 0.0 000 O Y ZM Z I I —� 0 h COO mm 0000)0)007700 mm wm770001O��0L0 r \ I \ 1' - W 00p 00 (ONOOdNOONNMMwwwm7'OnmmO NNOInu')OMM �0 az \ \ \ I - 33 -�Mnrnnnnrrrrmmm0mmrnrnrn0mmmrn Y� ��a \ I I 1 \ _ 0 d :' E 3N-00000000 to 0NNNNN00 r r.-M7 Mm0N000N00 r i i N..N. \ \ 1 \ 0 -o EE 2NooOeaNedadM� co(o7o)7adcdMm7�c60500vr(tiodo Q Q Z�• I0 1'34\\ _ o MM 7Owwnnrnrm00I707ornaVaOm R8{fpOMM,mM.-Or NNM Iw cc NM7mmm.-NNmO�«NNmMVa7CININIU)WM0Mou W0�0 O O0yZ 111 \5 - 0. baa OO ��O W 0 a'`- O O�NM7mmn 000•-NM7mmnm00�NM OO OO 0 N �\ \\ Al _p > o TZ'Z' - w�NM7mmnm0 00000NNNNNMMMM 0 N ((1\ \ ' - ( - w $ 000 1(n O t0 M ❑ 2\ \ ZZ 6 O (To-• ooN - O 3. N 0 N \ \ \ -u) _ o Lo 525 too a N 0 o ff to (o , I t- (o 17, Nm ❑ I17 co M L8 N. _ co N Q 0 gg C C C C C T C C C C C C MO I O 6 EN-0 r o o o o o o o o-5 0 0 5 5 , p M Cl) -_ a -- E - 0 • • m ON700 waaaaaaaa0aaaaa . m O ap O)mmr\Ommmmm MNN.-N Z 0 n w to COLA.-.-MMMOOMWOON II ❑ ❑ rn o W \ 0. o f6 0 w "oi l�(6N, Mroono(oroi (n 1- m 0 _ in M - O c O H m.-CO 0 N 0 n co o 0 w co o)77 0 - 1 1 Q WNN 0M0.0NNNMl[NN7N-7 ES n , ^ ❑ O M \ 1 :GS\ O O Z 000m0m0000000(O (n W ` N- ❑ \ I \ Q - 0 7777x777777777 0 M Ns - M '2 .0' \I \\A - M Z 0)07.-N0M.-.-,-000.7 p 0 0 COM rn)n n w 0 n n)On�Vm 0 0 (0 0' 0 �_ co \`GAB.\ > - (n '''''''C'c' L Di N 7 I�r r Qi 00 co I� di V o ❑ 72 - O Nn(NOON O 0 m0)YEN 100Nmm r O�m7 - - 2 ❑ N ❑ \0 \ o N U 0. 0.0 o .- t -o \ E o U N.-o)ro ZOommmnrrr7N00M pp o m, c \ M - :C C. MMNNNNNNNNNNNN 1.0 Q 00000000000000 0) i� LW W - 0 0 0 0 O m m m m m m m m m m m 00 M Z' F g59I Cl) m .03001.-II)N WI 01)N- t I- f.- 0 M d 0 5.55P'-0) '/ J �omNo NMr,-,-7(NOrIIm07 0 0 0 ❑- ^ W \`LO9. 1 \ —N 0 Q MN0 NO,-,-00.,00 > > s-, r . \ - I- + rnn mmmmm0 II-nu) F - 2 � O m Co K gOrn7o ° M• N• o) .0 0 y. �. (n mNNM r 0OOmmmmm0000-00) - M o In .'p , II, > - O Q 7m0)m W rn M M 7 N O m m N O M ON W 7 U 7oM0 0 Z 000 co co 0 w 000 m co 0 co IL co V 7. N M C -- —O 0007 +o •0)0)0O0)0)00�ven ~ ❑> >❑> 0 Q w 1• M' - co o(o l-n < X 0 0) f- ❑ 0 o ❑ t I - O Hoo0romoioia 6n.c66 o H M O O O W N Mmmm cp N00o oo opp m�M70 M O n LL� NI N N C I _ O m 00(0(00 �0 00NNN r pp ❑ ❑ C (� (O w I O a s m ❑ 4 d H- 0 M o M Q G �` • .-o d d ❑ O 2 o .- . _7,0 O .E O 2 N Lr 2 T. ; N d O (0 -- N —O 3av7 oO ro O) OO ❑ fA ' m40E7EE Con - N NNoNMM--7mNM0 0 oD. O N 0N -IO 0 r > > _ LNzz i� a >D>i>>>0c00M CO 0 0M EM (") o Oa �o �, o�aaa NMM Co i) 0 0 0 0 W_ 00000(0MMMMM M � \ 7 0 - -_ a 0. ozzzzzOOzzZzzzz 0 ❑ ` L \0) IM 7 ❑ zaaaaaooaaaaaaa 0 v 7- - - OO I .-I0a m , 0 00 \ W __I , - MM = ❑ www m wm t • 0 1 1 1 I 'i _ o m c m 0 1 I I v O. c� i0 —0 J y t W w r. I I I I \ I M r - . Q NN w wym s II OEwL mOOL NN U Q 1 1 n. h\ 1 I O I w 10°- -;, y,2hy S=DY Z 0 \1\99h f� - '� N b \\\ U O —p R O 1"O>>U°O A O a O A A O D U O a `/ M N U ` W wen i-m i-wM I-0) V1.-mY1-Jm 1-V .O J 7 - 0 N Y [s' 04 0 0. .0n Tn(070(007'70070mN0 -4 y N C w .0 N / W `p O mo)(-4u)M0p'•(cmmo)o)a)v)'•v)md- w C' / w?“744C00000)000000)(0N 0 a ra to m y a t a l l (0 Z ��NN MY�Oni000NN(O')t•N')(`N')MMt`0') E f« W m O O O` U 0 2 , I // N - DLa 0 a d 'o N g I- F Io 2 I / V c LUQ, Q .0a ....1. aommmc?au....0. a z' 'O v 5 - m / i O 0, f e iad44Mvin(co)o)Goo O7iolriO u0 p I \ w\ $ �'. I On N Z W y-N m N 0 0 N N 0 to m O M 0 0 0 m F m F // -. I- _ 0 y�NN NM77.... .ul.Wmm I I I I I I I I I I I I I I 1 I I l I I I I I I 1�I1 I I I I�T 11 I I I I ) f`�1 I 1 1 I O a o 0 0 0 0 0 0 0 0 0 0 a LOO000oo00000000000 IOICIN�.-ONa(0mm0dh nh 00 n Nn co N co V 0 (O N a g 0 a I�Iy = mWM000)NNA.M(hh W ONimm044 •- .- N M 1) 7 �' 0u'NN NM77 Y)w Nm Nm NY)mmm C. 1 (u!/u 0096)4Tdea!eo!Tan anal a o, 2 i- p 2 g r E U > i i i i i c c g v :_ a o p v_ p m 8 rn - Z^^ E 5 5 5 E 5 E _§- ->.�,c c c c c c _ .,(7E-3 paj pa, C m N m M M M M M M M a0 a0 a U a0 a0 a0 a0 a0 - �� o �� `m z z z z z z z —g ^yy �, OIL r a a a a a a s m0000MNN N - 7 3$%}3$5 m �.+ CM 000M(000N y U'0 OOOMmmCD0Im ONOMa NO-OOmm00 IOOOMNnm M NOm00 O.j^ ^op�p Qi - ❑ZZ O ii m00�(V 666a6F46aMOr4o4om Mp o6MNaON0N0 W r M S$0 M NNQi a s - O`-"-' O - '01 0 aasa 0000J0,00ce M00. 0e-NMe-W W 0I..I�,,,N,f� Z r '�NNOfa -N000mNa 000,O,CO�N�NMM {5��,�(,N N - C NMMMaaaaa1.18 OI�N� 2 NONONONO28 Z SZ } oo as a a a aaN� _ O agog . ogl- MN+� OOo<oomor.oro.-omoNp ,c,v Oud888o W m y - ZNiA V9 u0000m SSSOa ON070e-0.-OWOW000NSOO O O r C_ 0 I�i�Vj 0,0 a 3 - ��,.,,.I� EE LLoo�o,�o'oocN<dor�dc�'c�o�oNop�o�oc �o'rioo < L 0 a5 O j0 �M_ r 0'N 0000000(0 0a _O � ++ ZZ a p O z�r Ph VNN00N00M _ O A �',1,4,*��+ } NCOaa M w80000000000.-OM 88808880$$888088888 O 0 0 0 0 0 0 0 0 0 _ M q SW O a�� - 00e-ONN,-OMMOMOMOaOMOMOMMOMMOMMOt`MO Q 0t00tD 100000 D ;�B K 8 ,ZZ O o2.04.3‘-,-N001....7 Z r.e.e.t. N O QQ to 300r00r-at0aIN00M�O0.ar--7Ma0M1n I,OONANO�00 a ?I4 4 • N N 0o —8 O g py y 4�X F _J GC�MOam NimNNw7-MN 'f1N OhNNL�O $iSapNG�ODONN 2 N$ y O N O = N WAcii a 0 woo Q �Nr�vO�N�N-a{NUM'IN��NOO NAa� O O� gmNNQ c + 00 ``YY11"''v f�1�N Egli 00N- 1- , 7ri N0OT00TTTTI r�nr�rTTT90ga co N Eg+Fli 0 Lol+Oi b9b O _ 8 7. N��'�` p Cl'm NN O ,OOMmm.,..p.p...VNNf000�mppm0'0$QO_ONOMOm MtOm00 W O0{Omm0(O-Om —8 .7N .N-, �r0 8 N ?OO�fV�N08 e-NNw, rr WO�ou3Nl Vw0 00 N NMM ?MMmmt0momN �;'r • ONO ~ Qom+ _ O lip^ �� "' 0 r.00m.-MOO.*7OI-OO M 00 A 0000 Cl 7 O ONND hNOaNO a a' 8 R N000VMOON.-66. ter• m00��OM NM�O0(NA0i0Nr- Q 0•0 - .N. 0 j C �aNPO')�fOOnDt00.T-NNN00rO t0000 OtOtNOfNOtNOtNOfNOfNO(OtOtOtNpfO(NOtNO w pOOOOOmO.�-M.*00! I // (0„/$ 4Cr'. 00000NNNN�l- -0oo0oo00WW0 p nM0� 00NNrr, O 0 0 0OOOO _ ' ' . p000$OOOmmmNOOMMNNoOMMaaaaaa000mmm m0 :Q — $ I 9 00888§§8muuooaapM"o$ 808$o8w M MNNNNNN a Cl - o 0s N0IA - 1 O m V0$$O188000NNaaSSS8,--8.9VC aNN nn VI , m 80fm0DO0como[N00 .800 E E - _ 0 _-_ 66, -0fGONNMMnA /�� pMM 0 - _ I��������r� .om.gommo..mm — O °00e• g O rr N-NNrrzz - ON-00 ONN0OOMN NNNN 0M1,,,7MaM(0. 0 N000NNO ON- as Cl>>>>>> - • e. ✓ <o,0rrrN,MSSCCp0pMpNar�ON0tda0mDl0WMM,-m"e-0,VM , V V VPVVO �H OOSZ \ ♦ S NMa000NOr-NN7<a00, 0mMa mM0e- .-NmMed 0°000OMO .iEAAAAAA —- 8 \\ \ CO N NOOZZZZZZZ3.* y ezooaaaaaaa - \ • 0) O,-NM*ONON-000ONNMa(NON00OO.-NM - O NA�NM.*505ON 0O NNNNNN NN NNMMMM - O b i ▪z MAN, `�° p 0 -�V \ \\ N N - —00 O N \ \ ^ ^ V 'O - '. r �3 pp \ - • a F F 'Z _o W C.� \ \� N v, en n _ N + - II N - uy �pp \ N p a \Q O Q n r N �' QI _- 0 CO, t500 0, - - .A _ 7, Q I l TA Cg. en G .. - N 1 1 18 = N 0E 5 r11 o $ 3 o . e ,„ °. o r3 p,IV Z 0 U\I•' '0 '0 Opp <V I / / / / / - + .4 _ / / / - in /l^ I mi ///Y, /�// a - oY o N+1 O I / / / / - u'JOOO r ems., qq ' h n G / / // r eE Or-NO0 s h O .a. /M / G I / / x i - N •NO00 / / / / Z ` 8 NO�mf�a O O !+ 'v, a I / W I l/ / / '/ a _a J z- 2 fV W vNOi oG I I l I /l / / // r dO�1�N lT vp, a N �M�pp / / / // / / _ WO �Mn .500 a 5Ni $ i� �' `$ a°°ro ;Ga% % / // // , F - o t / r s o Q V C OQ ,,i .. M M 8s. I I / //// ///t •F u M - QQ 8 ..1 M I I I I / / //. :,2' O i• ' m 000m4a� q N 51 5 i I //`/ //, E dy a L MONO NO I OIM g W 1 {[C]/1 0 1 I I // / / r d• \ - 0 1 SI SpI C I ' I , T r// L 00 Zm - 8 Q - 1 M 1 ♦I // a -- I IQ a %' %/ 'M 1 O O O 0 y Z z o +-I / �./ OOOOy At z ti3' I I % � '; e w% 5i-- ciO = o ems"" 00 ° a g :I3�>: E C kS o a \3� [-vaa Z, - NT D 3 8 'S'48 -_ Q e Ehm e Z C a agmgc OJ W =W rN0 W I I 1 I I I I I I I p I 11 1 1 I 1 1 1 1 8 I 1 I I 18 I I I 1 18 I 11 1 I o I I I 1 1 I I I 1 1 p I 1 1 1 1 pQp l 1 1 1 1 Q I 1 1 I = O g N OOD N M M N S Oa \p N O W a ¢_ o ST (ul/8 OOSI)(+)9uoN/(-)Alnos 2: U -- o o —rn 7 U O) _- m7 - O Zz —co a _ of - zo '' : 0 12 g P W.- o 0 0 `O v s m � y - ,2 k E E. E E E E 01.= - o O o - - -... _CD Q8888"l, $4.Siq$V-8-8Cam8�E.”.ili 8888 Z a as T a 0'4 �nm o0 O N - n8888.S.RSRR MLIISRB$8�8888888ME W Q O _ . m _mom �n ��R6^S�R� m`m�g Z P 7 __._ -. __ —.__..__. _0 ^ T 4444 14^mrnn`n�w 4 TY O CO N CO _ .- %,,,,,, m.m.mmm,knommewgT,,” ,,,, maoo J G N Z H - O pG0-!=i J .7,,88 � n " ,,,,I7,,,!, r ,< nc�tL - o2e mmmcR $6'seemmme8 , e 1; iii 12;4 o _ 888888iOmnR88 -mmR6am -JcO `O _ g 88RR88$RE,82MS.SZKV: s8& --844856 m025m888d.$2dEBaZ " � mq"; Aga$g �� 0 20 G O - M^ ..mto,..^ ^^^^^^maE&Ir«««EEERWSm O - O LL d d~ I 2 OT 7 d=O C , - O C C73.-71�V1 O - .1-ilCe N - O r 7 - .--..O N O sioce \ 0 , C i I - r 4- O - N _ O L - O ` = Y 1\ O - Z _ O = '00 LO-O , U L nm CO O U m j - a (1) LT,cc o o I _I'll \ o :::: T ___ ...._ _O \ .\,„ _- c, -LT � 8. : m m ,\ ' Nagy r J� O N W N O Z 0 2 Z co-2. r N a O _o z0 Z�'r"�n ci a azo h __..... _..\ V • :, u'i 'E • MI' - "'� -'2. O 2 I�' - Q. J d C, O O �Ju Yui N > o$ 11W _ Z 3amof 5 v •• as - o - .......... .6 0 O __ --- - -- oM VWi u u u u o a o rn� to' ;0'0 - Z CCCCr d Or^ 'O W EEE Em O CJ NN N �� O El ▪ w w d w f w a a > �� _ w z�zz"o a cc e o..",.r. --- -,o ' I � c z-_ - oN ? Zoe rnv> „, a ›.. M1` rn m o C a z co - to c 0 u 0 v z E.5 F o G O Z a Z o i- in - c 'vr v o 00 .o v�O O Y a v ,y Y Z _ to C j co A z co D'0.,--: +r. M to I� .. Z O _00 N O f ,0 o Foo Z to Z M CO O O U N ahaO 0 O -O � c O - m o 5; p O OO O A r:0 2 c9 - o cr p Op 1 I I I ' 1 1 1 1 I I I I I I I I I IIITIIIIIIIIIIIIIIII O z 0 O CO O �O O O - O (ui/i.j 06 uoqeiedag aijuao of aqua° T W Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ff Latitude: 70°29'46.242 N From: Map Easting: 469,920.45ft Longitude: 150°14'45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23? Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.0 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +E/-W 0.0 ft Easting: 469,826.11 ft Longitude: 150°14'48.230 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5 ft Wellbore ODSN-17 PN13 mid Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 3/7/2007 23.24 80.81 57,644 Design ODSN-17 PN13 mid wp09.b Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.7 0.0 0.0 180.00 7/12/2010 1:59:27PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 0.00 0.00 0.00 0.00 350.0 1.50 130.00 350.0 293.8 -1.3 1.5 1.00 1.00 0.00 130.00 450.0 1.50 130.00 449.9 393.7 -2.9 3.5 0.00 0.00 0.00 0.00 674.2 3.00 300.00 674.1 617.9 -1.9 0.7 2.00 0.67 75.81 173.33 874.2 7.00 300.00 873.3 817.1 6.8 -14.4 2.00 2.00 0.00 0.00 1,672.8 18.98 300.00 1,650.0 1,593.8 96.4 -169.6 1.50 1.50 0.00 0.00 1,778.5 18.98 300.00 1,750.0 1,693.8 113.6 -199.4 0.00 0.00 0.00 0.00 2,278.5 35.91 289.90 2,192.4 2,136.2 204.9 -409.3 3.50 3.39 -2.02 -20.00 3,483.3 70.80 258.92 2,911.1 2,854.9 216.3 -1,342.2 3.50 2.90 -2.57 -46.40 9,896.2 70.80 258.92 5,020.0 4,963.8 -947.6 -7,285.5 0.00 0.00 0.00 0.00 10,996.2 72.45 222.62 5,366.7 5,310.5 -1,449.3 -8,181.0 3.14 0.15 -3.30 -87.26 11,046.2 72.45 222.62 5,381.8 5,325.6 -1,484.4 -8,213.3 0.00 0.00 0.00 0.00 11,396.2 73.85 210.37 5,483.3 5,427.1 -1,753.2 -8,412.1 3.37 0.40 -3.50 -83.19 11,441.2 73.85 210.37 5,495.8 5,439.6 -1,790.5 -8,434.0 0.00 0.00 0.00 0.00 12,409.0 75.51 170.20 5,761.7 5,705.5 -2,687.6 -8,595.5 4.00 0.17 -4.15 -93.17 12,791.8 75.51 170.20 5,857.5 5,801.3 -3,052.8 -8,532.4 0.00 0.00 0.00 0.00 13,488.7 75.52 145.00 6,034.5 5,978.3 -3,670.9 -8,277.7 3.50 0.00 -3.62 -93.17 13,788.7 75.52 145.00 6,109.5 6,053.3 -3,908.9 -8,111.1 0.00 0.00 0.00 0.00 14,298.1 84.43 132.38 6,198.5 6,142.3 -4,284.0 -7,780.3 3.00 1.75 -2.48 -55.61 14,533.3 84.43 132.38 6,221.3 6,165.1 -4,441.8 -7,607.4 0.00 0.00 0.00 0.00 14,665.4 87.00 135.40 6,231.2 6,174.9 -4,533.1 -7,512.5 3.00 1.95 2.29 49.69 14,731.3 88.98 135.46 6,233.5 6,177.3 -4,580.0 -7,466.3 3.00 3.00 0.09 1.66 15,238.6 88.98 135.46 6,242.5 6,186.3 -4,941.5 -7,110.5 0.00 0.00 0.00 0.00 15,313.8 90.00 137.47 6,243.2 6,187.0 -4,996.0 -7,058.7 3.00 1.36 2.67 63.05 15,386.2 92.17 137.48 6,241.8 6,185.6 -5,049.3 -7,009.8 3.00 3.00 0.010.25 , 16,736.0 92.17 137.48 6,190.7 6,134.5 6,043.5 6,098.2 0.00 0.00 0.000.00 16,816.0 90.00 138.50 6,189.2 6,133.0 -6,102.9 -6,044.7 3.00 -2.71 1.28 154.80 16,964.8 85.54 138.57 6,195.0 6,138.8 -6,214.3 -5,946.2 3.00 -3.00 0.05 179.05 18,177.2 85.54 138.57 6,289.4 6,233.2 -7,120.6 -5,146.5 0.00 0.00 0.00 0.00 18,326.6 90.00 138.97 6,295.2 6,239.0 -7,232.9 -5,048.1 3.00 2.99 0.26 5.03 18,428.9 93.07 138.97 6,292.5 6,236.3 -7,310.0 -4,981.0 3.00 3.00 0.00 0.00 19,830.7 93.07 138.97 6,217.4 6,161.2 -8,366.0 -4,062.0 0.00 0.00 0.00 0.00 7/12/2010 1:59:27PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map M 1 Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) -13.50 1 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,056.25 469,826.11 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,056.25 469,826.11 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,056.25 469,826.11 0.00 0.00 Start Dir 1°/100':200'MD,200'TVD:130°RT TF 300.0 1.00 130.00 300.0 243.8 -0.6 0.7 6,031,055.69 469,826.77 1.00 0.56 350.0 1.50 130.00 350.0 293.8 -1.3 1.5 6,031,054.98 469,827.61 1.00 1.26 End Dir:350'MD,350'ND , 400.0 1.50 130.00 400.0 343.8 -2.1 2.5 6,031,054.14 469,828.61 0.00 2.10 450.0 1.50 130.00 449.9 393.7 -2.9 3.5 6,031,053.29 469,829.61 0.00 2.94 Start Dir 2°/100':450'MD,449.9'TVD 500.0 0.52 142.92 499.9 443.7 -3.5 4.1 6,031,052.69 469,830.24 2.00 3.55 600.0 1.52 296.75 599.9 543.7 -3.3 3.2 6,031,052.93 469,829.33 2.00 3.31 674.2 3.00 300.00 674.1 617.9 -1.9 0.7 6,031,054.35 469,826.78 2.00 1.90 700.0 3.52 300.00 699.8 643.6 -1.2 -0.6 6,031,055.09 469,825.51 2.00 1.16 800.0 5.52 300.00 799.5 743.3 2.8 -7.4 6,031,059.05 469,818.71 2.00 -2.77 874.2 7.00 300.00 873.3 817.1 6.8 -14.4 6,031,063.12 469,811.72 2.00 -6.81 Start Dir 1.5°/100':874.2'MD,873.3'ND 900.0 7.39 300.00 898.9 842.7 8.4 -17.2 6,031,064.75 469,808.93 1.50 -8.43 1,000.0 8.89 300.00 997.9 941.7 15.5 -29.5 6,031,071.88 469,796.71 1.50 -15.51 1,100.0 10.39 300.00 1,096.4 1,040.2 23.9 -44.0 6,031,080.30 469,782.25 1.50 -23.88 1,200.0 11.89 300.00 1,194.6 1,138.4 33.5 -60.7 6,031,090.03 469,765.56 1.50 -33.53 1,300.0 13.39 300.00 1,292.1 1,235.9 44.5 -79.6 6,031,101.04 469,746.66 1.50 -44.47 1,400.0 14.89 300.00 1,389.1 1,332.9 56.7 -100.8 6,031,113.34 469,725.56 1.50 -56.68 1,500.0 16.39 300.00 1,485.4 1,429.2 70.2 -124.1 6,031,126.91 469,702.28 1.50 -70.16 1,600.0 17.89 300.00 1,581.0 1,524.8 84.9 -149.6 6,031,141.74 469,676.83 1.50 -84.89 1,672.8 18.98 300.00 1,650.0 1,593.8 96.4 -169.6 6,031,153.33 469,656.94 1.50 -96.40 i End Dir:1672.8'MD,1650'ND 1,689.7 18.98 300.00 1,666.0 1,609.8 99.1 -174.3 6,031,156.09 469,652.19 0.00 -99.15 Base Permafrost 1,700.0 18.98 300.00 1,675.7 1,619.5 100.8 -177.2 6,031,157.78 469,649.30 0.00 -100.82 1,778.5 18.98 300.00 1,750.0 1,693.8 113.6 -199.3 6,031,170.63 469,627.24 0.00 -113.59 Start Dir 3.5°/100':1778.5'MD,1750'TVD 1,800.0 19.69 299.24 1,770.3 1,714.1 117.1 -205.5 6,031,174.18 469,621.07 3.50 -117.10 1,900.0 23.02 296.28 1,863.4 1,807.2 134.0 -237.8 6,031,191.19 469,588.91 3.50 -133.99 2,000.0 26.39 294.04 1,954.2 1,898.0 151.7 -275.6 6,031,209.06 469,551.14 3.50 -151.71 2,100.0 29.79 292.28 2,042.4 1,986.2 170.2 -318.9 6,031,227.71 469,507.93 3.50 -170.19 2,200.0 33.21 290.85 2,127.7 2,071.5 189.4 -367.5 6,031,247.08 469,459.42 3.50 -189.36 2,278.5 35.91 289.90 2,192.4 2,136.2 204.9 -409.3 6,031,262.75 469,417.73 3.50 -204.86 2,300.0 36.43 288.98 2,209.7 2,153.5 209.1 -421.2 6,031,267.01 469,405.80 3.50 -209.07 2,400.0 38.94 285.00 2,288.8 2,232.6 226.9 -479.7 6,031,285.04 469,347.42 3.50 -226.87 2,407.9 39.15 284.70 2,295.0 2,238.8 228.2 -484.5 6,031,286.35 469,342.59 3.50 -228.15 Top West Sak 2,415.7 39.35 284.41 2,301.0 2,244.8 229.4 -489.2 6,031,287.60 469,337.85 3.50 -229.39 Hue2 tuff 2,500.0 41.58 281.44 2,365.1 2,308.9 241.6 -542.6 6,031,300.02 469,284.59 3.50 -241.59 7/12/2010 1:59:27PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 2,382.14 2,600.0 44.32 278.23 2,438.3 2,382.1 253.2 -609.7 6,031,311.87 469,217.53 3.50 -253.17 2,700.0 47.13 275.33 2,508.2 2,452.0 261.6 -680.8 6,031,320.57 469,146.49 3.50 -261.58 2,800.0 50.02 272.68 2,574.3 2,518.1 266.8 -755.5 6,031,326.07 469,071.74 3.50 -266.78 2,900.0 52.96 270.25 2,636.6 2,580.4 268.8 -833.7 6,031,328.36 468,993.55 3.50 -268.75 3,000.0 55.94 268.01 2,694.7 2,638.5 267.5 -915.1 6,031,327.42 468,912.22 3.50 -267.49 3,100.0 58.96 265.91 2,748.5 2,692.3 263.0 -999.2 6,031,323.27 468,828.06 3.50 -262.99 3,200.0 62.02 263.95 2,797.8 2,741.6 255.3 -1,085.9 6,031,315.91 468,741.37 3.50 -255.28 3,300.0 65.10 262.10 2,842.3 2,786.1 244.4 -1,174.8 6,031,305.38 468,652.47 3.50 -244.39 3,400.0 68.20 260.33 2,881.9 2,825.7 230.3 -1,265.5 6,031,291.71 468,561.71 3.50 -230.35 3,453.3 69.86 259.42 2,901.0 2,844.8 221.6 -1,314.4 6,031,283.16 468,512.71 3.50 -221.60 Tuffacious Shales 3,483.3 70.80 258.92 2,911.1 2,854.9 216.3 -1,342.2 6,031,277.97 468,484.92 3.50 -216.29 End Dir:3483.3'MD,2911.1'ND 3,500.0 70.80 258.92 2,916.6 2,860.4 213.3 -1,357.7 6,031,275.00 468,469.44 0.00 -213.26 3,600.0 70.80 258.92 2,949.5 2,893.3 195.1 -1,450.4 6,031,257.23 468,376.69 0.00 -195.11 3,700.0 70.80 258.92 2,982.4 2,926.2 177.0 -1,543.0 6,031,239.46 468,283.95 0.00 -176.96 I 3,800.0 70.80 258.92 3,015.3 2,959.1 158.8 -1,635.7 6,031,221.69 468,191.21 0.00 -158.81 3,900.0 70.80 258.92 3,048.1 2,991.9 140.7 -1,728.4 6,031,203.92 468,098.47 0.00 -140.66 ' 4,000.0 70.80 258.92 3,081.0 3,024.8 122.5 -1,821.1 6,031,186.14 468,005.73 0.00 -122.51 4,100.0 70.80 258.92 3,113.9 3,057.7 104.4 -1,913.8 6,031,168.37 467,912.99 0.00 -104.37 4,200.0 70.80 258.92 3,146.8 3,090.6 86.2 -2,006.4 6,031,150.60 467,820.25 0.00 -86.22 4,300.0 70.80 258.92 3,179.7 3,123.5 68.1 -2,099.1 6,031,132.83 467,727.51 0.00 -68.07 4,400.0 70.80 258.92 3,212.6 3,156.4 49.9 -2,191.8 6,031,115.06 467,634.76 0.00 -49.92 4,483.4 70.80 258.92 3,240.0 3,183.8 34.8 -2,269.1 6,031,100.23 467,557.39 0.00 -34.78 SCP-11 3/4" 4,500.0 70.80 258.92 3,245.5 3,189.3 31.8 -2,284.5 6,031,097.29 467,542.02 0.00 -31.77 4,600.0 70.80 258.92 3,278.3 3,222.1 13.6 -2,377.1 6,031,079.52 467,449.28 0.00 -13.62 4,700.0 70.80 258.92 3,311.2 3,255.0 -4.5 -2,469.8 6,031,061.75 467,356.54 0.00 4.53 4,800.0 70.80 258.92 3,344.1 3,287.9 -22.7 -2,562.5 6,031,043.98 467,263.80 0.00 22.68 4,900.0 70.80 258.92 3,377.0 3,320.8 -40.8 -2,655.2 6,031,026.21 467,171.06 0.00 40.83 5,000.0 70.80 258.92 3,409.9 3,353.7 -59.0 -2,747.9 6,031,008.43 467,078.32 0.00 58.98 5,100.0 70.80 258.92 3,442.8 3,386.6 -77.1 -2,840.5 6,030,990.66 466,985.58 0.00 77.13 j 5,200.0 70.80 258.92 3,475.6 3,419.4 -95.3 -2,933.2 6,030,972.89 466,892.83 0.00 95.27 1 5,300.0 70.80 258.92 3,508.5 3,452.3 -113.4 -3,025.9 6,030,955.12 466,800.09 0.00 113.42 5,400.0 70.80 258.92 3,541.4 3,485.2 -131.6 -3,118.6 6,030,937.35 466,707.35 0.00 131.57 5,500.0 70.80 258.92 3,574.3 3,518.1 -149.7 -3,211.2 6,030,919.58 466,614.61 0.00 149.72 5,600.0 70.80 258.92 3,607.2 3,551.0 -167.9 -3,303.9 6,030,901.81 466,521.87 0.00 167.87 5,700.0 70.80 258.92 3,640.1 3,583.9 -186.0 -3,396.6 6,030,884.04 466,429.13 0.00 186.02 I 5,800.0 70.80 258.92 3,673.0 3,616.8 -204.2 -3,489.3 6,030,866.27 466,336.39 0.00 204.17 5,900.0 70.80 258.92 3,705.8 3,649.6 -222.3 -3,582.0 6,030,848.50 466,243.65 0.00 222.32 6,000.0 70.80 258.92 3,738.7 3,682.5 -240.5 -3,674.6 6,030,830.73 466,150.90 0.00 240.47 6,100.0 70.80 258.92 3,771.6 3,715.4 -258.6 -3,767.3 6,030,812.95 466,058.16 0.00 258.62 6,200.0 70.80 258.92 3,804.5 3,748.3 -276.8 -3,860.0 6,030,795.18 465,965.42 0.00 276.76 6,300.0 70.80 258.92 3,837.4 3,781.2 -294.9 -3,952.7 6,030,777.41 465,872.68 0.00 294.91 6,400.0 70.80 258.92 3,870.3 3,814.1 -313.1 -4,045.3 6,030,759.64 465,779.94 0.00 313.06 7/12/2010 1:59:27PM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 3,846.96 6,500.0 70.80 258.92 3,903.2 3,847.0 -331.2 -4,138.0 6,030,741.87 465,687.20 0.00 331.21 6,600.0 70.80 258.92 3,936.0 3,879.8 -349.4 -4,230.7 6,030,724.10 465,594.46 0.00 349.36 6,700.0 70.80 258.92 3,968.9 3,912.7 -367.5 -4,323.4 6,030,706.33 465,501.72 0.00 367.51 6,800.0 70.80 258.92 4,001.8 3,945.6 -385.7 -4,416.1 6,030,688.56 465,408.97 0.00 385.66 6,900.0 70.80 258.92 4,034.7 3,978.5 -403.8 -4,508.7 6,030,670.79 465,316.23 0.00 403.81 7,000.0 70.80 258.92 4,067.6 4,011.4 -422.0 -4,601.4 6,030,653.02 465,223.49 0.00 421.96 7,100.0 70.80 258.92 4,100.5 4,044.3 -440.1 -4,694.1 6,030,635.24 465,130.75 0.00 440.11 7,200.0 70.80 258.92 4,133.4 4,077.2 -458.3 -4,786.8 6,030,617.47 465,038.01 0.00458.26 7,300.0 70.80 258.92 4,166.2 4,110.0 -476.4 -4,879.4 6,030,599.70 464,945.27 0.00 476.40 7,400.0 70.80 258.92 4,199.1 4,142.9 -494.6 -4,972.1 6,030,581.93 464,852.53 0.00 494.55 7,500.0 70.80 258.92 4,232.0 4,175.8 -512.7 -5,064.8 6,030,564.16 464,759.79 0.00 512.70 7,600.0 70.80 258.92 4,264.9 4,208.7 -530.9 -5,157.5 6,030,546.39 464,667.04 0.00 530.85 7,621.6 70.80 258.92 4,272.0 4,215.8 -534.8 -5,177.5 6,030,542.55 464,647.02 0.00 534.77 Brook 2B 7,700.0 70.80 258.92 4,297.8 4,241.6 -549.0 -5,250.2 6,030,528.62 464,574.30 0.00 549.00 7,800.0 70.80 258.92 4,330.7 4,274.5 -567.1 -5,342.8 6,030,510.85 464,481.56 0.00 567.15 7,900.0 70.80 258.92 4,363.6 4,307.4 -585.3 -5,435.5 6,030,493.08 464,388.82 0.00 585.30 8,000.0 70.80 258.92 4,396.4 4,340.2 -603.4 -5,528.2 6,030,475.31 464,296.08 0.00 603.45 8,100.0 70.80 258.92 4,429.3 4,373.1 -621.6 -5,620.9 6,030,457.54 464,203.34 0.00 621.60 8,200.0 70.80 258.92 4,462.2 4,406.0 -639.7 -5,713.5 6,030,439.76 464,110.60 0.00 639.75 8,300.0 70.80 258.92 4,495.1 4,438.9 -657.9 -5,806.2 6,030,421.99 464,017.86 0.00 657.90 8,400.0 70.80 258.92 4,528.0 4,471.8 -676.0 -5,898.9 6,030,404.22 463,925.11 0.00 676.04 8,500.0 70.80 258.92 4,560.9 4,504.7 -694.2 -5,991.6 6,030,386.45 463,832.37 0.00 694.19 8,600.0 70.80 258.92 4,593.8 4,537.6 -712.3 -6,084.3 6,030,368.68 463,739.63 0.00 712.34 8,700.0 70.80 258.92 4,626.6 4,570.4 -730.5 -6,176.9 6,030,350.91 463,646.89 0.00 730.49 8,800.0 70.80 258.92 4,659.5 4,603.3 -748.6 -6,269.6 6,030,333.14 463,554.15 0.00 748.64 8,900.0 70.80 258.92 4,692.4 4,636.2 -766.8 -6,362.3 6,030,315.37 463,461.41 0.00 766.79 9,000.0 70.80 258.92 4,725.3 4,669.1 -784.9 -6,455.0 6,030,297.60 463,368.67 0.00 784.94 9,100.0 70.80 258.92 4,758.2 4,702.0 -803.1 -6,547.6 6,030,279.83 463,275.93 0.00 803.09 9,200.0 70.80 258.92 4,791.1 4,734.9 -821.2 -6,640.3 6,030,262.06 463,183.18 0.00 821.24 9,300.0 70.80 258.92 4,824.0 4,767.8 -839.4 -6,733.0 6,030,244.28 463,090.44 0.00 839.39 9,400.0 70.80 258.92 4,856.8 4,800.6 -857.5 -6,825.7 6,030,226.51 462,997.70 0.00 857.54 9,500.0 70.80 258.92 4,889.7 4,833.5 -875.7 -6,918.4 6,030,208.74 462,904.96 0.00 875.68 9,600.0 70.80 258.92 4,922.6 4,866.4 -893.8 -7,011.0 6,030,190.97 462,812.22 0.00 893.83 9,700.0 70.80 258.92 4,955.5 4,899.3 -912.0 -7,103.7 6,030,173.20 462,719.48 0.00 911.98 9,756.3 70.80 258.92 4,974.0 4,917.8 -922.2 -7,155.9 6,030,163.20 462,667.29 0.00 922.20 Top Torok Sand 9,800.0 70.80 258.92 4,988.4 4,932.2 -930.1 -7,196.4 6,030,155.43 462,626.74 0.00 930.13 1 9,896.2 70.80 258.92 5,020.0 4,963.8 -947.6 -7,285.5 6,030,138.34 462,537.56 0.00 947.58 Start Dir 3.14°I100':9896.2'MD,5020'TVD-PN13mid Curve 4 9,900.0 70.81 258.79 5,021.3 4,965.1 -948.3 -7,289.1 6,030,137.65 462,534.00 3.12 948.29 9,907.0 70.82 258.56 5,023.6 4,967.4 -949.6 -7,295.6 6,030,136.38 462,527.48 3.12 949.59 PN13mid Curve 3 10,000.0 70.96 255.49 5,054.0 4,997.8 -969.3 -7,381.2 6,030,117.01 462,441.82 3.12 969.31 10,100.0 71.11 252.19 5,086.5 5,030.3 -995.6 -7,472.0 6,030,091.07 462,350.90 3.12 995.62 7/12/2010 1:59:27PM Page 6 COMPASS 2003.16 Build 428 Halliburton Company HALLIBLIRTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section 1 (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,062.58 10,200.0 71.26 248.89 5,118.8 5,062.6 -1,027.1 -7,561.2 6,030,059.91 462,261.54 3.13 1,027.14 10,300.0 71.41 245.59 5,150.8 5,094.6 -1,063.8 -7,648.6 6,030,023.62 462,174.05 3.13 1,063.79 10,306.9 71.42 245.36 5,153.0 5,096.8 -1,066.5 -7,654.6 6,030,020.92 462,168.06 3.14 1,066.52 Base Torok Sand 10,400.0 71.56 242.29 5,182.5 5,126.3 -1,105.4 -7,733.7 6,029,982.33 462,088.72 3.13 1,105.43 10,500.0 71.71 238.99 5,214.1 5,157.9 -1,152.0 -7,816.5 6,029,936.15 462,005.84 3.14 1,151.95 10,600.0 71.86 235.69 5,245.3 5,189.1 -1,203.2 -7,896.4 6,029,885.23 461,925.68 3.14 1,203.20 10,700.0 72.01 232.39 5,276.3 5,220.1 -1,259.0 -7,973.4 6,029,829.73 461,848.52 3.14 1,259.02 10,796.4 72.16 229.21 5,306.0 5,249.8 -1,317.0 -8,044.4 6,029,772.07 461,777.22 3.14 1,316.97 Torok Shale 1 10,800.0 72.16 229.09 5,307.1 5,250.9 -1,319.2 -8,047.0 6,029,769.84 461,774.61 3.15 1,319.22 10,829.1 72.20 228.13 5,316.0 5,259.8 -1,337.5 -8,067.8 6,029,751.63 461,753.78 3.15 1,337.51 ICP1 -9 5/8" 10,900.0 72.31 225.79 5,337.6 5,281.4 -1,383.6 -8,117.2 6,029,705.73 461,704.22 3.15 1,383.62 10,996.2 72.45 222.62 5,366.7 5,310.5 -1,449.3 -8,181.1 6,029,640.28 461,640.04 3.15 1,449.33 End Dir:10996.2'MD,5366.7'TVD 1 11,000.0 72.45 222.62 5,367.9 5,311.7 -1,452.0 -8,183.5 6,029,637.63 461,637.58 0.00 1,452.00 11,046.2 72.45 222.62 5,381.8 5,325.6 -1,484.4 -8,213.4 6,029,605.34 461,607.62 0.00 1,484.41 Start Dir 3.37°/100':11046.2'MD,5381.8'TVD 11,100.0 72.67 220.74 5,397.9 5,341.7 -1,522.7 -8,247.5 6,029,567.15 461,573.35 3.37 1,522.75 11,200.0 73.07 217.24 5,427.4 5,371.2 -1,597.0 -8,307.6 6,029,493.13 461,512.94 3.37 1,597.02 11,300.0 73.47 213.74 5,456.2 5,400.0 -1,675.0 -8,363.2 6,029,415.40 461,457.05 3.38 1,674.98 11,396.2 73.85 210.37 5,483.3 5,427.1 -1,753.2 -8,412.2 6,029,337.37 461,407.75 3.38 1,753.21 End Dir:11396.2'MD,5483.3'TVD 11,400.0 73.85 210.37 5,484.3 5,428.1 -1,756.4 -8,414.0 6,029,334.23 461,405.90 0.00 1,756.36 11,441.2 73.85 210.37 5,495.8 5,439.6 -1,790.5 -8,434.0 6,029,300.17 461,385.75 0.00 1,790.51 Start Dir 4°l100':11441.2'MD,5495.8'TVD 11,500.0 73.73 207.92 5,512.2 5,456.0 -1,839.8 -8,461.5 6,029,250.98 461,358.06 4.00 1,839.82 11,600.0 73.60 203.76 5,540.3 5,484.1 -1,926.2 -8,503.3 6,029,164.81 461,315.90 4.00 1,926.17 11,700.0 73.55 199.59 5,568.6 5,512.4 -2,015.3 -8,538.7 6,029,075.85 461,280.13 4.00 2,015.28 11,774.7 73.57 196.47 5,589.8 5,533.6 -2,083.4 -8,560.9 6,029,007.82 461,257.68 4.00 2,083.41 PN13mid Curve test 1 11,800.0 73.58 195.42 5,596.9 5,540.7 -2,106.7 -8,567.6 6,028,984.52 461,250.92 4.00 2,106.73 11,900.0 73.70 191.25 5,625.1 5,568.9 -2,200.1 -8,589.7 6,028,891.28 461,228.43 4.00 2,200.07 11,955.1 73.79 188.95 5,640.5 5,584.3 -2,252.2 -8,599.0 6,028,839.22 461,218.93 4.00 2,252.18 PN13mid Curve 5 12,000.0 73.89 187.09 5,653.0 5,596.8 -2,294,8 -8,605.0 6,028,796.58 461,212.75 4.00 2,294.85 12,100.0 74.17 182.94 5,680.5 5,624.3 -2,390.6 -8,613.4 6,028,700.87 461,203.97 4.00 2,390.60 12,200.0 74.52 178.80 5,707.5 5,651.3 -2,486.9 -8,614.8 6,028,604.63 461,202.12 4.00 2,486.85 ' 12,239.4 74.68 177.17 5,718.0 5,661.8 -2,524.8 -8,613.5 6,028,566.69 461,203.30 4.00 2,524.80 Top HRZ 12,300.0 74.95 174.68 5,733.9 5,677.7 -2,583.1 -8,609.3 6,028,508.33 461,207.22 4.00 2,583.15 12,400.0 75.46 170.57 5,759.4 5,703.2 -2,679.0 -8,596.9 6,028,412.43 461,219.24 4.00 2,679.01 12,409.0 75.51 170.20 5,761.7 5,705.5 -2,687.6 -8,595.5 6,028,403.84 461,220.66 4.00 2,687.60 End Dir:12409'MD,5761.7'TVD 7/12/2010 1:59:27PM Page 7 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E!-W Northing Fasting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,725.32 12,488.3 75.51 170.20 5,781.5 5,725.3 -2,763.2 -8,582.4 6,028,328.17 461,233.41 0.00 2,763.22 PN13mid Curve 1 wp11 12,500.0 75.51 170.20 5,784.5 5,728.3 -2,774.4 -8,580.5 6,028,316.97 461,235.30 0.01 2,774.42 12,600.0 75.51 170.20 5,809.5 5,753.3 -2,869.8 -8,564.0 6,028,221.50 461,251.38 0.00 2,869.82 12,700.0 75.51 170.20 5,834.5 5,778.3 -2,965.2 -8,547.5 6,028,126.04 461,267.47 0.00 2,965.23 12,709.9 75.51 170.20 5,837.0 5,780.8 -2,974.7 -8,545.9 6,028,116.56 461,269.07 0.00 2,974.71 Base HRZ 12,791.8 75.51 170.20 5,857.5 5,801.3 -3,052.8 -8,532.4 6,028,038.41 461,282.24 0.00 3,052.81 Start Dir 3.5°/100':12791.8'MD,5857.5'TVD 12,800.0 75.49 169.91 5,859.5 5,803.3 -3,060.6 -8,531.0 6,028,030.58 461,283.57 3.48 3,060.63 12,900.0 75.33 166.30 5,884.7 5,828.5 -3,155.3 -8,511.1 6,027,935.83 461,303.14 3.50 3,155.31 13,000.0 75.22 162.68 5,910.2 5,854.0 -3,248.5 -8,485.2 6,027,842.56 461,328.62 3.50 3,248.48 13,065.9 75.19 160.29 5,927.0 5,870.8 -3,308.9 -8,465.0 6,027,782.06 461,348.61 3.50 3,308.91 Kalubik Mkr 13,100.0 75.17 159.06 5,935.7 5,879.5 -3,339.8 -8,453.6 6,027,751.12 461,359.92 3.50 3,339.81 13,200.0 75.18 155.44 5,961.3 5,905.1 -3,428.9 -8,416.2 6,027,661.84 461,396.94 3.50 3,428.94 13,261.4 75.21 153.21 5,977.0 5,920.8 -3,482.5 -8,390.4 6,027,608.23 461,422.45 3.50 3,482.46 Top Kup C 13,265.3 75.22 153.07 5,978.0 5,921.8 -3,485.8 -8,388.7 6,027,604.84 461,424.14 3.50 3,485.84 LCU 13,300.0 75.25 151.82 5,986.8 5,930.6 -3,515.5 -8,373.2 6,027,575.07 461,439.52 3.50 3,515.55 13,400.0 75.37 148.20 6,012.2 5,956.0 -3,599.3 -8,324.9 6,027,491.12 461,487.52 3.50 3,599.31 13,488.7 75.52 145.00 6,034.5 5,978.3 -3,671.0 -8,277.6 6,027,419.27 461,534.48 3.50 3,670.98 End Dir:13488.7'MD,6034.5'ND 13,500.0 75.52 145.00 6,037.3 5,981.1 -3,679.9 -8,271.4 6,027,410.29 461,540.71 0.00 3,679.94 13,600.0 75.52 145.00 6,062.3 6,006.1 -3,759.3 -8,215.8 6,027,330.76 461,595.92 0.00 3,759.25 13,611.1 75.52 145.00 6,065.1 6,008.9 -3,768.1 -8,209.7 6,027,321.92 461,602.06 0.00 3,768.06 ODSN-17 PN13 mid GeoPoly 13,700.0 75.52 145.00 6,087.3 6,031.1 -3,838.6 -8,160.3 6,027,251.23 461,651.13 0.00 3,838.57 13,705.7 75.52 145.00 6,088.8 6,032.6 -3,843.0 -8,157.2 6,027,246.73 461,654.25 0.00 3,843.05 ODSN-17 PN13 mid DD Poly 13,738.6 75.52 145.00 6,097.0 6,040.8 -3,869.2 -8,138.8 6,027,220.50 461,672.46 0.00 3,869.21 BCU 13,788.7 75.52 145.00 6,109.5 6,053.3 -3,908.9 -8,111.1 6,027,180.71 461,700.08 0.00 3,908.89 Start Dir 3°/100':13788.7'MD,6109.5'TVD-PN13mid v7 T1 -PN13mid v7 T1 1/4 mile radius 13,800.0 75.71 144.71 6,112.3 6,056.1 -3,917.9 -8,104.7 6,027,171.71 461,706.36 3.00 3,917.87 13,900.0 77.42 142.18 6,135.6 6,079.4 -3,996.0 -8,046.8 6,027,093.37 461,763.97 3.00 3,995.98 13,930.2 77.94 141.42 6,142.0 6,085.8 -4,019.2 -8,028.6 6,027,070.11 461,782.12 3.00 4,019.16 Top Nuiqsut 13,954.6 78.37 140.81 6,147.0 6,090.8 -4,037.7 -8,013.6 6,027,051.50 461,797.01 3.00 4,037.72 ICP2-7" 14,000.0 79.16 139.68 6,155.9 6,099.7 -4,072.0 -7,985.1 6,027,017.12 461,825.37 3.00 4,071.99 14,100.0 80.91 137.20 6,173.2 6,117.0 -4,145.7 -7,919.7 6,026,943.18 461,890.40 3.00 4,145.67 14,200.0 82.68 134.76 6,187.4 6,131.2 -4,216.8 -7,851.0 6,026,871.74 461,958.88 3.00 4,216.83 14,298.1 84.43 132.38 6,198.5 6,142.3 -4,284.0 -7,780.3 6,026,804.29 462,029.22 3.00 4,284.01 End Dir:14298.1'MD,6198.5'ND 7/1212010 1:59:27PM Page 8 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Veil Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,14244 14,300.0 84.43 132.38 6,198.6 6,142.4 -4,285.3 -7,778.9 6,026,803.01 462,030.62 0.00 4,285.28 14,400.0 84.43 132.38 6,208.3 6,152.1 -4,352.4 -7,705.4 6,026,735.64 462,103.86 0.00 4,352.36 14,500.0 84.43 132.38 6,218.0 6,161.8 -4,419.4 -7,631.9 6,026,668.27 462,177.11 0.00 4,419.44 14,533.3 84.43 132.38 6,221.3 6,165.1 -4,441.8 -7,607.4 6,026,645.83 462,201.50 0.00 4,441.78 Start Dir 3°/100':14533.3'MD,6221.37VD 14,600.0 85.73 133.91 6,227.0 6,170.8 -4,487.2 -7,558.9 6,026,600.20 462,249.79 3.00 4,487.22 14,665.4 87.00 135.40 6,231.2 6,174.9 -4,533.1 -7,512.5 6,026,554.16 462,296.02 3.00 4,533.08 I' PN13mid v7 T2 14,700.0 88.04 135.43 6,232.6 6,176.4 -4,557.7 -7,488.2 6,026,529.43 462,320.19 3.00 4,557.71 14,731.3 88.98 135.46 6,233.5 6,177.3 -4,580.0 -7,466.3 6,026,507.05 462,342.05 3.00 4,580.00 End Dir:14731.3'MD,6233.5'ND 14,800.0 88.98 135.46 6,234.7 6,178.5 -4,629.0 -7,418.1 6,026,457.91 462,390.03 0.00 4,628.96 14,900.0 88.98 135.46 6,236.5 6,180.3 -4,700.2 -7,348.0 6,026,386.37 462,459.87 0.00 4,700.22 15,000.0 88.98 135.46 6,238.3 6,182.1 -4,771.5 -7,277.8 6,026,314.83 462,529.70 0.00 4,771.48 15,100.0 88.98 135.46 6,240.1 6,183.9 -4,842.7 -7,207.7 6,026,243.29 462,599.54 0.00 4,842.74 15,200.0 88.98 135.46 6,241.8 6,185.6 -4,914.0 -7,137.6 6,026,171.75 462,669.37 0.00 4,914.01 15,238.6 88.98 135.46 6,242.5 6,186.3 -4,941.5 -7,110.5 6,026,144.14 462,696.33 0.00 4,941.51 Start Dir 3°/100':15238.6'MD,6242.5'TVD 15,300.0 89.81 137.10 6,243.2 6,187.0 -4,985.9 -7,068.1 6,026,099.60 462,738.58 3.00 4,985.88 15,313.8 90.00 137.47 6,243.2 6,187.0 -4,996.0 -7,058.7 6,026,089.41 462,747.91 3.00 4,996.04 PN13mid v7 T3 15,386.2 92.17 137.48 6,241.8 6,185.6 -5,049.4 -7,009.8 6,026,035.89 462,796.60 3.00 5,049.37 i End Dir:15386.2'MD,6241.8'ND 15,400.0 92.17 137.48 6,241.3 6,185.1 -5,059.5 -7,000.5 6,026,025.69 462,805.88 0.00 5,059.53 15,500.0 92.17 137.48 6,237.5 6,181.3 -5,133.2 -6,932.9 6,025,951.77 462,873.11 0.00 5,133.18 15,600.0 92.17 137.48 6,233.7 6,177.5 -5,206.8 -6,865.4 6,025,877.85 462,940.34 0.00 5,206.83 15,700.0 92.17 137.48 6,229.9 6,173.7 -5,280.5 -6,797.8 6,025,803.94 463,007.57 0.00 5,280.48 15,800.0 92.17 137.48 6,226.2 6,170.0 -5,354.1 -6,730.3 6,025,730.02 463,074.80 0.00 5,354.13 15,900.0 92.17 137.48 6,222.4 6,166.2 -5,427.8 -6,662.8 6,025,656.10 463,142.03 0.00 5,427.78 16,000.0 92.17 137.48 6,218.6 6,162.4 -5,501.4 -6,595.2 6,025,582.19 463,209.26 0.00 5,501.43 16,100.0 92.17 137.48 6,214.8 6,158.6 -5,575.1 -6,527.7 6,025,508.27 463,276.49 0.00 5,575.08 16,200.0 92.17 137.48 6,211.0 6,154.8 -5,648.7 -6,460.2 6,025,434.35 463,343.72 0.00 5,648.73 16,300.0 92.17 137.48 6,207.2 6,151.0 -5,722.4 -6,392.6 6,025,360.44 463,410.96 0.00 5,722.38 16,400.0 92.17 137.48 6,203.4 6,147.2 -5,796.0 -6,325.1 6,025,286.52 463,478.19 0.00 5,796.04 16,500.0 92.17 137.48 6,199.7 6,143.5 -5,869.7 -6,257.6 6,025,212.60 463,545.42 0.00 5,869.69 16,600.0 92.17 137.48 6,195.9 6,139.7 -5,943.3 -6,190.0 6,025,138.69 463,612.65 0.00 5,943.34 16,700.0 92.17 137.48 6,192.1 6,135.9 -6,017.0 -6,122.5 6,025,064.77 463,679.88 0.00 6,016.99 16,736.0 92.17 137.48 6,190.7 6,134.5 -6,043.5 -6,098.2 6,025,038.16 463,704.08 0.00 6,043.50 Start Dir 3°/100':16736'MD,6190.7'TVD 16,800.0 90.43 138.30 6,189.3 6,133.1 -6,091.0 -6,055.3 6,024,990.53 463,746.79 3.00 6,090.96 16,816.0 90.00 138.50 6,189.2 6,133.0 -6,102.9 -6,044.7 6,024,978.56 463,757.33 3.00 6,102.89 PN13mid v7 T4 16,900.0 87.48 138.54 6,191.0 6,134.8 -6,165.8 -5,989.0 6,024,915.39 463,812.72 3.00 6,165.84 1 16,964.8 85.54 138.57 6,195.0 6,138.8 -6,214.3 -5,946.2 6,024,866.74 463,855.33 3.00 6,214.32 End Dir:16964.8'MD,6195'ND 7/12/2010 1:59:27PM Page 9 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,141.54 17,000.0 85.54 138.57 6,197.7 6,141.5 -6,240.6 -5,923.0 6,024,840.34 463,878.44 0.00 6,240.64 17,100.0 85.54 138.57 6,205.5 6,149.3 -6,315.4 -5,857.0 6,024,765.32 463,944.09 0.00 6,315.39 17,200.0 85.54 138.57 6,213.3 6,157.1 -6,390.1 -5,791.1 6,024,690.31 464,009.74 0.00 6,390.14 17,300.0 85.54 138.57 6,221.1 6,164.9 -6,464.9 -5,725.1 6,024,615.30 464,075.40 0.00 6,464.90 17,400.0 85.54 138.57 6,228.9 6,172.7 -6,539.6 -5,659.1 6,024,540.28 464,141.05 0.00 6,539.65 17,500.0 85.54 138.57 6,236.7 6,180.5 -6,614.4 -5,593.2 6,024,465.27 464,206.70 0.00 6,614.40 17,600.0 85.54 138.57 6,244.4 6,188.2 -6,689.2 -5,527.2 6,024,390.26 464,272.36 0.00 6,689.16 17,700.0 85.54 138.57 6,252.2 6,196.0 -6,763.9 -5,461.2 6,024,315.24 464,338.01 0.00 6,763.91 17,800.0 85.54 138.57 6,260.0 6,203.8 -6,838.7 -5,395.3 6,024,240.23 464,403.67 0.00 6,838.66 17,900.0 85.54 138.57 6,267.8 6,211.6 -6,913.4 -5,329.3 6,024,165.22 464,469.32 0.00 6,913.42 18,000.0 85.54 138.57 6,275.6 6,219.4 -6,988.2 -5,263.3 6,024,090.21 464,534.97 0.00 6,988.17 18,100.0 85.54 138.57 6,283.4 6,227.2 -7,062.9 -5,197.4 6,024,015.19 464,600.63 0.00 7,062.93 18,177.2 85.54 138.57 6,289.4 6,233.2 -7,120.6 -5,146.5 6,023,957.28 464,651.31 0.00 7,120.63 Start Dir 3°/100':18177.2'MD,6289.4'TVD 18,200.0 86.22 138.63 6,291.0 6,234.8 -7,137.7 -5,131.4 6,023,940.16 464,666.28 3.00 7,137.69 18,300.0 89.20 138.90 6,295.0 6,238.8 -7,212.8 -5,065.6 6,023,864.77 464,731.82 3.00 7,212.83 18,326.6 90.00 138.97 6,295.2 6,239.0 -7,232.9 -5,048.1 6,023,844.64 464,749.22 3.00 7,232.89 PN13mid v7 T5 18,400.0 92.20 138.97 6,293.8 6,237.6 -7,288.2 -4,999.9 6,023,789.11 464,797.16 3.00 7,288.24 18,428.9 93.07 138.97 6,292.5 6,236.3 -7,310.0 -4,981.0 6,023,767.25 464,816.02 3.00 7,310.01 End Dir:18428.9'MD,6292.5'TVD 18,500.0 93.07 138.97 6,288.7 6,232.5 -7,363.6 -4,934.4 6,023,713.51 464,862.41 0.00 7,363.57 18,600.0 93.07 138.97 6,283.3 6,227.1 -7,438.9 -4,868.8 6,023,637.93 464,927.65 0.00 7,438.89 18,700.0 93.07 138.97 6,278.0 6,221.8 -7,514.2 -4,803.2 6,023,562.35 464,992.89 0.00 7,514.22 18,800.0 93.07 138.97 6,272.6 6,216.4 -7,589.5 -4,737.7 6,023,486.77 465,058.13 0.00 7,589.54 18,900.0 93.07 138.97 6,267.2 6,211.0 -7,664.9 -4,672.1 6,023,411.18 465,123.38 0.00 7,664.87 19,000.0 93.07 138.97 6,261.9 6,205.7 -7,740.2 -4,606.6 6,023,335.60 465,188.62 0.00 7,740.19 19,100.0 93.07 138.97 6,256.5 6,200.3 -7,815.5 -4,541.0 6,023,260.02 465,253.86 0.00 7,815.52 1 19,200.0 93.07 138.97 6,251.2 6,195.0 -7,890.8 -4,475.5 6,023,184.44 465,319.10 0.00 7,890.84 19,300.0 93.07 138.97 6,245.8 6,189.6 -7,966.2 -4,409.9 6,023,108.85 465,384.35 0.00 7,966.17 19,400.0 93.07 138.97 6,240.5 6,184.3 -8,041.5 -4,344.4 6,023,033.27 465,449.59 0.00 8,041.49 19,500.0 93.07 138.97 6,235.1 6,178.9 -8,116.8 -4,278.8 6,022,957.69 465,514.83 0.00 8,116.82 19,600.0 93.07 138.97 6,229.8 6,173.6 -8,192.1 -4,213.2 6,022,882.10 465,580.07 0.00 8,192.14 19,700.0 93.07 138.97 6,224.4 6,168.2 -8,267.5 -4,147.7 6,022,806.52 465,645.32 0.00 8,267.47 19,800.0 93.07 138.97 6,219.1 6,162.9 -8,342.8 -4,082.1 6,022,730.94 465,710.56 0.00 8,342.79 • 19,830.7 93.07 138.97 6,217.4 • 6,161.2 -8,365.9 -4,062.0 6,022,707.74 465,730.59 0.00 8,365.92 Total Depth:19830.7'MD,6217.4'ND-41/2"-PN13mid v7 T6 7/12/2010 1:59:27PM Page 10 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (7) (?) (ft) (ft) (ft) (ft) (ft) PN13mid v7 T6 0.00 0.00 6,217.4 -8,366.0 -4,062.0 6,022,707.70 465,730.62 -plan hits target -Point PN13mid Curve test 1 0.00 0.00 5,397.1 -2,163.5 -8,496.1 6,028,927.52 461,322.15 -plan misses by 218.5ft at 11777.0ft MD(5590.4 TVD,-2085.5 N,-8561.5 E) -Point ODSN-17 PN13 mid DD Poly 0.00 0.00 6,109.5 -3,892.6 -8,237.2 6,027,197.53 461,573.98 -plan misses by 96.4ft at 13705.7ft MD(6088.8 TVD,-3843.0 N,-8157.2 E) -Polygon Point 1 6,109.5 -3,892.6 -8,237.2 6,027,197.53 461,573.98 Point 2 6,109.5 -3,963.7 -8,189.1 6,027,126.24 461,621.79 Point 3 6,109.5 -3,973.0 -8,182.4 6,027,116.92 461,628.45 Point4 6,109.5 -4,055.5 -8,123.2 6,027,034.19 461,687.31 Point 5 6,109.5 -4,134.4 -8,058.4 6,026,955.03 461,751.78 Point6 6,109.5 -4,213.7 -7,993.0 6,026,875.47 461,816.85 Point7 6,109.5 -4,286.9 -7,920.3 6,026,801.99 461,889.25 Point8 6,109.5 -4,359.1 -7,848.6 6,026,729.50 461,960.64 Point 9 6,109.5 -4,360.4 -7,847.3 6,026,728.20 461,961.94 Point 10 6,109.5 -4,427.5 -7,773.8 6,026,660.81 462,035.16 Point 11 6,109.5 -4,915.4 -7,281.3 6,026,170.96 462,525.62 Point 12 6,109.5 -5,129.2 -7,076.2 6,025,956.35 462,729.83 I Point 13 6,109.5 -5,644.5 -6,603.2 6,025,439.19 463,200.69 Point 14 6,109.5 -6,088.0 -6,199.7 6,024,994.10 463,602.35 Point 15 6,109.5 -6,532.9 -5,801.9 6,024,547.63 463,998.30 Point 16 6,109.5 -7,131.1 -5,274.4 6,023,947.36 464,523.31 Point 17 6,109.5 -7,378.4 -5,059.3 6,023,699.21 464,737.38 Point 18 6,109.5 -7,657.6 -4,815.7 6,023,419.05 464,979.82 Point 19 6,109.5 -7,958.8 -4,553.3 6,023,116.82 465,240.97 Point 20 6,109.5 -8,184.9 -4,356.8 6,022,889.95 465,436.53 Point 21 6,109.5 -8,260.2 -4,291.3 6,022,814.39 465,501.72 Point 22 6,109.5 -8,335.6 -4,225.7 6,022,738.73 465,567.01 Point 23 6,109.5 -8,410.9 -4,160.2 6,022,663.18 465,632.20 i Point 24 6,109.5 -8,434.1 -4,140.0 6,022,639.90 465,652.30 Point 25 6,109.5 -8,298.0 -3,983.7 6,022,775.35 465,809.13 Point 26 6,109.5 -8,274.8 -4,003.8 6,022,798.63 465,789.13 Point 27 6,109.5 -8,199.5 -4,069.4 6,022,874.18 465,723.84 Point 28 6,109.5 -8,124.2 -4,135.0 6,022,949.74 465,658.56 1 Point29 6,109.5 -7,823.0 -4,397.3 6,023,251.97 465,397.51 Point 30 6,109.5 -7,295.9 -4,856.3 6,023,780.88 464,940.70 ' Point 31 6,109.5 -6,920.2 -5,186.1 6,024,157.88 464,612.46 Point 32 6,109.5 -6,471.8 -5,582.0 6,024,607.83 464,218.42 Point 33 6,109.5 -6,036.7 -5,969.6 6,025,044.46 463,832.63 Point 34 6,109.5 -5,801.8 -6,183.3 6,025,280.20 463,619.91 Point 35 6,109.5 -5,432.2 -6,519.6 6,025,651.13 463,285.14 Point 36 6,109.5 -4,990.4 -6,924.9 6,026,094.52 462,881.68 Point 37 6,109.5 -4,845.1 -7,067.3 6,026,240.39 462,739.89 Point 38 6,109.5 -4,508.4 -7,393.3 6,026,578.37 462,415.29 Point 39 6,109.5 -4,278.1 -7,637.5 6,026,809.64 462,172.05 Point40 6,109.5 -4,211.7 -7,711.6 6,026,876.33 462,098.23 Point41 6,109.5 -4,210.5 -7,713.1 6,026,877.54 462,096.73 Point 42 6,109.5 -4,145.2 -7,779.8 6,026,943.10 462,030.30 Point 43 6,109.5 -4,075.3 -7,843.5 6,027,013.25 461,966.90 Point 44 6,109.5 -4,005.8 -7,906.9 6,027,083.00 461,903.78 Point 45 6,109.5 -3,936.6 -7,970.1 6,027,152.45 461,840.87 Point 46 6,109.5 -3,861.2 -8,024.4 6,027,228.06 461,786.88 Point 47 6,109.5 -3,852/ -8,030.5 6,027,236.59 461,780.82 7/12/2010 1:59:27PM Page 11 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Point48 6,109.5 -3,784.7 -8,083.1 6,027,304.79 461,728.50 PN13mid Curve 4 0.00 0.00 5,020.0 -947.6 -7,285.5 6,030,138.34 462,537.56 -plan hits target -Point PN13mid Curve 5 0.00 0.00 5,395.6 -2,433.8 -7,920.9 6,028,654.91 461,896.17 -plan misses by 743.5ft at 11968.8ft MD(5644.3 TVD,-2265.1 N,-8601.0 E) -Point PN13mid Curve 3 0.00 0.00 4,960.0 -1,017.0 -7,302.8 6,030,069.00 462,519.98 -plan misses by 92.9ft at 9905.3ft MD(5023.0 TVD,-949.3 N,-7294.0 E) -Point PN13mid v7 T2 0.00 0.00 6,231.2 -4,533.1 -7,512.5 6,026,554.16 462,296.02 -plan hits target -Point PN13mid v7 T3 0.00 0.00 6,243.2 -4,996.0 -7,058.7 6,026,089.41 462,747.91 -plan hits target -Point PN13mid v7 T1 1/4 mile radius 0.00 0.00 6,109.5 -3,908.9 -8,111.1 6,027,180.71 461,700.08 -plan hits target -Circle(radius 1,320.0) PN13mid v7 T4 0.00 0.00 6,189.2 -6,102.9 -6,044.7 6,024,978.56 463,757.33 -plan hits target -Point PN13mid Curve 1 wp11 0.00 0.00 5,600.0 -2,731.8 -8,124.5 6,028,357.76 461,691.36 -plan misses by 493.5ft at 12488.3ft MD(5781.5 TVD,-2763.3 N,-8582.4 E) I -Point ODSN-17 PN13 mid GeoPoly 0.00 0.00 6,109.5 -3,659.6 -8,074.8 6,027,429.81 461,737.38 -plan misses by 178.7ft at 13611.1ft MD(6065.1 TVD,-3768.1 N,-8209.7 E) -Polygon Point 1 6,109.5 -3,659.6 -8,074.8 6,027,429.81 461,737.38 Point2 6,109.5 -3,738.4 -8,018.5 6,027,350.79 461,793.35 Point 3 6,109.5 -3,884.0 -7,903.8 6,027,204.74 461,907.45 Point 4 6,109.5 -4,074.3 -7,710.8 6,027,013.68 462,099.66 Point 5 6,109.5 -4,287.0 -7,467.4 6,026,800.01 462,342.17 Point 6 6,109.5 -4,853.1 -6,904.2 6,026,231.69 462,903.01 Point 7 6,109.5 -5,569.5 -6,227.3 6,025,512.62 463,576.93 Point 8 6,109.5 -6,158.1 -5,680.3 6,024,921.86 464,121.48 Point 9 6,109.5 -6,968.0 -4,940.4 6,024,109.05 464,858.01 Point 10 6,109.5 -7,562.7 -4,404.4 6,023,512.24 465,391.54 Point 11 6,109.5 -8,252.8 -3,781.7 6,022,819.69 466,011.37 Point 12 6,109.5 -8,606.1 -4,231.0 6,022,468.25 465,560.68 Point 13 6,109.5 -7,917.6 -4,808.8 6,023,159.02 464,985.74 Point 14 6,109.5 -7,231.6 -5,387.0 6,023,847.29 464,410.39 Point 15 6,109.5 -6,472.7 -6,033.8 6,024,608.73 463,766.74 Point 16 6,109.5 -5,875.3 -6,558.0 6,025,208.20 463,245.02 Point 17 6,109.5 -5,130.0 -7,222.0 6,025,956.11 462,584.12 Point 18 6,109.5 -4,573.9 -7,771.7 6,026,514.38 462,036.74 Point 19 6,109.5 -4,436.4 -7,918.4 6,026,652.46 461,890.61 Point20 6,109.5 -4,278.1 -8,061.6 6,026,811.32 461,748.07 Point21 6,109.5 -4,108.0 -8,189.9 6,026,981.93 461,620.47 Point22 6,109.5 -3,938.7 -8,302.1 6,027,151.66 461,508.97 Point23 6,109.5 -3,858.9 -8,356.9 6,027,231.68 461,454.50 PN13mid v7 T5 0.00 0.00 6,295.2 -7,232.9 -5,048.1 6,023,844.64 464,749.22 -plan hits target -Point PN13mid v7 T1 0.00 0.00 6,109.5 -3,908.9 -8,111.1 6,027,180.71 461,700.08 -plan hits target -Point 7/12/2010 1:59:27PM Page 12 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 4,483.4 3,240.0 11 3/4" 11.750 13.500 10,829.1 5,316.0 9 5/8" 9.625 11.750 13,954.6 6,147.0 7" 7.000 8.750 19,830.7 6,217.4 4 1/2" 4.500 6.125 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (?) 1,689.7 1,666.0 Base Permafrost 0.00 12,239.4 5,718.0 Top HRZ 0.00 3,453.3 2,901.0 Tuffacious Shales 0.00 13,261.4 5,977.0 Top Kup C 0.00 4,483.4 3,240.0 SCP 0.00 12,709.9 5,837.0 Base HRZ 0.00 13,930.2 6,142.0 Top Nuiqsut 0.00 7,621.6 4,272.0 Brook 2B 0.00 9,756.3 4,974.0 Top Torok Sand 0.00 2,407.9 2,295.0 Top West Sak 0.00 10,829.1 5,316.0 ICP1 0.00 10,796.4 5,306.0 Torok Shale 1 0.00 13,954.6 6,147.0 ICP2 0.00 10,306.9 5,153.0 Base Torok Sand 0.00 13,265.3 5,978.0 LCU 0.00 2,415.7 2,301.0 Hue2 tuff 0.00 13,738.6 6,097.0 BCU 0.00 13,065.9 5,927.0 Kalubik Mkr 0.00 7/12/2010 1:59:27PM Page 13 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Design: ODSN-17 PN13 mid wp09.b Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 200.0 200.0 0.0 0.0 Start Dir 1°/100':200'MD,200'TVD: 130°RT TF 350.0 350.0 0.0 0.0 End Dir:350'MD,350'TVD 450.0 449.9 -1.3 1.5 Start Dir 2°/100':450'MD,449.9'TVD 874.2 873.3 -2.9 3.5 Start Dir 1.5°/100':874.2'MD,873.3'TVD 1,672.8 1,650.0 -1.9 0.7 End Dir:1672.8'MD, 1650'TVD 1,778.5 1,750.0 6.8 -14.4 Start Dir 3.5°/100': 1778.5'MD,1750'TVD 3,483.3 2,911.1 96.4 -169.6 End Dir:3483.3'MD,2911.1'TVD 9,896.2 5,020.0 113.6 -199.3 Start Dir 3.14°/100':9896.2'MD,5020'TVD 10,996.2 5,366.7 204.9 -409.2 End Dir:10996.2'MD,5366.7'TVD 11,046.2 5,381.8 216.3 -1,342.2 Start Dir 3.37°(100': 11046.2'MD,5381.8'TVD 11,396.2 5,483.3 -947.6 -7,285.5 End Dir: 11396.2'MD,5483.3'TVD 11,441.2 5,495.8 -1,449.3 -8,181.1 Start Dir 4°/100':11441.2'MD,5495.8'TVD 12,409.0 5,761.7 -1,484.4 -8,213.4 End Dir:12409'MD,5761.7'TVD 12,791.8 5,857.5 -1,753.2 -8,412.2 Start Dir 3.5°/100': 12791.8'MD,5857.5'TVD 13,488.7 6,034.5 -1,790.5 -8,434.0 End Dir:13488.7'MD,6034.5'TVD 13,788.7 6,109.5 -2,687.6 -8,595.5 Start Dir 3°/100':13788.7'MD,6109.5'TVD 14,298.1 6,198.5 -3,052.8 -8,532.4 End Dir: 14298.1'MD,6198.5'TVD 14,533.3 6,221.3 -3,671.0 -8,277.6 Start Dir 3°/100': 14533.3'MD,6221.3'TVD 14,731.3 6,233.5 -3,908.9 -8,111.0 End Dir:14731.3'MD,6233.5'TVD 15,238.6 6,242.5 -4,284.0 -7,780.3 Start Dir 3°/100':15238.6'MD,6242.5'TVD 15,386.2 6,241.8 -4,441.8 -7,607.4 End Dir:15386.2'MD,6241.8'TVD 16,736.0 6,190.7 -4,533.1 -7,512.5 Start Dir 3°/100': 16736'MD,6190.7'TVD 16,964.8 6,195.0 -4,580.0 -7,466.3 End Dir:16964.8'MD,6195'TVD 18,177.2 6,289.4 -4,941.5 -7,110.5 Start Dir 3°/100':18177.2'MD,6289.4'TVD 18,428.9 6,292.5 -4,996.0 -7,058.7 End Dir: 18428.9'MD,6292.5'TVD 19,830.7 6,217.4 -5,049.4 -7,009.8 Total Depth: 19830.7'MD,6217.4'TVD 7/12/2010 1:59:27PM Page 14 COMPASS 2003.16 Build 428 2 0L > I— L m 3 C - J J L Q m = a W L .12cri Ts /A m 3 c 0) a c O E H M c O 0 Z0. 10 O U 0 i • 0. N d co N N 1 00 � a vo L le w o COrt € � N• o a) M tZ M o o ZZ ? n o m o CO Z £ C o O r D• 3 ._ _ O z • oo N r E 0_ co I .Q W c ZWr' p. ci 3 a) G ti p o 04.1 I— () O N 'O VcO cu o 10 Om M t 0 `O Z = d w ■. V c co a N G�7 C d C O ,0 13 0 U) 0 YN (AIn in = CO fX a C W _I E ` b c. .7 0 V ' CO w C0 CD 'i r r O O M r d'p ii rt 0 Z Z L C — a 0o + � " Q .al ¢ CL � � o_ a �, ca O �;, s7ommo L• L r r r N y d co - a) p • a) an Z Z Z . w >+ C Q N c 'O N G O. O OtoCO Cl) • c = (> , v � �as al� 2 i 0 0 Ci CI Cl 0000 0 w 0 Q N 5w 3 '° .Lmm r F C 13 ci N 0 > N to • U C �� 70 W • �,a as > > YY E, = gl- F.F. fr& y N N o a, �� YY ZZ rn » yh N Eo Ya UY oo •7� o ,.��`\ N 1L1 0 gi s� ° A A A A AAA c O l;l ii pM pMoo «"wkr"ai ? " aam"am'R"a� w 2 -4v ai , C� '/JI 15�1�\moi 0 0 a° R .$« $mmm� m �•- 1 Mi ���� '� \\ `� ` i V 888888888848.R8V'8C8C8m8mm8848xo8o88 O 4=. Z z ` b '• : \ �, , , a'+At Ar / *F• ,f . - \_ . 4888888888888'8888888888 8888888, ' - 3 c m 888�8rr�e�,�,mmmwm.mMaM a y• Oy I1 ; , E' U < 38888-.----2,.1_em<._„ V O O°O •� ��it,/,, ♦ W 8x -x l' Z O-7 it-I \�11/..�`-i/ ,i + `� Za a o 88 8 w $ �d'n5 n� $ ri f�`t t �is�� CO� s F 6 3 8 e . d} -144,...;.,y4,1,7,44.,, ;°�g.ti'�.' /F7,`.i p i i ^ m foo „a 'x iz :41_T Ii§A4a§AlA -R Z as \ fes,\ .* fIar " - moi:., i N 2 .e m_ m v vvvv nn O o t 111ww� wiiI AV, ', =V�♦�• 00 W z<�izm ixs i isi a a axxiisi v W Y g� .a or ' _ r♦pia f „Rxa �s m mm m N oo.__ q \\� 1�\tom �� s ,,P...\ ♦♦♦ ,� , k' ,J ad EJ 2 \ ��•. 'it:01�// , ^`�• ♦ N�® , F, g88888888bigR22 RRR8888 44'4448 "" OJ n fo a `�. t �II/'7 ./4' r2r- ,• ,����®1��/ r oo8 ReePPA8A �xxA NA U t'Z0' /��//4 ` \ill -. c _ 88888888mx844d8n,`28: 88888888 6 0 •• I z / tr totti f_--_—' ` A ` 3 88x88"« mmmmaa 228mx x Z 0,9._,- f7---- 11•t;,/, .Pliti�I� //� . � ` nmmnn$n$nn-mm`s-8.888«oo Q p� J .,Z p �4 \�il ;it//l�,,, --// l/// , �+ t�rR88m ««R;...:m8mm8mmmg8 N N LL a CO `"\ QI ','�'1' �``c�// yflid�l 11 1 /t;.l1l N C O 'O Z• p❑O J a I pfai 11\NV --_'-' U8j.I; �%, 'ill? Q ._r8.88,88.ec��s�ncmaR,PAArRrvRRRmm N N _ o L7. 0 CO C ❑ C7 N .. LE _ LL 1i? . Oc. d d E 0 w c 0 C C al u 0 p 0 0 0 0 0 0 0 pp o 0 0 0 0 0 0 E E E E E E E E E E E E 's N J O O o 0 N o N o N O N O N E N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '��>am.. 1- N O N O N N n O N N A O N m r O Co O O O o O N MNr W A N N N N r r r r r N N N N M M M M sr N fp r W W . . . . . . . . . . N -- E add O 3.,QIZ :e° 41° I I ovE o000000 0 0 0 0 0 00000000000 000 0 0 0000 OU UInd N o N o N O m O N O N ONOm0000OOOOOOO00OOO0IaN m r O - m A N N N N ONNItOOo0000 ' N00000000 ' Q 0 m � � N N N N M M M M O N 10 n m a6 0 N M Y Y N (O W O1 0 G N U U ___.... - LL C C ,6.__ P-- - - ° CNH II re O _ iq f i a ; 7 a Z LL -04- j.- T's a a v c o f.7 a `N7 A n el c1 % oY_3 e� eZ3 a_ L d r �°s N �� i ti• y o, I1to 'r7 yZy Y Y. 4 y4 ( 2m2y2 re 'n to ❑ \ p - N Y O q Y Y z O�`� O O O O co p ,e z, C ° a o fW, o c • s , O i'p v mW`mwE W 1Pr oP O r� -1p '1 A'..i.*' AaC- 1 0 . OI 0 , W U) d Z D � 1. - ,i i N , , O --- a ►fir %.�r � a �- 'eV". -a-v i o ' � ,00, � n / fV / o � ...,,,,.'.`.;,..-f / "i Z S /� ttl r►A7, eta•. , , a N CS Z ad .-.;'S"--%41:/;1. sl\tIN!a , ' Z en y 6 it:4'10 '10Ni:' \\\\\` �.� i ar 1„1 1 Y r.r. I 1// U i 111 r111�1��1VA m „AA a -RA�� I I I/i�� I 1a s\ �\���t�\..r$ �i ,,�a � / o Z•ri '' .c o a CTo4}may f� 11,% �q► 1. : flit t �,�� ` r�E E' oCi r.+. ii=a ,� r -zN;1\l'!'\11. „e - l�1 'a,� = �1Z VI ° fin . •4 �. tl��\\� ittp\I�'r♦e:.. O !1I L_ V t Iy3J J O S 3 • 1, \ 1, f {4, S f gyp, �, y r (� o f 2 eI�i a\,.�,�+a -'y 121E/1`1 +i=� ,.-4,.......„,_"•••••• - 4 jri` =in y in U •• c a EE N I� tJ v ti - /� J -` �f :f1r E Q ��o E m pc > 0 F.0. a =I//�, \\` e 1,'; , �♦ ;.4di '1,t1�•.Y� _ --- Q O m�Ohc N Wa AMM M �'� \\\Z ♦ � '1 'II - W N-r- a ro a '•' 6.hh Y Z M I� _��I �.. .�+,1 y (v(iL N ,. ivmof ra v > II IN4 - i• v;• :Si 5.- / /� i/1 CI g Z cccct G W �m i ,1 1 , `d``r 00 > 0 if*tC►� ��"i. -"'%/i r w w d d z c_N v00 N� 11� iii 3. M V fie, mummy Z rvO '$ 4v i1�1��.J�:4i, 'n N oL LL K K K K p o 0 7 00� a i�1� "-t' /,�11 fCc Zll K wCM a= Zo F'oo O f /, , C D ?�> uo N > 2.7-,'...2. r o !s'2.,:::-----1,---,//,';\ I N 2 ° i 8• 16°eU o u m 3 o o _ Q ^ Z `o>Nm wo e E"e W "+ n' ar eo °ao 0O J U Z o b r io +o a co o N ,- 50) s:. E Q a OA 0 0 E 0 N 0 U C , Y Y Y Y Y Y . Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y CO CO CO (0 (n CO CO CO CO CO CO CO CO CO CO CO co Cl) N CO (n CO CO CO CO cn ' `o EEEEEE iEE E E E E EREEEE EEEEEE EcE y ,� 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .8 .8 m m Ea' m 'm m m 'm 'm m 'm 'm m 'm 'm m'm m m 'm 'm m 'm m m 'm G 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 O N CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO N (n U) CO (n 00 CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO N (n CO CO a) (n CO CO CO CO CO L O aaaaaa aaaaaa aaaaaa aaaaaa as OA C c 0 O w E 0 0 m 0 m `0 0 `0 m `0 a) o m 0 0 0 m 0 m o m o m `O m `0 o 5 0 t 0 t 0 ti a ti O t.5 O t 0 t 0 i) O t 0 ti 0 t 0 et m m c , c (a c CO c co c m c (p c (p c as c (p c m c m c CO c (0 a m £ m LL m LL ;d LL m LL CO LL m LL _m LL m LL CO LL m LL m LL (0 LL L ) (0 N (0 ur 0 N 0 N N a) m ul y .i'.7) (+7) 0) N a) N 0 - CO E 2 O 2 5 2 000 V 000 2 000 2 0 V c c c c c c c c c c c c c E a) co a) co m co m m d m m m m m m m m CO m m a) CO d CO Eu. m E m m m (15 m m m Z m m m m m CO m a) m a) 0 a) a) a) a) a) m a) a) a) a) 0 a) CD a) a) da) a) a) a) a) Cn U 50505 000000 0 0 0 0 0 0 000000 c_) 5 d V 0 N V' N- cr N- V N d' O (O O CO O CO V N- V I� N- M N co N- O V co U) 00 00 V CO CO V N CO N CO N CO O) CO CO (O L() CO «) CO (f) LO CO (n O In O LO O (n 0 0 .- O . O . N O N O O N O N (O CO o V M M C") c`') c+) M C') M M V M V M V M V V V V n M N- (O M M i ti ti OS 0 LL U •0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O . . . . d o LciN- (n (n (n (n (n (n (n (n Ns N- LriN- LriN- (n N- o 0 0 0 0 EriN- o (o (n (n N- m L (f) CON N N N N N N N LV CO CV CO CV CD 0) O) O O) 0 0 0 L) N 0 N (n M V (n V (� V (n V In N CO N CO N M 0) O) O) O) (n (O «) (n (n (n d a) ©2 C C to (f) O CO O M C) CO O CO .- V N V .- V Cl) O) In 0) T- N- T- N- (O T- C O) a0 O) W O) 00 O) c0 (n V (n 4 (n V O O) O O) O O M ) C d G M M .-- .- .-- .- — r r r (f) V (n V LP) Cl) Cl) Ln N N N O.CO = ai W a O CO 0) Q 0 O M O O) O O) O CO O 0) O CO 0 CO O W M n M n O M O M N (V C) - a) n C (n4 (n4 (n4 U) V (n C Lc) V (+) N M N6 V O V M M (n G •£ 3 O V ( L N- N N N N N N N N N- N N- N- N- N- O) V O) V O N- O Ns N N 0CQ .) n CO V In ,t (n V (L) V (n N CO N CO N CO CO O) 00 O) In In (n (n In In m .- 73 j m0 a M M C Z co co V co V co V M V M N 7 N 7 N 7 M 7 co l (O V (0 •7 CO O) d m d N to N- o N- co n O N- O O O (f) (O (n (O O) O O) O N N Z V V V N N N N N N N N N N N N N N (O CO CO CO (n (O (n CO M M CL i 0 8 m = ti N co c cn (0 I4) O a Z d ;0 W O co O O) O O) O 0) O 07 O a0 O co O co M (f) co (P) O M O CO N- N CO ccE m K `. t O d' (n V In 4 (n4 (n4 Ln V (n V U) V M N M N646 V M M (n N- N N N N N N N N N- N- N- N- N- N- 0) V 0) V O N- O N- N I.-- QCi L MN G LO M V LO V LO V (n V (n N CO N CO N CO a0 O) CO O) LO (n (n (n (n (n O O and Za CD CI 1` m z — 0 U) c I Tp 71 71 ais °7 O (n c v v CO CO n n> >2 Z m m Z 2 Z of v v n Cl 3 3 YY 0 0 0 0 N rn C 3 3 . CT = 3 2 2 (0 (0 (0 (0 CO (n Ci c Z 3 0 a 0 Y 1' Z Z G a n n d ¢m. CO n U CO n n O CL 0 p 0 8 m 0 i i*) d d Y Y Y Y N N 7 7 CO(0 CO Y Y 7 7 Y Y E Y Y CO aO CO CO Y Y (n (n L o m 0 Z Y Y to (n co _M M_ M_ CO CO a s d a CO CO CO (n co M Y Y (� 0 c O LD LL f.12 m -C73,0 U U 0 Y Y Y Y n a v c v c CO CO 0 Y Y ._7.: Q ZLF O = N do ❑ ❑ (n U (� (� Y Y Y Y O O M M Ln Cn WY O c v O O O Y Y Y Y (n m ❑ ❑ �+ m = a) c a 0n 0n m 0000 � � cn (n (n (n ❑ ❑ (') Cl) 00 U T� co 3 to ❑ YY 7 7 222 = YY 000000 n7m0000 0 o I— Q Y v v a a o a n n n n U U Q Q Y Y 0 0 n n o •� O U d Q) d m m 7 7 7 7 7 ❑ ❑ N N n a 7 0 . E = Z Z Y Y Y Y O O d d d d Y Y 0 0 Yr, Yr, an (n Y Y p 0 w m CD a co co co co M M M M 4 4 4 4 4 4 co co co co M M M M N N 3 C O •- a0 Z d Cr) CO r .- N. M M M M Y Y Y Y M M O a 0 « ao — CI' •L ❑ ❑ U (•) Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y U m U (n Y Y rr` m (0 0 0 0 a a Cn (n N (n (n (n 07 (n (n (n (n co co (n co (n ❑ ❑ ❑ O CO CO N O c • • ❑ ❑ ❑ ❑ 000000 000000 000000 ❑ ❑ Cl)� z �� w d Y Y Y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q Q Q Q O 0 J = y d (� 'n M M M M M M M M ,r V V V V M M M M (n (n (n (n c0 c0 JO C C o L 7 M M M M M M M M M M 4 v O Z a C ❑ ❑ Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y cv a.+ co co V d . p O 0 000000 000000 000000 000000 ❑ ❑ I @ C m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o u (n I~ OOjp p, c 0 0 0 0 0 0 C p 0 0 0 0 0 0 0 O NNNNNN U CO 0 Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y O (0 co Cl) CO (/) CO co CO co cn co CO co CO Co Co CO CO co N co U) co CO CO CO co co CO CO 1 c REEEEE REEEEE EREEELE Rirrci5262E EREEEE I.. — `o `0 `0 00 `0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000 0 0 0 0 y �^�' 'CG 'a, •m 'C6'W 'O1 CO •CO .0 .a .m.m 'C6 CO 'CO.� 'CO CO C C C C C C .O CC'CG .0 @ 'N C �� 222222 222222 222222 � � � � � � 222222 0 U) ca ca CO CO N Cl) coCO to co co co co co N CO co CO CO CO CO CO co CO 0 CO CO co LOU) co ISIoco co CO co co CO co co co co co CO CO COco co co co COcn U) CO CO CO CO co co Cl) co l O aalQClaa a (iaaaa OS O d (ia (i (i (i (iliaalia OA c 0 = y E a) 0) O N a) ° (0 ° (0 ° a) O N O a) O o O o O a) O CO O 4) O a) O C� l0 7 07-30 -60 -6 00 0 U 0 C) 0 0 0 0 0 0 0 .5075073 000000 — c C0 c (0 c 0 C ca c (0 c ca c (a c C0 c C0 c C0 c CC c ( c 0 c Lo c (0 a m E CO LL 0 LL 0 LL 00 LL 0 LL 0 LL 0 LL 10 u_ 10 CL C«0 LL M LL @ LL C0 CL M Ll (0 LL �'C N O) 0) V) O) co a) co O) N a) n a) o. CO o 0 y m y 0) n. 0 N CO N CO V)0 ) A 606c-) 60 0 0 0 () 0 0 O00 0 0O0 0 0 0 0 0 0 0 C C C c c C c c c c c c c c C E0) co 0) co 0) co 0) 0 0) CO 0 CC1 0) co 0 CCI N co m m 0) CO 0) co o co 0 ca 0) CO c c @ c c 0 c c m c@ c 0 c 0 c c c c c m c m N N a) 0) a) N a) 0 a) 0 a) 0 a) a) a) 0 a) N N 0 a) 0 o N a) a) a) 0 a) 0 co0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) to CO CO O) 0 V N CO V 6) - 0 M N CO c0 CO N M LC) M Ln CO Ln - co t- (NJ CO CO V N c0 CO V CO M CO N. 0) C CC) L` N CO CO 0) N N N M N- t-- Ln Co c i V N M N V M CO (0 0) V CO CO (b N N N co co t- co r co N N CO CO CO N CO t. CO M M C6 Ch M M C•O N c0 n 4 CO CC) N N N N N N N N N CO V N V CO 0 •C o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o 0 0 0 0 0 0 0 0 0 d N- 0 cc)N- 0 N- 0 CC) 0 0 0 0 Cn 0 0 0 0 0 0 Cn O 0 0 0 criN- 0 0 0 0 0 7 r5. h o `7 0 0 0 O 0 to N CD 0 LO O N O CV O N- 0 CV 0 t- Co 0 0 0 V CA V V LO LC) CO V' V CO V LO C LO N CO N CO N CO N CO CO N CO Cl) V C N. Ln Co c• N- LC) N- CO 1C) CO N V t` o CO N ,- t. N N N N N ` CON N tCO CO CO 00000) 60 0ocoN co v t; co (riN 444444 rim 0 (n0 0) C — e- ,— N— N N N N N N Ln V V CO (`•) N N y O.0 a W a o G (n o) Q d N O N O f) O CO O N N O O 0 0 0 0 COCA 0 0 0 0 0 0 N O Cf) N O (o • 13 C) ad. d V 0) V O7 CC) O L() o O O O 4 O O O r o Oto O) CC) O LO 0) L() O o 6) O O y 0 •� t r CO N CO N- O N- 0O 0 LO N L() O LC) OO 0) A 0) n O N O) N- Ln Cr, 6) 0 0 O) a c 3 - V 7 V V V L() V LU co 7 V co co C V N N N N N N N N ,- CO N N V L() C0 a ' £ y 2 M M c U T" Z aO-.. 6) o 6) 0 .- M 7 M CD t- (O O) L` CO CO V N- N CO - CO N- CO Is O CO 0 V N- CD Z a co E 0) co E t- co N- co O) C) O) 6) (h V 6) N N Co (n O N M (0 CO CO CO CO CO N.: N- cc) co (6 C. N N N N N N N N M M C() CO LC) CO V CO ,- .-.• N N N N d z' C. E Lo - y C 0 1 w 0 a Z d ;o W '6 N 0 N 0 Ln 0 C() O N N 0 o 0 0 0 .- 0 (7 •�0 C) O C) O O N < 0 C) N 0 R ` V CC7 V 0 Ln O Ln O) w#O O O O R O O o t` O - to Ci (O to O o Cn O O Q L L` 01 N- CA N- 0 ti 0 0 0 CC) N CC) O LC) CO Ln CO I-' P. CO Is. 0) N- CO o 6) O 0 M 2 N 0 V C• R v v CC) 'Cr CO M V V CO v Ln V V N N N N N N N v- CO N N ' Ln O cc -....7..- 0) 1 r N0 Z t� 0 LL LL CO CO U) CO a a C). a 1 ( 0 CO (n a o- ar) �` >` N co Z 2 H rn a) Y Y 6) 6) co co Z Z M co p p 55 co 3 � w 2 Z nn nnnn 3 3 ('ninZ Z 3 3rnrn 0 c Z s o •• CO LL m m (, ( p p 3 3 3 3 3 3 3 LL LL Cl Cl 0. 0. 0. a N (Ni ,_ o o N N CO M CO M a a CV N O M O dw a0 G d ` d > > c v Y Y 3 3 (n (n (n (n co (n z Z z z z z J -zz Z Z 0 O n n L 0 0 .. m Y Y Y Y (V N 0 f6i 0 a _ = a a a a a a d [1 CO CO 3 3 ZCV C. Z Cn (n v v d - - N N in 0 C_o C_o CO Cfl Z Z CA 0O 0 0 (n Cn o " a d m• Y Y D O N N (Yn U)) p Z Z Z Z Z Z Z Z Z Z Z Z 0 0 Z Z 0 0 O � co v) co co co co co co co (n co co O O (n (n m m N N () COy a(0i c 42 0 0 LL LL Y Y 0 0 '- '- 0 0 0 0 0 0 0 0 0 0 0 0 D D y rn Z Z /c/ yon —y 00 = 0o o , , 00 000000 0000M (,.) 00 ancoco CL `Y d LL LL Y Y 0 0 a a 0 O N N - p p ,- N CO M ,_ M Z Z 0 0 0 0 CDO a G� E 2 ° 0 a) = = mm � cncninin cninin ) ZZ ZZZZ °La zZo o ' CIi x 0_,o E YYaa '¢ ¢ YYD0aa ._ ._- aa 0_ 0_ 0_ 0_ = J n. a77 ( � CO N N N N 0 0 7 N C1i25 CO CO O CO Cfl CO c0 N N N 3 c o 0w-co z v C ' ' � � � � � � aa M r0 p ^ .) YYYY � � � � ZZ � � ZZZZZZ ZZZZZZ ZZ00 `"" 1Y C_ co co (n cn (n u) (n (n (n (n (n (n (n (n u) (n Z Z (�.1 o c1` , 000000 00 (0 (/) 00 000000 000000 0000 (0 (/) �y z o)� 1 d o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000 0 0 J y , , , , , , N 0) N N N N 0 0 ,— N N LC) LC) Co co Co co co co co co C) C) 'C L] W CO3 W R V V V V V V V V N N 5 d �'� z a YYYYYY Y Y Z Z Z Z ZZZZZZ ZZZZZZ ZZZZZZ •,- 41 c.) T C CO (0 •0 E (n (n (n u) (n (n (n (n co (n co (n (n (n (n CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO / V (y R' Q' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C > a C C Cn O 000000 000000 000000 000000 000000 5 CO o 0 CO 0 a O p C Z C s. 0 O 3 Y Y Y Y Y Y Y Y .) Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y /N''� _) N_ _N N_ _0 _0 (n N _U) U) CO N U) U) COEEE _ U) _) _N (I) (0 CO Cl) N _U) N U) U) I U) CA U) _ 1 C 0 y ,- 03 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000 Q co mai 'm'm 'm 'm m 'm 'm 'm 'm 'm m 'm 'm 'm'm 'm m 'm 'm'm 'm 'm m 'm'� 'm 'm 'm Q. •. (n N (A N CO C0 C0 CA N N CA N CA CA CO N N N U) U) U) 0 CA U) N U) U) N N V) N P. p CO N N N N y (A N CO y (0 U) U) CO N N U) V) N U) CO N N U) (A (A C0 C0 U) N ( Op aaaaaa aaaaaa aaaof- aa aaaaaa aaaaaa bio O C 0 t+„ y E 0 0 0 0 a) O a) O a) O a) O a) O a) O a) O m O a) O a) O 0 0 0 0 a) O CC Cam cmcmcm ci) cmci) ctccocco ctcascco ccucmcm ,_, m E c c c c c c c Ca c (0 CO c (D CO CO c C0 COU) CO 0 C6 _ c (0 COc COc F., • _ LL LL LL LL LL L.L. LL L.L. LL LL IL LL LL LL LL c 7.8O N a) N O N a) ) O N O N O N O N O NO •N O N O iii O a) V) a) E p O p O p c) p 0 p 0 p 0 p c) p c) p c) p 0 p 0 p U i5050 .60 C C C C C C C C C C C GC C C E N N a) N T. N E d c0 E 0 Ca 0 CO 0 CO a) CO 0 Ca 0 co a) ca a) co o c E c CO C6 c U c c c c c c c c c coz: c c c c c c c c c c c c c c c c 3 d a) a) m 0 a) 0 (1) a) 0 a) a) a) 0 a) a) a) 0 o 0 a) 0 a) a) a) a) a) a) a) a) Cl) 000000 050500 000 '500 000000 050505 CD N C0 N CA C` M N O) N- N CO O V N V V 0') M CO M CO O V O V N O) N O) M O V N ,- 0- N- CO C0 O O CO CO N- CO M co N O .- O c0 O 10 O CO N.- CO N- C i CO M O ,- 0 CA V 0 CO LO CO CO CO CO sl- r( N CA N O) N V CO V CO i V O CO N N V CO N N- O V M N a0 4 M N ,- O O ,- O Cb CO W N a0 C- W CO LL r U -O O O O O O O O 00000 000000 000000 000000 ` o (n O N- 6 0- 0 0 0 0 0 0 0 0 0 0 0 0 CVO Co 0 0 0 o O O (n o (n 7 t O N O 0, O h Cn 1.0 (0 O O C0 Cn LO LO O O (0 N O N O O U) O 10 CO N C0 N y N t` N M N M CO 7 V C0 Cn t0 CO 7 V (f7 Cn 10 V .0 V In to U3 to to V l0 V 10 a20 V co coco CO.- ,- CO V CO N CO N- CS) CO 00 C0 CO C0 CO .- CO 1- 00 M CO COCO C lf) O N O 0 h O M M O CA O M N co N- Cb I- O) OO CA xi I- CO h CO d•C co N V V .0- V' co co N N ,- <- O O O O) C) N- N- N- N- CO CO CO CO C0 LO C0 C0 .13 asa ^ 6 w a CO U) Cn QO a D O W C) O) O CO W W D O O M 0 0 0 0 0 O O C) O CO O CO CS) W (P CO a - d (n O V O V Cn 6 O O CA O O O) CO O CO O O O) O WO V O4 d O. '£ t O O N O t` O N- V V (0 O O V C0 C0 (0 O O V N O N O O V O V 10 N Cn N 0 0 N N- N CO N CO CO V V LC) (0 C0 CO ' V C0 Cn LC) d' C0 C0 C0 CO C0 Cn V C0 V C0 a 6 n N M ,co - c40 @� Z - O C O N ,- N C0 N CO M CO O) ,- CO 1.0 co co CO co V co V Cb CO CO M o V CA .0- Z Z d i E 0 CO CO CO M CA 6O N N 6 0) N N C0 CO C0 CO Cb N- CU V Cn V (0 r t6 C) CO V V V C0 C0 M M N 01 N N - - 0 0 0 0 CO CO 00 CO N- N- N- N- CO CO CO CO d Z a.y E ._yCiO. = N C C co 1 y 0 a Z d W •0 O O) O CD O CO CO CO O C) 0 C') O O O O V O O O O O M O CO CM CO CC7 CO x d t O (0 O V O V (P O O O (T O O O co O CO O O CA O CA O V O4 td O N O r O V V .13 O O .7 10 C0 C0 O O V N O N O O V O V C0 N (f) N Q L M 2 N Q^, N C- N CO N CO CO V V Ln Ln (0 co V C inCn in c CDLUCDCD (0 C0 V in4 (n O O Z Cu ti cuZ •E oh •c I ›,c) D c If ItCU a) ZOi N O) r N N N N CO CO 7 7 >. >. N. 0- >, >. Cl) fry r d o n n n n n M0 OO coco O0 0 o co O C (n (1) 0) N d ZZ a) a) 0 = p 3 3 3 3 3 3 on n n n a n n Q n n w (n CO CO 7 Z z (V N a V CO CO V V co co N N 3 3 3 3 3 3 3 3 3 3 c c In LC) a Z (0 N tl a v) Cn N N O 0 Q w E Cl fl _ _ _ _ n on Z Z Z Z Z Z Z Z Z Z 0 7 Z Z cN") c`? Z Z LL Cl L U O a u as N N M M 3 3 CL d — —_ d d — — d Cl COU) Z N CO Z N N N N N N V V CO CO C0 00 O) O) O O C0 O N N O C LL a) W W N N N N N N N N M M ZZ M M M M M M M M IF O ._ y m0 Z Z Z Z Z Z wow Z Z Z Z Z Z ZZZZZZ [1 a Z Z Z Z ❑ ❑ Z Z �' cU `°CD C a ❑ ❑ ❑ ❑ ❑ ❑ (n (DU) U) coco 0) 0) 0) 0) 0) 0) U) U) UU OO 0CCnCO 0 0 c) 7: � i Ty 000000 NN ❑ ❑ 0 ❑ ❑ 00000 MM0000 � � ❑ ❑ 00 O C/) p to Z Z 0000 000000 ZZ0000 z Z_ OO , •�•• O U co co �t V co co 0 N N CO CO V V Ln Lc) 0 0 0- N O O) m m O CECEE d (00) 0) 0) 0) OOZZZZ ZZZZZZ OOmmZZ mmZZ � a (� ' o E as — — ad as - - aa , , aa — as — — p in,w 0 N N M M C0 C0 (0 co N- r co co CA a 0 0 N N N N V V V ;7 2O co Z N N N N N N N N N N N N N N N N CO CO CO CO CO CO M M M M M M M M O O a O p cc; Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z ZZZZZZ 0 r 0 „) 0) Cn C./) CO CO co co co co U) co co U) N 0) Cn co 0) co u) U) U) C1) U) CI) U) U) C/)000000 000000 pon000 000000 000000 N ,N Z DC C y a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J = y W of y N N M M Lo C) CO CO h E. 00 W OOco O N N N N ;Ti- Zr" V J O 1:10 E NNNNNNNNNNNNNNNNMMMMM MMMMMMMMM Z a ZZZZZZ ZZZZZZ ZZZZZZ ZZZ Q V co }I U y• QQ a3E co 0) nCnnCn CnnCnCnCnn nnnnnn CnCnnCnnCn 0) CnCnnnCn 0 00000 0 000000 000000 000000 00000 0 CA 0 000000 000000 000000 000000 000000 I c c Q F- R• ecn V ) xE LL o •E 0 O O N m C) C Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y CO CO CO CO _CO CO _CO CO CO_ CO CO CO CO CO CO CO CO CO_ CO CO CO CO CO _O CO _CO CO _CO CO co r Q C E R E E E E E E E E E EE FeE 2 E EZE E E E E E E E E E R E 6.6) ,- co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 y m 'm 'm 'm 'm'm F . 'm m .� m 'm 'm'm m m F . m.@ 'Fa 'm m 'm 'm 'm 'm 'm C ra 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 • OD CO CO CO CO CO CO N CO Cn Cn N CO Cn CO Cn Cn cn CA Cn CO Cn Cn Cn cn cn CO CO Cn cn cn Cn 0,.1 O CO CO cn CO CO CO CO CO CO CO co co CO co CO CO CO CO co co CO CO CO (I) CO CO CO CI) CO CO 1 te O d O CO O CO CO CO d ( CO CO CO d CO CO CO d CO d d CO CO d CO d CO d CO CO d C o 0 v = HE 0 0 0 0 0 0 O O O O O O 0 0 0 0 0 0 0 0 0 8a) 8 0 0 0 0 0 0 0 CO7 O CO O CO O CO O CO U CO O CO O CO O CO O CO O CO O CO O CO O CO U CO O U et C N C @ C N Cal c p) c p) C p) C O C CO C O C cp c cp C N c cp C co F.: m E O LL co LL ca LL co LL m u_ ca LL m LL m LL ca LL m LL CO LL CO LL CO LL CO LL CO u_ 00 -50 .3+ 0 t , N 0 -7, 0 . O CO O N O CO O Cn 0 7.-/s cu N O i O N a) E05050 0 o U o 0 o 0 o U ❑ U a00 0 ❑ o o U o U o U ❑ U ❑ 0 Cl.) COC C C c c c C C C C C C C c C O to O co O co O c0 0 CO O co O co O CO O as O CO O as O ca O co O N O ca E C C C C C' va C C C' cu C C C -C40 -8' 0Z0 CO• a) a) a) a) a) N O a) a) a) O N a O a) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000 O N O) N 01 CO O aO C) aO O O) c0 CV N.- C 0 N C C Cr) c0 N O M CO N O) n V (O N- CO n CO C CO C 0 C O C 0) CO C C N- CO CC h N ,- CO r M N CO N- CO C i C M C M C CO C CO C CO C N N O N O Cr) N O N- C N- N W M r N r CO V CO ti M N- (o r` cd n Co r- C C C C V V O (O V Cn (h C C C 'C' 4 C r- CC) Ca O rL co r r e r U T3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 6 . r CC) o cLc) o 0 0 O o 0 C) rn o N- o CA CC) xiC N- N- C) CA Lc) xi cn n cn LO CV 7 S CA N CA N O CA O CO O CO O N CA r` CC) r` N N 0 N h r` N N-r N r N N N C CO CO C C C C C CC) CA C C C C N C C 0 M C M C M C ("0 C CO C ca d= () p c C co co M CO ,- I ,- N- .- N- 0 c0 N- CO O h N- N N O r- O CC) .7 CO co CO N C N- o N- CO O) W O) Cb O) 0) CA cb c0 Cn CO Cn c0 C o r- Cn xi C CA C CO C Cn C O 0 CC CO CO LO .1- .1" C C C C N N N N N N N- O O N N N N N N c`') M Q L F • CO d▪i is O CA Cr) Q .0 .a Co a O) CO m oo Cr) T O O CP CO Cr) O O O N m to to 0 «) C) A O Cry Oi w O O V O V O O 0 0 0 0 0 C() O Lc) O CC) Lc) CCi Lc) C CC'i C V 4 C C C V CCi vi O O- E 3-C C CNA C CLO NC) C C C C C C COO U C C C C N C C CO M C M C CV M C C') C CO 'C O) G E € u) 5 M (h C 'F''' Z �O-, W C (A C co co co In O N O N f11 N f` o N CO O CO O (O O O (fl Z d CO E O C CC) C CO CO CO CA O Cr) M C V C C o N CT O N C N N N L CO co CO co CC CA CA co «) CA co C') CO CO Co) Co) .- N ,- N .- M CO C+) co) co) M C C d a £ w z N •C N C p w p 1 ti Q Z d 7+3 W .a CA W O) CO CA Cr) O) O) 0) O O O 0) CO O CO O ,- O C N O CC) LO CC) CC) CA CA r-- co x `. 0 O C O C O O O O O O O CC) O «) O CA CA CC) CC) C CC) C C C C C C C CC CC) C C C C C ' Lo CA C C C C Q S M O CA N CC) N O CC O CO C) 0 O N CO N- CA h N N N. N- N N- N- N N- N N N N N Q^ C CC) C Cf) N4 C CA co C co C co C co C co C O R O Z d •a m 0 0 2 1 2 r..- c. Z .E 0 u) 2 1 >,0 D T T O O CO T N_ N N_ N_ Z Oi N CD Z (O f6 Z Z Z Z C C 0 a a a o 0 N � o 4 0 0 0 0 0 0 0 0 � � 22`0 = N N 3 3 Q t p Z Z z Z Z Z Z Z p o m m m m 0 cz o dd dd o) °) C) 0wr- r� ado 0 CAC p o ° N m a d z z Z Z 0 0 a a a vE a a E E E m m z z N N a a .L 0 . o 0 CO vvaaaa aacoco rnrnnn Coo ZZZZc) ()Z CcoM MM ❑ O ❑ > n n MCO C, C ❑ ❑ ❑ V C G OCO C O LLeLe_ zz Cv) Cj co M co co z zzz O o., 0., u) co cncnconF.-.) b5 cn (n O O rn p" � 2 E 2 co co 0 0 `' ' � Tu 00 00 00 OO9900a NNNN (nu) OO COIIMY 00 0 0 ❑ 0 ❑ Z Z Z Z 12. 0 0 0 0 0 0 0 NNdddLLCAC) 0 Mi U xrno W 0_m maa c0 a � �a I QQ , Z Z0a � aaaaaCC'4C'NMMas a O O CCO d 0 W0 p CO C C C C (O (O co co co co N- N- O O 5 ON N _ aLLO o 0 0 0 0 M M Z M M M M M co) M Co) Co) Co) M M (h CO CO COct dzzzzz z z z z z z V c?) M I- I- ❑ ❑ zz zzzzzz O- M O L , 'y , � 0) 0) n n nnnnnnn n n nv) z z (n nn n (n (n co co 000000 o 0000 000 ❑ (0U) Cncnnwoo 0000 ❑ ❑ N z 0cN 000000 000000 000000 000000 000000 J = yO c 0 M M M M MO o CMO MCO CO MO M rM M o M M M M M M C C CO O O COC CO CM MCV JOp CV CM Z O., Z Z Z Z Z Z ZZZZZZ ZZZZZZ ZZZZZZ ZzZZZZ Q o . C - > CO co } V O dQy E cn co co co co co co cn v) co u) v) co n u) u (n (n co cc) to co v (n vco co (n (n (n 0 0 ❑ ❑ ❑ 0 0 0 ❑ 0 0 ❑ ❑ ❑ ❑ ❑ 0 ❑ 0 ❑ ❑ 0 ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ 0 v) 0 000000 000000 000000 000000 000000 I a 1- Urn a O C 0 C N O/ 0 0Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y C) U) U) U) U) U) N U) V) V) U) U) U) N U) N N CO V) V) CO I oEEEEEE EEEEEE EEEEEE EE i, ` '0 '0 '`o '` '`o 'o o ` '0 '0 •0 '` '` '` '` 'o '` '` '` y ,.. a G> im m m m m m m m m m c m c c m o m m m cis a.• 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2C •^. A (.0 CO N V) U) (I) CO CO V) CO N CO V) CO U) U) CO (/) (/) U) U) 0 V) N V) U) CO V) CO V) V) U) N CO U) U) U) Cl) CO (/) U) CO m m CO m m CO m CO m CO m m m m CID m (0 m CO m I 0 a a a a a a a a a a a a a a a a a a a s bi) C C 0 C n C y £ 0 0 0 0 0 0 0 0 0 0 C) O 0 0 0 0 a) O 0 0 O V O O O (.) O (, O U O U O O O U O U U O 0* m E O Il m LL (a co m lL m (L m LL m Il CO co CO Il (a tL C — U) UV) O 7. VUNUUUN U) cp U) C ❑ ❑ a) ❑ a) ❑ a) ❑ C ❑ C ❑ U ( U CO£ C C C C C C C C • as C) as Cas C) m Cm C) m Cm C) as N as am O) O N E c m c m c m c m c m c m c m c m c m c m F + co m m o o m m m m m o a) m a) a) m m u) 000000 050505 000000 05 d co co co _M co co x- 0 O U) O (O N- N CO r N_ (O CLIDO V) N V IO CO N N CO CO CO U)O CD O O N O a 2' M 0) CO M O) CO V 7 0) 0) CO CO M t` N 0 O V CD t` O LL a — co ca W M N co cc) (O V O c•) ,- (O '— r` V C) r` O) V T + d LL 0 co 2 -a r- o r-- 0 0 0 0 0 0 0 o O 0 0 0 0 0 0 0 0 E N U) N U) O O N) U) O U) U) U) CN O O N- to U) O 3 t V N V N U) O CD N (O CO N N N O U) I� N In N-CO U) V V' N V M In N CO V In M U) V N- V U) CO I� R d C) 2 CIV C O) O O) CO CO (O M CD N. CO r- N CD N M CO N O V O) O) U) O) U) O U) V M N CO I- M O) M M U) C) U) dC V V V V IO U) U) U) O CO O) O) O) O CO CO CO COLO U) N ra 12 C. O . Oi ,i- 0. C) O w C) Q o '8 .p N- CO co M N N N co N- .- CO (O Cr7 w d N In N (n O O U) U) O (O U) U) O) O M U) V U) O) C C. ' t V N N U) O N- N (n N- N N N O) U) N- N N- N V C) 0 O. E,C m Q V' V N V CO In N M V' U) M V V N- V U) M N d a co aa11 m >, •E ECo) co (o 7 r Z • C) co O co V V O) ,- co s- N Irl C) N r` I,- CO ,- CO N d SD Z d (La E y O (+i6 CO co N C') Co Oi 6U) Co C7 CD (+7 Ci In (O O m CT n O U) U) U) U) U) U) M CO CO CO 0 O O) 0 CO CO r` N- CO N- CD CD d z a) £ = 3 3 N. m y Cl) •£ a" a o c G w 2 CI E E ` Q _a M M Z d 'O W -O I,- CO N- CO M N- I,- N N h N N- i- CO N- ,- N- ti v- CO Z Z Cl) d N In N 6 O O U) 6 O U) U V U) C) O M U) V U) O) Q £ lx6 L t V N V N in O r N If) N- N N N O) IO N- N N- V' h N. Z M )7 0 - C V N V Cl U) N C') ' U) M V V N- V U) M N O pZ as d ZZ d ---a m e: 0 CO m 7 E 0 0 N. 0 z - I• OT co 0 C., _ _ _ _ o 0 Z Z 0 N O Z Z C C C C I _ = O M CO � N m@ (` 'm o o Y Y YYco co co co Inco 3 O d y ° CO > in in 0 0 r` v •v m 0 OD O) Co co CD CO ` p m m ) a) v v v v v ' z z n 0. o. o. a s o. n n n L 3 O , o E z Z Z z z z z 3 3 3 3 3 3 3 3 3 3 u) u) u) co U) u) e0 eo U) In N- N- C) rn O7 Z 0 C , m LL Z u) v) ❑ ❑ ❑ ❑ ❑ ❑ a a cn v_) a a v_) cn ` o 0 3 �, CQpp00 OOzz C N C) O O U) (n U1 U) (A (!� (O C0 h r aD OO O) 6) N O L ) = C) C a_ �' �' M M U O m m ❑ ❑ Z Z ZZZZZZ ZZ 2 E V UO) O H ❑ CS u) U) C C C C O O ❑ ❑ 000000 ❑ ❑ lL a U) 2 d ❑ ❑ m m m mvv 00 000000 00 Q o £ i o U a) 00E ,7688 O O Z Z O r • a)o £ QQaa22 22 2u) (ncn (22 corn = o O (o w as U) U) in in CO co r` r-- CZ co a Cl... d d a o z v v v v c c c v v v O M O O o M O � 0 ° n d v7-7 ziU) O) u)iu) u) uz) U) U) U) zz zZZZzZ ZZ o 1Y c r4.-: g 000000 0000 "") cn cn u ) (n (n u) z N — Z •N� N c 000000 000080 000000 00 0 J — • - tococococo N- NCC „ J o C ° mo RC 1- � � � � � 'T � � inin (9 ( NNC) C) a) a) Q V - mac a Z o. ZZZZZZ ZZZZZZ ZZZZZZ ZZ CV C m (a �, £ (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n �.+ O d o 000000 000000 000000 ❑ ❑ I c 5 o C Cin 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CIQ 4inrvn • l0 0 O 00 6 Q a,• a O bA a O O a CD CDo Q o 0)a)▪E Mo Z `° riaa ti °' a N = ai a) W Z CO E . � ca.) O U N L O 2 a Tu c z a 6 3 aa)i m tic a c r m U I C 3 Z 0 , • U N L c E CO - (6 _ Ca O N c y c_ O O a) b O N N \ .0 a) n • w - i — c ac) 2O OCL cN 3Na) aC) aa 0O ° cco cp) a) @ a)u) a) a) I— "6 V) a) a) O U O Q. .O. CL m O Et co UN " OS N NO aLci .,-- 3 C N 0N yO a3 y 0 O C U U N Na) II N ON N_ • n Y 3 o NJ o76 .T a) LT o o 4 O O O m U c U c O +▪ + a) `, m c 2 _m m m w < ul U u) 6 U Q CO CD n L. at C L J J 4 L 0 = a L a L :E 08) c C O MN co N a Z N f 2 A N V 1 Li a> 0 � a L )s. .W o 001) .t Mre E O W O Z Z + C 2 n o m 6 M O O 16 2.. 1),0 u) E c 0d 0 N N Om t 3 ,.. ,... os .Q i A\ Z W 1 V/ a) co -o " 3 — tc w a, 0ai� O '� L V 0 N 0 y p Q 0. C •„e„ Cil Z a7 LL•co tv co m o hal. 3 m N v N c a ■� Q A! O N zoo a C '^ p _,, ,,! ©82 E E iii Q' V' i t0 U 'O m 111 •L z = 0 O ' w ao _9--6 LL 1. 0 0 Z Z d 0 0 + o O. a a L M O 0 r ”^ o � omm = = ti I` ti L C Z rnwv NnLL7iOJN - L L r l� r cor/ N y ayi t v, m o oh U - z = . . 4 m cAV+ ■— p rn ti o 9 o W Q Q C C Cl) Cl. W }I �+ c d Oro' w c. c. o 0 0 C _ N O 0000 CO a) 0 Q N m w o 2 m o 0 0 ill It Cho coc000 > co co ._.. C Po g o o E O 8ill PIT i .aog s.mF -> > i i ITMg $ if ,, `N4‘44‘: 11 1"".'2:41VaiiiiiiPAinilliM0a c U �ssssos80gA8ms�s�sm1srsass0« E s � A4` Q a maim 3 • 1ssss aoMsssssssozn tl:to U 3oo" Qgm<W 2.17 0 0 gee COLU c.aQ 'CD e 140 D V m444T14�nr m J Di J IT �" �88sb',0th f'RR44Xfr3 AxxxxRA U -o eia ,IV*,`` ' ;..... x, e88aa88xx aaaa����< 8xx8 �8Rx88o, Z A'v c r.-Ili 8 mm-,,-.,mmaoo 00� ,4a2%saasaaggm o 000rr.�„ r����e. 4 m.nmmm�mm. d rx ax�.< :�a ammm�m C01-00 0� M �`,,• AO , N U rm.mm mr RrHr«RRnRRR Pm c' .4 > ❑C«050 \ _ O N O --I 2 UdOo ? d E.' o 0 co U >, O rLL d dl– N ' 15RaE C C.- U 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000 0 0 0 O N-I N 0000 . O N O . 0 . O . 000 0 0 0 0 0 0 0 N 00000 . 00 0 O N O .4 0 N . A ON . h O N y 1, 000000 0 M . W r W M O. (pre Y F N . A 4- , 4- 4- N N N N M M M M a 0 (O A 00 0 ell O 1 , 0 _0ix O m Z cA 5 U I °o mom M G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O U c U . E S O N O a O N O S O N O S O y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N If/ A O " ' O N N r O N y r O O 000 0 . 0000 0 0 0 0 0 0 ' E Q TIC N Q N N N N M M M M O . W r W . O N M a N . h W O O CJ () U m Q c c V a ¢7 C d y � ~Wd' G' Ifflil U. `1i o — 0c c rn rn .Y c _ .2Q � oc LLQ o ���'�Aii�r m w`m w E \\\i" 470 I ��lIIlI(flfl* 4� 1 ii U W ,.......,...,,„„N, �� -\\ Fell®\\�1 .5,�♦�` II Iqa� -4111111'.... .511� F h � m rya 1\ 'il SI ♦♦6O�AA11111 ,arn /, i�'��lllr��lllll'�� ✓TNL� ,_ Yy A. jOehil•SC? 0 , PI._. :77a1 ifiti A111114W14; u z c W __ z_ _ 01 ..#kidif i I--t.m.- ,4 ...;;;.. lb, loostoi s,,,, .c> :! ‘ ,ir;i, "ft....-,,,..:..,,,,,,, jrc'. , iiii i.44154111,410 o9 Ps 11`in,.. \\- ,�\\ %ill To ?AVIA. ` ',�,�4.`�, I 1 — ~ yawl-zez J vMd�\ i.��� r i m la oa♦♦_ o W vi\♦ iii•��►'♦=11 if \� i ���� ori, H: o ..`�v a s ���� :/I�l`diiit ,�`-`0 —� " ul c N A J mN o �u��'�Y%,I'/irr►�11:,,+� � � L p z �u J a .a 8 11 .°.9 1 Ir 71st♦ iu:.�� uzi y4 N yi U o c rn� > rn r, / �w '`r��'�Y�.I. �4i1..���������''•'y 'y a 0+�+ E c (7 mr '' p Hi U ! �jt.4044 s4%�►i,'A,#*,.p ♦liW' `a ,� V W v`v`m`al! z tw $ a Ary���r�:���/�!11��6�:"ilei`:�`: cn LL rez z M o a o ro e °o r Y r�� i�\�I��+��-p r �1♦♦���+►��:v;;.`_c Z 1 11111 o �4 *Mli. / 1.1401i••p..• a a4- �!/a,3 14-4 '- i 300 O" O� = Z v y z LL�l 4; Ero N . a N `o> w m ieo •`/0 O O N A I+- v, U "26 t �f_�g +o O O x• 0 Co O coa o c 0tIlL O co 0 C3 Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y a) V) V) CO (I) co N CO co co _o _o CO V) V) V) V) N CO (0 V) Cl) Cl) Cl) N V) CO O E EE EEE y :r. O 0000 0 9999 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 .8 .8 a) m m 'm 'm 'm'm m m m m co m 'm 'm 'm'm m'm 'm 'm 'm 'm m'm 'a 'a //C o. 22222 22222 22222 222222 2222 I� O N V) N CO V) V) U) V) CO V) V) CO CO V) V) CO V) V) V) V) V) V) V) U) (.0 4) V) V) V) CO V) (I) (I) (/) (/) (/) (1) CO CO (/) Cl) V) CO (I) W V) CO (1) (/) V) CO V) V) CO 00 L CO CO CO CO CO aCO d CO CO CO CO CO CO CO CO CO aaa. CO CO CO CO d CO GAO C .E O E `0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '8888 , 8 m0 `0 0 ti 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o m E u_ I1 LL u Lus L LL LL LL LL LL LL co u Lus L LL LL LL LL LL LL @ u @ LL IL LL p" 'c a) a) a) 0 a) CC O a) a) a) C) a) m a) m m a) 0) a) 0) N a) N a) O a) 0 0 0 0 0 0 00000 0 0 0 0 0 0 0 0 0 6 0 0 0 0 0 c c c c c c c c c c c c c c c c c c c c c c c c E m m co as (a co co CC as co co co co (o (o co m 2 m a m m co m m E co aa)) aa)) a0) N a0) co co a) co co N N co co co co co co CD co co 0 co 0 co co co CO U 00000 00000 00000 000000 0005 N L- LO O) O O) C)1 O) 6) 6) (0 (0 O C) O) CO V CD N CO N N CO M L` co V U N N LO• V V CO O) 6) - V N h CO V O O) 00 O N- O V CO O CO N CO a) O) O) 6) 6) 6) 0) co W ,— ,— co. N N N ,- CO O CO � CO CO LO C 0 CO (D N N N N r — — c+) M N- N ,— ,— ,— 6) O) a) V — ,— a- ,- V N a) LasL U '0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O 0 0 0 0 0 0 P. (0 0 0 0 0 0 0 0 0 n n o o n n n 0 Ln n n n 0 o o L0 0 t LO O O O O O O O N N LO LC) LU LU r r n N N O O NNO O CO LO Ln LO LO Ln LO Ln Ln LO LO LO LO LO LO Ln Ln U) In in 6 LO (0 LO LO m O a2 V V M O O O O O O O C6 coO O (D N- CO Ln Ln CO V O CO O CO CO O C O) LO LO LO Ln Ln M N N MM N (-Si N r O O M DD 0) (0 LO (D (() a) G CO V LO LO Ln LO N N N N- N LO LO (0 LO LI) CO CO CO CO M N N N CO V N M a- a- a- N N N N N N o - ^ = ,a OiLIo N N. Q .0 .O Mf` f7 n n n N N N N N W CO O to O N N V CO O - O Ln CO LO ON C) Od £G N-M N- 6 O O V 4 CC V O M M n ) V O O O N O D co O O O O O O O O O O O O O O N N O O N t CO LO O O n n n OLO 6 O O LO LO LO LO Ln Ln L.O. LC LO N- LO CO Ln LO 0) � 3 g � n . a a _ CI E u) 'b M M c '. Z w co 7 N N N N a- CD (D CO CO N N- N- CO CO O O) CO CO O N- O Z d La E O ' co C') M M CO CO (6 W M (0 CO co N N CD 6 N N- CO N V N a Z '- O V r CO CO CO CO L!) Ln Ln O CO h CO CO CO LO LID N N N N N M M CO (0 r £ co N C_ N_ "� r c O N O Z d ,a W v CO N LO LO LO LO N N N N N CO CO O to LI) N N V CO O O LO CO LO CI) c E X 0 N- r Ln Ln Ln a 4 V 4 O C() M Ln Ln V O O O N CO CO 0 (a t (fl O O O O 0 0 0 0 0 O O O O O O N N O O (7 co LO L() LL� In LI) LC Ln LI) Ln Ln Ln LO Ln LO Ln Ln In U) LL7 In r- LO CO «) LI) O a- a- a- a- a- l- a- a= O▪ Z 03 ?a m i O 1 l0 ti 1° z •.£ r O cs) c I >.Cl n u co — C ' N (,) V) L.L m (a co °' O a C v O 5 a Z >, > > Z�/� .0 N 3 N 3 Y 0 Z 0 a Y ,_ 0 C) CO CO n V/ fn O. O as 'Cr 2 m m Cn O (n _ 0. Q n O. a O a) p YZd = nn m m (n ❑ (nm 0ZS 3 3 3 3 3 3 C Z O V ' ❑ Q. d Y Y a d = = a LL d O. d N a- a- O O N M Q � o 2 p £ � ihYaY aCL CO o (N CO Y ' Y ' Y LL, Y � av) u) ddZd L () D y V to O Y fn CO a a M co LO Y M Y v 0 0 N N Ln CO Z O C 0 RLL Z (n ❑ M ❑ Ya vp n - � a- - � a �F O = 2 0 m ❑ O Y O c�i (n Y 0 N CA N Z Z Z Z Z Z Z O LaNc Y (on"o O@00 � v) a) ❑ a 0 � g01L YO '- ❑ 00 0000 C.) 'c o y a ❑ ❑ 0 o_ ❑ 0o_ (n , c:1000 0 0 0 0 O O La y 5 Y00 o NI � c 0 7 (� cs) coN (13 Y V �" 6 7 ❑ N d r 7 O O_ D_ Y O N O O N CO CO Ln 7 M ,+�' Z Y Y O CO d Y d Ln Lan Y Y d Q Y p a Cn (n a a Z Zd av,' E O w 0 — Y ( 0 (0 .7 4 M M M M M (s.I FJV' (N O O a- CV N CO ('') (`') Y Y V V O C a 0 co _ d o O Y Y Y Y Y Y Y Y (n (n Y Y Y Y Y 'T Z Z Z Z Z Z ^O M •0 � o � CC G Oj000 00000 00000 up 0) 0000 N = �U) Z• �Ln a C O� Y , Y 000 00000 C . 00O 000000 0000 3 d d C y 3 L c`') M c'') c'') V V V C'') C') La Lan WCC N N ' O N N if) CO JO O Lo La L Y a- a- a- a- — — — M M M M M V V V '7 '7 a- " a- Q V >, 0 R La a,z C00000() (n (n cn (n (n Cn Cn (n cn () (n (n (n cn cn v> (n Cn (n (n (n cn (n U d CL 0 m 00000 00000 000000 0000 _ C > w C 0 U 0 Y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 eL la 0 Cl.E 0 O L U m O Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y N CO CA CA U) CA CO CA CA CO U) 0 CO CO CO 0 CO CA CO (I) 0 Cl) U) CO Cl) CO N U) (A CO CO c REERE EiEEEE ERirizE trtrEEE EEEEE EEizEE s.y x 80 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m'm 'm'm 'm co 'm m 'co 'm m 'm 'm'm 'm 'a •m m'c, m m cc cc m'm m m 'm'c m C 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 /�"'� CO U) V) CO q) CO CO CO N N CO CO CO CO N V) U) Cl) N Cl) (A CA Cl) Cl) U) to V) CO U) CO Cl) all O N 0 CO 0 CO 0 0 CO N (A (1 CO CO N 0 CO CO N 0 0 CO 0 0 0 0 0 0 0 0 V) I 2 CO CO CO RI CO CO CD OE C 0 o a = H £ `o `o `o o `o `o o `o `o o `o o `o `0 0 0 `o `0 0 0 `0 0 0 `0 0 0 `o `o m 0 eis00000 0 0 0 o 0 00000 0 0 o 0 0 U U U U U 'Citric-sr) m £ LLLLLLLLLL as co OS LLLLLLLLLL co cc p" i*:i: teN 0 m 0 0 m m 0 0 d 0) m m m 0 0 0 0 0 m 0 d m m m 0 0 o 8 p o y /0 c c c c c c c c c c c c c c c c c c c c c c c c c c c c c £ CO CCI CO C0 CO CO f9 Co CO CO co Co CO CO m CO Co C6 CO (o Co CO CO (0 (0 co co CO a) co E co ca co co co ca co ca o co co co co co o m m m m m m m m co m co co ca c CO O a) 0 a) a) a) Q) a) Q) 0 N Q) a) 0 a) a) Q) 0 0) a) a) a) a) a) a) Q) a) N 0 d N CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O MV M V oVD U) OO N CO) CO UM) O O d) O )N` N)` CO cO O O N O a V MO 0N0 CON c7", N 0 U) (P f` O CO e- CO CO N m O O m V 'Cl- CO CO. CO CO O CO CO V 7 CO O) El tN N 7 U) 7 4 `- C Cn N U) M N4 1 ,- .- M M M Mai O) 6 N M .- ,- 6 ep CO U •O 8 0 0 0 0 0 0 0 0 0 0 0 0 C. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m 66606 n0n00 Ln0on cn0000 06060 00666 O � ^ L) L0NN- COOONNOOOOOO0 o 0 0 OoN3•w 0 CO N O LlU CO V/ 0 CO CO CO_ o o o o O CO (O COco o co. CC Rdp 0 a 2 C O O c0 N V N CD N N O V CO U) M I- N- O) C) 0 U) 0 U) CO CO CO V o 0 Ns M M M 4 N_ N c0 LC) V CA V CO CO M M M M N N N N6 o 0 U) lb O 01.2 V V C) L) 0 0 CC'') N M 0) M N (0 CO C) C) N N N N CO o) CO M e- V H r+ — c`) .-- — .- .4- M M CO CO C% CO CO N N CO M C+) C') V V V CO M 1- N ami w a O N N. Q a a Un N- V W N V U) CD 0 UO 0 O CO CO CO CO (D CO N N N CD UCO ) O 0C') C) OQ) G •£ CO O N W UN N- O V N N O CO O r r V V V V OA C) O O N- M O CD O N CD _ N N O CD O O O CD CD CD 0 0 0 O CO CD CD c t Uco U) ) U 7 ) ) fUco ) O ) ) U) U) UUUU) n L) L() U ) U 4 UUT E 74 E N 2 ° M M c @J Z +O-„ O O CO N CO O) CO d' Co N M U) CO r N. V V e- CO CO CO 0 st LO U) 0 Z d Co E Q CO MNN CT M O V M O O co c0 c0 Cb CO CO CO N N CA N- N N N- CO CO V CO V N- 0 CO V N CO L) as a> N N V V V V V V CO CO ) '- coN. 7 0 M e- e- 1- V C) COM cr M COM COM CO M COM M c') COM COM U) U) U) COM M M N N a _Z £ � E N h .= )- l""' C ° N ° 1 cu o a Z d ,a_ W a U) U) C- V co - N V U) 0 '- 0 Ln CA O O CO CO CO CO CO CO N N N O U) CO U) O Cn cc E )CCV CO CO N M U) N h O V N N O Co Co r 4 4 V V C) CA co O O M O LCI t O O N O N N 0 0 CD CD 0 CD CD 0 0 O O O CO 0 O Q t M 2 C7 a- U) U) U7 U) L() U) to Ln L() U) UU)Ln ) L() U) U) U) L() U) U) U) U) Ln Lo. U) Ln U) 4. U) Ln d - r- - .- - - - - - - '- '- --a- . a- a- a- a- e- a- a- a- a- 1- a- a- .- 0 0 O 21. a1))° 1` R z - I ° m >c a), C1 o m >. N CU Z 2 O. w " 3 as O Z M 8 N- N N CQ j cn N 0 N (` U) CT) d o ayi (j z 3 co a o a o 0 0 (0 8 Cl) a) ? et(n _0 7 0 0 0 c Z ° 7 c) _M d — N> co M 3 3 0. n o. n (1 Z 5 m Z Z Z Z Z o 22 ,- 0 2 as cr> 8 O cu ° d ` O Z J Z > d fn Cn 0 3 N M V Z CO N CO d d M M 30 O C£0 a � a � 3 a 3CL Z a zaza (n mZ (? Za aaaaa zzZ " L U . u) ,50 co co ❑ N M d Z V V O CA (n (n c• N COj 0 O (n 8 (,) __O N (n CO CI) Z Z Z Z Z Z o ZZ O z (n (n Z Z Z O) Mu) O O CO Oy D � m O O Q O O O z O 0 0 0 O z 0 0 2 0 9 0 000 Z O ❑ ❑ o i M a ❑ 0 M V O ❑ ' c\I srs ❑ CO , , O @ �m b IX (1) E 3 v U • trm z zrn cniipzzzzp mzmzm ammmmNz O❑ z � Oii E a o.. - 7, a , a - a a , aa - d a a a pO « .CO o ao @O (o M N a NNU) OMO C.4MMCD CO CO � M _ _ N Z N N N N N M CM M M M — zzz ❑ Nzzz zzzz zzzzz ZZzzz Z IL I- O M O o _ o (nnn (nzn . 0n (n (n 0, (nnn (n (n (ncm (n (nncoco (n (n (n (n ❑ 00000 00000 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0000u) c) NZ .151 in-w co 0 0 0 0 f 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0000 ,0 j J = � NCD d d N c CO (O CO O N M U) CO r N O) O N N V V . CO CO CO r O) O) m J0 C ° C) O W 7 N N N N N N N C'I N M M M c"'""'") (`) C) C`) C) M (M M C') U) c`) cv J V - 0 c =o Z a zzzzz ZZZZZ zzzzz zzzzz zzzzz zzzzz • c R N .d. E (n (n (n C) (n (n (n (n (n (n Cn (n CO (n (n U) (n (n CO (n Cn (n (n (n (n co co co co co a.+ U m 0 ❑ ❑ ❑ ❑ ❑ 0000 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ _ _ ino 00000 00000 00000 00000 00000 00000 < H 1) (n H • E � a c o c o O 5 R 0 Y Y Y Y Y Y Y - Y Y Y Y Y Y Y Y C.) 0 0 0 0 N 0 0 0 0 0 0000 (1) 0 0 EEEEE EEEEE EEEEE E y ,- R 0 0 0 0 0 0 0 0 `o `o o `o `o `o `o ccs m 'm 'm 'm 'm m 'm'm .8F 'm m'm 'm 'm 'm C Q. 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 N 0 0 0 0 CO N N(0 (0 (0 () 0 0 (/) CO CO p"'�.1 o Cl)` (1) CON N N N CO COCO N <I) N ( ) a03 ( L O aaaaaaaaaaaaaaa bio c ., 0 = •a O a E 0 0 0 `0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .r m E LL LL IL CO C3 03 LL LL LL LL LL LL LL LL LL LL LL CO LL E4 Z,'E CD O) U) 0) U) ) N U) U) U) U) 03 U) U) 0) 0) CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 c C C C c CCCCC CCCCC C o) 3 E (L6 @ N N CO 06 CO C3 CO @@ (6 N N @ o CO E N co @ (6 CO CO N CO CO CO CO @ (0 CO (6 @ F- + 3 0) 0) 0) N U) 0) 0) U) U) U) U) N U) U) U) U) CO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 y N co O O CO CO CO CO N (0 CO O c N V CO COCO 0 CO 0 0 O CO coLn LCDIn co O c i O ( O O O COW V • V coM r lL') O N p LL t0 w W co V Lt) V M N N O (L) tb O coLL) V M �., + mti rrr r r r r 00 U co g 13 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 . . ` O (n LL)( n LL) LL) O O LL) (L) O (0 LL) O LL) Ln ( LO t LCD N N N N N O O LO N LO N N LL) N N n tt) CO CO CO CO CO CO l0 lt) (!) (17 17 «) CAa rrrrr rrrrr � rr � r N d @O C 'Q U) LO O LL) CO V CO V O CO O I,- r O V O O O V V V' V' (fl V'Cr Lf) LL) LL) 4 r N I.-- 00 O N CO COCO M CO7 O') O•) N N N- N- Lo N MO Q` rLCDNr r r • co E. w Q Q Cl) r� 0.. O .0 -13 .„, (n O L17 Ll) to O CO CO CO O N- N CO M CO V � O $1 O O O O O co ,- O O M O 0 0 LL) N N C 0 3 O Q r r r r �- r r r d CO0 LO LO LO LO LCD LO 03 a P MU7 d v d O o .E H C) M C' o m' Z C r O N N N CO r r 0 N r r- CO V N Z d A E O M O LL) LL) LL) N r V CO N LL•i O O O N. O 0 CO N CO CO CO O CO CO O N- OO O O O L0 O O O r C N N CO CO M M CO CO M r N N N r r r C1 Cl CL z Q E.m I%••• c (I) I) - G 7_ -30_ E IU) 0 _Q co M Z d ,a_ W .a Ln O «) LL) in O CO CO CO O N. N M CO OO . Z Z 42 aZ sO N- O O O OO O O (O (O Ln V n NNX U7 cu4a- L 0 0 0 O O O O O _ N Qt2 N QE LC) LC) LL) Ln LL) L° LQ. (L () In (LLOLQLQLn (° N< rr rOOZ mOQ 0 2 0? z r. La 00 1` w z - 0 co c >.0 n TN N 0 O O r- Z w Di s cc Z ZZ V Z C C I I O O CO r j N' O-p ami c d LL a m m o Y Y LC M9 Q p a o N m m 3 d 0 3 0o a0 F �.r m O d 'a 0 W OO •,- >, l[) CO N ,- co O co M r O d d ° ° Z "a v v CO O v v v O O O O L 3 p a CO 3 3 a Z z a z z z 3 3 3 3 3 o M zo °= °�' L` d CO CI) z < 000 z 0- 0-00 `�cn `C- � o © {.� c in 2 o c� v (n (4 L? (o oo rn o L a - S-' co Q Z Z O N N O z CO U CO O COZ (n (n CO CO O O,E ,••' tf) r Q >.� od 0 ZZ . 0z C C ❑ ❑ ❑ ❑ 0 U. co 3 v U Q000 N Lop m m v O O O O 0 O Lo aCO CO CO CD 0 20 . -- c O co CO O O O CO LL) Ll) (o h O e p o O Z M v v v v v v v v v cao oao o O o op Z Z Z Z Z Z Z Z Z M ° s o � c) Zz (n (n (o co (� (� (n (n InZZZZ Z o LLLLL� .y Z ?)LL'C•1 d o 80000 0 0 0 0 0 O 0 ❑O 0 ❑O ❑0 y LJ — y r d d N O O O M LO LO CO h CO J o d , M V V V V V V V V V (O 00 N ° = a El)ii z n. ZZZZZ zzzzz ZZZZZ Z Q .T C co co 0 E Ln (n (n (n Ln (n Ln (n U) co (n cn (n (n Ln CO "47. V dcc o ❑ ❑ 0 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ 0 w �nO 00000 00000 00000 0 _ _ ro� Q I-- Ce U) V) xE � c ex c c cc 0 0 O O 0 u L Q 14 1 ObA a O O GA c c c —Ai — eu 3 a; o N. a Looa) E MC vzr E. Z m n O. °' ti a N 1 0 W Z cig a) L CO a) a) o U CI m 2 E c) C m vi 3 a) m I c c p N a) 7 T"' fl- 3 m V I C Z 0 a) U j N4 C E co - f6 ._ V� N U V C_ O0 co 0 2 O . N co y z co ` ZO ` o c E C co ` N• d a) d C Uam ' 00OU nc C as _0 c 2C/' CU Inn a- a) C a) U co ) Cecu C .L.. m V 2 oEt2 N C U C N C N n CU U o (‘3 3C O m �O 115 yNN _ON n un Cl) 0)E a) ` J a 0 2 m C J 0 mZ tcc° N Q _ • d C U COns C 0 C m I CQ m � � � N � N W 0 co 6 5 .. 2 03 0 m a) J L J L 4 L 0 = a to mNe M 12 13 O 0) M 3 .€ O IDCM O O Z0. ° 0 .Na0 cid azMcu N0 c, c0 0. co N 1 d ov a ° L ® IHH co(11) in .t CI• u) C0 C CO 0 o N M 3 •M O O L N a AOm • o w I ci . W duZjW � as j ) ++ 0 (� O N .0 V Q D)• Q p woiZ gLL • CL (1) 73 73 Cl U) 0 t) •— Z ,c; rs cc Cl. W LLI 7.1 o R 5 03 cc QQ C) ■C Mw � d L <oV - w� N V x 1 CI z Z C. _ a c. . + 0 0. -J Om d d C. O O— o ozu, Nr m ,00o = 7 1` ti L O Z °r:: v o N � -1 cv - i i r r r ID V N d d c t — m c - 7 3 . I I ■ .o ci :a 0) rn U N ai ai Q QCO CnZZ Z D W r. �, c $ xRRoc � � Q Q D CI 0 1. -, v � U B � re t, o � � 0000 0 Ui V < N `�° w' �, 3 ` 13000 r 1- ct 3 o co u) 0 > m cn 1.11 111 U O a _ o 0 .-7. O N O O N C i II ,� ";?Ot "'R `�S�$�o8$ WnW$. s� Ww � m maa a co ZQ .,....-..0..---0.- 0 m .- -rm r �e p 3 0 + z<s3mmm a�ar� �^ amps (� a0 V 1!J Totsmem. ,. J Go Ee. 38888888$aS�OiYmmRR88$$9e<izmv) mV ZL /OW 4, - 8oA9,8,8,$$0$8::$$nn80^.:8$$8��811860, N�,� Qj d .- 0 .0«^""'"'"'"130$$$00$$$$00 ZNo c—I-- Q r ryry...A,ryryryry.mr,r,.-,NNA,mmryo0.<N..,. Q —11i=1 o &NO2122 oLL . r �< mme:« a $$a a "a Nom 1$m VC• Co cpcks 2:2E:0 0 � o 00000,_O. M _ N - L C 0 - d w ~ — N E tg O= O C ❑C4V C � O O O O O O O 000 O OOCJ 000 N O N 0 N O In 0 N 000 0 0 0 0 0 0 000 O 0 O 000 0 O 'Ca W 0 00 0 ,- ` N A O N N A ONO , O 0 0 0 0 0 N M a N W A W A O N N N r N N N N M M M M 0) 00- 00) = OL Y r 2-7-2;d o o 2-7-2;y0� 3 m ,. U U o o m _ a o U o m M ooN0 000000 0 0 N00 000 0 0000 0 00000 0 p SC-) 0 '4-42 No IOIOON O N O NONO I2 0 0 0 000 0000000000 NO -- ' N- NNNNMMCMV nWNm010r NMO n 0 AMMO IEU - 0 LL d EU as a NiwK JC v -o ai-o O Q uo C L ''r c L C d l a)t 5 ll al 1• a CT' C C 07 li rn O Q V O C W ��0�.. C �WtJW ial E (n Q i o Afar . es t. p 'Oil 1 --- ct v aZ CI' on O p Of * 1 la( y ...._ , ,/ / 01111k d ..,,..„ N Ii.IA *4 FnN / +._ v r N., 0 0.4 gat 1 1 ON _ o n N N A oro E. H p ^-.7-7 cC4/-,I •p u `` ulak NFG N o Z a -g+d , ® ,, O uJo NoNq -I >d Zg� J O Zy C E Q o-8'' E 1 pc.2 men } O Q O a O r C N W M ` ` , N y W t O H p f Q b Z N O 0/, e0� ``` 11111:Epp cN ' Q 30 N 41 E N g N O>N A W A m Cl) Ts ieo o 2 G L*. 0 Z o s + a a. D • cU) t)) ., c bpO O Z 0E N N 0 O MU O t 3 Y Y Y Y Y Y Y Y Y Y Y . Y Y Y -X‘ C Y Y N CO U) Cl) U) U) Cl) C/) U) U) U) U) U) N_ _) N NCU U) _) _ 6 - O .... 0,4 0 • O O(6 c6 @ @ .O 6 O O O O O O O O O (6 f6 C C @ F E m(6 C 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 ^O� Cl)a co CU N U) U) U) U) U) U) U) U) Cl) U) U) U) U) U) N U) ISI Co (O O co co CO CO CO CO CO CO CO CO CO CO CO CO CO CO (01) O a an. n. n. aa a0 Q . Q 0 0 0 0 0 as C .,. o st 0O 0 0 0 0 0) 0 8 „ 88 8888 a)O 0) O =ust ca E E v v v i) 0 0 0 t v v 0 t3 �, (O CO CO CO CO C CO C0 C C CO CO CO CO CO CO C C CO �i m E LL LL LL LL LL 49 LL LL +(.O ,O LL LL u LL LL LL m 40 LL Z` C a) d a) a) a) N a) a) N N a) a) 8) 8 a) a) '� N a) .ter 0 000000 0 0 0 0 0 0 0 0 0 0 c c c c c c c cc c c c c c E CO Co C0 Co C00 m a) Co Co 2 m Co C0 a) '2 CO E m m m (o m . `m @ E. c CO Co CO CO CO CO C c CO o a) a) m a) a) a) a) a) a) a) CD 0 a) 0 d a) a) a) Cl) 0 555505 50055 0 0 0 U 0 00 a) (0 (0 (0 cO M V co 6) (0 (O N N_ (n N- co C) co C ` co c0 co c0 O) (0 N- N- u) 6) V 6) 6) V' CO V co N- N h V CO V (C) O) t- V N CO. CO C) O N 6) ` V V M M M (C) (0 (O (O (O (O (C) M (M .- CO (C) (0 (C) (O 0 COLL C) -0 O O 00c1: 00 0 0 0 0 0 00000 00 ` O (n (C) (t) O «) (C) (C) (C) (C) O U) ori O (C) O O (C)6 t (0 N N N O Ct) II) NNNNO t) CO O N C') CV r O N co co co CO � In N CP O N S O CO (11 CO M N M co• 0= (t) ‘-- (5 ,- M M M M ,- ,- M (C) t- � V C (O V V V co V (l1 co V O c0 (n N O CO CO O N CO LI) (0 (C) Co (O co 6) a0 (O N a0 C O a0 N d C N N N M 0 C) N N O) CO N LO N LO V a CO CO N %) co V V V co. c0 N. CO .4- CO M N. 6) M M 0) 6) amirT- ai Wa 0 N 4) . • CO COM M6) coM 6) v M t� CO 0 O O M O 0(V Cw 0)O � O (C) U) C) 6 (() V M 6 O M 0 N V - - O 4 O y ✓ O O co 0) O CO N M N. N 0 CO V 0)C Ot O V V V r C) 0) (CCO «) 000) V VV Cr) 6) a) V tu E V M M M t` (O (f) V M 4- V CD (. CC) M M M co- CO CLC.E EN0o M Mc l Z C N 0 0 0 V M CO M () N W( 6 h CO Cr) 0) c0 co Z Il ` E y M M O (O CO M N M t� O V 0D CO t� t` CO 0 0 1 N- N- N- M CO t` 6) CO O) 6) (C) g N O O (C) (C) ^ N. Cn U) (t) CO 6) 6) CO_ CO CO CO O N '- co_ (0 T- V- Ii Z y +a�' V) C _) r C C 0 G I 0O a Z d 7 W 'O m M (+) . C) - CO 6) V co t- '0 co. 6 O O 00 O Cr) ce £ Xd O 6 6 U) 6) 6 V 6 6) 6 6 W N t� O V O la L s V (O O M 6) CD M N M N. N O (O V Q .0 co N C e (O V '0N- C) (0 111 V CO (n CO CO V V .:1- 6) O) ON. (p d V M M M N- (n (' V M V V O) CO 6 ) M M (O (O z Z a 2°)p m N- co Z . • co D a .N- Cr) .. ... ... (a O s w m 3 ami aTi Z Z v z c c c Z Q 0 d j M 0 0 0 Z Z 0 (E 'ED C o 0 COCO p 0 co 3U) Z 3 3 3 COCOmm ; m 0 `o `0 3 3 Q C Z 'p V M M J V co (O N N a a � H a a, v Cr O 6 0 7 •6 0) Z Z CO (n () (' Z Z c) V (n N V V V V Z Z E a s a s a Z O C O_ d lL Z CO CO Z N N N ,t V CO CO V (n (n ❑ 0 0 Y c (n � oCV ZZ2ZZZ co co0cococo co co00z vOOOO ZZ O Ca = C Y ❑ ❑ ❑ ❑ ❑ ❑ ❑ N N ❑ _M U m m N ;= n m 00 (;) 000 UO O Z a) a) N 0000 O G o (a . . , . Z Z (n Z c c c Q `Y (n N ca co co Z V CO CO CV CV d d (n ❑ '(0 '(` ', T ix • 6 8 EE C r0, co Co Xk C/) O CO CO N m m 0 0 0 0 co (n in co r N- ib Co C 4 0 0 0 Z ti; Y - "- N N N V '7 'd' V 1' V V V V V V v o O • co U) la 'L ZZZZZZ zzzzz zzzzz Z Z CD'.• v (Cl 0 0 0 0 0 co 0 0 0 0 0 0 0 0 0 0 0 0 N .y Z• .0)el N c O Y Y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 —I - y - o �c 7 'O G at d N 3 N (O (O (O N M C') O O O O M (O (C) O t- ',1'; - c0 00 ' J E L :) N N N V V V g V v v V V V V V N (, C (dj COC'O Z Q- � Z 0 Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z ZZ 4 �.•+ co U dR' LL' . c 0 m 0 000000 00000 00000 00 _ .- R (c03 a coU O Y O 000000 00000 00000 00 Q F � y N co 0 y CO rL O CL 0I° _0 0 O 0 O N S. Q I) O 0 O OA .a O b01) 0O 0 0 0 CI Ao 3co CO m 2 co N aU O °- >, + U' 0 th co 2 . O Q O co Q) m CO E Z M m' . l— a a Z O cn 00 co O. 3 3 m r•-. 77 m N d 1 C) C) N W Z ZZ ` ' U N L CO d d m a� O 2zo co _0o a c w 1 OO c c a) co co ti 'o m a r o_ m m 0 Z O O O N U j Cl) O Co 4) d c E v+ ° w LoW • N U y c ~ ` moo) 15 oo o m 0 2 O N — L+ d o_ 'O N 1 N N O 4. N• O c C 0 m L I-- O N N N j 0 O £ v S o m m m d m ■im. fa.O LL N N N 7 �A1,, O N N c_) V To o if W m m m N CD m U LL O 2- '5 co 0 O ii6 4,-,-, N O m O 7 al i) m 'c U 8 a ii a O .'A y N c c VI UUi O O O 3 J c - � N � 1, ° U QCO d0 0 O cn I C Q a � 0N � N W 0 co 6 U Q m m 4- c"- `•e } ; L� 0 1-' iil r, i g - _ i rpt-..•• . •• IA f •i; a :A` _ V) S i U OP 1;r• e Ot•,t. a v 9 •1 J t�r `.� p a•• J 0 _ • _ .o _I ill agb I or ° 9. ,� • •t ••• o v' oLo m . . c , ° o F a E o :7---. g qo 'D r ° - ° r 0 mzw O • ° F .-� 11 0 0 `5 °oc8E a P . sK> 7 c ° 0 p'- C • 9 °C��, 0 a U 3 B ° • 'Ae• o - d'i• cal o `E g! 3 pE ti 0 . 4Z 0 eto eE w 0 F- 0 3 O. E 41. o FEm V W s� 0 o EE co O 0 • 41, o s'E 91 ° 0 el 0 o <-2‘9z o s[ o ° d 5` 3 V R-- as O, ° ee. ' ee t ` f' 3 s 3 w - V a I.., 4. 3 �t • C g �a a ° O ! s O V - •on',,,c Oeo -N � c(.: T �,/ a 3 N C '� 0 o$ N = a o am (I), .-O Z0°0< D� {{ =cr i 1 1 i • • i:•lric1 boondl• i ‘ I SE Corner of F. 1`000c iRUK 9IL Protracted Sectioni 11 i Li -" �� V Coordinates I. I i 1 N 6028111.04 C l; 1 I 1 E 470989.01 i ._• 1 ' '1 I Cl `• �N 1, Harrison: Boy Tract: �A'°~ 1PI-24\ A ..._ r4 • ®rawin• is I \�•�c r2 I % ‘9'j -�. ,. 1 ,' "s i .I• ' 12 i li Or-shore Ittroc_ __c*---' 9.; 1.11. '� � • Near Short lotrooia,3.82 U - ' 11-13 z Pi ?D 3c %cccvruk Site • � ` . P1 7 to P. •r I _ 14' m q . , - •L s T b �� r - P.1-14 I PI-2. ....,_ i� PI-161V • ''-'--"'41111.11111.111 I :•�, �� ,r1-17 'loom Icecap( DS 3N 6dOP / d y " i• •` ' FI- ? I i' Roods to talo _ J Basis of Location i I''' I6Jc EN - - DS-3H West Monument Coordinates And i I ."-- 7Z' Ft�-3.' .; N 6001016.61 — A E 498081.23 STAKED PI INFORMATION ONLY p <, 'a... X / 7/ _�: Ref. Lownsbury & Assoc. ►� '�� i Drawing No. cl cc ' I NSK 6.01—d672 _ 1 i1Ps�'OF•A�,,:ti, WI w S ' ilip G.Daub • o 01 ''•:-...=,..7..,---.1--1...4.:;--,•,-;,-...:-, . "' Is:vr s. No.a11as ,: ,j c::,. . 3/4%�04E51011M 'or 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 Ronne 7 East DATE: 7-12-07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 A.la.�ka State ° 1 ectiI n Llne Offtet WeII Ng, I -- ._ -- Y-_.- - ..-- ----- Latitude (14) Longitude ,,i) -FSL P � Pad Elev, 1 6,031,161.32 469,920.45 70 29 46.24160 150 14 45,46466 3035 1077 -13,.5-0--- '.--2 6,031,140,05 459,915.52 70 29 46.19252 150 19 45.60922 $030 1082 13,50 6,031,141.39 469,910.59 70 29 46.14354 150 14 45.75375 3025 1087 '13.50 4 6,031,136.46 469,905 67 70 29 46.09485 15014 45,89799 3020 1092 --13-50-- " 6,0$1,131,40 469,900 74 70 29 46,04538 150 1-4-46,04252- 3015 1097 13.-50 6 6,031,126.51 469,895,60 70 29 45.99660 150 14 46,16735 3010 1102 13.50 7 6,031,113,73 469,553,13---70 29 45,87039 150 14. 46,55879 2997 1115 13,50 8 ~-6,031,1003 469,878.21 -70 29 45,821021-1607'14 46,70303 2992 1120 WO — 9 6,031,103.75 469,873,3 70 29 45.77184 150 14 46.54.814 2987 1125 1340 10 6,031,098,79 469,868.36 70 29 45.12286 150 14 46/99/79 2982 1130 13,50 469,553,39.. . - 11 6,031,093.84 _ 70 29 45,67398 150 14.47.13750 2977 1135 13.50_ • 12 6,031,088,87 - 469,858.47 7029 45.62490 - 150 14 47,28174 2972 1144 13,5Q-- 15 6,031,076,06 469,84.5,51 70 29 45.49640-150 14 47.65286 2960 1152 13,50 14 6,031,071,09 469f840,87 70 29 45-44932 150 14 47,79770 2955 1157 13,5-0-- -15 6,031,066.15 469,835.96 70 29 45,40053 15Q 14 47,94165 2950_ 1162-------13-,5Q---- ----16 162 '13.50— '166,031,061.18 469,83104 70 29 45,35145 - 150 14 48 08585 294-5 1-167 -- 13,50 - --� 17 0,031,056,25• 469,826.11 . 70 29 45:30277 150 14 48,23042 2940 1172 13.50 i 6,031,051,27 469,821.15 70 29 95,25359 150 14 46,374.95 2935__1177 '13.50 19 6,031,038,52 469,808.50 7o 29 45.12765 1150 14 48:74668 2922 1159 13.50 20. 6,031,033,5Q 469,803 59 70.29 45.07811 150 14 48,89061 2917 1194 10,5Q 4 21 6,031,028.53 469,798.62 70 29 45.02903 150 14. 49,03632 2912 1198 13,50 - 6,031,023,58 469793.67 70 29 44.98014 150 14 49,18144 2447 1244 13.54 23 1-6,001,010,57 469,785,76 70 29 444 93067 15014 49.32537 2902 1209 13.50 24 0,0-17,00-.6-0- 4 69,7 53,$4 7 0 29 44.88159 150 14 49,46960 —2-8-9T--1-2-14 15,50 . �`-Zt`‘ OA( P,kt. . . ,q t '• fi 6 s .ram °;Is 6 p; . 9.r . :y-. .1* it, • c1 Philip G.Davis o _:yam'—'?- . $ �iP1♦ No.41104 •. - i 1, Elevetions ore hosed on SP McQn Sec Level, - ...---- - 2, Coordinotes ore Posed on Alosko Stoic Plone Nod 27, gene 4, 3. All condvciors ore within Protrocted Section 11. Pioneer NQturcl ReSOuoCE . 10E NAME: Qooaur-uk Drill !ite Conductors DRAWN 8Y: 8L CHECKED EY; M,1D QCATIQN Pr-otrocted Section 11 SCALE.: N/A Township 13 North RQnge 7 Eopt DATE; 7=12=07 Umiot Meridion - NANUQ JO NQ. SHEET E$CRIPTIQN As—built Coordingte. 05204. 3 of 4. Sectio Well No. Alaska ska Statez Latitude (N) Longitude FSLn Line Eftset 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 45.7 7071 150 14 45.50137 2988 1079 13.50 31 6,031,090.65 469,906.38 70 29 45.64431 150 14 45.87163 2975 1092 13.50 32 6.031,085.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 13.50 41 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 1154. 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 . 469,811.98 70 29 44.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 • � 1 SURVEYOR'S CERTIFICATE _ . OF qi: 1i �E •�..•..•• '••.`s '.�• !� I HEREBY CERTIFY THAT I AM ow e0.0 TH '•�I I� PROPERLY REGISTERED AND d LICENSED TO PRACTICE LAND 5'"J • "' I SURVEYING IN THE STATE OF ; ; J_ r. . . . ... ALASKA. AND THAT THIS PLAT •�-��-%�!'=�:' �_;,� % t REPRESENTS A SURVEY DONE EY x F - �`='�' • ilii G.Davis o� a s'�= a_.� , � ...v�;.: ;n' .41104 ;J1or ME OR UNDER MY SUPERVISION '��'• `J� AND THAT I BELIEVE ;, �14,e-4-"F,7 THAT ALLi , � : i hOjE„inNF,% DIMENSIONS AND OTHER DETAILS s:-�.»,. �.. 1 1� +'� ARE CORRECT AS SUBMITTED TO ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooauruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD. LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Rance 7 East DATE: 7-12-07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 TRANSMITTAL LETTER CHECKLIST NAME _47 -,J/ t-t.l/ �'-- '" ~ r---) PTD# 3---/C-) • C'93 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD:( u1-t-Ic'_ POOL: LP 1-�Ll� �/ I St'(• � �� ,� 0 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (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. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 E n CO N °) O n H N rn ft a) 6 n o N pp 7f•••• E °i a=in a L o 2 Z cici a) v oTO -0 O o a) _ _0 z o • L N '- W (n JI CO a)ta) C > W o •O. a CO N. a0. In C a) r O` co > L N N N O) n UQ N @ = CO Q 0) 3 0 0 c ) MO Q r o N @ 0 'C °O c C C' 0 0 O N 3 CO N O to F a CI= U ' - N 0 - CO 0 .N• of 0) N a) •` 7 7 a) 0) co a) C C Q) c -0 °- o n 'O 0 CD m m 3 c 2.0 •° o CO N -- c N D v") Cr C O. a o = m O E as � 7 'V N N a @ IO E N O N C p Y N N a) @ N N N w a a O tp Z Q ° N (n c o °c o 0 0 rn .E a COo) CO O C0 -0 N C7 0 O p C C C L coc 0 co p W V CO t a 0 O °• '� c c c m u w 3 o $ 0 3 ao U 7 W Z .0 r' O @ @ C N 2Ts N •Q N a0 a)C N O C Y a C U L L 30 ) CO n "' COa Z n co CO n N CO D `O ° N n N a) C a) C N a) coN _n O C y O) O) 0) .- CO CO 7 CO 7 n 7 LO CO to L 0 7 U T c a n O L N N c O o z Z z a, co CO TI) E E ° a) a) E L n E O O) C ° N N N C CO m U O N n 6 `) L. O O co C O 'O '0 O •F) 0 @ L N N N .c-i) N •(7) 7 E o a 0 0 0 -0 3 T N -.,(I-; a) U a) N V CO O N O o a O• O o O N a) • 0 N @ @ a. °- d E ° o �c m m m a - c a n N 0 ° a 0 co CDu a) Z U 7 aa) N 0) C Q E Ti', s Q E @ O a N C U O) Er N Z 7 00 00' 0 0 0 +@+' 0 a 0) O. > CO Q o N d _C w (n 0 0 0 0 a) z c a . E a 0 2 2 z = w -o a --- > 0 i NN CO CO CO co co CO CO CO co CO co CO CO CO CO co CO co CO CO co CO O Q a) a) a) a) a) a) a) CO a) a) a) a) Q Q Q Q a) Q a) 0 0 CO a) Q a) Q a) a) a) a) Cl) o Q a) a) Q Q Q Q z > > > > > > > > > > > > zzzz >- Z >- ZZ >- rZ >- Z >- >- >• >- >- zz >- >- Zzz T o N ° @ INI N — T 0co t U N 0 C @ m a) E E 3 - E a) o U U j ' c a) N C O U ' 7 T C �•' a c r o , Ita) 3 E _ 3 0 M N U L U_ C --- C O o Z w a 0 E a) CD > COE O U @ N. N N Q m `O a) U `8 u O' Z a > 'C p. @ N U n x 0 o 0 u C J N CO 7 C 7 .@+ N. Y d a n @ O Q N O ° N a 0) O a) 0 a) O p CI. T .- C 4 Q 3 @ a) o M ° N N a c 0 - 7 2 3 ° N u) Oc' �, 7. a) '@ @ T L. 0- cN `ri p -° 0 u$ E N a) '' o co -° O N. CO �. wt O) U Z in @ 7 3 0 (n c O) C c N ° �L) 7 < N CO a) � 0) 0 "o' O C a o a) c a @ @ n D o ` a) m O o 0) a) • Q- L C C 0 c o a) y. N @ > ch C U > a O- N N t a) a ° ° O)N D E E = a c c E o 3 C in ', I- @ o us c _ c m 0, N N n E 0 O o 0 0 `o v o m n o o Q c °c) U ° a aoi ° °� a m •i ° > N Y co oo - m CO Q m u) a o o) O a) ami w O COa) a) > o a@ .m o Y m o 0 0o f m m >, c . cc O E n U U 0 r a o o ° c - n a) E 7 3 ° o a) -c CO 3 V o E C C 17 N O L L -0 CO CO 7 CO a @ ` E a) c.) ,;() .-,T1 -'- a) O) O' N n 3 p o 3 °c)E -) CO C a CO CO. CO n n a @ a E CO N N C CO M (6 CO L N O N 0 C T 0 o Q • a) N u m 3 3 a) a) 0 .. o '� - 3 m 92 o n o N a 3 m o 3 2 s m o w U,� a o c C a a o O •o o ° @ E o c o a) o o c a o o CO a E aa)) @ E L °) 0 aa) O- `n N c I- 0 a@ -00 a) a) .t.5° 7 7 a c r U OU a o a) a) -_ a CO a) -6@ E 0) O (n ;-• 7 C O 0 0 Q U @ E @ O O co O) N n N N Cp L 'C N O) O- @ @ @ @ MC') @ o N 0) T C U 3 = 5c N O N O n N 20 N C C n n c) y T CO(13 CO a) a) 3 C -0 0) C _c 0• O• a) C C @ = 7 0_ _c (` U O 00 CO a) T a a) • w@ - m m aai 0 c@ .0 w o c N Nzs, a > •'y' CO L 3 a o CO c o °3 (2 m c coo c c E I— cm z CO C U c@) c@) N Cl)( 0 o U CO N U N a0 C O a) O (7, 8 (a 'o f0 r . to a E .3 a) C U O 0 a U V) O .- CO 7 0 0 0 .- '5 CO m n o ° a 0 -0 0 > > 3 c Q - Q O c) w w Y N CO ' a E a) 0 ai J n_ E N Q - - - •- a) a) m E E c - 3 C C t i- i- 1- - a•m a) > = a a 0 0 E m u) CO c -to- .... T a _I D ('n " 0 0 `5) Cl) CO Q a` 0 0 (0 0 0 0 0 -c) t < t 0 0 0 0 2 a 0 (p in 0 p U CO W O ✓ EN co V in CO N co ° 0 Vc'- W O° O N N M V CoN O nN W O O CNC) M V L• (CO CN) W O)) O U _O 0 O_ 1— N a) O N O a) O 0O C N N NR U re M O 0 O 0 ft O 0 CO _ 'N W O • p E r r o f J N •- E N 01 0 J it La La a a Q p 0 Q 0 ca- L 0 a Q Q w Q 0 Q Well History File A END IX Infoirnation 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 infoH���ation. HALLIBURTON Sperry Drilling END OF WELL REPORT ODSN-17 Oooguruk Development a`s`s. Yr' 5 K i>R ' ry! I a a "r"h.' `4%.„, vstat 107' ,_ Pf. Surface Data Logging Services at° HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup PIONEER NATURAL RESOURCES HALLIBURTON Sperry Drilling GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-17 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20622-00 Sperry Job Number: AK-AM-7007267 Job Start Date: 6 Sep 2010 Spud Date: 21 Aug 2010 Total Depth: 19948' MD, 6388' TVD North Reference: True Declination: 21.314 Dip Angle: 80.942 Total Field Strength: 57630 nT Date Of Magnetic Data: 25 Aug 2010 Wellhead Coordinates N: North 70° 29' 45.30" Wellhead Coordinates W: West 150° 14' 48.23" Drill Floor Elevation 56.2' Ground Elevation: 13.6' Permanent Datum: Mean Sea Level SDL Engineers: Tom Mansfield, Colby Marks, Mark Lindloff, Ryan Massey Company Geologist: Jacque Ledbetter, Paul Cozma, Jim Stewart, Mindaugas Kuzminskas Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling DAILY SUMMARY Begin ODSN-17 9/3/2010 Mudloggers on arrive on location. 9/4/2010 Pull out of the hole and laid down 10 5/8" milltooth bit and mud motor. Remove wear bushing and install test plug. Test BOPS, all tests went well. RD testing equipment. Pull Test Plug and Install Wear Bushing. Picked up 11-3/4" RTTS and tripped in hole to test casing. Planned to test casing in joint above FC @ -4550' MD; however, experienced excessive drag while tripping in with RTTS at 3719' MD. Unable to get RTTS to set in casing between 3243' MD and 3719' MD. Tripped out of hole with RTTS and picked up clean out assembly with PDC bit. 9/5/2010 Finished washing and reaming to 4588' MD to remove cement sheath from inside 11-3/4" casing. Circulated weighted hi-vis sweep and cleaned cement cuttings from wellbore. Tripped from 4588' to 2374' MD and Tripped in while picking up 69 joints of 5"drill pipe. Tripped out of hole and lay down clean out assembly. 9/6/2010 Pulled out the hole to surface, laid down BHA. Picked up HES RTTS and run in hole on HWDP to 370' MD. Tripped in the hole to 4,550' MD. Circulated 10 bbls around RTTS and set same with 20k down. Tested casing -good test. Pulled out the hole from 4,550' MD to 370' MD. Pulled out the hole racking back HWDP. Picked up directional BHA and shallow pulse tested. Tripped in the hole from 650' to 4,588' MD. Drilled cement and float shoe from 4,588' MD to 4,670' MD. Drilling from 4,670' MD to 4,690' MD. Performed F.I.T. at 4,659' MD, 3,285' TVD with 10.0 ppg WBM to 1,003 psi for EMW of 15.87 ppg. Drilled from 4,690' MD to 4,698' MD. No losses to the hole, with a max gas of 134 units for the past 24 hours. 9/7/2010 Directionally drilled from 4,698' MD to 4,770' MD. Dropped 1 5/8" ball and pump ball on seat and sheer ball seat to engage under reamer cutters. Directional drilling from 4,770' MD to 5597' MD. Directional drilling from 5,597' MD to 6,250' MD. No losses for the past 24 hours with a max gas of 193 units. 9/8/2010 Directionally drilled ahead at 7,950'. Max gas seen in the past 24 hours was 693 units. No losses to the hole in the past 24 hours. 9/9/2010 Directionally drilled from 7,740' MD to 8,565' MD. Circulated while switching changing out swabs and liners on pumps#1 and #2. Directionally drilled from 8,565' MD to 8,805' MD. No Losses to the hole. Max gas for the past 24 hours was 579 units. 9/10/2010 Directionally drilled from 8,805' MD to 8,847' MD. Serviced rig and top drive. Directionally drilled from 8,847' MD to 9,700' MD. Pumped carbide lag at 9501' MD connection. Lag gas returned to surface 1000 strokes under gauge for a calculation for 11.75" hole. Another sweep pumped at 9737' MD returned to surface 1000 strokes early, confirming carbide test. No losses to the hole, with a max gas for the past 24 hours of 1847 units. PIONEER NATURAL RESOURCES HALLIBURTON nprry t"lrilling 9/11/2010 Directionally drilled from 9,700' MD to 10,683' MD. Circulated at reduced rate while trouble shooting losing high line power. Directional drilling from 10,683' MD to 10,833' MD. Functioned test BOPE - functioned properly. Directionally drilled from 10,833' MD to 10,928' MD. TD hole section at 10980' MD, 5365' TVD. No losses to the hole. Max gas was 858 units. 9/12/2010 Circulated the hole clean with two 45 bbls hi-vis, weighted sweeps at 12.4 ppg, and make 400 bbl whole mud dilution with clean 9.8 ppg mud. Circulated and conditioned mud for one surface to surface volume every 6 to 8 hours to ensure mud properties are in spec for casing run. Max gas seen in the past 24 hours was 538 units. Less than 1 bbl/hr seepage to hole while circulating from trip tank with hole fill pump. 9/13/2010 Monitored well while waiting on parts for the rig. Circulated and conditioned mud while pumping one surface to surface volume every 6-8 hours to ensure mud properties are in spec for running casing. Shut annular preventer and monitored well while prepping for rig maintenance. Circulated and conditioned mud while pumping one surface to surface volume every 6-8 hours to ensure mud properties are in spec for running casing. Shut annular preventer and monitored well while installing new monkey board. Max gas for the past 24 hours was 411 units. Slight intermittent mud seepage with losses of up to 1.5 bbl/hr while using hole fill pump. 9/14/2010 Shut annular preventer and monitored well while performing rig maintenance. Circulated and conditioned mud with 2x bottoms up. Pulled out the hole from 10,960' MD to 5,512' MD. Attempted to circulate at 5,512' MD, hole appeared to pack off, worked pipe free and used step rate method to establish circulation. Pulled out the hole from 5,512' MD to 4,677' MD. Established circulation with step rate method up to 700 gpm and pulled test Rhino reamer against casing shoe with 10k over P/U wt--Good test. Circulated hole clean with 3x bottoms up. Pumped out the hole from 4,677' MD to 2,393' MD. Max gas seen was 305 units. Losses seen for the 24 hour period was 15 bbls. 9/15/2010 Pump out of hole from 2393' MD to 681' MD. Pumped 30 bbls hi-vis sweep around. Slip and cut drilling line. Pulled out of the hole. Function tested Rhino Reamer. Ran in hole to 4685' MD. Pulled test reamer at shoe. Ran in hole to 10885' MD. Circulated hole clean. Opened hole with reamer to 11 3/4" from 10885' MD to 10969' MD. Pumped hi-vis sweep around surface to surface. Began seeing H2S at gas agitator with 5100 strokes. Pack off event with 40 bbls pumped away. Recycled H2S peak of 45 ppm with second circulation. Maximum gas through circulation was 547 units, average gas was 242 units. 9/16/2010 Circulated hi-vis sweep surface to surface. Tripped out of hole from 10980' MD to 6170' MD. Ran in hole to 6243' MD. Circulated bottoms up. Tripped out of hole from 6243' MD to 4763' MD. Pumped hi-vis sweep surface to surface. Pulled test rhino reamer at shoe. Pumped out of hole from 4763' MD to 956' MD. Trouble shoot top drive link tilt problem. Continued to pump out of hole. Laid down BHA and rigged up to test BOPE. Installed test plug. Max gas seen for the past 24 hours with a 7 bbl loss for the trip out of the hole. 9/17/2010 Tested BOPE. Picked up and ran 9 5/8" liner to 6448' MD. PU liner hanger. No significant gas to report for this period, over all losses for run in with liner was 75 bbls. PIONEER NATURAL RESOURCES HALLIBURTON Sperry !rilling 9/18/2010 Continued to run 9 5/8" liner on 5" DP from 6497' MD to 10978' MD. Dropped ball and circulated down. Circulated and conditioned mud for cement job. Mix and pump 128.4 bbls cement at 15.8pg. Rig down equipment and begin pulling out of the hole from 4467' MD to 873' MD. Max gas was 345 units, with total losses to hole being 142 bbls. 9/19/2010 Continued pulling out of the hole to surface. Laid down liner running tool. Nipple down BOPE, install riser and flow line. Picked up and ran in hole with HWDP and 5" drill pipe. Pull out of hole with same. Circulate drill pipe with 2 bottoms up. Pick up 8 1/2" drilling BHA. No gas or losses to report at this time. 9/20/2010 Picked up BHA#8. Ran in hole 10850' MD. Test 11 3/4"x 9 5/8"casing, good test. Drill shoe and clean out rathole to 10980' MD. Drilled 20' of new hole to 11000' MD. Circulate and displace well with 10.0 ppg LSND mud. Perform FIT to 14.0 ppg EMW. Install RCD head. No losses or significant gas to report for the previous 24hrs. 9/21/2010 Directionally drilled from 11000' MD to 12155' MD. No losses for the past 24 hours. Max gas was 4577 units. Max connection gas 3828 units while making connection at 12359' MD. 9/22/2010 Directionally drilled from 12155' MD to 13719' MD. Drilled ahead to 13730' MD where standpipe increased 150 psi and ECD climbed to 14.14 ppg EMW. Slowed pump rate and worked pipe. 17 bbls lost due to pack-off. Circulated out with 2762 units gas and significantly increased cuttings load to surface. Total 24 hr mud loss of 17 bbls. Very minor connection gases of 100 to 150 units over background. 9/23/2010 Directionally drilled from 13719' MD to 14103' MD. Circulated hole clean with two bottoms up. Changed out RCD bearing due to element going out. Circulated bottoms up at 14103' MD. Backreamed out the hole from 13977' MD to 13590' MD. Worked pipe to clear pack off, established circulation, and circulated bottoms up. Backreamed out the hole from 13590' MD to 13311' MD. Changed out RCD bearing as the top hydraulic seal went out. Backreamed out the hole from 13311' MD to 13121' MD. Max gas seen in the past 24 hours was 8560 units after experiencing a pack off event. 736 bbl lost in the past 24 hours. 9/24/2010 Backreamed out the hole from 13121' MD to 12240' MD. Pumped a 40 bbl hi-vis sweep and circulated 2x bottoms up at 12240' MD. Pulled out the hole from 12240' MD to 10978' MD. Tripped in the hole from 10978' MD to 13501' MD. Function tested BOP. Washed and reamed in the hole from 13501' MD to 14103' MD. Established circulation, backreamed out the hole from 14103' MD to 13691' MD. Tripped in the hole from 13691' MD to 14103' MD. Directionally drilled from 14103' MD to 14108' MD. Pumped a low then a high sweep and circulated surface to surface. Circulated up trip gas of 6101 units while running in hole and gas settled to an average of 1000 units while circulating. Saw a combination of trip/drilling gas while drilling 5' of new hole, with a max of 3853 units. Losses for the past 24 hours 288 bbl. 9/25/2010 Continued running in the hole to 14100' MD and circulated. Circulated 2435 units of trip gas which promptly fell off to a background gas of 230 units and slowly dropped off before pump rates were lowered. Displaced hole to 13.0ppg mud in preparation for the casing by combining 11.0ppg and 18.0ppg spike fluid from RSC in the rig pits. Multiple circulations took place to equalize system to 12.9ppg. Background gas averaging 113 units were noted during displacement. Tripped to the shoe and pulled RCD head and prepped for pulling out of hole. Pulled out of hole with no problems losing 10 bbls to the hole. Began laying down BHA and downloaded MWD. Continuing to lay down BHA at time of report. 37 bbls loss downhole was noted from midnight to midnight. PIONEER NATURAL RESOURCES HALLI B U RTO N I Sperry Drilling 9/26/2010 Finished laying down the BHA. Picked up 7"elevators and running equipment. Picked up and ran 7" casing into the hole. Noted a 3.3 bbls loss. Made up hanger and began running in the hole on 5"drill pipe. Noted a 11 bbls gain thus far. Background gas of 32 units was detected while filling drill pipe and circulating at low pump rates. 9/27/2010 Continued tripping in the hole on 5"drill pipe while noting a 12 bbls gain. Circulated and conditioned mud with low flow rates (28 gpm) slowly increasing to 166 gpm). Once flow rates increased, trip gas was circulated out. Trip gas slowly rose to a max of 2351 units and slowly dropped off. Mud was circulated from an 11.4 pgg to a 10.2 ppg while background gas leveled off around 50 units. Setting ball was dropped and pumped. Running tool did not release and was emergency released. Circulated and conditioned mud. Performed cement job however plug did not bump. Rigged down cementing equipment, cut and slip drill line, and pumped dry job. Began tripping out of the hole at time of report. Losses from midnight to midnight were 33 bbls. 9/28/2010 Continued to pull out of the hole with 5"drill pipe sideways in order to pick up the 4"drill pipe. Lost 39.7 bbls on the trip out. Ran in the hole with remaining 35 stands and singled out of the hole laying the 5" down. Gained 10.8 bbls during the trip in and lost 13.0 bbls on the trip out for a net loss of 2.2 bbls. Rigged up to run casing. Began running casing and noted a 1.3 bbls gain thus far. The losses down hole from midnight to midnight were 32.9 bbls. 9/29/2010 Continued to run 7" liner tieback to the landing point. Pumped 140 bbls of diesel to freeze protect behind the casing prior to landing it. Took returns into pit#1 and the trip tanks and then pumped the gained volume over to the RSC for disposal. Rigged up and testing BOP's. 9/30/2010 Continued to test BOP's. Rigged up and ran in hole with 4" Drill Pipe to 13950' MD. Currently pressure testing casing to 3665 psi at time of report. Trip showed 23 bbls over calculated. 10/01/2010 Set retainer as per Halliburton hand directions. Spotted cement below retainer, pulled out of the retainer with the stinger. Circulated 1.25x with Max gas 38 Units. Rig up to trip out of the hole, trip out of the hole to surface. Noted -19 bbl loss during trip. Lay down stinger. Rig up and test BOP's. Rig down and prepare to run in hole for cleanout run. 10/02/2010 Single in with 4" drill pipe to 8694' MD, continued to run in hole with full stands. Performed bond log from 13600' MD to 13900' MD, continued to run in hole, drill out shoe track. Drill 20 ft new formation. Max gas 188 was units, no trip gas noted. Performed FIT to 12.5 ppg. Ran Bond Log from 14060' MD to 14108' MD, currently pulling out of the hole at report time. 10/03/2010 Finish pulling out of the hole, laid down BHA#6. Picked up BHA#7 and ran in the hole. No losses or gains during trip in. Installed RCD, staged up pumps and displaced to OBM, went smoothly. Start drilling ahead with no losses. 10/04/2010 Drilling ahead, loss of 25 bbls over the shakers. Samples predominately Sandstone. Occasional Claystone when in crossing through zone 2. Gas is moderate to high peaking at 2778 units. :. ' ,� . ft :e #` HALLIBURTON ( Sper"v [7ril$ing 10/05/2010 Drilling ahead, loss of 26 bbls over the shakers and on cuttings. Samples consist 100% Sandstone. Occasional Claystone when crossing different zones. Gas has been moderate with no wild peaks. 10/06/2010 Drilled ahead, loss of 20 bbls while drilling, stopped to repair the top drive. Continued to drill until reaching the end of the sand at 19773' MD. Continued to drill to TD at 19947' MD, 6382.36' TVD. Samples showed very good Sandstone until 19772' then degraded to Claystone. Gas also dropped off at this point. 10/07/2010 TD well section on 10/07/2010 at 00:45 hrs. Circulated bottoms up then started to POOH to the shoe. Continued to short trip to inside 7"casing. Circulate well clean, Slipped and cut drill line and serviced the top drive. Tripped in hole to TD. Washed down from 18800'to 19690' due to weight. Circulated 2X bottoms up with trip gas of 5609 units at B/U. Pulled out of the hole to sump at 15213' pumping 16 bbls of 10.1 every 10 stands. Spotted 40 bbl pill and pulled to shoe. Swapped out 8.0 ppg mud for 10.1. Circulated until hole was stabilized . Pulled the RCD bearing. 10/08/2010 Pull 6 1/8" BHA out of the hole with negligible loss. Lay down BHA#6, Rig up and run 4 '/2" liner. 10/09/2010 Finish RIH with 4.5" liner then continued RIH on 4"drill pipe. Set liner with the Top at 14265', and bottom at 19695'. No losses or gains noted during liner run. POOH to casing shoe and circulated casing volume with max gas 1247 units of trip gas (TG). Trip gas dropped off quickly with continued circulating. POOH with liner tool on 4"drill pipe. Trip displacement showed -2 mud loss. 10/10/2010 Performed DP maintenance (L/D 23 joints worn hardband). P/U 24 joints and 4 joints HWDP from pipe shed. Pump drill pipe volume and stand back. Service top drive. Change out saver sub. Pull wear ring, pick up test tools, fill stack and test BOPE. Pick up BHA and upload MWD. Shallow pulse test and RIH to 6159'. Shallow pulse test MWD good. No gas to report. No mud losses. PIONEER NATURAL RESOURCES Customer: Pioneer Natural Res. Report#: 1 Well: ODSK-17 Date: 9/07/2010-04:00 HALLriag JRTON Area: Oooguruk _ 04:00 Depth 5000' Location: North Slope Progress 24 hrs: 330' Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $22,793.72 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 118.0 124.0 183.0 4954' Flow In(gpm) 773 SPP (psi) 2382 Gas(units) 68 61 134 4878' Flow In(spm) 184 Gallons/stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.04 Min 10.27 Avg 10.56 Max 5000' 4.78 0 bbls 11.75" All Circ 10.04 Min 10.26 Avg 10.54 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 4694' 10.00 10.00 40 10.0 7 14 15.0 12.50 15k 12.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 4802.00 to 4886.00 28 134 17024 239 59 99 20 GP to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG- Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: RIH with the RTTS tool.Set packer and tested the casing.Trip out of the hole after the successful test.Make up drilling BHA with Rhino reamer included.Pick up BHA and RIH to drill out and perform the leak off test.Performed leak off test, test successful.Currently displacing over to LSND mud,Continue to drill ahead at report time. Logging Engineer: Mark Lindloff/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 2 Well: ODSK-17 Date: 9/08/2010-04:00 riALLIBURTON Area: Oooguruk 04:00 Depth 6477' Location: North Slope Progress 24 hrs: 1477' Sperry Grilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $28,191.81 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 130.0 124.0 200.0 5504' Flow In (gpm) 836 SPP (psi) 3080 Gas (units) 107 91 193 6334' Flow In (spm) 240 Gallons/stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.31 Min 10.80 Avg 11.46 Max Hole Condition 6477' 4.78 10 bbls 11.75" PWD All Circ 10.31 Min 10.79 Avg 11.46 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (lb/100ft2) ml/30min mg/I yo 6265' 10.00 10.00 56 7.0 16 30 10.0 8.65 14K 7.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 6309.00 to 6340.00 153 193 22551 755 408 189 89 GP to to to to to to to to Gas Type abreviations: BG - Background Gas; GP -Gas Peak; CG - Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilling ahead.Some slow sections but no problems once through them.51 bbl down hole loss. Logging Engineer: Mark Lindloff/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 3 Well: ODSK-17 Date: 9/09/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 7882' Location: North Slope Progress 24 hrs: 1407' Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $33,589.90 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 81.0 . 98.8 187.0 6956' Flow In (gpm) 840 SPP (psi) 3556 Gas(units) 270 244 579 7666' Flow In (spm) 200 Gallons/stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.50 Min 10.81 Avg 11.40 Max 7882' 39.43 10 bbls 11.90" All Circ 10.50 Min 10.81 Avg 11.40 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 7764' 9.85 9.85 54 16.0 15 32 8.4 9.00 14K 7.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 7250.00 to 7350.00 250 573 54095 3336 2193 1078 325 CG 7430.00 to 7500.00 250 573 38223 3064 2327 1201 359 CG 7500.00 to 7750.00 355 579 48041 4071 3373 2232 932 GP to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilling ahead with no losses down hole. Logging Engineer: Mark Lindloff/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 4 Well: O DS K-17 Date: 9/10/2010-04:00 HALLiftsIJRTDN Area: Oooguruk 04:00 Depth 8943' Location: North Slope Progress 24 hrs: 1061' Sperry Grilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $6,258.09 Total Charges: $39,847.99 AL 11111 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 30.0 _ 75.6 155.0 8849' Flow In (gpm) 850 SPP (psi) 3780 Gas (units) 325 349 779 8412' Flow In (spm) 203 Gallons/stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.37 11 10.81 Avg 10.94 Max Hole Condition 7882' 56.8 20 bbls 11.85" PWD All Circ 10.20 Min 10.63 Avg 10.94 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I iyo 8823' 9.80 9.80 42 14.0 11 22 7.6 8.50 13k , 7.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data 1 Sample Line Max: Avg: 1 Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 8200.00 to 8440.00 478 779 75186 3996 2258 1578 915 GP to to to to to to to Gas Type abreviations: BG - Background Gas; GP- Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- -Trip...; F--- Formation...; E--- Early... 24 hr Recap: Con't drilling 10 5/8"x 11 3/4"intermediate hole. Drilled F/7784'-T/8823',Pumped hi-vis sweeps at:7858'and 8672'- minimal increase in cuttings as sweeps come back.Worked on mud pumps at 8358'. and replaced rubber seal at 8834'md Drilling ahead at report time.No connection gas observed. Tom Mansfield coming out for Mark Lindloff Logging Engineer: Mark Lindloff/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 5 Well: O DS N-17 Date: 9/11/2010-04:00 i-1ALLIBURTGII\i Area: Oooguruk 04:00 Depth 9922' Location: North Slope Progress 24 hrs: 979' Sperry Drilling --- Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polys/J. Cortez Daily Charges $5,398.09 Total Charges: $49,394.25 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: _ R.O.P. (ft/hr) 108.0 67.2 136.0 9897' Flow In (gpm) 825 SPP (psi) 3750 Gas (units) 340 228 1847 9690' Flow In (spm) 197 Gallons/stroke 4.1860 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.20 Min 10.59 Avg 11.77 Max Hole Condition 9854' 73.95 0 bbls 11.75" PWD All Circ 10.20 Min 10.59 Avg 11.77 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 9633' 9.80 9.80 40 14.0 10 19 8.4 85.00 13K 7.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 73.95 16 123 Lithology (%): Sd ' Sst Silt ' Siltst Cht Clyst Sh Lst Coal Gvl ' Tuff (current) , Gas Breakdown l H2S Data II Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 9000.00 to 9400.00 333 149 25691 927 461 271 112 BG 9400.00 to 9685.00 523 304 40040 1518 622 285 98 BG 9685.00 to 9692.00 1847 666 121925 4234 1959 836 245 GP 9692.00 to 9727.00 622 381 36567 1564 783 399 130 BG 9727.00 to 9815.00 391 116 18005 919 491 265 94 BG 9815.00 9875.00 1366 543 97361 3689 1582 738 332 BG to to to Gas Type abreviations: BG - Background Gas; GP -Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drill ahead from 8943'to 8949'and pumped 40 bbl sweep for bit balling. Added 40 bbl NXS to maintain 4%lubes. Pumped carbide lag at 9501'connection. Lag gas returned to surface 1000 strokes under gauge calculation for 11.75"hole. Hole attempted to pack off at 9698'WI ECD of 11.77 ppg. As ECD began dropping,gas peaked to 1847 units accompanied with large(big as your hand)shale fragments. Another sweep pumped at 9737'returned to surface 1000 stks early,confirming carbide. lag. Drilling ahead. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 6 Well: ODSN-17 Date: 9/12/2010-04:00 HALLIE3URTDN Area: Oooguruk 04:00 Depth 10980' Location: North Slope Progress 24 hrs: 1058' Sperry Urilimy Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $54,792.34 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na 76.7 131.0 10706' Flow In (gpm) 815 SPP (psi) 3775 Gas (units) 128 252 1366 9845' Flow In (spm) 195 Gallons/stroke 4.1860 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.20 Min 10.59 Avg 11.77 Max 10980' 90.3 0 bbls 11.75" All Circ 10.20 Min 10.59 Avg 11.77 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I ok 10866' 9.75 9.80 47 17.0 10 21 11.0 8.50 15K 7.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 16 123 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 9875 to 10354 858 358 51757 3319 1821 1091 517 BG 10354 to 10980 378 170 19943 1335 880 708 427 BG to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilled ahead. Encounted Torok Top at 9797'MD,4978'TVD,Torok Base at 10377'MD,5167'TVD with average gas through Torok interval of 365 units,maximum gas of 1366 units. Pumped sweeps at each connection through Torok interval with moderate increase in cuttings when pill returned to surface. Drilled to 10683'and trouble shot generator. Drilled ahead to 10833'and function tested BOPS. TD hole section at 10980'MD, 5365'TVD. Circulating and conditioning hole at report time. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 7 Well: ODSN-17 Date: 9/13/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 10980' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $68,433.19 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 695 SPP (psi) 3025 Gas (units) 113 135 538 na Flow In(spm) 166 Gallons/stroke 4.1860 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling - na Min na Avg na Max 10980' 90.3 0 bbls 11.75" All Circ 10.30 Min 10.60 Avg 12.20 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in i out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 10866' 9.75 9.80 47 17.0 10 21 11.0 8.50 15K 7.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to Gas Type abreviations: BG - Background Gas; GP -Gas Peak; CG - Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: TD hole section at 10980'MD,5365'TVD. Circulated and conditioned hole while pumping two 50 bbl 12.4 ppg Hi-Vis sweeps. Sweeps produced max gas of 538 units and lots of fine sands. Diluted mud system with 400 bbls fresh 5%lube 9.8 ppg mud. Monkey boards damaged,work on same while working pipe every 30 minutes and wait on parts. Circulated hole volume at 21:00 hrs with a max gas of 219 units. Continue working pipe every 30 minutes. Circulating hole volume at report time with a background gas of 113 units. Less than 1 bbl/hr seepage to hole while circulating from trip tank with hole fill pump. Logging Engineer: Tom Mansfield/Colby Marks " 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 8 Well: ODSN-17 Date: 9/14/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 10980' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $74,906.69 ' jay ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr na na na na Flow In .pm) 694 SPP (psi) 2775 Gas (units) 165 135 411 na Flow In(spm) 167 Gallons/stroke 4.1860 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na Min na Avg na Max 10980' 90.3 0 bbls 11.75" All Circ 10.60 Min 10.68 Avg 11.16 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft _ in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 10980' 9.75 9.80 40 15.0 9 17 10.0 8.50 13,000 7.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 Lithology (%): Sd Sst _ Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to Gas Type abreviations: BG - Background Gas; GP- Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T-- -Trip...; F--- Formation...; E--- Early... 24 hr Recap: Working on Monkey Board while moving pipe every hour. Circulated hole volume at 4am with max gas of 411 units. Work on Monkey board. Slight intermittent mud seepage losses of up to 1.5 bbl/hr with hole fill pump. Circulated another hole vol at 2pm with max gas of 370 units. At 2:45 pm(7000stks)SPP instantaneously dropped from 2950 psi to 2550 psi. At 3:15 MWD quit transmitting data, however pulser continues to pulse. Continued working on Monkey Boards. At 2:15 am began circulating 2X hole volume with a 250 bbl dilution from RSC. Max gas was 324 units and no mud losses while circulating hole. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. __ Report#: 9 Well: ODSN-17 Date: 9/15/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 10980' - Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $80,304.78 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) na SPP (psi) na Gas (units) na 25 305 na Flow In (spm) na Gallons/stroke 4.1860 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 10980' 90.3 0 bbls 11.75" PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I • 10980' 9.85 9.85 47 13.0 12 24 8.8 8.70 13,000 8.3 _BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data 1 Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Finished rebuilding and inspecting Monkey Boards. POOH to 5512'working through tight spots at 8260'-7977',6370' and 5620'. Circulated to work thru tight spot at 5512',hole packed off. Established circulation by staging up pumps and circulate hole clean with a maximum gas of 305 units. POOH to 4765'and pull test Rhino reamer,test good. Circulated hole clean while staging up pumps with a maximum gas of 118 units. Large clay balls returned to surface. Pumped out of hole to 665'at 4 bbl/min and 250-400 psi. Pumped Hi Vis sweep bringing more clay balls to surface. Begin pulling HWDP at report time. 24 hr mud loss to hole of 15 bbls. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 10 Well: ODSN-17 Date: 9/16/2010-04:00 HALLIBURT®N Area: Oooguruk 04:00 Depth 10980' Location: North Slope Progress 24 hrs: 0' Sperry Grilling Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J. Cortez Daily Charges $5,398.09 Total Charges: $85,693.87 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na , na na na Flow In (gpm) na SPP (psi) na Gas(units) na 242 547 10965' Flow In (spm) na Gallons/stroke 4.1860 Depth _On Bot Hrs Ann Corr Avg DiamDrilling na Min _ na Avg na Max Hole Condition 10980' 90.3 0 bbls 11.75" PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 10980' 10.20 10.20 48 18.5 12 27 12.0 8.50 13,000 9.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 50+ppm Avg: 20 I Ambient Air Pit Room Max: 8 Avg: 3 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Slip&cut drill line. L/D BHA. Make up clean out BHA and function test Rhino Reamer. Ran in hole to 4685'and pull tested Rhino Reamer. RIH to 10885'and break circulation staging pumps. Began seeing H2S at gas agitator with 5100 strokes rising to over 55 ppm at bottoms up. Pack off event with 40 bbls pumped away. Pumped 40 bbl Hi Vis sweep with minor increase in cuttings. Recycled H2S peak of 45 ppm w/second circulation. Maximum gas through circulation was 547 units,average gas 242 units. Opened hole from 10885'to 10980'. Trip displacement good-no losses. Pumped another 40 bbl Hi Vis sweep. Begin pulling out on elevators. 25 stnds out,good displacement. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 11 Well: ODSN-17 Date: 9/17/2010-04.00 HALLIBURTON /17/2010-04 00 ALLIBURT®N Area: Oooguruk 04:00 Depth —10980' – — Location: North Slope _ Progress 24 hrs: 0' Sperry Drilling Rig: Nabors. 19AC Rig Activity: Test BOP Job No.: AK-AM-0007007267 Report For: R.Kiepzig/J.Haberthur Daily Charges _ $3,999.08 _ Total Charges: ^ $89,702.05 _ ROP & Gas: Current Avg 24 hr Max Max®ft Current Pump & Flow Data: R.O P. (ft/hr) na na na na Flow In(gpm) na' SPP_(2si) _� —_ na Gas(units) na 48 264 Flow In (spm) na Gallons/stroke 4.1160 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na !vimHole Condition 10980' 90.3 — 0 bbls 11.75° �-PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 10980' 10.30 10.30 55 17.5 8 35 11.2 8.00 13,000 9.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 • Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) • Gas Breakdown H2S Data 1 Sample Line Max: 50+ppm 'Avg: 20 I Ambient Air Pit Room Max: 8 Avg: 3 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to _ to _ to to to — ---- to to Gas Type abreviations: BG - Background Gas; GP • Gas Peak; CG -Connection Gas; WTG -Wiper Trip Gas; POG -Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T-- -Trip...; F--- Formation...; E---Early... • 24 hr Recap: POOH from 10980'to 9618'and slug pipe. Continue POOH from 9618'to 6243'and worked through tight spot to 6170'. RIH to 6243'and staged up pumps to 700 gpm. Backreamed from 6243'to 6090'. POOH to 4673'and circulated a Hi Vis sweep with large increase of cuttings returning to shaker. POOH to casing shoe and pull tested Rhino Reamer. Hole swabbing while attempting to POOH in casing. Pumped out of casing at 215 gpm with 400 psi. Serviced Top Drive. Continued pumping out of casing. UD BHA. 7 bbl loss for trip out. Test BOPs. Logging Engineer Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. —. Report#: 12 _ Well: ODSN-17 Date: 9/13/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 10980' -------- — Location: North Slope Progress 24 hrs: 0 Sperry Drilling Rig: Nabors 1 i)AC Rig Activity: Run 9 518"Liner Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $3,999.08 Total Charges: $93,701.23 • ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ na na na na Flow In(gpm) na SF'P (psi) na Gas(units) na 10 38 Flow In(spm) na Gallons/stroke 4.1860 Depth On Bot Hrs Ann Corr Avg Diam _ _ Drilling na Min na Avg na Max Hole Condition 10980' 90.3 0 bbls 11.75' PWD All Circ na Min na Avg na Max • Mud Data: _ Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 10980' 10.10 10.10 44 17.5 9 17 12.0 9.40 12,000 8.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM 0....._Condition 300 PDC 10.63 1.270 90.30 4670' 6310' 16 123 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ _ (current) Gas Breakdown H2S Data I Sample Line Max: 53+ppm Avg: 3 ) Ambient Air Pit Room Max: 9.9 Avg: 2 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to �+® to to to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Finish testing BOPS. R/U and run 9 5/8"liner to 4608'and circulate 2X bottoms up with full returns.Max gas of 28 units w/53+ppm H2S from sample line,9 ppm H2S from ambient shaker sensor. Continue RIH with tight spot at 6330'. Wash down from 6409'to 6448'. Washed down from 6409'to 6448'with 29 units gas,36 ppm H2S from sample line and 6 ppm H2S from ambient shaker sensor. Pumped away 25 bbls. P/U liner hanger and began running liner on 5"DP. Losses so far on liner trip in 85 bbls. !Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: __13 _ Well: O DSN-17 Date: 9/19/2010-04:00 HALLIBURTON Area: _Oooguruk 04:00 Depth �� 10980' _— _ — — Location: North Slope Progress 24 hes: —0' � Sperry Drilling Rig: Nabors 19AC Rig Activity: _ __ Chg out Rams Job No.: AK-AM-0007007267 Report For: _R.Klepzig/.1.Haberthur Daily Charges $3,999.08 Total Charges: ____$97,700.31 ROP & Gas_ : Current Avg 24 hr Max Max @ ft Current Pump & Flow Data. R.O.P. (ft/hr) na_ na na na Flow In(gpm) na SPP(psi) na Gas(units) na 40 345 na Flow In(spm) na Gallonsistroke 4.1860 Depth On Bot Hrs Ann Corr Avg DiamDrilling na Min na Avg na Max Hole Condition 10980' 90.3 0 bbls 11.75" PWD All Circ na Min na Avg na Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (lb/1 00ft2) ml/30min mg/I % 10980' 10.15 10.15 42 15.0 10 21 13.0 8.50 13,000 8.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 16 123 Lithology (%): I Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data Sample Line Max: 53+ppm Avg: 1 Ambient Air Pit Room Max: 25 Avg: 1 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG -Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG- Produced Gas; RG - Ream Gas;T-- -Trip...; F-- - Formation...; E--- Early... 24 hr Recap: Ran liner on 5"DP at reduced rate due to down hole losses. R/U cmt head and step circ to 4 bpm.345 units max gas with 25ppm H2S from ambient shaker sensor. Set 9 5/8"liner at 4498'TOL. R/U cmt line and circ w/losses noted at 8 bpm. Reduced rate to 4 bpm at 630 psi Pump cmt. Displaced cmt and bumped plug with rig pumps at 6 bpm and 1000 psi. Inceased pump rate to 9 bpm at 2850 psi with 60%losses. Lost 92 bbls while cementing. Set packer and test to 3500 psi for 5 min. Released from liner. Circulated 1.5 BU w/no cmt at BU and 276 units max gas. POOH and L/D liner running tool. N/D N/U BOP. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air — Customer: Pioneer Natural Res._ Report#: 14 Well: ODSN-17 Date: _ HALL®IQU1�"N'O1� 9/20/2010-04:00 Area: Oooguruk 04 00 Depth 10980' — — — Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $5,397.99 w/ADT Total Charges: $103,098 50 ROP & Gas: Current Avg 24 hr Max Max G@ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) na SPP (psi) na Gas(units) na na na na Flow In(spm) na Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg____ na Max Hole Condition PWD - 10980' 90.3 0 bbls 11.75" All Circ na Min na Avg na Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec./qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 10980' 10.15 10.15 42 15.0 10 21 13.0 8.50 13,000 8.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition r_ 400 Sec FXG-46Ds 8.5 0.991 0.00 10980' 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) Gas Breakdown I H2S Data II Sample Line IMax: Avg: Ambient Air Pit Room IMax: Avg: Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to _ to _ to to to to • to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG - Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG -Ream Gas; T---Trip...; F---Formation...; E---Early... 24 hr Recap: Installed lower VBR's on stack and test same. R/U MPD equipment.Change pump liners from 6"to 5.5". UD 2 stnds DC and 2 stnds HWDP. P/U 102 jnts DP while RIH. Circ DP volume to flush. POOH racking back 5"DP. Service Top Drive. Clear floor and M/U 8.5"BHA. Shallow pulse test MWD at 325'-good. Continue RIH. No gas to report. Logging Engineer Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air �! Customer: Pioneer Natural Res. Report#: 15 --- �� HALLIBURTON Well: ODSN-17 Date: _ 9/21/2010-04:00 Area: Oaoguruk 04:00 Depth 11075' ------ Location: North Slope Progress 24 hrs: 95' E3per,'v Drilling Rig: Nabors 19AC Rig Activity: Drilling-- Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $5,397.99 w/ADT — Total Charges: $108,496.59 ROP & Gas: Current ....._® 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 46.0 32.0 55.0 11037' Flow In(gpm) 598 SPP (psi) _� 3010 Gas(units) 25 37 74 10999'a Flow In(spm) 166 Gallons/stroke _ 3.5920 Depth On Bot Hrs Ann Corr Avg DiamDrilling 12.88 Min _13.03 Avg__ 13.08 Max Hole Condition 11070' 3.1 0 bbls 8.50" PWD All Circ 12.88 Min 13.03 Avg 13.08 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor 7lids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 10980' 10.15 10.15 42 15.0 10 21 13.0 8.50 13,000 8.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 3.13 10980' 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 10980 to 11075 74 37 4734 219 97 94 66 BG to _ to _�� - — to to - to – - to to Gas Type abreviations: BG -Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: RIH to 10820'and tag cement stringers. Wash and ream to 10850'and test casing shoe to 3500 psi for 30 min. Slip and cut drill line. Continued to wash and ream to 10885'. Drilled out float equipment and shoe. Drilled 20'of new hole to 11,000' (5372'TVD). CBU and displace well with new 10.0 ppg mud. Perform FIT to 14.0 ppg EMW. Rigged up MPD RCD. Drill ahead. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report.#: __ 16 Well: ODSN-17 Date: 9/22/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 12454 –� — Location: North Slope Progress 24 hrs: 1379' aperry Drilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Flaberthur Daily Charges $5,397.99 w/ADT Total Charges: . $113,894.68 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 88.0 79.9 187.6 11316' Flow In (gpm) 658 SPP (psi) 3830 Gas(units) 1370 610 4577 11992' Flow In(spm) 183 Gallons/stroke 3.5920 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.36 Min 13.03 Avg 13 43 Max_ 12454' 22.95 7.5 bbls 8.84" All Circ 12.36 Min 13.03 Avg 13 43 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH 1Chlorides Cor Sclids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 11883' 10.10 10.15 44 8.5 14 31 5.6 8.20 12,500 7 3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 400 Sec FXG-46Ds 8.5 0.991 3.13 10980' 1474' 25 135 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 'Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg C1 C2 C3 C4 C5 Type 11050 to 11910 859 252 70175 2920 1202 609 243 BG 11910 to 11990 2029 862 139522 5737 2190 1022 391 BC 11990 to 12000 4577 3518 379760 12392 4503 1760_ 587 BG 12000 to 12359 3228 1347 241580 10988 4349 1883- 665 665 BG 12359 to 12359 3828 2825 257729 11367 4430 1904 681 CG to _ to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG - Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG- Produced Gas; RG- Ream Gas; T-- -Trip...; F--- Formation...; E---Early... 24 hr Recap: Drilled ahead maintaining 13 ppg EMW from MPD with an average gas of 610 units. Maximum gas was 4577 units from a very thin stringer at 11992'. Very minor connection gases observed from 11978'on with a maximum being 3828 units over a background gas of 3100 units from connection at 12359'. Background gases began increasing from 750 units at 11950'to over 1400 units by 12350'. No mud losses. — Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: _Pioneer NaturalRes. Report#: _17 Well: ODSN-17 Date: _ 9/23/2010-04:00_ HALLIBURT®N Area: Oooguruk 04:00 Depth _ 13970' _ --- --- --- Location: North Slope Progress 24 hrs: 1516' ___ Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling _ Job No.: AK-AM-0007007267 Report For: R.Kiepzig/J.Cortez Daily Charges $5,397.99 w/ADT Total Charges: $119,292.77 ROP & Gas:: Current Avg 24 hr Max Max @ ft Current Pump & Flow_Data: _ R.O.P. (ft/hr) 80.0 89.8 475.1 12780' Flow In(gpm) SPP (psi) --- T- 4092 Gas(units) 480 526 2762 13720' Flow In(spm) 182 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.39 Min 13.04 Avg 14.14 Max_ • 13950' 41.66 20 bbls 8.91" All Circ 12.39 Min 13.04 Avg 14.14 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % _ 13692' 10.00 620.00 42 13.0 13 28 5.6 8.60 13,500 7.1 BHA [Min Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 42.00 10980' 2990' 25 135 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-1-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 12400 to 12900 2079 886 120408 6169 2739 1471 589 BG 12900 to 13708 1102 413 64659 3001 1347 903 517 BG 13708 to 13722 2762 1359 226573 8795 3113 1287 510 PG 13722 to 13787 710 540 54264 2740 1305 729 353 BG 13787 to 13787 620 450 47902 2244 1079 669 342 CG to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Drilled ahead to 13730'where standpipe increased 150 psi and ECD climbed to 14.14 ppg EMW. Slowed pump rate and worked pipe. 17 bbls lost due to pack-off. Circulated out with 2762 units gas and significantly increased cuttings load to surface. Total 24 hr mud loss of 22 bbls. Very minor connection gases of 100 to 150 units over background. Drilling ahead at report time. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#• 18 F-�/�►LLIBURT Well: ODSN-17 Date: 9/24/2010-04:00 Area: Oooguruk 04:00 Depth 14103' —-- — ~ Location: North Slope Progress 24 hrs: 133' Sperry drilling Rig: Nabors 19AC Rig Activity: _ Backreaming Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Cortez Daily Charges $6,258.96 Total Charges: $12.5.551.73 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na 78.9 135.7 14047' Flow In (gpm) 416 SPP (psi) 2435 Gas(units) 750 526 1224 14096' Flow In(spm) 119 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam _Drilling 12.60 Min 12.99 Avg 13.22 Max_ Hole Condition 13950' 43.78 > 35 bbls 9.15" PWD All Circ 11.30 Min 13.10 Avg 14.10 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (secgt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 13692' 10.10 10.10 41 15.0 12 22 5.0 9.60 14,000 7.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 3123' 25 135 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 I Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 13950 to 14103 1224 509 47270 2427 1251 820 437 BG TD to 4:00am 8560 1054 589524 33744 11167 4074 1285 GP to to to to _ to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG- Produced Gas, RG - Ream Gas; T-- -Trip...; F--- Formation.. ; E-- - Early.. 24 hr Recap: Drilled ahead to 14103'md,6185'tvd. Circulated two Hi Vis sweeps. Began taking mud losses. Started backreaming out to the top of the HRZ with mud losses up to 250 bbl/hr,tight hole conditions,pack off events and high gas up to 8500 units. Mud losses as of midnight 736 bbls. Continue backreaming at report time. Logging Engineer Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air .111M111111MMMMIIMAP 4111.11 •11=1, Customer: Pioneer Natural Res. Report#: 19 _ Well: _Pioneer Date: 9/25/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth _�14108:M�� Location: North Slope Progress 24 hrs: 5'----------]Date: Sperry Drilling Rig: Nabors 19AC � Rig Activity: RIH �_ Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Cortez Daily Charges $5,398.09 Total Charges: $130,949.8.2 ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) na 49.0 75.0 14107' Flow In •.m 0 SPP(psi) 4 Gas(units) na 1003 6101 na Flow In (spm) 0 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drillin• 12.71 Min 12.80 Avg 12.88IMax_ 14108' 44.08 52 bbls 8.55" All Circ 12.99 Min 13.07 Avg 13.23,Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Flit pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 14108' 10.00 10.00 40 15.0 10 22 8.5 9.00 15,800 7.4 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 3128' 25 135 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-1-CT-TD ILithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line'Max: 0 Avg: 0 J Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 14032 to 13986 6101 4292 522806 22814 8204 3414 1193 WTG 14100 to 14074 3853 721 414962 11882 4320 1988 811 WTG to to to �v to _ to to Gas Type abreviations: BG -Background Gas; GP--Gas Peak; CG -Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG- Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Continued backreaming while circulating an average of 962 units of gas. Pulled out to approximately 10928'MD. Tripped back into the hole,encountered apparent tight spots beginning at 13469'MD and continued to 14030'MD at which the pumps were kicked on and reamed towards bottom. Circulated up trip gas of 6101 units while running in hole and gas settled to an average of 1000 units before continuing to run in hole with no pumps. Brought pumps on at approximately 14080'MD and reamed to bottom where the remaining 5'were drilled to a section TD of 14108'MD,6186'TVD. A combination of trip gas and drilling gas of 3836 units was circulated up. Pumped a 3 phase sweep according to program. Short tripped 10 stands up hole losing 14 bbls. Began running back in hole and noticed 8 bbls gain for first 5 stands. Calculated 288 bbls loss from midnight to midnight. Currently running in hole to circulate and displace at time of report. Logging Engineer: Ryan Massey/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 20 Well: —ODSN-17 Date: 9/26/2010-04:00 HALLIE3URTC IN Area: - Oooguruk_ 04:00 Depth _ 14178'— �� ------ -- Location: North Slope Progress 24 hrs: 0'�_ Sperry Drifting Rig: Nabors 19AC Rig Activity: �Laying Down 3HA m Job No.: AK-AM-0007007267 Report For `R.Kle _ pzig /J.Cortez Daily Charges _______ $5,398.09 Total Charges° $136,347.9'1 _—a l ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: _ R.O.P. (ft/hr) na na _ na — na Flow In(gpm) 0 SPP(psi) _ __���0 Gas(units) na 342 2548 na Flow In(spm) 0 Gallonsistroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling - Min -Ava - Max 14108' 44.08 52 bbls 8.55" All Circ 12.43 Min 12.87 Avg 13.24 Max Mud Data: Density(ppg) _ Viscosity MBT PV YP API Filt pH Chlorides Co,Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mgil 14108' 10.00 10.00 48 10.0 21 27 6.0 8.30 16,000 19.3 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 JAvg: 0 I Ambient Air Pit Room(Max: 0 JAvg: 0 Gas(units) Chromatograph (ppm) Depth max avg C1 C2 C3 C4 C5 type 05:49am to 06:15am 2548 1261 235453 10918 4064 1827 763 WTG _to to _ to to to to _ to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas,T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Continued running in the hole to 14100'MD and circulated. Circulated 2435 untis of trip gas which promptly fell off to a background gas of 230 units and slowly dropped off before pump rates were lowered. Displaced hole to 13.0ppg mud in preparation for the casing by combining 11.Oppg and 18.0ppg spike fluid from RSC in the rig pits. Multiple circulations took place to equalize system to 12.9ppg. Background gas averaging 113 units were noted during displacement. Tripped to the shoe and pulled RCD head and prepped for pulling out of hole. Pulled out of hole with no problems losing 10 bbls to the hole. Began laying down BHA and downloaded MWD. Continuing to lay down BHA at time of report. 37 bbls loss downhole was noted from midnight to midnight. Logging Engineer: Ryan Massey/Colby Marks * 10000 units= 100%Gas In Air ° Customer: Pioneer Natural Res. _ Report#: 21 _ Well: _OUSN 17 Date: 9/27/2010-04_:00 HALLIBURTON Area: Oooguruk __ 04:00 Depth 14108_` -- - Location: North Slope Progress 24 hrs: 0' _ Sperry Dritili n Rig: Nabors 19AC RigActivity: Lain Down BHA Laying Job No.: AK-AM-0007007267 Report For: R Klepa .Cortez Daily Charges $5,398.09 Total Charges: _$141,746.00 _ _ ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: _ R.O.P. (ft/hr) na na na na Flow In(gpm) 0 SPP (psi) 0 Gas(units) na 32 91 na Flow In (spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg DiamDrilling - Min _ -Avg - Max Hole Condition 14108' 44.08 52 bbls 8.55" PWD All Circ - Min ' -Avg — Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min_ m /cZi__, 14108' 12.70 12.70 47 10.0 16 32 9.6 9.80 16,000 17.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-a\-X-1-CT-TD 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-131-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff __ _ (current) IGas Breakdown H2S Data II Sample Line Max: 0 ]Avg: 0 1 Ambient Air Pit Room IMax: , 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to __ to _ to _ ___ to to to �� to ---. to Gas Type abreviations: BG -Background Gas; GP -Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas; T---Trip...; F--- Formation...; E---Early... 24 hr Recap: Finished laying down the BHA. Picked up 7"elevators and running equipment. Picked up and ran 7"casing into the hole. Noted a 3.3 bbls loss. Made up hanger and began running in the hole on 5"drill pipe. Noted a 11 bbls gain thus far. Background gas of 32 units was detected while filling drill pipe and circulating at low pump rates. Logging Engineer: Ryan Massey/Colby Marks * 10000 units= 100%Gas In Air Customer: _Pioneer Natural Res. Report#: 22 Well: ODSN-17 _f Date: _9/28/2010-04:00 HA4..LIBURT� ; Area: Oooguruk N� _ 04:00 Depth 14108' - Location: North Slope Progress 24 hrs: _ _ 0' Sperry Drilling Rig: Nabors 19AC �_ RigActivity: Prepping to pumpdryjob tY __ Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Cortez Daily Charges $5,398.09 _ Total Charges: e $147,144.09 ROP & Gas: Current Avg 24 hr Max Max a@ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) na _ na na na Flow In(gpm) 0 SPP si 0 Gas(units) na 234 2351 na Flow In(spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling - Min -Avg Max Hole Condition 14108' 44.08 52 bbls 8.55" _PWD All Circ - Min Avg -I Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) ••b E. cP (Ib/100ft2) ml/30min m4/1 14108' 10.00 10.00 41 12.0 6 20 9.0 9.00 15,000 6.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-B T-C-X-I-CT-TD rLithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: , 0 Avg: 0 Gas(units) Chromatograph(ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to to —_— to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Continued tripping in the hole on 5"drill pipe while noting a 12 bbls gain. Circulated and conditioned mud with low flow rates(28 gpm)slowly increasing to 166 gpm. Once flow rates increased,trip gas was circulated out. Trip gas slowly rose to a max of 2351 units and slowly dropped off. Mud was circulated from a 11.4 pgg to a 10.2 while background gas leveled off around 50 units. Setting ball was dropped and pumped. Running tool did not release and was emergency released. Circulated and conditioned mud. Performed cement job however plug did not bump. Rigged down cementing equipment,cut and slip drill line,and pumped dry job. Began tripping out of the hole at time of report. Losses from midnight to midnight were 33 bbls. Logging Engineer: Ryan Massey/Colby Marks * 10000 units= 100%Gas In Air Customer Pioneer Natural Res. - Report#: 23 a Well: ODSN•17 _ _ Date: 9/29/2010-04:00 HALLIBURTCDN Area: Oooguruk—�_ 04:00 Depth 14108' — -- -- Location: North Slope _ Progress 24 hrs: �0' Sperry Drilling Rig: Nabors 19AC �~ Rig Activity: RIH w/7"Casing Job No.: AK-AM-0007007267 _ Report For: R.KlepzigiJ.Cortez Daily Charges TM $6,258.96 _ Total Charges: $1535 ,403.0 _ ROP & Gas: Current Avg _ 24 hr Max Max @ ft Current Pump & Flow Data: _ R.O.P. (ft/hr) na na na - na — Flow In (gpm) 0 SPP (psi) 0 _ Gas(units) na na na na Flow In(spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling - Min Avg - Max__ Hole Condition14108' 44.08 52 bbls 8.55" -PWD All Circ - Min Avg - Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids _ Depth ft in out (sec/qt) ••b E• cP (Ib/100ft2) m1/30min m•/I % 14108' 10.20 10.20 44 10.0 11 21 9.0 9.00 15,000 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 400 _ Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff L (current) Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: , 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to _ to _ _ to – _to _�_ �i to to to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG - Ream Gas;T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Continued to pull out of the hole with 5"drill pipe sideways in order to pick up the 4"drill pipe. Lost 39.7 bbls on the trip out. Ran in_the hole with remaining 35 stands and singled out of the hole laying the 5"down. Gained 10.8 bbls during the trip 0 in and lost 13. bbls on the trip out for a net loss of 2.2 bbls. Rigged uo to run casing. Began running casing and noted a 1.3 bbls gain thus far. The losses down hole from midnight to midnight were 32.9 bbls. Logging Engineer: Ryan Massey/Colby Marks * 10000 units= 100%Gas In Air �---.. Customer: Pioneer Natural Res. Report#: 24 Well: ODSN-17 Date: 9/30%2010-04:00— 1-IALLIBURTONArea: Ooo uruk �� 04:00 Depth 14_tos' -- Location: North Slope _ Progress 24 hrs: 0' Sperry Drifting Rig: Nabors 19AC Rig Activity: RIH w/7"Casing — Job No.: AK-AM-0007007267 Report For: J. Polya/,;.Cortez Daily Charges $5,398.09 Total Charges: $158,651714 ROP & Gas: r Current Avg a 24 hr Max_ Max @ ft— Current Pump Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 0 SPP (psi) 0 Gas (units) na na na na Flow In(spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling - Min -Avg HMax Hole Condition14108' 44.08 52 bbls 8.55" PWD All Circ Min -Avg Max— • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30minmg/I 14108' 10.20 10.20 44 10.0 12 20 9.0 9.00 15,000 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-1-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) , Gas Breakdown H2S Data I Sample Line Max: 0 'Avg: 0 I Ambient Air Pit Room Max: . 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg C1 C2 C3 C4 C5 fype to _ to ___ to to to to to to I — to___ Gas Type abreviations: BG -Background Gas; GP-Gas Peak; CG -Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG- Produced Gas; RG-Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Continued to run 7"liner tieback to the landing point. Pumped 140 bbls of diesel to freeze protect behind the casing prior to landing it. Took returns into pit#1 and the trip tanks and then pumped the gained volume over to the RSC for disposal. Rigged up and testing BOP's. Logging Engineer Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: _Pioneer Natural Res_. Report#: _ 25 Well: ODSN-17 Date: 10/01/2010-04:00 HALLIBURTONArea: —Ooaguruk04:00 Depth Y 14106' ____ -- Location: North Slope _ Progress 24 hrs: 0' Sperry Drilling Rig: —AK-AM-0007007267 Nabors 19AC __ Rig Activity: �Pressure Testing Job No.: _AK AM 0007007267 Report For: _J. Polya/J Cortez Daily Charges $6,097.55 Total Charges: _ $159,500.R-- .... ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: __ R.O.P. (ft/hr) na ` na na na Flow In(gpm) 0 SPP(psi) —�� 0 Gas(units) na na na na Flow In (spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling - Min Al. .... - Max_ Hole Condition 14 08' 44.08 52 bbls� 8.55" -PWD All Circ Min Avg Max. j Mud Data: Density(ppg) _ Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min m9/I % 14108' 10.20 10.20 44 10.0 12 21 9.0 9.00 15,000 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition __ 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD 300 PDC 10.63 1.270 90.30 4670' 10980' 6310' 15 136 1-1-BT-C-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _ M Gas Breakdown H2S Data 1 Sample Line'Max: 0 Avg: 0 I Ambient Air Pit Room Max: , 0 'Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to ____to _ to to to to to Gas Type abreviations: BG- Background Gas; GP -Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Continued to test BOP's,Rig up and Run in hole with 4"Drill Pipe to 13950.Currently pressure testing casing to 3665 psi_Trip showed 23 bbls over calculated 2 sample catchers coming in today. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air • Customer: Pioneer Natural Res. Report if: _ 27 ---I Well: ODSN-17 Date• 10/03/2010-04:00 HALLIBURTON Area: __Oooguruk 04:00 Depth 14108'_ Location: North Slope Progress 24 hrs: 0' ___ Sperry Drilling Rig: Nabors 19AC Rig Activity: �Mavng up BHA_ Job No.: AK-AM-0007007267 Report For: J. Polya/J.Cortez _ Daily Charges $6,097.55 Total Charges: _$165,598.15 ROP & Gas: Current , Avg 24 hr Max Max @ ft Current Pump & Flow_Data_:___ _ R.O.P. (ft/hr) 0.0 40.0 122.0 14122' Flow In(gpm) 350 SPP(psi) 2711 Gas(units) 0 100 188 14126' Flow In(spm) 100 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling - Min -Avg - Max Hole Condition 14128' 0.9 10 bbls 6.25" PWD All Circ Min -Avg - Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft ► in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 14108' 10.20 10.20 43 10.0 11 20 9.4 9.00 14,000 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 _ 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data II Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room'Max: . 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to _ to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG -Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG -Ream Gas;T---Trip...; F---Formation.. ; E---Early... 24 hr Recap: Set retainer as per Halliburton hand directions. Spotted cement below retainer,pulled out of the retainer with the stinger. Circulated 1.25x with Max gas 38 Units. Rig up to trip out of the hole,trip out of the hole to surface.Noted-19 bbl loss during trip. Lay down stinger. Rig up and test BOP's. Rig down and prepare to run in hole for cleanout run. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air • Customer: Pioneer Natural Res. Report#: 27 Well: ODSN-17— Date: –10/0572010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth �_14128_�—� -- Location: North Slope Progress 24 hrs: __ 20' -_ Sperry Drilling Rig: Nabors 19AC Rig Activity: - POOH Job No.: AK-AM-0007007267 Report For: J. Priya/.1 Cortez Daily Charges $4,884.32 Total Charges: _� $173,030.10-- ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 40.0 122.0 14122' Flow In m 350 SPP (psi! 2711 Gas (units) 0 100 188 14126' Flow In (spm) 100 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Av Diam _ Drillin - Min -Avg _ - Max _ Hole Condition 14128' 0.9 10 bbls 6.25" PWC All Circ - Min -Avg ----Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 14108' 10.20 10.20 39 10.0 10 18 9.9 9.00 14,000 8.2 — BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 400 Sec FXG-46Ds 8.5 0.991 43.78 10980' 14108' 3128' 25 135 2-3-BT-A-X-I-CT-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown FH2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: , 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to- —-- to ---to to to to _ to to to Gas Type abreviations: BG - Background Gas; GP Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG-Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Single in with 4'drillpipe to 8694',continue to RIH with full stands. Performed Bond Log from 13600-13900,continue to RIH,drillout shoe track.Drill 20 ft new formation.Max gas 188 units,no trip gas noted.Performed FIT to 12.5 ppg. Run Bond Log from 14060 to14108,Currently POOH at report time. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air 1 Customer: Pioneer Natural Res. Report#: 28 Well: ODSN-17 Date: 10/04/2010-04:00 HALLIE3URTDN Area: Oooguruk 04:00 Depth ___V 14332' ---- -- ----- - Location: North Slope Progress 24 hrs: _ 204' _ SperryDriftingRig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J.Cortez_ Daily Charges $6,361.15 Total Charges: __ $180,868.08 ROP & Gas: CurrentAvg 24 hr Max Max @ ft Current Pump & Flow_Data: _ SPP _ R.O.P. (ft/hr) 74.0 97.0 154.0 14122' Flow In(gpm) 209 (psi) -_ 2150 Gas(units) 411 501 783 14126' Flow In (spm) 60 Gallons/stroke 3.5170 Depth On Bot Hrs_ Ann Corr Avg DiamDrilling 9.70_ Min 9.83 Avg_ 10.00 Max _ Hole Condition 14' 0.9 10 bbls 6.25" PW® All Circ 9.58 Min 9 83 Avg 10.11 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Fiit pH Chlorides Car Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 14108' 10.20 10.20 40 12 20 8.2 • BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 700 Sec FXG-54 6.125 0.389 0.00 0' 0' 0' 0 0 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data 1 Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: . 0 Avg: 0 Gas(units) Chromatograph(ppm) Depth max avg Cl C2 C3 C4 C5 Type 14128 to 14250 783 503 91812 2427 717 262 103 to to to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG-Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Finish POOH,Lay down BHA 6, Picked up BHA 7 RIH,No losses or gains during trip in. Installed RCD, Staged up pumps and displaced to OBM,went smoothly.Start drilling ahead with no losses. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air ' Customer: Pionee_r Na_tural Res. Report#: 29 _ _ Well: ODSN 17 Date: 10/05/2010-04:00 1�1�4LLIBURTON Area: _Oooguruk04:00 Depth 16279' i_ — _ — Location: North Slope Progress 24 hrs: 1947' v _ Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling - Job No.: AK-AM-0007007267 ! Report For: J. Polya/J.Cortez Daily Charges $7,269.97 Total Charges: $188,13805 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 144.0 139.0 334.0 15629' Flow In (gpm) 238_ SPP (psi) _2743 Gas(units) 491 943 2778 15771' Flow In(spm) 240 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.38 Min 9.87 Avg 10.20 Max Hole Condition16234' 19.3 20 bbls 6.50" PWD All Circ 9.35 Min 9.88 Avg 10.33 Max Mud Data: Density(ppg) Viscosity HTHP PV Y Elec Stab Lime Alkal Cor Solids _ Depth ft in out (se c/gt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pam) to 15602' 7.80 7.80 43 5.3 9 7 1489 7.38 5.7 3.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 700 Sec FXG-54 6.125 0.389 0.00 0' 0' 0' 0 0 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 'Avg: 0 I Ambient Air Pit Room IMax: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 15120 to 15414 2141 1279 265320 4497 1510 539 178 GP 15672 to 15860 1310 2778 324078 5677 1872 641 203 GP to _ to to to __ to _ to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas; T---Trip...; F---Formation...; E---Early... 24 hr Recap: Drilling ahead, loss of 25 bbls over the shakers.Samples predominately sandstone.Occasional Claystone when in crossing through zone 2.Gas is moderate to high peaking at 2778 units. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units = 100%Gas In Air Customer: Pioneer Natural Res. Report#: 30__ Well: ODSN-17 Date: 10/06/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 18346' Location: North Slope Progress 24 hrs: 2067' !Sperry Drilling Rig: Nabors 19AC Rig Activity: _ Drilling Job No.: AK-AM-0007007267 Report For: �J. Polya/J.Cortez Daily Charges $6,361.15 Total Charges: $193,760.78 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 170.0 150.0 539.0 17368' Flow In(gm) 238 _ SPP(psi) 2847 Gas(units) 804 768 1701 16476' Flow In (spm) 66 Gallons/stroke 3.5170 ' Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.52 Min 10.07 Avg10.35 Max Hole Condition 16234' 35.9 20 bbls 6.50" PWD All Circ 9.52 Min 10.08 Avg 10.63 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids] Depth ft in out (sec/qt) _Jm1/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 15602' 7.90 7.90 47 5.2 11 11 1465 8.42 6.5 2.7 BHA Run # 1 Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 — 700 Sec FXG-54 6.125 0.389 0.00 0' 0' 0' 0 0 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 16861 to 16900 1649 1101 197113 3670 1206 445 154 GP 17792 to 17884 959 1560 174687 2996 991 358 118 GP to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas;T-- -Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilling ahead, loss of 26 bbls over the shakers and on cuttings.Samples consist 100$sandstone.Occasional Claystone when crossing different zones.Gas has been moderate with no wild peaks. Tom Mansfield is coming out for Ryan Massey Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 31 Well: ODSN-17 Date: 10/07/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth �19947 Location: North Slope Progress 24 hrs: 1600' Sperry Drilling Rig: Nabors 19AC Rig Activity: TD/Circulating Job No.: AK-AM-0007007267 Report For: J.Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $200,860.35 ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: _ R.O.P. (ft/hr) 0.0 145.0 310.0 19766' Flow In(gpm) 238 SPP(psi) 2847 Gas(units) 804 549 1340 19659' Flow In(spm) 66 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg DiamDrilling 9.68 Min 10.27 Avg_ 10.72 Max _ Hole Condition 19947' 48.4 20 bbls 6.50" PWD All Circ 9.66 Min 10.27 Avg 10.72 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 19555' 8.00 8.00 47 6 10 8 1232 6.73 5.2 4.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 40 60 Gas Breakdown rH2S Data I Sample Line Max: 0 IAvg: 0 Ambient Air Pit Room Max: . 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 19300 to 19725 1340 706 153597 3737 1262 405 125 GP to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T-- -Trip...; F---Formation...; E--- Early... 24 hr Recap: Drilling ahead,loss of 20 bbls while drilling,stopped to repair the top drive.Continue to drill till reaching the end of the sand @ 19773'md,Continued to drill to TD at 19947'md,6382.36'TVD.Samples showed really good sandstone till 19772 ft then degraded to daystone.Gas also dropped off t this point.TD well 10/07/2010 @ 00:45 hrs.Circulated bottoms up then started POOH to the shoe. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air �! � Customer: Pioneer Natural Res. Report#: _ 3.2 WelODS N-17 Date: 10_/08/201_0-04:00 F#14LLIBURTON Areal:: Oooguruk 04:00 Depth 19947' -- -- - - Location: _ North Slope__ Progress 24 hrs: 1600' Sperry Drilling Rig: --(Tabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007007267 Report For: J. Polya/J Haberthur Daily Charges $6,361.15 Total Charges: $207,221.50 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow_Data: • R.O.P. (ft/hr) _ na na — na na Flow In(gpm) 152 SPP(psi) ®1397 Gas(units) 0 198 5609 19946', Flow In(spm) 43 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition19947' 48.4 20 bbls 6.50" PWD All Circ 9.65 Min 10.35 Avg 11.51 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 19947' 8.00 8.00 51 6 11 7 1296 4.79 3.7 4.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 _ 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 40 60 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: ' 0 IAvg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to _ to _ to - — to __ -- - - to to to to —to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Continue to short trip to inside 7"casing.Circulate well clean,Slip and cut drill line and serviced the top drive Trip in hole to TD,washed down from 18800 to 19690 ft do to weight.Circulated 2X bottoms up,Trip gas 5609 units at B/U. Pull out of the hole to sump at 15213'pumping 16 bbls of 10.1 every 10 stands.Spotted 40 bbl pill and pulled to shoe,swapped out 8.0 ppg mud for 10.1.Circulated till hole was stabilized. Pulling the RCD at report time. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 33 Well: _ ODSN-17 Date: 10/09/2010-04:00 IALLIBURTON Area: Oooguruk 04:00 Depth 19947' —- Location: _ North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: Running Liner Job No.: AK-AM-0007007267 Report For: J.Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $213,582.65 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 0 SPP(psi) 0 Gas(units) 0 0 0 Flow In(spm) 0 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na.Min na Avg na Max._ 19947' 48.4 20 bbls 6.50" All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % _ 19947' 8.10 8.10 51 6.2 11 7 1367 4.27 3.3 5.1 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 — 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 40 60 . Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: . 0 Avg: 0 Gas(units) Chromatograph(ppm) Depth max avg Cl C2 C3 C4 C5 Type to to _ to to to . to . to to _ to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Pull 6.125"BHA out of the hole gains and losses were negligible.Lay down BHA#6,Rig up and currently running 4.5"liner, Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 34 Well: ODSN-17 Date: 10/10/2010-04:00 HALLIBURTON Area: -Oooguruk 04:00 Depth 1994T Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: _�POOH Job No..: AK-AM-0007007267 Report For: J. Po_lyaLJ. Haberihur Daily Charges — $6,361.15 Total Charges: $213,582.65 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 0 SPP(psi) 0 Gas(units) 0 72 1247 14100' Flow In (spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling naiMin na Av.� na Max Hole Condition PWD All Circ 0.00 Min 0.00 Avg o.00 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 19947' 10.10 10.10 60 5.6 19 8 1353 3.89 3 19.0 BHA Run # IB it Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room JMax: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to t o to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG - Pumps Off Gas; PG-Produced Gas; RG -Ream Gas;T—-Trip..., F--- Formation. .; E-- - Early... 24 hr Recap: Finish RIH with 4.5"liner then continued RIH on 4"drill pipe.Set liner with the Top at 14265',and the bottom at 19695 ft.No losses or gains noted suring flip in.POOH to casing shoe and circulated casing volume with max gas 1247 units of trip gas(TG).TG dropped off quickly with continued circulating.POOH with liner tool on 4"drill pipe with-10 bbl displacement. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air ' Customer: Pioneer Natural Res. Report#: 35 Well: ODSN-17Date: 10/11/2010-04:00 HALLIBURTON Area: Oooguruk — 04:00 Depth _ — — Location: North Slope Progress 24 hrs: Sperry Drilling Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007007267 Report For: J. Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $219,943.65 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 0 SPP(psi) 0 Gas(units) 0 72 1247 14100' Flow In(spm) 0 Gallons/stroke 3.5170 Depth On Bot Hrs Ann Corr Avg Diam Drilling _ na Min I na Avg na Max Hole Condition PWD AllCirc 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in _ out (sec/qt) (ml/30 min) cP (Ib/100ft) (volt) (lbs/bbl) (Porn) % 19947' 10.10 10.10 60 5.6 19 8 1353 3.89 3 19.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 600 Sec FXG-46Ds 6.125 1.114 0.90 14108' 14128' 20' 22 82 700 Sec FXG-54 6.125 0.389, 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 0 'Avg: 0 I Ambient Air Pit Room Max: , 0 'Avg: 0 Gas(units) Chromatograph(ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to _ to to to --- to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-.Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: NO REPORT Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air N Y toE d a o F- a o Y G O . 0 V 2 7 F- y 2 7 N co7 z o r w Q O m m o cn 0 )6 • m 0 O Z < CD N a- a a U a Z Q W a a 0 0 0 O W F- O H p CL Q < u, a U U O oO X X O c', < z J m F- F- W 00 m W - M N 2 a O x N an a u) O o 0 O a O a N J LL co d V 3 O a K a a a a O u) E N O OO O M M E. )` 7 o N n n Z m as d A a a a n R E Z. C o 3 12 a m K v O m o N o0 O a m z Q £ W CC O m 2 O O E O O Cl- 0 o 0 > ▪ O o Z Q D >- :ii"ccoo N W CC W- d Wo v rn a O d 0.. I-- m CO (/) F- o - o co O o co m 0 x aO> a Oa a 0 C) co O oo rn C ch N oN co o co co cn LL t o m co Q 7 co o N m O 0 O a v a> t 2 C 2 o d - o v a O 0 6) M O C, .M-- Q m N . V) cpp W cLJ cc; O a m __ • a W s m X K J o aCD CD X V n n t Millit Qa W C M m M a cD I 0) = O O O O O O O O mM { COcO I� I f i i o 8d O V O I c) 2 i I ii I d w c 3 ae N Ocr E aai =O o aaz ce6 c I� 2 E ' 4] 2I = d a ! p 0 '610 N c c!c c m d c K O 3 w fm .. "6 .5 .5-F, 'a) a O a' O � c in mc� (� ac9 `m E p0000 dm ° a. in oc c c c c c m (0 p = _ (D I J c c c `) f0 c c)I c c'I o c m 0, 0, .= -a = 3 o.'a S m .- _ .- 1c 7 'a'c c 'c 'a - a - _ .- O o'n n._ .- '- '- = = - D 0 ,- y . 2 = .c = 0 , a' > > > n 2 0 a = _ = n m O m E H (- 0 0 0 0 0 0 3 a 0 H a 0 K 0 0 0 m 0 F- a m a H K H u 0 0 0 0 O) 2 a E . • no (oanmo '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U( O O O o N + (0 0 N O N 0 0 o o m o o w (D o o N o 0 (O (O a a m (D o0 o w w o o (0 (0 (O c0 (O (O (0 _ (• m .- N O O O M N N .- N .- N a N N N ' Q M N M N N N N N O a M N w(N w 000000000000000000000000000000 co (0MN WNN ya OO`(A y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M00MM0MMNMN N0U On000 0 a00as0aMMNNMaDo0NNNaa , = n0) 00 0 (N'D C)L Y 7 D LE y) n O t' H Q O U (7 a M f` 7 7 V r V O O (a xt J O Z <N Z QQ W 0 0 0 0 0 00000000 010 (0 0 0 0 0.0 0 0 0'0 0'0 0 0 O W F-D H 4.. V (O o w r- n 0 (0 o v M n O 0 0 o (nM CD n (0 0 0 O) ao N o (n (0 N v .- W m M W Q a E 00 (\ M a 0 - 0 0 0 0 0 .- m O �-- O O M N O .- ,- N N .- . a E O N O (0 0' a < H(/) O O O O o O (n (n (n O N to O O O 0 0 (n O O (n (n (n (n (n ([) N (i] n n 0) a M (0 N N O (1) a .4. 0040 ,i .- 000 ,- 00 .- , .- 0 .- .- , 00 .- 00000000 0 a w n O w a a a O NNNN 0 0 0 0 0 0 0 0 6666 ° 66666666666 NNMNMMM -.1N m O w M M w 0 0) H 0000000000000000 000000000000 n n N n O W V m 6 0 6 0 n o a a n M 6 M m n n (0 m M 6 M O O N 0 0 0 0 6 . IUO a v. vj Dj V7 N O . 7 0 0 0 0 0 (0 n O (0 (0 (0 O 0 n O O a N O .- N o 0 0 M aD 0 0 0 0 0 0 0 .. M N (.N) N , W fl. M M M N m O m N w O w w w w 0) w O O w w W O) m m 6 6 0) O) 0) 0) . 0 M o a a N N M M m - - - - - W N CO 7 0 0000 N u] '0 00 00 0 (0 d {0 a!8 E 0. 000 '400 M O M N M °1 E ,-0 , , N0 , vN r Z m O0 N (0 N 0 0 0 O O O 6 O O X n0-1-: 0664464 n a a a a Z d O N ' N 0 0 N OOOO MOOOO _ _ _ NNM N M N N N NN O O OO N M O MNNN _ _ Yo E Nm O AA N6000000000000000 0000000000006a0. 66666r5OdmZQ w Q: . ..m `- o O N 0 0 (0 O O (0 N 0 0 u") O u") ((") O o. O N (0 M O O (0 0 0 0 0 0 0 y 0 (0 ( 000 N m m w w COD m n n n w O D N n N m o O 06 NC nC 0D r rw n N n n a) (D (O C C C o (O2OUEO 0 , mwmwwwmwwwwmmcmmpwmmwmm o (n00) mo Q 0 -, S ' ON0000000n000N00unO00000000 a066640jZE- re 0 0000riri4446666666 - - (15666644444444 0 mo) mmmnm W a W ,- 07 ,- N O M M r n M M 0.D m w m M M (h 7 (h 7 M W n N N N N N N v w n o w .- 0 3O a _ NaDO .- rNNNnc � aDODie6CD (o6nr- rr- p) � ro (oCDCDCDCO - • r) NavuD a Nco H 0 = 0 w 73 U m M M M M M N A- N A- N N .- A- A- N N N N N N N N N N M M V (c N N N N N N O wN °w �oY rn�NO MO ° Cn ° �.- �MM MAa CO awNNDrMa �V n O(N (OrM (0 N CC rt wwro 0. ° mrn _ mmmm roCp mm4 - m (fl ; 4 (nn ; 0O04am - 0 '- mommom N- aMac- M•- \aW\a v O � m W Q`iMCN5nC) . w '- C wmO0OoN - 0 - (NM - 0 - n , NNNNO - _ N \ e . . . . . O(9C aM i - rertEnO 0 ONNN (D wO - nm0mO (0 aEn Cm OO0 ,- - O ONN8NN mmN wNOUNNNNNNN NN O, MON - (0a ONN ( (p O Mm (� (N (nNM wNO (nNOOO (� - KM L7MNo nMN NNmM MN N M N Mm pN , M M M N M m R (nN OWWNO 73 CO a \ a MM M O wNOVuM70MaK NNNNNNMMna MaasNaaMaaaaMa Do a 00 NNNNNw N !' 0.E,O O O O O a m a O m O m O N O 0 0 0 w w O M O w O 0 0 0 a O) = pE M N O O N w N G LL M w n (0 O m n m n 6 w N N M w (D (0 (p (0 m (D O) m O) O) O) O) O) ' H M (n (n w O w (0 n }� E N N M ,- .- ,- ,- = E V ' N a M M (`) a r0 W N N (0 a ' ' ' ' ' OM W 0 M M N N N N N ' e O' ; O '- '- N .- m o ,- r n a h o (O m e v (O CD O O) O ,- ,- e0 a 0 0 0 0 M d o 0 0. m - N W N M N N N m m m n O O '- '- .- N .-- - .-rto M - M , 0. O) O M O M N n,0 O O m.0 .. (O , n O = iD 0 0 0 6 r� O /� ' o N a m a O N N O) o n a n (0 n .- O N m N N n N0 .- 0 .- 0M0 0 n ! m n n w (n O W a o_ M N .- N .- .- N N M .- N N N M N N N N M N N N N N .- N a 0. } } n HMM . . , O O0. w (0 (0 `O O O) M N N m M O O O a M N O m m N N O N > 0) .- 0 .- O) n (4 W a- M@LI; . .• — . . . . ., 0 , . . , . . ,, , , — . . , ,, m . . N M n n O (0 Q d 0 ,,,, ) aaaaaaa (naaaaaaaavaaaaMa > y ,,,. . noa C NVV.,0 = ca ,0000000000000000000000000000000, H 0 0 0 0 0 0 0 N p d d � 3 rn(0 w 0 0 0 w m m N m n m N M .- .- 0 0 .- 0 .- 0 0) r O N N N N N N4.. ,W000 .- .- 0) I..LL a W 6 0 0 0 0) 0) 0i O 0) O) O) O O O O O O O O O O N N O O O O O O O 3 a n n 0.D m m 0 N- V1- 63-0 No O L 0 = 0t J L O O O a N M M w 0 0 0 0 0 0 0 0 0 M N M w w w w m w w w w m C y 12 J �, , o n n n W m (D N M m w w w w w w w w 0 w O) 0 0 0 0 0 0 0 0 O O N N O O N a a a a �/ 0.M (D o 0 o N n m o m M O) O) 0) 0) W 0) 0) O m w 0. (D o w 0) O) O) 0) N U.W C ♦� Q a a a a w n w w 0 0 0 0 0 0 0 0 0 M a a a a a a a a a a a 0 (0 n W C) W 0) 0) N. 40 a a a a a a a a a a 0. 0. a a a a a a a aO. = a 0 N N N N N N N d 0 d 0 0 0 0 a) 0 a) 0 0 (0 0 a) 0 a) 0 0 m a) U U U rd U O D U U O O . (q tn (O tq (n ,s ( (/� u) (n (of0 ( Ov) (Ov) (n (nu) v) u) V� (Ou) (Oo) 000 (e 000000 O civ n bn' comd . ( C 46br 0 66 .„,.„ 4 „ „ c1, ., „dO 4 (UCn' Dodd N N N N N N N N N M 9 H LLIBURTDN PIONEER 5pprry Itril;issg NATURAL RESOURCES ODSN-17 Interpolated Tops Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 _ 6.34 296.73 837.27 731.01 Base of Permafrost 1692.00 18.79 298.97 1667.96 1611.76 Top West Sak 2408.00 _ 37.98 _ 290.91 2300.03 2243.83 _ Tuffaceous Shale 3674.00 70.19 _ 255.89 2959.11 2902.91 _ Hue_1 3998.00 70.93 257.14 3065.82 3009.62 Hue_2 4340.00 70.48 258.62 3179.04 3122.84 Top of 9 7/8"Liner 4498.00 70.66 258.38 3231.52 3175.32 SCP 4659.80 71.14 259.64 3285.15 3228.95 Brook 2B 7643.00 _ 70.31 _ 258.35 _ 4266.47 _ 4210.27 Torok Top 9797.00 70.95 257.43 4978.08 4921.88 Torok Base 10382.00 70.92 245.48 5168.77 5112.57 Top of 7 Liner Tieback Seal 10829.00 70.75 228.12 5315.31 5259.11 _ Torok SH_1 10930.00 70.71 223.66 5348.78 5292.58 ICP1 10978.00 71.07 222.82 5364.53 5308.33 Top HRZ 12244.00 74.04 182.90 5750.02 5693.82 Base HRZ 12713.00 74.33 172.43 5877.78 5821.58 Kalubik Marker 13008.00 75.28 162.55 5955.25 5899.05 Top Kup C 13236.00 76.37 154.36 6009.32 5953.12 LCU 13239.00 76.36 154.27 6010.03 5953.83 BCU 13834.00 78.98 142.75 6137.29 6081.09 13991.00 79.90 140.87 6166.08 6109.88 Top Nuigsut_D1 14061.00 80.24 139.76 6178.14 6121.94 Top Nuiq::Nuiq_1_D1 14080.00 80.34 139.74 6181.35 6125.15 ICP2 14106.00 80.53 139.63 6185.67 6129.47 14425.00 87.03 141.78 6220.09 6163.89 Nuiq_1::Nuiq_2_D1 14460.00 86.99 141.07 6221.91 6165.71 Nuiq_2::Nuiq_3_D1 14573.00 86.08 138.46 6228.41 6172.21 Nuiq_3::Nuiq_4_D1 14760.00 86.09 136.94 6240.14 6183.94 Nuiq_4::Nuiq_5_D1 14863.00 85.03 135.86 6248.45 6192.25 T3 15000.00 86.65 136.08 6258.99 6202. T4(Invert#1) 15212.87 90.00 139.92 6266.33 6210.,.. T5 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_5::Nuiq_4_U2 15400.00 94.40 140.79 6257.82 6201.62 Nuiq_4::Nuiq_3_U2 15493.00 94.11 140.01 6251.08 6194.88 Nuiq_3::Nuiq_2_U2 15601.00 94.38 138.81 6242.75 6186.55 Nuiq_2::Nuiq_1_U2 15677.00 93.95 137.93 6237.38 6181.18 15700.00 94.29 137.49 6235.72 6179.52 _ T 7(Revert#2) 15854.23 90.00 141.21 6228.00 6171= T' 16000.00 85.64 144.07 6235.08 6178.83 Nuiq_1::Nuiq_2_D3 16105.00 85.00 143.72 6243.50 6187.30 Nuiq_2::Nuiq_3_D3 16196.00 84.24 140.01 6252.04 6195.84 Nuiq_3::Nuiq_4_D3 16319.00 84.30 138.72 6264.79 6208.59 Nuiq_4::Nuiq_5_D3 16430.00 85.80 139.96 6274.53 6218.33 19 16500.00 85.94 139.87 6279.50 6223.30 T10(Invert#2) 17098.72 90.00 141.12 6312.80 6256.60 T11 17205.40 94.00 142.93 6308.93 6252.73 Nuiq_5::Nuiq_4_U4 17510.00 94.70 139.62 6287.67 6231.47 Nuiq_4::Nuiq_3_U4 17580.00 94.97 139.42 6281.76 6225.56 Nuiq_3::Nuiq_2_U4 17707.00 94.55 139.67 6271.24 6215.04 Nuiq_2::Nuiq_1_U4 17785.00 94.95 139.38 6264.78 6208.58 T12 17800.00 94.68 139.42 6263.51 6207.31 T13(Revert#3) 18090.59 90.00 141.14 6248.33 6192.13 T14 18310.00 85.91 140.91 6259.03 6202.83 Nuiq_1::Nu1q_2_D5 18475.00 84.67 140.54 6271.26 6215.06 Nuiq_2::Nuiq_3_D5 18557.00 84.45 140.12 6279.03 6222.83 Nuiq_3::Nuiq_4_05 18715.00 86.58 140.22 6291.15 6234.95 Nuiq_4::Nuiq_5_D5 18861.00 87.03 141.20 6298.87 6242.67 Nuiq_5::Transition Zone 19511.00 86.39 140.03 6346.96 6290.76 Nuiq_5::Nuiq_Base_D5 19775.00 85.00 140.20 6365.91 6309.71 T15-TD 19947.00 84.88 140.35 6382.31 6326.11 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-17 Permit to Drill: 210-093 API: 50-703-20622-00-00 Sperry Drilling Definitive Survey Report 20 October, 2010 inommomi HALLIBURTON Sperry Drilling Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.00 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +EI-W 0.00 ft Easting: 469,826.11 ft Longitude: 150°14'48.230 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-17 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 PN13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +EJ-W 'Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 206.29 Survey Program Date 10/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,105.00 ODSN-17 Gyro(ODSN-17) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 8/26/2010 1: 1,154.91 4,612.64 ODSN-17 MWD 1 (ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8/27/2010 1: 4,710.05 10,949.10 ODSN-17 MWD 2(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:1IFR dec&3-axis correction+sag 9/7/2010 12: 11,042.53 14,070.86 ODSN-17 MWD 3(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/21/2010 1: 14,156.32 19,909.97 ODSN-17 MWD 4(ODSN-17) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/4/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,056.25 469,826.11 0.00 0.00 UNDEFINED 100.00 0.35 5.53 100.00 43.80 0.18 0.02 6,031,056.43 469,826.13 0.61 -0.16 SR-Gyro-SS(1) 172.00 0.78 357.31 172.00 115.80 0.88 0.01 6,031,057.13 469,826.13 0.61 -0.80 SR-Gyro-SS(1) 218.00 0.77 11.51 217.99 161.79 1.50 0.06 6,031,057.75 469,826.18 0.42 -1.37 SR-Gyro-SS(1) 264.00 0.67 32.05 263.99 207.79 2.03 0.27 6,031,058.28 469,826.38 0.60 -1.94 SR-Gyro-SS(1) 310.00 0.51 59.03 309.99 253.79 2.36 0.58 6,031,058.61 469,826.70 0.69 -2.38 SR-Gyro-SS(1) 356.00 1.45 98.70 355.98 299.78 2.38 1.33 6,031,058.63 469,827.45 2.41 -2.73 SR-Gyro-SS(1) 399.00 1.30 100.16 398.97 342.77 2.21 2.35 6,031,058.45 469,828.47 0.36 -3.03 SR-Gyro-SS(1) 445.00 1.49 102.67 444.95 388.75 1.99 3.45 6,031,058.23 469,829.57 0.43 -3.31 SR-Gyro-SS(1) 493.00 1.12 103.85 492.94 436.74 1.74 4.51 6,031,057.97 469,830.63 0.77 -3.56 SR-Gyro-SS(1) 1020/201010:42:51AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 539.00 0.59 88.47 538.94 482.74 1.64 5.19 6,031,057.87 469,831.30 1.25 -3.77 SR-Gyro-SS(1) 585.00 0.57 339.47 584.93 528.73 1.86 5.34 6,031,058.09 469,831.46 2.05 -4.03 SR-Gyro-SS(1) 631.00 2.15 303.65 630.92 574.72 2.55 4.54 6,031,058.78 469,830.66 3.74 -4.30 SR-Gyro-SS(1) 679.00 2.89 299.16 678.87 622.67 3.64 2.74 6,031,059.88 469,828.86 1.59 -4.48 SR-Gyro-SS(1) 725.00 4.49 297.38 724.78 668.58 5.03 0.13 6,031,061.28 469,826.26 3.49 -4.57 SR-Gyro-SS(1) 775.00 5.09 297.86 774.60 718.40 6.97 -3.57 6,031,063.23 469,822.57 1.20 -4.67 SR-Gyro-SS(1) 821.00 6.25 296.89 820.38 764.18 9.06 -7.61 6,031,065.34 469,818.54 2.53 -4.75 SR-Gyro-SS(1) 870.00 6.52 296.43 869.07 812.87 11.50 -12.48 6,031,067.80 469,813.68 0.56 -4.78 SR-Gyro-SS(1) 916.00 6.47 297.18 914.78 858.58 13.85 -17.12 6,031,070.17 469,809.04 0.21 -4.83 SR-Gyro-SS(1) 964.00 6.72 300.83 962.46 906.26 16.52 -21.94 6,031,072.86 469,804.24 1.02 -5.09 SR-Gyro-SS(1) 1,010.00 7.59 303.62 1,008.10 951.90 19.58 -26.78 6,031,075.94 469,799.41 2.04 -5.69 SR-Gyro-SS(1) 1,059.00 8.84 304.73 1,056.60 1,000.40 23.52 -32.57 6,031,079.90 469,793.64 2.57 -6.66 SR-Gyro-SS(1) 1,105.00 10.33 306.26 1,101.95 1,045.75 27.97 -38.80 6,031,084.38 469,787.43 3.29 -7.89 SR-Gyro-SS(1) 1,154.91 10.97 306.14 1,151.00 1,094.80 33.42 -46.25 6,031,089.85 469,780.01 1.28 -9.48 MWD+IFR2+MS+sag(2) 1,249.75 12.79 310.01 1,243.81 1,187.61 45.49 -61.57 6,031,101.99 469,764.73 2.09 -13.51 MWD+IFR2+MS+sag(2) 1,345.36 14.25 306.47 1,336.77 1,280.57 59.29 -79.14 6,031,115.86 469,747.21 1.75 -18.10 MWD+IFR2+MS+sag(2) 1,441.50 16.46 305.59 1,429.47 1,373.27 74.25 -99.74 6,031,130.90 469,726.68 2.31 -22.39 MWD+IFR2+MS+sag(2) 1,535.55 17.50 301.22 1,519.42 1,463.22 89.34 -122.67 6,031,146.08 469,703.82 1.75 -25.76 MWD+IFR2+MS+sag(2) 1,630.45 18.59 302.17 1,609.66 1,553.46 104.79 -147.68 6,031,161.63 469,678.88 1.19 -28.53 MWD+IFR2+MS+sag(2) 1,696.70 18.80 298.73 1,672.41 1,616.21 115.54 -165.98 6,031,172.46 469,660.62 1.69 -30.07 MWD+IFR2+MS+sag(2) 1,757.05 18.77 298.18 1,729.55 1,673.35 124.80 -183.06 6,031,181.78 469,643.57 0.30 -30.80 MWD+IFR2+MS+sag(2) 1,852.52 20.92 295.54 1,819.34 1,763.14 139.41 -211.98 6,031,196.50 469,614.71 2.44 -31.09 MWD+IFR2+MS+sag(2) 1,947.56 25.06 292.03 1,906.82 1,850.62 154.28 -245.97 6,031,211.51 469,580.79 4.59 -29.37 MWD+IFR2+MS+sag(2) 2,042.11 27.21 292.05 1,991.70 1,935.50 169.91 -284.57 6,031,227.29 469,542.26 2.27 -26.28 MWD+IFR2+MS+sag(2) 2,137.05 30.84 291.63 2,074.70 2,018.50 187.03 -327.32 6,031,244.59 469,499.58 3.83 -22.69 MWD+IFR2+MS+sag(2) 2,232.35 31.42 292.38 2,156.28 2,100.08 205.50 -373.00 6,031,263.24 469,453.98 0.73 -19.01 MWD+IFR2+MS+sag(2) 2,327.45 35.63 292.98 2,235.54 2,179.34 225.76 -421.45 6,031,283.69 469,405.63 4.44 -15.72 MWD+IFR2+MS+sag(2) 2,422.51 38.40 290.54 2,311.44 2,255.24 246.93 -474.60 6,031,305.08 469,352.57 3.30 -11.16 MWD+IFR2+MS+sag(2) 2,517.34 42.48 288.71 2,383.60 2,327.40 267.55 -532.53 6,031,325.93 469,294.72 4.48 -3.98 MWD+IFR2+MS+sag(2) 2,613.42 46.37 284.64 2,452.22 2,396.02 286.75 -596.94 6,031,345.39 469,230.40 5.02 7.33 MWD+IFR2+MS+sag(2) 2,708.38 48.97 279.31 2,516.18 2,459.98 301.24 -665,58 6,031,360.16 469,161.83 4.97 24.74 MWD+IFR2+MS+sag(2) 2,803.28 51.29 273.38 2,577.05 2,520.85 309.22 -737.91 6,031,368.43 469,089.54 5.38 49.63 MWD+IFR2+MS+sag(2) 2,899.43 54.08 268.08 2,635.35 2,579.15 310.13 -814.32 6,031,369.65 469,013.14 5.26 82.66 MWD+IFR2+MS+sag(2) 2,994.43 56.77 265.45 2,689.27 2,633.07 305.69 -892.40 6,031,365.52 468,935.05 3.63 121.23 MWD+IFR2+MS+sag(2) 3,090.16 59.62 263.56 2,739.72 2,683.52 297.88 -973.36 6,031,358.04 468,854.06 3.42 164.10 MWD+IFR2+MS+sag(2) 3,185.33 63.02 262.45 2,785.39 2,729.19 287.70 -1,056.22 6,031,348.20 468,771.17 3.72 209.92 MWD+IFR2+MS+sag(2) a 3,279.10 65.81 261.16 2,825.88 2,769.68 275.63 -1,139.92 6,031,336.48 468,687.44 3.22 257.82 MWD+IFR2+MS+sag(2) 3,374.77 70.37 260.38 2,861.57 2,805.37 261.39 -1,227.50 6,031,322.59 468,599.80 4.83 309.38 MWD+IFR2+MS+sag(2) 3,469.87 72.08 259.20 2,892.18 2,835.98 245.42 -1,316.11 6,031,306.99 468,511.14 2.15 362.94 MWD+IFR2+MS+sag(2) 3,565.72 70.73 257.02 2,922.74 2,866.54 226.72 -1,405.00 6,031,288.64 468,422.18 2.57 419.09 MWD+IFR2+MS+sag(2) 10/20/2010 10:42:51AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL©56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL©56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey -- --- - --- Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El-W Northing Easting DLS Section • (ft) (?) (?) (ft) (ft) (R) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 3,661.41 70.08 255.90 2,954.84 2,898.64 205.61 -1,492.64 6,031,267.90 468,334.47 1.30 476.83 MWD+IFR2+MS+sag(2) 3,756.32 70.91 255.84 2,986.52 2,930.32 183.77 -1,579.40 6,031,246.41 468,247.63 0.88 534.84 MWD+IFR2+MS+sag(2) 3,851.14 71.00 256.41 3,017.47 2,961.27 162.28 -1,666.41 6,031,225.27 468,160.54 0.58 592.65 MWD+IFR2+MS+sag(2) 3,945.82 70.58 256.69 3,048.62 2,992.42 141.48 -1,753.37 6,031,204.83 468,073.51 0.52 649.82 MWD+IFR2+MS+sag(2) 4,041.02 71.21 257.51 3,079.78 3,023.58 121.40 -1,841.05 6,031,185.11 467,985.75 1.05 706.66 MWD+IFR2+MS+sag(2) 4,136.12 71.00 258.58 3,110.57 3,054.37 102.76 -1,929.07 6,031,166.83 467,897.66 1.09 762.36 MWD+IFR2+MS+sag(2) 4,231.28 70.01 259.27 3,142.33 3,086.13 85.53 -2,017.11 6,031,149.96 467,809.57 1.24 816.80 MWD+IFR2+MS+sag(2) 4,326.25 70.46 258.64 3,174.45 3,118.25 68.41 -2,104.83 6,031,133.19 467,721.79 0.78 871.01 MWD+IFR2+MS+sag(2) 4,421.27 70.63 258.51 3,206.10 3,149.90 50.66 -2,192.64 6,031,115.80 467,633.91 0.22 925.82 MWD+IFR2+MS+sag(2) 4,516.95 70.67 258.35 3,237.80 3,181.60 32.55 -2,281.09 6,031,098.06 467,545.41 0.16 981.23 MWD+IFR2+MS+sag(2) 4,612.64 70.46 259.48 3,269.64 3,213.44 15.20 -2,369.64 6,031,081.07 467,456.79 1.14 1,036.01 MWD+IFR2+MS+sag(2) 4,710.05 71.86 259.82 3,301.09 3,244.89 -1.36 -2,460.33 6,031,064.88 467,366.05 1.47 1,091.03 MWD+IFR2+MS+sag(3) 4,803.06 71.54 259.66 3,330.30 3,274.10 -17.09 -2,547.22 6,031,049.50 467,279.10 0.38 1,143.62 MWD+IFR2+MS+sag(3) 4,898.59 71.16 259.30 3,360.85 3,304.65 -33.61 -2,636.21 6,031,033.34 467,190.05 0.53 1,197.85 MWD+IFR2+MS+sag(3) 4,994.01 70.97 259.96 3,391.81 3,335.61 -49.86 -2,724.99. 6,031,017.46 467,101.21 0.68 1,251.75 MWD+IFR2+MS+sag(3) 5,088.97 70.57 259.98 3,423.09 3,366.89 -65.47 -2,813.29 6,031,002.20 467,012.87 0.42 1,304.86 MWD+IFR2+MS+sag(3) 5,186.08 70.17 260.76 3,455.71 3,399.51 -80.78 -2,903.46 6,030,987.27 466,922.64 0.86 1,358.52 MWD+IFR2+MS+sag(3) 5,278.62 70.69 260.22 3,486.71 3,430.51 -95.18 -2,989.46 6,030,973.21 466,836.59 0.79 1,409.53 MWD+IFR2+MS+sag(3) 5,376.29 71.16 259.12 3,518.63 3,462.43 -111.74 -3,080.26 6,030,957.03 466,745.73 1.17 1,464.59 MWD+IFR2+MS+sag(3) 5,469.55 70.84 256.79 3,548.99 3,492.79 -130.13 -3,166.50 6,030,938.98 466,659.43 2.39 1,519.28 MWD+IFR2+MS+sag(3) 5,564.83 70.64 255.55 3,580.42 3,524.22 -151.63 -3,253.83 6,030,917.84 466,572.02 1.25 1,577.24 MWD+IFR2+MS+sag(3) 5,659.60 70.97 254.92 3,611.58 3,555.38 -174.44 -3,340.38 6,030,895.38 466,485.39 0.72 1,636.03 MWD+IFR2+MS+sag(3) 5,754.46 70.75 254.41 3,642.69 3,586.49 -198.14 -3,426.80 6,030,872.04 466,398.88 0.56 1,695.56 MWD+IFR2+MS+sag(3) 5,848.47 70.70 254.77 3,673.72 3,617.52 -221.72 -3,512.35 6,030,848.81 466,313.24 0.37 1,754.60 MWD+IFR2+MS+sag(3) 5,943.87 70.12 255.24 3,705.71 3,649.51 -244.98 -3,599.17 6,030,825.91 466,226.34 0.76 1,813.90 MWD+IFR2+MS+sag(3) 6,040.89 70.30 255.87 3,738.55 3,682.35 -267.75 -3,687.57 6,030,803.50 466,137.85 0.64 1,873.47 MWD+IFR2+MS+sag(3) 6,135.45 70.37 257.19 3,770.38 3,714.18 -288.49 -3,774.17 6,030,783.11 466,051.18 1.32 1,930.43 M1ND+IFR2+MS+sag(3) 6,231.22 70.89 258.90 3,802.14 3,745.94 -307.20 -3,862.55 6,030,764.76 465,962.73 1.77 1,986.35 MWD+IFR2+MS+sag(3) 6,325.15 71.08 260.28 3,832.75 3,776.55 -323.25 -3,949.89 6,030,749.07 465,875.34 1.40 2,039.43 MWD+IFR2+MS+sag(3) 6,421.02 70.77 260.20 3,864.08 3,807.88 -338.61 -4,039.19 6,030,734.07 465,785.99 0.33 2,092.75 MWD+IFR2+MS+sag(3) 6,516.19 70.75 260.29 3,895.44 3,839.24 -353.83 -4,127.74 6,030,719.21 465,697.38 0.09 2,145.63 MWD+IFR2+MS+sag(3) 6,613.33 70.35 260.71 3,927.79 3,871.59 -368.95 -4,218.08 6,030,704.46 465,606.99 0.58 2,199.20 MWD+IFR2+MS+sag(3) 6,706.26 70.37 261.96 3,959.02 3,902.82 -382.14 -4,304.60 6,030,691.63 465,520.42 1.27 2,249.34 MWD+IFR2+MS+sag(3) 6,800.98 70.63 260.84 3,990.64 3,934.44 -395.49 -4,392.89 6,030,678.63 465,432.10 1.15 2,300.42 MWD+IFR2+MS+sag(3) 6,896.38 70.76 261.31 4,022.18 3,965.98 -409.46 -4,481.83 6,030,665.03 465,343.11 0.48 2,352.34 MWD+IFR2+MS+sag(3) 6,992.18 70.91 260.31 4,053.63 3,997.43 -423.91 -4,571.16 6,030,650.94 465,253.73 1.00 2,404.86 MWD+IFR2+MS+sag(3) 7,088.03 71.15 259.90 4,084.79 4,028.59 -439.49 -4,660.45 6,030,635.73 465,164.38 0.48 2,458.38 MWD+IFR2+MS+sag(3) 7,182.18 71.35 259.30 4,115.05 4,058.85 -455.58 -4,748.14 6,030,619.99 465,076.64 0.64 2,511.65 M1ND+IFR2+MS+sag(3) 7,277.41 71.34 257.39 4,145.52 4,089.32 -473.81 -4,836.50 6,030,602.13 464,988.21 1.90 2,567.14 MWD+IFR2+MS+sag(3) 7,372.56 70.96 257.20 4,176.26 4,120.06 -493.61 -4,924.35 6,030,582.68 464,900.30 0.44 2,623.80 MWD+IFR2+MS+sag(3) 1020201010:42 51AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL©56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL©56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100•) (ft) Survey Tool Name 7,468.27 70.82 257.82 4,207.59 4,151.39 -513.17 -5,012.64 6,030,563.48 464,811.93 0.63 2,680.45 MWD+IFR2+MS+sag(3) 7,563.47 70.03 257.84 4,239.49 4,183.29 -532.08 -5,100.32 6,030,544.93 464,724.19 0.83 2,736.24 MWD+IFR2+MS+sag(3) 7,658.61 70.36 258.45 4,271.72 4,215.52 -550.47 -5,187.92 6,030,526.90 464,636.52 0.70 2,791.53 MWD+IFR2+MS+sag(3) 7,754.46 70.37 258.66 4,303.93 4,247.73 -568.38 -5,276.41 6,030,509.35 464,547.97 0.21 2,846.78 MWD+IFR2+MS+sag(3) 7,848.82 70.25 259.03 4,335.72 4,279.52 -585.57 -5,363.57 6,030,492.52 464,460.75 0.39 2,900.80 MWD+IFR2+MS+sag(3) 7,945.27 70.68 259.62 4,367.98 4,311.78 -602.41 -5,452.89 6,030,476.04 464,371.37 0.73 2,955.46 MVVD+IFR2+MS+sag(3) 8,038.91 70.82 259.69 4,398.85 4,342.65 -618.28 -5,539.86 6,030,460.52 464,284.34 0.17 3,008.22 MWD+IFR2+MS+sag(3) 8,134.96 70.96 260.58 4,430.29 4,374.09 -633.83 -5,629.28 6,030,445.34 464,194.88 0.89 3,061.76 MWD+IFR2+MS+sag(3) 8,230.17 71.28 260.76 4,461.10 4,404.90 -648.43 -5,718.17 6,030,431.10 464,105.93 0.38 3,114.23 MWD+IFR2+MS+sag(3) 8,324.98 71.15 260.58 4,491.63 4,435.43 -662.99 -5,806.74 6,030,416.91 464,017.31 0.23 3,166.51 MWD+IFR2+MS+sag(3) 8,420.04 70.82 260.48 4,522.60 4,466.40 -677.77 -5,895.39 6,030,402.48 463,928.61 0.36 3,219.04 MWD+IFR2+MS+sag(3) 8,515.53 70.29 260.55 4,554.39 4,498.19 -692.61 -5,984.20 6,030,388.00 463,839.75 0.56 3,271.68 MWD+IFR2+MS+sag(3) 8,609.58 70.82 260.71 4,585.70 4,529.50 -707.05 -6,071.71 6,030,373.92 463,752.20 0.59 3,323.39 MWD+IFR2+MS+sag(3) 8,705.65 71.28 260.48 4,616.90 4,560.70 -721.90 -6,161.35 6,030,359.44 463,662.51 0.53 3,376.40 MWD+IFR2+MS+sag(3) 8,801.16 71.66 259.31 4,647.26 4,591.06 -737.79 -6,250.50 6,030,343.91 463,573.30 1.23 3,430.14 MWD+IFR2+MS+sag(3) 8,896.34 70.45 258.87 4,678.16 4,621.96 -754.82 -6,338.89 6,030,327.24 463,484.84 1.34 3,484.57 MWD+IFR2+MS+sag(3) 8,991.27 70.09 258.28 4,710.20 4,654.00 -772.52 -6,426.48 6,030,309.89 463,397.20 0.70 3,539.23 MWD+IFR2+MS+sag(3) 9,086.77 70.30 258.61 4,742.56 4,686.36 -790.52 -6,514.51 6,030,292.26 463,309.10 0.39 3,594.36 MWD+IFR2+MS+sag(3) 9,182.69 70.49 258.53 4,774.75 4,718.55 -808.43 -6,603.08 6,030,274.71 463,220.47 0.21 3,649.65 MWD+IFR2+MS+sag(3) 9,277.16 70.87 258.94 4,806.00 4,749.80 -825.84 -6,690.51 6,030,257.65 463,132.98 0.57 3,703.99 MWD+IFR2+MS+sag(3) 9,372.89 69.98 259.04 4,838.07 4,781.87 -843.07 -6,779.05 6,030,240.79 463,044.38 0.93 3,758.65 MWD+IFR2+MS+sag(3) 9,467.20 70.36 259.56 4,870.07 4,813.87 -859.54 -6,866.22 6,030,224.67 462,957.15 0.66 3,812.03 MWD+IFR2+MS+sag(3) 9,563.91 71.00 259.30 4,902.06 4,845.86 -876.28 -6,955.93 6,030,208.30 462,867.38 0.71 3,866.78 MWD+IFR2+MS+sag(3) 9,659.05 71.01 258.16 4,933.03 4,876.83 -893.86 -7,044.16 6,030,191.08 462,779.09 1.13 3,921.62 MWD+IFR2+MS+sag(3) 9,752.68 70.89 257.04 4,963.59 4,907.39 -912.87 -7,130.59 6,030,172.43 462,692.59 1.14 3,976.95 MWD+IFR2+MS+sag(3) 9,849.04 71.03 257.88 4,995.03 4,938.83 -932.64 -7,219.51 6,030,153.01 462,603.60 0.84 4,034.06 MWD+IFR2+MS+sag(3) 9,943.96 71.22 258.20 5,025.73 4,969.53 -951.25 -7,307.37 6,030,134.76 462,515.67 0.38 4,089.67 MWD+IFR2+MS+sag(3) 10,039.79 70.31 256.57 5,057.31 5,001.11 -971.01 -7,395.67 6,030,115.36 462,427.31 1.87 4,146.49 MWD+IFR2+MS+sag(3) 10,134.14 71.07 253.76 5,088.51 5,032.31 -993.81 -7,481.73 6,030,092.91 462,341.16 2.92 4,205.05 MWD+IFR2+MS+sag(3) 10,229.16 71.22 250.69 5,119.23 5,063.03 -1,021.26 -7,567.34 6,030,065.82 462,255.45 3.06 4,267.59 MWD+IFR2+MS+sag(3) 10,324.49 71.07 247.66 5,150.04 5,093.84 -1,053.33 -7,651.65 6,030,034.10 462,171.02 3.01 4,333.68 MWD+IFR2+MS+sag(3) 10,419.51 70.82 244.06 5,181.07 5,124.87 -1,090.05 -7,733.60 6,029,997.71 462,088.93 3.59 4,402.90 MWD+IFR2+MS+sag(3) 10,508.96 70.45 240.96 5,210.74 5,154.54 -1,128.99 -7,808.45 6,029,959.07 462,013.93 3.30 4,470.97 MWD+IFR2+MS+sag(3) 10,610.40 70.69 236.81 5,244.49 5,188.29 -1,178.42 -7,890.32 6,029,909.99 461,931.86 3.87 4,551.55 MWD+IFR2+MS+sag(3) 10,705.79 71.54 232.94 5,275.38 5,219.18 -1,230.34 -7,964.12 6,029,858.37 461,857.86 3.94 4,630.79 MWD+IFR2+MS+sag(3) 10,800.97 70.83 229.60 5,306.08 5,249.88 -1,286.69 -8,034.40 6,029,802.31 461,787.37 3.40 4,712.44 MWD+IFR2+MS+sag(3) y 10,895.62 70.57 224.59 5,337.39 5,281.19 -1,347.48 -8,099.81 8,029,741.79 461,721.72 5.00 4,795.92 M1ND+IFR2+MS+sag(3) 10,949.10 70.78 223.14 5,355.08 5,298.88 -1,383.87 -8,134.78 6,029,705.55 461,686.61 2.59 4,844.03 MWD+IFR2+MS+sag(3) 11,042.53 71.73 222.09 5,385.11 5,328.91 -1,448.98 -8,194.68 6,029,640.69 461,626.45 1.47 4,928.93 MWD+IFR2+MS+sag(4) 11,088.41 71.75 221.46 5,399.48 5,343.28 -1,481.47 -8,223.70 6,029,608.32 461,597.29 1.30 4,970.92 MWD+IFR2+MS+sag(4) 1020/201010:42:51AM Page 5 COMPASS 2003.16 Budd 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL(4)56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD WDSS +N/-S +EI-W Northing Easting DLS Section (�) (?) (?) (ft) (ft) (ft) (ft) (n) (ft) morn (ft) Survey Tool Name 11,183.91 70.74 219.27 5,430.19 5,373.99 -1,550.36 -8,282.27 6,029,539.67 461,538.45 2.42 5,058.63 MWD+IFR2+MS+sag(4) 11,279.14 71.02 215.72 5,461.39 5,405.19 -1,621.74 -8,337.02 6,029,468.53 461,483.41 3.53 5,146.87 MWD+IFR2+MS+sag(4) 11,373.84 71.41 212.82 5,491.89 5,435.69 -1,695.82 -8,387.50 6,029,394.66 461,432.64 2.93 5,235.65 MWD+IFR2+MS+sag(4) 11,469.31 71.08 209.09 5,522.60 5,466.40 -1,773.33 -8,433.99 6,029,317.35 461,385.84 3.72 5,325.73 MWD+IFR2+MS+sag(4) 11,565.32 70.57 205.46 5,554.14 5,497.94 -1,853.91 -8,475.54 6,029,236.94 461,343.97 3.61 5,416.38 MWD+IFR2+MS+sag(4) 11,660.83 72.20 201.49 5,584.64 5,528.44 -1,936.91 -8,511.57 6,029,154.10 461,307.60 4.29 5,506.76 MWD+IFR2+MS+sag(4) 11,755.15 72.84 198.69 5,612.98 5,556.78 -2,021.39 -8,542.47 6,029,069.75 461,276.37 2.91 5,596.19 MWD+IFR2+MS+sag(4) 11,850.51 73.61 195.85 5,640.51 5,584.31 -2,108.57 -8,569.57 6,028,982.69 461,248.92 2.96 5,686.35 MWD+IFR2+MS+sag(4) 11,946.56 73.95 192.22 5,667.34 5,611.14 -2,198.03 -8,591.93 6,028,893.34 461,226.20 3.65 5,776.45 MWD+IFR2+MS+sag(4) 12,042.13 73.74 188.24 5,693.94 5,637.74 -2,288.34 -8,608.23 6,028,803.10 461,209.53 4.01 5,864.65 MWD+IFR2+MS+sag(4) 12,136.56 73.79 184.72 5,720.35 5,664.15 -2,378.41 -8,618.46 6,028,713.08 461,198.94 3.58 5,949.93 MWD+IFR2+MS+sag(4) 12,231.94 74.12 183.17 5,746.72 5,690.52 -2,469.86 -8,624.76 6,028,621.67 461,192.26 1.60 6,034.71 MWD+IFR2+MS+sag(4) 12,326.15 73.47 181.03 5,773.01 5,716.81 -2,560.26 -8,628.08 6,028,531.29 461,188.58 2.29 6,117.22 MWD+IFR2+MS+sag(4) 12,421.45 73.28 179.34 5,800.28 5,744.08 -2,651.57 -8,628.38 6,028,439.99 461,187.91 1.71 6,199.22 MWD+IFR2+MS+sag 14) 12,516.10 74.76 177.01 5,826.34 5,770.14 -2,742.50 -8,625.47• 6,028,349.05 461,190.45 2.84 6,279.46 MWD+IFR2+MS+sag(4) 12,612.64 75.21 175.12 5,851.35 5,795.15 -2,835.52 -8,619.07 6,028,256.02 461,196.47 1.95 6,360.02 MWD+IFR2+MS+sag(4) 12,707.53 74.31 172.56 5,876.30 5,820.10 -2,926.54 -8,609.25 6,028,164.97 461,205.92 2.77 6,437.27 MWD+IFR2+MS+sag(4) 12,797.87 74.71 170.43 5,900.43 5,844.23 -3,012.63 -8,596.38 6,028,078.84 461,218.44 2.31 6,508.76 MWD+IFR2+MS+sag(4) 12,897.12 74.83 166.63 5,926.51 5,870.31 -3,106.47 -8,577.34 6,027,984.94 461,237.10 3.70 6,584.45 MWD+IFR2+MS+sag(4) 12,993.65 75.07 163.20 5,951.58 5,895.38 -3,196.46 -8,553.08 6,027,894.86 461,260.99 3.44 6,654.38 MWD+IFR2+MS+sag(4) 13,090.13 76.50 158.81 5,975.28 5,919.08 -3,284.86 -8,522.64 6,027,806.34 461,291.07 4.65 6,720.15 MWD+IFR2+MS+sag(4) 13,183.84 76.56 155.90 5,997.12 5,940.92 -3,368.96 -8,487.55 6,027,722.11 461,325.81 3.02 6,780.01 MWD+IFR2+MS+sag(4) 13,278.88 76.22 153.10 6,019.48 5,963.28 -3,452.32 -8,447.79 6,027,638.59 461,365.23 2.89 6,837.14 MWD+IFR2+MS+sag(4) 13,373.87 76.86 151.23 6,041.60 5,985.40 -3,534.01 -8,404.66 6,027,556.74 461,408.03 2.03 6,891.27 MWD+IFR2+MS+sag(4) 13,468.91 77.43 149.40 6,062.74 6,006.54 -3,614.50 -8,358.77 6,027,476.07 461,453.58 1.97 6,943.11 MWD+IFR2+MS+sag(4) 13,564.20 77.50 146.25 6,083.43 6,027.23 -3,693.22 -8,309.24 6,027,397.16 461,502.78 3.23 6,991.75 MWD+IFR2+MS+sag(4) 13,658.27 78.51 143.53 6,102.98 6,046.78 -3,768.48 -8,256.32 6,027,321.69 461,555.39 3.03 7,035.78 MWD+IFR2+MS+sag(4) 13,753.68 78.76 142.94 6,121.78 6,065.58 -3,843.42 -8,200.34 6,027,246.54 461,611.07 0.66 7,078.16 MWD+IFR2+MS+sag(4) 13,848.63 79.02 142.71 6,140.08 6,083.88 -3,917.66 -8,144.04 6,027,172.08 461,667.06 0.36 7,119.78 MWD+IFR2+MS+sag(4) 13,944.20 79.65 142.01 6,157.77 6,101.57 -3,992.03 -8,086.68 6,027,097.48 461,724.11 0.98 7,161.05 MWD+IFR2+MS+sag(4) 14,038.97 80.15 139.71 6,174.39 6,118.19 -4,064.38 -8,027.79 8,027,024.89 461,782.70 2.45 7,199.84 MWD+IFR2+MS+sag(4) 14,070.86 80.28 139.78 6,179.81 6,123.61 -4,088.37 -8,007.49 6,027,000.83 461,802.91 0.46 7,212.35 MWD+IFR2+MS+sag(4) 14,156.32 80.88 139.42 6,193.80 6,137.60 -4,152.57 -7,952.84 6,026,936.41 461,857.28 0.82 7,245.71 MWD+IFR2+MS+sag(5) 14,220.44 83.40 139.25 6,202.56 6,146.36 -4,200.75 -7,911.46 6,026,888.07 461,898.47 3.94 7,270.56 MWD+IFR2+MS+sag(5) 14,316.88 84.70 140.27 6,212.56 6,156.36 -4,273.97 -7,849.50 6,026,814.61 461,960.12 1.71 7,308.76 MWD+IFR2+MS+sag(5) 14,412.73 87.05 142.03 6,219.45 6,163.25 -4,348.41 -7,789.53 6,026,739.93 462,019.78 3.06 7,348.95 MWD+IFR2+MS+sag(5) 14,509.50 86.93 140.06 6,224.54 6,168.34 -4,423.56 -7,728.78 6,026,664.55 462,080.22 2.04 7,389.41 MWD+IFR2+MS+sag(5) 14,606.43 85.63 137.62 6,230.83 6,174.63 -4,496.37 -7,665.13 6,026,591.48 462,143.57 2.85 7,426.49 MWD+IFR2+MS+sag(5) 14,702.36 87.24 137.26 6,236.79 6,180.59 -4,566.89 -7,600.37 6,026,520.70 462,208.03 1.72 7,461.03 MWD+IFR2+MS+sag(5) 14,798.69 85.32 136.73 6,243.04 6,186.84 -4,637.19 -7,534.81 6,026,450.15 462,273.30 2.07 7,495.02 MWD+IFR2+MS+sag(5) 10/20/201010:42.51AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska 1 Survey Map Map Vertical MD Inc Azi TVD WDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (e/100') (ft) Survey Tool Name 14,896.15 84.88 135.41 6,251.37 6,195.17 -4,707.12 -7,467.44 6,026,379.95 462,340.38 1.42 7,527.87 MWD+IFR2+MS+sag(5) 14,991.10 86.55 135.91 6,258.46 6,202.26 -4,774.83 -7,401.27 6,026,311.98 462,406.27 1.84 7,559.27 MWD+IFR2+MS+sag(5) 15,087.91 87.61 137.74 6,263.39 6,207.19 -4,845.34 -7,335.12 6,026,241.21 462,472.12 2.18 7,593.18 MWD+IFR2+MS+sag(5) 15,184.57 89.15 139.52 6,266.13 6,209.93 -4,917.85 -7,271.27 6,026,168.45 462,535.68 2.43 7,629.90 MWD+IFR2+MS+sag(5) 15,281.17 92.06 140.87 6,265.11 6,208.91 -4,992.04 -7,209.44 6,026,094.01 462,597 20 3.32 7,669.03 MWD+IFR2+MS+sag(5) 15,377.70 94.53 140.96 6,259.56 6,203.36 -5,066.84 -7,148.68 6,026,018.98 462,657.64 2.56 7,709.18 MWD+IFR2+MS+sag(5) 15,473.31 93.97 140.24 6,252.47 6,196.27 -5,140.52 -7,088.16 6,025,945.06 462,717.86 0.95 7,748.43 MWD+IFR2+MS+sag(5) 15,570.08 94.66 139.13 6,245.19 6,188.99 -5,214.09 -7,025.73 6,025,871.24 462,779.98 1.35 7,786.74 MWD+IFR2+MS+sag(5) 15,666.72 93.79 138.14 6,238.07 6,181.87 -5,286.42 -6,962.04 6,025,798.66 462,843.37 1.36 7,823.38 MWD+IFR2+MS+sag(5) 15,699.11 94.29 137.47 6,235.79 6,179.59 -5,310.36 -6,940.34 6,025,774.64 462,864.97 2.58 7,835.23 MWD+IFR2+MS+sag(5) 15,763.33 93.98 138.70 6,231.16 6,174.96 -5,358.02 -6,897.55 6,025,726.81 462,907.56 1.97 7,859.00 MWD+IFR2+MS+sag(5) 15,859.45 89.77 141.35 6,228.01 6,171.81 -5,431.62 -6,835.86 6,025,652.97 462,968.95 5.17 7,897.66 MWD+IFR2+MS+sag(5) 15,956.26 85.75 143.74 6,231.80 6,175.60 -5,508.39 -6,777.04 6,025,575.97 463,027.45 4.83 7,940.43 MWD+IFR2+MS+sag(5) 16,052.38 85.50 144.46 6,239.13 6,182.93 -5,586.03 -6,720.84 6,025,498.11 463,083.33 0.79 7,985.14 MWD+IFR2+MS+sag(5) 16,075.59 85.25 144.49 6,241.00 6,184.80 -5,604.85 -6,707.40- 6,025,479.23 463,096.69 1.08 7,996.07 MWD+IFR2+MS+sag(5) 16,148.61 84.63 142.57 6,247.44 6,191.24 -5,663.34 -6,664.17 6,025,420.57 463,139.68 2.75 8,029.36 MWD+IFR2+MS+sag(5) 16,245.48 83.83 137.34 6,257.19 6,200.99 -5,737.10 -6,602.19 6,025,346.57 463,201.36 5.43 8,068.03 MWD+IFR2+MS+sag(5) 16,342.73 84.45 139.16 6,267.12 6,210.92 -5,809.27 -6,537.77 6,025,274.15 463,265.47 1.97 8,104.20 MWD+IFR2+MS+sag(5) 16,438.75 85.94 140.04 6,275.16 6,218.96 -5,882.14 -6,475.76 6,025,201.04 463,327.18 1.80 8,142.06 MWD+IFR2+MS+sag(5) 16,501.93 85.94 139.86 6,279.63 6,223.43 -5,930.38 -6,435.21 6,025,152.64 463,367.53 0.28 8,167.35 MWD+IFR2+MS+sag(5) 16,631.38 85.69 140.63 6,289.08 6,232.88 -6,029.63 -6,352.65 6,025,053.06 463,449.68 0.62 8,219.76 MWD+IFR2+MS+sag(5) 16,728.55 86.87 140.73 6,295.38 6,239.18 -6,104.64 -6,291.20 6,024,977.81 463,510.81 1.22 8,259.80 MWD+IFR2+MS+sag(5) 16,824.70 90.02 141.69 6,297.99 6,241.79 -6,179.55 -6,231.00 6,024,902.67 463,570.71 3.42 8,300.29 MWD+IFR2+MS+sag(5) 16,920.33 85.50 138.95 6,301.73 6,245.53 -6,253.07 -6,170.01 6,024,828.91 463,631.39 5.53 8,339.18 MWD+IFR2+MS+sag(5) 16,974.67 84.45 138.27 6,306.49 6,250.29 -6,293.68 -6,134.22 6,024,788.16 463,667.01 2.30 8,359.74 MWD+IFR2+MS+sag(5) 17,017.02 86.06 139.09 6,309.99 6,253.79 -6,325.37 -6,106.36 6,024,756.35 463,694.75 4.26 8,375.81 MWD+IFR2+MS+sag(5) 17,113.13 90.70 141.48 6,312.71 6,256.51 -6,399.25 -6,044.99 6,024,682.23 463,755.80 5.43 8,414.87 MWD+IFR2+MS+sag(5) 17,209.90 94.16 143.00 6,308.61 6,252.41 -6,475.67 -5,985.80 6,024,605.58 463,814.68 3.90 8,457.16 MWD+IFR2+MS+sag(5) 17,306.33 94.65 142.70 6,301.20 6,245.00 -6,552.31 -5,927.74 6,024,528.72 463,872.43 0.60 8,500.15 MWD+IFR2+MS+sag(5) 17,402.91 92.86 140.54 6,294.88 6,238.68 -6,627.84 -5,867.91 6,024,452.95 463,931.94 2.90 8,541.37 MWD+IFR2+MS+sag(5) 17,498.38 94.66 139.65 6,288.62 6,232.42 -6,700.92 -5,806.80 6,024,379.63 463,992.75 2.10 8,579.81 MWD+IFR2+MS+sag(5) 17,595.38 95.03 139.38 6,280.42 6,224.22 -6,774.43 -5,744.04 6,024,305.87 464,055.20 0.47 8,617.93 MWD+IFR2+MS+sag(5) 17,692.24 94.47 139.73 6,272.40 6,216.20 -6,847.89 -5,681.43 6,024,232.17 464,117.51 0.68 8,656.05 MWD+IFR2+MS+sag(5) 17,788.24 94.97 139.37 6,264.50 6,208.30 -6,920.70 -5,619.35 6,024,159.12 464,179.28 0.64 8,693.83 MWD+IFR2+MS+sag(5) 17,885.08 92.55 139.76 6,258.15 6,201.95 -6,994.24 -5,556.69 6,024,085.33 464,241.64 2.53 8,732.00 MWD+IFR2+MS+sag(5) 17,981.42 94.35 140.48 6,252.36 6,196.16 -7,068.03 -5,495.03 6,024,011.29 464,302.99 2.01 8,770.85 MWD+IFR2+MS+sag(5) 18,077.59 90.39 141.35 6,248.38 6,192.18 -7,142.60 -5,434.46 6,023,936.48 464,363.25 4.22 8,810.88 MWD+IFR2+MS+sag(5) 18,174.18 87.48 139.82 6,250.17 6,193.97 -7,217.20 -5,373.15 6,023,861.64 464,424.25 3.40 8,850.60 MWD+IFR2+MS+sag(5) 18,270.78 85.50 140.62 6,256.09 6,199.89 -7,291.30 -5,311.46 6,023,787.31 464,485.63 2.21 8,889.70 MWD+IFR2+MS+sag(5) 18,367.21 86.50 141.34 6,262.81 6,206.61 -7,366.03 -5,250.90 6,023,712.33 464,545.89 1.28 8,929.88 MWD+IFR2+MS+sag(5) 10/20/`2010 10.42:51AM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Project: Oooguruk Development ND Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 Survey Calculation Method: Minimum Curvature Design: ODSN-17 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,464.21 84.70 140.60 6,270.26 6,214.06 -7,441.16 -5,190.00 6,023,636.97 464,606.47 2.01 8,970.26 MWD+IFR2+MS+sag(5) 18,560.44 84.44 140.10 6,279.36 6,223.16 -7,514.92 -5,128.87 6,023,562.97 464,667.30 0.58 9,009.31 MWD+IFR2+MS+sag(5) 18,656.42 86.00 139.88 6,287.36 6,231.16 -7,588.17 -5,067.38 6,023,489.47 464,728.48 1.64 9,047.75 MWD+IFR2+MS+sag(5) 18,749.65 86.93 140.42 6,293.11 6,236.91 -7,659.61 -5,007.76 6,023,417.80 464,787.81 1.15 9,085.39 MWD+IFR2+MS+sag(5) 18,814.45 86.86 139.98 6,296.62 6,240.42 -7,709.32 -4,966.34 6,023,367.93 464,829.02 0.69 9,111.61 MWD+IFR2+MS+sag(5) 18,848.29 87.55 141.37 6,298.27 6,242.07 -7,735.47 -4,944.92 6,023,341.70 464,850.33 4.58 9,125.56 MWD+IFR2+MS+sag(5) 18,881.71 86.18 140.92 6,300.10 6,243.90 -7,761.46 -4,923.99 6,023,315.63 464,871.16 4.31 9,139.59 MWD+IFR2+MS+sag(5) 18,945.12 87.92 141.91 6,303.36 6,247.16 -7,810.95 -4,884.49 6,023,265.97 464,910.45 3.16 9,166.47 MWD+IFR2+MS+sag(5) 19,036.17 86.18 138.15 6,308.05 6,251.85 -7,880.63 -4,826.10 6,023,196.07 464,968.56 4.55 9,203.07 MWD+IFR2+MS+sag(5) 19,137.27 85.38 137.60 6,315.49 6,259.29 -7,955.41 -4,758.47 6,023,121.03 465,035.87 0.96 9,240.16 MWD+IFR2+MS+sag(5) 19,235.40 85.00 137.83 6,323.72 6,267.52 -8,027.75 -4,692.68 6,023,048.43 465,101.36 0.45 9,275.87 MWD+IFR2+MS+sag(5) 19,331.91 84.51 138.86 6,332.54 6,276.34 -8,099.55 -4,628.80 6,022,976.37 465,164.94 1.18 9,311.95 MWD+IFR2+MS+sag(5) 19,428.22 85.38 140.12 6,341.02 6,284.82 -8,172.49 -4,566.49 6,022,903.19 465,226.95 1.59 9,349.74 MWD+IFR2+MS+sag(5) 19,524.49 86.56 140.02 6,347.79 6,291.59 -8,246.13 -4,504.85 6,022,829.31 465,288.28 1.23 9,388.46 MWD+IFR2+MS+sag(5) 19,621.33 85.19 138.35 6,354.76 6,298.56 -8,319.23 -4,441.72- 6,022,755.96 465,351.11 2.23 9,426.03 MWD+IFR2+MS+sag(5) 19,717.32 86.56 140.15 6,361.66 6,305.46 -8,391.75 -4,379.23 6,022,683.19 465,413.30 2.35 9,463.38 MWD+IFR2+MS+sag(5) 19,813.62 83.95 140.23 6,369.63 6,313.43 -8,465.47 -4,317.79 6,022,609.23 465,474.43 2.71 9,502.25 MWD+IFR2+MS+sag(5) 19,909.97 84.88 140.35 6,379.00 6,322.80 -8,539.24 -4,256.53 6,022,535.22 465,535.39 0.97 9,541.25 MWD+IFR2+MS+sag(5) 19,947.00 84.88 140.35 6,382.31 6,326.11 -8,567.63 -4,232.99 6,022,506.73 465,558.81 0.00 9,556.28 PROJECTED to TD 1020/201010:42:51AM Page 8 COMPASS 2003.16 Build 42F -IALLIBURTON Sperry Drilling Oooguruk ODSN-17 2000 3000 - i Loggers on location Sept.3rd,2010 O lil L... LLL 4000 - - NATURAL,RESOURCES Set 11.75"Casing at 4670'MD,3285'TVD Begin •drilling 10 5/8"with 11.75"Rhino — 5000 - -Reamer Intermediate Hole Sept 6th,2010 • — ~ 6000 _- 7000 8000 - 1* I jI —. 9000 - - - TD Intermediate Section Sept 12th,2010 mum Set 9 5/* Liner at 10978'MD,5364'ND =IIIIIIIII 10000 t i ) / Begin drilling 8.5"#2 Intermediate on Section on Sept 20th,2010 11000 —.. CI 12000 - _ .. L " Begin drilling initial 6 1/8" _ M Production Section Oct 1st,2010. U) 13000 - E Ir 1011.1 C� \ " C 14000 - minim 15000 f TD#2 Intermediate Section,Sept 24th,2010 _."_ Set 7"casing at 14106'MD,6185'ND 16000 -- t -. t 17000 - - . I m 1 , _ ri 18000 - 19000 - 20000 - - R ... EPP TD initial Production Section Oct Run 4 1/2" 21000 7th,2010. 19948'MD,6388'TVD Liner _ _ 22000 , ;- -_I , --1 -Tr T I ' 1 I I - l , - 0 10 20 30 40 50 60 Rig Days HALLIBURTON Sperry Drilling Surface Data Logging After Action Review Employee Name: Mark Lindloff Date: 9/09/2010 Well: ODSN-17 Hole Section: Intermediate What went as, or better than, planned: No problems generating logs. All surface sensors gathered data and functioned as expected. Difficulties experienced: None Recommendations: Innovations and/or cost savings: None HALLIBURT®N I Sperry DriW nt:1 ODSN-17 API 50-703-20622-00-00 Digital Data EMF & PDF Logs ADI End of Well Report Halliburton Log Viewer EMF Viewer [-P I O'N E E R 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.
