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208-010
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: _Convert SPJP to Gas Lift ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 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 13,018 feet N/A feet true vertical 3,784 feet 8,000 feet Effective Depth measured 13,018 feet 6,985', 7,455'ft true vertical 3,784 feet 3,785', 3,851'ft Perforation depth Measured depth 7,622'-7,751'; 7,880'-8,352'; 8,522'-10,757'; 10,917'-12,947'feet True Vertical depth 3,864'-3,853'; 3,851'-3,840'; 3,833'-3,803'; 3,800'-3,783'feet Tubing (size, grade, measured and true vertical depth)4 1/2 L-80 7,265' 3,831' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 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: Stephanie Thomson Contact Name:Stephanie Thomson Authorized Title:Staff Petroleum Engineer Contact Email:stephanie.thomson@cop.com Contact Phone:907-263-4536 WINJ WAG 43 Water-Bbl MD N/A 110 3,640 ZXP Liner Top Packer, ZXP Liner Top Packer. No SSSV. 46 2107 Oil-Bbl measured true vertical Packer 6,985', 7,455'3,785', 3,851' 2375 1092 4. Well Class Before Work: 219 Representative Daily Average Production or Injection Data 301435 Casing Pressure Tubing Pressure ADL 25649, ADL 0025650 KRU 1C-172AL2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-010 50-029-23159-01-00 5. Permit to Drill Number:2. Operator Name N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 202 Gas-Mcf measuredPlugs Junk measured N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-287 263 Size 70 3,600 8,261 5,453 Kuparuk River Field / West Sak Oil Pool Conductor Surface Production Authorized Signature with date: Authorized Name: Liner Length N/A Casing Structural N/A 16 9 5/8 7 5/8 TVD N/A 110 2,501 3,939 3,785 N/A 4 1/2 8,310 13,011 Senior Engineer:Senior Res. Engineer: Collapse N/A Burst t Fra O 208 6. A G L PG , R ft Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am approving this document with my legally binding signature Location: your signing location here Date: 2020-08-05 11:51:47 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson By Samantha Carlisle at 9:50 am, Aug 06, 2020 RBDMS HEW 8/6/2020 61 HEW VTL 8/11/20 DSR-8/6/2020 SFD 8/10/2020 1C-172A Well Events Summary Date Event Summary 5/17/2020 1C-172A SI and Freeze Protected 7/20/2020 Displaced tubing with diesel. Pulled slip stop at 6,755’ RKB. Pulled jet pump with downhole gauges at 6,757’ RKB. 7/21/2020 Displaced IA with diesel. Closed CMU at 6,757’ RKB. Performed MITIA to 3500 psi (passed). Set slip stop catcher at 6,750’ RKB. Pulled dummy valve at 6,688’ RKB. 7/22/2020 Made multiple attempts to set OV at 6,688’ RKB with various kickover tools. 7/23/2020 Set OV at 6,688’ RKB. Pulled dummy valve and set gas lift valve at 3,407’ RKB. Obtain good IA drawdown test. Pulled catcher at 6,750’ RKB. 7/29/2020 1C-172A brought online. 7/31/2020 1C-172A well test completed. Casing Strings Casing Description LINER AL2 OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 7,558.7 Set Depth (ftKB) 13,011.4 Set Depth (TVD) … 3,784.6 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,558.7 3,846.9 91.59 SLEEVE 5.5" Baker "HR" Liner Setting Sleeve w/ 6' TBR 5.750 7,621.0 3,846.4 88.55 XO BUSHING X-O Bushing 5-1/2" Hyd 521 x 4-1/2" BTC 3.920 12,989.4 3,784.3 89.06 XO Reducing X-O 3-1/2" IBT x 4-1/2" BTC 3.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,000.0 3,846.3 90.97 FISH 2 Centralizer Arms lost 9.19.2008 9/19/2008 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,622.0 7,751.0 3,846.4 3,853.1 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends 7,880.0 8,352.0 3,850.7 3,840.4 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS 8,522.0 10,757.0 3,833.1 3,803.0 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS 10,917.0 12,947.0 3,800.2 3,783.6 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS Notes: General & Safety End Date Annotation 5/9/2008 NOTE: WELL SIDETRACKED TO 'A', AL1, AL2, NEW PROD CSG 8/17/2008 NOTE: VIEW SCHEMATIC w/AlaskaSchematic9.0REV Comment SSSV: NONE1C-172AL2, 10/2/2017 3:41:05 PM Vertical schematic (actual) LINER AL2; 7,558.7-13,011.4 SLOTS; 10,917.0-12,947.0 SLOTS; 8,522.0-10,757.0 SLOTS; 7,880.0-8,352.0 FISH; 8,000.0 SLOTS; 7,622.0-7,751.0 INTERMEDIATE; 49.1-8,310.0 AL2 Liner HH; 7,354.7-7,608.0 SEAL ASSY; 7,242.2 LOCATOR; 7,241.0 AL2 Liner LEM; 6,984.9-7,236.0 JET PUMP; 6,758.0 Sliding Sleeve; 6,757.7 SLIP STOP; 6,755.0 GAS LIFT; 6,688.6 SURFACE Post S/T; 40.1- 3,640.2 WINDOW A; 3,513.0-3,523.0 GAS LIFT; 3,407.1 CONDUCTOR; 40.0-110.0 HANGER; 35.8 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: GLV C/O, SET JET PUMP & SLIP STOP, OPEN CMU Last Mod By pproven End Date 10/2/2017 KUP PROD KB-Grd (ft) 33.39 Rig Release Date 6/24/2003 Annotation Last WO: End Date 5/13/2008 1C-172AL2 H2S (ppm) 90 Date 8/12/2016 ... TD Act Btm (ftKB) 13,018.0 Well Attributes Wellbore API/UWI 500292315961 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 94.81 MD (ftKB) 8,511.84 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: Convert SPJP to Gas Lift 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1C-172AL2 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,018 8,000 Casing Collapse Conductor Surface Production Liner 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 Commission Representative: GINJ Op Shutdown Abandoned Stephanie Thomson Contact Name:Stephanie Thomson Staff Petroleum Engineer Contact Email:stephanie.thomson@cop.com Contact Phone: 907-263-4536 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 208-010 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25638 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23159-61 ConocoPhillips Alaska, Inc. Length Size 3,784 13,018 3,784 1,019 L-80 TVD Burst 7,265' MD 3,600 110 2,501 110 3,640 8,261 4 1/2 3,9397 5/8 8,310 16 9 5/8 70 13,0115,453 4.5" 3,785 Perforation Depth MD (ft): 7,622'-7,751'; 7,880'-8,352'; 8,522'-10,757'; 10,917'-12,947' 3,864'-3,853'; 3,851'-3,840'; 3,833'-3,803'; 3,800'-3,783' Packers and SSSV Type: Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: None Packers and SSSV MD (ft) and TVD (ft): 6985' MD/ 3785' TVD 7455' MD/ 38501' TVD SSSV: N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 7/23/2020 m n P s 66 t t c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:31 am, Jul 08, 2020 320-287 Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am approving this document with my legally binding signature Location: your signing location here Date: 2020-07-07 17:51:43 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson 0025650 DLB -00 DLB 10-404 X DLB 07/08/2020VTL 7/15/20 DSR-7/8/2020 X Comm 7/16/2020 JLC 7/15/2020 RBDMS HEW 7/17/2020 Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 July 6, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Applications for Sundry Approval for the ConocoPhillips Alaska Inc well KRU 1C- 172A, 1C-172AL1, and 1C-172AL2 (PTD 208-008, 208-009, and 208-010). The request is for approval to convert this producer from a surface powered jet pump (SPJP) to a gas lifted well. 1C-172A has a possible matrix bypass event (MBE) from 1C-121, and converting to gas lift will allow better monitoring of changes in water cut to diagnose the MBE. The down hole conversion work includes pulling the jet pump, closing a sliding sleeve, installing gas lift valves, and performing the appropriate integrity testing. If you have any questions regarding this matter, please contact me via the details below. Sincerely, Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 Attachments: Sundry Application Proposed Steps Well Schematic Well Events Summary Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am approving this document with my legally binding signature Location: your signing location here Date: 2020-07-07 17:52:08 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson KRU 1C-172A DESCRIPTION SUMMARY OF PROPOSAL Jet Pump to Gas Lift Conversion for KRU 1C-172A CPAI proposes the following plan: 1. Install blind to water injection header and remove blind to lift gas header to connect individual well to lift gas. 2. Pull jet pump from sliding sleeve. 3. Flush the inner annulus with diesel to remove all produced water. 4. Shift the CMU closed. Perform drawdown test. 5. Bring the well online on gas lift. 6. Submit 10-404 following conversion. Casing Strings Casing Description LINER AL2 OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 7,558.7 Set Depth (ftKB) 13,011.4 Set Depth (TVD) … 3,784.6 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,558.7 3,846.9 91.59 SLEEVE 5.5" Baker "HR" Liner Setting Sleeve w/ 6' TBR 5.750 7,621.0 3,846.4 88.55 XO BUSHING X-O Bushing 5-1/2" Hyd 521 x 4-1/2" BTC 3.920 12,989.4 3,784.3 89.06 XO Reducing X-O 3-1/2" IBT x 4-1/2" BTC 3.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,000.0 3,846.3 90.97 FISH 2 Centralizer Arms lost 9.19.2008 9/19/2008 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,622.0 7,751.0 3,846.4 3,853.1 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends 7,880.0 8,352.0 3,850.7 3,840.4 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS 8,522.0 10,757.0 3,833.1 3,803.0 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS 10,917.0 12,947.0 3,800.2 3,783.6 WS A4, 1C- 172AL2 5/7/2008 32.0 SLOTS Notes: General & Safety End Date Annotation 5/9/2008 NOTE: WELL SIDETRACKED TO 'A', AL1, AL2, NEW PROD CSG 8/17/2008 NOTE: VIEW SCHEMATIC w/AlaskaSchematic9.0REV Comment SSSV: NONE1C-172AL2, 10/2/2017 3:41:05 PM Vertical schematic (actual) LINER AL2; 7,558.7-13,011.4 SLOTS; 10,917.0-12,947.0 SLOTS; 8,522.0-10,757.0 SLOTS; 7,880.0-8,352.0 FISH; 8,000.0 SLOTS; 7,622.0-7,751.0 INTERMEDIATE; 49.1-8,310.0 AL2 Liner HH; 7,354.7-7,608.0 SEAL ASSY; 7,242.2 LOCATOR; 7,241.0 AL2 Liner LEM; 6,984.9-7,236.0 JET PUMP; 6,758.0 Sliding Sleeve; 6,757.7 SLIP STOP; 6,755.0 GAS LIFT; 6,688.6 SURFACE Post S/T; 40.1- 3,640.2 WINDOW A; 3,513.0-3,523.0 GAS LIFT; 3,407.1 CONDUCTOR; 40.0-110.0 HANGER; 35.8 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: GLV C/O, SET JET PUMP & SLIP STOP, OPEN CMU Last Mod By pproven End Date 10/2/2017 KUP PROD KB-Grd (ft) 33.39 Rig Release Date 6/24/2003 Annotation Last WO: End Date 5/13/2008 1C-172AL2 H2S (ppm) 90 Date 8/12/2016 ... TD Act Btm (ftKB) 13,018.0 Well Attributes Wellbore API/UWI 500292315961 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 94.81 MD (ftKB) 8,511.84 1C-172A Well Events Summary Date Event Summary 5/17/2020 1C-172A SI and Freeze Protected From:Thomson, Stephanie To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]KRU 1C-172A(PTD 208-008, Sundry 320-289) Conversion Jet Pump to Gas Lift Date:Monday, July 13, 2020 9:21:11 AM Hi Victoria, Below is the graph. The red boxes show the sensitivities I ran: 0 psi at the wellhead and 0 lift gas. As you can see, the 0 lift gas curve does not meet the IPR curve indicating no unassisted flow to surface. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, July 13, 2020 9:11 AM To: Thomson, Stephanie <Stephanie.Thomson@conocophillips.com> Subject: [EXTERNAL]KRU 1C-172A(PTD 208-008, Sundry 320-289) Conversion Jet Pump to Gas Lift Thanx Stephanie, Could you provide a hydraulic calculation demonstrating this? I can see the low reservoir pressure but would like to see a simple calculation. The gas lift design/calculation would show this. Thanx, Victoria Thanx, Victoria From: Thomson, Stephanie <Stephanie.Thomson@conocophillips.com> Sent: Monday, July 13, 2020 9:02 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1C-172A(PTD 208-008, Sundry 320-289) Conversion Jet Pump to Gas Lift Hi Victoria, To my knowledge, we have never conducted a no flow test on this well. Based on nodal analysis, I would not expect this well to flow to surface without some type of artificial lift. Thanks, Stephanie From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, July 13, 2020 8:52 AM To: Thomson, Stephanie <Stephanie.Thomson@conocophillips.com> Subject: [EXTERNAL]KRU 1C-172A(PTD 208-008, Sundry 320-289) Conversion Jet Pump to Gas Lift Staphanie, Does this well flow to surface? Has a no flow test ever been conducted? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov • Image Project Weli History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~~ Q Well History File Identifier Organizing (done) RESCAN ~lor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o..s,,.a iuuii~iuiuim DI TAL DATA Diskettes, No.3 ^ Other, No/Type: BY: Maria Date: Project Proofing BY: Maria Date: Scanning Preparation _~. x 30 = BY: ~ Maria Date:. '~ Production Scanning Re,~,~~~aea muiiiuiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: v ~1P muiiiiiiiaiuu ~~ + 3 =TOTAL PAGES~~ (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: I d~ -J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: r /~,Cj lO ~s~ /l Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ annin is com lete at this Dint unless rescanning is required. I) I II II II I II II I (III Sc g p p ReScanned II I II ~I II I I III I I III BY: Maria Date: ~s~ Comments about this file: Quality Checked II I II'll) III (I I) III 10I6l2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1/14/2009 Permit to Drill 2080100 Wefl Name/No. KUPARUK RIV U WSAK 1C-172AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23159-61-00 MD 13018 TVD 3785 Completion Date 5/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~ DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Informat ion: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name _ _ _ _.._. L IS Verification C Lis E a~~"Induction/Resistivity R t IGS~- LIS Verification p (~ C Lis 16502~Induction/Resistivity GR(S/ LIS Verification C Lis 16503~nduction/Resistivity D Asc Directional Survey t Directional Survey D~~ D Asc Directional Survey Xpt Directional Survey ~ E D D A ~ sc Directional Survey ~~ ~Ftpt Directional Survey ~C og Induction/Resistivity / ~/Log Induction/Resistivity j/, Cog Induction/Resistivity og Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 3508 13018 Open 6/24/2008 LIS Veri, GR, FET, RPS, ~, RPM, RPD, RPX, ROP 3508 13018 Open 6/24/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 3508 10205 Open 6/24/2008 P61 LIS Veri, ~R, FET, RPS, RPM, RPD, RPX, ROP 3508 10205 Open 6/24/2008 P81 LIS Veri, GR, FET, ~i RPS, RPM, RPD, RPX, ROP 3508 12424 Open 6/24/2008 PB2 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 3508 12424 Open 6/24/2008 P82 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 0 13018 Open 6/24/2008 '~, 0 13018 Open 6/24/2008 i 0 10205 Open 6/24/2008 i PB 1 0 10205 Open 6/24/2008 PB 1 0 12424 Open 6/24/2008 PB 2 i 0 12424 Open 6/24/2008 PB 2 25 Col 3515 13018 Open 8/8/2008 MD ROP, DGR, EWR 25 Col 2448 3784 Open 8!8/2008 TVD DGR, EWR it 25 Col 3515 10205 Open 8/8/2008 PB1 MD ROP, DGR, EWR 25 Col 2448 3812 Open 8/8/2008 PB1 TVD DGR, EWR ~ DATA SUBMITTAL COMPLIANCE REPORT 1 /14/2009 Permit to Drill 2080100 Well Name/No. KUPARUK RIV U WSAK 1C-172AL2 Operator CONOCOPHILLIPS ALASKA I NC API No. 50-029-23159-61-00 MD 13018 TVD 3785 Completion Date 5/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N Log Induction/Resistivity 25 Col 3515 12424 Open 8/8!2008 PB2 MD ROP, DGR, EWR i, /off I~uction/Resistivity 25 Col 2448 3785 Open ~ 6- 8/8/2008 8/8/2008 PB2 TVD DGR, EWR EWR l f L2 PB1 d ~/ED C 16718 See Notes -- - ogs or , an J'a a ~) Uc7 ~ PB2 in EMF, CGM and PDS graphics /ED C Las 16946 rProduction 7506 10265 Case 9/30/2008 PPL, Pres, CCL, GR ~9 Production 2 Blu 7518 10265 Case 9/30/2008 PPL, MPL, Pres, GR, CCI, '~ ILS, Temp, Spin 20-Sep- 2008 I Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ! J Chips Received? ~-FP1-- Analysis ~L~} Received? Comments: • Compliance Reviewed By: _ __ _ ______ Daily History Received? ~"/ N Formation Tops ~'N Date: ~J Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Monday, February 02, 2009 1:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Page 1 of 3 Subject: FW: 1 C-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Attachments: Patrick.J.Reilly@conocophillips.com.vcf Tom, Here is the breakdown of our blank intervals. Sharon will send over the ConocoPhillips schematics, Baker Oil Tool schematics, and the liner/hook hanger detail sheets. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com From: Allsup-Drake, Sharon K Sent: Monday, February 02, 2009 1:00 PM To: Reilly, Patrick J Subject: FW: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) From: Allsup-Drake, Sharon K Sent: Monday, February 02, 2009 10:12 AM To: Reilly, Patrick J Subject: FW: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) ,~ Pat - Below is the breakdown of blank intervals for each of the laterals for 1 C-172A for your review before forwarding to Tom Maunder. I will also send him paper copies of the schematic, wellbore diagram and casing detail sheets of each lateral. 1 C-172A: entire liner is slotted except for the following blank intervals - 7925'-8487' MD 3901'-3945' ND 10239'-10410' MD 3927'-3929' ND 12601' -12773' MD 3911'-3912' ND 13027'-13072' MD 3914'-3915' ND 1 C-172AL1: entire liner is slotted except for the following blank intervals - 7818'-8103' MD 3904'-3904' ND 9863'-9990' MD 3881'-3880' ND 12533'-12705' MD 3856'-3855' ND 13047'-13092' MD 3851'-3851' ND 1 C-172AL2: entire liner is slotted except for the following blank intervals - 7354'-7622' MD 3846'-3845' ND .~---;~ 7752'-7880' MD 3853'-3850' ND 2/2/2009 8352'-8522' MD 3840'-3832' TVD 10757'-10917' MD 3803'-3801' TVD 12947'-12991' MD 3783'-3784' TVD Thank you, Sharon 263-4612 Page 2 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, November 15, 2008 8:21 AM To: Reilly, Patrick J Cc: McKeever, Steve; Allsup-Drake, Sharon K Subject: RE: 1C-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Pat and Sharon, Lets talk on Monday before you redo the 407s. I am all in favor of the correct information, however I am also in favor of keeping the paperwork as low as we can too. Tom From: Reilly, Patrick J [mailto:Patrick.J.Reilly@conocophillips.com] Sent: Fri 11/14/2008 1:39 PM To: Maunder, Thomas E (DOA) Cc: McKeever, Steve; Allsup-Drake, Sharon K Subject: FW: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Tom, Sorry about the confusion on this. Sharon and I reviewed the 407 and we think we have come up with a better way to describe the liner/blank placement. The liner is all slotted except for the specific depths listed (which are blank). We will send over new 407's with a clearer description. We will also send over a drawing similar to the proposed drawing. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 04, 2008 12:57 PM To: McKeever, Steve Subject: RE: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Hi Steve, Sooner would be appreciated. I think between Sharon and an engineer they could get the stuff together. Let me know what works. Main thing is we have the items flagged so they don't go through the cracks. Tom 2/2/2009 Page 3 of 3 From: McKeever, Steve [mailto:Steve.McKeever@conocophillips.com] Sent: Tuesday, November 04, 2008 11:48 AM To: Maunder, Thomas E (DOA) Subject: RE: 1C-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Hi Tom - My apologies for the incomplete information. How soon do you need it? The reason I ask is I am ofF on vacation for a couple of weeks at the end of this week. If I get it to you in the first week of December, will that be soon enough? If not, I will find someone else to get it to you. Steve McKeever Drilling Superintendent, Greater Kuparuk ConocoPhi!lips Alaska, Inc. office: 9Q7.2b5.6826 cell: g07.35i.5004 home: 9Q7.345.1229 Units of Conversion: lOQO aches: 1 kilohurtz From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 04, 2008 10:32 AM To: McKeever, Steve Cc: Allsup-Drake, Sharon K Subject: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Steve, I am not sure which engineer was responsible for this well, so you get the message. I have just reviewed the completion reports for these wells and have some questions. 1. On block 23 on all 407, some amount of liner detail is given. There are depth gaps. Is the liner solid/blank in the gaps? It is somewhat confusing how it is listed. 2. Please provide the completion details sheet for each leg. 3. Please provide a wellbore drawing. I believe an earlier message was exchanged regarding a completion drawing similar to the proposed drawing provided in the permit applications. A drawing similar to that would be appreciated. Thanks in advance. Call or message with any questions. Tom Maunder, PE 2/2/2009 ~~~ KU P r. ~OtIOCO~I~~1 5 Well Attributes Max M p ~ A(. S~ f i ~ Wellhore APVU WI 'rield Name __ IWeII Status Prod/Inj Type Intl (°) I f ~ . / 500292315961 (WEST SAK 94 81 '~PROD ... W II C tl 1C 2/~ Comment H25 (ppm) 0 PPL 24 23 P P0 2 I bate Annota4on IEnd Date I 7/1/2008 Last WO ~, 5!13!2008 @ on L~r1.2, . _ _ e -.~ _ _ ~ g sdi_.mstc ncw M ~.1 : De th ftKB End Date Ann tat on a'I_.... p ( 1 A nnotat~on ', Last Tag: Rev Reason SCHEMATIC CORRECTIONS HANGER, 36 ~ _ __ Casin Strin s '-~ Casing Descrption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... Stria L2-A4 LEM 4112 3.958 6,984.9 7,236.0 3828.1 1 !. Casing Description String 0... String ID . .. Top (ftKB) Set Depth (f... Sat Depth (ND) ... Stria L2-A4 HK HNGR 41/2 4.000 ~ 7,354.7 7,608.0 3,846.2 1 '~ Casin Descri Lion Strin 0... Strin ID . -~ 9 P 9 9 .. To ftKB Set De [h f... Set De th NO Stril P( ) P( P( )~~- NER 41/2 4.000 _ , L2 - A4 LI 7,558.7 13,011.4 3.7846 1 - CONDUCTOR, - eta! lS in D ___ __. NIPPLE. 5 EAT TRACE p , ToP De th (TVD) iTop Intl ~ H ,_ -- 36 o ftK -_~ P ( ) (ftKB) (°) Item Descnpt ion Comment _. ` 7,558.7 3,847.0 92.48 SLEEVE 5.5" Baker "HR"Liner Setting Sleeve w/ 6' TBR GAS LIFf,_-_. I ~~ 7,621.0 3,845.1 85.58 XO BUSHING X-O Bushing 5-1/2" Hyd 521 x 4-1/2" BTC i 3,39x - -.. _ .*::aq"' ~ 12.989.4 3.784.3 89.06 XO __. X-O 3-1 /2" IBT x 4-12" BTC A2 CSG WINDOW, 3,513-3,523 GAS LIFT, 6.fi92 SURFACE, 0-6,712 DISCHARGE, 6,740 FLUTED SUB, _ _. __ 6,783 BLEEVE, 6,786 FLUTED SUB, 6,78E XO, 6,E24 --- - ~~ --- GAUGE, 6,829 X0,6,830-- L2 -Ad LEM, 6,985-7,236 LOCATOR, 7 241' SEAL ASSV, ].243 A4 CSG WINDOW, 7.357-7.3fi] 1 - L2 - PA HK HNGR, 7 355-7,606 - - -- SLOTS, ],622-7.751 - - -- FISH, 8.000 - SLOTS, 7.880-8.352 - !- sLOrs, __ __~_ _ 6.522-10,757 SLOTS,. 10,917-12,94] ~ _ ~~ L2 - A4 LINER, 7,559-13,011 TD 13.018 7,880.0 8,352.0 3,850.6 3.840. 8,522.0 10,757.0 3,833.8 3,803. Comment 1 C-172AL2 MD Tl) KB) Act eim (tiKB) ,511.84 13,018.0 'd (H) Rig Release Date 33.39 624/2003 Entl Date vv2aa9 .. Stnng ~. String TOp Thrd L-80 IBT -_ .. String ... 'String Top Thrd L-80 ! BTC Comment P N c~ OD Valve Latch S e TRO R ') Make Model (n) Serv Type Type (nJ (ps) Run Date Comn .64'CAMCO KBMG 1~Gas Lift GLV BK 0.156 1,263.0 SI14/2008 .61 CAMCO KBMG 1 Gas Lift OV BKO-3 O.OBl14/2008 Ports 3/8" x _.. __ _ _._. - _ I ____ -.. __.... __. __ 7/16.. ~~ ~,, 1C-172A (A4) Plop and Drop slot/blank liner Well: 1C-172AL2 ConoeoP hil li ps 4-1/2" 11.6 ppg BTC-m L-80 BTC-m Date: 5/7/2008 Alaska, inc. Rig Supervisors: Mike Thornton /Scott Lapiene Rig: Doyon 15 Depth Jt Number N Jtsot Well Equipment Description and Comments age 1 Length Tops 5" DP to Surface =_> 7549.05 Crossover 4" XT-39 Box x 3-1 r`2°° il= ~'ir~ ;'aces t~c}t st~~-,~ in hole; 2.98 7549.05 Baw~ r ;. SE~ti ~ G~: ,c - ,.'~ ~-.: 6.70 7552.03 5.5" Baker "HR" Liner Setting Sleeve w/ 6' TBR 12.68 7558.73 5 1/2", 15.5 ppf, L-80, Hydril 521 Pup joint P x P 7.35 7571.41 5 112", 15.5 ppf, L-80, Hydril 521 (Receptacle Joint) 42.21 7578.76 X-O Bushing 5-112" Hyd 521 x 4-1/2" BTC 1.44 7620.97 Jts 126 to 128 Jts 4-1/2", 11.6 ppf, L-80, BTCM Slotted Casing with torque rirsLls 129.48 7622.41 Jts 123 to 125 3 Jts 4-112", 11.6 ppf, L-80, BTC Blank Casing with torque rings 127.81 7751.89 Jts 114 to 122 9 Jfs 4-112", 11.6 ppf, L-80, BTCM Slotted Casirkg ~t,ritf . te~rq~ie rir~cls 386.38 7879.70 Jts 112 to 113 2 Jt 4-1l2", 11.6 ppf, L-80, BTCM Slotted Casit-.c_:¢ 86.39 8266.08 Jts 108 to 111 4 Jc ~ 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 169.39 8352.47 Jts 54 to 107 54 Jts 4-1/2", 11.6 ppf, L-80, BTCM Slatted Casing 2234.78 8521.86 Jts 50 to 53 4 Jts 4-112", 11.6 ppf, L-80, BTC Blank Casing 160.48 10756.64 Jts 2 to 49 48 Jts 4-112", 11.6 ppf. L-80, BTCM Slotted Casirzq 2029.50 10917.12 Jts 1 to 1 1 Jr 4-112", 11.6 ppf, L-80, BTC Blank Casing 42.80 12946.62 X-O 3-112" IBT x 4-1/2" BTC 1.43 12989.42 X-O Pup jt 3-1/2" EUE x 3-1/2" IBT 5.92 12990.85 3-1 /2" 9.3 ppf L-80, EUE 8rd casing {Orange Peeled Pin End) 14.64 12996.77 13011.41 13011.41 13011.41 13011.41 A4 Lat TD @ 13,018' MD/ 3,784' TVD 13011.41 3-1/2" Shoe @ 13'011.41 MD / 3,784' ND (Rat Hole 6.59') 13011.41 Top of Plop ~ Drop is spaced out to match Hook Assembly 13011.41 13011.41 13011.41 13011.41 7 Constrictor Packers @ 12,958', 10,888', 10,773', 8,508', 8,368', 13011.41 7,877', 7,753'. 13011.41 13011.41 13011.41 13011.41 13011.41 Remarks: Up Wt 225K Torque Instructions : Torque BTCM wl torq rings= 4500 ft-Ibs , Dn Wt OK BTCM - 2800 ft-Ibs Avg 10 jts to diamonds Block Wt 70K Total Footage of each = 4.866.53' of Slotted, 500.48' of Blank Rot Wt 147K Centrilizers : Run 1 •4.5" X 6 1/8" Hydroform per joint floating on Joints #2 thru # 128 =Total ran 121 Torque Rings In : Jts 114 thru 128 =Total used 15 Rot Torque 8K Hook Hanger Detail Well: 1C-172AL2 1C-172A A4 Lateral 4-1/2" Plop 8 Drop Date: 5/8/2008 ConoCOPhillips Rig: Doyon 15 Alaska, Inc. Depth JtNumber Joints Well Equipment Description an °iments Length Tops Top of String or Top of Flan, 4" Drill pipe to surface (does not stay in hole) 7345.66 Crossover 4" XT-39 Box x 3-1 /2" IF Pin (does not stay in hole] 2.98 7345.66 Baker running tool {does not stay in hole) 6.07 7348.64 Baker Model 'B-1' Hook Hanger 7-5/8" x 4-1 /2" (Inside csg) 16.29 7354.71 Baker Model 'B-1' Hook Hanger 7-5/8" x 4-1 /2" (Outside csg) 6.63 7371.00 4-1/2", 12.6 ppf, L-80, BTC PUP Jt. (Drift 3.850") 3.91 7377.63 Jts 2 to 3 2 Jts 4-1/2", 11.6 #, L-80, BTC Blank casing s5.19 7381.54 4-112", 12.6 ppf, L-80, BTC PUP Jt. 5.81 7466.73 Payzone ECP -Shear Valve 2600 psi, Control Valve 575 psi 22.96 7472.54 4-112", 12.6 ppf, L-80, BTC PUP Jt.(PxP) (Drift 3.850") 3.05 7495.50 Jts 1 to 1 1 Jts 4-1/2", 11.6 #, L-80, BTC Blank casing 40.69 7498.55 4-1/2", 12.6 #, L-80, BTC Blank casing BTC box x STL pin (Drift 3.850") 37.83 7539.24 4 1/2" ,11.6#, L-80 STL BENT joint Blank Casing 30.90 7577.07 w/ full mule shoe +++++ Bottom of mule shoe =_> 7607.97 7607.97 7607.97 7607.97 7607.97 7607.97 TD 6 3/4" hole @ 13,018' MD / 3,784' TVD 7607.97 7607.97 "A4" Window top at 7357' MD / Btm of window @ 7371' MD 7607.97 Top of'A4' Lateral Liner (In open Hole) @ 7,558.73' MD 7607.97 A4' Lat. XO Bushing 3.92" ID @ 7,620.97' MD 7607.97 7607.97 Mule shoe is spaced out 49.24' inside of plop S drop liner top. 7607.97 Mule shoe is spaced out 29.21' inside Receptacle joint. 7607.97 7607.97 7607.97 Found bttm of "A4" Window @ 7371' When Hooked 45/ K. 7607.97 7607.97 7607.97 7607.97 7607.97 7607.97 Remarks: Torque 4-1/2" STL = 1800 ft/Ibs, 4-1 /2" BTC = 2800 ft lbs. up wt 190 K Used Run-N-Seal thread compound on all connections. Dn Wt 140 K Drifted casing to 3.875" w/ teflon rabbit. Block Wt 7o K Supervisors: Mike Thornton /Scott Lapiene 16" Conductor, K-55, set at 107' XXX" x 41/2" Wellhead, 5,000 psi Turing, 4112", 12.8#, IBTM, Special Ddn above 7.875 BD nipple 511' MD-J.875" OB Nipple, 510 ND IJ degl 3394' MD -GLM, Camco KBMG, 4112" X 1", 2393 188 tlegl Whipstock Casing Exit Tow 3,613' «I-, 2,7A0' ND Camco KBMG, 4112" X 1 ", 3819 ND 6] tle 6692'MO-GLM, ( 91 8783' MD-CMD Sliding Sleeve, w17.87" DB Pro111e, 3836 ND (88 deg( 7475' MD-Casing Sealbore Receptacle 20'Length ~7559'MD-5-112"Tieback Sleeve 130t7'MD-4112"Dner Shce, 11.6k, L-00 BTC, 3850' NO MD -bosom of 4112" bent muleshoe 9-sla° ago, arc ~ ,• "L 1 C-172 7255' MD -Casing Sealbore Receptace, 20' Lenqth 7J11'MD-3.75"DB-B NIpple, JeJ5 ND184 de91 ~~~~~~. A~ (~ Tubing String VVV 4112" 71.BM, L-90, IBTM 3.858" ID, 7197' MD-Lateral Enfry ModulelLEMI 1.833" Ddn 7357'MD-A45and Wlntlow, 3917'N0184 tlegl 'A4' Sand Lateral ]236' MD- 5-112" X T-518" ZXP Liner Top Packer w/Hold Downs 7473' MO- Payzone ECP 4112" 11.6p L-00 Slotted an0 Blank Liner i -:?>.. ~ / 3-112"Guide Shoe _- 7265' MD-Bottom of Seal Assemdy r 7755'MD-4112'X7-518" gem Bores ~ Motlel'B'HOON Hanaer ace"ID 7456' MD - 51/2" %7-518" ZXP L iner Top Packer w/ Hold Downs Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 7818' MD- 4712" X 7-518" Motlel'B' HOOK Hanoer sam eor:. 9.a9' to 7487' MD-Bottom of Seal Assemdy 0.75" Seal OD 4113" t3.ap Tubing 9,819" Orltt 95@'ID ConocoPhillips West Sak 7-5/8" Producer 1 C-172a ST Tri-Lateral Completion a-vz° Gwae snoe 73092' MD-4112" liner Shce, 9030' MD- 5-712" Tieback Sleeve 11.6#, L-00 BTC, 3850' ND 8092' MD -Bottom 0141/2" bent muleshoe - 7887' MD - 3.562" DB8 Nipple, 3998 ND (BJ degl 5112" X 7-518" ZXP Winer Top Packer nh Hola Down9 Svz^ x Isle" Rex Lxk T826'MD-Dner Hanged Packer Assembly Dner Hanger / 7957' MD-Casing Sealbore Receptacle, 20'Length 8307' MO ©Baker Hughes 2005. This document may sat De reprotluced or dlstdbutetl, In while or In pan, in any form or by any means electronic or mechanical, inclutling photocopying. recording, or by any informellon storage antl retrieval syrtem now known or hereaher Invented, without written pennlsslon Imm Baker Hughes Inc. 7964• MD-Bosom or seal a9semay Diverter and Sleeve Length: +1-18.5' 4.75" seal oD 'A2' Sand Lateral avx° nsa Lao slates ana Blank Liner 4112"Eccentric Guide / Shce ~({~~-~~}--1~J- 13m2' MD-4-112" Casing Shce, 11.871, L-00 BTC, 3975' w ~~'! W~~~~- TVG ig, L-80, Hydd151 J, 3939' TVD 190 aegl Assembly 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs ~~ Casing Sealbore Receptacle 4.75" ID Orienting Profile '-/ Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location I"_ Seal Bore for Lateral Isolation - 3.68" ID Access Window )` Positive Lateral Access Via \ Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID As Completed r/:® MYGNES baker Oil Tools Lateral Entrv Module (LEM1 With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool Shing Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector (Running/Retrieving \ (1.00' Length) Snap In/Snap Out dPOSitive Locating rBack Pressure Valve Collet (1.80' Length) Lateral Isolation ~' r Plow-Thru Swivel Seals ' (1.25' Length) / Lateral Diverter / Hydraulic Ramp ~ Disconnect Isolation/ Mainbore (1.50' Length) Diverter Sleeve ~ GS Spear ~~ (1.50' Length) Lateral Isolation 6 .85 h Approx. Seals OAI.' -Jars may be required in highly devlatetl or deep applications (6' approx length). 18.5' Diverter Length 18.5' Sleeve Length ~ 7870' MD-Lateral Entry ModulelLEM) 7820/'MD-AJ.SandWlndow,7918'NDl86tleg) 'AS' Sand Lateral ®/ ]940' MD- Payzone ECP 4112^ 77.6M L-00 Slated antl frank Dner Eauiament Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LateraUMainbore Diverter OD: 6.75" 41/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter antl Sleeve: +l- 3.89" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REC~iV~~ AUG 2 8 2008 WELL COMPLETION OR RECOMPLETION REP~c~~;,l~-/,~,.~~,~„~,;~y~,;,,~ 1 a. Well Status: -Oil O Gas Plugged Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1 b. Well Clads: ` ~r~ ~ Development ~ . "~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~`,~, rZ,f ,gyp or Aband.: ~° ~J,luiy-+2695' ~1> 12. Permit to Drill Number: a208-009 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: /S ~ April 008 ~•~ 13. API Number: 50-029-23159-60 4a. Location of Well (Governmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11N, R10E, UM ~ 7. Date TD Reached: April 18, 2008 14. Well Name and Number. 1C-172A-L1 ' Top of Productive Horizon: 18' FNL, 2272' FEL, Sec. 11, T11N, R10E, UM 8. KB (ft above MSL): 100.5' RKB Ground (ft MSL): 59.1' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 182' FNL, 2426' FEL, Sec. 14, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 13092' MD / 3851' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562102 , y- 5968801 ' Zone- 4 10. Total Depth (MD + ND): • 13102' MD ! 3851' TVD • 16. Property Designation: ALK 25649, 25650 TPI: x- 558722 y- 5970191 Zone- 4 Total Depth: x- 558617 - 5964748 Zone- 4 11. SSSV Depth (MD + ND): landing nipple @ 511' MD / 511' ND 17. Land Use Permit: 467, 468 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 2439' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gf eW 78T1~ Md 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE MENTING RECORD C AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE E PULLED 16" 62.5# H-40 40' 107' 40' 107' 42" 838 sx ArcticCRETE 9.625" 40# L-80 40' 3513' 40' 2448' 12.25" top of window @ 3513' 7.625" 29.7# L-80 40' 8302' 40' 3939' 9.875" 445 sx DeepCRETE 5.5" / 4.5" 15.5 / 11.6# L-80 7818' 13092' 3888' 3851' 6.75" slotted liner 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore n/a none slotted liner from 8030'-8103' MD 3902'-3904' TVD 9862'-9989' MD 3881'-3880' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12533'-12704' MD 3856'-3855' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED blank intervals from 13047'-13092' MD 3851'-3851' TVD na 26. PRODUCTION TEST Date First Production flowback starting 6!13/08 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 7/9/2008 Hours Tested 6 hours Production for Test Period --> OIL-BBL 556 GAS-MCF 686 WATER-BBL 0 CHOKE SIZE 20% GAS-OIL RATIO 1233 Flow Tubing not available Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 2224 GAS-MCF 2743 WATER-BBL 0 OIL GRAVITY -API (corr) 20 deg. 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COMPLETtOt~! ( DATE NONE s~ ~ ~9 Form 10-407 Revised 2/2007 ~..~ f~ 1 i ~ i ~;~ L~ ~ CONTINUED ON REVERSE SIDE •~ .,J '' t' .. ~ ~I*~; Sit' ~ 91008 -°`` L:~ ~~~ u G ~~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3490' 2439' needed, and submit detailed test information per 20 AAC 25.071. West Sak A2 13102' 3851' West Sak A3 7648' 3872' West Sak A4 7272' 3832' N/A Formation at total depth: West Sak A-3 30. LIST OF ATTACHMENTS ~' Summary of Daily Operations, Directional Survey ~ 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: at Reilly @ 26 -604 Printed Name S ,ve McK e r Title: GKA Drilling Superintendent ~C ~ ~~ ~ ~ Phone Date Si~nature~~ ~ ~~'"" INSTRUCTIONS Sharon Alfsup-Drake 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 1a: 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 welt producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval}. Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • • Time Low- - - _ -- - - - - ~ Date From To Dur S- De tis E. De-ih PhaSe Cudc Subco~e T Com~-nen; __ 22:15 22:45 0.50 0 0 PROD2 STK WPST T Directional survey tools extend 2.5" past pin end of tools interfering with float./ float sub. Attempted to rearrange BHA to fit stick out. Located and made up cross overs with enough internal clearance o fit directional tools. 22:45 23:45 1.00. 0 193 PROD2 STK WPST P Continued picking up whipstock and / millin BHA. 23:45 00:00 025 193 193 PROD2 STK WPST P Downloading MWD. Monitor well via tri tank. 4/15/2008 Trip in hole with whipstock and milling BHA. Set whipstock 11 degrees left, shear off and mill window.-Cut 22' of new hole and circulated clean. Tri ed out of hole.and laid down mills and flushed surfaces ui ment. 00:00 00:30 .0.50 193 193 PROD2 STK . WPST P Finish downloading MWD. Monitoring well via tri tank. 00:30 01:00 0.50 193 302 PROD2 STK WPST P Trip in hole on elevators with whipstock and milling BHA monitoring well via trip tank. Shallow pulse test MWD pumping 200 gpm / 580 psi -good test. PU wt 85k SO wt 85k 01:00 06:00. 5.00 302 7,220 PROD2 STK WPST P Trip in hole on elevators with whipstock and milling BHA monitoring displacement via trip tank. Fill pipe every 25-stands: 2848' MD / 188 gpm / 770 psi 520T M D / 200 m f 1050 si 06:00 06:45 0.75 7,220 7,269 PROD2 STK WPST P' MAD pass to confirm depths. 06:45 07:45 1.00 7,269 7,895 PROD2 STK WPST P Trip in holeon elevators. Monitor displacement via trip tank. PU wt 190k, SO wt 130k. 07:45 08:00 0.25 7,895 7,926 PROD2 STK WPST P Orient to 14 degrees left while running in hole, pumping 290 gpm / 69 spm. Calculated displacement 55.8 bbls, actua153.5, lost 2.3 bbls Burin tri . 08:00 08:15 0:25 7,926 7,926 PROD2 STK WPST P Landed whipstock @ 11 degrees left and sheared bolt to milling BHA with 40k down weight. Top of whipstock / 7820' MD 08:15 08:30 0.25 7,917 7,917 PROD2 STK WPST P PJSM -displacing SFOBM with OBM 08:30 09:15 0.75 7,917 7,820 PROD2 STK WPST P Displace well with 320 bbls OBM, um in 310 m / 2840 si. 09:15 12:00 2.75 7,820 7,836 PROD2 STK WPST P Milling window for A3 lateral. Pumping 280 gpm / 2460 psi, rotating 60 rprn, torque 8k ft lbs. Pumped 30 bbl 9.3 ppg 300 vis ~~~ ~ sweep halfway thru milling window, observed 20% increase in cuttin s. 12:00 13:45 1.75 7,836 7,853 PROD2 STK WPST P Continue milling window and cut 22' of new hole. Pumping 280 gpm / !, ~ 2460 psi, rotating 60 rpm, torque 8k ft lbs. PacJe 27 of 6Et ~ ~ Time Logs -- - ~ Date From To Dur S. depth E De th Fhase Code Sut~eo~le T Gomment_ 13:45 14:15 0.50 7,853 7,820 PROD2 STK WPST P Work mills thru window. No overpull. PU wt 185k SO wt 132k. Top of Window 7820' MD / 3889' TVD Bottom of Window 7833.7 MD / 3890.4` TVD 14:15 15:30 1.25 7,820 7,853 PROD2 STK WPST P Pump 30 bbl sweep & 2 bottoms up @ 320 gpm / 3050 psi. PU wt 185k, SO wt-132 k, rotating wt 145k, torque 5-6k ft lbs. Observed 40% increase in cuttin s. 15:30 15:45 0.25 7,853 7,853 PROD2 STK WPST P Monitor well -static 15:45 16:30 0.75 7,853 6,707 PROD2 STK WPST P Pull out of hole on elevators, monitoring hole fill via trip tank. Record weights every 10 stands. PU . wt 170k, S0 wt 120k 16:30 16:45 0.25 6,707 6,707. PROD2 STK WPST P .Pump 15 bbl, 11.3 ppg, 72 vis dry job and blow down to drive. 16:45 19:45 3.00 6,707 -488 PROD2 STK WPST P Pull out of hole on elevators, monitoring hole fill via trip tank. Record weights every 10 stands. PU wt 170k, SO wt 120k 19:45 20:00 0.25 488 193 PROD2 STK WPST_ P Lay down milling BHA, monitoring hole fill via tri tank. 20`00 20:30 0.50 193 193 PROD2 STK WPST P Download MWD 20:30 -22:00 1.50 193 0 PROD2 STK - WPST P Contirue laying down milling BHA, monitoring hole fill via trip tank. .Mills were full gauge when pulled out ofi hole.. 22:00 -00:00 2.00 0 0 PROD2 DRILL CIRC P Flush stack and choke manifold. Blow down choke and kill lines. 4/16/2008 Picked up and made up A3 lateral Geo-Pilot drilling BHA.- Ran in hole to top. of window and stopped to service rig and cut drilling line. Recorded baseline ECD 11.46 ppg and drilled to 8669' MD. Pumps kicked off while drillin and inclination increased 1 de ree. Trou hed until inclination back to tar et. 00:00 00:15 0.25 0 0 PROD2 DRILL RURD P Rig up tools to make up drilling BHA. Blind rams shut. 00:15 00:30 0.25 0 0 PROD2 DRILL SFTY P PJSM -making up BHA 00:30 01:45 1.25 0 87 PROD2 DRILL PULD P Pick up and make up geo-pilot- drillin BHA. 01:45 02:30 0.75 87 57 PROD2 DRILL PULD P Upload MWD, monitor well via trip tank 02:30 03:15 0.75 57 386 PROD2 DRILL PULD P Continue to make up BHA. Shallow ulse test MWD um in 200 m. 03:15 06:00 2.75 386 7,728 PROD2 DRILL TRIP P Trip in hole on a-evators. Record weights every 10 stands. Fill pipe every 25 stands: 2730' MD pumping 200 gpm / 1050 psi 5092' MD pumping 200 gpm / 1250 si 06:00 06:45 0.75 -7,728 7,728 PROD2 RIGMNT SVRG P Service rig, blocks, top drive, crown and iron rou hneck Page 28 of 6© ~ ~ __ Time Lois -Date Fro_m__To D_ur S. Depth E ~e th t~'hase Code. _ ,Subcode T Comment ~ 06:45 07:00 0.25 7,728 7,728. PROD2 RIGMNT SVRG P Blow down top drive.. 07:00 07:15 0.25 7,728 7,728 PROD2 RIGMNT SVRG P Hang blocks for cutting and. slipping drillin line. 07:15 07:30 0.25 7,728 7,728 PROD2 RIGMNT SFTY P PJSM -cut & slip drilling line. 07:30 09:00 1.50 7,728 7,728 PROD2 RIGMNT SVRG- P Cut and slip 8T of drilling line.. Unhan blocks. 09:00 09:30 0.50 7,728 7,853 PROD2 DRILL TRIP P Trip in hole on elevators. Wash and ream last 13' to bottom. Pump 320 gpm / 3180 psi, rotating 40 rpm, torque 8k ft lbs. PU wt 155k, SO wt 110k, rotatin wY122k. 09:30 10:15 0.75 7,853 7,918 ' PROD2 DRILL DDRL P Drilling A3 lateral 10:15 11:00 0.75 7,918 .7,800 PROD2 DRILL CIRC P Pull up inside casing and get ECD baseline. 320 gpm 3200 psi 80 rpm 11.34 PP9e 320 gpm 3200 psi 1.10 rpm 11.46 PP9e 280 gpm 2460 psi SO rpm 11.05 PP9e 280 gpm 2460 psi 110 rpm 11.17 e 11:00 12:00 1.00 7,918 7,920 FROD2 DRILL DDRL P Drilling A3 lateral. Experienced high torque stalling topdrive 7918' - 7924'. Noted that stabilizer was on whi stock slide Burin this eriod. 12:00 16:45 4.75 7,920 8,252 PROD2 DRILL DDRL P Drillirg A3 lateral.-Pump kicked off. Found 1 degree of iriclination more than fanned. 16:45 17:00 A.25 8,252 8;235 PROD2 STK KOST T Turn pumps back on and pick up to trou h. 17:00 20:45 3.75 8,235 8,252 PROD2 STK KOST T Troughing to reduce hole angle 20:45 00:00 3.25 8,252 8;669 PROD2 DRILL DDRL P Resume drilling A3 lateral 4/17/2008 Drilling A3 lateral. Max ECDs 12.16 and max gas 1121 units. 00:00 06:00 6.00 8,669 9,365 PROD2 DRILL DDRL P Drilling A3 lateral. 06:00 12:00 6.00 9,365 9,983 PROD2 DRILL DDRL- P Drilling A3 lateral. 12:00 18:00 6.00 9,983 10,530 PROD2 DRILL DDRL P Drilling A3 lateral. 18:00 00:00 6.00 10,530 11,277 PROD2 DRILL DDRL P Drilling A3 IateraL 4/18/2008 Drilled A3 lateral to TD, 13102' MD / 3847' TVD. Circulated 30 bbl sweep around and began backreaming at 4 stands er hour after swee returned to surface. 00:00 01:30 1.50 11,277 11,392 PROD2 DRILL DDRL P Drilling A3 IateraL 01:30 02:30 1.00 11,392 11,298 PROD2 DRILL CIRC P Observed increase in loss rate. Monitor well -static after 3 minutes. Check surface equipment - ok. Circulate bottoms up, pumping 320 m / 3580 si. Max as 481 units. 02:30 06:00 3.50 11,298 11,861 PROD2 DRILL DDRL P Drilling A3 lateral Page 29 of fiQ Time Low- - - -- - _. -- - -- -Date From To Dur S Depth E. De th Phase Code _ Subcode_ T Comment -06:00 12:00 6.00 11,861 12,504 PROD2 DRILL DDRL P Drilling A3 lateral 12:00 1:6:30 4:50 12,504 12,799 PROD2 DRILL DDRL P Drilling A3 lateral 16:30 17:30 1.00 12,799 12,799 PROD2 DRILL REAM P Backream at 2 fpm to clean hole and reduce ECDs. Pumping 300 gpm / 3410 psi. ECDs before 12.26 ppg, after 12.08 17:30 20:45 3.25 12,799 13,102 PROD2 DRILL DDRL P Drilled A3 lateral to TD. 20:45 22:30 1.75. 13,102 13,102 PROD2 DRILL CIRC P Obtain SPRs & Torque arid Drag data: Pump 30 bbl, 9.3 ppg, 250 vis sweep @ 290 gpm / 3230 psi, rotating 120 rpm. Observed 40% increase in cuttings when sweep returned. 22:30 22:45 0.25 13,102 13,079 PROD2 DRILL REAM P Backream and lay down single. Install stri in rubbers and air sli s. 22:45 00:00 1.25 13,079 12,891 PROD2 DRILL REAM P Back reamimg out of hole at 4 stands er hour. 4/19/2008 Backreamed until inside casing. Slowed rpms whit BHA across. whipstock. Circulated casing clean with 40 bbl swee and 4 bottoms u . 00:00 06:00 6.00 12,891 10,736 PROD2 DRILL REAM. P Continue backreaming out of hole @ 4 stands per hour. Stop and gist surve s as directed b DD. 06:00 .12:00 6.00 10,736 8,576. PROD2 DRILL REAM P Backreaming out of hole. 12:00 13:45 1.75 8,576 7,925 PROD2 DRILL REAM P Backreaming out of hole.. Slowed rotation to 40 rpm while pulling BHA across whi stock. 13:45 14:15. 0.50 7,925 7,728 PROD2 DRILL CIRC P Pump out of hole @ 320 gpm / 3050 psi. PU wt 170k, SO wt 110k. Calculated hole fill oh trip 29.7 bbls, actual fill 69:5-bbls, lost 39.8 bbls 14:15 16:30 2.25 7,728. 7,728 PROD2 DRILL CIRC P Circulate sweep to clearrcasing and total of 4.4 bottoms up. Pumping at 320 gpm / 3050 psi. Rotating 80 rpm, torque 61 ft Ibs, PU wt 170k, SO wt 110k, ECDs 11.16. Pumps off rotating wt 930k, torque'6k ft lbs. Observed 25% increase in cuttings return with sweep. ECDs at end of curculation 10.85 16:30 17:30 .1.00 7,728 7,728 PROD2 DRILL - OWFF P Monitor well -breathing. Static after 1 hour. Well returned 1.5 bbls. Sim ops, service blocks, crown, rou hneck and ins ect saver sub. 17:30 18:30 1.00 7;728 8,763 PROD2 DRILL TRIP P Trip in hole for swap to SFOBM. Lost down weight @ 8382'. MD, began washing & reaming in hole, Pumping 100 gpm, rotating 50 rpm, torque 7k ft lbs. 18:30 20:00 1.50 8,763 12,611 PROD2 DRILL TRIP P Tripping in hole on elevators. Monitor displacement via trip tank. Fill pipe every 25 stands, record torque and dra eve 10. Page 3tt of &#t Tirne Logs --- _ j Date From To Dur _S. Depth E.,De th Phase Code Subcode T Gon~n~ent .20:00 21:00 1.00 12,611 13.,102 PROD2 DRILL REAM P Wash and ream to TD. Pumping .100. gpm, rotating 50 rpm, torque 8k ft lbs. PU et 190k, SO wt 72k: 21:00 .23:45 2.75 13,102 13,019 PROD2 DRILL CIRC P' Circulate on bottom and-.pump 35 bbl, 9.3 ppg, 250 vis sweep. Pumping 300 gpm / 3580 psi, rotating 120 rpm, torque 9k ft lbs. Circulated total of 2.5 bottoms up. Observed 80% increase in cuttings returned with swee . 23:45 00:00 0.25 13,019 13,019 PROD2 DRILL CIRC P Begin displaceing well over to SFOBM, pumping @ 300 gpm / 3730 psi. 1074 strokes into displacement at midni ht. 4/20/2008 Displaced well over to SFOBM. Pulled 2 stands out of hole and hole not. takeing proper fill, breathing: Pumped out of hole stopping. to check for flow and attempting to pull on elevators. Pumped out to 8199' MD, shoe at 7833' MD. Pulled 30k over at 8267 MD, reamed hole and pulled on elevators. Layed down MWD and rigged u 4-1 /2" liner runnin tools. Ran in hole with liner and liner runnin tools. 00:00 01:15 1.25 13;019 13,102 PROD2 BRILL CIRC P Continue displaceirig well over to SFOBM. Pumping 310 gpm /3720 psi, rotating 120 rpm. PU wt 195k, SO wt 125k, torque 8k ft lbs. Overdisplaced 40 bbls. Torque with um s off 30 r m 8-9k ft lbs. 01:15 01:30 0.25 13;102 13,102 PROD2 .DRILL CIRC P Record slow pump rates and torque & dra data. 01`.30 01:45 0:25 13,102 13,102 PROD2 DRILL OWFF P Monitor well -breathing then static 01:45 02:00 0.25 13,102 12,894 PROD2 DRILL. TRIP P Lay down single and pull on elevators. Monitoring :weld via-trip. tank. Fluid level in stack not fallin . 02:00 06:00 4.00 12,894 9,608 PROD2 DRILL TRIP P Pump out of hole, 170. gpm / 107.0 psi. Attempt to pull on elevators every 5 stands. PU wt 200k, SO wt 72k. Monitoring hole fill via active s stem. 06:00 08:30 2.50 9,608 8,199 PROD2 DRILL TRIP P Continue pumping out of hole, 170 gpm 7 1020 psi. PU wt 2001cSo wt 90k. Monitoring well via active system. Observed 30k overpull at 8267 MD, slacked off, no down weight. Pull up to rotating wt 120k, washed and reamed down to 8296' MD, torque and pressure good. Backreamed to 8199' MD. Trip into-8296' MD, 90k SO wt. Pull out of hole 200k PU wt. .Dropped 1.90 rabbit on wire at 8670' MD 08:30 09:30 1.00 8,199 7,728 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitor well via trip tank. PU wt 170k SO wt 110k, rotating wt 130k, torque 7-9k ft Ibs 09:30 10:00 0.50 7,728 .7,728 PROD2 DRILL OWFF P Monitior well -falling. Clean rig floor. Page 31 of &0 TimeLo_ s_ __ ___ 9 - - - _ _ __ _. - _ ~ - T -- ~~ From To Dur S, p_e th E Depth Phase Code Subdode T_ Comment Date P 10:00 10:15 0.25 7,728 7,728 PROD2 DRILL TRIP P Blow down top drive; install stripping rubbers and air sli s. 10:15 14:30 4.25 7,728. 368... PROD2 DRILL TRIP P Pull out of hole on elevators," monitoring well via trip tank. PU wt 90k, SO wt 90k. Monitor well @ 4330' MD -static. Recorded weights every 10 stands on tri out of hole. 14:30 14:45 0.25 368 368 PROD2 DRILL OWFF P Monitor well -static. 14:45 15:30 0.75. 368 88 PROD2 DRILL TRIP P Pull and rack back HWDP, jars, bumber sub and flex collars. Lay down stabilizer and float sub. Recovered rabbit from to of float: 15:30 16:45: 1.25 88 88 PROD2 DRILL PULD P Download MWD, clear and clean rig .floor. 16:45 18:00 1.25 88 0 PROD2 DRILL PULD P Lay dowry BHA. 18:00 18:15 0.25 0 0 - COMPZ CASING RURD P Clear and clean rig floor. 18:15 19:15- 1.00 0 0 COMPZ CASING RURD P Pick up and rig up 4-1/2" liner handling equipment. Monitoring hole via tri tank. 19:15 19:30 0.25 0 0 COMPZ CASING SFTY P PJSM -running liner with GBR and Baker Oil Tools re s. 19:30 22:00 2.50 0 4,998 COMPZ CASING RUNL P Run 116 jdints of 4-1/2" liner. PU wt 110k, SO wt 100k. 22:00 22:45 0.75 4,998 5,069 COMPZ CASING RUNL P Run Plop &-Drop reciptacle joint and settin sleeve. '22:45 23:15 0:50 5,069 5,069 COMPZ CASING RURD P Rig down and Jay down liner. running tools, clear rig floor. Monitoring well via tri tank. 23:15 23:45 0:5.0 5,069 5,069 COMPZ CASING SFTY P Post job safety review. Recapping Iessonslearned. Monitoring well via tri tank. 23:45 00:00 0.25 5,069 5,069 COMPZ CASING SFTY P PJSM -tripping in hole withJiner on drill i e. 4/21 /2008 Run 4-1/2" A3 lateral "plop & drop" liner on drill pipe. Trip out of hole. Pick up, make up and run in hole with whi stock retrievin BHA. Attem t to latch whi stock. 00:00 01:15 1.25 5,069 7,710 COMPZ CASING RUNL P Trip in hole on elevators with liner on 4-1/2"drill pipe. Monitor displacement via. trip tank. PU wt 145k, SO wt 100k, rotating @ 30 m wt 115k for ue 4k ft lbs. 01:15 02:30 1.25 7,710 7,710 COMPZ RIGMNT SVRG P Change out saver sub on top drive. 02:30 05:45 2.75 7,710 13,D63 COMPZ CASING RUNL P Continue tripping in hole with liner on drill i e. 05:15 05:30 0.25 13,063 13,102 COMPZ CASING RUNL P Rotate in hole and tag bottom. PU wt 240k, So wt 75k, rotating 30 rpm wt 155k 05:30 06:00 .0.50 13,102 13,092 COMPZ CASING RUNL P PuII liner with elevators to 13063' MD, break stand and dro ball 06:00 06:15 0.25 13,092 13,092 COMPZ CASING CIRC P Pump ball down to release running - tool. Pumping 130 gpm / 650 psi. Ball on seat at 691 strokes. Pu wt 225k, SO wt 80k. Page 32 of 60 Time Log s ',,Date ._ From ?o Dur S. De^th E De th Phase Code Subcode T .Coy ~naont 06:15 07:00 0.75 .13,092 8,026 - COMPZ - CASING RUNL _ P _. - - -_. Pressure up to 2500 psi and slack off to 80K to release finer. Pick up to 225k; still have liner: Slack off to 140k'and pressureup to 3000 psi and pick up to 190k. Liner released. Pull up 20' and pressure up to 4000 _ psi to shear circulation sub. No shear. Rig up test pump and ressure u .Sheared at 4800 si. :07:00 07:15 0.25 8,026 7,976 COMPZ CASING OTHR P Pull out of hole and monitor well - static 07:15 12:00 4.75 7,976 440 COMPZ CASING RUNL P Pull out of hole on elevators. Monitoring. well via trip tank. Record ' wei hts eve 10 stands on tri out. 12:00 12:15 0.25 440 440 COMPZ CASING OTHR P Monitor well -static 12;15 12:30 0.25. 440 440 COMPZ CASING SFTY P PJSM -laying down liner running tools. 12:30 13:00 0.50 440 0 COMPZ CASING KURD P Lay down. liner running tools and clear ri floor. 13:00 13:30 0.50 0 0 COMPZ FISH PULD P Pick up tools for retrieving whipstock: 13:30 13:45 0:25 0 0 COMPZ FISH SFTY P PJSM -Making up whipstock retrieving BHA with Baker Fishing re . 13:45 15:45 2.00 0 130 COMPZ FISH PULD P Make up whipstock retrieving BHA includin MWD tools. 15:45 18:30 2.75 130. 7,290 COMPZ FISH TRIP P Trip in hole on elevators with whipstock retrieving BHA. Filling.. pipe every 25 stands. Shallow pulse test 600' MD - ood test. 18.30 19:00. 0.50 7,290 7,290 COMPZ FI$H CIRC P` Break circulation pumping 200 gpm / 1300 psi. Observed 155 units of gas. Circulated until O units. 19:00 19:45. 0.75 7,290. 7,820. COMPZ FISH TRIP P Continue trip in hole on elevators.with whipstock retrieving BHA. PU wt 170k, SO wt 129k. Orient toolface and run in to to of whi stock: 19:45 00:00 4.25. 7,820 7,820 COMPZ FISH WASH P Wash slot in whipstock face and attem f to latch into whi stock. 4/22/200$ Fished for and Hooked Whipstock; Jarred Whipstock Loose and Circulated Bottoms Up (No gas); Pulled Out-of-Hole f/ 7725' - 6827 MD; Hole Took 38 Bbls and Gave 21 Back (Breathing); Pumped Out-of-Hole f/ 6827 - 3623' MD; Pulled Out-of--Hole on Elevators f/-3623' - 0' MD; Layed Down Whipstock /MWD Assemblies; Picked Up and Made Up A3 liner Hook Hanger Assy; Initial MWD Shallow Test Failed; Chan ed Pulser Orifice; Checked Good; Ran Iri Hole w/ Hook Han er f/ 366' - 5270' MD 00:00 00:45 0.75 7,820 7,820 COMPZ FISH WASH P Continue to Hook Whipstock Slot per BOT Rep; P/U 190; S/O 129; 200 GPM. 1330 Psi 00:45 01:00 0.25 7,820 7;820 COMPZ FISH FISH P Latched Whipstock and Jarred Loose er BOT Re 01:00 01:15 '0.25 7,820 7,725 COMPZ FISH OTNR P Pull 1 Std & OWFF (Static) 01:.15 02:00 0.75 7,725 7,725 COMPZ FISH CIRC P CBU; 310 GPM @ 3130 Psi; No gas- 02:00 02:30 0:50 7,725 7,725 COMPZ FISH OTHR P OWFF -- Breathing; Flow Out 3% w/ Pumps Off, 6 BPH f/ First 10 Minutes, 1 BPH f/ 2nd 10 Minutes, Then Sto ed Static PacJe 33 of fi0 Time Lo s -- - _ ___ _ Comment Date From To Dur S. DeAth E De th Phase erode Subcode T _ 02:30. 04:30 2.00: 7,725 6,827 COMPZ FISH TRIP P POOH f/ 7725' - 682T MD; Monitor Fill on Trip Tank; Hole Took 38 Bbls on fill and Gave 21 Bbls BacKAfter Pumps. Shut Down; Total Loss 17 Bbls 04:30 . 05:00 0.50 6,827 6,827 COMPZ FISH CIRC P CBU; 310 GPM @ 2600 Psi; No Gas 05:00 05:15 0.25 .6,827 6,827... COMPZ FISH OTHR P OWFF -- Breathing 05:15 10:30. 5;25 6,827. 3,623 COMPZ FISH TRIP P Pump Out of Hole f/ 6827 -.'3623' MD;'168 GPM 610 Psi 10:30 13:00 2.50 3,623 240 COMPZ FISH TRIP P POOH. on Elevators f/ 3623' - 240' MD; Fill Pi a Eve 25 Stds 13:00 13:15 .0:25 '- 240 240 COMPZ FISH OTHR P Plug In & Turn Off MWD 13:15. 16:30 3:25 240 0 COMPZ FISH PULD P POOH w/ Whipstock Hook BHA; Break & UD Baker Hook Assy, Whipstock, Whipstock Subs, and MWD er Baker / S er Re s 16:30 17:00 0.50 0 0 COMPZ RPCOM RURD P Rig Up to Run Hook Hanger Assy; Closed Blind Rams 17:00 17:15 0.25 0 0 COMPZ RPCOM SFTY P PJSMforM/U Hook Hanger Assy. 17:15 -19:00 1.75 0 271 COMPZ RPCOM PULD P P/U & M/U Baker Hook Hanger Assy er BOT Re 19:00 19:30 0.50 271 271 COMPZ RPCOM DHEQ P Orient MWD /Hook Hanger &' M/U Hook Hanger to ECP BHA per MWD / BOT Re 19:30. 19'45 .0.25 271 366 COMPZ RPCOM DHEO P Change Elevators and RIH w/ 1 Std t/ 366' MD & Shallow Test MWD @ 100 GPM w/ 370 psi theh 120 GPM w/ 450. i; Weak Si' nal f/ Pulser .19:45 20:15 0.50 366 271 COMPZ RPCOM TRIP T Stand Back 1 -Stand & Unscrew Hook Han er f/ BHA 20:15 20:30- 0.25 271 271 COMPZ RPCOM DHEQ T ChangePulser Orifice f/ 1.6625" to 1.5625" 20:30 21:00 0.50. 271 366 COMPZ RPCOM DHEQ T Screw Hook Hanger Back into BHA and RIH w/ 1 Stand to 366' MD; Shallow Test Good @ 90 GPM w/ 470 si 21:00 21:15. 0.25 366 366 COMPZ' RIGMNI OTHR P Blowbown Top Drive 21:15 00:00 2.75 366 5,270 COMPZ RPCOM TRIP P RIH on Elevators w/ Hook Hanger Assy f/ 366' - 5270' MD; Run Speed 75 - 90 FPM; Record P/U & S/O Eve 10 Stds 4/23/2008 Continue to run in the hole w/ Hook Hanger assembly f/ 5270' to 8065' (1T above hook point), orient, obtain PU and SO wt's, Hook window with. indication of 39 deg right of highside, pickup, orient 180 deg, slack off 4' past hook point, pickup orient to 39 deg right, hook window, set dawn 40k on the hook (top of hook hanger @ 7818') (Window hooked @ 7835'), drop 1-3/4" ball pump down and inflate external casing packer w/ approx 8.4 gallons of mud, pull inner string from Hook Hanger, circulate bottom's. up, monitor well, pull out of hole (adjust Western Well Tools super sliders on 4"drill pipe), lay down running tools, PJSM, PU/MU/RIH w/ LEM assembly, tag up with LEM on top of Hook Hanger with indication of 21 deg right of highside, pickup 15k over to verify latchup, drop 1-3/4" ball, pump ball to seat, Set HR ZXP packer (top @ 7456'), test packer to 2900 -psi f/ 5 minutes (chart test), bleed off, lay down a jt of 4"drill pipe, monitor well-static, run into tag ZXP with dog sub on running tool to confirm depth (.73' deeper than Hook hanger tally-7456:76'), pull out of the hole with runnin tools to 7365' midni ht Page 34 of 60 Time Logs ___ _ Date` From To Dur S. De th E. De th Phase Cade Subcode T Comment 23:30 00:00 0.50 7,965 7,365 COMPZ RPCOM TRIP P Pull out of the hole with LEM running tools. Monitor displacement on the tri tank. 4/24/2008 Continue to pull out of the hole with LEM running tools from 7365' ,lay down LEM running tools, PU Whipstock assembly for the A4 lateral (1C-172A L2) (PROD 3), orient MWD with whipstock, shallow test MWD, trip in, MAD Pass seal depth 6694' to 6742' (Gamma depth 6515' to 6563'), continue trip in orient whipstock to 31 deg left of high side, set down 15k on the ZXP packer of the A3 lateral @ 7456.76', pickup 10k over pull to verify anchor set, shear bolt on whipstock/mills (Top of whipstock @ 7456.76'), displace well from 9.3 ppg SFOBM to 9.3 ppg OBM, acquire slow pump rates, milling window from top of window @ 7357' to starter mill depth of 7377' at midnight. Note: To of window 7357.27', bottom of window 7371'. 00:00 03:00 3.00 7,365 0 COMPZ RPCOM TRIP P POOH w/ LEM running tools f/ 7365' - 0' MD; Monitor Hole on Trip Tank; Hole Took Pro er Fill 03:00 03:45 0.75 0 0 COMPZ RPCOM PULD P UD LEM Running Tools &MWD 03:45 04:00 0.25 0 0 COMPZ RPCOM OTHR P Clean & Clear Rig Floor of LEM Tools 04:00 04:30 0.50 0 0 PROD3 STK OTHR P P / U Whipstock Tools f/ A4 Lateral & Brin to Ri Floor 04:30 07:00 2.50 0 207 PROD3 STK PULD P M/U A4 Lateral Whipstock Assy & MWD. Orient whi stock to MWD. 07:00 07:45 0.75 207 207 PROD3 STK OTHR P Install MWD Pulser Spacer and U load MWD Software 07:45 08:15 0.50 207 302 PROD3 STK OTHR P P/U 1 Stand & Shallow Test MWD 250 GPM w/ 730 si; Good 08:15 11:00 2.75 302 6,694 PROD3 STK TRIP P RIH w/ Whipstock BHA f/ 302' - 6694' MD. Fill pipe every 25 stands (2463' & 4825' . 11:00 11:45 0.75 6,694 6,742 PROD3 STK OTHR P MAD Pass f! 6694' - 6742' MD of seals (Gamma at Depth of 6515' - 6563' MD); Circulated @ 220 GPM / 1550 psi During Pass. Travel speed of 3'/min. 11:45 13:30 1.75 6,742 7,457 PROD3 STK TRIP P RIH w/ Whipstock BHA f/ 6742' - 7456.76' MD; Orient Whipstock Slide to 31 Degrees Left; Tagged Top of ZXP on Depth @ 7456.76. PU wt 165k, SO wt 125k 13:30 13:45 0.25 7,457 7,357 PROD3 STK OTHR P Set Whipstock: Set Anchor by Setting 15K Down Weight on BHA; Verified Anchor Set by P/U 10K Overpull; Attempt to Shear Milling Assy Bolt by setting 40K Down - BoltSheared; Then Find Free Point (138k), apply 10K ft Ibs of right hand torque --Mills Free; TOW at 7357.27' MD; 13:45 14:45 1.00 7,357 7,357 PROD3 STK CIRC P Displace Wellbore f/ 9.3 ppg SFOBM to 9.3 ppg OBM, pumping 317 GPM w/ 2850 si. 14:45 15:00 0.25 7,357 7,357 PROD3 STK CIRC P Obtain slow pump rates prior to millin window. 15:00 18:00 3.00 7,357 7,365 PROD3 STK WPST P Milling 6 3/4" Window for A4 Lateral f/ 7357' - 7365'. Pumping 300 gpm w/ 2280 psi. Rotate 110 rpm w/ 5-8k ft Ibs of for ue. ~aqe .~7 of 84 Time Logs __ _ _ ~Date__ From To Dur___ S. Depth E De th Phase Code Subcode T Comment __ 00:00 02:30 2.50 5,270 7,980 COMPZ RPCOM TRIP P Continue TIH w/ Hook Hanger f/ 5270' - 7980' MD; Above the top of window 7820', P/U 185, S/O 135 02:30 04:15 1.75 7,980 8,082 COMPZ RPCOM TRIP P P/U Single and then Last Stand (#83); Pumping 102 GPM @ 960 psi; Obtain MWD Tool Face Position; Position Hanger at 4 Right with hook hanger 17' above hook point (8065' mule shoe depth), slack off and MWD showed 39 Deg Right when hooked & Set 30K Down on Hook; Pickup with 30k overpull, rotate 180 deg, work torque, then slackoff 4' past where window had hooked, Picked up, oriented to 39 right, worked torque, set back down and hooked window at same depth (7835'), with same MWD indication of 39 deg right of highside. Set down 40k on the hook. Top of Hanger @ 7818' MD, Hooked Window @ 7835' MD; Mule Shoe @ 8082' MD; P/U 195, S/O 135 04:15 05:15 1.00 7,980 8,082 COMPZ RPCOM OTHR P Drop 1-3/4" Ball; Pumped Down @ 24 SPM w! 950 psi for 500 strokes, then slow pumps to .5 bpm w/ 270 si. Ball On Seat 597 Strokes. 05:15 05:30 0.25 8,082 8,082 COMPZ RPCOM PACK P Set 40k on hook hanger, then Inflate ECP per BOT Rep; Pressure Up t/ 1500 & Hold 1 Min; then 2300 psi to Shear Bolts; Pressure Bled Off; Pressure Up t/ 2800psi 3 Times, Bled to 2000 psi, Pressure Up to 3000 psi to Verify Inflation. Appears to take 2 strokes to inflate ECP (8.4 allons). 05:30 05:45 0.25 8,082 7,615 COMPZ RPCOM TRIP P Pull Inner String Out of Hook Hanger and POOH f/ 8082' - 7615' MD 05:45 06:30 0.75 7,615 7,615 COMPZ RPCOM CIRC P Circulate bottom's up- pumping 400 GPM w/ 3000 si 06:30 06:45 0.25 7,615 7,615 COMPZ RPCOM OWFF P OWFF -- Breathing then Static. Blow down top drive, install air slips and the stri in rubbers. 06:45 14:15 7.50 7,615 0 COMPZ RPCOM TRIP P POOH f/ 7615' - 0' MD; Adjust Western Well Tools 4" Super Sliders on DP while Tripping out ; UD Slim MWD and Hook Hanger Inner String. Calculated displacement 55.67 bbls, actual 61 bbls, loss of 5.33 bbls. 14:15 14:45 0.50 0 0 COMPZ RPCOM RURD P Clean & Clear Rig Floor; Rig Up to Run LEM, SBE, and ZXP Packer per BOT Re 14:45 15:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Running LEM, SBE, & ZXP Packer Ass 15:00 16:45 1.75 0 518 COMPZ RPCOM RCST P Make up the LEM assembly, orient with S er Sun slimhole MWD. Pale 3~ of 6~ i ~ d Time Logs Date_ From To Dur S De th E. De th Phase __ Code Subcode __ T _ Comment 16:45 18:00 1.25 518 3,539 C©MPZ RPCOM TRIP P Trip in the hole with the LEM from 518' to 3539'. Monitor well on the trip tank. Shallow pulse tested MWD @ 608', pumping 100 gpm w/ 580 psi, OK. 18:00 20:30 2.50 3,539 7,772 COMPZ RPCOM TRIP P Continue to trip in the hole with the LEM from 3539' to 7772'. Monitor well on the trip tank. Record PU and SO wt's per Rig Engineer. Obtain PU wt of 180k and SO wt of 130k while 46' above the to of the hook han er. 20:30 21:00 0.50 7,772 7,953 COMPZ RPCOM TRIP P While pumping 105 gpm w/ 1000 psi, orientation of 16 Right of highside, slackoff and pass through the top of the Hook Hanger @ 7818' to LEM assembl seals de th of 7953'. 21:00 21:30 0.50 7,953 7,965 COMPZ RPCOM TRIP P Pickup a single of 4" drill pipe and make a top drive connection. Rig up chart recorder. Pumping 105 gpm w/ 1000 psi. MWD indication of 13 right. Slack off and index LEM into the Hook hanger with MWD indication of 21 Right of highside. Set 30k down on Hook Hanger. Pickup 15k over (195k) to verify LEM installed. Depth of seals 7965.54' (.73' deep to the hook han er tall 21:30 22:00 0.50 7,965 7,965 COMPZ RPCOM CIRC P Drop a 1-3/4" ball, pump ball down by pumping 103 gpm w/ 1000 psi, slowed to 65 gpm with 560 psi after pumping 500 strokes. Ball on seat with 566 strokes um ed. 22:00 22:15 0.25 7,965 7,965 COMPZ RPCOM OTHR P Set Baker HR ZXP packer: Pressure to 2000 psi, hold, then increase to 3400 psi to activate pusher tool for setting ZXP, hold, then pressure to 4000 psi to neutralize the pusher tool. Bleed off ressure. Picku 1'. 22:15 22:45 0.50 7,965 7,965 COMPZ RPCOM DHEQ P Test ZXP packer. Break top drive from drill pipe (drill pipe open to atmoshere). Pump into kill line with the top pipe rams closed. Pumped a total of 34 strokes to pressure up to approx 3000 psi. Shut in pump. Hold 2900 psi for 5 min., chart test. Good test. Bleed off pressure. Open top i e rams. 22:45 23:00 0.25 7,965 7,861 COMPZ RPCOM TRIP P Lay down single of 4"drill pipe. Stand back stand #79. Blow down the to drive and kill line. 23:00 23:15 0.25 7,861 7,861 COMPZ RPCOM OWFF P Observe well for flow. Static. 23:15 23:30 0.25 7,861 7,965 COMPZ RPCOM TRIP P Run in the hole to reconfirm depth of ZXP packer with the dog sub on the running tool. Tagged top of ZXP packer @ 7456.76', (seals of LEM assembl 7965.54' . ' ~ ~€~~ 3~ caf bit ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 C Pad 1 C-172AL2 50-029-23159-61 :~ ~ •rr ~ _ 'T ~ "yj ~yyM.s ~ ~ x . f O .. _, ~f t.y :J Definitive Survey Report 03 June, 2008 ..~.~.. ',a' : ..' ~~r. ,,;~. '~z~r Sperry C'~rilling Ser-vices ~: ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1C Pad Wel I: 1 C-172 Wel I bore: 1 C-172AL2 Design: 1 C-172AL2 Local Co-ordinate Reference: We111C-172 TVD Reference: 1C-172A @ 100.50ft (Doyon 15) MD Reference: 1C-172A @ 100.50ft (Doyon 15) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Kuparuk River Unit, North Slope Alaska 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 Iii Well 1C-172 - Well Position +N/S 0.00 ft Northing: 5,968,801.43 ft Latitude: 70° 19' 31.051 N +E/-W 0.00 ft Easting: 562,101.96 ft Longitude: 149° 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 59.10ft Wellbore 1C-172A.L2 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 5/6/2008 17.88 79.77 57,285 BGGM2007 3/29/2008 17.93 79.77 57,280 ----- Design 1C-172AL2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,079.07 Vertical Section: Depth From (TVD} +W-S +E/-W Direction (ft) (ft) (ft) (°) ~~ 41.40 0.00 0.00 180.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 158.30 279.40 1C-172 Gyro (atdb) (1G172) CB-GYRO-SS Camera based gyro single shot 11/11/2004 403.29 3,452.05 1C-172 (1C-172) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2004 ' 3,513.00 7,312.291G172A MWD+SAG+CA+IIFR+MS (1G MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2008 12: 7,357.00 9,877.661C-172AL2P61 MWD+SAG+CA+IIFR+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/21/2008 1: 9,890.00 12,079.07 1C-172AL2P62 MWD+SAG+CA+IIFR+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2008 1: 12,100.00 12,954.93 1C-172AL2 MWD+SAG+CA+IIFR+MS (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/6/2008 12: it Survey ~ i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +FJ-W Northing Easting DL5 Section i (ft) (°) (°) (ft) (ft) (ft) (ft) Iftl (ft) (°1100') (ft) Survey Tool Name 41.40 0.00 0.00 41.40 -59.1U 0.00 0.00 5,968,801.43 562,101.96 0.00 0.00 UNDEFINED 158.30 0.16 315.00 158.30 57.80 0.12 -0.12 5,968,801.54 562,101.84 0.14 -0.12 CB-GYRO-SS (1) 279.30 1.25 26.00 279.29 178.79 1.42 0.34 5,968,802.85 562,102.29 1.00 -1.42 CB-GYRO-SS (1) 403.29 2.39 36.29 403.22 302.72 4.72 2.47 5,968,806.17 562,104.39 0.95 -4.72 MWD+IFR-AK-CAZ-SC (2) 492.25 2.61 30.94 492.09 391.59 7.95 4.61 5,968,809.42 562,106.50 0.36 -7.95 MWD+IFR-AK-CAZ-SC (2) 582.80 4.26 27.22 582.48 481.98 12.71 7.20 5,968,814.20 562,109.06 1.84 -12.71 MWD+IFR-AK-CAZ-SC (2) 672.63 5.90 24.61 671.95 571.45 19.88 10.65 5,968,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 763.75 8.53 18.02 762.34 661.84 30.56 14.70 5,968,832.11 562,116.40 3.02 -30.56 MWD+IFR-AK-CAZ-SC (2) 853.71 11.70 14.76 850.89 750.39 45.73 19.08 5,968,847.31 562,120.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) 6/32008 2:31:55PM Page 2 COMPASS 2003. i6 Build 42F ConocoP hillips Defi nitive Survey Report Company: Con ocoPhillips(Alaska) I nC. Local Co-ordinate Reference: We11 1C-172 Project: Kuparuk River Unit ND Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Refere nce: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2 Survey Ca lculation Method: Minimum Curvature Design: 1C-172AL2 Database: CPAI EDM Production Survey --- --- Map Map Vertical MD Inc AZI ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) Ift) (ft) Ift) lftl (ft) (ft) (° /100') (ft) Survey Tool Name 944.17 12.10 10.82 939.31 833.81 64.37 23.29 5,968,865.98 562,124.71 1.44 -64.37 MWD+IFR-AK-Cr1Z-SG (2) 1,033.78 15.64 1.05 1,026.20 925.70 86.13 25.36 5,968,887.76 562,126.60 4.22 -86.13 MWD+IFR-AK-CAZ-SC (2) 1,128.53 19.91 351.25 1,116.42 1,015.92 114.86 23.14 5,968,916.47 562,124.14 5.49 -114.86 MWD+IFR-AK-CAZ-SC (2) 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 16.65 5,968,949.00 562,117.39 2.42 -147.46 MWD+IFR-AK-CAZ-SC (2) 1,315.26 21.18 341.57 1,290.78 1,190.28 179.74 7.40 5,968,981.21 562,107.87 1.92 -179.74 MWD+IFR-AK-CAZ-SC (2) 1,407.39 26.12 338.05 1,375.15 1,274.65 214.36 -5.45 5,969,015.72 562,094.74 5.57 -214.36 MWD+IFR-AK-CAZ-SC (2) 1,502.67 33.63 335.74 1,457.71 1,357.21 257.94 -24.16 5,969,059.13 562,075.67 7.97 -257.94 MWD+IFR-AK-CAZ-SC (2) 1,594.46 35.67 335.01 1,533.22 1,432.72 305.37 -45.91 5,969,106.38 562,053.53 2.27 -305.37 MWD+IFR-AK-CAZ-SC (2) 1,687.13 40.07 334.38 1,606.35 1,505.85 356.78 -70.23 5,969,157.58 562,028.78 4.77 -356.78 MWD+IFR-AK-CAZ-SC (2) 1,780.29 44.74 331.67 1,675.13 1,574.63 412.71 -98.78 5,969,213.27 561,999.78 5.38 -412.71 MWD+IFR-AK-CAZ-SC (2) 1,873.69 50.50 330.33 1,738.06 1,637.56 473.01 -132.24 5,969,273.28 561,965.82 6.26 -473.01 MWD+IFR-AK-CAZ-SC (2) 1,965.93 53.61 328.47 1,794.77 1,694.27 535.60 -169.28 5,969,335.55 561,928.27 3.73 -535.60 MWD+IFR-AK-CAZ-SC (2) 2,058.38 56.75 326.71 1,847.56 1,747.06 599.65 -209.97 5,969,399.26 561,887.05 3.74 -599.65 MWD+IFR-AK-CAZ-SC (2} 2,151.37 66.46 324.51 1,891.73 1,791.23 667.02 -256.18 5,969,466.25 561,840.30 10.65 -667.02 MWD+IFR-AK-CAZ-SC (2) 2,243.98 67.44 325.15 1,927.99 1,827.49 736.68 -305.26 5,969,535.49 561,790.64 1.23 -736.68 MWD+IFR-AK-CAZ-SC (2) 2,337.06 66.78 325.57 1,964.20 1,863.70 807.23 -354.00 5,969,605.63 561,741.32 0.82 -807.23 MWD+IFR-AK-CAZ-SC (2) 2,429.62 66.75 326.52 2,000.71 1,900.21 877.78 -401.51 5,969,675.77 561,693.24 0.94 -877.78 MWD+IFR-AK-CAZ-SC (2) 2,522.51 64.45 324.33 2,039.09 1,938.59 947.43 -449.49 5,969,745.02 561,644.68 3.28 -947.43 MWD+IFR-AK-CAZ-SC (2) 2,616.50 63.51 323.94 2,080.32 1,979.82 1,015.88 -498.98 5,969,813.05 561,594.64 1.07 -1,015.88 MWD+IFR-AK-CAZ-SC (2) 2,708.50 62.50 324.15 2,122.08 2,021.58 1,082.24 -547.11 5,969,879.00 561,545.97 1.12 -1,082.24 MWD+IFR-AK-CAZ-SC (2) 2,802.18 64.21 323.38 2,164.09 2,063.59 1,149.77 -596.60 5,969,946.11 561,495.92 1.97 -1,149.77 MWD+IFR-AK-CAZ-SC (2) 2,894.33 67.26 323.39 2,201.95 2,101.45 1,217.19 -646.70 5,970,013.11 561,445.27 3.31 -1,217.19 MWD+IFR-AK-CAZ-SC (2) 2,986.94 68.00 324.42 2,237.20 2,136.70 1,286.39 -697.15 5,970,081.88 561,394.25 1.30 -1,286.39 MWD+IFR-AK-CAZ-SC (2) 3,079.87 66.03 320.60 2,273.50 2,173.00 1,354.27 -749.19 5,970,149.32 561,341.66 4.34 -1,354.27 MWD+IFR-AK-CAZ-SC (2) 3,172.58 66.09 321.65 2,311.12 2,210.62 1,420.23 -802.37 5,970,214.84 561,287.94 1.04 -1,420.23 MWD+IFR-AK-CAZ-SC (2) 3,265.42 65.93 322.72 2,348.87 2,248.37 1,487.24 -854.37 5,970,281.40 561,235.39 1.07 -1,487.24 MWD+IFR-AK-CAZ-SC (2) 3,358.70 66.16 323.91 2,386.74 2,286.24 1,555.60 -905.30 5,970,349.33 561,183.90 1.19 -1,555.60 MWD+IFR-AK-CAZ-SC (2) 3,452.05 66.32 323.79 2,424.35 2,323.85 1,624.59 -955.70 5,970,417.90 561,132.94 0.21 -1,624.59 MWD+IFR-AK-CAZ-SC (2) 3,513.00 67.04 321.07 2,448.48 2,347.98 1,668.94 -989.82 5,970,461.96 561,098.45 4.26 -1,668.94 MWD+IFR-AK-CAZ-SC (3) 3,585.84 64.84 325.52 2,478.19 2,377.69 1,722.23 -1,029.58 5,970,514.92 561,058.26 6.34 -1,722.23 MWD+IFR-AK-CAZ-SC (3) 3,617.05 65.36 327.47 2,491.33 2,390.83 1,745.84 -1,045.21 5,970,538.39 561,042.44 5.91 -1,745.84 MWD+IFR-AK-CAZ-SC (3) 3,649.50 65.28 328.01 2,504.88 2,404.38 1,770.77 -1,060.94 5,970,563.19 561,026.50 1.53 -1,770.77 MWD+IFR-AK-CAZ-SC (3) 3,695.80 66.04 327.17 2,523.96 2,423.46 1,806.38 -1,083.55 5,970,598.61 561,003.60 2.33 -1,806.38 MWD+IFR-AK-CAZ-SC (3) 3,744.69 65.69 327.41 2,543.95 2,443.45 1,843.92 -1,107.66 5,970,635.95 560,979.18 0.84 -1,843.92 MWD+IFR-AK-CAZ-SC (3) 3,792.85 67.28 327.08 2,563.17 2,462.67 1,881.06 -1,131.56 5,970,672.88 560,954.98 3.36 -1,881.06 MWD+IFR-AK-CAZ-SC (3) 3,840.82 66.20 327.01 2,582.11 2,481.61 1,918.04 -1,155.53 5,970,709.66 560,930.71 2.26 -1,918.04 MWD+IFR-AK-CAZ-SC (3) 3,883.87 66.07 326.56 2,599.53 2,499.03 1,950.98 -1,177.10 5,970,742.41 560,908.87 1.00 -1,950.98 MWD+IFR-AK-CAZ-SC (3) 3,935.75 67.35 324.51 2,620.04 2,519.54 1,990.26 -1,204.06 5,970,781.47 560,881.58 4.39 -1,990.26 MWD+IFR-AK-CAZ-SC (3) 3,982.32 68.29 324.70 2,637.63 2,537.13 2,025.41 -1,229.04 5,970,816.41 560,856.32 2.05 -2,025.41 MWD+IFR-AK-CAZ-SC (3) 4,030.80 68.76 323.33 2,655.37 2,554.87 2,061.92 -1,255.55 5,970,852.69 560,829.51 2.80 -2,061.92 MWD+IFR-AK-CAZ-SC (3) &/3/2008 2:31:55PM Page 3 COMPASS 2003. i6 Buifd 42F ConocoPhillips Definitive Survey Report Company: ConocoPhiflips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit ND Reference: 1 C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Refere nce: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2 Survey Ca lculation Meth od: Minimum Curvature Design: 1C-172AL2 Database: - CPA I EDM Production .Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) {ft) (ft) (°/100') (ft) Survey Tool Name 4,080.64 68.81 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 560,601.34 0.68 -2,099.09 MWD+IFR-Ah-CAZ-SC (3) ~ 4,125.49 68.28 323.84 2,689.81 2,589.31 2,132.61 -1,308.30 5,970,922.93 560,776.18 2.16 -2,132.61 MWD+IFR-AK-CAZ-SC (3) I 4,175.33 67.30 325.15 2,708.65 2,608.15 2,170.17 -1,335.10 5,970,960.27 560,749.08 3.13 -2,170.17 MWD+IFR-AK-CAZ-SC (3) 4,220.69 66.91 328.35 2,726.31 2,625.81 2,205.11 -1,358.01 5,970,995.01 560,725.88 6.56 -2,205.11 MWD+IFR-AK-CAZ-SC (3) 4,273.07 67.39 327.31 2,746.65 2,646.15 2,245.96 -1,383.71 5,971,035.65 560,699.85 2.05 -2,245.96 MWD+IFR-AK-CAZ-SC (3) 4,315.29 67.35 326.13 2,762.89 2,662.39 2,278.54 -1,405.09 5,971,068.05 560,678.20 2.58 -2,278.54 MWD+IFR-AK-CAZ-SC (3) 4,360.35 67.02 324.56 2,780.37 2,679.87 2,312.71 -1,428.71 5,971,102.01 560,654.30 3.29 -2,312.71 MWD+IFR-AK-CAZ-SC (3) 4,409.23 67.34 323.59 2,799.32 2,698.82 2,349.19 -1,455.14 5,971,138.27 560,627.57 1.94 -2,349.19 MWD+IFR-AK-CAZ-SC (3) 4,457.69 67.78 323.19 2,817.82 2,717.32 2,385.14 -1,481.85 5,971,174.00 560,600.56 1.19 -2,385.14 MWD+IFR-AK-CAZ-SC (3) 4,506.21 68.87 323.19 2,835.74 2,735.24 2,421.24 -1,508.87 5,971,209.87 560,573.25 2.25 -2,421.24 MWD+IFR-AK-CAZ-SC (3) 4,551.46 68.80 321.91 2,852.08 2,751.58 2,454.74 -1,534.52 5,971,243.15 560,547.32 2.64 -2,454.74 MWD+IFR-AK-CAZ-SC (3) 4,601.20 68.93 320.38 2,870.02 2,769.52 2,490.87 -1,563.63 5,971,279.04 560,517.92 2.88 -2,490.87 MWD+IFR-AK-CAZ-SC (3) 4,652.27 68.66 317.69 2,888.49 2,787.99 2,526.82 -1,594.84 5,971,314.72 560,486.42 4.94 -2,526.82 MWD+IFR-AK-CAZ-SC (3) 4,695.93 67.82 314.97 2,904.68 2,804.18 2,556.15 -1,622.83 5,971,343.81 560,458.18 6.10 -2,556.15 MWD+IFR-AK-CAZ-SC (3) 4,741.75 66.56 312.96 2,922.44 2,821.94 2,585.47 -1,653.23 5,971,372.88 560,427.55 4.89 -2,585.47 MWD+IFR-AK-CAZ-SC (3) 4,791.17 65.32 309.76 2,942.60 2,842.10 2,615.29 -1,687.09 5,971,402.41 560,393.45 6.42 -2,615.29 MWD+IFR-AK-CAZ-SC (3) 4,837.62 65.20 307.28 2,962.04 2,861.54 2,641.56 -1,720.09 5,971,428.41 560,360.23 4.86 i -2,641.56 MWD+IFR-AK-CAZ-SC (3) 4,885.47 65.86 304.28 2,981.86 2,881.36 2,667.01 -1,755.42 5,971,453.57 560,324.70 5.87 -2,667.01 MWD+IFR-AK-CAZ-SC (3) 4,931.69 66.66 302.49 3,000.47 2,899.97 2,690.29 -1,790.75 5,971,476.55 560,289.18 3.94 -2,690.29 MWD+IFR-AK-CAZ-SC (3) 4,979.93 66.49 300.50 3,019.65 2,919.15 2,713.41 -1,828.49 5,971,499.36 560,251.26 3.80 -2,713.41 MWD+IFR-AK-CAZ-SC (3) 5,026.88 66.90 298.16 3,038.23 2,937.73 2,734.53 -1,866.08 5,971,520.17 560,213.50 4.66 -2,734.53 MWD+IFR-AK-CAZ-SC (3) 5,075.65 67.48 296.20 3,057.13 2,956.63 2,755.07 -1,906.07 5,971,540.36 560,173.34 3.89 -2,755.07 MWD+IFR-AK-CAZ-SC (3) ~ 5,122.83 66.43 292.82 3,075.61 2,975.11 2,773.08 -1,945.56 5,971,558.05 560,133.71 6.96 -2,773.08 MWD+IFR-AK-CAZ-SC (3) 5,171.43 66.15 290.26 3,095.15 2,994.65 2,789.41 -1,986.94 5,971,574.04 560,092.19 4.86 -2,789.41 MWD+IFR-AK-CAZ-SC (3) 5,218.47 66.25 287.55 3,114.14 3,013.64 2,803.36 -2,027.66 5,971,587.64 560,051.37 5.28 -2,803.36 MWD+IFR-AK-CAZ-SC (3) 5,267.44 67.09 285.02 3,133.53 3,033.03 2,815.96 -2,070.81 5,971,599.89 560,008.11 5.04 -2,815.96 MWD+IFR-AK-CAZ-SC (3) 5,312.08 67.20 282.82 3,150.87 3,050.37 2,825.86 -2,110.74 5,971,609.45 559,968.11 4.55 -2,825.86 MWD+IFR-AK-CAZ-SC (3) 5,361.27 66.28 279.48 3,170.30 3,069.80 2,834.60 -2,155.07 5,971,617.83 559,923.71 6.51 -2,834.60 MWD+IFR-AK-CAZ-SC (3) 5,412.46 66.84 275.53 3,190.67 3,090.17 2,840.73 -2,201.62 5,971,623.57 559,877.12 7.16 -2,840.73 MWD+IFR-AK-CAZ-SC (3) 5,457.39 66.76 273.44 3,208.37 3,107.87 2,843.96 -2,242.79 5,971,626.46 559,835.93. 4.28 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 5,512.09 67.69 270.51 3,229.55 3,129.05 2,845.69 -2,293.18 5,971,627.77 559,785.52 5.22 -2,845.69 MWD+IFR-AK-CAZ-SC (3) 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,627.07 559,748.35 5.19 -2,845.30 MWD+IFR-AK-CAZ-SC (3) 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,624.22 559,702.54 5.37 -2,842.82 MWD+IFR-AK-CAZ-SC (3) 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,619.84 559,661.20 4.55 -2,838.78 MWD+IFR-AK-CAZ-SC (3) 5,696.76 66.30 261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,613.53 559,616.72 3.38 -2,832.85 MWD+IFR-AK-CAZ-SC (3) 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,606.05 559,575.01 4.90 -2,825.70 MWD+IFR-AK-CAZ-SC (3) 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 559,532.36 6.07 -2,816.23 MWD+IFR-AK-CAZ-SC (3) 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,584.50 559,490.72 4.59 -2,804.86 MWD+IFR-AK-CAZ-SC (3) 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 559,447.91 6.88 -2,790.79 MWD+IFR-AK-CAZ-SC (3) 5,933.84 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,971,554.19 559,407.88 5.40 -2,775.22 MWD+IFR-AK-CAZ-SC (3) 6/3/2008 2:31:55PM Page 4 COMPASS 2003.16 Build 42F ConocoP hillips Defi nitive Survey Report Company: Con ocoPhillips(Alaska) Inc. .Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1G172AL2 Survey Ca lculation Met hod: Minimum Curvature Design: 1C-172AL2 Database: CPAI EDM Production ',Survey i ~~ Map Map Vertical MD Inc Azl TVD TVDSS +N/S +E/-W Northing Easting DLS Section '~ Ift) (~) (~) lft) (ft) (ft) lft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,978.50 67.04 245.10 3,413.51 3,313.01 2,758.63 -2,109.25 5,971,537.28 559,370.24 5.39 -2,i.~3.63 MWD+IFR-AK-CAZ-SG (?.) 6,028.43 66.58 242.95 3,433.18 3,332.68 2,738.53 -2,750.50 5,971,516.84 559,329.15 4.06 -2,738.53 MWD+IFR-AK-CAZ-SC (3) 6,074.69 67.49 240.86 3,451.23 3,350.73 2,718.47 -2,788.07 5,971,496.48 559,291.75 4.60 -2,718.47 MWD+IFR-AK-CAZ-SC (3) 6,123.77 67.64 238.03 3,469.96 3,369.46 2,695.41 -2,827.13 5,971,473.10 559,252.89 5.34 -2,695.41 MWD+IFR-AK-CAZ-SC (3) 6,169.08 66.75 235.65 3,487.52 3,387.02 2,672.57 -2,862.10 5,971,449.97 559,218.12 5.23 -2,672.57 MWD+IFR-AK-CAZ-SC (3) 6,218.69 67.03 233.61 3,507.00 3,406.50 2,646.16 -2,899.30 5,971,423.25 559,181.14 3.82 -2,646.16 MWD+IFR-AK-CAZ-SC (3) 6,267.43 67.88 230.95 3,525.69 3,425.19 2,618.62 -2,934.90 5,971,395.42 559,145.77 5.33 -2,618.62 MWD+IFR-AK-CAZ-SC (3) 6,314.03 66.91 229.11 3,543.60 3,443.10 2,590.99 -2,967.87 5,971,367.52 559,113.03 4.20 -2,590.99 MWD+IFR-AK-CAZ-SC (3) 6,358.62 66.68 226.98 3,561.17 3,460.67 2,563.59 -2,998.35 5,971,339.88 559,082.79 4.42 -2,563.59 MWD+IFR-AK-CAZ-SC (3) 6,409.08 66.96 224.00 3,581.04 3,480.54 2,531.08 -3,031.42 5,971,307.09 559,049.99 5.46 -2,531.08 MWD+IFR-AK-CAZ-SC (3) 6,455.79 66.97 221.59 3,599.32 3,498.82 2,499.54 -3,060.62 5,971,275.31 559,021.05 4.75 -2,499.54 MWD+IFR-AK-CAZ-SC (3) 6,505.16 67.34 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 558,992.00 5.37 -2,464.77 MWD+IFR-AK-CAZ-SC (3) 6,551.22 66.83 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 558,966.37 4.48 -2,431.19 MWD+IFR-AK-CAZ-SC (3) 6,599.24 66.93 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 558,941.23 5.33 -2,395.09 MWD+IFR-AK-CAZ-SC (3) 6,650.05 68.21 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 558,916.38 5.57 -2,355.45 MWD+IFR-AK-CAZ-SC (3) 6,696.47 67.69 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 558,895.30 5.08 -2,318.13 MWD+IFR-AK-CAZ-SC (3) 6,750.16 68.65 204.63 3,712.07 3,611.57 2,273.58 -3,210.20 5,971,048.15 558,873.36 7.06 -2,273.58 MWD+IFR-AK-CAZ-SC (3) 6,791.15 68.79 203.77 3,726.95 3,626.45 2,238.74 -3,225.86 5,971,013.18 558,858.00 1.98 -2,238.74 MWD+IFR-AK-CAZ-SC (3) 6,841.03 70.50 201.93 3,744.30 3,643.80 2,195.65 -3,244.01 5,970,969.95 558,840.20 4.87 -2,195.65 MWD+IFR-AK-CAZ-SC (3) 6,887.05 72.42 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 558,824.71 4.97 -2,154.99 MWD+IFR-AK-CAZ-SC (3) 6,937.09 75.14 200.64 3,772.91 3,672.41 2,110.03 -3,276.77 5,970,884.07 558,808.16 5.44 -2,110.03 MWD+IFR-AK-CAZ-SC (3) 6,981.79 75.77 197.68 3,784.14 3,683.64 2,069.16 -3,290.96 5,970,843.09 558,794.30 6.56 -2,069.16 MWD+IFR-AK-CAZ-SC (3) 7,032.37 76.56 195.96 3,796.23 3,695.73 2,022.15 -3,305.17 5,970,795.97 558,780.48 3.65 -2,022.15 MWD+IFR-AK-CAZ-SC (3) 7,076.80 77.92 193.87 3,806.05 3,705.55 1,980.28 -3,316.32 5,970,754.01 558,769.68 5.52 -1,980.28 MWD+IFR-AK-CAZ-SC (3) 7,124.94 80.37 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 558,758.92 5.18 -1,934.34 MWD+IFR-AK-CAZ-SC (3) 7,171.02 83.10 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 558,748.90 6.01 -1,889.94 MWD+IFR-AK-CAZ-SC (3) 7,217.39 84.93 191.34 3,826.57 3,726.07 1,844.86 -3,347.55 5,970,618.35 558,739.58 5.23 -1,844.86 MWD+IFR-AK-CAZ-SC (3) 7,266.96 84.23 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 558,731.41 5.58 -1,796.26 MWD+IFR-AK-CAZ-SC (3) 7,312.29 84.28 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 558,726.26 7.09 -1,757.51 MWD+IFR-AK-CAZ-SC (3) 7,357.00 84.36 183.09 3,840.22 3,739.72 1,707.14 -3,364.94 5,970,480.50 558,723.33 5.19 -1,707.14 MWD+IFR-AK-CAZ-SC (4) 7,427.16 87.15 184.80 3,845.41 3,744.91 1,637.35 -3,369.75 5,970,410.68 558,719.09 4.66 -1,637.35 MWD+IFR-AK-CAZ-SC (4) 7,473.28 88.70 185.92 3,847.08 3,746.58 1,591.46 -3,374.06 5,970,364.77 558,715.17 4.15 -1,591.46 MWD+IFR-AK-CAZ-SC (4) 7,522.99 90.36 187.12 3,847.49 3,746.99 1,542.08 -3,379.70 5,970,315.34 558,709.93 4.12 -1,542.08 MWD+IFR-AK-CAZ-SC (4) 7,567.91 91.90 188.21 3,846.60 3,746.10 1,497.57 -3,385.69 5,970,270.79 558,704.31 4.20 -1,497.57 MWD+IFR-AK-CAZ-SC (4) 7,617.53 88.75 189.41 3,846.32 3,745.82 1,448.55 -3,393.29 5,970,221.71 558,697.12 6.79 -1,448.55 MWD+IFR-AK-CAZ-SC (4) 7,662.04 86.17 190.49 3,848.29 3,747.79 1,404.75 -3,400.97 5,970,177.86 558,689.80 6.28 -1,404.75 MWD+IFR-AK-CAZ-SC (4) 7,713.67 86.91 189.00 3,851.41 3,750.91 1,353.96 -3,409.70 5,970,127.00 558,681.50 3.22 -1,353.96 MWD+IFR-AK-CAZ-SC (4) 7,756.46 87.96 187.75 3,853.32 3,752.82 1,311.67 -3,415.92 5,970,084.66 558,675.63 3.81 -1,311.67 MWD+IFR-AK-CAZ-SC (4) 7,807.68 90.73 186.75 3,853.91 3,753.41 1,260.87 -3,422.39 5,970,033.82 558,669.58 5.75 -1,260.87 MWD+IFR-AK-CAZ-SC (4) 7,850.84 93.33 185.88 3,852.38 3,751.88 1,218.00 -3,427.13 5,969,990.91 558,665.20 6.35 =1,218.00 MWD+IFR-AK-CAZ-SC (4) fi/3/2008 2:31:55PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference Kuparuk River Unit TVD Reference: Kuparuk 1C Pad MD Reference: 1C-172 North Reference: 1C-172AL2 Survey Calculation Method: 1C-172AL2 Database: MD Inc (ft) 1°) 7,902.Bi 93.57 7,944.87 91.41 7,999.15 90.98 8,040.57 90.55 8,092.17 91.91 8,134.65 91.54 8,184.47 90.86 8,229.10 90.68 8,322.92 90.55 8,373.67 90.86 8,416.78 92.46 8,463.30 92.22 8,511.86 94.81 8,557.92 92.52 8,606.12 89.93 8,700.51 89.87 8,794.90 92.65 8,888.83 92.10 8,940.01 92.22 8,983.33 90.49 9,034.53 91.54 9,076.61 92.09 9,170.62 90.12 9,216.06 90.00 9,264.24 89.56 9,294.65 91.04 9,329.58 89.68 9,358.30 90.49 9,410.71 90.06 9,452.15 90.98 9,502.30 88.20 9,546.30 89.19 9,598.45 91.10 9,639.41 91.17 9,689.90 90.18 9,732.91 89.81 9,783.47 90.36 9,825.83 89.63 9,877.66 91.47 9,890.00 91.40 Map +W-S +E!-W Northing Ift) Ift) (ft) 1,166.3A -3,431.83 5,969,939.22 1,124.41 -3,434.49 5,969,897.27 1,070.16 -3,435.62 5,969,843.02 1,028.78 -3,434.09 5,969,801.66 977.37 -3,429.88 5,969,750.29 935.19 -3,425.02 5,969,708.15 885.85 -3,418.22 5,969,658.87 841.67 -3,411.89 5,969,614.76 748.62 -3,399.93 5,969,521.82 698.11 -3,395.11 5,969,471.35 655.10 -3,392.45 5,969,428.38 608.66 -3,390.64 5,969,381.95 560.21 -3,389.36 5,969,333.52 514.26 -3,388.17 5,969,287.59 466.11 -3,386.47 5,969,239.45 371.80 -3,382.59 5,969,145.19 277.47 -3,380.93 5,969,050.88 183.65 -3,383.09 5,968,957.06 132.53 -3,384.68 5,968,905.93 89.23 -3,384.32 5,968,862.64 38.27 -3,379.70 5,968,811.73 -3.39 -3,373.90 5,968,770.12 -96.06 -3,358.32 5,968,677.59 -140.60 -3,349.28 5,968,633.14 -187.81 -3,339.69 5,968,586.01 -217.72 -3,334.22 5,968,556.14 -252.23 -3,328.84 5,968,521.68 -280.70 -3,325.08 5,968,493.25 -332.92 -3,320.75 5,968,441.07 -374.34 -3,320.87 5,968,399.65 -424.31 -3,325.00 5,968,349.66 -467.96 -3,330.41 5,968,305.97 -519.71 -3,336.84 5,968,254.17 -560.47 -3,340.75 5,968,213.38 -610.90 -3,342.94 5,968,162.94 -653.90 -3,342.04 5,968,119.96 -704.35 -3,338.73 5,968,069.55 -746.61 -3,335.97 5,968,027.31 -798.42 -3,334.99 5,967,975.51 -810.76 -3,335.14 5,967,963.18 We111 C-172 1 C-172A @ 100.50ft (Doyon 15) 1 C-172A @ 100.50ft (Doyon 15) True Minimum Curvature CPAI EDM Production - - -_ Map Vertical Fasting DLS Section Ift1 (~i100') lft) Survey Tool Name 556,660.93 2.67 -1,166.34 MWD+iFR-AK-CAZ-SG (4) 558,658.61 6.62 -1,124.41 MWD+IFR-AK-CAZ-SC (4) 558,657.93 5.76 -1,070.16 MWD+IFR-AK-CAZ-SC (4) 558,659.80 8.58 -1,028.78 MWD+IFR-AK-CAZ-SC (4) 558,664.44 4.10 -977.37 MWD+IFR-AK-CAZ-SC (4) 558,669.64 5.09 -935.19 MWD+IFR-AK-CAZ-SC (4) 558,676.86 1.64 -885.85 MWD+IFR-AK-CAZ-SC (4) 558,683.55 0.52 -841.67 MWD+IFR-AK-CAZ-SC (4) 558,696.27 1.94 -748.62 MWD+IFR-AK-CAZ-SC (4) 558,701.51 3.81 -698.11 MWD+IFR-AK-CAZ-SC (4) 558,704.53 5.81 -655.10 MWD+IFR-AK-CAZ-SC (4) 558,706.73 1.51 -608.66 MWD+IFR-AK-CAZ-SC (4) 558,708.41 5.58 -560.21 MWD+IFR-AK-CAZ-SC (4) 558,709.98 5.23 -514.26 MWD+IFR-AK-CAZ-SC (4) 558,712.07 5.41 -466.11 MWD+IFR-AK-CAZ-SC (4) 558,716.73 0.38 -371.80 MWD+IFR-AK-CAZ-SC (4) 558,719.17 4.37 -277.47 MWD+IFR-AK-CAZ-SC (4) 558,717.79 1.79 -183.65 MWD+IFR-AK-CAZ-SC (4) 558,716.62 1.29 -132.53 MWD+IFR-AK-CAZ-SC (4) 558,717.34 9.80 -89.23 MWD+IFR-AK-CAZ-SC (4) 558,722.38 10.95 -38.27 MWD+IFR-AK-CAZ-SC (4) 558,728.53 1.31 3.39 MWD+IFR-AK-CAZ-SC (4) 558,744.87 4.01 96.06 MWD+IFR-AK-CAZ-SC (4) 558,754.27 1.45 140.60 MWD+IFR-AK-CAZ-SC (4) 558,764.26 1.59 187.81 MWD+IFR-AK-CAZ-SC (4) 558,769.97 7.22 217.72 MWD+IFR-AK-CAZ-SC (4) 558,775.64 5.53 252.23 MWD+IFR-AK-CAZ-SC (4) 558,779.63 5.42 280.70 MWD+IFR-AK-CAZ-SC (4) 558,784.39 8.09 332.92 MWD+IFR-AK-CAZ-SC (4) 558,784.62 13.65 374.34 MWD+IFR-AK-CAZ-SC (4) 558,780.90 9.01 424.31 MWD+IFR-AK-CAZ-SC (4) 558,775.85 3.38 467.96 MWD+IFR-AK-CAZ-SC (4) 558,769.86 4.22 519.71 MWD+IFR-AK-CAZ-SC (4) 558,766.29 5.13 560.47 MWD+IFR-AK-CAZ-SC (4) 558,764.51 7.91 610.90 MWD+IFR-AK-CAZ-SC (4) 558,765.76 8.23 653.90 MWD+IFR-AK-CAZ-SC (4) 558,769.49 3.33 704.35 MWD+IFR-AK-CAZ-SC (4) 558,772.61 4.17 746.61 MWD+IFR-AK-CAZ-SC (4) 558,774.01 8.01 798.42 MWD+IFR-AK-CAZ-SC (4) 558,773.96 1.34 810.76 MWD+IFR-AK-CAZ-SC (5) Azi TVD TVDSS 184.5'1 3,849.25 3,748.75 182.75 179.65 176.12 174.50 172.37 171.92 171.77 173.59 175.50 177.43 178.09 178.89 178.14 177.82 177.47 180.52 182.11 181.46 177.58 172.07 172.07 168.85 168.20 168.83 170.45 171.82 173.15 177.37 182.95 186.51 187.62 186.53 184.43 180.56 177.04 175.45 177.06 180.78 180.63 3,847.43 3,846.29 3,845.74 3,844.63 3,843.35 3,842.31 3,841.71 3,840.70 3,840.08 3,838.83 3,836.93 3,833.95 3,831.01 3,829.98 3,830.14 3,828.07 3,824.18 3,822.25 3,821.22 3,820.32 3,818.98 3,817.17 3,817.12 3,817.31 3,817.15 3,816.93 3,816.89 3,816.63 3,816.26 3,816.62 3,817.62 3,817.49 3,816.67 3,816.08 3,816.08 3,816.01 3,816.01 3,815.51 3,815.21 3,746.93 3,745.79 3,745.24 3,744.13 3,742.85 3,741.81 3,741.21 3,740.20 3,739.58 3,738.33 3,736.43 3,733.45 3,730.51 3,729.48 3,729.64 3,727.57 3,723.68 3,721.75 3,720.72 3,719.82 3,718.48 3,716.67 3,716.62 3,716.81 3,716.65 3,716.43 3,716.39 3,716.13 3,715.76 3,716.12 3,717.12 3,716.99 3,716.17 3,715.58 3,715.58 3,715.51 3,715.51 3,715.01 3,714.71 6/32008 2:31:55PM Page 6 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-172 Wellbore: 1 C-172AL2 Design: 1 C-172AL2 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi ND TVDSS +N/-S +E!-W Northing (ft) (°) 1°) (ft) lft) (ft) Ift) (ft) 9,920.28 85.50 182.90 3,814.97 3,714.47 -841.02 -3,336.07 5,967,932.91 9,970.12 90.67 184.95 3,814.89 3,714.39 -890.74 -3,339.48 5,967,883.17 10,015.03 91.42 188.47 3,814.07 3,713.57 -935.33 -3,344.71 5,967,838.54 10,065.80 89.50 191.30 3,813.67 3,713.17 -985.34 -3,353.39 5,967,788.47 10,107.24 90.36 191.33 3,813.72 3,713.22 -1,025.97 -3,361.53 5,967,747.77 10,156.86 92.95 191.25 3,812.28 3,711.78 -1,074.61 -3,371.23 5,967,699.06 10,201.66 90.85 190.38 3,810.80 3,710.30 -1,118.59 -3,379.64 5,967,655.02 10,252.49 91.41 190.82 3,809.80 3,709.30 -1,168.54 -3,388.98 5,967,605.00 10,294.64 90.55 189.88 3,809.08 3,708.58 -1,210.00 -3,396.56 5,967,563.48 10,389.16 91.97 189.70 3,807.00 3,706.50 -1,303.11 -3,412.62 5,967,470.24 10,482.24 90.43 187.06 3,805.05 3,704.55 -1,395.17 -3,426.18 5,967,378.09 10,577.44 90.79 183.24 3,804.03 3,703.53 -1,489.96 -3,434.73 5,967,283.24 10,671.15 90.37 185.38 3,803.09 3,702.59 -1,583.40 -3,441.77 5,967,189.76 10,728.38 90.00 187.16 3,802.90 3,702.40 -1,640.28 -3,448.02 5,967,132.83 10,764.49 89.32 187.79 3,803.11 3,702.61 -1,676.08 -3,452.72 5,967,096.99 10,811.61 89.19 187.34 3,803.73 3,703.23 -1,722.79 -3,458.92 5,967,050.24 10,858.41 91.78 188.02 3,803.33 3,702.83 -1,769.16 -3,465.17 5,967,003.82 10,906.56 94.07 188.04 3,800.87 3,700.37 -1,816.78 -3,471.89 5,966,956.16 10,951.95 91.72 186.28 3,798.58 3,698.08 -1,861.75 -3,477.54 5,966,911.14 10,999.56 89.00 185.80 3,798.28 3,697.78 -1,909.09 -3,482.55 5,966,863.77 11,047.29 89.50 184.65 3,798.91 3,698.41 -1,956.62 -3,486.89 5,966,816.21 11,093.03 91.04 183.37 3,798.69 3,698.19 -2,002.24 -3,490.09 5,966,770.57 11,141.50 91.41 183.33 3,797.66 3,697.16 -2,050.62 -3,492.92 5,966,722.17 11,185.62 90.61 179.66 3,796.88 3,696.38 -2,094.71 -3,494.07 5,966,678.08 11,235.90 91.35 178.35 3,796.02 3,695.52 -2,144.97 -3,493.20 5,966,627.83 17,279.41 91.29 179.28 3,795.02 3,694.52 -2,188.46 -3,492.30 5,966,584.35 11,329.70 91.41 180.96 3,793.83 3,693.33 -2,238.74 -3,492.41 5,966,534.08 11,374.87 90.49 181.02 3,793.08 3,692.58 -2,283.89 -3,493.19 5,966,488.93 11,423.76 91.29 181.76 3,792.32 3,691.82 -2,332.76 -3,494.37 5,966,440.05 11,467.30 88.57 181.68 3,792.38 3,691.88 -2,376.28 -3,495.68 5,966,396.53 11,518.02 89.44 181.36 3,793.26 3,692.76 -2,426.97 -3,497.02 5,966,345.83 ~ 11,611.62 90.24 181.12 3,793.52 3,693.02 -2,520.55 -3,499.05 5,966,252.25 11,703.13 90.00 179.81 3,793.33 3,692.83 -2,612.05 -3,499.79 5,966,160.75 11,799.02 91.04 179.89 3,792.46 3,691.96 -2,707.94 -3,499.54 5,966,064.88 11,845.11 91.04 179.39 3,791.62 3,691.12 -2,754.02 -3,499.25 5,966,018.81 11,892.91 90.55 179.18 3,790.96 3,690.46 -2,801.81 -3,498.66 5,965,971.03 11,933.69 90.24 176.59 3,790.67 3,690.17 -2,842.56 -3,497.15 5,965,930.30 11,986.14 90.80 173.48 3,790.20 3,689.70 -2,894.80 -3,492.61 5,965,878.10 12,037.70 92.22 172.83 3,788.84 3,688.34 -2,945.98 -3,486.47 5,965,826.99 12,079.07 89.13 .174.17 3,788.35 3,687.85 -2,987.07 -3,481.79 5,965,785.93 Well 1 C-172 1 C-172A @ 100.50ft (Doyon 15) 1 C-172A @ 100.50ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Fasting DLS Ift! 1°!100'1 558,773.28 9.78 558,770.28 4.74 558,765.43 7.88 558,757.15 6.83 558,749.36 2.08 558,740.06 5.22 558,732.02 5.07 558,723.09 1.40 558,715.86 3.02 558,700.56 1.51 558,687.77 3.28 558,680.01 4.03 558,673.74 2.33 558,667.96 3.18 558,663.56 2.57 558,657.75 0.99 558,651.88 558,645.56 558,640.28 558,635.66 558,631.71 558,628.89 558,626.46 558,625.67 558,626.96 558,628.22 558,628.53 558,628.13 558,627.34 558,626.40 558,625.47 5.72 4.76 6.47 5.80 2.63 4.38 0.77 8.51 2.99 2.14 3.35 2.04 2.23 6.25 1.83 558,624.22 0.89 558,624.24 1.46 558,625.28 1.09 558,625.95 1.08 558,626.94 1.12 558,628.79 558,633.76 558,640.32 558,645.34 6.40 6.02 3.03 8.14 Vertical Section Ift) Survey Tool Name 841.02 MWD+IFR-AK-CAZ-SC (5) 890.74 MWD+IFR-AK-CAZ-SC (5) 935.33 MWD+IFR-AK-CAZ-SC (5) 985.34 MWD+IFR-AK-CAZ-SC (5) 1,025.97 MWD+IFR-AK-CAZ-SC (5) 1,074.61 MWD+IFR-AK-CAZSC (5) 1,118.59 MWD+IFR-AK-CAZ-SC (5) 1,168.54 MWD+IFR-AK-CAZ-SC (5) 1,210.00 MWD+IFR-AK-CAZ-SC (5) 1,303.11 MWD+IFR-AK-CAZ-SC (5) 1,395.17 MWD+IFR-AK-CAZ-SC (5) 1,489.96 MWD+IFR-AK-CAZ-SC (5) 1,583.40 MWD+IFR-AK-CAZ-SC (5) 1,640.28 MWD+IFR-AK-CAZ-SC (5) 1,676.08 MWD+IFR-AK-CAZ-SC (5) 1,722.79 MWD+IFR-AK-CAZ-SC (5) 1,769.16 MWD+IFR-AK-CAZ-SC (5) 1,816.78 MWD+IFR-AK-CAZ-SC (5) 1,861.75 MWD+IFR-AK-CAZ-SC (5) 1,909.09 MWD+IFR-AK-CAZ-SC (5) 1,956.62 MWD+IFR-AK-CAZ-SC (5) 2,002.24 MWD+IFR-AK-CAZ-SC (5) 2,050.62 MWD+IFR-AK-CAZ-SC (5) 2,094.71 MWD+IFR-AK-CAZ-SC (5) 2,144.97 MWD+IFR-AK-CAZ-SC (5) 2,188.46 MWD+IFR-AK-CAZ-SC (5) 2,238.74 MWD+IFR-AK-CAZ-SC (5) 2,283.89 MWD+IFR-AK-CAZ-SC (5) 2,332.76 MWD+IFR-AK-CAZ-SC (5) 2,376.28 MWD+IFR-AK-CAZ-SC (5) 2,426.97 MWD+IFR-AK-CAZ-SC (5) 2,520.55 MWD+IFR-AK-CAZ-SC (5) 2,612.05 MWD+IFR-AK-CAZ-SC (5) 2,707.94 MWD+IFR-AK-CAZ-SC (5) 2,754.02 MWO+IFR-AK-CAZ-SC (5) 2,801.81 MWD+IFR-AK-CAZ-SC (5) 2,842.56 MWD+IFR-AK-CAZ-SC (5) 2,894.80 MWD+IFR-AK-CAZ-SC (5) 2,945.98 MWD+IFR-AK-CAZ-SC (5) 2,987.07 MWD+IFR-AK-CAZ-SC (5) 6/3/2008 2:31:55PM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: We111C-172 Project: Kuparuk River Unit ° ND Reference: 1C-172A @ 100.50ft (Doyon 15) Site: ' Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2 Survey Calculation Method: Minimum Curvature Design: 1C-172AL2 Database: CPAI EDM Production ' Survey - - - _ - _ _ Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting DLS Section Ift) (°) (°) Ift) lft) Ift) Ift) (ft) (ft) (°1100'1 (ft) Survey Tool Name 12,100.00 85.92 174.47 3,;33.53 3,688.03 -3,007.90 -3,479.72 5,565,765.13 558,647.59 4.04 3,007.90 MWD+IFR-AK-CAZ-SG (6) 12,129.36 89.74 175.58 3,788.61 3,688.11 -3,037.15 -3,477.17 5,965,735.90 558,650.37 3.83 3,037.15 MWD+IFR-AK-CAZ-SC (6) 12,177.15 91.34 176.94 3,788.16 3,687.66 -3,084.83 -3,474.05 5,965,688.25 558,653.89 4.39 3,084.83 MWD+IFR-AK-CAZ-SC (6) 12,270.38 88.69 177.98 3,788.14 3,687.64 -3,177.96 -3,469.92 5,965,595.17 558,658.79 3.05 3,177.96 MWD+IFR-AK-CAZ-SC (6) 12,364.38 89.12 777.25 3,789.93 3,689.43 -3,271.86 -3,466.01 5,965,501.31 558,663.47 0.90 3,271.86 MWD+IFR-AK-CAZ-SC (6) 12,409.43 90.29 178.74 3,790.17 3,689.67 -3,316.88 -3,464.43 5,965,456.31 558,665.42 4.21 3,316.88 MWD+IFR-AK-CAZ-SC (6) 12,458.11 91.41 182.46 3,789.44 3,688.94 -3,365.54 -3,464.94 5,965,407.65 558,665.32 7.98 3,365.54 MWD+IFR-AK-CAZ-SC (6) 12,509.86 90.85 186.10 3,788.42 3,687.92 -3,417.13 -3,468.81 5,965,356.04 558,661.88 7.12 3,417.13 MWD+IFR-AK-CAZ-SC (6) .12,552.28 91.34 185.65 3,787.61 3,687.11 -3,459.32 -3,473.15 5,965,313.82 558,657.89 1.57 3,459.32 MWD+IFR-AK-CAZ-SC (6) 12,645.32 91.22 186.07 3,785.53 3,685.03 -3,551.85 -3,482.64 5,965,221.22 558,649.16 0.47 3,551.85 MWD+IFR-AK-CAZ-SC (6) 12,738.68 89.80 185.98 3,784.70 3,684.20 -3,644.69 -3,492.44 5,965,128.32 558,640.13 1.52 3,644.69 MWD+IFR-AK-CAZ-SC (6) 12,831.73 91.16 184.89 3,783.92 3,683.42 -3,737.31 -3,501.25 5,965,035.63 558,632.09 1.87 3,737.31 MWD+IFR-AK-CAZ-SC (6) 12,925.67 89.55 185.49 3,783.34 3,682.84 -3,830.86 -3,509.75 5,964,942.02 558,624.37 1.83 3,830.86 MWD+IFR-AK-CAZ-SC (6) 12,954.93 89.06 183.99 3,783.70 3,683.20 -3,860.02 -3,512.17 5,964,912.85 558,622.19 5.39 3,860.02 MWD+IFR-AK-CAZ-SC (6) • 13,018.00 89.06 183.99 3,784.73 3,684.23 -3,922.93 -3,516.56 5,964,849.91 558,618.32 , 0.00 3,922.93 PROJECTED to TD 6/3/2008 2:31:55PM Page 8 COMPASS 2003.16 Build 42F • ~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1C Pad 1 C-172AL2PB1 50-029-23159-70 .., Definitive Survey Report 03 June, 2008 . .. .._.... s _ .~,,. Sperry Drifting ~e~vices ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We111C-172 Project: Kuparuk River Unit TVD Reference: 1C-172A C~ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2PB1 Survey Calculation Method: Minimum Curvature Design: 1C-172AL2PB1 .Database: CPAI EDM Production Project Kuparuk River Unit, North Slope Alaska Map System:. US State Plane 1927 (6cact 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 1C-172 Well Position +N/-S 0.00 ft Northing: 5,968,801.43 ft Latitude: 70° 19' 31.051 N +E/-W 0.00 ft Easting: 562,101.96 ft Longitude: 149° 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 59.10ft Wellbore Magnetics Design Audit Notes: Version: ', Vertical Section i 1 C-172AL2PB1 Model Name BGGML007 BGGM2007 1C-172AL2PB1 1.0 Sample Date Declination (°1 12/18/2007 18.05 3/29/2007 18.36 Phase: Depth From (TVD) (ft} Dip Angle Field Strength l°) (nT- 79.76 57.268 79.75 57,2:57 ACTUAL Tie On Depth: 7,312.29 +N/-S +FJ-W Direction 1ft) (ftl (°) 180 00 J 41.40 0.00 0.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 158.30 279.40 1 C-172 Gyro (atdb) (1 G172) CB-GYRO-S5 Camera based gyro single shot 403.29 3,452.05 1C-172 (1C-172) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,513.00 7,312.291C-172A MWD+SAG+CA+IIFR+MS (1G MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC I 7,357.00 10,140.66 1C-172AL2PB1 MWD+SAG+CA+IIFR+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Inc Azi TVD TVDSS +N/-S (ft) (°) (°) lft) (ft) (ft) 41.40 0.00 0.00 41.40 -55.10 0.00 158.30 0.16 315.00 158.30 57.80 0.12 279.30 1.25 26.00 279.29 178.79 1.42 403.29 2.39 36.29 403.22 302.72 4.72 492.25 2.61 30.94 492.09 391.59 7.95 582.80 4.26 27.22 582.48 481.98 12.71 672.63 5.90 24.61 671.95 571.45 19.88 763.75 8.53 18.02 762.34 661.84 30.56 853.71 11.70 14.76 850.89 750.39 45.73 944.17 12.70 10.82 939.31 838.81 64.37 Survey Date 11/11/2004 11/11/2004 4/1 /2008 12: 4/21/2008 1: Map Map Vertical +El-W Northing Easting DLS Section (ft) (ft) (ft) (°!100'1 Ittl Survey Taol Name 0.00 5,968,801.43 562,101.56 0.00 0.00 UNDEFINED -0.12 5,968,801.54 562,101.84 0.14 -0.12 CB-GYRO-SS (1) 0.34 5,968,802.85 562,102.29 1.00 -1.42 CB-GYRO-SS (1) 2.47 5,968,806.17 562,104.39 0.95 -4.72 MWD+IFR-AK-CAZ-SC (2) 4.61 5,968,809.42 562,106.50 0.36 -7.95 MWD+IFR-AK-CAZ-SC (2) 7.20 5,968,814.20 562,109.06 1.84 -12.71 MWD+IFR-AK-CAZ-SC (2) 10.65 5,968,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 14.70 5,968,832.11 562,116.40 3.02 -30.56 MWD+IFR-AK-CAZ-SC (2) 19.08 5,968,847.31 562,120.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) 23.29 5,968,865.98 562,124.71 1.44 -64.37 MWD+IFR-AK-CAZ-SC (2) fi/3/2008 2:41:39PM Page 2 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Refer ence: We11 1C-172 Project: Kuparuk River Unit ND Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2P61 Survey Ca lculation Meth od: Minimum Curvature Design: 1C-172AL2P61 Database: CPA I EDM Production ~ Survey I II Map Map Vertical ~~ MD Inc Azi ND NDSS +NI-S +E/-W Northing Easting DLS Section lft) (~) (~) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,033.78 15.64 1.05 1,026.20 925.70 H6.13 25.36 5,566,BH7.76 562,126.60 4.22 -86.13 MWD+If=R-HK-GAZ-SG (2) 1,128.53 19.91 351.25 1,116.42 1,015.92 114.86 23.14 5,968,916.47 562,124.14 5.49 -114.86 MWD+IFR-AK-CAZ-SC (2) 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 16.65 5,968,949.00 562,117.39 2.42 -147.46 MWD+IFR-AK-CAZ-SC (2) 1,315.26 21.18 341.57 1,290.78 1,190.28 179.74 7.40 5,968,981.21 562,107.87 1.92 -179.74 MWD+IFR-AK-CAZ-SC (2) 1,407.39 26.12 338.05 1,375.15 1,274.65 214.36 -5.45 5,969,015.72 562,094.74 5.57 -214.36 MWD+IFR-AK-CAZ-SC (2) 1,502.67 33.63 335.74 1,457.71 1,357.21 257.94 -24.16 5,969,059.13 562,075.67 7.97 -257.94 MWD+IFR-AK-CAZ-SC (2) 1,594.46 35.67 335.01 1,533.22 1,432.72 305.37 -45.91 5,969,106.38 562,053.53 2.27 -305.37 MWD+IFR-AK-CAZ-SC (2) 1,687.13 40.07 334.38 1,606.35 1,505.85 356.78 -70.23 5,969,157.58 562,028.78 4.77 -356.78 MWD+IFR-AK-CAZ-SC (2) 1,780.29 44.74 331.67 1,675.13 1,574.63 412.71 -98.78 5,969,213.27 561,999.78 5.38 -412.71 MWD+IFR-AK-CAZ-SC (2) 1,873.69 50.50 330.33 1,738.06 1,637.56 473.01 -132.24 5,969,273.28 561,965.82 6.26 -473.01 MWD+IFR-AK-CAZ-SC (2) 1,965.93 53.61 328.47 1,794.77 1,694.27 535.60 -169.28 5,969,335.55 561,928.27 3.73 -535.60 MWD+IFR-AK-CAZ-SC (2) 2,058.38 56.75 326.71 1,847.56 1,747.06 599.65 -209.97 5,969,399.26 561,887.05 3.74 -599.65 MWD+IFR-AK-CAZ-SC (2) 2,151.37 66.46 324.51 1,891.73 1,791.23 667.02 -256.18 5,969,466.25 561,840.30 10.65 -667.02 MWD+IFR-AK-CAZ SC (2) 2,243.98 67.44 325.15 1,927.99 1,827.49 736.68 -305.26 5,969,535.49 561,790.64 1.23 -736.68 MWD+IFR-AK-CAZ-SC (2) 2,337.06 66.78 325.57 1,964.20 1,863.70 807.23 -354.00 5,969,605.63 561,741.32 0.82 -807.23 MWD+IFR-AK-CAZ-SC (2) 2,429.62 66.75 326.52 2,000.71 1,900.21 877.78 -401.51 5,969,675.77 561,693.24 0.94 -877.78 MWD+IFR-AK-CAZ-SC (2) 2,522.51 64.45 324.33 2,039.09 1,938.59 947.43 -449.49 5,969,745.02 561,644.68 3.28 -947.43 MWD+IFR-AK-CAZ-SC (2) 2,616.50 63.51 323.94 2,080.32 1,979.82 1,015.88 -498.98 5,969,813,05 561,594.64 1.07 -1,015.88 MWD+IFR-AK-CAZ-SC (2) i 2,708.50 62.50 324.15 2,122.08 2,021.58 1,082.24 -547.11 5,969,879.00 561,545.97 1.12 -1,082.24 MWD+IFR-AK-CAZ-SC (2) 2,802.18 64.21 323.38 2,164.09 2,063.59 1,149.77 -596.60 5,969,946.11 561,495.92 1.97 -1,149.77 MWD+IFR-AK-CAZ-SC (2) 2,894.33 67.26 323.39 2,201.95 2,101.45 1,217.19 -646.70 5,970,013.11 561,445.27 3.31 -1,217.19 MWD+IFR-AK-CAZ-SC (2) 2,986.94 68.00 324.42 2,237.20 2,136.70 1,286.39 -697.15 5,970,081.88 561,394.25 1.30 -1,286.39 MWD+IFR-AK-CAZ-SC (2) 3,079.87 66.03 320.60 2,273.50 2,173.00 1,354.27 -749.19 5,970,149.32 561,341.66 4.34 -1,354.27 MWD+IFR-AK-CAZ-SC (2) 3,172.58 66.09 321.65 2,311.12 2,210.62 1,420.23 -802.37 5,970,214.84 561,287.94 1.04 -1,420.23 MWD+IFR-AK-CAZ-SC (2) 3,265.42 65.93 322.72 2,348.87 2,248.37 1,487.24 -854.37 5,970,281.40 561,235.39 1.07 -1,487.24 MWD+IFR-AK-CAZ-SC (2) 3,358.70 66.16 323.91 2,386.74 2,286.24 1,555.60 -905.30 5,970,349.33 561,183.90 1.19 -1,555.60 MWD+IFR-AK-CAZ-SC (2) 3,452.05 66.32 323.79 2,424.35 2,323.85 1,624.59 -955.70 5,970,417.90 561,132.94 0.21 -1,624.59 MWD+IFR-AK-CAZ-SC (2) 3,513.00 67.04 321.07 2,448.48 2,347.98 1,668.94 -989.82 5,970,461.96 561,098.45 4.26 -1,668.94 MWD+IFR-AK-CAZ-SC (3) 3,585.84 64.84 325.52 2,478.19 2,377.69 1,722.23 -1,029.58 5,970,514.92 561,058.26 6.34 -1,722.23 MWD+IFR-AK-CAZ-SC (3) 3,617.05 65.36 327.47 2,491.33 2,390.83 1,745.84 -1,045.21 5,970,538.39 561,042.44 5.91 -1,745.84 MWD+IFR-AK-CAZ-SC (3) 3,649.50 65.28 328.01 2,504.88 2,404.38 1,770.77 -1,060.94 5,970,563.19 561,026.50 1.53 -1,770.77 MWD+IFR-AK-CAZ-SC (3) 3,695.80 66.04 327.17 2,523.96 2,423.46 1,806.38 -1,083.55 5,970,598.61 567,003.60 2.33 -1,806.38 MWD+IFR-AK-CAZ-SC (3) 3,744.69 65.69 327.41 2,543.95 2,443.45 1,843.92 -1,107.66 5,970,635.95 560,979.18 0.84 -1,843.92 MWD+IFR-AK-CAZ-SC (3) 3,792.85 67.28 327.08 2,563.17 2,462.67 1,881.06 -1,131.56 5,970,672.88 560,954.98 3.36 -1,881.06 MWD+IFR-AK-CAZ-SC (3) 3,840.82 66.20 327.01 2,582.11 2,481.61 1,918.04 -1,155.53 5,970,709.66 560,930.71 2.26 -1,918.04 MWD+IFR-AK-CAZ-SC (3) 3,883.87 66.07 326.56 2,599.53 2,499.03 1,950.98 -1,177.10 5,970,742.41 560,908.87 1.00 -1,950.98 MWD+IFR-AK-CAZ-SC (3) 3,935.75 67.35 324.51 2,620.04 2,519.54 1,990.26 -1,204.06 5,970,781.47 560,887.58 4.39 -1,990.26 MWD+IFR-AK-CAZ-SC (3) 3,982.32 68.29 324.70 2,637.63 2,537.13 2,025.41 -1,229.04 5,970,816.41 560,856.32 2.05 -2,025.41 MWD+IFR-AK-CAZ-SC (3) 4,030.80 68.76 323.33 2,655.37 2,554.87 2,061.92 -1,255.55 5,970,852.69 560,829.51 2.80 -2,061.92 MWD+IFR-AK-CAZ-SC (3) 4,080.64 68.81 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 560,801.34 0.68 -2,099.09 MWD+IFR-AK-CAZ-SC (3) 6/3/2008 2:41:39PM Page 3 COMPASS 2003.16 Build 42F ~~ C onocoP hillips Defi nitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit ND Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2P61 Survey Ca lculation Met hod: Minimum Curvature Design: 1C-172AL2PB1 Database: CPA I EDM Production Survey Map Map Vertical MD Inc Azi ND NDSS +N1S +E/-W Northing Easting DLS Section (ft) (°) (°) lft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,125.48 63.28 323.84 2,639.81 2,589.31 2,732.61 -1,308.30 5,970,922.93 560,776.18 2.16 -2,132.61 MWD+IFR-AK-CAZ-SC (3) 4,175.33 67.30 325.15 2,708.65 2,608.15 2,170.17 -1,335.10 5,970,960.27 560,749.08 3.13 -2,170.17 MWD+IFR-AK-CAZ-SC (3) 4,220.69 66.91 328.35 2,726.31 2,625.81 2,205.11 -1,358.01 5,970,995.01 560,725.88 6.56 -2,205.11 MWD+IFR-AK-CAZ-SC (3) 4,273.07 67.39 327.31 2,746.65 2,646.15 2,245.96 -1,383.71 5,971,035.65 560,699.85 2.05 -2,245.96 MWD+IFR-AK-CAZ-SC (3) 4,315.29 67.35 326.13 2,762.89 2,662.39 2,278.54 -1,405.09 5,971,068.05 560,678.20 2.58 -2,278.54 MWD+IFR-AK-CAZ-SC (3) 4,360.35 67.02 324.56 2,780.37 2,679.87 2,312.71 -1,428.71 5,971,102.01 560,654.30 3.29 -2,312.71 MWD+IFR-AK-CAZ-SC (3) 4,409.23 67.34 323.59 2,799.32 2,698.82 2,349.19 -1,455.14 5,971,138.27 560,627.57 1.94 -2,349.19 MWD+IFR-AK-CAZ-SC (3) 4,457.69 67.78 323.19 2,817.82 2,717.32 2,385.14 -1,481.85 5,971,174.00 560,600.56 1.19 -2,385.14 MWD+IFR-AK-CAZ-SC (3) 4,506.21 68.87 323.19 2,835.74 2,735.24 2,421.24 -1,508.87 5,971,209.87 560,573.25 2.25 -2,421.24 MWD+IFR-AK-CAZ-SC (3) 4,551.46 68.80 321.91 2,852.08 2,751.58 2,454.74 -1,534.52 5,971,243.15 560,547.32 2.64 -2,454.74 MWD+IFR-AK-CAZ-SC (3) 4,601.20 68.93 320.38 2,870.02 2,769.52 2,490.87 -1,563.63 5,971,279.04 560,517.92 2.88 -2,490.87 MWD+IFR-AK-CAZ-SC (3) 4,652.27 68.66 317.69 2,888.49 2,787.99 2,526.82 -1,594.84 5,971,314.72 560,486.42 4.94 -2,526.82 MWD+IFR-AK-CAZ-SC (3) 4,695.93 67.82 314.97 2,904.68 2,804.18 2,556.15 -1,622.83 5,971,343.81 560,458.18 6.10 -2,556.15 MWD+IFR-AK-CAZ-SC (3) 4,741.75 66.56 312.96 2,922.44 2,821.94 2,585.47 -1,653.23 5,971,372.88 560,427.55 4.89 -2,585.47 MWD+IFR-AK-CAZ-SC (3) 4,791.17 65.32 309.76 2,942.60 2,842.10 2,615.29 -1,687.09 5,971,402.41 560,393.45 6.42 -2,615.29 MWD+IFR-AK-CAZ-SC (3) 4,837.62 65.20 307.28 2,962.04 2,861.54 2,641.56 -1,720.09 5,971,428.41 560,360.23 4.86 -2,641.56 MWD+IFR-AK-CAZ-SC (3) 4,885.47 65.86 304.28 2,981.86 2,881.36 2,667.01 -1,755.42 5,971,453.57 560,324.70 5.87 -2,667.01 MWD+IFR-AK-CAZ-SC (3) 4,931.69 66.66 302.49 3,000.47 2,899.97 2,690.29 -1,790.75 5,971,476.55 560,289.18 3.94 -2,690.29 MWD+IFR-AK-CAZ-SC (3) 4,979.93 66.49 300.50 3,019.65 2,919.15 2,713.41 -1,828.49 5,971,499.36 560,251.26 3.80 -2,713.41 MWD+IFR-AK-CAZ-SC (3) 5,026.88 66.90 298.16 3,038.23 2,937.73 2,734.53 -1,866.08 5,971,520.17 560,213.50 4.66 -2,734.53 MWD+IFR-AK-CAZ-SC (3) 5,075.65 67.48 296.20 3,057.13 2,956.63 2,755.07 -1,906.07 5,971,540.36 560,173.34 3.89 -2,755.07 MWD+IFR-AK-CAZ-SC (3) 5,122.83 66.43 292.82 3,075.61 2,975.11 2,773.08 -1,945.56 5,971,558.05 560,133.71 6.96 -2,773.08 MWD+IFR-AK-CAZ-SC (3) 5,171.43 66.15 290.26 3,095.15 2,994.65 2,789.41 -1,986.94 5,971,574.04 560,092.19 4.86 -2,789.41 MWD+IFR-AK-CAZ-SC (3) ~ 5,218.47 66.25 287.55 3,114.14 3,013.64 2,803.36 -2,027.66 5,971,587.64 560,051.37 5.28 -2,803.36 MWD+IFR-AK-CAZ-SC (3) 5,267.44 67.09 285.02 3,133.53 3,033.03 2,815.96 -2,070.81 5,971,599.89 560,008.11 5.04 -2,815.96 MWD+IFR-AK-CAZ-SC (3) 5,312.08 67.20 282.82 3,150.87 3,050.37 2,825.86 -2,110.74 5,971,609.45 559,968.11 4.55 -2,825.86 MWD+IFR-AK-CAZ-SC (3) 5,361.27 66.28 279.48 3,170.30 3,069.80 2,834.60 -2,155.07 5,971,617.83 559,923.71 6.51 -2,834.60 MWD+IFR-AK-CAZ-SC (3) 5,412.46 66.84 275.53 3,190.67 3,090.17 2,840.73 -2,201.62 5,971,623.57 559,877.12 7.16 -2,840.73 MWD+IFR-AK-CAZ-SC (3) 5,457.39 66.76 273.44 3,208.37 3,107.87 2,843.96 -2,242.79 5,971,626.46 559,835.93 4.28 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 5,512.09 67.69 270.51 3,229.55 3,129.05 2,845.69 -2,293.18 5,971,627.77 559,785.52 5.22 -2,845.69 MWD+IFR-AK-CAZ-SC (3) 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,627.07 559,748.35 5.19 -2,845.30 MWD+IFR-AK-CAZ-SC (3) 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,624.22 559,702.54 5.37 -2,842.82 MWD+IFR-AK-CAZ-SC (3) 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,619.84 559,661.20 4.55 -2,838.78 MWD+IFR-AK-CAZ-SC (3) 5,696.76 66.30 261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,613.53 559,616.72 3.38 -2,832.85 MWD+IFR-AK-CAZ-SC (3) 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,606.05 559,575.01 4.90 -2,825.70 MWD+IFR-AK-CAZ-SC (3) 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 559,532.36 6.07 -2,816.23 MWD+IFR-AK-CAZ-SC (3) 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,584.50 559,490.72 4.59 -2,804.86 MWD+IFR-AK-CAZ-SC (3) 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 559,447.91 6.88 -2,790.79 MWD+IFR-AK-CAZ-SC (3) 5,933.84 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,971,554.19 559,407.88 5.40 -2,775.22 MWD+IFR-AK-CAZ-SC (3) 5,978.50 67.04 245.10 3,413.51 3,313.01 2,758.63 -2,709.25 5,971,537.28 559,370.24 5.39 -2,758.63 MWD+IFR-AK-CAZ-SC (3) &/3/2008 2:41:39PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2PB1 Survey Calculation Method: Minimum Curvature Design: 1G172AL2PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section lftl (°) (°) lft) Ift) lft) Ift) (ft) (ft) (°1100') (ft) Survey Tool Name 6,028.43 66.58 242.55 3,433.18 3,332.68 2,738.53 -2,750.50 5,971,516.84 559,329.15 4.06 -2,738.53 MWD+IFR-AK-CAZ-SC (3) 6,074.69 67.49 240.86 3,451.23 3,350.73 2,718.47 -2,788.07 5,971,496.48 559,291.75 4.60 -2,718.47 MWD+IFR-AK-CAZ-SC (3) 6,123.77 67.64 238.03 3,469.96 3,369.46 2,695.41 -2,827.13 5,971,473.10 559,252.89 5.34 -2,695.41 MWD+IFR-AK-CAZ-SC (3) 6,169.08 66.75 235.65 3,487.52 3,387.02 2,672.57 -2,862.10 5,971,449.97 559,218.12 5.23 -2,672.57 MWD+IFR-AK-CAZ-SC (3) 6,218.69 67.03 233.61 3,507.00 3,406.50 2,646.16 -2,899.30 5,971,423.25 559,181.14 3.82 -2,646.16 MWD+IFR-AK-CAZ-SC (3) 6,267.43 67.88 230.95 3,525.69 3,425.19 2,618.62 -2,934.90 5,971,395.42 559,145.77 5.33 -2,618.62 MWD+IFR-AK-CAZ-SC (3) 6,314.03 66.91 229.11 3,543.60 3,443.10 2,590.99 -2,967.87 5,971,367.52 559,113.03 4.20 -2,590.99 MWD+IFR-AK-CAZ-SC (3) 6,358.62 66.68 226.98 3,561.17 3,460.67 2,563.59 -2,998.35 5,971,339.88 559,082.79 4.42 -2,563.59 MWD+IFR-AK-CAZ-SC (3) 6,409.08 66.96 224.00 3,581.04 3,480.54 2,531.08 -3,031.42 5,971,307.09 559,049.99 5.46 -2,531.08 MWD+IFR-AK-CAZ-SC (3) 6,455.79 66.97 221.59 3,599.32 3,498.82 2,499.54 -3,060.62 5,971,275.31 559,021.05 4.75 -2,499.54 MWD+IFR-AK-CAZ-SC (3) 6,505.16 67.34 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 558,992.00 5.37 -2,464.77 MWD+IFR-AK-CAZ-SC (3) 6,551.22 66.83 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 558,966.37 4.48 -2,431.19 MWD+IFR-AK-CAZ-SC (3) 6,599.24 66.93 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 558,941.23 5.33 -2,395.09 MWD+IFR-AK-CAZ-SC (3) 6,650.05 68.21 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 558,916.38 5.57 -2,355.45 MWD+IFR-AK-CAZ-SC (3) 6,696.47 67.69 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 558,895.30 5.08 -2,318.13 MWD+IFR-AK-CAZ-SC (3) 6,750.16 68.65 204.63 3,712.07 3,611.57 2,273.58 -3,270.20 5,971,048.15 558,873.36 7.06 -2,273.58 MWD+IFR-AK-CAZ-SC (3) 6,791.15 68.79 203.77 3,726.95 3,626.45 2,238.74 -3,225.86 5,971,013.18 558,858.00 1.98 -2,238.74 MWD+IFR-AK-CAZ-SC (3) 6,841.03 70.50 201.93 3,744.30 3,643.80 2,195.65 -3,244.01 5,970,969.95 558,840.20 4.87 -2,195.65 MWD+IFR-AK-CAZ-SC (3) 6,887.05 72.42 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 558,824.71 4.97 -2,154.99 MWD+IFR-AK-CAZ-SC (3) 6,937.09 75.14 200.64 3,772.91 3,672.41 2,110.03 -3,276.77 5,970,884.07 558,808.16 5.44 -2,110.03 MWD+IFR-AK-CAZ-SC (3) 6,981.79 75.77 197.68 3,784.14 3,683.64 2,069.16 -3,290.96 5,970,843.09 558,794.30 6.56 -2,069.16 MWD+IFR-AK-CAZ-SC (3) 7,032.37 76.56 195.96 3,796.23 3,695.73 2,022.15 -3,305.17 5,970,795.97 558,780.48 3.65 -2,022.15 MWD+IFR-AK-CAZ-SC (3) 7,076.80 77.92 193.87 3,806.05 3,705.55 1,980.28 -3,316.32 5,970,754.01 558,769.68 5.52 -1,980.28 MWD+IFR-AK-CAZ-SC (3) 7,124.94 80.37 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 558,758.92 5.18 -1,934.34 MWD+IFR-AK-CAZ-SC (3) 7,171.02 83.10 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 558,748.90 6.01 -1,889.94 MWD+IFR-AK-CAZ-SC (3) 7,217.39 84.93 191.34 3,826.57 3,726.07 1,844.86 -3,347.55 5,970,618.35 558,739.58 5.23 -1,844.86 MWD+IFR-AK-CAZ-SC (3) 7,266.96 84.23 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 558,731.41 5.58 -1,796.26 MWD+IFR-AK-CAZ-SC (3) 7,312.29 84.28 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 558,726.26 7.09 -1,751.51 MWD+IFR-AK-CAZ-SC (3) 7,357.00 84.36 183.09 3,840.22 3,739.72 1,707.14 -3,364.94 5,970,480.50 558,723.33 5.19 -1,707.14 MWD+IFR-AK-CAZ-SC (4) 7,427.16 87.15 184.80 3,845.41 3,744.91 1,637.35 -3,369.75 5,970,410.68 558,719.09 4.66 -1,637.35 MWD+IFR-AK-CAZ-SC (4) 7,473.28 88.70 185.92 3,847.08 3,746.58 1,591.46 -3,374.06 5,970,364.77 558,715.17 4.15 -1,591.46 MWD+IFR-AK-CAZ-SC (4) 7,522.99 90.36 187.12 3,847.49 3,746.99 1,542.08 -3,379.70 5,970,315.34 558,709.93 4.12 -1,542.08 MWD+IFR-AK-CAZ-SC (4) 7,567.91 91.90 188.21 3,846.60 3,746.10 1,497.57 -3,385.69 5,970,270.79 558,704.31 4.20 -1,497.57 MWD+IFR-AK-CAZ-SC (4) 7,617.53 88.75 189.41 3,846.32 3,745.82 1,448.55 -3,393.29 5,970,221.71 558,697.12 6.79 -1,448.55 MWD+IFR-AK-CAZ-SC (4) 7,662.04 86.17 190.49 3,848.29 3,747.79 1,404.75 -3,400.97 5,970,177.86 558,689.80 6.28 -1,404.75 MWD+IFR-AK-CAZ-SC (4) 7,713.67 86.91 189.00 3,851.41 3,750.91 1,353.96 -3,409.70 5,970,127.00 558,681.50 3.22 -1,353.96 MWD+IFR-AK-CAZ-SC (4) 7,756.46 87.96 187.75 3,853.32 3,752.82 1,311.67 -3,415.92 5,970,084.66 558,675.63 3.81 -1,311.67 MWD+IFR-AK-CAZ-SC (4) 7,807.68 90.73 186.75 3,853.91 3,753.41 1,260.87 -3,422.39 5,970,033.82 558,669.58 5.75 -1,260.87 MWD+IFR-AK-CAZ-SC (4) 7,850.84 93.33 185.88 3,852.38 3,751.88 1,218.00 -3,427.13 5,969,990.91 558,665.20 6.35 -1,218.00 MWD+IFR-AK-CAZ-SC (4) 7,902.81 93.57 184.51 3,849.25 3,748.75 1,166.34 -3,431.83 5,969,939.22 558,660.93 2.67 -1,166.34 MWD+IFR-AK-CAZ-SC (4) &/3/2008 2:41:39PM Page 5 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We11 1C-172 Project: Kuparuk River Unit ND Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2P61 Survey Ca lculation Method: Minimum Curvature Design: 1C-172AL2P61 Database: CPA I EDM Production Survey - Map Map Vertical MD Inc Azi ND NDSS +N/S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1104') (ft) Survey Tool Name 7,944.87 91.41 182.75 3,847.43 3,746.93 1,124.41 -3,434.49 5,969,897.27 558,658.61 6.62 -1,124.41 MWD+IFR-AK-CAZ-SC (4) 7,999.15 90.98 179.65 3,846.29 3,745.79 1,070.16 -3,435.62 5,969,843.02 558,657.93 5.76 -1,070.16 MWD+IFR-AK-CAZ-SC (4) 8,040.57 90.55 176.12 3,845.74 3,745.24 1,028.78 -3,434.09 5,969,801.66 558,659.80 8.58 -1,028.78 MWD+IFR-AK-CAZ-SC (4) 8,092.17 91.91 174.50 3,844.63 3,744.13 977.37 -3,429.88 5,969,750.29 558,664.44 4.10 -977.37 MWD+IFR-AK-CAZ-SC (4) 8,134.65 91.54 172.37 3,843.35 3,742.85 935.19 -3,425.02 5,969,708.15 558,669.64 5.09 -935.19 MWD+IFR-AK-CAZ-SC (4) 8,184.47 90.86 171.92 3,842.31 3,741.81 885.85 -3,418.22 5,969,658.87 558,676.86 1.64 -885.85 MWD+IFR-AK-CAZ-SC (4) 8,229.10 90.68 171.77 3,841.71 3,741.21 841.67 -3,411.89 5,969,614.76 558,683.55 0.52 -841.67 MWD+IFR-AK-CAZ-SC (4) 8,322.92 90.55 173.59 3,840.70 3,740.20 748.62 -3,399.93 5,969,521.82 558,696.27 1.94 -748.62 MWD+IFR-AK-CAZ-SC (4) 8,373.67 90.86 175.50 3,840.08 3,739.58 698.11 -3,395.11 5,969,471.35 558,701.51 3.81 -698.11 MWD+IFR-AK-CAZ-SC (4) 8,416.78 92.46 177.43 3,838.83 3,738.33 655.10 -3,392.45 5,969,428.38 558,704.53 5.81 -655.10 MWD+IFR-AK-CAZ-SC (4) 8,463.30 92.22 178.09 3,836.93 3,736.43 608.66 -3,390.64 5,969,381.95 558,706.73 1.51 -608.66 MWD+IFR-AK-CAZ-SC (4) 8,511.86 94.81 178.89 3,833.95 3,733.45 560.21 -3,389.36 5,969,333.52 558,708.41 5.58 -560.21 MWD+IFR-AK-CAZ-SC (4) 8,557.92 92.52 178.14 3,831.01 3,730.51 514.26 -3,388.17 5,969,287.59 558,709.98 5.23 -514.26 MWD+IFR-AK-CAZ-SC (4) 8,606.12 89.93 177.82 3,829.98 3,729.48 466.11 -3,386.47 5,969,239.45 558,712.07 5.41 -466.11 MWD+IFR-AK-CAZ-SC (4) 8,700.51 89.87 177.47 3,830.14 3,729.64 371.80 -3,382.59 5,969,145.19 558,716.73 0.38 -371.80 MWD+IFR-AK-CAZ-SC (4) 8,794.90 92.65 180.52 3,828.07 3,727.57 277.47 -3,380.93 5,969,050.88 558,719.17 4.37 -277.47 MWD+IFR-AK-CAZ-SC (4) 8,888.83 92.10 182.11 3,824.18 3,723.68 183.65 -3,383.09 5,968,957.06 558,717.79 1.79 -183.65 MWD+IFR-AK-CAZ-SC (4) 8,940.01 92.22 181.46 3,822.25 3,721.75 132.53 -3,384.68 5,968,905.93 558,716.62 1.29 -132.53 MWD+IFR-AK-CAZ-SC (4) 8,983.33 90.49 177.58 3,821.22 3,720.72 89.23 -3,384.32 5,968,862.64 558,717.34 9.80 -89.23 MWD+IFR-AK-CAZ-SC (4) 9,034.53 91.54 172.07 3,820.32 3,719.82 38.27 -3,379.70 5,968,811.73 558,722.38 10.95 -38.27 MWD+IFR-AK-CAZ-SC (4) 9,076.61 92.09 172.07 3,818.98 3,718.48 -3.39 -3,373.90 5,968,770.12 558,728.53 1.31 3.39 MWD+IFR-AK-CAZ-SC (4) 9,170.62 90.12 168.85 3,817.17 3,716.67 -96.06 -3,358.32 5,968,677.59 558,744.87 4.01 96.06 MWD+IFR-AK-CAZ-SC (4) 9,216.06 90.00 168.20 3,817.12 3,716.62 -140.60 -3,349.28 5,968,633.14 558,754.27 1.45 140.60 MWD+IFR-AK-CAZ-SC (4) 9,264.24 89.56 168.83 3,817.31 3,716.81 -187.81 -3,339.69 5,968,586.01 558,764.26 1.59 187.81 MWD+IFR-AK-CAZ-SC (4) 9,294.65 91.04 170.45 3,817.15 3,716.65 -217.72 -3,334.22 5,968,556.14 558,769.97 7.22 217.72 MWD+IFR-AK-CAZ-SC (4) 9,329.58 89.68 171.82 3,816.93 3,716.43 -252.23 -3,328.84 5,968,521.68 558,775.64 5.53 252.23 MWD+IFR-AK-CAZ-SC (4) 9,358.30 90.49 173.15 3,816.89 3,716.39 -280.70 -3,325.08 5,968,493.25 558,779.63 5.42 280.70 MWD+IFR-AK-CAZ-SC (4) 9,410.71 90.06 177.37 3,816.63 3,716.13 -332.92 -3,320.75 5,968,441.07 558,784.39 8.09 332.92 MWD+IFR-AK-CAZ-SC (4) 9,452.15 90.98 182.95 3,816.26 3,715.76 -374.34 -3,320.87 5,968,399.65 558,784.62 13.65 374.34 MWD+IFR-AK-CAZ-SC (4) 9,502.30 88.20 186.51 3,816.62 3,716.12 -424.31 -3,325.00 5,968,349.66 558,780.90 9.01 424.31 MWD+IFR-AK-CAZ-SC (4) 9,546.30 89.19 187.62 3,817.62 3,717.12 -467.96 -3,330.41 5,968,305.97 558,775.85 3.38 467.96 MWD+IFR-AK-CAZ-SC (4) 9,598.45 91.10 186.53 3,817.49 3,716.99 -519.71 -3,336.84 5,968,254.17 558,769.86 4.22 519.71 MWD+IFR-AK-CAZ-SC (4) 9,639.41 91.17 184.43 3,816.67 3,716.17 -560.47 -3,340.75 5,968,213.38 558,766.29 5.13 560.47 MWD+IFR-AK-CAZ-SC (4) 9,689.90 90.18 180.56 3,816.08 3,715.58 -610.90 -3,342.94 5,968,162.94 558,764.51 7.91 610.90 MWD+IFR-AK-CAZ-SC (4) 9,732.91 89.81 177.04 3,816.08 3,715.58 -653.90 -3,342.04 5,968,119.96 558,765.76 8.23 653.90 MWD+IFR-AK-CAZ-SC (4) 9,783.47 90.36 175.45 3,816.01 3,715.51 -704.35 -3,338.73 5,968,069.55 558,769.49 3.33 704.35 MWD+IFR-AK-CAZ-SC (4) 9,825.83 89.63 177.06 3,816.01 3,715.51 -746.61 -3,335.97 5,968,027.31 558,772.61 4.17 746.61 MWD+IFR-AK-CAZ-SC (4) 9,877.66 91.47 180.78 3,815.51 3,715.01 -798.42 -3,334.99 5,967,975.51 558,774.01 8.01 .798.42 MWD+IFR-AK-CAZ-SC (4) 9,920.35 91.23 180.26 3,814.51 3,714.01 -841.10 -3,335.38 5,967,932.84 558,773.98 1.34 841.10 MWD+IFR-AK-CAZ-SC (4) 9,972.70 89.50 177.02 3,814.18 3,713.68 -893.42 -3,334.13 5,967,880.53 558,775.65 7.02 893.42 MWD+IFR-AK-CAZ-SC (4) 6/3/2008 2:41:39PM Page 6 COMPASS 2003.16 Build 42F w Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1C Pad Wel I: 1 C-172 Wel I bo re: 1 C-172AL2P61 Design: 1 C-172AL2P61 Survey ConocoPhillips Definitive Survey Report Local Co-ard[nate Reference: Well 1C-172 TVD Reference: 1C-172A @ 100.50ft (Doyon 15) MD Reference: 1C-172A @ 100.50ft (Doyon 15) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production MD Inc Azi TVD TVDSS +N/S lft) (°) (°) Ift) lft) (ft) 10,014.25 90.92 175.79 3,814.02 3,713.52 -934.89 10,064.86 89.50 170.83 3,813.84 3,713.34 -985.14 10,107.00 90.55 169.30 3,813.82 3,713.32 -1,026.64 10,140.66 90.80 165.60 3,813.42 3,712.92 -1,059.49 10,205.00 90.80 165.60 3,812.52 3,712.02 -1,121.80 Map Map Vertical +E7-W Northing Easting DLS Section Ift) (ft) (ft) (°l100') (ft) Survey Tool Name -3,331.53 5,967,839.09 558,778.60 4.52 934.89 MWD+IFR-AK-CAZ-SG (4) -3,325.63 5,967,788.90 558,784.91 10.19 985.14 MWD+IFR-AK-CAZ-SC (4) -3,318.36 5,967,747.46 558,792.52 4.40 1,026.64 MWD+IFR-AK-CAZ-SC (4) -3,311.05 5,967,714.68 558,800.11 11.02 1,059.49 MWD+IFR-AK-CAZ-SC (4) -3,295.05 5,967,652.50 558,816.62 0.00 1,121.80 PROJECTED to TD fi/3/2008 2:41:39PM Page 7 COMPASS 2003. f6 Build 42F ~ ~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1C Pad 1 C-172AL2PB2 50-029-23159-71 ~.~ .~ Definitive Survey Report 03 June, 2008 ^.~:~ '~-~~T», Sperry 'Drilling Services i ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1C-172 North Reference: Wellbore: 1C-172AL2PB2 Survey Calculation Method: Design: 1C-172AL2P62 Database: • Well 1 C-172 1C-172A @ 100.SOft (Doyon 15) 1C-172A @ 100.50ft (Doyon 15) True Minimum Curvature CPAI EDM Production Protect Kuparuk River Unit, North Slope Alaska 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 1C-172 Well Position +NI-S O.OO ft Northing: 5,968,801.43 ft Latitude: 70° 19' 31.051 N +EI-W 0.00 ft Easting: 562,101.96 ft Longitude: 149° 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 59.10 ft Wellbore 1C-172AL2P62 I Magnetics Model Name Sample Date Decllnatlon Dlp Angle Field Strength BGGM2007 4/30/2008 BGGM2007 3/29!2008 17.89 17.93 75.77 57,284 79.77 57,280 Deslgn 1C-172AL2PB° Audit Notes: Version: 1 0 Phase: i+CTU ~L Tie On Depth: 9,877.66 Vertical Section : Depth From (TVD) +NI-S +E!-W Direction ftt) (ft) (ft) (°) at ao 0 00 0 0o tao 00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 158.30 279.40 1C-172 Gyro (atdb) (1C-172) CB-GYRO-SS Camera based gyro single shot 11/11/2004 1. 403.29 3,452.05 1C-172 (1C-172) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2004 1: 3,513.00 7,312.29 1C-172A MWD+SAG+CA+IIFR+MS (1C- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2008 12:0 7,357.00 9,877.66 1C-172AL2P81 MWD+SAG+CA+IIFR+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/21/2008 12: 9,890.00 12,308.48 1C-172AL2PB2 MWD+SAG+CA+IIFR+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2008 12: Survey Map Map Vertical MD I nc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (tt) (ft) (°1100') (ft) Survey Tool Name 41.40 0.00 0.00 41.40 -55.10 ODO O.CnT 5,5158,801.43 5ti2,101.5b 0.00 O.uO UWDEFHJcD 158.30 0.16 315.00 158.30 57.80 0.12 -0.12 5,968,801.54 562,101.84 0.14 -0.12 CB-GYRO-SS (1) 279.30 1.25 26.00 279.29 178.79 1.42 0.34 5,968,802.85 562,102.29 1.00 -1.42 CB-GYRO-SS (1) 403.29 2.39 36.29 403.22 302.72 4.72 2.47 5,968,806.17 562,104.39 0.95 -0.72 MWD+IFR-AK-CAZ-SC (2) 492.25 2.61 30.94 492.09 391.59 7.95 4.61 5,968,809.42 562,106.50 0.36 -7.95 MWD+IFR-AK-CAZ-SC (2) 582.80 4.26 27.22 582.48 481.98 12.71 7.20 5,968,814.20 562,109.06 1.84 -12.71 MWD+IFR-AK-CAZ-SC (2) 672.63 5.90 24.61 671.95 571.45 19.88 10.65 5,968,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 763.75 8.53 18.02 762.34 661.84 30.56 14.70 5,968,832.11 562,116.40 3.02 -30.56 MWD+IFR-AK-CAZ-SC (2) 853.71 11.70 14.76 850.89 750.39 45.73 19.08 5,968,847.31 562,120.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) 944.17 12.70 10.82 939.31 836.81 64.37 23.29 5,968,865.98 562,124.71 1.44 X4.37 MWD+IFR-AK-CAZ-SC (2) 6/3/2008 2:53:30PM Page 2 COMPASS 2003.1fi Build 42F n ~J ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Slte: Kuparuk 1C Pad MD Reference: Well: 1C-172 North Reference: Wellbore: 1C-172AL2PB2 Survey Calculation Method: Design: 1C-172AL2PB2 Database: Survey • Well 1 C-172 1C-172A @ 100.50ft (Doyon 15) 1C-172A @ 100.SOft (Doyon 15) True Minimum Curvature CPAI EDM Production Vertical DLS Section (°1100') (ft) Survey Tool Name 4.22 -86.13 MWD+IFR-AK-CAZ-SC (2) 5.49 -114.86 MWD+IFR-AK-CAZ-SC (2) 2.42 -147.46 MWD+IFR-AK-CAZ-SC (2) 1.92 -179.74 MWD+IFR-AK-CAZ-SC (2) 5.57 -214.36 MWD+IFR-AK-CAZ-SC (2) 7.97 -257.94 MWD+IFR-AK-CAZ-SC (2) 2.27 305.37 MWD+IFR-AK-CAZ-SC (2) 4.77 -356.78 MWD+IFR-AK-CAZ-SC (2) 5.38 -012.71 MWD+IFR-AK-CAZ-SC (2) 6.26 -473.01 MWD+IFR-AK-CAZ-SC (2) 3.73 -535.60 MWD+IFR-AK-CAZ-SC (2) 3.74 599.65 MWD+IFR-AK-CAZ-SC (2) 10.65 567.02 MWD+IFR-AK-CAZ-SC (2) 1.23 -736.68 MWD+IFR-AK-CAZ-SC (2) 0.82 -807.23 MWD+IFR-AK-CAZ-SC (2) 0.94 -877.78 MWD+IFR-AK-CAZ-SC (2) 3.28 -947.43 MWD+IFR-AK-CAZ-SC (2) 1.07 -1,015.88 MWD+IFR-AK-CAZ-SC (2) 1.12 -1,082.24 MWD+IFR-AK-CAZ-SC (2) 1.97 -1,149.77 MWD+IFR-AK-CAZ-SC (2) 3.31 -1,217.19 MWD+IFR-AK-CAZ-SC (2) 1.30 -1,286.39 MWD+IFR-AK-CAZ-SC (2) 4.34 -1,354.27 MWD+IFR-AK-CAZSC (2) 1.04 -1,420.23 MWD+IFR-AK-CAZ-SC (2) 1.07 -1,487.24 MWD+IFR-AK-CAZ-SC (2) 1.19 -1,555.60 MWD+IFR-AK-CAZ-SC (2) 0.21 -1,624.59 MWD+IFR-AK-CAZ-SC (2) 4.26 -1,668.94 MWD+IFR-AK-CAZ-SC (3) 6.34 -1,722.23 MWD+IFR-AK-CAZ-SC (3) 5.91 -1,745.84 MWD+IFR-AK-CAZ-SC (3) 1.53 -1,770.77 MWD+IFR-AK-CAZ-SC (3) 2.33 -1,806.38 MWD+IFR-AK-CAZ-SC (3) 0.84 -1,843.92 MWD+IFR-AK-CAZ-SC (3) 3.36 -1,881.06 MWD+IFR-AK-CAZ-SC (3) 2.26 -1,918.04 MWD+IFR-AK-CAZ-SC (3) 1.00 -1,950.98 MWD+IFR-AK-CAZ-SC (3) 4.39 -1,990.26 MWD+IFR-AK-CAZ-SC (3) 2.05 -2,025.41 MWD+IFR-AK-CAZSC (3) 2.80 -2,061.92 MWD+IFR-AK-CAZ-SC (3) 0.68 -2,099.09 MWD+IFR-AK-CAZ-SC (3) Map Map MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting (h) (°) (°) (n) ln) (ft) (ft) (1t) Iftl 1,033.78 15.64 1.05 1,026.20 925.70 86.13 25.36 5,968,887.76 562,126.60 1,128.53 19.91 351.25 1,116.42 1,015.92 114.86 23.14 5,968,916.47 562,124.14 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 16.65 5,966,949.00 562,117.39 1,315.26 21.18 341.57 1,290.78 7,190.28 179.74 7.40 5,968,981.21 562,107.87 1,407.39 26.12 336.05 1,375.15 1,274.65 214.36 -5.45 5,969,015.72 562,094.74 1,502.67 33.63 335.74 1,457.71 1,357.21 257.94 -24.16 5,969,059.13 562,075.67 1,594.46 35.67 335.01 1,533.22 1,432.72 305.37 -45.91 5,969,106.38 562,053.53 1,667.13 40.07 334.38 1,606.35 1,505.85 356.78 -70.23 5,969,157.58 562,028.78 1,780.29 44.74 331.67 1,675.13 1,574.63 412.71 -98.78 5,969,213.27 561,999.78 1,873.69 50.50 330.33 1,738.06 1,637.56 473.01 -132.24 5,969,273.28 561,965.82 1,965.93 53.61 328.47 1,794.77 1,694.27 535.60 -169.28 5,969,335.55 561,928.27 2,058.38 56.75 326.71 1,847.56 1,747.06 599.65 -209.97 5,969,399.26 561,887.05 2,151.37 66.46 324.51 1,891.73 1,791.23 667.02 -256.18 5,969,466.25 561,840.30 2,243.98 67.44 325.15 1,927.99 1,827.49 736.68 -305.26 5,969,535.49 561,790.64 2,337.06 66.78 325.57 7,964.20 1,863.70 807.23 -354.00 5,969,605.63 567,741.32 2,429.62 66.75 326.52 2,000.71 1,900.21 877.78 -401.51 5,969,675.77 561,693.24 2,522.51 64.45 324.33 2,039.09 1,938.59 947.43 -449.49 5,969,745.02 561,644.68 2,616.50 63.51 323.94 2,080.32 1,979.82 1,015.88 -498.98 5,969,813.05 561,594.64 2,708.50 62.50 324.15 2,122.08 2,021.58 1,082.24 -547.11 5,969,879.00 561,545.97 2,802.18 64.21 323.38 2,164.09 2,063.59 1,149.77 -596.60 5,969,946.77 561,495.92 2,894.33 67.26 323.39 2,201.95 2,101.45 1,217.19 -646.70 5,970,013.11 561,445.27 2,986.94 68.00 324.42 2,237.20 2,136.70 1,266.39 597.15 5,970,081.88 561,394.25 3,079.87 66.03 320.60 2,273.50 2,173.00 1,354.27 -749.19 5,970,149.32 561,341.66 3,172.58 66.09 321.65 2,311.12 2,210.62 1,420.23 -802.37 5,970,214.84 561,287.94 3,265.42 65.93 322.72 2,348.87 2,248.37 1,487.24 -854.37 5,970,281.40 561,235.39 3,358.70 66.16 323.91 2,386.74 2,286.24 1,555.60 -905.30 5,970,349.33 561,183.90 3,452.05 66.32 323.79 2,424.35 2,323.85 1,624.59 -955.70 5,970,417.90 567,132.94 3,513.00 67.04 321.07 2,448.48 2,347.98 1,668.94 -969.82 5,970,461.96 561,098.45 3,585.84 64.84 325.52 2,478.19 2,377.69 1,722.23 -1,029.58 5,970,514.92 561,058.26 3,617.05 65.36 327.47 2,491.33 2,390.83 1,745.84 -1,045.21 5,970,538.39 561,042.44 3,649.50 65.26 328.01 2,504.88 2,404.38 1,770.77 -1,060.94 5,970,563.19 561,026.50 3,695.80 66.04 327.17 2,523.96 2,423.46 1,806.38 -1,083.55 5,970,598.61 561,003.60 3,744.69 65.69 327.41 2,543.95 2,443.45 1,843.92 -1,107.66 5,970,635.95 560,979.18 3,792.85 67.28 327.08 2,563.17 2,462.67 1,881.06 -1,131.56 5,970,672.88 560,954.98 3,840.82 66.20 327.01 2,582.11 2,481.61 1,918.04 -1,155.53 5,970,709.66 560,930.71 3,883.87 66.07 326.56 2,599.53 2,499.03 1,950.98 -1,177.10 5,970,742.41 560,908.87 3,935.75 67.35 324.51 2,620.04 2,519.54 1,990.26 -1,204.06 5,970,781.47 560,881.58 3,982.32 68.29 324.70 2,637.63 2,537.13 2,025.41 -1,229.04 5,970,816.41 560,856.32 4,030.80 68.76 323.33 2,655.37 2,554.87 2,061.92 -1,255.55 5,970,852.69 560,829.51 4,080.64 68.61 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 560,601.34 6/3/2008 2:53:30PM Page 3 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1C Pad WeII : 1 C-172 W e I I bo ra: 1 C-172AL2P62 Design: 1 C-172AL2P62 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: • Well 1 C-172 1C-172A @ 100.50ft (Doyon 15) i C-172A @ 100.50ft (Doyon 15) true Minimum Curvature CPAI EDM Production Map Map Vertical MD Inc Azl ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,125.45 68.28 323.84 2,6tl9.81 2,589.31 2,131.61 -1,308.30 ~,57u,922.93 560,776.18 2.16 -2,13Y.61 MWD+IFR-AK-CAZ-SC (3) 4,175.33 67.30 325.15 2,708.65 2,608.15 2,170.17 -1,335.10 5,970,960.27 560,749.08 3.13 -2,170.17 MWD+IFR-AK-CAZ-SC (3) 4,220.69 66.91 328.35 2,726.31 2,625.81 2,205.11 -1,358.01 5,970,995.01 560,725.88 6.56 -2,205.11 MWD+IFR-AK-CAZ-SC (3) i 4,273.07 67.39 327.31 2,746.65 2,646.15 2,245.96 -1,383.71 5,971,035.65 560,699.85 2.05 -2,245.96 MWD+IFR-AK-CAZ-SC (3) 4,315.29 67.35 326.13 2,762.89 2,662.39 2,278.54 -1,405.09 5,971,068.05 560,678.20 2.58 -2,278.54 MWD+IFR-AK-CAZSC (3) 4,360.35 67.02 324.56 2,780.37 2,679.87 2,312.71 -1,428.71 5,971,102.01 560,654.30 3.29 -2,312.71 MWD+IFR-AK-CAZ-SC (3) 4,409.23 67.34 323.59 2,799.32 2,696.82 2,349.19 -1,455.14 5,971,138.27 560,627.57 1.94 -2,349.19 MWD+IFR-AK-CAZ-SC (3) 4,457.69 67.78 323.19 2,817.82 2,717.32 2,385.14 -1,481.85 5,971,174.00 560,600.56 1.19 -2,385.14 MWD+IFR-AK-CAZ-SC (3) 4,506.21 68.87 323.19 2,835.74 2,735.24 2,421.24 -1,508.87 5,971,209.87 560,573.25 2.25 -2,421.24 MWD+IFR-AK-CAZ-SC (3) 4,551.46 68.80 321.91 2,852.08 2,751.58 2,454.74 -1,534.52 5,971,243.15 560,547.32 2.64 -2,454.74 MWD+IFR-AK-CAZ-SC (3) 4,601.20 68.93 320.38 2,870.02 2,769.52 2,490.87 -1,563.63 5,971,279.04 560,517.92 2.88 -2,490.87 MWD+IFR-AK-CAZ-SC (3) 4,652.27 68.66 317.69 2,688.49 2,787.99 2,526.82 -1,594.84 5,971,314.72 560,486.42 4.94 -2,526.82 MWD+IFR-AK-CAZ-SC (3) 4,695.93 67.82 314.97 2,904.68 2,804.18 2,556.15 -1,622.83 5,971,343.81 560,458.18 6.10 -2,556.15 MWD+IFR-AK-CAZ-SC (3) 4,741.75 66.56 312.96 2,922.44 2,821.94 2,585.47 -1,653.23 5,971,372.88 560,427.55 4.89 -2,585.47 MWD+IFR-AK-CAZ-SC (3) 4,791.17 65.32 309.76 2,942.60 2,842.10 2,615.29 -1,687.09 5,971,402.41 560,393.45 6.42 -2,615.29 MWD+IFR-AK-CAZ-SC (3) 4,837.62 65.20 307.28 2,962.04 2,861.54 2,641.56 -1,720.09 5,971,428.41 560,360.23 4.86 -2,641.56 MWD+IFR-AK-CAZ-SC (3) 4,885.47 65.86 304.28 2,981.86 2,881.36 2,667.01 -1,755.42 5,971,453.57 560,324.70 5.87 -2,667.01 MWD+IFR-AK-CAZ-SC (3) i 4,931.69 66.66 302.49 3,000.47 2,899.97 2,690.29 -1,790.75 5,971,476.55 560,289.18 3.94 -2,690.29 MWD+IFR-AK-CAZ-SC (3) 4,979.93 66.49 300.50 3,079.65 2,919.15 2,713.41 -1,828.49 5,971,499.36 560,251.26 3.80 -2,713.41 MWD+IFR-AK-CAZ-SC (3) 5,026.88 66.90 298.16 3,038.23 2,937.73 2,734.53 -1,866.08 5,971,520.17 560,213.50 4.66 -2,734.53 MWD+IFR-AK-CAZ-SC (3) 5,075.65 67.48 296.20 3,057.13 2,956.63 2,755.07 -1,906.07 5,971,540.36 560,173.34 3.89 -2,755.07 MWD+IFR-AK-CAZ-SC (3) 5,122.83 66.43 292.82 3,075.61 2,975.11 2,773.08 -1,945.56 5,971,558.05 560,133.71 6.96 -2,773.08 MWD+IFR-AK-CAZ-SC (3) 5,171.43 I 66.15 290.26 3,095.15 2,994.65 2,789.41 -1,986.94 5,971,574.04 560,092.19 4.86 -2,789.41 MWD+IFR-AK-CAZ-SC (3) 5,218.47 66.25 287.55 3,114.14 3,013.64 2,803.36 -2,027.66 5,971,587.64 560,051.37 5.28 -2,803.36 MWD+IFR-AK-CAZ-SC (3) 5,267.44 67.09 285.02 3,133.53 3,033.03 2,815.96 -2,070.81 5,971,599.89 560,008.11 5.04 -2,815.96 MWD+IFR-AK-CAZ-SC (3) 5,312.08 67.20 282.82 3,150.87 3,050.37 2,825.66 -2,110.74 5,971,609.45 559,968.11 4.55 -2,825.86 MWD+IFR-AK-CAZ-SC (3) 5,361.27 66.28 279.48 3,170.30 3,069.80 2,834.60 -2,155.07 5,971,617.83 559,923.71 6.51 -2,834.60 MWD+{FR-AK-CA2-SC (3) 5,412.46 66.84 275.53 3,190.67 3,090.17 2,840.73 -2,201.62 5,971,623.57 559,877.12 7.16 -2,840.73 MWD+IFR-AK-CAZ-SC (3) 5,457.39 66.76 273.44 3,206.37 3,107.87 2,643.96 -2,242.79 5,971,626.46 559,835.93 4.28 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 5,512.09 67.69 270.51 3,229.55 3,129.05 2,845.69 -2,293.18 5,971,627.77 559,785.52 5.22 -2,845.69 MWD+IFR-AK-CAZ-SC (3) 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,627.07 559,748.35 5.19 -2,845.30 MWD+IFR-AK-CAZ-SC (3) 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,624.22 559,702.54 5.37 -2,842.82 MWD+IFR-AK-CAZ-SC (3) 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,619.84 559,661.20 4.55 -2,838.78 MWD+IFR-AK-CAZ-SC (3) 5,696.76 66.30 261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,613.53 559,616.72 3.38 -2,832.85 MWD+IFR-AK-CAZ-SC (3) 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,606.05 559,575.01 4.90 -2,825.70 MWD+IFR-AK-CAZ-SC (3) I 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 559,532.36 6.07 -2,816.23 MWD+IFR-AK-CAZ-SC (3) 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,584.50 559,490.72 4.59 -2,804.86 MWD+IFR-AK-CAZ-SC (3) 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 559,447.91 6.88 -2,790.79 MWD+IFR-AK-CAZ-SC (3) 5,933.84 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,971,554.19 559,407.88 5.40 -2,775.22 MWD+IFR-AK-CAZ-SC (3) 5,978.50 67.04 245.10 3,413.51. 3,313.01 2,758.63 -2,709.25 . 5,971,537.28 559,370.24 5.39 -2,758.63 MWD+IFR-AK-CAZ-SC (3) I 6/3/2008 2:53:30PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(A laska) Inc. Loca) Co-ordinate Reference : Well 1G172 Project: Kupa ruk River Unit ND Reference: 1C-172A @ 100.SOft (Doyon 15) Site: Kupa ruk 1C Pad MD Reference: 1C-172A ~ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2P62 Survey Calc ulation Method: Minimum Curvature Design: 1C-172AL2P62 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°} (ft) (ft) (ft) {ft) (ft) (ft) (°/1 00') (ft) Survey Tool Name 6,02b.43 66.58 242.95 3,433.18 3,3:12.68 2,730.53 -2,750.5) 5,9.1,-.516.3) 559,329.15 4.06 -2,738.53 MWD+IFR-AK-I;AZ-0C(3) 6,074.69 67.49 240.86 3,451.23 3,350.73 2,718.47 -2,788.07 5,971,496.48 559,291.75 4.60 -2,718.47 MWD+IFR-AK-CAZSC (3) 6,123.77 67.64 238.03 3,469.96 3,369.46 2,695.41 -2,827.13 5,971,473.10 559,252.89 5.34 -2,695.41 MWD+IFR-AK-CAZ-SC (3) 6,169.08 66.75 235.65 3,487.52 3,387.02 2,672.57 -2,862.10 5,971,449.97 559,218.12 5.23 -2,672.57 MWD+IFR-AK-CAZSC (3) 6,218.69 67.03 233.61 3,507.00 3,406.50 2,646.16 -2,899.30 5,971,423.25 559,181.14 3.82 -2,646.16 MWD+IFR-AK-CAZ-SC (3) 6,267.43 67.68 230.95 3,525.69 3,425.19 2,618.62 -2,934.90 5,971,395.42 559,145.77 5.33 -2,618.62 MWD+IFR-AK-CAZ-SC (3) 6,314.03 66.91 229.11 3,543.60 3,443.10 2,590.99 -2,967.87 5,971,367.52 559,713.03 4.20 -2,590.99 MWD+IFR-AK-CAZ-SC (3) 6,358.62 66.68 226.98 3,561.17 3,460.67 2,563.59 -2,998.35 5,971,339.88 559,062.79 4.42 -2,563.59 MWD+IFR-AK-CAZ-SC (3) 6,409.08 66.96 224.00 3,581.04 3,480.54 2,531.08 -3,031.42 5,971,307.09 559,049.99 5.46 -2,531.08 MWD+IFR-AK-CAZ-SC (3) 6,455.79 66.97 221.59 3,599.32 3,498.82 2,499.54 -3,060.62 5,971,275.31 559,021.05 4.75 -2,499.54 MWD+IFR-AK-CAZ-SC (3) 6,505.16 67.34 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 558,992.00 5.37 -2,464.77 MWD+IFR-AK-CAZ-SC (3) 6,551.22 66.83 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 558,966.37 4.48 -2,431.19 MWD+IFR-AK-CAZ-SC (3) 6,599.24 66.93 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 558,94123 5.33 -2,395.09 MWD+IFR-AK-CAZSC (3) 6,650.05 68.21 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 558,916.38 5.57 -2,355.45 MWD+IFR-AK-CAZ-SC (3) 6,696.47 67.69 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 558,895.30 5.08 -2,318.13 MWD+IFR-AK-CAZ-SC (3) 6,750.16 68.65 204.63 3,712.07 3,611.57 2,273.58 -3,210.20 5,971,048.15 558,873.36 7.06 -2,273.58 MWD+IFR-AK-CAZ-SC (3) 6,791.15 68.79 203.77 3,726.95 3,626.45 2,238.74 5,225.86 5,971,013.18 558,858.00 1.98 -2,238.74 MWD+IFR-AK-CAZSC (3) 6,841.03 70.50 201.93 3,744.30 3,643.60 2,195.65 5,244.01 5,970,969.95 558,840.20 4.87 -2,195.65 MWD+IFR-AK-CAZSC (3) 6,887.05 72.42 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 558,824.71 4.97 -2,154.99 MWD+IFR-AK-CAZ-SC (3) 6,937.09 75.14 200.64 3,772.91 3,672.41 2,110.03 5,276.77 5,970,884.07 558,808.16 5.44 -2,110.03 MWD+IFR-AK-CAZ-SC (3) 6,981.79 75.77 197.68 3,784.14 3,683.64 2,069.16 5,290.96 5,970,843.09 558,794.30 6.56 -2,069.16 MWD+IFR-AK-CAZ-SC (3) 7,032.37 76.56 195.96 3,796.23 3,695.73 2,022.15 5,305.17 5,970,795.97 558,780.48 3.65 -2,022.15 MWD+IFR-AK-CAZ-SC (3) 7,076.80 77.92 193.87 3,806.05 3,705.55 1,980.28 5,316.32 5,970,754.01 558,769.68 5.52 -1,980.28 MWD+IFR-AK-CAZ-SC (3) 7,124.94 80.37 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 558,758.92 5.18 -1,934.34 MWD+IFR-AK-CAZ-SC (3) 7,171.02 83.10 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 558,748.90 6.01 -1,889.94 MWD+IFR-AK-CAZ-SC (3) 7,217.39 84.93 191.34 3,826.57 3,726.07 1,844.86 5,347.55 5,970,618.35 558,739.58 5.23 -1,644.86 MWD+IFR-AK-CAZ-SC (3) 7,266.96 84.23 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 558,731.41 5.58 -1,796.26 MWD+IFR-AK-CAZ-SC (3) 7,312.29 84.28 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 558,726.26 7.09 -1,751.51 MWD+IFR-AK-CAZ-SC (3) • 7,357.00 84.36 183.09 3,840.22 3,739.72 1,707.14 -3,364.94 5,970,480.50 558,723.33 5.19 -1,707.14 MWD+IFR-AK-CAZ-SC (4) 7,427.16 87.15 184.80 3,645.41 3,744.91 1,637.35 5,369.75 5,970,410.68 558,719.09 4.66 -1,637.35 MWD+IFR-AK-CAZ-SC (4) 7,473.28 88.70 185.92 3,847.08 3,746.58 1,591.46 5,374.06 5,970,364.77 558,715.17 4.15 -1,591.46 MWD+IFR-AK-CAZ-SC (4) 7,522.99 90.36 187.12 3,847.49 3,746.99 1,542.08 -3,379.70 5,970,315.34 558,709.93 4.12 -1,542.08 MWD+IFR-AK-CAZ-SC (4) 7,567.91 91.90 188.21 3,846.60 3,746.10 1,497.57 -3,385.69 5,970,270.79 558,704.31 4.20 -1,497.57 MWD+IFR-AK-CAZ-SC (4) 7,617.53 88.75 189.41 3,846.32 3,745.82 1,448.55 -3,393.29 5,970,221.71 558,697.12 6.79 -1,448.55 MWD+IFR-AK-CAZ-SC (4) 7,662.04 86.17 190.49 3,848.29 3,747.79 1,404.75 -3,400.97 5,970,177.86 558,689.80 6.28 -1,404.75 MWD+IFR-AK-CAZ-SC (4) 7,713.67 86.91 189.00 3,851.41 3,750.91 1,353.96 5,409.70 5,970,127.00 558,681.50 3.22 -1,353.96 MWD+IFR-AK-CAZ-SC (4) 7,756.46 87.96 187.75 3,853.32 3,752.82 1,311.67 5,415.92 5,970,084.66 558,675.63 3.81 -1,311.67 MWD+IFR-AK-CAZ-SC (4) 7,807.68 90.73 186.75 3,853.91 3,753.41 1,260.87 -3,422.39 5,970,033.62 558,669.58 5.75 -1,260.87 MWD+IFR-AK-CAZ-SC (4) 7,850.84 93.33 185.88 3,852.38 3,751.88 1,218.00 5,427.13 5,969,990.91 558,665.20 6.35 -1,218.00 MWD+IFR-AK-CAZ-SC (4) 7,902.81 93.57 184.51 3,849.25 3,748.75 1,166.34 -3,431.83 5,969,939.22 558,660.93 2.67 -1,166.34 MWD+IFR-AK-CAZSC (4) 8/3/2008 2:53:30PM Page 5 COMPASS 2003.16 Build 42F i ~ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference : V~lell 1C-172 Project: Kuparuk River Unit ND Refere nce: iC-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: iC-172A @ 1 00.50ft (Doyon 15) Well: 1C-1 72 North Reference: True Wellbore: 1C-1 72AL2P62 Survey Calc ulation Method: Minimu m Curvature Design: 1C-1 72AL2P62 Database: CPAI E DM Production - - _ Survey ' Map Map Vertical MD Inc Azt ND TVDSS +N/-S +E!-W Northing Easting D LS Section (ft) (°) (°) (ft) (ft) (ft) lft) (ft) (ft) (°11 00') (ft) Survey Tool Name 7,944.87 51A7 18`[.75 3,&17.43 3,74c.93 1,124A3 -3,434.49 5,969,897.27 558,858.61 6.b'2 -1,124.41 MWD+iFR-AK-CAZ-~G ~4~ 7,999.15 90.98 179.65 3,846.29 3,745.79 1,070.16 -3,435.62 5,969,843.02 558,657.93 5.76 -1,070.16 MWD+IFR-AK-CAZ-SC (4) 8,040.57 90.55 176.12 3,845.74 3,745.24 1,028.78 -3,434.09 5,969,801.66 558,659.60 8.58 -1,028.78 MWD+IFR-AK-CAZ-SC (4) 8,092.17 91.91 174.50 3,844.63 3,744.13 977.37 -3,429.88 5,969,750.29 558,664.44 4.10 -977.37 MWD+IFR-AK-CAZ-SC (4) 8,134.65 91.54 172.37 3,843.35 3,742.85 935.19 -3,425.02 5,969,708.15 558,669.64 5.09 -935.19 MWD+IFR-AK-CAZ-SC (4) 8,184.47 90.86 171.92 3,842.31 3,741.81 885.85 -3,418.22 5,969,658.87 558,676.86 1.64 -885.85 MWD+IFR-AK-CAZ-SC (4) 8,229.10 90.68 171.77 3,841.71 3,741.21 841.67 -3,411.89 5,969,614.76 558,683.55 0.52 -641.67 MWD+IFR-AK-CAZ-SC (4) 8,322.92 90.55 173.59 3,840.70 3,740.20 748.62 -3,399.93 5,969;521.82 558,696.27 1.94 -748.62 MWD+IFR-AK-CAZ-SC (4) 8,373.67 90.86 175.50 3,840.08 3,739.58 698.11 -3,395.11 5,969,471.35 558,701.51 3.81 -698.17 MWD+IFR-AK-CAZ-SC (4) 8,416.78 92.46 177.43 3,838.83 3,738.33 655.10 -3,392.45 5,969,428.38 558,704.53 5.61 -655.10 MWD+IFR-AK-CAZ-SC (4) 8,463.30 92.22 178.09 3,636.93 3,736.43 608.66 -3,390.64 5,969,381.95 558,706.73 1.51 -608.66 MWD+IFR-AK-CAZ-SC (4) 8,511.86 94.81 178.89 3,833.95 3,733.45 560.21 -3,389.36 5,969,333.52 558,708.41 5.58 -560.21 MWD+IFR-AK-CAZ-SC (4) 8,557.92 92.52 178.14 3,831.01 3,730.51 514.26 -3,388.17 5,969,287.59 558,709.98 5.23 -514.26 MWD+IFR-AK-CAZ-SC (4) 8,606.12 89.93 177.82 3,829.98 3,729.48 466.11 -3,386.47 5,969,239.45 558,712.07 5.47 -466.11 MWD+IFR-AK-CAZ-SC (4) 8,700.51 69.87 177.47 3,830.14 3,729.64 371.80 -3,382.59 5,969,145.19 558,716.73 0.38 -371.80 MWD+IFR-AK-CAZ-SC (4) 8,794.90 92.65 180.52 3,828.07 3,727.57 277.47 -3,380.93 5,969,050.88 558,719.17 4.37 -277.47 MWD+IFR-AK-CAZ-SC (4) 8,868.83 92.10 182.11 3,824.18 3,723.68 783.65 -3,383.09 5,968,957.06 556,717.79 1.79 -183.65 MWD+IFR-AK-CAZSC (4) 8,940.01 92.22 181.46 3,822.25 3,721.75 132.53 -3,384.68 5,968,905.93 558,716.62 1.29 -132.53 MWD+IFR-AK-CAZ-SC (4) 8,983.33 90.49 177.58 3,821.22 3,720.72 89.23 -3,384.32 5,968,862.64 558,717.34 9.80 -89.23 MWD+IFR-AK-CAZ-SC (4) 9,034.53 91.54 172.07 3,820.32 3,719.82 38.27 -3,379.70 5,968,811.73 558,722.38 10.95 -38.27 MWD+IFR-AK-CAZ-SC (4) 9,076.61 92.09 172.07 3,818.98 3,718.48 -3.39 -3,373.90 5,968,770.12 558,728.53 1.31 3.39 MWD+IFR-AK-CAZSC (4) 9,170.62 90.12 168.85 3,817.17 3,716.67 -96.06 -3,358.32 5,968,677.59 558,744.87 4.07 96.06 MWD+IFR-AK-CAZ-SC (4) 9,216.06 90.00 165.20 3,817.12 3,716.62 -140.60 -3,349.28 5,968,633.14 558,754.27 1.45 140.60 MWD+IFR-AK-CAZ-SC (4) 9,264.24 89.56 168.83 3,817.31 3,716.81 -187.81 -3,339.69 5,968,586.01 558,764.26 1.59 187.81 MWD+IFR-AK-CAZ-SC (4) 9,294.65 91.04 170.45 3,817.15 3,716.65 -217.72 -3,334.22 5,968,556.14 558,769.97 7.22 217.72 MWD+IFR-AK-CAZ-SC (4) 9,329.58 89.68 171.82 3,816.93 3,716.43 -252.23 -3,328.84 5,968,521.68 558,775.64 5.53 252.23 MWD+IFR-AK-CAZ-SC (4) 9,358.30 90.49 173.15 3,816.89 3,716.39 -280.70 -3,325.08 5,968,493.25 558,779.63 5.42 280.70 MWD+IFR-AK-CAZ-SC (4) 9,410.71 90.06 177.37 3,816.63 3,776.13 -332.92 -3,320.75 5,968,441.07 558,784.39 8.09 332.92 MWD+IFR-AK-CAZ-SC (4) 9,452.15 90.98 182.95 3,816.26 3,715.76 -374.34 -3,320.87 5,968,399.65 558,784.62 13.65 374.34 MWD+IFR-AK-CAZ-SC (4) 9,502.30 88.20 786.51 3,816.62 3,716.12 424.31 -3,325.00 5,968,349.66 558,780.90 9.01 424.31 MWD+IFR-AK-CAZ-SC (4) 9,546.30 89.19 187.62 3,817.62 3,717.12 -467.96 -3,330.47 5,968,305.97 558,775.85 3.38 467.96 MWD+IFR-AK-CAZ-SC (4) 9,598.45 91.10 186.53 3,817.49 3,716.99 -519.71 -3,336.84 5,968,254.17 558,769.86 4.22 519.71 MWD+IFR-AK-CAZ-SC (4) 9,639.41 91.17 184.43 3,816.67 3,716.17 560.47 -3,340.75 5,968,213.38 558,766.29 5.13 560.47 MWD+IFR-AK-CAZ-SC (4) 9,689.90 90.18 780.56 3,816.08 3,715.58 510.90 -3,342.94 5,968,162.94 558,764.51 7.91 610.90 MWD+IFR-AK-CAZ-SC (4) 9,732.91 89.81 177.04 3,816.08 3,715.58 553.90 -3,342.04 5,968,119.96 558,765.76 8.23 653.90 MWD+IFR-AK-CAZ-SC (4) 9,783.47 90.36 175.45 3,816.01 3,715.51 -704.35 -3,338.73 5,968,069.55 558,769.49 3.33 704.35 MWD+IFR-AK-CAZ-SC (4) 9,825.83 89.63 177.06 3,816.01 3,715.51 -746.61 -3,335.97 5,968,027.31 556,772.61 4.17 746.61 MWD+IFR-AK-CAZ-SC (4) 9,877.66 91.47 180.78 3,815.51 3,715.01 -798.42 -3,334.99 5,967,975.51 558,774.01 8.01 798.42 MWD+IFR-AK-CAZ-SC (4) 9,890.00 91.40 180.63 3,815.21 3,714.71 -810.78 -3,335.14 5,967,963.18 558,773.96 1.34 810.76 MWD+IFR-AK-CAZ-SC (5) 9,920.28 89.50 182.90 3,814.97 3,714.47 -841.02 -3,336.07 5,967,932.91 558,773.28 9.78 841.02 MWD+IFR-AK-CAZ-SC (5) 6/3/2008 2:53:30PM Page 6 COMPASS 2003.16 Buitd 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Al aska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kupa ruk River Unit ND Referen ce: 1C-172A @ 100.SOft (Doyon 15) Site: Kupa ruk 1C Pad MD Reference: 1C-172A @ 100.SOk(Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172AL2PB2 Survey Calc ulation Method: Minimum Curvature Design: 1C-172AL2P62 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting D LS Section (ft) (°) (°) (h) ln) ln) (ft) (ft) (ft) (°11 00') (ft) Survey Tool Name 6,9%0.12 50.67 1b4.65 3,614.05 3,714.3y -d8u.74 -J,aJ8.48 5,567,&83.17 558,770.28 4.74 o4>U.74 tv1WD+IFR-AK-CAZSC (5) 10,015.03 91.42 186.41 3,814.07 3,713.57 -935.33 -3,344.71 5,967,838.54 558,765.43 7.88 935.33 MWD+IFR-AK-CAZ-SC (5) 10,065.80 89.50 191.30 3,813.67 3,713.17 -985.34 -3,353.39 5,967,788.47 558,757.15 6.83 985.34 MWD+IFR-AK-CAZ-SC (5) 10,107.24 90.36 191.33 3,813.72 3,713.22 -1,025.97 -3,361.53 5,967,747.77 558,749.36 2.08 1,025.97 MWD+IFR-AK-CAZ-SC (5) 10,156.86 92.95 191.25 3,812.28 3,711.78 -1,074.61 -3,371.23 5,967,699.06 558,740.06 5.22 1,074.61 MWD+IFR-AK-CAZ-SC (5) 10,201.66 90.85 190.38 3,810.80 3,710.30 -1,118.59 -3,379.64 5,967,655.02 558,732.02 5.07 1,118.59 MWD+IFR-AK-CAZSC (5) 10,252.49 91.41 190.82 3,609.80 3,709.30 -1,168.54 -3,388.98 5,967,605.00 558,723.09 1.40 1,166.54 MWD+IFR-AK-CAZ-SC (5) 10,294.64 90.55 189.88 3,609.08 3,708.58 -1,210.00 -3,396.56 5,967,563.46 558,715.86 3.02 1,210.00 MWD+IFR-AK-CAZ-SC (5) 10,389.16 91.97 189.70 3,807.00 3,706.50 -1,303.11 3,412.62 5,967,470.24 558,700.56 1.51 1,303.11 MWD+IFR-AK-CAZ-SC (5) 10,482.24 90.43 187.06 3,805.05 3,704.55 -1,395.17 3,426.18 5,967,378.09 556,687.77 3.28 1,395.17 MWD+IFR-AK-CAZ-SC (5) 10,577.44 90.79 183.24 3,804.03 3,703.53 -1,489.96 -3,434.73 5,967,283.24 558,680.01 4.03 1,489.96 MWD+IFR-AK-CAZ-SC (5) 10,671.15 90.37 185.38 3,803.09 3,702.59 -1,583.40 -3,441.77 5,967,189.76 558,673.74 2.33 1,583.40 MWD+IFR-AK-CAZ-SC (5) 10,728.38 90.00 187.16 3,802.90 3,702.40 -1,640.28 3,448.02 5,967,132.83 558,667.96 3.18 1,640.28 MWD+IFR-AK-CAZ-SC (5) 10,764.49 89.32 187.79 3,803.11 3,702.61 -1,676.08 3,452.72 5,967,096.99 558,663.56 2.57 1,676.08 MWD+IFR-AK-CAZ-SC (5) 10,811.61 89.19 187.34 3,803.73 3,703.23 -1,722.79 3,458.92 5,967,050.24 558,657.75 0.99 1,722.79 MWD+IFR-AK-CAZ-SC (5) 10,858.41 91.78 188.02 3,803.33 3,702.83 -1,769.16 -3,465.17 5,967,003.82 558,651.88 5.72 1,769.16 MWD+IFR-AK-CAZ-SC (5) 10,906.56 94.07 188.04 3,800.87 3,700.37 -1,816.78 -3,471.89 5,966,956.16 558,645.56 4.76 1,816.78 MWD+IFR-AK-CAZ-SC (5) 10,951.95 91.72 186.28 3,798.58 3,698.08 -1,861.75 3,477.54 5,966,911.14 558,640.28 6.47 1,861.75 MWD+IFR-AK-CAZ-SC (5) 10,999.56 89.00 185.80 3,798.28 3,697.78 -1,909.09 -3,482.55 5,966,863.77 558,635.66 5.80 1,909.09 MWD+IFR-AK-CAZ-SC (5) 11,047.29 89.50 184.65 3,798.91 3,698.41 -1,956.62 3,486.89 5,966,816.21 558,631.71 2.63 1,956.62 MWD+IFR-AK-CAZ-SC (5) 11,093.03 91.04 183.37 3,798.69 3,698.19 -2,002.24 -3,490.09 5,966,770.57 558,628.89 4.38 2,002.24 MWD+IFR-AK-CAZ-SC (5) 11,141.50 91.41 183.33 3,797.66 3,697.16 -2,050.62 3,492.92 5,966,722.17 558,626.46 0.77 2,050.62 MWD+IFR-AK-CAZ-SC (5) 11,185.62 90.61 179.66 3,796.88 3,696.38 -2,094.71 3,494.07 5,966,678.08 558,625.67 8.51 2,094.71 MWD+IFR-AK-CAZ-SC (5) 11,235.90 91.35 178.35 3,796.02 3,695.52 -2,144.97 3,493.20 5,966,627.83 558,626.96 2.99 2,144.97 MWD+IFR-AK-CAZSC(5) 11,279.41 91.29 179.28 3,795.02 3,694.52 -2,188.46 -3,492.30 5,966,584.35 558,628.22 2.14 2,188.46 MWD+IFR-AK-CAZ-SC (5) 11,329.70 91.41 180.96 3,793.83 3,693.33 -2,238.74 -3,492.41 5,966,534.08 558,628.53 3.35 2,238.74 MWD+IFR-AK-CAZ-SC (5) 11,374.87 90.49 181.02 3,793.08 3,692.58 -2,283.89 3,493.19 5,966,488.93 558,628.13 2.04 2,283.89 MWD+IFR-AK-CAZ-SC (5) 11,423.76 91.29 181.76 3,792.32 3,691.82 -2,332.76 3,494.37 5,966,440.05 558,627.34 2.23 2,332.76 MWD+IFR-AK-CAZSC (5) 11,467.30 88.57 181.68 3,792.38 3,691.88 -2,376.28 -3,495.68 5,966,396.53 556,626.40 6.25 2,376.28 MWD+IFR-AK-CAZ-SC (5) 11,518.02 89.44 181.36 3,793.26 3,692.76 -2,426.97 -3,497.02 5,966,345.83 558,625.47 1.83 2,426.97 MWD+IFR-AK-CAZ-SC (5) 11,611.62 90.24 181.12 3,793.52 3,693.02 -2,520.55 3,499.05 5,966,252.25 558,624.22 0.89 2,520.55 MWD+IFR-AK-CAZ-SC (5) 11,703.13 90.00 179.81 3,793.33 3,692.83 -2,612.05 -3,499.79 5,966,160.75 558,624.24 1.46 2,612.05 MWD+IFR-AK-CAZSC (5) 11,799.02 91.04 179.89 3,792.46 3,691.96 -2,707.94 3,499.54 5,966,064.88 556,625.28 1.09 2,707.94 MWD+IFR-AK-CAZSC (5) 11,845.11 91.04 179.39 3,791.62 3,691.12 -2,754.02 -3,499.25 5,966,018.81 558,625.95 1.08 2,754.02 MWD+IFR-AK-CAZ-SC (5) 11,892.91 90.55 179.18 3,790.96 3,690.46 -2,801.81 -3,498.66 5,965,971.03 558,626.94 1.12 2,801.81 MWD+IFR-AK-CAZ-SC (5) 11,933.69 90.24 176.59 3,790.67 3,690.17 -2,842.56 -3,497.15 5,965,930.30 558,628.79 6.40 2,842.56 MWD+IFR-AK-CAZ-SC (5) 11,986.14 90.80 173.48 3,790.20 3,689.70 -2,894.80 3,492.61 5,965,878.10 558,633.76 6.02 2,894.80 MWD+IFR-AK-CAZ-SC (5) 12,037.70 92.22 172.83 3,788.84 3,688.34 -2,945.98 -3,486.47 5,965,826.99 558,640.32 3.03 2,945.98 MWD+IFR-AK-CAZ-SC (5) 12,079.07 89.13 174.17 3,788.35 3,687.85 -2,987.07 -3,461.79 5,965,785.93 558,645.34 8.14 2,987.07 MWD+IFR-AK-CAZ-SC (5) 12,131.47 91.10 174.91 3,788.25. 3,687.75 -3,039.23 -3,476.80 5,965,733.62 558,650.76 4.02 3,039.23 MWD+IFR-AK-CAZ-SC (5) 6/3/2008 2:53:30PM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-172 W e l l bo re: 1 C-172AL2P62 Design: 1 C-172AL2P62 Survey MD Inc Azl ND NDSS (ft) l°) (°1 In) (n) 12,173.65 bU.ti1 174.47 J,7a7.b2 s,od7.12 12,218.13 90.67 176.12 3,787.12 3,686.62 12,220.51 90.85 176.24 3,787.09 3,686.59 12,230.37 91.90 176.58 3,786.85 3,686.35 12,241.04 93.26 179.28 3,786.37 3,685.87 12,250.48 93.87 178.97 3,785.79 3,685.29 12,267.83 92.89 160.82 3,784.76 3,684.26 12,308.48 89.31 182.02 3,783.98 3,663.48 12,424.00 89.31 182.02 3,785.37 3,684.87 Local Co-ordinate Reference : ~A1ell 1C-172 ND Refere nce: 1C-172A @ 1 00.SOft (Doyon 15) MD Referen ce: 1C-172A @ 1 00.SOft(Doyon 15) North Refer ence: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map Map Vertical +Nf-S +E/-W Northing Easting DLS Section (ft) (ft) {ff) (ft) (°I100') (ft) Survey Tool Name -3,081.22 -a,d72.50 5,965,691.87 558,655.01 L56 3,081.22 MWD+IFR-Ah-GAZ-SG tS) -3,125.55 -3,469.25 5,965,647.58 558,659.02 3.71 3,125.55 MWD+IFR-AK-CAZ-SC (5) -3,127.92 -3,469.09 5,965,645.20 558,659.20 9.09 3,127.92 MWD+IFR-AK-CAZ-SC (5) -3,137.76 -3,468.48 5,965,635.37 558,659.90 11.19 3,137.76 MWD+IFR-AK-CAZSC (5) -3,148.41 -3,468.09 5,965,624.73 558,660.37 28.31 3,148.41 MWD+IFR-AK-CAZ-SC (5) -3,157.83 -3,467.95 5,965,615.31 558,660.60 7.25 3,157.83 MWD+IFR-AK-CAZ-SC (5) -3,175.15 -3,467.91 5,965,597.99 558,660.77 12.05 3,175.15 MWD+IFR-AK-CAZ-SC (5) -3,215.77 -3,468.92 5,965,557.37 558,660.10 9.29 3,215.77 MWD+IFR-AK-CAZ-SC (5) -3,331.21 -3,472.99 5,965,441.91 558,656.98 0.00 3,331.21 PROJECTED to TD 6/3/2008 2:53:30PM Page 8 COMPASS 2003.16 Build 42F ~ ~ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Production Profile 20Sep-08 1 G172 L2 1 BL /EDE 50-029-23 1 59-7 1 2] Leak Detection - WLD 27 Aug-08 1 D~07 EDE 50-029-20430-00 ~O~ O~U ~ 1(~9~/(~ Signed : _ Date :j Print Name: ~ r e~~~. p _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: "~93s:~^r?'Ji:~t~l~t^~Ei,?`77L7Y'-/~+7t1.•CO~ WEBStTE:'A~i~l~~:'.~?~~?^,.j1~~?.i."Js`l /~ C:\Documents and Settings\Owner\Desktop\Transnut_Conoco.doc WELL L®G TRAI~SMIT'I'AL 'T®o State of Alaska July 18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1C-172A+L1+L2+L2PB1+L2PB2 AK-MW-5476893 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 C-172A+L 1+L2+L2PB 1+L2PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23159-01,60,61, 70, 71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23159-01,60,61,70,71 Digital Log Images 1 CD Rom 50-029-23159-01,60,61,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 9951;8_ Anchorage, Alaska 99508 `~ j l ~5~ ~~ ~ ir_ y-fia Date: _ _ Signed:( ~~ ~ ~--~' ~~ ,~~ U • 20-Jun-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-172AL2 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 12,079.07' MD Window /Kickoff Survey: 12,100.00' MD (if applicable) Projected Survey: 13,018.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ,~,W ~,~~~ ,Signed V Please call me at 273-3534 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ! • 20-Jun-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-172AL2PB1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 7,312.29' MD Window /Kickoff Survey: 7,357.00' MD (if applicable) Projected Survey: 10,205.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~,H, ~ ~1d~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 20-Jun-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-172AL2PB2 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 9,877.66' MD Window /Kickoff Survey: 9,890.00' MD (if applicable) Projected Survey: 12,424.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~,N ~~..,,` ~ii~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) WELL LOG TRANSMITTAL To: State of Alaska June 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1C-172A L2 AK-MW-5476893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23159-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: - ..~ '`- .. , . ti Signed: ~_o~~ l~5~ r ~o WELL LOG TRANSMITTAL To: State of Alaska June 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1 C-172A L2 PB 1 AK-MW-5476893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23159-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~gned: ~ a ~~-oi~ ~~~sz~a WELL LOG TRANSMITTAL To: State of Alaska June 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1C-172A L2 PB2 AK-MW-5476893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23159-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _ _ Signed: ~o ~ - o ro ~ ~~-03 1C-172A L2 BP1 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 29, 2008 8:39 AM To: 'Reilly, Patrick J' Subject: RE: 1 C-172A L2 (208-010) P61 Thanks Pat. I will place a copy of this message in the file. Please include the permit number in the message title. Tom Maunder, PE AOGCC From: Reilly, Patrick J [mailto:Patrick.J.Reilly(alconocophilfips.com) Sent: Tuesday, April 29, 2008 7:20 AM To: Maunder, Thomas E (DOA) Subject: 1C-172A L2 BPl Tom, The details of the sidetrack are as follows: • Well: 1 C-172A • Rig: Doyon 15 Date: 4/29/08 • Time: 0300 hrs • Last Casing: A4 Window 7,357' • MD of abandoned section: 9,874' - 10,175' We were having some leftlright directional control problems and wanted to get closer #o the planned directional path. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. tf you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR {907) 265-1535 FAX Patrick.J. Reifly@conocophillips.com 4/29/2008 r I~~ ~ p ~ ~ ~~ ~ .. ~ i. " ~ t .) ~ ~ p f . t ~'1, f , ALASSA OIL AP1TD GA.S C01~5ERQATIOI~T COl-IIrIISSI0I~T Randy Thomas Drilling Team Leader Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1C-172A-L2 Conoco Phillips Alaska, Inc. Permit No: 208-010 Surface Location: 1436' FNL, 1096' FWL, SEC. 12, Tl iN, R10E, UM Bottomhole Location: 181' FNL, 2423 FEL, SEC. 14, TI 1N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1C-172A-L2, Permit No 208-01.0, API 50-029-23 1 59-6 1-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply.with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6~,9~3607 (pager). DATED thir~ day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~ ~~ y~ STATE OF ALASKA ~" mod- ~ 2 3 2~[j JAN ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil ~ Oas Cons. Cof~... ,~ (~$ 20 AAC 25.005 Anchorage 1a. Type o~rk: (,7j Drill Re-drill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. BondC' ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1C-172A-L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13164' ND: 3796' - 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11 N, R10E, UM 7. Property Designation: ADL 25649, 25650 West Sak Oil Pool Top of Productive Horizon: 60' FSL, 2249' FEL, Sec. 2, T11 N, R10E, UM 8. Land Use Permit: ALK 467, 468 13. Approximate Spud Date: 3!2512008 Total Depth: 181' FNL, 2423' FEL, Sec. 14, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to 73 ~,'!,e s Nearest Property: /2.484'- 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562102 y- 5968801 'Zone- 4 10. KB Elevation (Height above GL): 99' AMSL feet 15. Distance to Nearest r-~¢-ob well within Pool: 1C-102 , 56' 16. Deviated wells: Kickoff depth: (,, Maximum HoleAngle~b 1°I"LD'4feg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1686 psig Surface: 1264 psig 18. Casing Program ecifications S Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (inGuding stage data) 20" 16" 109# K-55 Welded 80' 40' 40' ~ 121' 121' - 260 cf ArcticCRETE 12.25" 9-5/8" 40# L-80 BTC 3460' 40' 40' 3500' 2435' 740 sx AS Lite, 230 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8317' 40' 40' - 8400' 3944' 414 sx DeepCRETE 6.75" 4.5" 12.6# L-80 BTC 5991' 7646' 3852' .13164' 3796' - slotted 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 11970' Total Depth ND (ft): 3933' Plugs (measured) Effective Depth MD (ft): 11960' Effective Depth ND (ft): 3924' Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 121' 121' Surface 6712' 9-5/8" 6712' 3816' Intermediate Production 5248' 5.5" 11960' 3924' Liner Perforation Depth MD (ft): 6788'-11880' Perforation Depth ND (ft): 3838'-3908' 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact Steve Shultz @ 265-6178 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ ` ~ Phone LG~ 6-~ 3v Date ~ ~/~ ~c~g h n All D k Commission Use Only Permit to Drill7 /~ Number: f--~~ ~ '-~ ~~ API Number: 50- (' y~~ ~ ~J~~~j r Permit Approval Date:~~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedrm~ethane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No L'1 ud log req'd: Yes ^ No [r~ Other: ~~~ ~-~` ~'~~~~ H2S measures: Yes [/]~ No D~redi al svy req'd: Yes [~ No ^ APPROVED BY THE COMMISSION DATE: I _ ~ O ^ 0 ,COMMISSIONER Form 10-401 Revised 12/2005 ~ Submit in Duplicate yu J Applica>~r Permit to Drill, Well 1C-172A-L2 Revision No.O Saved: 21-Jan-08 Permit It -West Sak Well #1 C-172A-2L ~~~~~ Producer r.~ +~l .~,,, ~~~~I /~/~ A lication for Permit to Drill Document Mdxirttiiz~ Y/" 1Mell Vv~ue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ..........................•--•-•--.........................................................-•----••--•- 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ...............................•-•--•-•---......................................---•--................. 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4)-• .......................................................•--...................................... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..............................................................................•--................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) .....................................................................••--•--....................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .............................................•---................---.............................. 5 10.Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .....................................................................................:.......:.. 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 O~IG1~-~~~_ 1C-172A-2L PERMITIT.doc Page 1 of 6 Printed: 21-Jan-08 Applicator Permit to Drill, Well 1 C-172A-L2 Revision No.O Saved: 22-Jan-08 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) .....................~---....................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan .................................................................................~----.......................... 6 Attachment 2 Drilling Hazards Summary ............................................... Error! Bookmark not defined. Attachment 3 Well Schematic ............................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (t) Each we// must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2©AAC 25.040(6). For a well with multiple we/l branches, each branch must similar/y be identified by a unique name and API number by adding a suffix to the name designated far the well by the operator and to the number assigned to the wel/ by the commission. The well for which this Application is submitted will be designated as iC-172A-L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dril! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a p/at identifying the property and the property's owners and showing (A)che coordinates of the proposed /ocation of the wet/ at the surface, at the top of each objective formation, and at tote/depth, referenced to governmenta/section lines (B) the coordinates of the proposed location of the we// at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we// at the top of each objective formation and at tote! depth; Location at Surface 1 436' FNL, 4,184' FEL, Section 12, T11N R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 99.0' AMSL Northings; 5,968,801 Eastings; 562,101 Pad E/evation 59.0' AMSL Location at Top of Productive Interval 60' FSL, 2,249' FEL, Section 02, T11N, R10E West Sak "A-4" Sand ASPZone 4 NAD 27 Coordinates Measured De th RKB; 7,475' Northings; 5,938,970 Eastings; 550,772 Tota/ i/erticalDe th RKB; 3 831' Tote/ t/ertical De th, SS.' 3,732' Location at Total De th 181' FNL, 2,423' FEL, Section 14 T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 13 164' Northings; 5,964,748 Eastings: 558,619 Tota/ t/erticalDe th, RKB; 3,796' Total ~ertica/ De th, SS.• 3 697' and (DJ other information required by 20 AAC 25.0,50(6); Requirements of 20 AAC 25.050(6) If a wet/ is to be intentionally deviated, the application for a Permit to Dril/ (Form i0-401) must 1C-172A-2L PERMIT IT.doc Page 2 of 6 Printed: 22-Jan-08 !+`b and (©) other information required by 20 AAC 25.050(b); Applicator Permit to Drill, Well 1 C-172A-L2 Revision No.O Saved: 21-Jan-08 Requirements of 20 AAC 25.050(b) If a we// is to be intentionally deviated, the app/ication for a Permit to 1?rill (Form 10-401) must (1) include a p/at, drawn to a suitable scale, showing the path of the proposed wellbore, including a!/ adjacent we/!bores within 2110 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1C-172A-L2 and (2) for all wells withr`n 200 feet of the proposed wet/bore (A) Gst the names of the operators of those we//s, to the extent that those names are known or discoverable in pubfic records, and show that each named operator has been furnished a copy of the app/Icatlon by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fora Permr"t to Dri// must be accompanied by each of the fol%wing items, except far an item already on fi/e with the commission and identified m the application; (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1C-172A-L2. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. Both 10 3/a" and 9 5/8" Rams will be installed while running the tapered intermediate string. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fo!/owing items, except for an item a/ready on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iC area are 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). '~' -- The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak'~A-2" sand formation is 1,264 psi, calculated thusly: MPSP = (3,831 ft TVD)(0.44 - 0.11 psi/ft) = 1,264 psi ~ (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormal/y geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-172A-L2 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pernut to Drill must be accompanied by each of the following items, except for an item already on fife wr"th the commission and identified in the application.• (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(!); ~ ~~~~ 1C-172A-2L PERMITIT.doc Page 3 of 6 Printed: 21-Jan-08 L. J Applicator Permit to Drill, Well 1C-172A-L2 Revision No.O Saved:21-Jan-08 No formation integrity test is planned for the 1C-172A-L2 lateral in the A-3 due to the test was previously performed on the A-2. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dril/ must be accompanied by each of the fol/owing items, except far an item a/ready on fi/e with the commission and identified in the application: (6) a comp/ete proposed casing and cementing program as required by 20 AAC 25.0311, and a description of any slotted Inver, pre- pen`arated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 16" 20~~ 109 K55 Welded 80 40 / 40 - 121 / 121 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 9 5/8 12 ~/a." 40 L-80 BTC 3460 40 / 40 3,500 /2,442 740 sx ASLite Lead, 230 sx DeepCRETE Tail Cemented +/-500' above the 7 5/8 8 '/z" X 9 7/8" 29.7 L-80 BTCM 8317 40 / 40 • 8,400' / 3,944' uGNu (Bi-center bit) 4-1/2 6 3/4" A-2 Sand 12.6 L-80 BTC 5570 8,400' / 3,944' 13,169' / 3,914' Slotted- no cement slotted Lateral (1C-172A) 4-1/2 6 3/4" A-3 Sand 12.6 L-80 BTC 5654 8,117'/ 3,910' 13,168' / 3,860' Slotted- no cement Slotted Lateral (SC-172A L1 4-1/2 6 3~4" A-4 Sand 12.6 L-80 BTC 5991 7,646'/3,852' .13,164' /3,796' - Slotted- no cement Slotted Lateral (1C-172A ~--- L2 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to t?ril/ must be accompanied by each of the fol%wing items, except far an item a/ready on fi/e with the commission and identifed in the app/ication: (7) a diagram and description of the diverter system as required by 20 AAC 25. a35, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); N/A 1C-172A-2L PERMITIT.doc Page 4 of 6 Printed: 21-Jan-08 Applicator Permit to Drill, Well 1 C-172A-L2 Revision No.O Saved: 21-Jan-08 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication far a Permit to Drit/ must be accompanied by each of the fo1/owing items, except for an item already on file with the commission and identified in the application: (8) a dril/ing t7uid program, including a diagram and description of the drillinng fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals Lateral Mud Program (MI VersoPro Mineral Oil base) A-2, A-3 and A-4 sand laterals Density Plastic Yield Point HTHP Fluid Oil/Water Electric (ppg) Viscosity (cP) loss (ml/30 Ratio Stability (Ibi100sf) min @ 200 psi 8~ 150 degrees 8.4-8.5 15-25 18-28 <4.0 70/30 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dril! must be accompanied by each of the following items, except far an item already on fr/e with the commission and identified in the application; (9) far an exploratory or stratigraphic test wel% a tabu/ation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC25.033(l); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except far an item a/ready on fi/e wr"th the commissioon and ldentifred in the appiication: (10) for an exp/oratory ar stratigraphic test we/!, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication For a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on fife with the commission and identified in the app/ication.• (11) for a wel/ drilled from an offshore p/ah`orm, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application far a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application: (i2) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the lot/owing items, except far an item a/ready on fi/e with the commission and identified in the application: 1C-172A-2L PERMITIT.doc Page 5 of 6 Printed: 21-Jan-08 • 6. PU and run 4 ~/z" slotted liner, drop liner in open hole, POOH Application for Permit to Drill, Well 1C-172A-'~,~ Revision No.0 Saved: 22-Jan-08 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 8. PU and run 4-1/2" hook wall hanger. 9. RIH and hang off liner hanger. 10. Release hanger running tool. Pull out of hole laying down drillpipe as required. . Note: Remaining operations are covered under the 1C-172A-L2 Application for Permit to Drill, and are provided here for information only. li. Run and set Baker Gent WindowMaster whipstock system inside the 7 5/8" intermediate casing at +/- 7,646' MD / 3,852' TVD, the top of the A-4 sand. 12. Mill 6 3/4" window. POOH. . , ~`S ft.C~d~ 13. Plck up 6 3/4 drllltng assembly with LWD, MWD, PWD and rotary steerable tool. RIH. P 14. Drill to TD of A-4 sand lateral at +/- 13,164' MD / 3,796' TVD, as per directional plan. 15. Back ream out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Putl out of hole. 16. PU and run 4 ~/z" slotted liner, drop liner in open hole, POOH 17. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 18. PU and run 4-1/2" hook wall hanger. 19. RIH and hang off liner hanger 20. Release hanger running tool. Pull out of hole laying down drillpipe as required. 21. PU Jet pump completion with gas lift back up as required and RIH to depth. Land tubing. Set BPV 22. Nipple down BOPE, nipple up tree and test. Pull BPV. 23. Freeze protect well with diesel by pumping into 7 5/8" X 9-5/8"annulus, taking returns from tubing and allowing to equalize. 24. Set BPV and move rig off. 25. Rig up wire line unit. Pull BPV. 26. Set gas lift valves in mandrels. Use jet pump to clean up well. 27. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Oril/ must be accompanied by each of the fol%wii~g items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 1C-172A-1L PERMITIT.doc Page 6 of 7 0 F' I G I N A L Printed: 22-Jan-08 Applicator Permit to Drill, Well 1 C-172A-L2 Revision No.O Saved: 22-Jan-08 2. Mill /4" window. POOH. ~~ P ~ ~~SS ~ ~ 3. Pick up 3/4"drilling assembly with LWD, MWD, PWD and rotary~eerable tool. RIH. 4. Drill to TD A-4 sand lateral at +/- 13,164' MD / 3,796' TVD, as per directional plan. 5. Back ream out f lateral to window. TIH to bottom & displace to solids-free oil based i hole. 6. RU and run 4 ~/2" slo ed liner and drop in open hole, POOH 7. RIH with whipstock retr val tool. Retrieve whipstock and POOH. 8. PU and run 4-1/2"liner ha er 9. RIH and hang off liner hanger fter engaging top of 4 ~/2" liner. 10. Release hanger running tool. Pul ut of hole laying down 4" drillpipe as 11. PU Jet pump completion with gas lift ck up as required and RIH to det 12. Nipple down BOPE, nipple up tree and t t. Pull BPV. Pull out of fired. Land tubing. Set BPV 13. Freeze protect well with diesel by pumping to 7 5/8" X 9-5/8" ann s, taking returns from tubing and allowing to equalize. 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 16. Set gas lift valves in mandrels. Use jet pump to clean 17. Place well on production. SUPERSEDED t ~ _. ~ `~ ~7 14. Discussion of Mud and Cuttings Dispo I and Ann r Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Dri/l must be accompanied b each of the fo1/owing items, cept for an item a/ready on fi/e with the commission and identified in the app/ication: (14) a genera/ description of how the operator p/ans to ispose of dri//ing mud and cuttings a a statement of whether the operator intends to request authorization under 20 25.080 for an annu/ar disposal operatio in the we/%; Waste fluids generated during the drillin process will be disposed of by hauling he fluids to a KRU Class II disposal well. All cuttings generated ill be hauled to the Prudhoe Bay Grind a Inject Facility for temporary storage and eventual proc sing for injection down an approved disposal ell. ConocoPhillips Alaska may in the future request a orization for the use of this well for annular disp I operations. 15. Attachments Attachmenf 1 Direcfional Plan Attachment 2 Drilling Hazar Summary Attachment 3 Well Schem is ~,.~ C~'ft t' 1C-172A-2L PERMIT IT.doc Page 6 of 6 Printed: 22-Jan-08 Operator: ConocoPhillips (Alaska) Inc, -Kupl Surface Location: 596$$01,4,1 N 562101.96 E Well: IG-172A L2 (wp08) Grid Coordinate System: North American Datum 1927 ~"~/41,Lr..$B V RT~N Field: Kupaiuk River Unit Grid Convergence: Alaska. Zone 4 Rig: Doyon 141 Vertical Section Plane: 180,00° RKB Height: 99.1 ft Sperry Orilfing Services Date: 18-Tan-O8 Unwrapped Displacement: 11371.85 DDI: 7A25 SV~' MD Inc Azim. SSTVD TVD 1V/-S EJ-~'1' ~ Y DLS V.S. Conimcnts # (fI) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (#'t) °/100ft (ftj i 4L).00 O,oo 0:00 -59,10 40.00 0.00 N 11.00 E - 5621(11.96 E ~ 5968801.43 N 0.00 0.(10 2 156.90 0.16 315.00 57.8(1 156.90 0.12 N ` -11.12 ~ 562101.84E 5968801.54 N 0.14 -0.12 CB-GYRO-SS (1) 3 277.90 1.25 26.00 178.79 277.84 1.42 N 0.34 E 562102.29E 5968802.85 N 1.00 -1.42 4 401.89 2.39 36.29 302.72 401.82 4.72 N 2.47E 562104.39E 596~806.17 N 0.95 -4.72 MWD+IFR-AK-CAZ-SC (2) 5 490.85. 2.61 30.94 391.59 440.64 7.95 N .4.61E 562106.50E 5968809.42 N 0.36 -7.95 6 581.40 4.26 27.22 481.98 581.08 12.71 N 7.20. F 562109.06E 5968814.20 N 1.84 -12.71 7 677.23 5.90 . 24.61 571.45 67Q.55 19.88 N 10.65E 562112.45E 5968821.39 N 1.84 -19.88 8 762.3.5 8.53 I R.02 661.84 760.94 30.56 N 14.70 E 562116.40E 5968832:11 N 3.02 -30.56 9 852.31 11.70 . 14.76 750,39 849.49 45.73 N 19.08 E 562120.66E 5968847.31 N 3.58 -45.73 F~~ ~ 10 942.77 12.70 10.82 838.81 937.91 64.37 N 2.3.29E 562124.71 E 5968865.98 N 1.44 -64.37 °~~°'''` 11 1032,38 15.64 1.05 925.70 1024.80 86.13 N 25.36E 562126.61 E 5968887.75 N 4.22 -86.13 .~;,~ 12 1127.13 19.91 351.25 1015.92 11 15.02 114.86 N 23.14E 562124.15E 5968916.47 N 5.49 -114.86 ~~~- 13 .1221:35 21.43 346.42 1104.08 12(13.18 147.46 N 16.65E 562117.40E 5968949.00. N 2.42 -147.4E ~ 14 1303.86 21.18 341.57 1190.28 12$9.38 179.74 N 7.40E 562107.88E 5968981.20 N 1.92 -179.74 - 15 1405:99 26.12 338.05 1274.65 1373.75 214.36 N -5.45 W 562094.75E 596901x.72 N 5.57 -214.36 ~~ 16 1501.27 33.63 335.74 1357.21 1456.31 257.94 N -24.16 W 562075.69E 5969059.13 N 7.97 -257.94 17 1593.06 35.67 335.01 1432.72 153L82 305.37 N -45.9LW 562053.55E 5969106.,8 N 2.27 -305.37 18 1685.73 40.07 334,38 1505.85 160495 356.78 N -70.23 W 562028.81E 5969157.58 N 4.77 . -356.78 19 1778.89 44.74 331.67 1574.63 1673.73 412,71 N -98.78 w 561999.81E 5969213.27 N 5.38 -412.71 20 1872.29 50.50 330.33 1637.56 1736:66 473A1 N -132.24 ~~~ 561965.85E 5969273.28 N 6.26 -473.01 21 1964.53 53.61 328.47 1694.27 1793.37 535.60 N -169.25 ~ 561928.30E .5969335.55 N 3.73 -535.60 22 2056,98 56.75 326.71 1747.06 1846.16 599.65 N -2(~).97~' 561887.09E 5969399.26 N 3.74 -599.65 23 2149.97 66.46 324.51 1791.23 1890,33 667.02 N -256.18 W 561840.34E 5969466.25 N 10.65 -(,67.02 24 2242;58 67.44 325.15 1827.49 1926.59 736.68 N -305.26 W 561790,70E 5969535.49 N 1.23 -736.68 25 .2335.66 66.78 325.57 1863.70 1962,80 807.23 N -354.(10 VJ 561741.38 E 5969605.63 N 0.82 -807.23 26 2428.22 66.75 326.52 1900.21 1.999.31 877.78 N -401.5]. Vv 561693.30 E 5969675.78 N 0.94 -577.78 27 2521.11 64.45 324.33 .1938.59 2037.6' 947.43 N -449.49Vv 561644.75E 5969745.03 N 3.28 -947.43 28 2615.11) 63.51 323.}4 1979.82 2078.9= 1015,88 N -498.98 561594.72E 5969813.06 N 1.07 -10I5,£s8 29 2707.1(1 62.50 324.15 2021.58 2120.6 1082.24 N -547.11 1t' 561546.04E 5969879.01 N 1.12 -1082..24 30 2800.78 64.21 323.38 2063.59 2162.6~~ 1149.77 N -596.60 ~ 561496.00E 5969946.13 N 1.97 -1149.77 31 2892.93 67.26 323,39 2101.45 2200.5 1217.19 N -646.70 G~~ 561445.3b E 5970013.13 N 3.31 -1217.19 32 2985.54. 68.00 324.42 2136.70 2235.8u 1286.39 N -697.15 Vv 561394.34 F 597(108190 N 1.30 -1286.39 33 3078.47. 66.03 320,60 2173.00 2272.10 1354.27 N -749.19 ~~ 561341.76 E 5970149:34 N 4.34 -13542'7 34 3171.18 66.09 .321.65 2210.62 .2309.72 1420.23 N -802.37 561288.04E 5970214.86 N L04 -1420.23 35 .3264.02 65.93 :''-~ 72 2248.37 - 2347.47 1487.24 N -854:37W 561235.50 F x970281.43 N lA7 -1487.24 36 3357.30 66.16 .323.91 2286.24 2385.34 1555.60 N -905.30 Va 561184.02E 5970349.36 N 1.19 -1555.60 37 3450.65 66.32 323.79 2323.85 2422.95 1624.59 N -955.70 561133.06E 5470417.92N 0.21 -1624.59 u Page 1 of 5 ..~ ~'~ SV1'° ;STD Inc Atim. SST~'D TVD ?Vl-S E/-~~' X T DLS ~%.S. Co~»ncnts # (fe) (Deg) (Deg) ' (ft) (ft) (ft) (ft) (fr) (hj °/1o0ft (ft) 34 3500.00 66.90 32 L58 2343.44 2442.54 1660.61 N --933.16 W 561105.31E 5970453.71 N 427 -1660,61 39 350020 66.90 321.55 2343.52 2442.62 1660.75 N -983.27 w 561105.19E 5970453.(36 N 0.00 -1660.75 9 518" TOW - MWD+IER-AK-CAZ-SC (3) 40 3600.00 66.90 322,58 2382.68 2481.78 1733.17 N -1039.68 W 561048.20E >974525.50 N 0.92 -1733.17 41 3650.00 66.90 323.08 2402.29 2501.39 1769.82 N -1067.47 W 56102011E 5970562.22 N 0.92 -].769.82 42 3700.00 66.90 323,03 2421.91 2521.01 1806.59 N -1005.09 « 560992.19E 5970598.75 Ivy OAO -144h.59 43 3800.0(1 66.90 323.08 2461.14 256024 1880.13 N -115035 ~ 560936.34E 5970671.83N 0.00 -188{).13 44 3900.00 66.90 323.08 2500.37 2599.47 1953.67 N -1205.(;(1 w 560880.49E 597074490 N OAO -1953.67 45 4000.00 66.90 323.08 2539.61 . 2634.71 2027.21 N -126i).BSti~ 560824.64E 5970417.9$ N 0.00 -2027..21 46 4100.00 66.90 323,08 2578.84 2677.94 2100.74 N -1316.10 « 560768.79E 5970891.05 N 0.00 -2100:74 47 4200.00 66.90 323.08 2618.07 2717.17 2174.28 N -137136 W 560712.95 E 5970964.13 N O.UO -2174.28 48 4300,00 66.90 323.04 2657.30 2756.40 2247.82 N -142E.(~] Vv 560657.10E 597113720 N 0.00 -2247.82 49 4400.00 66.90 323.04 2696.53 2795:63 2321.36 N -1481.46 ~~ 560601.25 E 597111028 N 0.00 -232136 50 4500.00 66.90 323.04 2735.77 2834.87 2394.90 N -1537.17 « 560545.40E 5971143.35 N 0.00 -2394..90 51 4600.00 66.90 323.04 2775.00 . 2874.10 2468.44 N -159236 W 560489.55 E 5971256.43 N 0.00 -2468.44 52 4700.00 66.90 323.08 2814.23 291333 2541.98 N -1647.62 W 560433.70E 5971329.50 N 0.00 -254198 53 4721).00 66.90 3'3:.08 2822.08 2921.18 2556.69 N -1654.67 W 560422.53E 59713=t4.12N 0.00 -2556.69 54 4500.0{~ 66,98 318.24 2853.41 2952.51 2613.62 N -170529W 560375.45E 5971400.65 N 5.52 -2613.62 55 4900.00 67,08 312.28 2892,44 2991.54 2679.01 N -1770.05 w 560310.16E 5971465.50 N 5.52 -2679.01 56 5000.00 67.18 306.24 293130 3030.40 273732 N -1h4134 W 560238.41E 5971523:22N 5.53 -273732 57 5100.1)0 67.28 300.28 2970.00 .306910 2787.89 N -1918.39 ~h 560160.95E 597157316 N 5.53 -2787.89 58 520000 6738 294.24 3008.54 3107.64 2830.17 N -2000,36 W 560078.64E 5971614.75 N 5.54 -2530.17 59 5300.00 67.48 288.23 3046.92 3146.02 2863.67 N -2056.36 W 55999238 B 5971647.54 N 5..54 -2863.67 60 5400.00 67.58 242.23 3085.14 3134.24 2888.01 N -2175.46 t 559903.09E 5971671.15 N 5.55 -2488.01 61 550(?.00 67.68 ?76.24 3123.20 3222.30 2902.92 N -2266.69 Vv 559811.76 E 597L68531 N 5.55 -2902.92 62 5600.00 67.78 270.23 3161,09 3260.19 2908.21 N -2359,1)4 ~~ 55971938E 5971689.84 N 5.55 -2904.21 63 5700.00 67.88 264.24 3198.83 3297:93 2903.82 N -2451.50 W 559626.97E 597184.69 N 5.56 -2903.42 64 5800.00 67.98 254.24 3236.40 3335.50 2889.78 N -2543.06 W 559535.54E 5977669.90N 5.56 -2839.75 65 5900,00 68A8 252,28 3273.81 3372:91 2866.23 N -2E~32J1 « 559446.09E 5971645.62 N 5.56 -2866.23 66 6000.00 68.18 246.23 331 LU6 341016 2833.41 N -2719.47 \ 559359.61E 5971612.09 N 5.57 -2433.41 67 6100.Or1 68.28 240.24. 3348.14 344724 2791.68 N -2502.39 W 559277.05E 5991.569.63 N 5.57 -2791.63 68 6200.00 68.38 234.25 3385.07 3484. L7 2741.47 N -2350.54 W 55919932E 5971513.84 N 5.58 -2741.47 69 6300:00 68.48 ~"~.28 3421.83 3520.93 268332 N -2953.07 559127.28E 5971460.11 N 5.58 -268332 70 6400.00 68.58 22228 3458.43 3557.53 2617.87 N -3019. [6 559061.73E 5971394.13 N 5.58 -2617.47 71 .651)0.00 68.68 .21628 3494.87 3593.97 2545.82 N -3073.09 ~~ 559003.40E 5971321.60 TAI 5.59 -'545.82 72 ~F00.00 68.78 210.24 3531.14 3630.24 2467.95 N -3129.21 ~ 558952.94 E 5971243.3.1 N 5.59 -24(17:95 73 r~~~84.02 68.87 205.00 3562.94 3662.04 2395.27 N -3167.27 ~ 558915.47 1/ 5971170,34 N 5.60 -2395.27 74 6700.00 6938 205.33 3567.20 366630 2385.14 N -3172.03 ~ 558910.80 E 597116017 N 5.00 -2385.14 75 67E,0.57 72.00 20694 3587.23 . 368633 2333.83 N -3197.21. ~~ 558886.05E 5971108.66 N 5.00 -2333.83 76 67RR 26 72,00 206.94 3595.78 36y4.84 231035 N -320y14 ~ 55887431E 5971045.10 N 0.00 =231~~.3~ 77 68n~i.ub 72,21 .20636 359939 3694.49 230036 N -3214.15 ~ 55886938E .5971075.07 N 5,00 -230i~_~t~ 78 6900.00 74A8 20L52 362839 3727.49 2212.92 N -325296 55883130E 507098732 N 5.00 -221 ~.~i= Page 2 of 5 SVS' I'll) luc Azim. S~Ti~~ TVD AI-S E/-~j,_ K t' ULS ~%.S• Coanmcnts # (~) t~~g) ~fle~O) (ft) (ft) (ft) (ft) (lt) (ft) QllUQ#'t (ft) 79 7000.00 76.06 ]96.76 3654.17 ,37.5327 2121.66 N -3284(14 Vv 558800.40E 5970895:81 N 5.00 -2121.66 80 7100.00 78.13 192.09 3676.52 3775.62 2027.29 N -3308,87 ~ 558776.92E 597080L26 N 5.00 -2027.29 81 .7200.00 80.27 187.49 3695.27 3794.37 1930.53 N -3325.50 558761.03E 597070437 N SAU -1.930.53 82 730U.b0 82.47 18295 3710.29 380939 1832,10 N -3334.54 W 558752.86E 5970605.89 N SAO -1332.10 83 732L09 82.94 182.00 3712.96 '3312.06 1811.20 N -3335,}4 V4 558752.13E 597058498 N 5.00 -1811.20 84 7400.(10 82.94 1.82.00. 3722.66 3821.76 1732.94 N -3338.18 VJ 558750.04E 5970506.7.1 N 0.00 -1752.94 85 747L09 82.94 1.82.00 3731.40 3830,50 1662.43 N -3340.6 W 558748.15E 5970436.19 N OAO -]fi62.43 86 7474.71 82.94 181.99 3731.84 3830.94 1658,84 N -3340.76 W 558748.06E 5970432.61 N 0.25 -1658.44 1G172A MB_A4 Heel (12-19-07) 87 7500.00 82.94 181.93 3734.95 .3834.05 1633,76 N -334 L62 W 558747.41E 597007.52 N 0.25 -1633.76 88 7600.00 82.94 181.67 3747.24 384634 1534.56 N -3344.74~~ 558745.11E 597030831. TV 0.25 -1534.56 `Tie-On 764h.0t) 82,94 18].55 3752.90 3852.00 1488.93 N -33~6.02W 558744.20E 5970262.68 N 0.25 -1488.93 2 7646.01 82,94 181.55 3752.90 3852.00 148892 N -3346.02 1b 558744.20E 5070262:66 N 0.00 -1488.92 L2: 7 5/8" TOW ~ 7646' MD, 3852 T'VD; 53' FSL, 3 7650.00 83.58 18L55 3753.36 .3852.46 1484.96 N -3346.13 W 558744.12E 5970258.71N 15.95 -148496 4 .7658.00 84.85 381.55 3754.17 3853.27 1477.00 N -3346.34 W 558743.97E 5970250.75 N 15.90 -1477.00 5 7688.00 84.85 181.55 3756.86 .. 385596 1447.14 N -3347.15 ~~ 558743.41E 597022(1.88 N 0.00 -1447.14 6 7700.00 85.45 131.49 3757.88 385698 1435.18 N -3347.47 ~y 558743.19E 5970208.93 N 5.00 -135.18 7 7800.00 90.42 180.94 3761.49 3860.59 133530 N -3349.59 W 558741.90E 59701.09.04 N S.OU -1335.30 8 7853.13 93.06 180.65 3759.88 3858.98 1282.21 N -33503? W 558741.60E 5970055.95 N 5,00 -1282,21 9 7900:00 93A6 L80.65 375738 3856.48 1235.41 N -3350,86 W 558741.45E 5970009.15 N 0.00 -1235.41 10 90 7992 06 93 180 65 3752 42 52 3851 1142 65 N 91 W 3351 558741 16 P 59699f6 40 N 0 00 -1142 65 i . . . . . . . - , . . . `-~ 11 8000A0 92.78 180.70 3752.06 3851.16 1135.55 N -3351.99 ~ 558741.13E 5969909.31 N 4.00 -1135.55 12 8043.08 91.08 181.00 37,50.61 .3849.71 1092._50 N -3352.63 W 558740.84E 596986625 N 4.00 -1092.50 13 8100.00 91.08 181A0 3749.54 3848.64 1035.60 N -3353.63 55874032E 5969809,36 IMF 0.00 -1035.60 14 8118.05 91.08 181.00 374920 .3848.30 1017.53 N -3353.94 ~ 558740,15E 5969791.28 N 0.00 -1017.53 1C-172A MB_A4 Tl (12-19-07) 15 8742.84 90.61 .181.17 3748.83 3847.93 992.78 N -3354.41 Vv% 558739.89E 5969766.5; N 2.00 -992.78 16 8200.00 90.61 18].17 374822 384732 935.63 N -3355.57 Vv' 558739.19E 5969709.38 N OAO -935,63 17 830000 90.61 181.17 3747.15 3846.25 835.66 1v~ -3357.61 W 558737.98E 5969609.41 N 0.00 -835,66 18 84(10.00 90.61 181.17 3746.08 384518 735.69 N -3359:64 b 558736.77E 5969509.4# i~ 0.00 -735.69 19 8500.00 90.61 181.17 3745.01 3844.11 635.71 N -3361.68 w 558735.56E 5969409.46 N 0.00 ..-635.71 20 8600.0(1 90.61 181.17 3743.94 38=43.04 535.74 N -33(,3.71 55873434E 5'369309.4$ N 0.00 -535.74 21 8700.00 90.61 181..17 3742.87 34}.97 435.76 N -3365.74 5.58733.13 E Sy69209.51 N 0.00 -435.76 22 $781.2: 90.61 181..17. 3742.00 3841.111 354.55 N -3367.40 w 558732.15 E 5969128.30 N 0.00 -354.55 1G172A MB_A4 T2 (12-19-07) 23 8800.01 ~ 90.95 J .ti 133 3741.74 3840.84 335.79 N -336^, .81 558731.89E 5969109:54 N 2.00 -335.79 24 ~~;~47.45 91.80 1 ~ 1.76 3740.61 3839.71 2$837 N -3369A~ 1 558731.00E 5969062.11 N 2.00 -288:3.7 25 ti~ii111,04 91.80 l :~ 1.76 373896 3~~38.(t6 235.87 N -3370.70'v 558729.82 E 5969009.61 ~I 0.00 . -23.87 26 9~~nu n0 91.80 1`,1.76 3735.83 383493 135.97 N -3373.77 b1~ 558727.57E 596~'~(i9.70N 0.00 -135.97 27 ~iiil x.-41 91.80 181.76 373525 3834.35 117.58 N -3374.34 V4 558727.15 E 596`~3~~131 ICI 0.00 -117.58 1C-172A MB_A4 T2 (12-17-(17) 28 y100.U0 91.80 18L76 3732.69 3831.70 36.07 N -3376,85 55872532E 596~~~~~9.78 N 0.00 -36.07 29 9200.00 91.80 181.76 3729.56 3828.66 -63.84 S -33~~~.92 V4 558723.07E 596`=u9.87 N OAO 63..84 30 9300A0 91.80 .18.1.76 3726.42 3825.52 -163.74 S -~ x`;2.99 W 558720.82E 596~,r~~~~1.9E, N 0.00 163.74 31 9400A0 91,80 181.76 372329 3822.39 -263.64 S -3386.06Vo 558718.56E 5968510.04 N 0.00 263.64 32 9418.75 91.80 I ~~ 1.76 3722.70 3821.80 -282.37 S -3386.64 W 558718.14E 5968491.31 N 0.00 . 28 ~. ~, 1C-172A MB_A4 T3 (12-19-07) • U Page3of5 ...e.~.~ ~, ~,~~,,,, ,~x,- ~.,„ S~'~' ~J~ID Inc Azin~. :SSTk'D T~'A ~I!-S E/-11' X ~' DLS ti.S. Conn~ients # (fty (Deb) iDe~) (ft) (ft} (ft} (f't) (ft) (ft) °;100ft (f't) 33 9497.64 89.43 181.91 3721.85 3820.95 -361.21 S -3389:17 W 55x716.26 E 5968412:46 N 3.00 36121 34 9500.00 89.43 181.91 3721.88 3820.98 -363.57 S -3389 24 ~G 558716,2(1 E 5968410.]0 N 0.00 363.57 35 9600.00 89.43 181,91 3722.86 382196 -463.51 S -3392.58 w 558713.68E 5)68310,15 N 0,00 . 463.51 36 9700,00 89.43 18191 3723.85 3822.95 -563.45 S -3395.92 V. 558711.17E 596821020 N OAO 5(,3.45 37 9800.00 89.43 181.91 3724.84 3823.94 -66339 S -3399.26 W 558708.65E 5968110.25 N 0.00 6<3.39 38 991)0.00 89.43 181.91 3725.83 3$24.93 -76333 S -3402.60 ~ 558706.13 E 5968010.30 N OAO 7h333 39 10000.(10 89.43 18191 3726.81 3825.91 -863.27 S -3405.94ti~ 558703.62 E 5967910.34 N 0.00 86327 40 10019.03 89.43 181.91 3727A0 3826.10 -882.29 S -3406.5'7 558703.14E 5967891 33 N OAO 882.29 1G172A MB_A4 T'4 (12-19-07) 41 1009,1.93 90.89 182,00 3726.79 3825:89 -955.14 S -34t)9.06W 558701.25E 5967818.46 N 2.00 955.14 42 10100.00 90.89 182.00 3726.67 3825.77 -963.21 S -3409,35 W 5587U1A3 E 5967810.39 N 0.00 063.21 43 10200.00 90.89 182.00 3725.12 . 3824,22 -1063.13 S -3412.84 11 55869836E 5967710.45 N 0.00 1063.13 44 1030(1.00 90.89 182.00 3723.56 3822,66 -1163.06 S -3416.33 ~N 558695.68E 59617610.51 N 0.00 1 (63.06 45 10400,00 90.89 182.00 3722.01 .3821.11 -1262.99 S -3419.83 W 558693.01E 5967510.57 Al 0.00 1262.99 46 10500.00 90.89 182.00 3720.46 3819.56 -1362.92 S -3423.32 H 55869034E 5967410.63 N 0.00 136292 47 10600.00 90.89 182.00 3718.91 3818.01 -1462.84 S -3426:82 W 558687.67E 5967310.69 N 0.00 .1462.84 48 10700.00 90.89 182.00 371735 3816.45 -1562,77 S -3430.;1 V. 558684.99E 5967210:75 N 0.00 1562.77 49 10800.00 90.89 182.00 3715.80 38(4.90 -1662.70 S -3433.81 W 55868232 E 5967ll0.81 N 0.00 1662.70 50 10900.00 90.89 182.00 3714.25 3513.35 -1762,62 S -3437.30 « 558679.65E 5967010.87 N 0.00 1762.62 51 11000.00 90.89 182.00 3712.70 3811x40 -1862.55 S -3440.80 «~ 558676.97E 5966910.93 N O,OU 1862.55 52 l1 ] 00,00 90.89 182.00 3711.14 3810.24 -1962.48 ~ -3444.29 ~~ 558674.30E 5966810.99 N OAO 1962.43 53 ll 200.00 90.89 182.00 3709.59 3808.69 -2062.40 S -3447.78~w 558671.63E 5966711..05 N 0.00 2062.40 54 1127.8.71 90.89 182.00 370930 3808.40 -2081.10 S -3448.44 W 558671.13 F. 5966692,36 N 0.00 2081.10 1C-172A MB_A4 T5 (12-19-07) 55 11285.31) 90.23 18210 3708.65 3807.76 -2147.65 S -3450.82 W 558669.29E 5966625.50 N L00 2147.65 56 11300.00 9023 182.10 3708.59 3807.69 -216233 S -3451.36 W 558668.88E 5966611..11 N 0.00 2162.33 57 11400,00 9023 182.10 3708.19 380729 -226227 S -3455.02 W 558666.03E 5966511/6 N 0.00 226227 58 11500.00 9023 18210 3707.78 3806.88 -236220 ~ -3458.60 ~ 558663.19E 5966411.21 N 0.00 2362.20 59 11600.00 9023 18210 370738 3806.48 -2462.13 S -3462.35 « 55866035E .596631 ] 27 N 0.00 2462.13 60 1 J 700,00 9023 .18210 3706.98 3806:08 -2562.06 S -3466.01 ~'v 558657.51E 596621 132 N 0.00 2.562.06 61 11800.00 9023 18210 3706.58 3805.68 -2661.99 S -3469.68 ~'~~ 558654.66E 596611137 N 0.00 ?<,6199 62 118]9.01 9023 182.10 3706.50 3805.60 -2680.99 S -347037V~~ 558654.12E 596609237 N 0.00 268.99 1C-172A MB_A4 T6 (12-19-07) 63 11842:36 90.42 181.96 370637 .3805.47 -270433 S -347120 W 558653.49 E 5y66069.03 N 1.00 2704.33 64 11900,00 90.42 18196 3705.95 3805.05 -2761.93 S -3.473.:18 ti 558651.99E 596601 L42 N OA(1 276193 65 12000.00 90.42 I $196 370521 _38(!4.31 -2861.87 S -3476.60 ~ 55864939E 5965911.47 N 0.00 2861.87 66 12T(?0.00 90.42 181.96 3704.48 3803.58 -2961.81 8 -3:480.02 55$646.79 E 5965811:52 N 0.00 .2961:.81 67 12200.00 90.42 18 ] 96 3703.75 3802 R ~ -3061.75 S -3483.44 W 558644.18E 59657 i 1.57 N OAO 3061.75 68 12304,00 90.42 181.96 3703.02 380,. ] ? -3161.69 S -3486.87 ~V~ 558641.58E 5965611.62 N 0.00 316L69 69 12400.00 90.42 181.96 370229 3&013~~ -3261.62 S -3490.29 w 558638.98E 5965511.67 N 0.00 3261.62 70 12500.00 90.42 (81.96 3701.56 380ii.i~o -3361.56 S -3493.71 ~~~ 55863638E 5965411.71 N 0.00 33f~1.56 71 12600.00 90.42 . 18196 3700.82 3750.92 -3461.50 S -3497.14 w 558633.78E 5965311,76 N 0.00 3461.50 72 12700.00 90.42 .18196 3700.09 3799.19 -3561.44 S -3500.56 55863L18 E 5965211.81 N 0.00 35b1.44 73 I?`~'iiu,uii 90.42 181.96 369936 3798.46 -366138 S -3503.98 558628.58E 5965111.86 N 0.00 3661.38 74 1290u.u0 90.42 .181.06 3698.63 3797.73 -376132 S -3507.41 W 558625.97 E 5965011.91 N OAO 3761.32 C~ Page 4 of 5 ~"` ~~ S~"5' # :;YID (ft) Inc (Deg) Asim. (Deg) S~+TY`D (ft) TVD (ft) N!-S (ft) Ei-t'4' (ft) Y (ft) I' (ft) ULS °I100ft ~'.S. (ft) Comments 75 76 77 13000.(10 13100.00 li 153.63 90.42 90.42 90.42 181.96 181,96 1 ~ 1.96 369790 3697.17 3696.70 3797.00 3796.27 3795.80 -3861.26 S -3961.20 S -4024.78 S -351(1.83 W -3514.25 W -3516.43 W 558623.37E 558620.77E 558619.1 I E >964911.96 N 5964812.01 N 5964748.41 N 0.00 Q00 OAO 3861.26 3961?0 4(124.78 L2: 4 lf2" Liner @ 13164' MD, 3796' TVD; 181' F`N • ~~ Page 5 of 5 Plan View Plot 5973000 5972000 -- - _- - ----- _.- -- ---.- 5971000 - - ~ - .~~,~.,,, °W~~..,.~~ ` „~ - -- • 5970000 ,.~, 5969000 5968000 --- ---- -- --- -- --- ._.,_ .: _F - - :~ - - _ - 5967000 ._ _ _ - -. - - _ , f 5966000 r ~~.- 5965000 5964000 558000 558500 559000 559500 560000 560500 561000 561500 562000 562500 1 C-172 ~ targets -----1 C-172A (wp08) 1 C-172A L1 (wp08) -1 C-172A L2 (wp08) Vertical Section Plot Section Distance ___ -500 -~ -4000 -3000 -2000 -1000 d 1000 2000 3000 4000 5000 i ~ ~, 50 I ` i ~., .~"~' ~ *»..., j N ,~ ~ --- v;.. __------ - - -- ---200-- i _ _.. 3 _ ,. -K 1 dI2 ~~p1i61 S. _ A icc. 1 1C~~774'.C_A~~~~~g,(U) _. ~ ~d.,wd,.~. ,..~ - a ~~w..~ e .. m... -...~ ~ .,~ ~,_. u_~..~~,u~_.r_ 4500: ~ ~ .,. a _._ y..... ,. ~ .. .w ~,.,..e.u ,._._m_. ~e.~.~~ .~,~.~. _.~,,,k~.~~ -1 C-172 -1 C-172A (wp08) -1 C-172A L1 (wp08) -1 C-172A L2 (wp08) • 1C-172AL~ Drilling Hazards~ummarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard .Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, ,decreased mud wei ht, backreaming for hole cleanin Lost Circulation Low Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreamin 1C-172AL2 Drilling Hazards Summary.doc e ~ ~ .~ prepared by Shane Cloninger 1/15/2008 8:21:00 AM • i 1 C-172A 16" Conductor @ 107' 1 C-172A Trilateral Sidetrack Producer 7 5/8", 29.6#, L-80, Hydril 513 TOW 9 5/8" csg 3, 500" 2,348' TVD .,',~... `~- 9 5/8' Intermediate Casing ~_:~- ..- j,.. T ;, 13,164' TD A4 La _ _ ~ C'~ `~a ~~'-' a _ _ 3,796' TVD - TOW of the A4 sand - _ =__ _ =_ = - _ _ _ _ - @ 7,646' 3,852' TVD 13,168' TD A3 Lateral TOW of the A3 sand __- - - - - - - 3,860' TVD @8,117'MD ---- ----- 3,910' tvd 13,169' TD A2 Lateral A2 Sand -_ _ 3,914' TVD Top of A-2 --'-- Liner @ +/-8,150' 4 1 /2", 12.6#, L-80, BTC Liners slotted and blank 7 5/8" shoe @ 8,400' MD 3,944' TVD ~~~" `~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~-~~~ ~ ~ ~' ~~~fz ~- Z-- PTD# Z ~ ~ ` ~ r~ ~ Develo went p Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Gc. ~-.-4 / ~ _~ !~ `J~ POOL: ~~s~ c~~- ~~`~ \ 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 ~~u ~C - ! 72 .~ (If last two di it i ' g s n API number Permit No. y°g -~$, API No. 50- nL - Z 3 /~ -~/ , 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), alt 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 throu h tar et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/1 l/2008 WELL PERMtT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1G172AL2 Program DEV Well bore seg ^~ PTD#:2080100 Comp any CONOCOPHILLIPS ALASKA INC Initial ClasslType DE V! PEND GeoArea 890 Unit 11160 OnlOft Shore ~ Annular Disposal ^ Adminiatratton 1 Pe[mitfeeattached-- --------- ---- -- - -- -- NA----- - - ------- -- ------- - -- ----- - - --- ---- 2 lease number approRriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ _ _ - _ - - _ _ - _ _ _ _ Yes _ _ _ _ _ _ _ Surface and iop prod interval in ADL 25648; Tp in northermost-portion of AD1.25650, . - _ _ _ _ - - _ 3 Uniquawall-name andnurobe[- ---- -- -- -- - - -- --... --Yes---- ------- - ----------- - -- -- --- -- -- -------- 4 WflIU4catedlna_defnedp9ol________________--__--__-__.- -________Yes____ ___K~parukRiver,West&akOilPool-4gQ15Q,_goyemed-by CO406B__-----_____-_____.-___-_ 5 )Nell located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - _ Yes _ _ _ _ _ _ CQ 4068, Rule 3; no restrictions as-tg well spacing except that no-pay shall be DRened in a well clDSer - - - _ - - - 6 Well located proper distance f[omotherwells- - - - - - - - - - - - - - - - - - - - - - _ _ _ _ Yes _ _ - - _ _ than 600 feet to_en extemaLpropEdy line where ownershJp 4r Jsndcwnership changes. - - _ - - - - - - _ - - - _ - _ - 7 Sufficient acreag® availablQ in_dritling unit- _ - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ . _ _ _ _ Well is more khan 500 )eel from an external properly line. - - _ _ _ _ _ _ _ _ _ - - _ - _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ - 8 )fdeviated,ls-+vellbQreplai.includad------------------------ ---------Yes---- -----------------.---------------- 9 Operator only affectedpa~v- --------- -- -- --------Yea -- ---- -- - -- -- ----- --- --- - ----- - 10 Operator has-appropriate bond fn force-~- -- -- - --- ----- Yes---- -- --- -- -- ------------- - -- - - -- -- ----- 11 Parmttcanboissuedwithoutconservationorder_-----__--------- __--___--Yes--- -------------------------------------------------.-------------------- Appr Date 12 Permitcanbeissuedwithoutedministtatlve_approval---------------- ---------Yes---- --------------------------------------------------------------------- SFD 1124!2008 13 CanpertnitbQapRrovedbefora15-daY-uraR----- - -- -- ----- -Yes - ------- --- - -- --- ------ -- --- ----- --- --- - 14 -N1e1O00atedwithinarQeandstrataauthpr~edbylpjecton9[der#(ps~tlQ#Jn-comments)_(For_ NA__-- ____.________________-______--_____--____-----__-______-_---________ 15 -AllwalJs_within1l4_roile_areaof[eyiQYvidentif~ed(Forservicewehpnly)------ ---------NA----- --------------------------------------------------------------------- 16 Pre-producadinJector,duraNanolprep[oduckipn~ssthan3months(ForservfcewslloNy)--~---- ------------------------------------- -- -- - -------- 17 _Nonconven.gas.cAnformetRAS$1:05.030(t.1.A)~(G2.A•Dl --- ----- - ----- - NA- --- -- -- -- - -- --- ------------ -- -- -- -- --- - t:nglneering 18 Conductorsttlng.provided________.________-____-_------ -__---_ NA___.- --Canductorsetin1G172(203-Qg5).---------.------------------------------------ 19 Ss~[face_casingprotoctsallknov~nUSDWs---------------------- ---------NA--.-- ---Allaquifersexempted,40CFR_1A7.102(b)(3)~------------------------------------- 20 CMT-vofadequatetocirca,late_oncgnductor6 surfcsg__-___________ _________ NA____- _--Surfacecasingset)n1C•172,---_______._---_______-._-___-__--__-___________-_ 21 CMT_vofadaquaie-totiB•fnlongstring to surf csg--___--------__- -__-_____NA____- ___Productioncasingset'tn-1Cr172A(20$~006)___ _______________-____--__-_______-____- 22 CMT-will cover all known-praductiveb4r~ons_____________________ __________tyo___-_ ___Slottedliner-completionplanned,___________________-_-____-__--______-_-___-__ 23 Casing des~ns adequate f9r C, T, ~ &-permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ Original wek and redrill met dssignspscifcations._ NA tot sl9ded lines _ _ _ _ - - _ _ - _ - - - - - - _ _ _ _ _ - _ _ 24 -Adequate kankage_or resen+e pik _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig equiRped with steel pits: N9-reserve pit planned.- All waste to aRP-roved disRosal wall(s), _ _ - - _ _ - - _ _ - _ _ 25 Ifa-re-drilt,has.al0.403fcrabandortmeni beerraRprQved------------ ---------NA----- ---------------------------------------------------------------------- 26 Adequate-wellkare separationproposed- - - - - - - - - - - - - - _ . - - _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Traveling cylinder path calculated.- Nearest segment is A-3 segment ^~60' ivd deeper, - - - _ _ _ _ - _ _ _ _ _ _ _ _ _ 27 Itdiverter-required,dcesiimeetregulatipns---------------------- ---.---- NA:___ _.-8OPstack_willalready_beinRlace._--_--__.-_________________--__-____________-- Appr Date 28 DritGng fluld_ program schematic-& equip listadequate- - - - - - - - - - - - - - _ _ _ _ _ _ Yes - _ _ _ _ Meximum expected f_o[mation Rressure 8,4_EMW: MW planned $.4 - $.5ppg,. _ _ - - _ _ _ _ _ - - _ _ _ _ _ _ - _ _ - TEM 112512008 29 B-OPI=s,_dotheymeatregulat(on- -- ------ - ------ -- - - ?'as--- - -- -- -- - - ------ --- ---~--- --- -- --- --- ------ ~"(~ ~ /J 30 BOPI:_prass rating app[op[fate; lest to_(put psig U comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ _ _ _ MASP calculated at 1264psi, 3K stack arrangemeptand BOP test planned.- _ _ _ _ _ _ _ _ _ _ _ . _ _ _ G ;~,,~'I 31 Choke-rnanJfoldccroRliesuvlAPl_RP•53(May$4)___________________ ______-_Yas____ _ _ _ _ _ _ _ .__-_____ 32 -Wcrkwih9ccutwith9utoperationshutdown_____________________ _______Yas____ _______-__--__-_____---________.____.-_______-.----------------- 33 Is Rresence cf ti2S gas Rrobablg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - _ H2S is rep9rted-in 1C W_$wells, _ Mud shQUld preclude_H2S on 1ig._ Rig equipped with sensors and-alarms.- _ _ _ _ 34 Mechanicalc9nditioaofwellsYUiihinAORverified(F9rse[vicswellonly)----- --------- NA-.--- ----.----------------------------------------.----------~------------ Geology 35 Pemlitean be issued w/o hydrogensulfiderneasures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Ko_ _ - _ _ _ _ _ 1C-Pad West Sak welts -measure item 0 to-170 PPM_H2S, Pn3cautions a[e_advisable, - - - - - _ - - . . - _ . _ 36 Datapresented on potential 9verpresaurszones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Expected n3servoirpressure fs 8,4-ppg 1:MW; prod intenraJ will be drilled with 6.4 ko 8,5 ppg oil-base mud, - _ _ _ _ Appr Date 37 S®ismicanalysiscfsballowges-zones._______.__-__________ __________NA___.. __.Multilaieral--.-..__--__-- ----------------------------------------------- SFD 1124!2008 38 Seabedconditi9nsunrey-(ifoff-shore)_______________________ _________ NA_-___ _____ 39 Contactnamolphoneforweekly_progreasrepodsjexPloraioryonlyj-------_ .--_---_ NA-_-_ _____----__________________.__._----------------------------------- Geologic Engineering u ' Date Date: Date Multilateral producer targeting the West Sak A4 interval. Anticollision is a concern here. This wellbore will pass wiihin 250' of Commissioner; m si net Commissioner / Z~~ G~~ ~ ~ ' three nearby wells, / ~`3 ~-c d-0 ~ CJ • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • writing Library. 1C172AL2o0506200855N.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 12 17:23:27 2008 Reel Header Service name ............. LISTPE Date . ................... 08/06/12 Ori gin ................... STS Reel Name. .... ........ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Tape Header Service name .............LISTPE Date . ...................08/06/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Physical EOF comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA writing Library. scientific Technical services scientific Technical services 1C-172A L2 500292315961 ConocoPhillips Alaska Inc. Sperry Drilling Services 12-JUN-08 MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0005476893 w-0005476893 w-0005476893 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: F. HERBERT F. HERBERT M. THORNTON MWD RUN 10 MWD RUN 11 MWD RUN 12 Job NUMBER: w-0005476893 w-0005476893 w-0005476893 LOGGING ENGINEER: 6. HENNINGSE B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: F. HERBERT F. HERBERT F. HERBERT MWD RUN 14 JOB NUMBER: w-0005476893 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 12 Page 1 ~~Zf~©~~ 1~5Z5/ • t • • TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1C172AL200506200855N.txt 11N l0E 1436 1096 100.50 59.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3513.0 2ND STRING 6.750 7.625 7357.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 1C-172A L2PB2 WELLBORE AT 12100'MD/3788'TVD, WITHIN THE MWD RUN 12 INTERVAL. 4. MWD RUNS 2,3,11,12,14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). GEO- PILOT ROTARY STEERABLE BHA (GP) WAS ALSO INCLUDED IN MWD RUNS 11, 12,14. MWD RUN 13 DID NOT INCLUDE FORMATION-EVALUATION TOOLS. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M.WERNER (CPAI) TO R.KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3,10-12,14 REPRESENT WELL 1C-172A L2 WITH API#: 50-029- 23159-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13018'MD/3785'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 C~ 1C172AL200506200855N.txt SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPS FET RPD RPX RPM ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3505.0 3508.0 3508.0 3508.0 3508.0 3508.0 3513.5 STOP DEPTH 12969.0 12976.0 12976.0 12976.0 12976.0 12976.0 13018.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 3513.5 3549.0 MWD 2 3549.0 3620.0 MwD 3 3620.0 7357.0 MwD 10 7357.5 7391.0 MWD 11 7391.0 9890.0 MwD 12 9890.5 12100.0 MwD 14 12100.0 13018.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Page 3 • 1C172AL2o050620085SN.txt Frame Spacing.. ..... ..... .......60 .lIN Max frames per record ...... .......undefined Absent value ... ............ .......-999 Depth units. .. .. ..... Datum specifica tion Block s ub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3505 13018.5 8261.75 19028 3505 13018.5 RPD MWD OHMM 1.22 2000 23.7727 18937 3508 12976 RPM MWD OHMM 0.47 1679.1 22.5283 18937 3508 12976 RPS MWD OHMM 3.38 1501.03 21.7735 18937 3508 12976 RPX MWD OHMM 2.88 1501.2 22.5682 18937 3508 12976 FET MWD HR 0.15 538.62 1.19049 18937 3508 12976 GR MWD API 5 159.9 68.7438 18929 3505 12969 ROP MWD FPH 0.03 1111.59 179.027 19011 3513.5 13018.5 First Reading For Entire File..........3505 Last Reading For Entire File...........13018 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EoF File Header service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 Page 4 • 1C172AL2o05062008SSN.txt FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 3513.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 3549.0 31-MAR-08 Insite 74..11 Memory 3549.0 3513.0 3549.0 67.0 67.0 TOOL NUMBER 8.500 3513.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... ............ Datum specification Block sub-type...0 Page 5 Fresh water Gel 9.00 53.0 9.5 500 9.0 .000 .0 .000 59.0 .000 .0 .000 .0 1C172AL2o05062008SSN.txt Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 ROP MwD0.10 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3513.5 3549 3531.25 72 3513.5 3549 ROP MWDO10 FPH 0.27 64.31 15.8885 72 3513.5 3549 First Reading For Entire File..........3513.5 Last Reading For Entire File...........3549 File Trailer Service name... .......STSLI6.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLI6.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3505.0 3576.0 RPD 3508.0 3567.5 RPx 3508.0 3567.5 FET 3508.0 3567.5 RPS 3508.0 3567.5 RPM 3508.0 3567.5 ROP 3549.5 3620.0 LOG HEADER DATA DATE LOGGED:. O1-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 Page 6 1C172AL2o0506200855N.txt DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3620.0 TOP LOG INTERVAL (FT): 3549.0 BOTTOM LOG INTERVAL (FT): 3620.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... ............ Datum specification Block sub-type...0 65.7 67.0 TOOL NUMBER 250050 230203 9.875 3513.0 Fresh water Gel 9.00 53.0 9.5 500 9.0 1.750 72.0 2.100 59.0 1.650 72.0 2.300 72.0 Name service order units size Nsam Rep .code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 Page 7 1C172AL2o05062008SSN.txt RoP MwD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3505 3620 3562.5 231 3505 3620 RPD MWD020 OHMM 1.22 2000 171.561 120 3508 3567.5 RPM MWD020 OHMM 0.47 728.97 20.5484 120 3508 3567.5 RPS MWD020 OHMM 3.73 1501.03 26.8414 120 3508 3567.5 RPX MWD020 OHMM 2.88 1501.2 25.9054 120 3508 3567.5 FET MWD020 HR 0.77 38.4 27.5827 120 3508 3567.5 GR MWD020 API 24.01 94.2 51.6914 143 3505 3576 ROP MWD020 FPH 11.43 278.28 120.048 142 3549.5 3620 First Reading For Entire File..........3505 Last Reading For Entire File...........3620 File Trailer Service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3568.0 7357.0 RPM 3568.0 7357.0 RPx 3568.0 7357.0 FET 3568.0 7357.0 RPD 3568.0 7357.0 GR 3576.5 7357.0 ROP 3620.5 7357.0 LOG HEADER DATA DATE LOGGED: Page 8 04-APR-08 • 1C172AL2o05062008SSN.txt SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7357.0 TOP LOG INTERVAL (FT): 3620.0 BOTTOM LOG INTERVAL (FT): 7357.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 86.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 250050 EWR4 ELECTROMAG. RESIS. 4 230203 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3513.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 53.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1550 FLUID LOSS (C3): 7.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.800 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.350 102.0 MUD FILTRATE AT MT: 2.000 68.0 MUD CAKE AT MT: 2.200 66.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... ............ Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 Page 9 • 1C172AL2o05062008SSN.txt RPX MWD030 OHMM 4 1 68 16 5 FET MwD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 RoP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3568 7357 5462.5 7579 3568 7357 RPD MWD030 OHMM 3.38 102.98 13.0648 7579 3568 7357 RPM MwD030 OHMM 3.16 89.64 12.0009 7579 3568 7357 RPS MWD030 OHMM 3.38 112.34 11.8889 7579 3568 7357 RPX MWD030 OHMM 3.86 113.12 11.302 7579 3568 7357 FET MwD030 HR 0.27 11.18 1.00837 7579 3568 7357 GR MwD030 API 5 126.27 70.529 7562 3576.5 7357 ROP MWD030 FPH 4.72 341.79 144.742 7474 3620.5 7357 First Reading For Entire File..........3568 Last Reading For Entire File...........7357 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 10 .5000 VENDOR TOOL CODE ROP START DEPTH 7357.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 7391.0 25-APR-08 Insite 74.11 Page 10 • • 1C172AL2005062008SSN.txt DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7391.0 TOP LOG INTERVAL (FT): 7357.0 BOTTOM LOG INTERVAL (FT): 7391.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 84.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: TOOL NUMBER 6.750 7357.0 Mineral oil Base 9.30 73.0 .0 40000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point.... ...........undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 .000 .0 .000 99.7 .000 .0 .000 .0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FPH 4 1 68 4 2 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 7391 7374.25 68 7357.5 7391 ROP MWD100 FPH 0.03 19.9 6.76162 68 7357.5 7391 Page 11 • 1C172AL2005062008SSN.txt First Reading For Entire File..........7357.5 Last Reading For Entire File...........7391 File Trailer Service name... .......STSLI6.005 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7357.5 9890.0 GR 7357.5 9890.0 RPM 7357.5 9890.0 RPX 7357.5 9890.0 RPD 7357.5 9890.0 RPS 7357.5 9890.0 ROP 7391.5- 9890.0 LOG HEADER DATA DATE LOGGED: 27-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9890.0 TOP LOG INTERVAL (FT): 7391.0 BOTTOM LOG INTERVAL (FT): 9890.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 12 • • 1C172AL2o05062008SSN.txt DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 87.0 MUD PH: .O MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. Down optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing ........ ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 9890 8623.75 5066 7357.5 9890 RPD MWD110 OHMM 7.05 144.88 30.4539 5066 7357.5 9890 RPM MWD110 OHMM 6.07 162.83 30.203 5066 7357.5 9890 RPS MWD110 OHMM 5.98 102.93 28.9197 5066 7357.5 9890 RPX MWD110 OHMM 6.05 972.21 31.1894 5066 7357.5 9890 Page 13 1C172AL2005062008SSN.txt FET MWD110 HR 0.15 538.62 1.16567 5066 7357.5 9890 GR MWD110 API 41.24 108.57 67.9 181 5066 7357.5 9890 ROP MWD110 FPH 11.9 914.91 221. 266 4998 7391.5 9890 First Reading For Entire File.......... 7357.5 Last Reading For Entire File........... 9890 File Trailer Service name... .......STSLIB.006 ~ Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLI6.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9890.5 12100.0 GR 9890.5 12100.0 FET 9890.5 12100.0 RPx 9890.5 12100.0 RPS 9890.5 12100.0 RPM 9890.5 12100.0 RPD 9890.5 12100.0 LOG HEADER DATA DATE LOGGED: 29-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12100.0 TOP LOG INTERVAL (FT): 9890.0 BOTTOM LOG INTERVAL (FT): 12100.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 94.1 Page 14 C~ C~ 1C172AL2o050620085SN.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 85.0 MUD PH: .O MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT RPD MWD120 RPM MWD120 RPS MWD120 RPX MWD120 FET MWD120 GR MWD120 ROP MWD120 Units FT OHMM OHMM OHMM OHMM HR API FPH Size 4 4 4 4 Nsam Rep code offset channel 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9890.5 12100 10995.3 4420 RPD MWD120 OHMM 9.83 65.02 30.6688 4420 Page 15 First Reading 9890.5 9890.5 Last Reading 12100 12100 • 1C172AL200506200855N.txt RPM MWD120 OHMM 9.01 1679.1 31.4913 4420 9890.5 12100 RPS MWD120 OHMM 8.16 1184.93 30.5827 4420 9890.5 12100 RPX MWD120 OHMM 7.94 845.68 32.8586 4420 9890.5 12100 FET MWD120 HR 0.15 6.67 0.571124 4420 9890.5 12100 GR MWD120 API 44.82 159.9 68.2861 4420 9890.5 12100 ROP MWD120 FPH 1.78 487.93 218.935 4420 9890.5 12100 First Reading For Entire File..........9890.5 Last Reading For Entire File...........12100 File Trailer service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 12100.0 13018.5 RPX 12100.5 12976.0 RPD 12100.5 12976.0 GR 12100.5 12969.0 FET 12100.5 12976.0 RPM 12100.5 12976.0 RPS 12100.5 12976.0 LOG HEADER DATA DATE LOGGED: 06-MAY-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13018.0 TOP LOG INTERVAL (FT): 12100.0 BOTTOM LOG INTERVAL (FT): 13018.0 BIT ROTATING SPEED (RPM): Page 16 1C172AL2O05062008SSN.txt HOLE INCLINATION (DEG MINIMUM ANGLE: $8.7 MAXIMUM ANGLE: 91.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Re sis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (s): 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATU RE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 120.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FPH 4 1 68 28 8 First Last Page 17 1C172AL2o0506200855N.txt Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12100 13018.5 12559.3 1838 12100 13018.5 RPD MWD140 OHMM 9.11 199.78 23.2554 1752 12100.5 12976 RPM MWD140 OHMM 7.18 201.15 23.4006 1752 12100.5 12976 RPS MWD140 OHMM 6.27 52.54 21.2985 1752 12100.5 12976 RPX MWD140 OHMM 5.85 204.42 20.1859 1752 12100.5 12976 FET MwD140 HR 0.24 143.04 1.80502 1752 12100.5 12976 GR MWD140 API 44.46 110.74 65.9499 1738 12100.5 12969 ROP MWD140 FPH 0 1111.59 124.839 1838 12100 13018.5 First Reading For Entire File..........12100 Last Reading For Entire File...........13018.5 File Trailer Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File TyC~e....... .......LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date . ................... 08/06/12 Origin ................... STS Tape Name. .... ........ UNKNOWN continuation Number...... 01 Next Tape Name........... UNKNOWN Comments ................. STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/06/12 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LIS Physical EOF Physical EOF End Of LIS File writing Library. Scientific Technical services writing Library. Page 18 scientific Technical services • 1C172AL2PB1004292008SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri .7un 13 08:26:08 2008 Reel Header Service name .............LISTPE Date . ...................08/06/13 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/06/13 0rigin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: 1C-172A L2 PB1 API NUMBER: 500292315970 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 12-]UN-08 ]OB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 706 NUMBER: w-0005476893 w-0005476893 w-0005476893 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: F. HERBERT F. HERBERT M. THORNTON MWD RUN 10 MWD RUN 11 X06 NUMBER: w-0005476893 w-0005476893 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: F. HERBERT F. HERBERT SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: l0E FNL: 1436 FSL: FEL: FWL: 1096 Page 1 .~O~S-C) ~ U /tea. ~ ~ 1C172AL2P61004292008SSN.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 100.50 GROUND LEVEL: 59.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3513.0 2ND STRING 6.750 7.625 7357.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 7-9 DID NOT INCLUDE FORMATION-EVALUATION TOOLS. 4. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7357'MD/3840'TVD, WITHIN THE RUN 3 INTERVAL OF 1C-172A. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 10. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 5. MWD RUNS 2,3,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZ- ING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). GEO-PILOT ROTARY STEERABLE BHA (GP) WAS ALSO INCLUDED IN MWD RUN 11. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M.WERNER (CPAI) TO R.KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,10,11 REPRESENT WELL 1C-172A L2PB1 WITH API#: 50-029- 23159-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10205'MD/3812'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). Page 2 ~ ~ 1C172AL2P61o04292008SSN.txt SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3505.0 RPx 3508.0 RPS 3508.0 RPM 3508.0 FET 3508.0 RPD 3508.0 ROP 3513.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD all bit runs merged. STOP DEPTH 10155.5 10162.5 10162.5 10162.5 10162.5 10162.5 10205.0 BIT RUN NO MERGE TOP 1 3513.5 2 3549.0 3 3620.0 10 7357.5 11 7391.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3549.0 3620.0 7357.0 7391.0 10205.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 3 s ~- 1C172AL2P61o0429200855N.txt Depth units. .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3505 10205 6855 13401 3505 10205 RPD MWD OHMM 1.22 2000 22.8176 13310 3508 10.162.5 RPM MWD OHMM 0.47 728.97 21.0275 13310 3508 10162.5 RPS MWD OHMM 3.38 1501.03 20.2274 13310 3508 10162.5 RPX MWD OHMM 2.88 1501.2 20.5991 13310 3508 10162.5 FET MWD HR 0.14 538.62 1.28934 13310 3508 10162.5 GR MWD API 5 126.27 69.3126 13302 3505 10155.5 ROP MWD FPH 0.03 914.91 176.496 13384 3513.5 10205 First Reading For Entire File..........3505 Last Reading For Entire File...........10205 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 4 1C172AL2PB1004292008SSN.txt OP 3513.5 3549.0 $ LOG HEADER DATA DATE LOGGED: 31-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3549.0 TOP LOG INTERVAL (FT): 3513.0 BOTTOM LOG INTERVAL (FT): 3549.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.0 MAXIMUM ANGLE: 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3513.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 53.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 59.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ............ ... ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 5 • 1C172AL2P61o0429200855N.txt ROP MWDO10 FPH 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3513.5 3549 3531.25 72 3513.5 3549 ROP MWDO10 FPH 0.27 64.31 15.8885 72 3513.5 3549 First Reading For Entire File..........3513.5 Last Reading For Entire File...........3549 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3505.0 3576.0 RPD 3508.0 3567.5 RPx 3508.0 3567.5 RPM 3508.0 3567.5 FET 3508.0 3567.5 RP5 3508.0 3567.5 ROP 3549.5 3620.0 LOG HEADER DATA DATE LOGGED: O1-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3620.0 TOP LOG INTERVAL (FT): 3549.0 Page 6 1C172AL2PB1o04292008SSN.txt BOTTOM LOG INTERVAL (FT): 3620.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.7 MAXIMUM ANGLE: 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 250050 EWR4 ELECTROMAG. RESIS. 4 230203 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3513.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Fresh water Gel 9.00 53.0 9.5 500 9.0 1.750 72.0 2.100 59.0 1.650 72.0 2.300 72.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 Page 7 CJ 1C172AL2PB1o04292008SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3505 3620 3562.5 231 3505 3620 RPD MWD020 OHMM 1.22 2000 171.561 120 3508 3567.5 RPM MWD020 OHMM 0.47 728.97 20.5484 120 3508 3567.5 RPS MWD020 OHMM 3.73 1501.03 26.8414 120 3508 3567.5 RPX MWD020 OHMM 2.88 1501.2 25.9054 120 3508 3567.5 FET MWD020 HR 0.77 38.4 27.5827 120 3508 3567.5 GR MWD020 API 24.01 94.2 51.6914 143 3505. 3576 ROP MWD020 FPH 11.43 278.28 120.048 142 3549.5 3620 First Reading For Entire File..........3505 Last Reading For Entire File...........3620 File Trailer service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3568.0 7357.0 RPx 3568.0 7357.0 RPM 3568.0 7357.0 RPS 3568.0 7357.0 RPD 3568.0 7357.0 GR 3576.5 7357.0 RoP 3620.5 7357.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE S OFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: Page 8 04-APR-08 Insite 74.11 s 1C172AL2P61004292008SSN.txt DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7357.0 TOP LOG INTERVAL (FT): 3620.0 BOTTOM LOG INTERVAL (FT): 7357.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ... ..... Datum specification Block sub-type...0 65.2 86.9 • TOOL NUMBER 250050 230203 9.875 3513.0 Fresh water Gel 9.10 53.0 9.0 1550 7.5 1.800 75.0 1.350 102.0 2.000 68.0 2.200 66.0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 Page 9 1C172AL2PB1004292008SSN.txt RoP MWD030 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3568 7357 5462.5 7579 3568 7357 RPD MWD030 OHMM 3.38 102.98 13.0648 7579 3568 7357 RPM MWD030 OHMM 3.16 89.64 12.0009 7579 3568 7357 RPS MWD030 OHMM 3.38 112.34 11.8889 7579 3568 7357 RPX MWD030 OHMM 3.86 113.12 11.302 7579 3568 7357 FET MWD030 HR 0.27 11.18 1.00837 7579 3568 7357 GR MWD030 API 5 126.27 70.529 7562 3576.5 7357 ROP MWD030 FPH 4.72 341.79 144.742 7474 3620.5 7357 First Reading For Entire File..........3568 Last Reading For Entire File...........7357 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSL2B.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 7357.5 LOG HEADER DATA. DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 7391.0 Page 10 25-APR-08 Insite 74.11 Memory 7391.0 7357.0 1C172AL2PB1o04292008SSN.txt BOTTOM LOG INTERVAL (FT): 7391.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 84.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 7357.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Mineral oil Base 9.30 73.0 .0 40000 .0 .000 .0 .000 99.7 .000 .0 .000 .0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 7391 7374.25 68 7357.5 7391 ROP MWD100 FPH 0.03 19.9 6.76162 68 7357.5 7391 First Reading For Entire File..........7357.5 Page 11 • • 1C172AL2PB1o042920085SN.txt Last Reading For Entire File...........7391 File Trailer Service name... ....STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type .............. .LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7357.5 10162.5 RPD 7357.5 10162.5 RPM 7357.5 10162.5 GR 7357.5 10155.5 FET 7357.5 10162.5 RPS 7357.5 10162.5 ROP 7391.5 10205.0 LOG HEADER DATA DATE LOGGED: 28-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10205.0 TOP LOG INTERVAL (FT): 7391.0 BOTTOM LOG INTERVAL (FT): 10205.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 223565 Page 12 • 1C172AL2P61o0429200855N.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 .BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 87.0 MUD PH: .O MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 10205 8781.25 5696 7357.5 10205 RPD MWD110 OHMM 7.05 144.88 32.8101 5611 7357.5 10162.5 RPM MwD110 OHMM 6.07 162.83 33.2303 5611 7357.5 10162.5 RPS MWD110 OHMM 5.98 125.72 31.3491 5611 7357.5 10162.5 RPX MWD110 OHMM 6.05 972.21 33.0435 5611 7357.5 10162.5 FET MWD110 HR 0.14 538.62 1.10652 5611 7357.5 10162.5 GR MWD110 API 41.24 108.57 68.1195 5597 7357.5 10155.5 ROP MWD110 FPH 11.9 914.91 224.197 5628 7391.5 10205 Page 13 • 1C172AL2PB1o04292008SSN.txt First Reading For Entire File..........7357.5 Last Reading For Entire File...........10205 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 gate of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/06/13 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/06/13 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 14 • 1c-172a12pb2.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 13 08:44:48 2008 Reel Header Service name .............LISTPE Date . ...................08/06/13 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/06/13 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: 1C-172A L2 PB2 500292315971 ConocoPhillips Alaska Inc. Sperry Drilling Services 13-JUN-08 MWD RUN 1 MWD RUN 2 MWD RUN 3 W-0005476893 W-0005476893 W-0005476893 B. HENNINGSE B. HENNINGSE B. HENNINGSE F. HERBERT F. HERBERT M. THORNTON MWD RUN 10 MWD RUN 11 MWD RUN 12 W-0005476893 W-0005476893 W-0005476893 6. HENNINGSE 6. HENNINGSE B. HENNINGSE F. HERBERT F. HERBERT F. HERBERT 12 11N l0E 1436 1096 Page 1 ~C~~s~UlO /Cv~3 C~ 1c-172a12pb2.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 100.50 GROUND LEVEL: 59.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3513.0 2ND STRING 6.750 7.625 7357.0 3RD STRING PRODUCTION STRING REMARKS: C 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 1C-172A L2PB1 WELLBORE AT 9890'MD/3815'TVD, WITHIN THE MWD RUN 11 INTERVAL. 4. MWD RUNS 2,3,11,12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZ- ING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). GEO-PILOT ROTARY STEERABLE BHA (GP) WAS ALSO INCLUDED IN MWD RUNS 11,12. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M.WERNER (CPAI) TO R.KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3,10-12 REPRESENT WELL 1C-172A L2PB2 WITH API#: 50-029- 23159-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12424'MD/3796'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT Page 2 1c-172a12pb2.tapx WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPX FET RPS ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3505.0 3508.0 3508.0 3508.0 3508.0 3508.0 3513.5 STOP DEPTH 12375.0 12382.0 12382.0 12382.0 12382.0 12382.0 12424.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 3513.5 3549.0 2 3549.0 3620.0 3 3620.0 7357.0 10 7357.5 7391.0 11 7391.0 9890.0 12 9890.5 12424.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 Page 3 1c-172a12pb2.tapx RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 3505 12424 7964.5 17839 3505 12424 RPD MWD OHMM 1.22 2000 23.9785 17749 3508 12382 RPM MWD OHMM 0.47 1679.1 22.6922 17749 3508 12382 RPS MWD OHMM 3.38 1744.69 22.1524 17749 3508 12382 RPX MWD OHMM 2.88 2000 23.3107 17749 3508 12382 FET MWD HR 0.15 538.62 1.1113 17749 3508 12382 GR MWD API 5 159.9 69.2614 17741 3505 12375 ROP MWD FPH 0.03 914.91 184.148 17822 3513.5 12424 First Reading For Entire File..........3505 Last Reading For Entire File...........12424 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 3513.5 3549.0 LOG HEADER DATA DATE LOGGED: SOFTWARE 31-MAR-08 Page 4 1c-172a12pb2.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3549.0 TOP LOG INTERVAL (FT): 3513.0 BOTTOM LOG INTERVAL (FT): 3549.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.0 MAXIMUM ANGLE: 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3513.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 53.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 500 FLUID LO55 (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 59.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 5 1c-172a12pb2.tapx DEPT FT 3513.5 3549 3531.25 ROP MWDO10 FPH 0.27 64.31 15.8885 First Reading For Entire File..........3513.5 Last Reading For Entire File...........3549 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD 72 3513.5 3549 72 3513.5 3549 curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3505.0 3576.0 RPD 3508.0 3567.5 RPM 3508.0 3567.5 RPx 3508.0 3567.5 RPS 3508.0 3567.5 FET 3508.0 3567.5 RoP 3549.5 3620.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Page 6 O1-APR-08 Insite 74.11 Memory 3620.0 3549.0 3620.0 65.7 67.0 1c-172a12pb2.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 250050 EWR4 ELECTROMAG. RESIS. 4 230203 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3513.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ...0 Fresh water Gel 9.00 53.0 9.5 500 9.0 1.750 72.0 2.100 59.0 1.650 72.0 2.300 72.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 3505 3620 3562.5 231 RPD MWD020 OHMM 1.22 2000 171.561 120 RPM MWD020 OHMM 0.47 728.97 20.5484 120 Page 7 First Reading 3505 3508 3508 Last Reading 3620 3567.5 3567.5 ,_ 1c-172a12pb2.tapx RPS MWD020 OHMM 3.73 1501.03 26.8414 120 3508 3567.5 RPX MWD020 OHMM 2.88 1501.2 25.9054 120 3508 3567.5 FET MWD020 HR 0.77 38.4 27.5827 120 3508 3567.5 GR MWD020 API 24.01 94.2 51.6914 143 3505 3576 ROP MWD020 FPH 11.43 278.28 120.048 142 3549.5 3620 First Reading For Entire File..........3505 Last Reading For Entire File...........3620 File Trailer Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record ...65535 File Ty e ................LO Next Fie Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPx 3568.0 FET 3568.0 RPM 3568.0 RPS 3568.0 RPD 3568.0 GR 3576.5 RoP 3620.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG header data for each bit run in separate files. 3 .5000 STOP DEPTH 7357.0 7357.0 7357.0 7357.0 7357.0 7357.0 7357.0 Page 8 04-APR-08 Insite 74.11 Memory 7357.0 3620.0 7357.0 ~ ~ 1c-172a12pb2.tapx MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 86.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 250050 EWR4 ELECTROMAG. RESIS. 4 230203 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3513.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... ...... ..... Datum Specification Block sub-type...0 Fresh water Gel 9.10 53.0 9.0 1550 7.5 1.800 75.0 1.350 102.0 2.000 68.0 2.200 66.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MwD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 9 1c-172a12pb2.tapx DEPT FT 3568 7357 5462.5 7579 3568 7357 RPD MWD030 OHMM 3.38 102.98 13.0648 7579 3568 7357 RPM MWD030 OHMM 3.16 89.64 12.0009 7579 3568 7357 RPS MWD030 OHMM 3.38 112.34 11.8889 7579 3568 7357 RPX MWD030 OHMM 3.86 113.12 11.302 7579 3568 7357 FET MWD030 HR 0.27 11.18 1.00837 7579 3568 7357 GR MWD030 API 5 126.27 70.529 7562 3576.5 7357 ROP MWD030 FPH 4.72 341.79 144.742 7474 3620.5 7357 First Reading For Entire File..........3568 Last Reading For Entire File...........7357 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7357.5 7391.0 LOG HEADER DATA DATE LOGGED: 25-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7391.0 TOP LOG INTERVAL (FT): 7357.0 BOTTOM LOG INTERVAL (FT): 7391.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 84.4 Page 10 • ~ 1c-172a12pb2.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 73.0 MUD PH: .O MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 99.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD100 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 7391 7374.25 68 7357.5 7391 ROP MWD100 FPH 0.03 19.9 6.76162 68 7357.5 7391 First Reading For Entire File..........7357.5 Last Reading For Entire File...........7391 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... Page 11 t i 1c-172a12pb2.tapx version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7357.5 9890.0 FET 7357.5 9890.0 RPS 7357.5 9890.0 GR 7357.5 9890.0 RPM 7357.5 9890.0 RPD 7357.5 9890.0 ROP 7391.5 9890.0 LOG HEADER DATA DATE LOGGED: 27-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9890.0 TOP LOG INTERVAL (FT): 7391.0 BOTTOM LOG INTERVAL (FT): 9890.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS Page 12 1c-172a12pb2.t apx MUD TYPE: Mineral oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 87.0 MUD PH: .0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7357.5 9890 8623.75 5066 7357.5 9890 RPD MWD110 OHMM 7.05 144.88 30.4539 5066 7357.5 9890 RPM MWD110 OHMM 6.07 162.83 30.203 5066 7357.5 9890 RPS MWD110 OHMM 5.98 102.93 28.9197 5066 7357.5 9890 RPX MWD110 OHMM 6.05 972.21 31.1894 5066 7357.5 9890 FET MWD110 HR 0.15 538.62 1.16567 5066 7357.5 9890 GR MWD110 API 41.24 108.57 67.9181 5066 7357.5 9890 ROP MWD110 FPH 11.9 914.91 221.266 4998 7391.5 9890 First Reading For Entire File..........7357.5 Last Reading For Entire File...........9890 Page 13 1c-172a12pb2.tapx File Trailer Service name... .......STSLI6.006 service sub Level Name... version Number. ........-1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File TyC~e ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9890.5 RPD 9890.5 ROP 9890.5 FET 9890.5 RPS 9890.5 RPM 9890.5 RPx 9890.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 12375.0 12382.0 12424.5 12382.0 12382.0 12382.0 12382.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 29-APR-08 Insite 74.11 Memory 12424.0 9890.0 12424.0 88.6 94.1 TOOL NUMBER 184054 223565 6.750 Page 14 1c-172a12pb2.tapx DRILLER'S CASING DEPTH (FT): 7357.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 85.0 MUD PH: .O MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9890.5 12424.5 11157.5 5069 9890.5 12424.5 RPD MWD120 OHMM 7.31 1534.47 30.4394 4984 9890.5 12382 RPM MWD120 OHMM 7.04 1679.1 31.3674 4984 9890.5 12382 RPS MWD120 OHMM 5.32 1744.69 30.7682 4984 9890.5 12382 RPX MWD120 OHMM 7.94 2000 33.501 4984 9890.5 12382 FET MWD120 HR 0.15 6.67 0.575213 4984 9890.5 12382 GR MWD120 API 44.82 159.9 69.2077 4970 9890.5 12375 ROP MWD120 FPH 1.78 487.93 212.202 5069 9890.5 12424.5 First Reading For Entire File..........9890.5 Page 15 1c-172a12pb2.tapx Last Reading For Entire File...........12424.5 File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/13 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/13 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 16
