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208-009
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 13,102 feet N/A feet true vertical 3,850 feet N/A feet Effective Depth measured 13,102 feet 6,985', 7,455', 7,926', 7,961'ft true vertical 3,850 feet 3,785', 3,851', 3,901', 3,905'ft Perforation depth Measured depth 8,103'-9,863'; 9,990'-12,533'; 12,704'-13,047'feet True Vertical depth 3,904'-3,881'; 3,880'-3,857'; 3,856'-3,851'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 2. Operator Name Senior Engineer:Senior Res. Engineer: Collapse N/A Burst N/A TVD N/A 110 2,501 3,939 Length N/A 70 3,850 Structural N/A 16 9 5/8 7 5/8 4 1/2 Conductor Surface Production Authorized Signature with date: Authorized Name: Liner 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-288 263 Size 3,600 8,261 5,062 Casing 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 202 Gas-Mcf measuredPlugs Junk measured N/A 46 1092 KRU 1C-172AL1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-009 50-029-23159-01-00 N/A 5. Permit to Drill Number:4. Well Class Before Work: 219 Representative Daily Average Production or Injection Data 301435 Casing Pressure Tubing Pressure ADL 25649, ADL 0025650 Kuparuk River Field / West Sak Oil Pool measured true vertical Packer 6,985', 7,455', 7,926', 7,961' MD N/A 110 3,640 8,310 13,092 3,785', 3,851', 3,901', 3,905' 2375 WINJ WAG 43 Water-Bbl ZXP Liner Top Packer, ZXP Liner Top Packer, ZXP HRD Liner Top Packer, Baker Seal Assembly. No SSSV. 2107 Oil-Bbl 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 11:52:24 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson By Samantha Carlisle at 9:50 am, Aug 06, 2020 DSR-8/6/2020 60 HEW VTL 8/11/20 SFD 8/10/2020RBDMS HEW 8/6/2020 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 AL1 OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 8,030.3 Set Depth (ftKB) 13,092.0 Set Depth (TVD) … 3,850.6 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) 8,030.3 3,903.0 88.68 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.910 8,091.9 3,903.9 89.51 XO Reducing CROSSOVER 5.5x4.5" 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 8,103.0 9,863.0 3,904.0 3,881.2 WS A3, 1C- 172AL1 4/20/2008 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 9,990.0 12,533.0 3,880.5 3,856.9 WS A3, 1C- 172AL1 4/20/2008 32.0 SLOTS 12,704.0 13,047.0 3,856.4 3,851.0 WS A3, 1C- 172AL1 4/20/2008 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-172AL1, 10/2/2017 1:08:09 PM Vertical schematic (actual) LINER AL1; 8,030.3-13,092.0 SLOTS; 12,704.0-13,047.0 SLOTS; 9,990.0-12,533.0 SLOTS; 8,103.0-9,863.0 AL1 Liner LEM; 7,455.2-7,964.0 INTERMEDIATE; 49.1-8,310.0 AL2 Liner HH; 7,354.7-7,608.0 WINDOW L2; 7,357.0-7,367.0 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: PULL SLIP STOP, DB LOCK w/JET PUMP, SET DB LOCK w/JET PUMP & SLIP STOP 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-172AL1 H2S (ppm) 90 Date 8/12/2016 ... TD Act Btm (ftKB) 13,102.0 Well Attributes Wellbore API/UWI 500292315960 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 93.82 MD (ftKB) 12,736.09 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.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1C-172AL1 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): 13,102 N/A 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 3,850 Perforation Depth MD (ft): 8,103'-9,863'; 9,990'-12,533'; 12,704'-13,047' L-80 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. 3,640 8,261 4 1/2 Authorized Signature: 7/23/2020 13,0925,062 4.5" 3,600 11016 9 5/8 70 TVD 3,9397 5/8 8,310 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25638 2,501 110 1,015 Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY Size Burst 7,265' MD 208-009 COMMISSION USE ONLY Authorized Name: P.O. Box 100360, Anchorage, Alaska 99510 50-029-23159-60 ConocoPhillips Alaska, Inc. Length Tubing Grade: Packers and SSSV Type: Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer Packer: ZXP HRD Liner Top Packer Packer: Baker Seal Assembly SSSV: None Packers and SSSV MD (ft) and TVD (ft): 6985' MD/ 3785' TVD 7455' MD/ 38501' TVD 7926' MD/ 3901' TVD 7961' MD/ 3905' TVD SSSV: N/A 3,850 13,102 3,850 3,904'-3,881'; 3,880'-3,857'; 3,856'-3,851' Tubing MD (ft): N/A m n P s 66 t t c W 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 320-288 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 17:53:39 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson X -00 DLB X DSR-7/8/2020VTL 7/15/20 0025650 DLB DLB 07/08/2020 10-404 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 17:54:00 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 AL1 OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 8,030.3 Set Depth (ftKB) 13,092.0 Set Depth (TVD) … 3,850.6 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) 8,030.3 3,903.0 88.68 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.910 8,091.9 3,903.9 89.51 XO Reducing CROSSOVER 5.5x4.5" 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 8,103.0 9,863.0 3,904.0 3,881.2 WS A3, 1C- 172AL1 4/20/2008 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 9,990.0 12,533.0 3,880.5 3,856.9 WS A3, 1C- 172AL1 4/20/2008 32.0 SLOTS 12,704.0 13,047.0 3,856.4 3,851.0 WS A3, 1C- 172AL1 4/20/2008 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-172AL1, 10/2/2017 1:08:09 PM Vertical schematic (actual) LINER AL1; 8,030.3-13,092.0 SLOTS; 12,704.0-13,047.0 SLOTS; 9,990.0-12,533.0 SLOTS; 8,103.0-9,863.0 AL1 Liner LEM; 7,455.2-7,964.0 INTERMEDIATE; 49.1-8,310.0 AL2 Liner HH; 7,354.7-7,608.0 WINDOW L2; 7,357.0-7,367.0 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: PULL SLIP STOP, DB LOCK w/JET PUMP, SET DB LOCK w/JET PUMP & SLIP STOP 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-172AL1 H2S (ppm) 90 Date 8/12/2016 ... TD Act Btm (ftKB) 13,102.0 Well Attributes Wellbore API/UWI 500292315960 Field Name WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 93.82 MD (ftKB) 12,736.09 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 Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o~ ~ ~ - ~ Q (.~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ~..o,ard iiumiiiuiuuii DI ITAL DATA Diskettes, No. t ^ Other, No/Type: R~~a~~e~~ miiiiiuuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ` /s/ Project Proofing II I II ~I II I I III I I III BY: Maria Date: /s/ Scanning Preparation ~_ x 30 = + _ o~~ =TOTAL PAGES 1^ l (Count does not include cover sheet) ~/~ ,~ BY: Maria _ _ Date: ~ / ~~ ~ n /s/ ' V Production Scanning Stage 1 Page Count from Scanned File: ~_ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: lla~' ~ d /sl ,M Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO , ~1' BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III I II II I II II I I III ReScanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III I~III III IIII III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1 /14/2009 Permit to Drill 2080090 Well Name/No. KUPARUK RIV U WSAK 1C-172AL1 Operator CONOCOPHILLIPS ALASKA INC MD 13102 TVD 351 Completion Date 5/12/2008 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name pt /LIS Verification ~D C Lis 16500 !Induction/Resistivity ,,~U D Asc Directional Survey Directional Survey ',~g Induction/Resistivity ~g Induction/Resistivity /ED C 16717~See Notes Well Cores/Samples Information: Name ADDITIONAL INFORMATION) Well Cored?C Chips Received? ""Y / N/ Analysis 1~~IV Received? Comments: Samples No Current Status 1-OIL API No. 50-029-23159-60-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 3508 13102 Open 6/24/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 3508 13102 Open 6/24/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 0 13102 Open 6/24/2008 0 13102 Open 6/24/2008 25 Col 2448 3850 Open 8/8/2008 TVD DGR, EWR 25 Col 3513 13102 Open 8/8/2008 MD ROP DGR, EWR 0 0 8/8/2008 EWR logs in TVD and MD in EMF, CGM and PDS graphics Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y / Formation Tops JAN DATA SUBMITTAL COMPLIANCE REPORT 1 /14/2009 Permit to Drill 2080090 Well Name/No. KUPARUK RIV U WSAK 1C-172AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23159-60-00 MD 13102 TVD 351 Completion Date 5/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N _ Compliance Reviewed By: - _ __ __ --- Date _- __ - -- ~ ~___ c'!~-` _ -- - -__ _~ t~ C~ Page 1 of 3 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 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 Taol schematics, and the linedhook 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 - Belaw isthe breakdown. of blank intervals for each of the laterals for 1 C-172A for your review before forwarding to Tom Maunder. I wilt 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'-1!041.0' MD 392T-392.9' ND 12601' -12773' M D 3911'-3912' TVD 13027'-13072' MD 3914'-3915' TVD 1 C-172AL1: entire liner is slotted except for the following: blank intervals - 7818'-8103' MD 3904'-3904' TVD ~---~ 9863'-9990' MD 3881'-3880' TVD 12533'-12705' MD 3856'-3855' TVD 13047'-13092' MD 3851'-3851' TVD 1 C-172AL2: entire liner is slotted except for the following blank intervals - 7354'-7622' MD 3846'-3845' TVD 7752'-7880' MD 3853'-3850' TVD 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: iC-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.].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: 1C-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.]. Reilly@conocoph illips.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: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) HiTom- 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 ConocoPhillips Alaska, Inc. office: 907.265.6826 cell : 907.351.5004 home: 907.345.1229 Units of Conversion: 1000 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: 1C-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 COCtCyCQ~ll~fl~5 •• Well~onfig_ 1C~1725L1,'Ifll ~~_ _. SchemeL%~ acw HANGER, 36 ~ ~~ NIPPLE, 511 -- - HEATTRACE._ 36 GAS LIFT. __ --. _ 3.394 GAS LIFT, _- _ _J 6,692 JIII1 SURFACE, 0-6,712 DISCHARGE, 6.740 FLUFED SUB, 6.783 SLEEVE, 6,]84 FLUTED SUB, 6,788 XO, 6.824 -- GAUGE, 6.825 ---- - %O, 6,830 LOCATOR, ___ 7,241 -- - _ - SEAL ASSV. _- -..___ 7,243 A4 CSG WINDOW, ],357-7,36] Lt -A3 LEM,_ 7,455-7,964 L1 -A3 HK NJ HNGR.- 7.818-8.082 SLOTS, 8,103-9,Bfi3 -- _ SLOTS,.-._ 9,990.12,533 SLOTS. -+~}~ ~;'-. _ ___} ~« L1-A3 LINER. 8,030-13,092 TD (1C-172AL1), 13,102 ~ -- - ~ KU P 1 C-172AL1 _ -- Well Attribute s __ Max A ngle 8 MD .. TD __ Wellhore APVUWI ' Field Name __ Well Status Prod/Inj Type Inc! (°) MD (kK8) Act Btm (ftKB) 500292315960 WEST SAK (PROD I 93.82 I 12,736.09 13,1020 _ Comment Annotahon I, End Date H2S (ppm) Date KB-Grd (ft) RigR 1 Data SSSV: NIPPLE 11 ( ~ 0 7/1/2008 Last WO: I 5113!2008 33.39 6!24/2003 Annotation Annotation Depth (ftKB) End Da[e i End Dale ' Last Tag: ( ( Rev Reason: SCHEMATIC CORRECTIONS 2/2/2009 Casin Strin s '.Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrd iL1-A3 LEM ( 41/2 3.958 7,455.2 7,964.0 3,9006 12.60 L-80 IBT _ Casing Description String 0... I String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ._ String Top Thrd L7 -A3 HK IiNGR '~. 41/2 ! 4.000 7,818.3 8,082.1 , 3,903.7 11.60 L-80 BiC --.- Casing Description String 0... iString ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ._ String Top Thrd L7 -A3 LINER 4 1/2 I 4.000 8,030.3 13,092.0 3.850.6 1.1.60. L 80 __ BTC. . Liner Details I Top Depth __ _ - --- - ~I (NDI I Top Inc! i ToP (TVD) Btm (TVD) uens t ( ) dm ftKB (kK8) (ftKB) Zone Date (sh-~ Typa_. _ _ _ , 9,863.0 3,903.9 3,880.91 WS A3, 4/20/2008 32.0 SLOTS 1C-172AL7 12,533.0 3,880.6 3 856.81 WS A3, 4/20/2008 32 0 SLOTS i1C-172AL1 i 13,047.0 3,858.0 3 851.0-WS A3, 4/20!2008 32.0 SLOTS 1C-172AL1 eneral 8 Safet _ Annotation NOTE: VIEW SCHEMATIC w/AlaskaSchem atic9.0 landrel Details - TOpDepth Top ~ PoA (TVD) Inc! OD Valve Latch Size TRO Run n Top (ftKB) (ftKB) (°) Make Model (in) Serv Type Type (in) (ps) Run Date Com_ m_ ... 1 3,394.5 2 400.6 65 64~CAMCO KBMG 1 Gas Lift GLV BK 0.156 1,263.0 8/1412008 2 6,692.0 3,690.4 67 61 CAMCO KBMG 1 Gas Llft OV BKO-3 0 0 8/1412008 Ports 3/8" x __. _. _.___ _... ~._. _... __ J. ---._ 7/16"- ~~ ~~,. Slotted and Blank Liner Detail Well: 1C-172AL1 Conoco P hil li ps 1C-172A A3 Lateral 4-112" Plop & Drop Slotted Liner Date: 4/20/2008 Alaska, Inc. Rig: Doyon 15 Drilling Supervisors; Fred Herbert /Scott Lapiene Deptn Jt Number N Jtsof Well Equipment Description and Comments <, ~ P,~.StQ,1 Length Tops t. ~ n ,~. ~~ ~ ~ .. DP XO XT39 to 3-1/2" IF 1.51 8022.06 H~ err ? r,~r setti=~~ to~?!~ [3c~es r~r3t stay in hotel 6.70 8023.57 ?.?" Baker "HR" Liner Setting Sleeve~w/ 6' TBR 12.61 so3o.27 aoa2.aa 5 1/2", 15.5 ppf, L-80, Hydril 521 Pup joint Pin x Pin 7.36 aoa2.sa 5 1/2", 15.5 ppf, L-80, Hydril 521 (Receptacle Joint) 41.65 8050.24 5 1/2" Hyd 521 Box X 4 1/2" BTC Pin XO {3.92" I.D.) 1.46 8091.89 8093.35 4-1/2", 11.6 ppf, L-80, BTC Pup Joint w/ Torque rings 9.81 8093.35 Jts 76 to 116 a? Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing wl Torque rings 1759.68 8103.16 Jts 73 to 75 3 Jt5 4-1/2", 11.6 ppf, L-80, BTC Blank Casing w/ Torque rings 126.89 9862.84 Jts 61 to 72 12 Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing w/ Torque rings 501.91 9989.73 Jts 13 to 60 48 Jts 4-112",11.6 ppf, L-80, BTC Slotted Caking 2041.46 10491.64 Jts 9 to 12 4 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 171.53 12533.10 Jts 1 to 8 8 Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing 342.60 12704.63 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.14 13047.23 4-112" BTC Silver Bullet Float Shoe (O.D. 4.95") 1.63 13090.37 Bttm of Tail =_> 13092.00 13092.00 TD 6 3/4" hole @ 13102.42' MD ! 3850.55' TVD 13092.00 4-112" Shoe @ 13092' MD / 3850.63' TVD (10') 13092.00 TOW 7820' MD 13092.00 BOW 7833.68' MD 13092.00 13092.00 13092.00 13092.00 13092.00 Total Parts used: 111 HydroForm Centralizers 13092.00 Run 1 HydroForm Centralizer per joint floating 13092.00 f! Jt 1 thru Jt 116 (4.5" X 6.3") 13092.00 Installed Torque rings in Joints 61 Thru 116 Total of 56 13092.00 DO NOT RUN HYDROFORMS ON CONSTRICTOR JOINTS 13092.00 13092.00 Total of 5 Constrictor Packers ran @ 12,702' / 12,573' / 9960' 13092.00 9895' / 8100' 13092.00 Remarks: Ran total of 8 jts Blank= 351.37' (inc. shoe jt.) and 109 jts Slotted= 4645.65' ,Slots are up wt 2aoK w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers Rot wt 155K staggered 18 deg., 3 ft. non-slotted ends Dn Wt 80K Used Run-N-Seal thread compound on all connections. Block wt 7oK Drifted casing to 3.875" w/ teflon rabbit. Torque K fi~ ' Hook Hanger Detail Well: 1 C-172AL1 ConocoP hil li ps 1C-172A A3 Lateral 4-1/2" Plop ~ Drop Date: 4/22/2008 Alaska, Inc. Rig: Doyon 15 Drilling Supervisors: Fred Herbert (Granville Rizek Depth Jt Number Nu~msot Well Equipment Description and Can+ ents Length Tops 4" Drill pipe to surface (does not stay in hole) 7810.68 Crossover 4" XT-39 Box x 3-112" IF Pin (does not stay in hole} 1.51 7810.68 Baker running tool (does not stay in hole) 6.08 7812.19 Baker Model 'B-1' Hook Hanger 7-5/8" x 4-1 /2" (Inside csg) 16.70 7818.27 Baker Model 'B-1' Hook Hanger 7-5/8" x 4-1 /2" (Outside csg} 6.20 7a3a.97 4-1/2", 12.6 ppf, L-80, BTC PUP Jt. 3.70 7841.17 4-1/2", 12.6 ppf, L-80, BTC PUP Jt. 9.85 7844.87 Jts 2 to 3 2 Jts 4-1/2", 11.6 #, L-80, BTC Blank casing 79.88 785x.72 4-1/2", 12.6 ppf, L-80, BTC PUP Jt. 5.83 7934.60 Payzone ECP -Shear Valve 2600 psi, Control Valve 575 psi 22.95 7940.43 4-1l2", 12.6 ppf, L-80, BTC PUP Jt.(PxP) 3.07 7963.38 Jts 1 to 1 1 Jts 4-1/2", 11.6 #, L-80, BTC Blank casing 43.08 7966.45 4-1/2", 11.6 #, L-80, BTC Blank casing BTC box x STL pin 42.40 8009.53 4 1/2" ,11.6#, L-80 STL BENT joint Blank Casing 30.19 8051.93 w/ full mule shoe +++++ Bottom of mule shoe =_> 8os2.12 8082.12 8082.12 8082.12 8082.12 TD 6 314" hole @ 13102.42' MD / 3850.55' TVD sos2.12 8082.12 "A3" Window top at 7820' MD / Btm of window @ 7833' MD 8082.12 Top of'A3' Lateral Liner (In open Hole) @ 8030' MD sos2.12 A3' Lat. XO Bushing 3.92" ID @ 8091.7' MD 8082.12 Mule shoe is spaced out 31.88' inside Receptacle joint. sos2.12 8082.12 Found bttm of "A3" Window @ 7834.97' When Hooked w/ 30K. sos2.12 8082.12 8082.12 8082.12 8082.12 8082.12 8082.12 8082.12 Set 40K Down on Hook Flange when Hooked. 8082.12 Remarks: Torque 4-1/2" STL = 1800 ft/lbs, 4-1/2" BTC = 2800 ft lbs. up wt 195K Rot Wt ???K Dn Wt 138K Used Run-N-Seal thread compound on all connections. Block wt 7oK Drifted casing to 3.875" w/ teflon rabbit. Torque ???K 16" Conductor, K-55, set at 107' XXX" x 4112" Wellhead, 5,000 psi Tubing, 4712", 72.8#, IBTM, Special DeR above J.8I5 BD nipple 511' MD-J.8T5" DB Nlpple, 570 NO 1J tleg) ~ 3794' MD-GLM, Camco KBMG, 4712" %i", 239J (88 tleg) Whipstock Casing Etlt TOW 7,573'+I-, 2,7A0' ND 9-516" 40p, BTC 1c-nz Tuhing Siring / 4712" 12.5#, L-80, IBTM 1.958" ID, 3.833" OdR 7238' MD- 5-112" X 7-518" ZXP Liner / Top Packer wl Holtl Downs 7285' MD - BOHOm d Seal Assembly 4.75" Seal OD 6692' MD-GLM, Camco KBMG, 47/2" X 1", 3819 ND (6] tlegl 6783' MD-CMD Slitling Sleeve, wl J.81" DB Prollle, 3836 ND (68 tlegl ConocoPhillips West Sak 7-5/8" Producer 1 C-172a ST Tri-Lateral Completion 7255' MD-Casing Sealbore Receplecle, l0' Length 7Ji1' MD-3.]5" D% Nlpple, 7875 ND 184 tlegl 7347' MD-Lateral Entry MotlulelLEMI / n5T•MD-a4sanawmaow,3943•rvD(aaeegl 'A4' Sand Lateral 7673' MD- Pa32one ECP 4712" 77.5# LSO Slcltetl antl Blank Liner ., __\ / 3-112" Guide Shce \ ~T559'MO-5-712"Tieback Sleeve 770/7'MD-4712"Doer Shoe, 11.8#, LAO BTC, 3850' ND 7608' MD- bottom d 4112" bent muleshce 7355' MD-4112" X 7-518" seal Bores Motlel'B' HOOK Hanaer lse" to Casing Sealbore Receptacle I 4.75"ID Orienting Profile Automatic Alignment of LEM Poshive Latching Collet Indicates Correct Location 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 Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID T458' MD- &112" X T-518" Z%P Liner Top Packer wl Hold Downs MD - Bdtom of Seal Assembly a7s^ seal oD 7870' MD -Lateral Entry MotlulelLEM) As Completed ~/s 9~ NYGNES Baker Oil Tools Lateral Entrv Module (LEM1 With Diverters and Isolation Lateral Access Diverter Lateral isolation Diverter GS Running Tool String Installed Installetl (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector `Running/Retrieving \ (1.00' LengM) Snap In/Snap Out rBack Pressure Valve ~ Positive Lowting~ (1.80' LengM) Collet Lateral Isolation ~ r Flow-Thru Swivel Seals (1.25' Length) / Lateral Diverter /Hytlraulic Ramp Disconnect Isolation/ Mainbore (1.50' Length) Diverter Sleeve ~~ GS Spear ~~ (1.50' Length) Lateral Iwlalion 6 .85 ft Approx. Seals OALa 'Jars may be required in highly deviated lica8ons (6' a rox len th) or dee a th 18 5' Di t L ' pp g . p pp . ver er eng 18.5 Sleeve Length 7675'MD-Casing Sealbore Receptacle 7920'MD-AlSanO Wlntlow, 3918'ND184degl 'A3' Sand Lateral ` 20' Length / 1 C^ \ ~ \ ~~, 1 7940' MD-Payzone ECP 4712" 11.ON L-SO Sldted and Blank Dner ` ` ddd 4112" Gultle Shce 1.fwel ., Motlel'e' HOOK Hanaer 7818'MD-4112"X7518seel ecrea 1 a 8070'MD-5,~ tr a 13092'MD-4112"Liner Shce, 112" Tieback Sleeve 11.0#, L80 BTC, J850' TVD aas•lo 8082' MD - Bdtom 0141/2" bent muleshce a-11S' 120a Tueing 788]' MD - J.552" DBA Mpple, 3.033" aura 3898 ND 183 tlegl 3.950"10 5-112" X ]-518" ZXP 798q' MO -Bottom of 9ea1 Assembly Winer TOp Packer / 4,75"Seal OD Rh Holtl Downs / 'A2' Sand Lateral 5-112" %7318" Flex Lock 4112" 11.6# L-80 Slottetl and 7928' MD-Dner Hanged Packer ASSemdy Dner Hanger Blank Liner 7967• MD-casing Sealbore Reteptaele, 20' LengM 8301' MD - 7-518" 29.7# Casing, L-80, Hytlel 51 ], 3939' TVD 190 aegl ©Baker Hughes 2005. This document may nd be reproducetl or tlisidbuted, in whde or in part, in any form or by any means electronic or mechanical, Including pholceopying, recortling, or by any Information storage and retdeval system naw Known or hereaRer inventee, without wnttm pendsslon from Baker Hughes Inc. Equipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with tllverter: 4.63" Lateral Drift, no diverter or LEM: 3.68" Lateral Drift, wl diverter, no LEM: 3.68" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.69" Diverter and Sleeve Length: +1-18.5' 4112" EccenMC Guide Shce 73072' MD-4112" Casing Shce, 77.87!, LAO BTC, 3975' TVD Assembly .~ 5-112" X 7-516" ZXP Liner Top Packer with Hold Downs ~a.,~~vtu STATE OF ALASKA ~ A~JG 2 ~ 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOR"fi`~'il~'.~~: Cofnfnission 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~( ~S• ~ =,bb $ or Aband.: 12. Permit to Drill Number: 208-010 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: t,a April 26, 2008 13. API Number: 50-029-23159-61 4a. Location of Well (Governmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11N, R10E, UM 7. Date TD Reached: May 6, 2008 14. Well Name and Number: 1C-172A-L2 • Top of Productive Horizon: 355' FSL, 2260' FEL, Sec. 2, T11 N, 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: 80' FNL, 2423' FEL, Sec. 14, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 13011' / 3784' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562102 y- 5968801 Zone- 4 10. Total Depth (MD + ND): 13018' MD / 3785' TVD 16. Property Designation: ALK 25649, 25650• TPI: x- 558730 y- 5970565 Zone- 4 Total Depth: x- 558618 ~ - 5964850 Zone- 4 11. SSSV Depth (MD + ND): landing nipple @ 511' MD / 511' ND 17. Land Use Permit: 467, 468 18. Directional Survey: Yes ^/ 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): ~~S' ~~ GR/RES .,35 y~p ~ "71~A ~"" 'Q • ~ ~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE NTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME PULLED 16" 62.5# H-40 40' 107' 40' 107' 42" 638 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 4.5" 11.6# L-80 7354' 13011' 3840' 3784' 6.75" slotted liner 23. Open to production or injection? Yes Q 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 7558'-7622' MD 3847'-3846' ND 7751'-7879' MD 3853'-3850' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8352'-8521' MD 3840'-3832' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10756'-10917' MD 3803'-3801' ND na blank intervals from 12946'-13011' MD 3783'-3785' ND 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 15% GAS-OIL RATIO 1233 Flow Tubing not available Casing Pressure not available Calculated 24-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. IGOMPLETION NONE ~ f Z• i~ERif ED Form 10-407 Revised 2/2007 € ~ CONTINUED ON REVERSE SIDE r~~V~ "Z6 "~ 7 • ~, qS. J ~~,..~ e ~ ~ ~ ~~ S~~, i~ 4 2008 !~~ ~t'~~`'~' G 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ 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 Pemlafrost -Bottom 3490' 2439' needed, and submit detailed test information per 20 AAC 25.071. West Sak A2 13018' 3785' West Sak A3 13018' 3785' West Sak A4 7272' 3832' 1C-172AL2P61 TD 10205' 3813' 1 C-172AL2PB2 TD 12424' 3785' N/A Formation at total depth: West Sak A-4 30. LIST OFATTACHMENTS /~ r .~` Summary of Daily Operations, Directional Survey _ ~ ~ 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Steve Title: GKA Drilling Superintendent 7 ~ ~/ , ' Signature ! ~ Phone Date G 7 ~,,..,----"'""-- -` Sharon Allsup-D2ke -~''~~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a 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 V I~ Time Los - Date From To Dur S. De th E. De th Phase Code 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 displaosrr~ent on the tri tank. !2412008 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 (1G172A LZ) (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 sk~nr pump rates, milling window from top of window @ 735T to starter mill depth of 737T at midnight. Note: T of window 7357.2T, bottom of windrn~v 7371'. 00:00 03:00 3.00 7,365 0 OMPZ RPCOM TRIP P POOH w/ LEM running tools f! 7365' - 0' MD; Monitor Hole on Trip Tank; Hole Took Pr r Fill 03:00 03:45 0.75 0 0 COMPZ RPCOM PULD P UD LEM Running Tools & MWD 03:45 Q4:00 0.25 0 0 OMPZ RPCOM OTHR P Chan ~ Clear Rig Floor of LEM Tools 04:00 04:30 0.50 0 0 PROD3 STK OTHR P P 1 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 8 MWD. Orient whi todc to MWD. i 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 PIU 1 Stand 8~ Shallow Test MWD 250 GPM w/ 730 i; Good 08:15 11:00 2.75 302 6,694 PROD3 STK IP P RtH wl Whipstock BHA f< 302' -6694' MD. Fill pipe every 25 stands { 2463' 8 4825' . 11:00 11:45 0.75 6,694 6,742 PROD3 STK OTHR P MAD Pass f! 6694' - 6742' MD of i 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 RIP 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 725k 13:30 13:45 0.25 7,457 7,357 PROD3 STK OTHR P Set Whipstock: Set Anchor by Setting 15K Down Weigh on BHA; Verifies Anchor Set by P/U 10K Overpull; Attempt to Shear Milling Assy Bolt by setting 40K Down - Boft Sheared; Then Find Free Point (13$k), apply 10K ft Ibs of right hand torque - Mils Free; TOW at 7357.2T 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 _ __ ST _ P Milling 63/4" Window for A4 Lateral ~-- ~ ~, ~ ~ ~ f/ 735T - 7365'. Pumping 300 gpm w/ 2280 psi. Rotate 110 rpm w15-8k ft Ibs of to ue. Page 37 of 64 • Time Lomas _ _ _ __ ___ Date From To Dur S De th E De th Phase Code Subcode T Comment 18:00 19:15 1.25 7,365 7,371 PROD3 STK WPST P Continue to mill 6 3/4" Window for A4 Lateral f/ 7365' - 7371'. Pumping 300 gpm w/ 2280 psi. Rotate 110 rpm w/ 5-9k ft Ibs of torque, 10-12k weight on mills. PU wt 165k, SO wt 125k, Rotating weight 138k. Note: Pumped a 40 bbl high vis sweep (250 vis), while milling window @ 7370'. Observed a 20% increase in cuttin s. 19:15 00:00 4.75 7,371 7,377 PROD3 STK WPST P Continue to mill 6 3/4" Window for A4 Lateral f/ 7371' - 7377'. Pumping 305 gpm w/ 2475 psi. Rotate 125 rpm w/ 5-9k ft Ibs of torque, 10-12k weight on mills. PU wt 165k, SO wt 125k, Rotating weight 138k. Note: Rate of milling from 7374' to 7377' was one ft/hr average. Note: TOW 7357.27', BOW 7371'. 4/25/2008 Continue milling window for the A4 lateral from 7377' to 7378' (last foot took 115 minutes), monitor well, pull out of hole to change up milling assembly, lay down starter mill and flex joint, laydown Sperry Sun MWD, makeup BHA with a 6-1/8" bit, lower mill (6-5/16" OD) and upper mill (6-3/4"), Run in the hole to 7302'. Pre job safety meeting, slip and cut 170' of drilling line, pre job safety meeting, change out swivel packing (preventative), wash and ream 7302' to 7378', finish milling window, then full guage hole to 7382' and 6-1 /8" hole to 7391'. Note: Top of window @ 7357.27', bottom of window 7371', full guage hole to 7382' (11'), 6-1/8" hole to 7391' (9'). Pump a 25 bbls (300 vis) sweep while cleaning up window, monitor well, pull out of the hole with milling assembly, lay down milling assembly --upper mill full guage 6-3/4", clear floor, Flush Choke & Kill manifolds, & Stack of Milling Debris, Service Rig, Rig up to Test BOPE, Fill Stack and Attempt to Test Blind Rams and Choke Pur in Air f/ S stem 00:00 01:30 1.50 7,377 7,378 PROD3 STK WPST P Cont. Milling & Dress Window F/7377' MD T/7378' MD. Average ROP=0.8ft./hr. Unsucessfully Varied arameters tot to Im rove ROP. 01:30 01:45 0.25 7,378 7,378 PROD3 STK OWFF P Monitor well. Static. Prepare to POOH to chan a mill. 01:45 05:00 3.25 7,378 107 PROD3 STK TRIP T POOH for low ROP (suspect concretion} F/7378' MDT/107MD, monitor well on trip tank, hole taking ro er fill 05:00 06:00 1.00 107 0 PROD3 STK PULD T UD milling BHA &MWD. Starter mill nose worn, and slight ringing towards outside ed a of face. 06:00 07:00 1.00 0 145 PROD3 STK PULD T P/U & M/U 6 1/8"Mill tooth bit and configure second milling BHA. Removed the 6.5' flex joint between the second mill and u er mill. 07:00 10:30 3.50 145 7,302 PROD3 STK TRIP T RIH Fl145' MD T/7302' MD 10:30 10:45 0.25 7,302 7,302 PROD3 RIGMNT SFTY P PJSM, Cut & slip drill line 10:45 12:00 1.25 7,302 7,302 PROD3 RIGMNT SVRG P Cut & Slip 170' of 1-3/8" Drill Line 12:00 12:15 0.25 7,302 7,302 PROD3 RIGMNT SFTY P PJSM for Changing Out Swivel Packin ~c'iS,~2 ~$ of ~~ ~ ~ Time Logs Date From To Der S. Ce th E. Depth Phase Code Subcode T Comment 12:15 13:30 1.25 7,302 7,302 PROD3 RIGMNT SVRG P Change Out Swivel Packing. Spill revention measure. 13:30 13:45 0.25 7,302 7,378 PROD3 STK OTHR T Wash & Ream f/ 7302' - 7378' MD; 300 GPM @ 1780 psi; RPM 60, Torque 4 - 6K, P/U 165k, S/O 130k, Rot 138k 13:45 15:00 1.25 7,383 7,391 PROD3 STK MILL P Mill Window f/ 7378' - 7391' MD; 11' Gauge Hole; 300 GPM @ 1750 psi; RPM 110, Tor ue 5 - 8K 15:00 16:00 1.00 7,391 7,391 PROD3 STK OTHR P Pump 25 bbl - 9.3 PPG, 300 vs Sweep; Rotate & Reciprocate Mills Thorugh Window; 300 GPM @ 1750 psi; RPM 110, Torque 5 - 8K. Observed 20% increase in cuttings. No overpull while working to cleanup window 7357' to 7371' . 16:00 16:15 0.25 7,391 7,391 PROD3 STK TRIP P OWFF -Static. Install air slips and stri in rubbers. 16:15 19:15 3.00 7,391 145 PROD3 STK TRIP P POOH on Elevators f/ 7391 - 145 19:15 20:00 0.75 145 0 PROD3 STK PULD P UD Milling BHA, Upper Mill Full Gau e 6 3/4" , 6 1/8" Bit No Wear 20:00 20:15 0.25 0 0 PROD3 STK OTHR P Clean & Clear Rig Floor of BOT Millin Parts 20:15 21:00 0.75 0 0 PROD3 WELCTL OTHR P M/U Stack Washing Tool & Flush Kill & Choke Manifolds and Stack of Millin Debris; 420 GPM 200 si 21:00 21:30 0.50 0 0 PROD3 RIGMNT SVRG P Rig Service 21:30 22:00 0.50 0 0 PROD3 RIGMNT OTHR P Blow Down Top Drive & Choke /Kill Lines 22:00 22:15 0.25 0 0 PROD3 WELCTL OTHR P R/U to Test BOPE; Pull Wear Bushin ,Set Vetco Test Plu 22:15 00:00 1.75 0 0 PROD3 WELCTL BOPE P Fill Stack & Attempt to Test Blinds, & Choke Pur a Air f/ Lines /26/2008 Two week BOPE test: Witness of test waived by AOGCC inspector Chuck Scheve. Tested top pipe rams (3-1/2" x 6")and annular with 4", 4-1/2" and 5" test joints. Tested annular-and upper pipe rams to 250 psi low and 3000 psi high. Tested all valves in the choke manifold, kill line valves, choke line valves, floor safety valve and IBOP, top drive upper IBOP and lower manuel BOP valve. All tests were 250 psi low and 3000 psi high and held for 5 minutes each. Tests were charted. Accumulator tested. Gas alarms tested. Blow down choke manifold, rig down testing equipment, work on top drive shot pin and swivel packing, pickup/make up bha to drill the A4 lateral, troubleshoot and fix MWD problems, finish MU BHA, shallow test, run in the hole to 7319', PWD baseline, run in to 7391', drill to 7440', PWD baseline, directional drill A4 lateral to 7630'. E~acge 39 cif s~ ~ ~ Time Logs J___ _ Date From 7o Dur S De th E. De th __ Phase Code Su¢code T Comment -- 00:00 06:00 6.00 0 0 PROD3 WELCTL BOPE P Two week BOPE test: Witness of test waived by AOGCC inspector Chuck Scheve. Tested top pipe rams (3-1/2" x 6")and annular with 4", 4-1/2" and 5" test joints. Tested annular and upper pipe rams to 250 psi low and 3000 psi high. Tested all valves in the choke manifold, kill line valves, choke line valves, floor safety valve and IBOP, top drive upper IBOP and lower manuel BOP valve. All tests were 250 psi low and 3000 psi high and held for 5 minutes each. Tests were charted. All tests passed. Accumulator tested. Gas alarms tested. 06:00 07:00 1.00 0 0 PROD3 WELCTL OTHR P Blow down the choke and poor boy degasser, kill line and choke line. Drain stack and rig down testing e ui ment. 07:00 07:15 0.25 0 0 PROD3 RIGMNT SF1Y P Pre job safety meeting on changing out the swivel packing-again- slight low pressure leak. Also on replacing shot in assembl on the to drive . 07:15 08:30 1.25 0 0 PROD3 RIGMNT SVRG NP Service Top Drive; Repair Shot Pin Assy; Change Swivel packing again- sli ht leak low ressure. 08:30 09:00 0.50 0 0 PROD3 DRILL PULD P Pickup subs and handling e ui ment for BHA. Blind rams shut 09:00 09:15 0.25 0 0 PROD3 DRILL SFTY P PJSM P/U A4 Lateral BHA (6-3/4" bit and Geo ilot 09:15 11:00 1.75 0 88 PROD3 DRILL PULD P P/U 6 3/4" Directional BHA for A4 Lateral & RIH f/ 0' - 87.61' MD 11:00 11:30 0.50 88 45 PROD3 DRILL DHEQ P POOH t/ MWD & Upload MWD Software; No Communication; Clean & Redress Connection b/w Smart Stab & Gamma (Possible Side Step) -- Unsuccessful 11:30 12:30 1.00 45 45 PROD3 DRILL DHEQ T Replace Defective Gamma / Resistivity Sensor (Shorted Connector 12:30 13:15 0.75 45 45 PROD3 DRILL DHEQ T Upload Software-- Unuccessful 13:15 14:45 1.50 45 45 PROD3 DRILL DHEQ T Replace Dead Gamma / Resistivity SensorBatte 14:45 15:30 0.75 45 45 PROD3 DRILL DHEQ T Upload MWD Software -- Successful 15:30 16:00 0.50 45 371 PROD3 DRILL PULD P P/U & RIH w/ Remainder of A4 Lateral BHA f/ 45' - 371.3' MD 16:00 16:30 0.50 371 371 PROD3 DRILL DHEQ P Shallow Pulse Test MWD / Directional Suite; pumping 300 GPM w/1530 si 16:30 18:00 1.50 371 6,029 PROD3 DRILL TRIP P RIH f/ 371.3' - 6028.87' MD; Record Up and Down Weights Every 10 Stands; Fill Pipe Every 25 Stands. Monitor displacment on the trip tank. Pressure tested the swivel packing to 3000 psi- good. PU wt 150k, SO wt 110k 6028'. ~® ®® Page ~~ rsf 6tS Time Logs ~ Date From To Dur S. De th E. De th Phase Code Subcode T_ Comment 18:00 18:45 0.75 6,029 7,319 PROD3 DRILL TRIP P Continue trip in the hole. PU wt 162k, SO wt 162k, Rot wt 128k, Tor ue off bottom 6k ft Ibs 40 r m. 18:45 19:15 0.50 7,319 7,319 PROD3 DRILL CIRC P Circulate and establish PWD baseline ECD's above the window. Pumping 320 gpm w/ 3100 psi and ECD's of 11.1 ppg with 9.3 ppg mud weight, 20/16 PV/YP. RPM 120 w/ 6-7k ft Ibs of for ue. 19:15 19:30 0.25 7,319 7,391 PROD3 DRILL TRIP P Trip in the hole 19:30 20:00 0.50 7,391 7,440 PROD3 DRILL DDRL P Directional drill the A 4 lateral. 20:00 20:15 0.25 7,440 7,440 PROD3 DRILL CIRC P Circulate and establish PWD baseline ECD's after drilling 49' of new hole. Pumping 320 gpm w/ 3110 psi and ECD's of 11.23 ppg with 9.3 ppg mud weight, 20/16 PV/YP. RPM 120 w/ 6-7k ft Ibs of for ue. 20:15 00:00 3.75 7,440 7,630 PROD3 DRILL DDRL P Directional drill the A 4 lateral. 4/27/2008 Continue to directional drill A4 lateral from 7630' to 10126' @ midnight. Note: Pulled back too enhole sidetrack 9890' on 4-28-08. 00:00 06:00 6.00 7,630 8,230 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Max as 650 units. 06:00 12:00 6.00 8,230 8,952 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Max as 983 units. 12:00 18:00 6.00 8,952 9,515 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Max as 1165 units. 18:00 21:30 3.50 9,515 9,890 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Max as 1100 units. 21:30 00:00 2.50 9,890 10,126 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Note: This hole section was given up for a open hole sidetrack 0300 hrs, 4-28-2008 4/28/2008 Continue to directional drill A4 lateral from 10126' to 10170', circulate botom's up reducing ECD's, continue to drill to 10205', pull up 30' and circulate. Note: Pulled back to openhole sidetrack @ 9890' (315' of open hole). Pull out of the hole to 9874', pickup a single, trough 9874' to 9890' for sidetrack, sidetrack well @ 9890', continue to directional drill the A4 lateral from 9890' to 10452', backream to 10264 and circulate for ECD's (lowered .3 ppg), monitor well, repair Actuator on the top drive for the IBOP valve, ream in the hole to 10452', continue to drill the A4 lateral to 11485'. 00:00 00:30 0.50 10,126 10,170 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Note: This hole section was given up for a open hole sidetrack 0300 hrs, 4-28-2008 00:30 01:30 1.00 10,170 10,170 PROD3 DRILL CIRC P Circulate bottom's up. Initial ECD's were 12.17 ppg, final ECD's 11.83 01:30 01:45 0.25 10,170 10,205 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Note: This hole section was given up for a open hole sidetrack 0300 hrs, 4-28-2008. Note: 69' out of the polygon to the left (119') off the line). 65' away from well 172. Page ~€1 of 6€~ Time LOgs _ _ ___ Date From To Dur S De th E. De th Phase Code Subcode T Comment 01:45 02:15 0.50 10,205 10,175 PROD3 DRILL CIRC P Pull up 30' and circulate. Pumping 270 gpm w/ 2700 psi. Rotate 120 r m w/ 7-8k ft Ibs of for ue. 02:15 03:00 0.75 10,175 9,874 PROD3 DRILL TRIP T Pull out of the hole for open hole sidetrack. Install a single on top of stand # 101. PU wt 185k, SO wt 88k, Rot wt 125k. 03:00 03:45 0.75 9,874 9,890 PROD3 DRILL KOST T Trough for sidetrack. Sidetrack 9890'. Pumping 270 gpm w! 2700 psi. Rotating 120 rpm w/ 8 k f tl bs of torque. PU wt 185k, SO wt 88k, Rot wt 125k. Lay down the single which was picked up. Note: Sidetrack due to being out of polygon by 69' to the left of plan (119') off the line. 65' away from well 172. Could not break a left hand walk trend of the geopilot while drilling, azimuth change of 15 deg from 9920' to 10205' (285') from 180 deg azimuth to 165 deg azimuth. Stayed in the WestSak A4 sand. 03:45 06:15 2.50 9,890 10,205 PROD3 DRILL DDRL T Directional drill the A 4 lateral. Max as observed 825 units. 06:15 09:15 3.00 10,205 10,452 PROD3 DRILL DDRL P Directional drill the A 4 lateral. Max as observed 1218 units. 09:15 10:15 1.00 10,452 10,264 PROD3 DRILL REAM P Backream out of the hole from 10452' to 10361' to clean hole. Pumping 300 gpm w/ 3200 psi. Rotate 120 rpm w/ 8k ft Ibs of torque. PU wt 185k, SO 90k, Rot wt 130k. Pumped a total of 351 bbls- BU. Note: ECD's prior to backreaming 12.1 ppg, ECD's after circulating 11.8 PPG. 10:15 10:30 0.25 10,264 10,361 PROD3 DRILL OWFF P Monitor well- Static. 10:30 11:00 0.50 10,361 10,361 PROD3 RIGMNT RGRP T Change out the actuator on the upper IBOP on the top drive. Monitor well on the tri tank. 11:00 11:15 0.25 10,361 10,452 PROD3 DRILL REAM T Rotate and wash in the hole to continue drilling. Pumping 125 gpm w/ 990 psi. Rotate 50 rpm w/ 5 k ft Ibs of for ue. 11:15 12:00 0.75 10,452 10,545 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 127 units. 12:00 18:00 6.00 10,545 11,015 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 129 units. 18:00 00:00 6.00 11,015 11,485 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 753 units. Page ~4~ of 6fl ~ ~ Time Logs _ Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 4/29/2008 24 hr Summary Continue to directional drill A4 lateral from 11485' to 11766', back ream to clean hole and condition mud f/ 11766' to 11486' (reduce ECD's), trip in the hole to 11766', continue to directional drill from 11766' to 12320', mode switch MWD-trouble acquiring surveys, continue to directional drill from 12320' to 12424', lost 1200 psi pump pressure and 10k wt, pull out of the hole to 11955', monitor well- static, continue to pull out of the hole to 185', stand back a stand of 4" HWDP, then pull two 4" HWDp and the daily jars/bumper sub. The bottom 6" to a foot of the jars-- left in the hole. Top of the fish 12233' (191' of BHA in the hole). Proper hole displacement. Measure remains of the jars- take photo's (posted on the "X"drive in 1 C-172A well folder). Clean and clear ri floor, service ri ,than a the XT-39 saver sub on the to drive. 00:00 02:30 2.50 11,485 11,766 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 753 units. 02:30 04:15 1.75 11,766 11,486 PROD3 DRILL REAM P Backream out of the hole. Pumping 300 gpm w/ 3300 psi. Rotate 120 rpm w/ 8k ft Ibs of torque. Pulling speed 3'/min. Circulated 2 bottom's up to condition mud, reduce PV/YP and reduce MW to 9.2 ppg for ECD's. While pumping 300 gpm: Initial ECD's were 12.37 ppg, final ECD's 11.88 ppg. Initial PV 20/20, Final PV/YP 17/18 04:15 04:30 0.25 11,486 11,766 PROD3 DRILL TRIP P Trip in the hole on elevators. 04:30 06:00 1.50 11,766 11,907 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 653 units. 06:00 08:30 2.50 11,907 12,100 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 120 units. 08:30 11:30 3.00 11,907 12,320 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 120 units. 11:30 12:00 0.50 12,320 12,320 PROD3 DRILL OTHR T Mode switch to get a MWD survey. Having a little trouble getting surveys. Trouble shootin MWD detection. 12:00 13:45 1.75 12,320 12,424 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max as observed 97 units. 13:45 14:00 0.25 12,424 12,424 PROD3 DRILL OTHR T Lost 1200 psi pump pressure. Trouble shoot cause. Both pumps check out -OK. Pressure test surface lines--OK. Check PU and SO wt's. Lost 10k PU wt, gained 15k on slack off wt. 14:00 14:30 0.50 12,424 11,955 PROD3 DRILL TRIP T Pull out of the hole: PU wt 195k, SO wt 85k. Monitor displacement on the tri tank. Order fishin tools. 14:30 14:45 0.25 11,955 11,955 PROD3 DRILL OWFF T Monitor the well-- static. 14:45 18:00 3.25 11,955 6,970 PROD3 DRILL TRIP T Continue to pull out of the hole: Monitor displacement on the trip tank. Hole taking proper dis lacement. 18:00 20:30 2.50 6,970 185 PROD3 DRILL TRIP T Continue to pull out of the hole: Monitor displacement on the trip tank. Hole taking proper dis lacement. Paq~ ~3 ~t i~© Time Logs __ Date From To Dur S. Depth E De th Phase Subcode "Code T Comment 20:30 21:15 0.75 185 0 PROD3 __ DRILL TRIP T _ Stand back one stand of 4" HWD, pull two 4" HWDP with the jars (ser # 14001330) and bumper sub (ser # 15141045). Six inches to a foot of the bumper sub was left in the hole. Pictures posted to the "X"drive. Measurements taken- 4.8" OD. 21:15 21:45 0.50 0 0 PROD3 DRILL OTHR T Clean and clear the rig floor. 21:45 22:45 1.00 0 0 PROD3 RIGMNT SVRG T Service the rig. Grease crown, blocks and to drive. 22:45 00:00 1.25 0 0 PROD3 RIGMNT OTHR T Change out the 4" XT39 saver sub on the to drive. 4/30/2008 Continue to change the XT-39 saver sub on the top drive, bring fishing tools to the floor, MU BHA, run in the hole to 9653', wash down to top of fish @ 12233', atttempt to engage fish and confirm with pump pressure, slipped off twice, engage fish with no pump, pull out of the hole with apparent overpull on first 9 stands, pulled to surface with no fish, make up fishing BHA #2 to attempt to catch the crossover under the remains of the jars (4.96" OD), run in the hole with fishing BHA #2 to 7300' @ midnight. Fish: The bottom 6" to a foot of the 'ars-- left in the hole. To of the fish 12233' 191' of BHA in the hole . 00:00 00:45 0.75 0 0 PROD3 RIGMNT OTHR T Continue to change out the 4" XT39 saver sub on the to drive. 00:45 01:30 0.75 0 0 PROD3 FISH PULD T Bring Baker Oil Tools fishing tools to the rig floor. Install 4.75" grapple in overshot. 01:30 03:00 1.50 0 225 PROD3 FISH PULD T Make up fishing BHA to recover 191' of drillin BHA To of fish 12,233' . 03:00 06:00 3.00 225 8,526 PROD3 FISH TRIP T Trip in the hole with fishing BHA. Stand # 65 (just above the window: PU wt 155k, SO 110k 06:00 07:00 1.00 8,526 9,840 PROD3 FISH TRIP T Continue to trip in the hole with fishing BHA. Establish circulating rate of 3.5 bpm (150 gpm) w/ 675 si. 07:00 11:15 4.25 9,840 12,233 PROD3 FISH CIRC T Begin rotating and washing as needed to reach the top offish @ 12233'. While rotating 50 rpm w/ 8k to 10 k max ft Ibs of torque. Pumping @ 3.5 bpm (150 gpm) w/ a circulating pressure of 900 psi at the top of fish. Above fish: PU wt 205 to 210k, SO wt rotatin 136k. 11:15 12:15 1.00 12,233 12,424 PROD3 FISH FISH T Engage fish while pumping 3.5 bpm w/ 1000 psi. Rotate 30 rpm. Increase max torque to 15k on top drive control panel. Pumping 310 gpm- not catching fish. Increase pump rate to 310 gpm w/ 3100 psi, 305 gpm w! 2633 psi, 300 gpm w/ 2400 psi. Rotate onto fish with no pump. Picked up twice with overpull to 255k, pumping 300 gpm w/ 2400psi, slipped off twice. Engage fish with out um s. Page ~~ oaf 6g Time Logs _ Date From To Dur S. Depth E. De th Phase Code _ Subcode T Comment 12:15 19:15 7.00 12,424 0 PROD3 FISH TRIP T Pull out of the hole with the fish ?? (note that first 13 stands are hybrids ((2) 5" DC's and a joint of 4" HWDP). Maximum overpull on the first stand to 260k, 2nd stand 260k, 3rd stand 250k, 4th stand 240k, 5th stand 245k, 6th stand 240k, 7th stand 235k, 8th stand 220k, 9th stand PU wt 212k. Continue to pull out of the hole, lay down accelerators, stand back two stands of Hybrids in the BHA, pull overshot to the floor. No fish. 19:15 19:30 0.25 0 0 PROD3 FISH PULD T Break the guide on overshot- no grapple inside. Photo's on the "X" drive folder for 1 C-172A. 19:30 19:45 0.25 0 0 PROD3 FISH OTHR T Clear and clean floor. 19:45 20:15 0.50 0 0 PROD3 FISH PULD T Bring Baker fishing tools to the rig floor. 20:15 21:15 1.00 0 229 PROD3 FISH PULD T MU second attmept BHA (to try and catch the 4.96" OD crossover sub below the remains of the bumper jar). Install packoff and use a 5"grapple, install 4 foot extension (4-7/8" ID). Continue to make u BHA. 21:15 00:00 2.75 229 7,300 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. 75 stands of 4" in the hole, above window f/ the A4 lateral. 5/01 /2008 Pre job safety meeting, slip and cut drilling line, continue run in the hole with fishing BHA #2 from 7300' to 8138', work past 8138', continue to 9091', work st, start rotating in the hole to 9890', hung up, jarred free @ 9890', continue into 10250', circulate bottom's up, continue into 11663', started tossing some mud while pumping, pulled back to 11615', circulate bottom's up, continue in to 11810' with no progress @ 11810' work tight hole, circulate bottom's up, work in the hole to 11825'- tight hole @ 11810', jar free, start circulating to clean hole for trip out to make up a cleanout assembly. Note: A total of 168 bbls of mud lost to the hole toda . 00:00 00:15 0.25 7,300 7,300 PROD3 RIGMNT SFTY T Pre job safety meeting on slip and cut drillin line. 00:15 01:30 1.25 7,300 7,300 PROD3 RIGMNT SVRG T Slip and cut 1-3/8"drilling line. 01:30 02:15 0.75 7,300 8,138 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. PU wt at the window 160k, SO wt 105k. Circulate 20 spm (2 bpm) w! 360 psi. Lost all down wt @ 8138'. Pump 20 spm w! 400 psi. Pump 201 gpm w/ 890 psi. Rotate 30 rpm to get past 8138'. 02:15 03:00 0.75 8,138 9,091 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Lost all down wt @ 9091'. Fill pipe. Pump 20 spm w/ 440 psi. Pump 250 gpm w/ 1220 psi. Pump 255 gpm w/ 1380 psi. Rotate 30 rpm w/ 6k ft Ibs of torque to get past 9091'. Then trip in the hole on elevators. Page 46 of ~C7 i Time Lags _ Date From To Dur S Ge th E. De th Phase Code Subcode T Comment _ 03:00 03:30 0.50 9,091 9,188 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Start rotating in the hole from 9091'. Pumping 20 spm w/ 440 psi. Rotate 30 rpm w/ 6-8k ft Ibs of torque to get in the hole. Lost all down wt @ 9188'. 03:30 04:45 1.25 9,188 9,890 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Rotating in the hole from 9188'. Pumping 20 spm w/ 440 psi. Rotate 30 rpm w/ 8k ft Ibs of torque to get in the hole. Unable to go past 9890'. Torqued up to torque limit set @ 10k ft Ibs. 04:45 06:00 1.25 9,890 9,890 PROD3 FISH JAR T Let the torque out. Jarring with 270k on indicator and pulling to 335k. Jarred free. PU wt after free 175k, SO wt 85k, 120k rotating weight. Pumping 202 gpm w/ 1050 psi., 250 gpm w/ 1350 psi., 300 gpm w/ 1740 si. 06:00 07:30 1.50 9,890 10,250 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Continue rotating in the hole from 9890' to 10250'. Pumping 25 spm w/ 450 psi. Rotate 40 rpm w/ 8k ft Ibs of torque to get in the hole. Torqued up to for ue limit set 12k ft Ibs. 07:30 08:30 1.00 10,250 10,390 PROD3 FISH CIRC T Circulate bottom's up while reaming in from 10250' to 10390'. Pumping 310 gpm w/ 2230 psi. Rotating 50 r m w/ 8-9k ft Ibs of for ue. 08:30 11:45 3.25 10,390 11,663 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Continue rotating in the hole from 10390' to 11663. Pumping 66 spm(280 gpm) w/ 2500 psi. 35% normal returns, showing 30%. Rotate 40 rpm w/ 8k ft Ibs of torque to get in the hole. Torque limit set @ 15k ft lbs. Started tossing some mud. Slight pressure increase. Pulled back a stand to 11615'. 11:45 12:45 1.00 11,615 11,615 PROD3 FISH CIRC T Circulate bottom's up. Pumping 295 gpm w/ 2425 psi, 33% flow. Rotating 155 rpm w/ 8-9k ft Ibs of torque. PU wt 210k, SO wt 85k, Rot wt 130k. Final circulating pressure 2230 psi w/ 34% flow. Page ~6 ~a~ ~t~ ~ ~ Time Logs __ Date Frorn To Dur S_Depth E. De th Phase_ Code Subcode T Comm_ ent _,__ __ 12:45 15:15 2.50 11,615 11,810 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Continue rotating in the hole from 11615' to 11810'. Work tight hole with and without pumps.Pumping 69 spm(290 gpm) w/ 2500 psi. 35% normal returns, showing 30%. Rotate 45-55 rpm w/ 8k to 15k ft Ibs of torque to get in the hole. Torque limit set @ 15k ft Ibs. Lossing some mud at higher flow rates. Pu wt 215k, So wt 85k, rotating wt 140k. Little to no progress being made at 11810'/ Stand back a stand # 124 to 11800' 15:15 16:30 1.25 11,800 11,800 PROD3 FISH CIRC T Circulate bottom's up. Pumping 270 gpm w/ 2250 psi, 33% flow. Rotating 120 r m w/ 8k ft Ibs of for ue. 16:30 17:00 0.50 11,810 11,815 PROD3 FISH TRIP T Run in the hole with fishing BHA #2. Continue rotating in the hole from 11810' to 11825'. Work tight hole with and without pumps. Pumping 59 spm(250 gpm) w/ 1940 psi. 35% normal returns, showing 30%. Rotate 55 rpm w/ 8k to 15k ft Ibs of torque to get in the hole. Torque limit set @ 15k ft Ibs. Lossing some mud at higher flow rates. Pu wt 215k, So wt 85k, rotatin wt 140k. 17:00 17:30 0.50 11,815 .11,815 PROD3 FISH JAR T Tight hole @ 11815'. Jarring with 280k on indicator and pulling to 300k, 330k, then 350k. Jarred free. PU wt after free 215k. Stand back stand # 124 to 11800'. Pumping 250 m w/ 1940 si., 32% flow. 17:30 18:00 0.50 11,815 11,795 PROD3 FISH CIRC T Start circulating bottom's up x 5 or more to clean hole for trip out. Pumping 270 gpm w/ 1960 psi, 32% flow. Rotating 185 rpm w/ 8k ft Ibs of for ue. 18:00 23:15 5.25 11,795 10,970 PROD3 FISH CIRC T Rotating 180 rpm w/ 8k ft Ibs of torque while backreaming 2-3'/min while circulating hole clean. Stagged pump rate up from 270 gpm w/ 1860 psi 32% flow to 290 gpm w/ 2010 psi 33% flow, 300 gpm w/ 2020 psi 34% flow, 320 gpm w/ 2410 psi 35% flow, 350 gpm w/ 2660 psi 37% flow, 375 gpm w/ 3410 psi 39% flow, after two bottom's up--final of 400 gpm w/ 3050 psi 39% flow. Obtain PU and SO wt's every 5 stands. Note: Pumped 4-1/2 BU at 400 gpm. Pumped a total of 2570 bbls while circulating. Observed an increase in returns between the 3rd and 4th bottoms up. Shakers looked re ood when throu h circulatin . 23:15 23:30 0.25 10,970 10,970 PROD3 FISH OTHR T Monitor well for flow- static. ~a~~ ~7 of 50 ~ ~ Time Logs ~ _ __ _ ___ D_ a~e.____ From To Dur S De th E _De th Ph se Code Subcode T Comment ____ 23:30 00:00 0.50 10,970 10,594 PROD3 FISH TRIP T Pull out of the hole on elevators from 10970' to 10594'. Hole not taking correct fill. Note: 168 bbls of mud lost to the hole toda . 5/02/2008 Pump out of the hole from 10594' to 10407' (over pull @ 10465'), back ream out from 10407' to 8624', pull out on elevators to above the window @ 7357', circulate bottom's up/clean floor @ 7300', monitor well, pump dry job, pull out of the hole, lay down fishing BHA #2. Clear and clean floor, Pickup/make up cleanout assembly, upload MWD, shallow test MWD @ 355', run in the hole to 7350'--Continue to run in the hole with cleanout assembly--wash and ream as needed to 9971'. Continue to wash and ream from 9971' to the top of fish @ 12233', back ream to 12015' at midnight. Note: A total of 168 bbls of mud lost to the A4 lateral esterda , no losses toda . 00:00 00:45 0.75 10,594 10,407 PROD3 FISH TRIP T Pump out of the hole. Pumping 150 gpm w/ 620 psi 28% flow. Observed overpull @ 10465'. Monitor well on the active mud s stem. 00:45 04:15 3.50 10,407 8,624 PROD3 FISH TRIP T Backream out of the hole from 10407' to 8624'. Pulling speed 30- 40 ft/min. Pumping 300 gpm w/ 1800 psi. Rotate 120 rpm w/ 8 to 12k ft/Ibs of torque. Record PU and SO wt's every 5 stands. Monitor well on the active mud s stem. 04:15 05:30 1.25 8,624 7,303 PROD3 FISH TRIP T Pull out of the hole on elevators from 8624' to 7303'. Hole took proper dis lacement on the tri tank. 05:30 06:00 0.50 7,303 7,303 PROD3 FISH CIRC T Circulate bottom's up. Pumping 400 gpm w/ 2080 psi 38% flow. Rotate 50 rpm w/ 5-6k ft Ibs of torque. PU wt 160k, SO wt 112k. Same weight before pulling up past window and after in casin . 06:00 06:30 0.50 7,303 7,303 PROD3 FISH OTHR T Blow down the top drive, monitor well- static. 06:30 09:15 2.75 7,303 229 PROD3 FISH TRIP T Continue to pull out of the hole with the fishing BHA #2. Pull on elevators, monitor well on the tri tank. 09:15 10:15 1.00 229 0 PROD3 FISH PULD T Lay down fishing BHA. 10:15 10:45 0.50 0 0 PROD3 FISH OTHR T Clear and clean rig floor. 10:45 11:00 0.25 0 17 PROD3 DRILL PULD T Pickup and make up cleanout BHA. 11:00 11:30 0.50 17 74 PROD3 DRILL PULD T PU Sperry Sun MWD tools. 11:30 12:00 0.50 74 74 PROD3 DRILL OTHR T Upload MWD. 12:00 13:00 1.00 74 ~ 355 PROD3 DRILL PULD T Continue to pickup and make up cleanout BHA. BHA wt with top drive 90k. Blocks 70k. 13:00 13:15 0.25 355 355 PROD3 DRILL OTHR T Shallow pulse test MWD. Pumping 280 m w/ 870 si 37% flow. f~~s~a 48 of ~Q ~ ~ Time Logs ___ __ __ _ Date From To Dur S. De th E Depth Ph_a_se Code Subcode__ T Comment __ _ 13:15 15:45 2.50 355 7,350 PF2OD3 DRILL TRIP T Run in the hole on elevators to 7350'. Monitor the displacement on the trip tank. Record PU and SO wt's every 10 stands after stand # 50. Fill pipe every 25 stands. At depth of 7350': PU wt 150k, SO wt105k 15:45 18:00 2.25 7,350 9,971 PROD3 DRILL TRIP T Continue to trip in the hole from 7350' to 9971' (TOW 7357', BOW 7371'). Monitor the displacement on the trip tank. Record PU and SO wt's every 10 stands after stand # 50. Fill pipe every 25 stands. At depth of 9971': PU wt 170k, SO wt 93k, Rot wt 110k. 18:00 20:45 2.75 9,971 11,740 PROD3 DRILL REAM T Wash and ream in the hole from 9971' to 11740'. Pumping 120 gpm w/ 700 pi 27% flow. Rotate 40 rpm w/ 8k ft Ibs of for ue. 20:45 23:00 2.25 11,740 12,200 PROD3 DRILL REAM T Wash and ream in the hole from 11740' to 12233'. Pumping 250 gpm w/ 2180 pi 32% flow. Rotate 150 rpm w/ 8 to 9k ft Ibs of torque. Traveling 6 to 8'/minute. ECD's 11.35 ppg. At depth of 11740': PU wt 250k, Rotating wt 132k while traveling down. 23:00 23:30 0.50 12,200 12,233 PROD3 DRILL CIRC T Tried to circulate down to the top of fish pumping 35 spm (150 gpm) w/ 1010 psi 29% flow. No down weight. Then Rotated 40 rpm w/ 9-10k ft Ibs of torque. Traveling 6'/min rotating down with rotating down wt of 150k. Tagged up on top of fish on depth (12233'). Pumps on: PU wt 225k, SO wt 105k, Rotating 150k. After tagging fish: Pickup and backream pumping 300 gpm w/ 3090 psi 34% flow. Rotating 150 rpm w/ 8500 ft Ibs of torque. Pumps off: PU wt 210k, SO wt 112k, Rotatin wt 162k. 23:30 00:00 0.50 12,233 12,015 PROD3 DRILL REAM T Backream out of the hole from 12233' to 12015'. Pumping 320 gpm w/ 3450 psi 34% flow. Rotating 150 gpm w/ 8k ft Ibs of torque. Max ECD's 12.06 ppg. Pulling speed 25 to 30 feeUmin. Obtain PU and SO wt's every 10 stands. 5/03/2008 Continue to back ream from 12015' to 7333', circulate bottom's up, pump a 41 bbl sweep, continue to circulate two more bottom's up while reciprocate to cleanup casing, monitor well, pump a dry job, pull out of the hole on elevators to 355', work bottom hole assembly, lay down ghost reamer and hole opener with crossovers. Pickup/Make up/ Run in the hole with fishing BHA #3 to 10124'. Note: A total of 168 bbls of mud lost to the A4 lateral two da s a o, no losses esterda , no losses toda . Page ~ aaf firJ Time Lo s 9 ---- __ -- - - - Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:15 2.25 12,015 10,909 PROD3 DRILL REAM T Backream out of the hole from 12015' to 9250' .Pumping 320 gpm w/ 3450 to 2850 psi 34% flow. Rotating 150 gpm w/ 8 to 7k ft Ibs of torque. Max ECD's 12.06 ppg to 11.6 ppg. Pulling speed 25 to 30 feet/min. Obtain PU and SO wt's eve 10 stands. 02:15 05:00 2.75 10,909 9,690 PROD3 DRILL REAM T Backream out of the hole from 12015' to 9690' .Pumping 320 gpm w/ 2850 to 2450 psi 34% flow. Rotating 150 gpm w/ 8 to 7k ft Ibs of torque. ECD's 11.6 ppg to 11.1 ppg. Pulling speed 10 to 15 feeUmin. Pulled slower (9970' to 9873')- through sidetrack point (9890') Obtain PU and SO wt's eve 10 stands. 05:00 05:45 0.75 9,690 9,310 PROD3 DRILL REAM T Backream out of the hole from 9690' to 9310' .Pumping 320 gpm w/ 2450 psi 34% flow. Rotating 150 gpm w/ 8 to 7k ft Ibs of torque. ECD's 11.1 ppg to 11.00 ppg. Pulling speed 30 feet/min. Obtain PU and SO wt's eve 10 stands. 05:45 06:00 0.25 9,310 9,220 PROD3 DRILL REAM T Backream out of the hole from 9310' to 9220' .Pumping 320 gpm w/ 2450 psi 34% flow. Rotating 150 gpm w/ 8 to 7k ft Ibs of torque. ECD's 11.00 ppg to 10.92 ppg. Pulling speed 10 to 20 feet/min. Obtain PU and SO wt's eve 10 stands. 06:00 11:00 5.00 9,220 7,333 PROD3 DRILL REAM T Backream out of the hole from 9220' to 7333' .Pumping 320 gpm w/ 2450 to 2160 psi 34% flow. Rotating 150 gpm w/ 8 to 7k ft Ibs of torque. ECD's 10.92 ppg to 10.48 ppg. Pulling speed 10 to 20 feet/min. Obtain PU and SO wt's every 10 stands. 11:00 13:00 2.00 7,333 7,333 PROD3 DRILL CIRC T Circulate to cleanup the casing and hole: Pump a bottom's up, then a 41 bbl sweep (9 ppg/ 300+ vis) (showed 30% increase in cuttings on return), then pumped two more bottom's up. Pumping was at 310 gpm 2160 psi 34% flow. Initial ECD's were 10.48 ppg, Final ECD of 10.41 ppg. Rotating 150 rpm w/ 6k ft Ibs of for ue. 13:00 13:15 0.25 7,333 7,333 PROD3 DRILL OWFF T Monitor well- static. 13:15 13:30 0.25 7,333 7,333 PROD3 DRILL CIRC T Pump a 20 bbl dry job (11ppg), install stri in rubbers. 13:30 16:30 3.00 7,333 355 PROD3 DRILL TRIP T Pull out of the hole with cleanout BHA. Record PU and SO wt's every 10 stands to stand # 50. 16:30 17:00 0.50 355 74 PROD3 DRILL TRIP T Work the BHA 17:00 17:15 0.25 74 74 PROD3 DRILL OTHR T Download MWD. t'age 6t4 cif fi0 i Time Logs __ __ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:15 17:30 0.25 74 0 PROD3 DRILL PULD T Lay down the hole opener and ghost reamer and crossovers. 17:30 19:45 2.25 0 228 PROD3 FISH PULD T Pickup make up 3rd attmept fishing BHA. 19:45 00:00 4.25 228 10,124 PROD3 FISH FISH T Run in the hole f/ 228' to 10124' with Baker fishing BHA #3 to recover drilling assembly. Monitor returns on the trip tank. Proper displacement. Obtain PU and SO wt's every 10 stands. At the top of window: PU wt 152k, SO wt 110k. At 10124': PU wt 168k, SO wt 98k 5/04/2008 Continue to run in the hole with fishing BHA #3 from 10124' to 11430', wash in the hole to keep mud from overrunning the top of string to 12170', circulate and condition mud and hole prior to engagemnent of top of fish @ 12233'. Obtain slow pump rates. Run in the hole to 5' above the fish. Obtain parameters then slack off while pumping 20 spm w/ 460 psi/ rotating 35 rpm w/ 8500 ft Ibs of torque. Engage the fish and swallow 2', picked up and pulled off. Re-engage fish, spud down, pump 300 gpm w/ 3500 psi (MWD has pulses- verify over fish). Stop the pumps, pickup 30k over, then beat down some more. Pick fish off bottom by 10', start pumps and verify fish on. Continue to pump out 3 stands to 12172' bit depth. Pull out of the hole on elevators to 7300' bit depth, pump a dry job, pull out of the hole on elevators, lay down fishing tools, lay down the fish (191'). Pickup then makeup drilling BHA, shallow test @ 374', run in the hole to 9145' at midnight. Note: A total of 168 bbls of mud lost to the A4 lateral three da s a o while fishin , no losses since. 00:00 01:00 1.00 10,124 11,430 PROD3 FISH TRIP T Run in the hole f/ 10124' to 11430 with Baker fishing BHA #3 to recover drilling assembly. Monitor returns on the trip tank. Proper displacement. Obtain PU and SO wt's every 10 stands. At the top of window: PU wt 152k, SO wt 110k. At 11430': SO wt 98k 01:00 02:00 1.00 11,430 12,170 PROD3 FISH TRIP T Continue to run in the hole, pumping 30 spm w/ 690 psi. SO wt 95k while um in in the hole. 02:00 04:45 2.75 12,170 11,987 PROD3 FISH CIRC T Circulate and condition mud and hole. Rotate 120 rpm w/ 7-8k ft Ibs of torque. Circulate bottom's up, then pump a 35 bbl high vis sweep (300+ vis). Once the sweep was to surface, stood back a stand and reciprocated stand #126. then 2 more bottom's up. Pumped a total of 1476 bbls. Note: The entire first bottom's up (pumped at 375 gpm w/ 3350 psi 37% flow) showed to have a good bit of cutting in the hole, the sweep did not bring all that much back, then increased the flow rate to 400 gpm w/ 3600 psi 39% flow and saw an increase in cuttings again for one bottom's up. The hole was pretty clean after the next bottom's u . 04:45 05:00 0.25 11,987 11,987 PROD3 FISH CIRC T Obtain slow pump rates. PU wt 200k, SO wt 100k. Page 51 oaf ~i0 ~1 Time Logs __ _ Date From To Dur S. De th E_ De th Phase Code Subco_deT Comment 05:00 05:15 0.25 11,987 12,173 PROD3 FISH TRIP T Run in the hole, stand # 126 and #127. Pumping 30 spm w/ 660 psi. PU wt 203k, SO wt 105 to 110k. 05:15 05:30 0.25 12,173 12,233 PROD3 FISH FISH T Make up stand # 128, run in the hole to 5' above top of fish. Obtain parameters. PU 205k, SO wt 110k. Pumping 20 spm w/ 460 psi. Rotate 35 rpm w/ 8500 ft Ibs of torque. Rotatin wei ht 142k. 05:30 05:45 0.25 12,233 12,233 PROD3 FISH FISH T Engage fish: Rotate over and swallow 2' of the fish, picked up and pulled off with 10k overpull. Slackoff and retag and slide 2' down over fish. Spud down and engage fish. Bring pumps on line to 300 gpm w/ 3500 psi 35% flow. Obtained good MWD detection. Stop pumps. Pickup and pull 30k over. Then beat down some more. Pickup with out pumps for 10'. PU wt 280k. Stop pulling and fire up the pumps with 300 gpm w/ 3500 psi and ood MWD detection. 05:45 06:30 0.75 12,233 12,172 PROD3 FISH TRIP T Continue to pump and pull 3 stands with the pumps. Once the cleaned out hole was reached (12233'), lost 30-40k drag to 205k PU wt. Maximum overpull was 350k on the wei ht indicator. 06:30 10:45 4.25 12,172 7,300 PROD3 FISH TRIP T Pull out on elevators with fish (drilling assembly). Monitor displacement on the trip tank. Pump at intervals to verify fish with MWD detection. Pumping 260 gpm w/ 2800 psi 33% flow. Record PU and SO wt's every 10 stands. At 7300': PU wt 158k. Window is at 7357'. 10:45 11:15 0.50 7,300 7,300 PROD3 FISH CIRC T Monitor well- static. Pump a dry job (20 bbls, 2 ppg over MW- 11 ppg). Blow down the to d 11:15 12:00 0.75 7,300 5,260 PROD3 FISH TRIP T Continue to pull out on elevators with fish (drilling assembly). Monitor displacement on the trip tank. Record PU and SO wt's every 10 stands. 12:00 14:30 2.50 5,260 418 PROD3 FISH FISH T Continue to pull out on elevators with fish (drilling assembly). Monitor displacement on the trip tank. Hole took proper fill. Record PU and SO wt's every 10 stands. At 5260': PU wt 138k. 14:30 15:30 1.00 418 191 PROD3 FISH PULD T UD Fishing Tools (fishing BHA # 3 ) ,then lay down (Sperry Sun BHA #10) (Wellview BHA #15) from the Broken Bumper Sub (part of the overall jar measurement). Lay down fish: The crossover, then (3) flex collars. €'age 52 of fi0 • Time Lomas Date From To Dur S. De th E. De th Phase Code Subcod e T_ Comment 15:30 16:45 1.25 85 85 PROD3 FISH _ PULD T _ Download MWD /Clear and organize floor. Lay down fishing tools from rig floor. 16:45 17:45 1.00 85 0 PROD3 DRILL PULD T UD Drilling BHA (Sperry Sun BHA #10) (Wellview BHA #15) f/MWD to the Bit. All recovered. Grade bit. 17:45 18:45 1.00 0 90 PROD3 DRILL PULD T Load a new Sperry Sun Geopilot onto the pipe skate. Bring to the rig floor. Pickup and make the bit up. Continue to makeup drilling assembl . 18:45 19:30 0.75 90 90 PROD3 DRILL OTHR T Upload Sperry Sun MWD. 19:30 20:00 0.50 90 374 PROD3 DRILL PULD T Continue to make up bottom hole assembl . 20:00 20:30 0.50 374 374 PROD3 DRILL DHEO T Shallow test MWD. Pumping 270 gpm w/ 1200 psi 32% flow. Rotate 30 r m w/ 2k ft Ibs of for ue. 20:30 00:00 3.50 374 9,145 PROD3 DRILL TRIP T Trip in the hole with drilling assembly to 9145'. No problems at the window @ 7357'. Fill pipe every 25 stands. Monitor well on the tri tank. 5/05!2008 Continue the trip in the hole with 6-3/4" drilling assembly from 9145' to 10177', ream in the hole (no down wt) to 10455', backream to 10270' while circulating to clean the hole, trip in the hole on elevators to 11350', wash and ream in the hole (no down wt) from 11350' to 12282'. Start taking Cazandra survey's every 10' from 12282' to 12362', excessive dogleg indicated, pull out of the hole to 12055' for open hole sidetrack. Trough hole from 12055' to 12100'. Open hole sidetrack at 12100' and drill to 12146', ream sidetrack area, continue to drill the A4 lateral to 12664' at midni ht. 00:00 01:15 1.25 9,145 10,177 PROD3 DRILL TRIP T Trip in the hole with drilling assembly from 9145' to 10177'. No down weight. Fill pipe every 25 stands. Monitor well on the trip tank. Record PU and SO wt's eve 10 stands. 01:15 01:30 0.25 10,177 10,455 PROD3 DRILL REAM T Ream in the hole. Pumping 127 gpm w/ 1100 si 31 % flow. 01:30 02:45 1.25 10,455 10,270 PROD3 DRILL REAM T Backream out slow (2-3'/min) while cleaning the hole. Start off pumping 300 gpm w/ 3220 psi, then pumping 320 gpm w/ 3900 psi. Rotating 80 rpm w/ 7 - 8K ft Ibs of torque. Circulate almost 2 bottom's up to clean u the hole. 02:45 03:30 0.75 10,270 11,350 PROD3 DRILL TRIP T Continue to trip in the hole with drilling assembly from 10270' to 11350'. No down weight. Monitor well on the trip tank. Record PU and SO wt's eve 5 stands. 03:30 05:00 1.50 11,350 12,100 PROD3 DRILL REAM T Wash & Ream in Hole f/ 11350' - 12100' MD; 320 GPM @ 3830 psi; 50 RPM, Torque 7 - 8K; No Down Wei ht 05:00 05:30 0.50 12,100 12,282 PROD3 DRILL REAM T Wash & Ream in Hole f/ 12100' - 12282' MD; 320 GPM @ 3830 psi; 50 RPM, Torque 7 - 8K; No Down Wei ht Page 83 0~ 6f~ Time Logs ~ _ __ Date From 7o Dur 5 De th E. De th Phase Code Subcode T Comment 05:30 07:00 1.50 12,282 12,372 PROD3 DRILL SRVY T Take Cassandra Surveys per MWD Every 10' Starting @ 12282' - 12362' MD; Circ'ed at 300 GPm @ 3500 psi; 60 RPM, Torque 7 - 8K, P!U 205, S/O 0, Rot 125 07:00 07:30 0.50 12,372 12,055 PROD3 DRILL TRIP T POOH f/ 12372' - 12055' MD per DD for Side Track 07:30 07:45 0.25 12,055 12,100 PROD3 STK OTHR T Trough f/Side Track f/ 12055' - 12100' MD; 320 GPM @ 3620 psi; WOB 4K, Tor ue 8 - 9K, 120 RPM 07:45 08:15 0.50 12,100 12,146 PROD3 STK KOST T Drill Side Track f/ 12100' - 12146' MD; 300 GPM @ 3500 psi; WOB 2 -4 K; 120 RPM, Torque 8K, ECD = 11.53; P/U 205, S/O 0, Rot 124 08:15 10:30 2.25 12,146 12,146 PROD3 STK OTHR T Ream Side Track Area f/ 12100' - 12146' MD; 300 GPM @ 3500 psi; ECD = 11.56 10:30 11:00 0.50 12,146 12,168 PROD3 STK OTHR T Drill Side Track f/ 12146' - 12168' MD; 300 GPM @3450 psi; WOB 2 - 4K; 120 RPM, Torque 8K, ECD = 11.53; P/U 205, S/O 0, Rot 124 11:00 11:45 0.75 12,168 12,168 PROD3 STK TRIP T POOH f/ 12168' - 11969' MD; RIH t/ 12168' MD Challen ed Side Track 11:45 18:00 6.25 12,168 12,309 PROD3 DRILL DDRL T Directional drill the A4 lateral. 18:00 19:45 1.75 12,309 12,424 PROD3 DRILL DDRL T Directional drill the A4 lateral. 19:45 00:00 4.25 12,424 12,664 PROD3 DRILL DDRL P Directional drill the A4 lateral. 5/06/2008 Drilled A4 lateral to TD 13018' MD/3785' TVD. Circulated hole clean, total 6 bottoms up. Displaced well to SFOBM and began pulling out of hole. Pulled out to window, cut & slip drilling line and continue pulling out of hole. 00:00 05:45 5.75 12,664 13,018 PROD3 DRILL DDRL P Directional drill the A4 lateral. Final surve . 05:45 06:15 0.50 13,018 13,018 PROD3 DRILL PULD P Stand back a stand. Pickup a single 4" drill pipe to use while circulating hole clean. 06:15 11:30 5.25 13,018 13,018 PROD3 DRILL CIRC P Obtain slow pump rates. Circulate a 40 bbl (9.0 ppg/ 250 vis sweep) around, observed 25% increase in cuttings. Circulated 2nd sweep and observed 15% increase in cuttings when sweep returned. Circulated total of 6 bottoms up. Pumped @ 320 gpm, 3760 psi, rotating 120 rpm, for ue 8k ft lbs. 11:30 12:45 1.25 13,018 13,018 PROD3 DRILL CIRC P Displace well over to 9.3 ppg SFOBM. Pumped 320 gpm, 3800 psi, rotating 120 rpm, torque 8k ft lbs. 12:45 13:30 0.75 13,018 13,018 PROD3 DRILL OWFF P Monitor well -static 13:30 14:00 0.50 13,018 12,055 PROD3 DRILL TRIP P Pull out of hole, recording torque & drag every 5 stands. Dropped 2.45" rabbit. 14:00 14:15 0.25 12,055 12,055 PROD3 DRILL TRIP P Blow down top drive. fi'age ~~ oaf fi0 • Time Logs _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 14:15 17:30 3.25 12,055 7,351 PROD3 DRILL TRIP P Pull out of hole into window, recording torque & drag every 5 stands. 17:30 19:30 2.00 7,351 7,351 PROD3 RIGMNT SVRG P Cut & Slip 112' of drilling line 19:30 20:00 0.50 7,351 7,351 PROD3 RIGMNT SVRG P Inspect drawworks, brakes, rollers, ads and a ualizer bar. 20:00 00:00 4.00 7,351 2,163 PROD3 DRILL TRIP P Continue POOH on elevators, monitoring well via trip tank, recording weights every 5 stands. Recovered 2.45" rabbit stuck in stand #73 @ 7166' MD. Dropped 1.90 rabbit and continued POOH. 5/07/2008 Run 4-1/2" A4 lateral liner and set top of liner at 7588' MD. Circulated bottoms up inside casing. Pull out of hole and la down liner runnin tools. Pick u and make u whi stock fishin BHA. 00:00 01:00 1.00 2,163 341 PROD3 DRILL TRIP P Continue pulling out of hole on elevators. Monitoring hole fill via trip tank. PU wt 87k, SO wt 90 k. 01:00 01:30 0.50 341 341 PROD3 DRILL TRIP P Pull stripping rubbers and monitor well -static. Clean rig floor, PJSM - La in down BHA. 01:30 03:00 1.50 341 85 PROD3 DRILL PULD P Lay down HWDP, jars, bumper sub, flex collars and float sub. Recovered 1.90" rabbit from to of 'ars. 03:00 03:30 0.50 85 85 PROD3 DRILL PULD P Download MWD, service top drive and drawworks 03:30 04:30 1.00 85 0 PROD3 DRILL PULD P Lay down MWD, smart stabilizer, geo-flex collar, geo-pilot and bit. Hole fill on trip 95 bbls, calculated 82, lost 13 bbls to well. 04:30 04:45 0.25 0 0 COMPZ CASING RURD P Clear and clean rig floor. 04:45 05:30 0.75 0 0 COMPZ CASING RURD P Pick up and rig up GBR liner running tools. Make up floor valve for 4-1/2" liner. 05:30 05:45 0.25 0 0 COMPZ CASING SFTY P PJSM -running 4-1/2" liner 05:45 06:00 0.25 0 23 COMPZ CASING RUNL P Run liner in hole. Monitoring well via tri tank 06:00 09:30 3.50 23 5,460 COMPZ CASING RUNL P Running liner in hole. Record torque & drag as per detail from Rig Drilling En ineer. 09:30 10:00 0.50 5,460 5,472 COMPZ CASING RUNL P Make up liner setting sleeve and liner setting tool per Baker rep. Change out tongs. PU wt 100k, SO wt 105k, rotatin wt 105k, for ue 3k ft lbs. 10:00 12:00 2.00 5,472 7,350 COMPZ CASING RUNL P Running in hole with liner on drill pipe, monitoring displacement via trip tank. Recording torque & drag as instructed. 12:00 15:30 3.50 7,350 13,008 COMPZ CASING RUNL P Continue running in hole with liner on drill i e Page 55 of 60 _Time Logs _ _ _ __ _ ___ __ Date From To Dur S. De th E De th Phase Code Subcode T Comment 15:30 17:15 1.75 13,011 7,588 COMPZ CASING RUNL P Drop 29/32" ball and pump down @ 4 bpm / 940 psi. With ball on seat pressure up to 3500 psi to release liner. Before release PU wt 225k SO wt 74k, rotating wt 148K. After release PU wt 190k, SO wt 135k. Pressure up to 4600 psi and shear circulation sub. Top of liner set at 7588' MD. 17:15 18:30 1.25 7,588 7,371 COMPZ CASING CIRC P Pull out of hole to window and circulate bottoms up. Pumping 300 m / 1850 si. 18:30 19:00 0.50 7,371 7,371 COMPZ WELCTI OWFF P Monitor well -static. Blow down top drive, install stripping rubbers and air sli s. 19:00 22:15 3.25 7,371 125 COMPZ CASING RUNL P Pull out of hole on elevators, monitoring well via trip tank, recordin wei hts eve 5 stands. 22:15 22:30 0.25 125 125 COMPZ WELCTL OWFF P Monitor well -falling. 22:30 22:45 0.25 125 0 COMPZ CASING RUNL P Lay down liner running tool. 22:45 00:00 1.25 0 253 COMPZ FISH PULD P Pick up and make up whipstock retrievin BHA. 5/08/2008 Run in hole with whipstock retrieving BHA. Hook whipstock and jar free. Circulate bottoms up and pull out of hole with whi stock. Make u A4 lateral hook han er and run in hole. 00:00 00:15 0.25 253 343 COMPZ FISH TRIP P Tripping in hole with whipstock retrievin BHA. 00:15 01:00 0.75 343 343 COMPZ RIGMNT SVRG P Service crown and blocks. PM on drawworks and to drive. 01:00 04:30 3.50 343 7,352 COMPZ FISH TRIP P TIH on elevators, monitoring displacement via trip tank. Fill pipe every 25 stands. Record weights every 10 stands. PU wt 190k, SO wt 135k 04:30 05:15 0.75 7,352 7,362 COMPZ FISH FISH P Wash whipstock face and key slot pumping 208 gpm / 1270 psi, recprocating pipe 20'. Rotating 1/4 turn at a time. Hooked fish on depth, slacked off to 100k. Fired jars 3 times and fish came free. 05:15 06:15 1.00 7,362 7,278 COMPZ FISH CIRC P Pulled fish above window and circulate bottoms u at 255 m. 06:15 06:45 0.50 7,278 7,278 COMPZ WELCTt OWFF P Monitor well -breathing. Gained 1.2 bbls in 15 min, then static. 06:45 12:30 5.75 7,278 253 COMPZ FISH TRIP P Pull out of hole with whipstock. Hole took ro er dis lacement. 12:30 14:45 2.25 253 0 COMPZ FISH PULD P Lay down BHA and whipstock per Baker re .Clear ri floor. 14:45 15:30 0.75 0 0 COMPZ RPCOM RURD P Pick up and rig up tools for running hook han er. 15:30 15:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM -picking up and making up hook han er. 15:45 18:00 2.25 0 262 COMPZ RPCOM PULD P Pick up and make up hook hanger and aaker. Run in hole. 18:00 18:30 0.50 262 262 COMPZ RPCOM DHEQ P Shallow test MWD pumping 90 gpm / 480 si. Tested ood. i f~age b6 of ~~ • _Time Logs _ Date From To Dur S De th EDepth Phase Code Subcode T Comment 18:30 18:45 0.25 262 262 COMPZ RPCOM TRIP P Blow down topdrive 18:45 23:45 5.00 262 7,595 COMPZ RPCOM TRIP P Trip in hole with A4 lateral hook hanger, monitoring displacement via tri tank. 23:45 00:00 0.25 7,595 7,595 COMPZ RPCOM CIRC P Circulate to obtain toolface (6L), pump 113 gpm / 1020 psi. PU wt 190k SO wt 140k. 5/09/2008 Landed hook hanger and inflated ECP. Release hanger and tripped out of hole. Test BOPE, 1 failure - retested ok. Test witnessed by AOGCC Bob Noble. Pick up and run in hole with A4 LEM. Landed LEM set han er and acker. Tested acker - ressure held. 00:00 00:30 0.50 7,595 7,615 COMPZ RPCOM TRIP P Trip in hole holding toolface 6 degrees left. Pumping 113 gpm / 1020 psi. PU wt 190k So wt 140k. Set 40k on hook observed toolface rotate to 13 degrees right. Pulled to 200k to confirm hooked. Unhooked at 210k, pulled up 20' rotated toolface to 100R and run hook thru window. Pick up 30' rotate toolface to 6L. Run in and rehook. Set 45k on hook. Calculated displacement for trip 53.91 bbls, actual 46.5, lost 7.41 bbls. 00:30 01:30 1.00 7,615 7,615 COMPZ RPCOM PACK P Drop ball and pump down at 103 gpm / 960 psi. When ball on seat pressure up to 1500 psi and hold. Continue to pressure up, at 1650 psi pressure fell off to 900 psi (assume ECP opened early) Pumped another .5 bbl stopped pumps and held pressure at 1650 psi. Continue staging pressure up to 4000 psi. Hold for 5 minutes. Bleed off ressure. 01:30 01:45 0.25 7,615 7,330 COMPZ RPCOM TRIP P Pull out of hole to clear tools from han er. PU wt 185k SO wt 140k. 01:45 02:30 0.75 7,330 7,330 COMPZ RPCOM CIRC P Circulate bottoms up @ 258 gpm. 02:30 02:45 0.25 7,330 7,288 COMPZ RPCOM TRIP P Pull out of hole 02:45 03:00 0.25 7,288 7,288 COMPZ RPCOM OWFF P Monitor well -breathing then static 03:00 06:00 3.00 7,288 150 COMPZ RPCOM TRIP P Pull out of hole on elevators. Monitor hole fill via trip tank. Calculated fill 53.14 bbls, actual 55.5 bbls, lost 2.36 bbls. 06:00 06:15 0.25 150 150 COMPZ RPCOM OWFF P Pull stripping rubbers and monitor well -static 06:15 07:45 1.50 150 0 COMPZ RPCOM PULD P Lay down hook hanger running toots 07:45 09:00 1.25 0 0 COMPZ WELCTL BOPE P Pull wear bushing and drain stack. Set test plug, fill stack, manifold and lines. Pace 57 raf &td Time Logs __ . 5. De th E. De th Phase Code Subcode T Comment ..Date From To Dur 09:00 14:00 _ 5.00 0 0 COMPZ WELCTL BOPE P Test BOPE. 33 components tested, 1 failed and retested ok. Tested to 250 psi low and 3000 psi high. Accumulator drawdown test. Starting pressure 3100 psi, after closing 1450 psi. 37 seconds intil 200 psi increase. Full pressure after 3 minutes 50 seconds. 5 bottle average pressure 2475 psi. Test witnessed b AOGCC Bob Noble. 14:00 15:15 1.25 0 0 COMPZ WELCTL ROPE P Rig down BOPE test equipment, Blow down topdrive, manifold and lines. Run wear rin . 15:15 15:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM -running LEM 15:30 17:15 1.75 0 265 COMPZ RPCOM PULD P Pick up and make up LEM, packer and runnin tools er Baker re . 17:15 17:30 0.25 265 265 COMPZ RPCOM DHEO P Shallow pulse test MWD pumping 90 m / 510 si. Tested ood. 17:30 18:00 0.50 265 265 COMPZ RPCOM OTHR P Blow down top drive and install stri in rubbers. 18:00 22:00 4.00 265 7,318 COMPZ RPCOM TRIP P Tripping in hole w/LEM at 90 fpm. Monitoring displacement via trip tank. PU wt 180k SO wt 135k 22:00 22:45 0.75 7,318 7,486 COMPZ RPCOM TRIP P Make up to topdrive and obtain toolface. At 90 degress left trip in until seals in seal bore recepticle. Seals engaged 5.36 feet high, 7469' MD. Checked depths and continued in hole. LEM latched at 7486' MD. Set down 30k. Observed toolface come around to 18 degrees right. Pull to 200k to confirm latch. Set down to 90k and pulled up to 150k and set slips. Calculated displacement for trip 59 bbls, actual 55 bbls, lost 4 bbls to well. 22:45 23:30 0.75 7,486 7,486 COMPZ RPCOM PACK P Drop ball and pump down. Pressure up to 1500 psi when ball landed on seat. Stage pressure up to 4200 psi and hold. Bleed off pressure and slack off to 90k. Pick up to 160k and test packer with 1000 psi for 5 minutes. Charted test, ressure held. 23:30 00:00 0.50 7,486 7,123 COMPZ RPCOM TRIP P Pull out of hole with LEM running tools. 5/10/2008 Pull out of hole with LEM running tools. Lay down drill pipe and remove supersliders. Rig up and start running 4-1/2" com letion strip 00:00 00:30 0.50 7,123 7,123 COMPZ RPCOM OWFF P Monitor well -breathing to static 00:30 01:15 0.75 7,123 7,123 COMPZ RPCOM CIRC P Pump 15 bbl dry job. Blow down top drive and kill Tine. 01:15 01:45 0.50 7,123 5,991 COMPZ RPCOM TRIP P Pull out of hole and stand back hybrid drill collars. Monitoring hole fill vai tri tank. Pale ~8 of 60 Time Logs _ Date From To Dur S Depth_ _E. Depth Phase Code _ Subcode T Comment 01:45 06:00 4.25 5,991 80 COMPZ RPCOM TRIP P Pulling out of hole laying down drill pipe. Remov supersliders in pipe shed. Calculate hole fill 53.62 bbls, actual 58.5 bbls, lost 4.88 bbls. 06:00 09:00 3.00 80 0 COMPZ RPCOM PULD P Laying down LEM running tools. 09:00 15:00 6.00 0 0 COMPZ RPCOM OTHR P Lay down hybrid drill collars and drill i e from derrick. 15:00 15:45 0.75 0 0 COMPZ RPCOM OTHR P Putl wear bushing, clear and clean ri floor. 15:45 18:00 2.25 0 0 COMPZ RPCOM RURD P' Rig up to run 4-1/2" completion string, gauge spool, clamps and tools. Han sheave for au a wire. 18:00 18:30 0.50 0 0 COMPZ RPCOM RURD P Make splice for gauge wire. 18:30 19:15 0.75 0 185 COMPZ RPCOM RCST P Pick up & run seals and 5 joints of tubin from i e shed. 19:15 20:00 0.75 185 185 COMPZ RPCOM RURD NP Move gauge wire spool and rehang sheave so there will be room in the derrick for heat trace sheave. 20:00 21:45 1.75 185 400 COMPZ RPCOM RCST P Running tubing from derrick. Break for au a carrier. 21:45 00:00 2.25 400 410 COMPZ RPCOM PULD P Pick up and make up gauge carrier, install au es. 5/11 /2008 Run completion with gauge wire and heat trace. 00:00 00:30 0.50 410 537 COMPZ RPCOM PULD P Pick up and make up gauge carrier, install au es. 00:30 06:00 5.50 537 3,860 COMPZ RPCOM RCST P Trip in hole with 4-1/2" tubing with gauge wire. Testing wire every 1000' all tests ood. 06:00 06:30 0.50 3,860 4,133 COMPZ RPCOM RCST P Continue tripping in hole with 4-1/2" tubin with au a wire. 06:30 08:30 2.00 4,133 4,133 COMPZ RPCOM RURD P Rig up for heat trace, hang sheave, bring cable and clamps to floor. Perform continui test - ood. 08:30 18:00 9.50 4,133 6,196 COMPZ RPCOM RCST P Continue tripping in hole with completion string, gauge wire and heat trace. 18:00 00:00 6.00 6,196 7,243 COMPZ RPCOM RCST P Continue tripping in hole with completion string, gauge wire and heat trace. 5/12/2008 Land 4-1/2 completion string with gauge wire and heat trace. Space out and test seals. Splice connections thru hanger. Nipple down stack and nipple up tree. Pressure tests good. Shear out and freeze protect well w/ 143 bbls diesel. Rig down to move off well. Camps, shop and parts house moved to 3C pad, Release rig at 2400 hour 5/12/08 00:00 01:15 1.25 7;243 7,243 COMPZ RPCOM RURD P Rig up head pin and hose for circulating while stabbing into seals. Pum s off PU wt 135k SO wt 108k. 01:15 02:00 0.75 7,243 7,270 COMPZ RPCOM RCST P 5' in pumping 1 bpm / 130 psi until stabbed into seals. Shut down pumps and continue in hole until tagged upon nogo. Calculated displacement 33.5 bbls, actual 32 bbls, lost 1.5 bbls during completion run. P~~ i9 of 6~ C~ ~~ Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T_ Comment __ 02:00 03:30 1.50 7,270 7,226 COMPZ RPCOM HOSO P Lay down 3 joints of tubing, pick up space out pups, hanger and landing 'oint. 03:30 07:30 4.00 7,226 7,226 COMPZ RPCOM RCST P Install 3 penitrators in hanger (1 dummy). Splice gauge wire and heat trace. 07:30 10:00 2.50 7,226 7,265 COMPZ RPCOM RCST P Drain stack and land tubing. Verify hanger orientation. Pick up 3', leaving seals engauged, fill stack, close bag and pressure test seals to 1000 psi for 10 minutes -good test. Bleed off, drain stanck and land tubing. Reverify hanger orientation and run in lock down screws. Test upper and lower hanger seals to 5000 psi for 10 minutes - ood test. 10:00 14:15 4.25 0 0 COMPZ RPCOM NUND P Nipple down BOP, riser, bell nipple and flow line. Cleanin dri an. 14:15 17:30 3.25 0 0 COMPZ RPCOM NUND P Nipple up tree and test tubing hanger void to 5000 psi for 10 minutes - ood test. Chan in out saver sub. 17:30 18:30 1.00 0 0 COMPZ RPCOM RURD P Rig up to test tree. Test 350 psi & 5000 si - ood test 18:30 22:00 3.50 0 0 COMPZ RPCOM FRZP P Rig up to shear out and freeze protect. Shear out with 2100 psi and pump 143 bbls of freeze protect diesel at 1 bpm @ 375 psi. Tubing shut in 100 psi, Inner annulus 150 psi, outer annulus 200 psi. Prep to skid rig floor, blow down stream and water lines. 22:00 00:00 2.00 0 0 COMPZ RPCOM RURD P Rig lubricator and set BPV, Empty remainder SFOBM from pit, Clean out cellar. *** Release Rig at 24:00 hours 5/12/08 *** Page 6 of b0 ~ ~ WELL LOG TRANSMITTAL To: 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 1C-172A+L1+L2+L2PB1+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 5 0-02 9-2 315 9-01, 60, 61, 70, 71 Digital Log Images 50-029-23159-01,60,61,70,71 1 CD Rom 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 L ~o~-oo d i~o~'~io Date: _ - Signed: ~ ~:_ r ao~-o~ 1 ~~r ~ • • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1C Pad 1 C-172AL1 50-029-23159-60 ~ r~illir~ r i Definitive survey Report 03 June, 2008 ~f F1~2.. i::1_'.L~N4t2k .. ~._:_.~ ~~.~ ..._ ....____ _._ I. d' .:. ''~.'.~'~i ~.. `.~i Cam,-. ~_~~t,'~~it3'="~~h~c~`L':;"_,~ ,_ ._, _.. ___ _.. '~."_ .~..v:. ~z~~ru?~.z.~~_.~;«_.a~~9~('~` ._.._,. Sperry Driliirtig ~ctwvices Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1 C-172 Wellbore: 1 C-172AL1 Design: 1 C-172AL1 • ConocoPhi~iips Definitive Survey Report Local Co-ordinate Reference: Well 1C-17Z TVD Reference: 1C-172A ~ 100.50ft (Doyon 15) MD Reference: 1C-172A ~ 100.50ft (Doyon 15) North References True Survey Calculation Method: IVlinimum Carrvature Database: CPA( EDM production Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Daturrn: Mean Sea (Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well il2eference 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: 7fl° 19' 31.051 N +E/-W 0.00 ft Easting: 562,101.96ft Longitude: 149" 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Le~ael: 59.10ft - - _ ellbore C-172AL1 --- - __ _ _ --- - M ti M d l agne cs o e Name Sample Date Declin ation Dip Angle Field Strength BGGM2007 12/18/2007 18.05 79.76 57,268 BGGM2007 3/29/2008 17.93 75.77 57,280 , Design 1C-172AL1 _ -- - -- Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,732.79 Vertical Section: Depth From (TVD) +NI-S +E/-W birection ~ (ft) (ft) (ft) (°) ~ 41.40 0.00 0.00 180.00 Survey Program Date. Frorn To (ft) (ft) Survey (Wellbore) Tool Name Description 158.30 279.40 1 C-172 Gyro (atdb) (1 C-172) CB-GYRO-SS Camera based gyro sirngle shot 403.29 3,452.05 1C-172 (1C-172) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SG1cC 3,513.00 7,732.79 1C-172A MWD+SAG+CA+(IFR+MS (1C-MWD+IFR-AK-CAAZ-SC MWD+IFR AK CAZ SC1tC 7,819.83 13,040.20 1C-172AL1 MWD+SAG+CA+(IFR+MS (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SG[C Survey MD Inc Azi TVD TVDSS +N/-S (ft) (°) (°) (ft) (ft) (ft) 41.40 0.00 0.00 41.40 -59.10 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: 4/16/2008 1: lilEap Map \1/ertical +E/-W Norathing Easting DLS Section lft)' (`fit) (ft) (°/100') (ft) Survey Tool Name 0.00 5,968,801.43 562,101.96 0.00 0.00 UNDEFWED -0.12 5,968,801.54 562,101.84 0.14 -0.12 CB-GYRO-SSi (1) 0.34 5,9,802.85 562,102.29 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 5,96'8,809.42 562,106.50 0.36 -7.95 MWD+IFR-Ate-CAZ-SC (2) 7.20 5,968,814.20 562,109.06 1.84 -12.71 MWD+IFR-A!~ CAZ-SC (2) 10.65 5,96+8,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 14.70 5,965,832.11 562,116.4® 3.02 -30.56 MWD+IFR-A(K CAZ-SC (2) 19.08 5,968,847.31 562,120.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) 23.29 5,96ffi,865.98 562,124.71 1.44 -64.37 MWD+IFR-A54 CAZ-SC (2) 6/3/2008 2:30:49PM Page 2 COMPASS 20FA3.16 Bui/d 42F • Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1 C-172 Wellbore: 1 C-172AL1 Design: 1 C-172AL1 Survey ConocoPhillips • Definitive Survey Report MD Inc Azi ND NDSS +N/-S (ft) (°) (°) (ft) (ft) (ft) 1,033.78 15.64 1.05 1,026.20 925.70 86.13 1,128.53 19.91 351.25 1,116.42 1, 015.92 114.86 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 1,315.26 21.18 341.57 1,290.78 1,190.28 179.74 1,407.39 26.12 338.05 1,375.15 1,274.65 214.36 1,502.67 33.63 335.74 1,457.71 1,594.46 35.67 335.01 1,533.22 1,687.13 40.07 334.38 1,606.35 1,780.29 44.74 331.67 1,675.13 1,873.69 50.50 330.33 1,738.06 1,965.93 53.61 328.47 1,794.77 2,058.38 56.75 326.71 1,847.56 2,151.37 66.46 324.51 1,891.73 2,243.98 67.44 325.15 1,927.99 2,337.06 66.78 325.57 1,964.20 2,429.62 66.75 326.52 2,000.71 2,522.51 64.45. 324.33 2,039.09 2,616.50 63.51 323.94 2,080.32 2,708.50 62.50 324.15 2,122.08 2,802.18 64.21 323.38 2,164.09 1,357.21 257.94 1,432.72 305.37 1,505.85 356.78 1,574.63 412.71 1,637.56 473.01 1,694.27 1,747.06 1,791.23 1, 827.49 1, 863.70 535.60 599.65 667.02 736.68 807.23 Local Co-ordinate Reference: Well 1C-172 ND Reference: 1C-172A @ 100.50ft (Doyon 15} MD Reference: 1C-172A @ 100.50ft (Doyon 15} North Reference: Frue Survey Calculation Method:. Minimum Curvature Database: CPAI EDM Production Map +E!-W Northing (ft) (ft) 25.36 5,968,887.76 23.14 5,968,916.47 16.65 5,968,949.00 7.40 5,968,981.21 -5.45 5,969,015.72 -24.16 5,969,059.13 -45.91 5, 969,106.38 -70.23 5,969,157.58 -98.78 5,969,213.27 -132.24 5,969,273.28 -169.28 5,969,335.55 -209.97 5,969,399.26 -256.18 5,969,466.25 -305.26 5,969,535.49 -354.00 5,969,605.63 Map Vertical Fasting DLS Section (ft) (°1100') (ft) Surveys-ool Name 562,126.60 4.22 -86.13 MWD+IFR-AK-CAZ-SC (2) 562,124.14 5.49 -114.86 MWD+IFF~ AK-CAZ-SC (2) 562,117.39 2.42 -147.46 MWD+IFR-AK-CAZ-SC (2) 562,107.87 1.92 -179.74 MWD+IFR-AK-CAZ-SC (2) 562,094.74 5.57 -214.36 MWD+IFR-AK-CAZ-SC (2) 562,075.87 562,053.53 562,028.78 561,999.78 561.965.82 561,928.27 561,887.05 561,840.30 561,790.64 561.741.32 1,900.21 877.78 -401.51 5,969,675.77 561,693.24 1,938.59 947.43 -449.49 5,969,745.02 561,644.68 1,979.82 1,015.88 -498.98 5,969,813.05 561,594.64 2,021.58 1,082.24 -547.11 5,969,879.00 561,545.97 2,063.59 1,149.77 -596.60 5,969,946.11 561,495.92 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 1,286.39 -697.15 5,970,0$1.88 561,394.25 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 1,555.6.0 -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 5,970,417.90 561,132.94 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 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 65.28 328.01 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 1,990.25 -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 68.81 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 560,801.34 7.97 -257.94 MWD+IFR-AK-CAZ-SC (2) 2.27 -305.37 MWD+IFR-,4K-CAZ-SC (2) 4.77 -356.78 MWD+IFR-AK-CAZ-SC (2) 5.38 -412.71 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 -667.02 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-#\K-CAZ-SC (2) 1.12 -1,082.24 MWD+IFR-d4K-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~1K-CAZ-SC (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-~4K-CAZ-SC (2) 0.21 -1,624.59 MWD+IFRb4K-CAZ-SC (2) 4.26 -1,668.94 MWD+IFR-AK-CAZ-SC (3) 6.34 -1,722.23 MWD+IFR-,P,K-CAZ-SC (3) 5.91 -1,745.84 MWD+IFR~K-CAZ-SC (3) 1.53 -1,770.77 MWD+IFR AK-CAZ-SC (3) 2.33 -1,806.38 MWD+IFR-s4K-CAZ-SC (3) 0.84 -1,843.92 MWD+IFR-~4K-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-P,K-CAZ-SC (3) 4.39 -1,990.26 MWD+IFR--AK-CAZ-SC (3) 2.05 -2,025.41 MWD+IFR-,AK-CAZ-SC (3) 2.80 -2,061.92 MWD+IFR->P+,K-CAZ-SC (3) 0.68 -2,099.09 MWD+IFR-,AK-CAZ-SC (3) 6/3/2008 2:30:49PM Page 3 COMPASS 2'003.16 Build 42F i Company: __ ConocoPhillips(Alaska) Inc. Project: Kuparuk Rive r Unit Site: Kuparuk 1C Pad Well: 1 C-172 Wel Ibore: 1 C-172AL1 Design: 1C-172AL1 Survey ~, MD Inc Azi TVD TVDSS I (ft) (°) (°) lft) lft) 4,125.49 68.28 323.84 2,689.81 2,589.31 4,175.33 67.30 325.15 2,708.65 2,608.15 4,220.69 66.91 328.35 2,726.31 2,625.81 4,273.07 67.39 327.31 2,746.65 2,646.15 4,315.29 67.35 326.13 2,762.89 2,662.39 4,360.35 67.02 324.56 2,780.37 2,679.87 4,409.23 67.34 323.59 2,799.32 2,698.82 4,457.69 67.78 323.19 2,817.82 2,717.32 4,506.21 68.87 323.19 2,835.74 2,735.24 4,551.46 68.80 321.91 2,852.08 2,751.58 4,601.20 68.93 320.38 2,870.02 2,769.52 4,652.27 68.66 317.69 2,888.49 2,787.99 4,695.93 67.82 314.97 2,904.68 2,804.18 4,741.75 66.56 312.96 2,922.44 2,821.94 4,791.17 65.32 309.76 2,942.60 2,842.10 4,837.62 65.20 307.28 2,962.04 2,861.54 4,885.47 65.86 304.28 2,981.86 2,881.36 4,931.69 66.66 302.49 3,000.47 2,899.97 4,979.93 66.49 300.50 3,019.65 2,919.15 5,026.88 66.90 298.16 3,038.23 2,937.73 5,075.65 67.48 296.20 3,057.13 2,956.63 5,122.83 66.43 292.82 3,075.61 2,975.11 5,171.43 66.15 290.26 3,095.15 2,994.65 5,218.47 66.25 287.55 3,114.14 3,013.64 5,267.44 67.09 285.02 3,133.53 3,033.03 5,312.08 67.20 282.82 3,150.87 3,050.37 5,361.27 66.28 279.48 3,170.30 3,069.80 5,412.46 66.84 275.53 3,190.67 3,090.17 5,457.39 66.76 273.44 3,208.37 3,107.87 5,512.09 67.69 270.51 3,229.55 3,129.05 ConocoPhiliips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculat7ion Method: Database: Ma;P +N1-S +E/-W Nortk~ing (ft) (ft) (~ 2,132.61 -1,308.30 5,970,922.93 2,170.17 -1,335.10 5,970,960.27 2,205.11 -1,358.01 5,970,995.01 2,245.96 -1,383.71 5,971,035.65 2,278.54 -1,405.09 5,971„068.05 2,312.71 -1,428.71 5,971,102.01 2,349.19 -1,455.14 5,971,138.27 2,385.14 -1,481.85 5,971„174.00 2,421.24 -1,508.87 5,971,209.87 2,454.74 -1,534.52 5,971„243.15 2,490.87 -1,563.63 5,971„279.04 2,526.82 -1,594.84 5,971,314.72 2,556.15 -1,622.83 5,971„343.81 2,585.47 -1,653.23 5,971,372.88 2,615.29 -1,687.09 5,971,402.41 2,641.56 -1,720.09 5,971„428.41 2,667.01 -1,755.42 5,971,#53.57 2,690.29 -1,790.75 5,971„476.55 2,713.41 -1,828.49 5,971,499.36 2,734.53 -1,866.08 5,971„320.17 2,755.07 -1,906.07 5,971„540.36 2,773.08 -1,945.56 5,971„558.05 2,789.41 -1,986.94 5,971,574.04 2,803.36 -2,027.66 5,971,587.64 2,815.96 -2,070.81 5,971,.'599.89 2,825.86 -2,110.74 5,971,x509.45 2,834.60 -2,155.07 5,971„x517.83 2,840.73 -2,201.62 5,971,23.57 2,843.96 -2,242.79 5,971,E626.46 2,845.69 -2,293.18 5,971,+'&27.77 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,1627.07 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,24.22 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,19.84 5,696.76 66.30 261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,~'i13.53 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,06.05 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,.'584.50 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 5,933.84 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,97t,~54.19 5,978.50 67.04 245.10 3,413.51 3,313.01 2,758.63 -2,709.25 5,971,537.28 • Well 1 C-172 1 C-172A @ 1i 00.50ft (Doyon 15) 1 C-172A @ ~ 00.50ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Wertical Fasting DLS Section (ft) (°/100') (ft) Survey Too6 Name 560,776.18 2.16 -2,132.61 MWD+IFR-AK CAZ-SC (3} 560,749.08 3.13 -2,170.17 MWD+IFR-Aft-CAZ-SC (3) 560,725.88 6.56 -2,205.11 MWD+IFR-AK-CAZ-SC (3) 560,699.85 2.05 --2,245.96 MWD+IFR-AIC-CAZ-SC (3) 560,678.20 2.58 -2,278.54 MWD+IFR-AK~CAZ-SC (3) 560,654.30 3.29 -2,312.71 MWD+IFR-AK-CAZ-SC (3) 560,627.57 1.94 -2,349.19 MWD+IFR-AK-CAZ-SC (3) 560,600.56 1.19 -2,385.14 MWD+IFR-AK-CAZ-SC (3) 560,573.25 2.25 -2,421.24 MWD+IFR-AK-CAZ-SC (3) 560,547.32 2.64 -2,454.74 MWD+IFR-AK-CAZ-SC (3) 560,517.92 2.88 -2,490.87 MWD+IFR AK-CAZ-SC (3) 560,486.42 4.94 -2,526.82 MWD+IFR-AK-CAZ-SC (3) 560,458.18 6.10 -2,556.15 MWD+IFR-AK-CAZ-SC (3) 560,427.55 4.89 -2,585.47 MWD+IFR-AK~AZ-SC (3) 560,393.45 6.42 -2,615.29 MWD+IFR-AK-CAZ-SC (3) 560,360.23 4.86 -2,641.56 MWD+IFR-AK-CAZ-SC (3) 560,324.70 5.87 -2,667.01 MWD+IFR-AK-•CAZ-SC (3) 560,289.18 3.94 -2,690.29 MWD+IFR-AK-CAZ-SC (3) 560,251.26 3.80 -2,713.41 MWD+IFR-AK~CAZ-SC (3) 560,213.50 4.86 -2,734.53 MWD+IFR-AK~CAZ-SC (3) 560,173.34 3.89 -2,755.07 MWD+IFR-AK-CAZ-SC (3) 560,133.71 6.96 -2,773.08 MWD+IFR-AK-CAZ-SC (3) 560,092.19 4.86 -2,789.41 MWD+IFR-AK<CAZ-SC (3) 560,051.37 5.28 -2,803.36 MWD+IFR-AK-aCAZ-SC (3) 560,008.11 5.04 -2,815.96 MWD+IFR-AK-+CAZ-SC (3) 559,968.11 4.55 -2,825.86 MWD+IFR-AKCAZ-SC (3) 559,923.71 6.51 --2,834.60 MWD+IFR-AK-CAZ-SC (3) 559,877.12 7.16 2,840.73 MWD+IFR-AK4;AZ-SC (3) 559,835.93 4.28 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 559,785.52 5.22 -2,845.69 MWD+IFR-AK-d;AZ-SC (3) 559,748.35 5.19 -2,845.30 MWD+IFR-AK-CAZ-SC (3) 559,702.54 5.37 -2,842.82 MWD+IFR-AK-FCAZ-SC (3) 559,661.20 4.55 -2,838.78 MWD+IFR-AK-aCAZ-SC (3) 559,616.72 3.38 --2,832.85 MWD+IFR-AK-CAZ-SC (3) 559,575.01 4.90 -2,825.70 MWD+IFR-AK-CAZ-SC (3) 559,532.36 6.07 -2,816.23 MWD+IFR-AK-~ICAZ-SC (3) 559,490.72 4.59 -2,804.86 MWD+IFR-AK-+CAZ-SC (3) 559,447.91 6.88 -2,790.79 MWD+IFR-AK-CAZ-SC (3) 559,407.88 5.40 -2,775.22 MWD+IFR-AK~CAZ-SC (3) 559,370.24 5.39 -2,758.63 MWD+IFR-AK-4rAZ-SC (3) 6/3/2008 2.~30:49PM Page 4 COMPASS 200.x.16 Build 42F • ComocoPhillips Defir~iaive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C-172A @ 100.508 (Doyon 15) Site: Kuparuk 1C Pad GIRD Reference: 1C-172A @ 100.508 (Doyon 15) Well: 1C-172 ~lorth Reference: True Wellbore: 1C-172AL1 Survey Calculation Method: Minimum Curvature Design: 1C-172AL1 ®atabase: CPAI EDM Production Survey MD Inc Azi ND NDSS +Ni-S (ft) (°) (°) (ft) (ft) (ft) 6,028.43 66.58 242.95 3,433.18 3,332.68 2,738.53 6,074.69 67.49 240.86 3,451.23 3,350.73 2,718.47 6,123.77 67.64 238.03 3,469.96 3,369.46 2,695.41 6,169.08 66.75 235.65 3,487.52 3,387.02 2,672.57 6,218.69 67.03 233.61 3,507.00 3,406.50 2,646.16 6,267.43 67.88 6,314.03 66.91 6,358.62 66.68 6,409.08 66.96 6,455.79 66.97 6,505.16 67.34 6,551.22 66.83 6,599.24 66.93 6,650.05 68.21 6,696.47 67.69 6,750.16 68.65 6,791.15 68.79 6,841.03 70.50 6,887.05 72.42 6,937.09 75.14 6,981.79 75.77 7,032.37 76.56 7,076.80 77.92 7,124.94 80.37 7.171.02 83.10 7,217.39 84.93 7,266.96 84.23 7,312.29 84.28 7,361.90 84.37 7,398.79 83.89 7,430.40 83.26 7,457.31 83.57 7,500.41 84.00 7,552.19 83.41 7,601.90 83.95 7,642.67 83.74 7,684.06 84.46 7,732.79 84.58 7,819.83 83.85 7,852.34 84.75 230.95 3,525.69 3,425.19 2,618.62 229.11 3,543.60 3,443.10 2,590.99 226.98 3,561.17 3,460.67 2,563.59 224.00 3,581.04 3,480.54 2,531.08 221.59 3,599.32 3,498.82 2,499.54 Map ¢Ei-W Northing (ft) (ft) -2,750.50 5,971,516.84 -2,788.07 5,971,496.48 -2,827.13 5,971,473.10 -2,862.10 5,971,449.97 -2,899.30 5,971,423.25 -2,934.90 5,971,395.42 -2,967.87 5,971,367.52 -2,998.35 5,971,339.88 -3,031.42 5,971,307.09 -3,060.62 5,971,275.31 Map Vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 559,329.15 4.06 -2,738.53 MWD+IFR-AK-GAZ-SC (3) 559,291.75 4.60 -2,718.47 MWD+IFR-AK-CAZ-SC (3) 559,252.89 5.34 -2,695.41 MWD+IFR-AK-CAZ-SC (3) 559,218.12 5.23 -2,672.57 MWD+IFR-AK-CAZ-SC (3) 559,181.14 3.82 -2,646.16 MWD+IFR-AK-CAZ-SC (3) 559,145.77 5.33 -2,618.62 MWD+tFR-AK-CAZ-SC (3) 559,113.03 4.20 -2,590.99 MWD+IFR-AK-CAZ-SC (3) 559,082.79 4.42 -2,563.59 MWD+IFR-AK-CAZ-SC (3) 559,049.99 5.46 -2,531.08 MWD+IFR-AK-CAZ-SC (3) 559,021.05 4.75 -2,499.54 MWD+IFR-AK-CAZ-SC (3) 558,992.00 5.37 -2,464.77 MWD+IFR-AK-CAZ-SC (3) 558,966.37 4.48 -2,431.19 MWD+IFR-AK-CAZ-SC (3) 558,941.23 5.33 -2,395.09 MWD+IFR-AK-CAZ-SC (3) 558,916.38 5.57 -2,355.45 MWD+IFR-AK-CAZ-SC (3) 558,895.30 5.08 -2,318.13 MWD+IFR-AK-CAZ-SC (3) 558,873.36 7.06 -2,273.58 MWD+IFR-AK-CAZ-SC (3) 558,858.00 1.98 -2,238.74 MWD+IFR-AK-CAZ-SC (3) 558,840.20 4:87 -2,195.65 MWD+IFR-AK-CAZ-SC (3) 558,824.71 4.97 -2,154.99 MWD+IFR-AK-CAZ-SC (3) 558,808.16 5.44 -2,110.03 MWD+IFR-AK-CAZ-SC (3) 558,794.30 6.56 -2,069.16 MWD+IFR-AK-CAZ-SC (3) 558,780.48 3:65 -2,022.15 MWD+IFR-AK-CAZ-SC (3) 558,769.68 5.52 -1,980.28 MWD+IFR-AK-CAZ-SC (3) 558,758.92 5.18 -1,934.34 MWD+IFR-AK-CAZ-SC (3) 558,748.90 6.01 -1,889.94 MWD+IFR-AK-CAZ-SC (3) 558,739.58 5.23 -1,844.86 MWD+IFR-AK-CAZ-SC (3) 558,731.41 5.58 -1,796.26 MWD+IFR-AK-CAZ-SC (3) 558,726.26 7.09 -1,751.51 MWD+IFR-AK-CAZ-SC (3) 558,723.12 5.20 -1,702.27 MWD+IFR-AK-CAZ-SC (3) 558,722.12 4.48 -1,665.60 MWD+IFR-AK-CAZ-SG (3) 558,721.69 2.00 -1,634.20 MWD+IFR-AK-CAZ-SC (3) 558,721.53 3.55 -1,607.47 MWD+IFR-AK-CAZ-SC (3) 558,721.43 1.47 -1,564.62 MWD+IFR-AK-CAZ-SC (3) 558,721.42 1.78 -1,513.16 MWD+IFR-AK-CAZ-SC (3) 558,721.89 1.35 -1,463.75 MWD+IFR-AK-CAZ-SC (3) 558,722.58 1.26 -1,423.22 MWD+IFR-AK-CAZ-SC (3) 558,723.71 2.47 -1,382.05 MWD+IFR-AK-CAZ-SC (3) 558,725.39 0.28 -1,333.56 MWD+IFR-AK-CAZ-SC (3) 558,728.11 0.96 -1,246.99 MWD+IFR-AK-CAZ-SC (4) 558,728.98 2.81 -1,214.65 MWD+IFR-AK-CAZ-SC (4) 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 204.63 3,712.07 3,611.57 2,273.58 -3,210.20 5,971,048.15 203.77 3,726.95 3,626.45 2,238.74 -3,225.86 5,971,013.18 201.93 3,744.30 3,643.80 2,195.65 -3,244.01 5,970,969.95 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 200.64 3,772.91 3,672.41 2,110.03 -3,276.77 5,970,884.07 197.68 3,784.14 3,683.64 2,069.16 -3,290.96 5,970,843.09 195.96 3,796:23 3,695.73 2,022.15 -3,305.17 5,970,795.97 193.87 3,806.05 3,705.55 1,980.28 -3,316.32 5,970,754.Ot 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 191.34 3,826.57 3,726.07 1,844.86 -3,347.55 5,970,618.35 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 182.83 3,840.70 3,740.20 1,702.27 -3,365.19 5,970,475.63 181.24 3,844.47 3,743.97 1,665.60 -3,366.49 5,970,438.96 181.28 3,848.01 3,747.51 1,634.20 -3,367.18 5,970,407.55 180.37 3,851.09 3,750.59 1,607.47 -3,367.57 5,970,380.82 180.84 3,855.76 3,755.26 1,564.62 -3,368.02 5,970,337.98 180.13 3,861.44 3,760.94 1,513.16 -3,368.46 5,970,286.52 179.73 3,866.91 3,766.41 1,463.75 -3,368.40 5,970,237.12 179.26 3,871.28 3,770.78 1,423.22 -3,368.04 5,970,196.59 178.53 3,875.54 3,775.04 1,382.05 -3,367.25 5,970,155.44 178.47 3,880.19 3,779.69 1,333.56 -3,365.98 5,970,106.97 178.87 3,888.96 3,788.46 1,246:99 -3,363.97 5,970,020.42 179.02 3,892.19 3,791.69 1,214.65 --3,363.37 5,969,988.09 6/3/2008 2:30:49PM Page 5 COMPASS 2003.76 Build 42F • ConocoPhiliips ' Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1C-172 North Reference: Wellbore: 1C-172AL1 Survey Calculation Method: Design: 1 C-172AL1 Database: Survey I Map MD Inc. Azi TVD TVDSS +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) lft) (ft) 7,895.82 85.05 179.22 3,896.06 3,795.56 1,171.35 -3,362.70 5,969,944.80 7,947.81 86.79 179.46 3,899.76 3,799.26 1,119.49 -3,362.11 5,969,892.95 8,041.90 88.95 179.90 3,903.25 3,802.75 1,025.47 -3,361.58 5,969,798.95 8,136.36 90.00 180.34 3,904.12 3,803.62 931.02 -3,361.78 5,969,704.51 8,230.43 90.98 181.07 3,903.31 3,802.81 836.96 -3,362.94 5,969,610.45 8,325.31 90.30 182.08 3,902.25 3,801.75 742.13 -3,365.55 5,969,515.61 8,419.02 91.35 181.43 3,900.91 3,800.41 648.47 -3,368.41 5,969,421.94 8,512.90 91.91 181.32 3,898.23 3,797.73 554.66 -3,370.67 5,969,328.12 8,606.43 91.85 184.07 3,895.17 3,794.67 461.29 -3,375.06 5,969,234.73 8,702.25 91.85 182.16 3,892.07 3,791.57 365.67 -3,380.27 5,969,139.08 8,795.09 91.41 181.25 3,889.43 3,788.93 272.91 -3,383.03 5,969,046.30 8,889.19 90.67 180.75 3,887.72 3,787.22 178.84 -3,384.67 5,968,952.23 8,982.82 88.89 179.99 3,888.08 3,787.58 85.21 -3,385.27 5,968,858.62 9,077.26 91.47 182.96 3,887.79 3,787.29 -9.18 -3,387.70 5,968,764.22 9,169.88 91.48 185.02 3,885.40 3,784.90 -101.54 -3,394.15 5,968,671.82 9,263.43 90.73 183.02 3,883.60 3,783.10 -194.83 -3,400.70 5,968,578.48 9,357.51 91.72 178.83 3,881.59 3,781.09 -288.86 -3,402.22 5,968,484.46 9,451.46 90.43 178.05 3,879.82 3,779.32 -382.75 -3,399.66 5,968,390.59 9,545.62 90.37 181.06 3,879.17 3,778.67 -476.90 -3,398.93 5,968,296.47 9,638.77 90.37 183.53 3,878.56 3,778.06 -569.96 -3,402.66 5,968,203.38 9,732.64 89.13 183.20 3,878.97 3,778.47 -663.67 -3,408.17 5,968,109.64 9,826.48 88.82 182.37 3,880.65 3,780.15 -757.38 -3,412.73 5,968,015.90 9,920.84 90.30 185.80 3,881.38 3,780.88 -851.48 -3,419.45 5,967,921.76 10,013.47 91.48 187.11 3,879.94 3,779.44 -943.51 -3,429.86 5,967,829.66 10,063.00 91.23 183.70 3,878.77 3,778.27 -992.80 -3,434.53 5,967,780.34 10,108.02 91.72 181.65 3,877.61 3,777.11 -1,037.75 -3,436.63 5,967,735.37 10,201.76 90.00 178.24 3,876.20 3,775.70 -1,131.46 -3,436.54 5,967,641.67 10,295.59 89.81 177.75 3,876.36 3,775.86 -1,225.24 -3,433.25 5,967,547.94 10,389.20 89.93 180.97 3,876.57 3,776.07 -1,318.83 -3,432.21 5,967,454.37 10,437.98 89.38 183.42 3,876.86 3,776.36 -1,367.57 -3,434.08 5,967,405.62 10,483.27 92.89 186.05 3,875.96 3,775.46 -1,412.68 -3,437.81 5,967,360.48 10,576.93 91.85 184.24 3,872.09 3,771.59 -1,505.88 -3,446.20 5,967,267.23 10,670.87 90.92 182.00 3,869.82 3,769.32 -1,599.65 -3,451.31 5,967,173.43 10,764.38 90.98 178.06 3,868.27 3,767.77 -1,693.13 -3,451.36 5,967,079.96 10,858.95 89.93 175.85 3,867.52 3,767.02 -1,787.55 -3,446.34 5,966,985.59 10,954.05 89.63 175.61 3,867.88 3,767.38 -1,882.39 -3,439.26 5,966,890.83 11,046.71 91.54 176.35 3,866.94 3,766.44 -1,974.81 -3,432.76 5,966,798.47 11,140.80 91.11 178.12 3,864.76 3,764.26 -2,068.76 -3,428.23 5,966,704.57 11,235.76 89.44 178.56 3,864.31 3,763.81 -2,163.68 -3,425.48 5,966,609.69 11,329.37 90.12 182.59 3,864.67 3,764.17 -2,257.26 -3,426.42 5,966,516.11 Well 1 C-172 1 C-172A @ 100.a~ft (Doyon 15) 1 C-172A @ 100.5~ft (Doyon 15) True Minimum Curvatu4-~e CPAI EDM Production Map Vertical Fasting DLS Section (ft) (°/100') (ft) Survey Tool Nar>fae 558,730.00 0.83 -1,17'1.35 MWD+{FR-AK-CAZ$C (4) 558,731.02 3.38 -1,119.49 MWD+IFR-AK-CAZ-$C (4) 558,732.33 2.34 -1,025.47 MWD+IFR-AK-CAZ-SC (4) 558,732.91 1.21 -93.02 MWD+IFR-AK-CAZ-SC (4) 558,732.53 1.30 -83.96 MWD+IFR-AK-CAZ-SC (4) 558,730.71 1.28 -74;2.13 MWD+IFR-AK-CAZ-SC (4) 558,728.62 1.32 -649.47 MWD+IFR-AK-CAZ~C (4) 558,727.14 0.61 -5541.66 MWD+IFR-AK-CAZ-SC (4) 558,723.52 2.94 -461!.29 MWD+IFR-AK-CAZ-SC (4) 558,719.11 1.99 -365.67 MWD+IFR-AK-CAZ-SC (4) 558,717.11 1.09 -27.91 MWD+IFR-AK-CAZSC (4) 558,716.25 0.95 -1781.84 MWD+IFR-AK-CAZwC (4) 558,716.42 2.07 -85.21 MWD+IFR-AK-CAZ-SC (4) 558,714.77 4.17 9.18 MWD+IFR-AK-CAZSC (4) 558,709.09 2.22 10.54 MWD+IFR-AK-CAZ-SC (4) 558,703.31 2.28 1944.83 MWD+IFR-AK-CAZ-SC (4) 558,702.57 4.58 2881.86 MWD+IFR-AK-CAZSC (4) 558,705.90 1.60 38'.?'.75 MWD+IFR-AK-CAZ-SC (4) 558,707.41 3.20 4761.90 MWD+IFR-AK-CAZvC (4) 558,704.46 2.65 5694.96 MWD+IFR-AK-CAZ-SC (4) 558,699.72 1.37 6635.67 MWD+IFR-AK-CAZ-SC (4) 558,695.94 0.94 757.38 MWD+IFR-AK-CAZ-SC (4) 558,690.00 3.96 8511.48 MWD+IFR-AK-CAZ-SC (4) 558,680.35 1:90 9435.51 MWD+IFR-AK-CAZ-SC (4) 558,676.09 6.90 99.80 MWD+IFR-AK-CAZ~C (4) 558,674.37 4.68 1,037.75 MWD+IFR-AK-CAZ-SC (4) 558,675.23 4.07 1,131!_46 MWD+IFR-AK-CAZ~.C (4) 558,679.29 0.56 1,2251.24 MWD+IFR-AK-CAZ (4) 558,681.11 3.44 1,3181.83 MWD+IFR-AK-CAZ-SC (4) 558,679.65 5.15 Y,36T:57 MWD+IFR-AK-CAZ-S'C (4) 558,676.28 9.68 1,412'..:68 MWD+IFR-AK-CAZ-~C (4) 558,668.67 2.23 1,505e.88 MWD+IFR-AK-CAZ-9C (4) 558,664.33 2.58 1,5992:65 MWD+IFR-AK-CAZ-~C (4) 558,665.06 4.21 1,6931.13 MWD+IFR-AK-CAZ- (4) 558,670.86 2.59 1,787:..55 MWD+IFR-AK-CAZ-9C (4) 558,678.72 0.40 1,882`.39 MWD+IFR-AK-CAZ-SiC (4) 558,685.98 2.21 1,9741.81 MWD+IFR-AK-CAZ-~ (4) 558,691.30 1.94 2,068<.76 MWD+IFR-AK-CAZ-S'~ (4) 558,694.83 1.82 2,163::88 MWD+IFR-AK-CAZ-SC (4) 558,694.67 4.37 2,257..26 MWD+IFR-AK-CAZ-~ (4) 6/3/2008 2:30:49PM Page 6 COMPASS 2003.16 &uild 42F • • CanocoPhillips : Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit ~1/D Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad f4AD Reference: 1C-172A @ 100.50ft (Doyon 15) WeIL 1C-172 tatorth Reference: True Wellbore: 1C-172AL1 Survey Calculation Method: Minimum Curvature Design: 1C-172AL1 Database: CPAI EDM Production j Survey Map .Map Vertical MD Inc Azi ND NDSS +N/-S i-E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 11,423.55 90.06 184.47 3,864.52 3,764.02 -2,351.26 -3,432.21 5,966,422.07 558,689.65 2.00 2,351.26 MWD+IFR-AK-CAZ-SC (4) 11,517.28 89.93 183.24 3,864.53 3,764.03 -2,444.77 -3,438.52 5,966,328.52 558,684.12 1.32 2,444.77 MWD+IFR-AK-CAZ-SC (4) 11,611.36 90.42 182.18 3,864.24 3,763.74 -2,538.75 -3,442.96 5,966,234..52 556,680.45 1.24 2,538.75 MWD+IFR-AK-CAZ-SC (4) 11,704.92 90.80 181.99 3,863.24 3,762.74 -2,632.24 -3,446.37 5,966,141.04 558,677.82 0.45 2,632.24 MWD+IFR-AK-CAZ-SC (4) 11,798.84 90.43 181.64 3,862.23 3,761.73 -2,726.11 -3,449.34 5,966,047.13 558,675.63 0.54 2,726.11 MWD+IFR-AK-CAZ-SC (4) 11,892.64 91.16 180.02 3,860.93 3,760.43 -2,819.88 -3,450.70 5,965,953.3& 558,675.04 1.89 2,819.88 MWD+IFR-AK-CAZ-SC (4) 11,986.40 90.67 178.31 3,859.44 3,758.94 -2,913.62 -3,449.33 5,965,859.64 558,877.18 1.90 2,913.62 MWD+IFR-AK-CAZ-SC (4) 12,080.66 89.38 181.65 3,859.39 3,758.89 -3,007.86 -3,449.30 5,965,765.41 558,678.00 3.80 3,007.86 MWD+IFR-AK-CAZ-SC (4) 12,174.02 90.43 183.90 3,859.55 3,759.05 -3,101.11 -3,453.82 5,965,672.14 558,674.25 2.66 3,101.11 MWD+IFR-AK-CAZ-SC (4) 12,266.97 90.61 184.71 3,858.71 3,758.21 -3,193.79 -3,460.80 5,965,579.42 558,668.04 0.89 3,193.79 MWD+IFR-AK-CAZ-SC (4) 12,361.32 91.60 187.67 3,856.89 3,756.39 -3,287.56 -3,470.97 5,965,485.57 558,658.65 3.31 3,287.56 MWD+IFR-AK-CAZ-SC (4) 12,455.61 89.56 189.39 3,855.93 3,755.43 -3,380.79 .3,484.95 5,965,392..24 558,645.44 2.83 3,380.79 MWD+IFR-AK-CAZ-SC (4) 12,549.23 88.94 186.62 3,857.16 3,756.66 -3,473.48 .3,497.99 5,965,299.45 558,633.17 3.03 3,473.48 MWD+IFR-AK-CAZ-SC (4) 12,642.26 90.18 187.81 3,857.87 3,757.37 -3,565.77 -:3,509.67 5,965,207.08 558,622.25 1.85 3,565.77 MWD+IFR-AK-CAZ-SC (4) 12,736.10 93.82 186.28 3,854.60 3,754.10 -3,658.83 -:3,521.17 5,965,113.94 558,611.52 4.21 3,658.83 MWD+IFR-AK-CAZ-SC (4) 12,783.37 90.42 183.61 3,852.85 3,752.35 -3,705.88 -3,525.24 5,965,066.86 558,607.84 9.14 3,705.88 MWD+IFR-AK-CAZ-SC (4) 12,829.52 90.86 180.67 3,852.33 3,751.83 -3,751.99 -3,526.96 5,965,020.74 558,606.50 6.44 3,751.99 MWD+IFR-AK-CAZ-SC (4) 12,922.74 90.18 179.05 3,851.49 3,750.99 -3,845.20 -x,526.74 5,964,927.54 558,607.50 1.88 3,845.20 MWD+IFR-AK-CAZ-SC (4) 13,016.99 90.24 177.19 3,851.14 3,750.64 -3,939.40 -3,523.64 5,964,833.39 558,611.37 1.97 3,939.40 MWD+IFR-AK-CAZ-SC (4) 13,040.20 90.42 176.76 3,851.01 3,750.51 -3,962.57 -3,522.42 5,964,810.22 558,612.79 2.01 3,962.57 MWD+IFR-AK-CAZ-SC (4) 13,102.42 90.42 176.76 3,850.55 3,750.05 -4,024.69 -3f,518.90 5,964,748.14 558,616.82 0.00 4,024.69 PROJECTED to TD 6/3/2008 2:30:49PM Page 7 COMPASS 2003.16 Buidd 42F 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-172AL1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 7,732.79 ' MD Window /Kickoff Survey: 7,819.83 ' MD (if applicable) Projected Survey: 13,102.00 ' 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 ~ K~M+.- ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) r ~ 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 L1 AK-MW-5476893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23159-60 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: ~v~-~~~ $1 ~~~ ~~ ALASSA OIL A1~TD Gr~$ COI~TSER'QATIOI~IT COMl-IISSIOI~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, IC-172A-L] Conoco Phillips Alaska, Inc. Permit No: 208-009 Surface Location: 1436' FNL, 1096' FWL, SEC. 12, T11N, R10E, UM Bottomhole Location: 181' FNL, 2423 FEL, SEC. 14, T I 1 N, R l OE, 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 1 C-172A-L 1, Permit No 208-008, API 50-029-23159-01-00. 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 Eeld inspector at (90~-3607 (pager). DATED thiscJ'0 day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~E~~I~I~ STATE OF ALASKA `~'1 JAN23 0 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ Z ~$ PERMIT TO DRILL Alaska Oil & Gas cons. commis ion 20 AAC 25.005 Anrhnraaa 1 a. Type of W k/:.U I•.L~4.° Drill J- 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: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180. 11. Well Name and Number. 1C-172A-L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13168' . TVD: 3860' 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. Properly Designation: ADL 25649, 25650 West Sak Oil Pool Top of Productive Horizon: 375' FNL, 2257' FEL, Sec. 11, T11 N, R10E, UM 8. Land Use Permit: ALK 467, 468 13. Approximate Spud Date: 3/20/2008 Total Depth: 181' FNL, 2423' FEL, Sec. 14, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to , 3,yli"~~ Nearest Property: 4184' kR~ ~• .~k r 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 Well within Pool: 1 C-102 , 56' 16. Deviated wells: Kickoff depth: // , ft. Maximum Hole Angle: •8937 • deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) F~bOwnhole: 1698 psig ~ Surface: 1274 psig - 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including 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 5051' 8117' 3910' 13168' - 3860' • slotted 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): 11970' Total Depth TVD (ft): 3933' Plugs (measured) Effective Depth MD (ft): 11960' Effective Depth TVD (ft): 3924' Junk (measured) Casing Length Size Cement Volume MD TVD 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 TVD (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 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 265-6178 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ i Phone Z.F,S°-6$ ~r~ Date [ lrS/t~a -~ h n All D Commission Use Only Permit to Drill Number: ~~'~'~~ API Number: 50- pZq-L3/S~-~ PermitdA~pproval Date: V~ ~tj (~~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed met ane, gas drates, or gas contained in shales: 3~V p5~ ~ ~~ ~C ~~ Samples req'd: Yes ~ No ud log req'd: Yes ^ No [~ Other: V ` \' H2S measures: Yes lJ Nom it ~ nal svy req'd: Yes [/~ No ^ "~ AP OVED BY THE COMMISSION DATE: ` ~ I D ,COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate x ~ „.i„ °$ ~~ r. ~.-r,-cam Permit It -West Sak Well #1 C-172A-1 L Producer App/ication for Permit to Drill Document Table of Contents Appli~ for Permit to Drill, Well 1C-172A-1L Revision No.Q Saved: 22-Jan-08 M p x i m i z 1M~11 Vplu 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)(~) ................................................................................................... 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 1C-172A-1L PERM/TIT.doc Page 1 of 7 ~"'~ ('~ ~ ~ ~ ~ ` Printed: 22-Jan-08 ~J Appli~ for Permit to Drill, Well 1C-172A-1L 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 ............................................................................................................. 7 Attachment 1 Directional Plan ......................................•......................................................................... 7 Attachment 2 Drilling Hazards Summary ............................................... Error! Bookmark not defined. Attachment 3 Well Schematic .........................................................o..................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each we/I must be identified by a unique name designated by the operator and a unique API number assigned by the commission under ZO AAC 25.040(6). For a well with mu/tip/e well branches, each branch must Simi/arly be identiFed by a unique name and API number by adding a suffix to the name designated for the we// by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as iC-172A-1L. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An appGcatian for a Permit to l~ri/l 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 location of the wel/ at the surface, at the top of each objective formation, and at tots/depth, referenced to governments/section /fines. (8) 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 Nations! Geodetic Survey in the Nations/ Oceanic and Atmospheric Administration; (C) the proposed depth of the we/! at the top of each objective formation and at total depth; Location at Surface 1,436' FNL, 4,184' FEL, Section 12, T11N, R10E ASPZone4NAD27Coordinates RKBE/evation 99.0'AMSL Northings; 5,968,801 `Eastings: 562,102 ~ Pad E/evation 59.0' AMSL Location at Top of Productive Interval West Sak "A-3" Sand 375' FNL, 2,257' FEL, Section 11, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 8,117' Northings; 5,969,834 Eastings: 558,740 Total I/erticalDe th RKB: 3 910' Total vertical De th, SS.• 3,811' Location at Total De th 181' FNL, 2,423' FEL, Section 14, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB.' 13,168' Northings: 5,964,748 Eastings: 558,619 Tota/ I/ertica/De th, RKB.• 3,860' Total ~ertica/ De th, SS.• 3,761' and (d) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) Ifs wet/ is to be intentionally deviated, the app/icatron for a Permit to Dri// (Farm 10-401) must 1C-172A-1L PERMITIT.doc Page 2 of 7 Printed: 22-Jan-OS ~.. • Appli~ for Permit to Drill, Well 1C-172A-1 L Revision No.O Saved: 22-Jan-08 (i) include a p/at, drawn to a suitab/e scale, showing the path of the proposed wellbore, including al> adjacent wellbores within 200 feet of any portion of the proposed we/I; Please see Attachment 1: Directional Plan 1C-172A-1L and (Z) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those we/ls, to the extent that those names are known or discoverab/e in pub/ic records, and show that each named operator has been furnished a rnpy of the application by certified mai/; or (B) state that the applicant is the on/y affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified m the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as appficab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1C-172A-1L. 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 app/ication for a Permit to Drill must be accompanied by each of the following items, except far an item a/ready on file with the commission and identified in the application: (4) information on drilling hazards, inducting (A) the maximum downhale pressure that maybe 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 1C 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 1,274 psi, calculated thusly: ~' MPSP = (3,860 ft TVD)(0.44 - 0.11 psi/ft) = 1,274 psi (B) data on potentia! gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of hole prob/ems such as abnorma//y geo pressured strata, Jost circu/anon zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-172A-1L Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on F/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); No formation integrity test is planned for the iC-172A-L1 lateral in the A-3 due to the test was previously performed on the A-2. 1C-172A-1L PERMITIT.doc Page 3 of 7 Printed: 22-Jan-08 Appli~ for Permit to Drill, Well 1C-172A-1 L Revision No.O Saved: 22-Jan-08 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drit/ must be accompanied by each of the fa!/owing items, except far an item already on fi/e with the commissian and identified in the app/ication; (6) a complete proposed casing and cementing program as required by 20 AAC 15, 030, and a descriptian of any slatted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top etm 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 Already in place Already in place 9 5/8 12 ~/a" 40 L-80 BTC 3460 40 / 40 - 3,500 /2,442 Cemented +/-500' above the 7 5/8 8 ~/z" X 9 7/8" 29.7 L-80 Hydril 513 8317 40 / 40 .8,400' / 3,944', UGNU (Bi-center bit) 414 sk of 12 ppg DeepCRETE 4-1/2 6 3/4" A-2 Sand 12.6 L-80 BTC 4969 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 5051 8,117'/ 3,910' 13,168' / 3,860' Slotted- no cement Slotted Lateral (iC-172A L1 4-1/2 6 3/4"A-4 Sand 12.6 L-80 BTC 5518 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 appicatian for a Permit to 17ri1/ must be accompanied by each of the fo//awing items, except for an item a/ready on ale with the cammission and identified in the application; (7) a diagram and description of the diverter system as required by 20 AAC25.035, unless this requirement is waived by the commission under ZO AAC 25.035(h)(2); N/A 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to t7rilt must be accampanied by each of the fo!/owing items, except far an item a/ready an hle with the commission and identifed in the application; (8) a dri/ling t7uidpragram, including a diagram and description of t/re dri//mg 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 1C-172A-1L PERMIT IT.doc Page 4 of 7 ,~ ~ ~ ~ ~ ~) R ~ Printed: 22-Jan-08 Appli~ for Permit to Drill, Well 1 C-172A-1 L Revision No.O Saved: 22-Jan-08 Density Plastic Yield Point HTHP Fluid Oil/V1later Ratio- Electric Stability (ppg) Viscosity (cP) loss (ml/30 min (Ib/100sf) 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/r"cat/on for a Permit to ©ri/! must be accompanled by each of the fo/%wing items, except for an item a/ready on fife wr"th the Comm/ssion and identified in the application: (9) for an exploratory or stratigraphic test we/% a tabulation setting out the depths of predicted abnormal/y geo pressured strata as required by 20,4AC25.033(>]; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Dri!/ must be accompanied by each of the following items, except far an item already on file with the commission and identified in the application: (10) for an exp/oratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 20 RRC 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//cat/on for a Permft to ©ri/1 must be accompanied by each of the fo/%wing /terns, except for an item a/ready on file with the commission and identified in the application: (11) far a well dri/!ed from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20 AAC25.OS1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app//cation far a Permit to /7r/// must be accompanied by each of the fo/%wing items, except for an item a/ready on fr/e wit/t the Comm/ssion and identiled in the app/ication: (12) evidence showing that the requirements of 20 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 Dri// must be accompanled by each of the fo/%wing items, except for an item already on fr/e with the commission and identified in the app/ication: The proposed drilling program is listed below for the A-3 Lateral. Please refer also to Attachment 4, Well Schematic. 1. Run and set Baker Gent WindowMaster whipstock system inside the 7 5/8" intermediate casing at +/- 8,117' MD / 3,910' TVD, the top of the A-3 sand. 2. Mill 6 3/4"window. POOH. 3. Pick up 6 3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 4. Drill to TD of A-3 sand lateral at +/- 13,168' MD / 3,860' TVD, as per directional plan. 5. Back ream out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pull out of hole. 3~ 1C-172A-1L PERMITIT.doc Page 5 of 7 Printed: 22-Jan-08 Appli~ for Permit to Drill, Well 1 C-172A-1 L Revision No.O Saved: 22-Jan-08 6. PU and run 4 1/z" slotted liner, drop liner in open hole, POOH 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. . 8. PU and run 4-1/2" hook wall hanger. r ~~S Et ~~ ~-- 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. 11. 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. 13. Pickup 6 3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool.. RIH. 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. Pull 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 app/ication for a Permit to ©ri!/ must be accompanied 6y each of the fal/aw/ng items, except for an item a/ready on fi/e with the commission and identified in the application: (14) a genera/ description of how the operator plans to dispose of drit/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAG 25.080 for an annu/ar disposa/ operation in the we/%; 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 ~"~, ~ ~O`r ~~@ ~ Printed: 22-Jan-08 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Applic~for Permit to Drill, Well 1C-172A-1 L Revision No.O Saved: 22-Jan-08 1C-172A-1L PERMIT IT.doc Page 7 of 7 Printed: 22-Jan-08 .. _.: ~~ Operator: ConocoPhillips (Alaska) Inc.-Kupl Surface Location: 5968801.43 N 562101.96 E Well: IC-172A L.1 (~=p08) Grid Coordinate System: North American Datum 1927 ~"~~r,.~..(~'i(.~~,'T`(~N Field: Kuparuk River Unit Grid Convergence: Alaska. Zone 4 Rig: Doyon 141 Vertical Section Plane: 180.00° RKB Height: 99.1 ft '3Perry C'lrilling service Date; 18-Tan-08 Unwrapped Displacement: 11371.87 DDI: 7.036 SVh !V1D lnc Arim. SSTVD `I'VD 'S1-S E/-W 1 Y DLS V.S. Comments # (ft) ('Deg) (Deg) (ft1 (ft) (ft) (ft) (ft) (ft) °/100ft (ft) 1 40.(10 0.00 0.011 -59.10 40.00 0.00 N O.OO E 562101.96E .5968801.43 Al 0.00 0.00 2 15<90 0.16 315.00 57.80 756.90 0.12 N -0.1.2 562101.84E 5963301.54N O.14 -1).12 CB-GYRO-SS (1) 3 277.90 1.25 26.1)0 178.79 277.89 1.42 N 0.34E 562102.29E 5968802.85 N 1.00 -1.42. 4 401.9 2.39 36:29 302.72 40L82 4.72 N 2.4`7 E 562104.39E 79668.06.17 N 0,95 -4.72 MWD+IFR-AK-CAZ-SC (2) 5 490.85. 2.61 30.94 391.59 490.69 7.95 N 4.61E 562106.50 E 5966609.42 N 0.36 -7.95 6 581.4(1 4.26 27.22 481.98 581.06 12.71 N 720E 562109.06E 5966614.20 N 1.84 -12:71 7 .671.23 5.90 24.61 571.45 670.55 19.88 N 10.65E 562112,45E >966821.39 N 1.84 -19.88 8 762.35 8.53 16:02 661.84 760.94 30.56 N 14.70E 562116.40E 5968632.11 N 3.02 -30.5h 9 852.31 11.70 14.76 7.50.39 849.49 45.73 N 19.08E 562120.66E 5968847.31 N 3.58 -45.73 10 942,77 12.70 10.82 838.81 937.91 64.37 N 23.29E 562124.71E 596$865.98 N 1.44 -64.37 11 .1032.38 15.64 . L05 925.70 1024.30 86.13 N 25.36 E 562126.61E 59686$7.75 N 4.22 -86.13 12 1127.13 19.91 351.25 1015.92 1115.02 114.86 N 23.14E 562124.15E 5963916.47 N 5.49 -114.66 13 .1223.35 21.43 346.42 1104.08 1203.18 147.46 N 16.65E 562117.40E 5968949.00 N 2.42 -147.46 14 1313.86 2L18 341.57 1190.28 1239.38 179.74 N 7.40 E 562107.88E 596896L20 N 1.92 -)79.74 15 1405.99 26.12 335.05 1274.65 ,1373.75 214.36 N -5.45 ~~ 562094.75E 5969015:72 N 5.57 -214.36 16 150127 33.63 335.74 1357.21 1456.;1 257.94 N -24.16 ~w 562075.69 L 5969059.13 N 7.97 -257.94 17 1593.06 35.67 335.01 1432,72 15,1.82 305.37 N -45.91 ~ 562053.55E 5969106.36 N 2.27 -305.37 18 1.685.73 40.07 334.36 15(15.85 1604.95 356.78 N -70.23 ~ 562028.81E 5969157.58 N 4.77 -356.78 19 1778.69 44.74 33 L67 1574.63 1673.73 412,71 N -93.78 ~ 561999.81E 596921327 TAT 5.38 -412.71 20 1872,29 50.50 330.33 1637.56 1736.66 473.01 N -132.24 ~~ 561965.85 E 5969273.23 N 6.26 =473.01 21 1964.53 53.61 328.47 1694.27 1793.37 535.60 N -169..23 Vv 561928.30E 5969335.55 N 3.73 -535,60 22 2056.98 56.75 326.71 1747A6 1846, i h 599.65 N -209.97 ~ 561887.09E 5969399.26 N 3.74 -599.65 23 21499? 66.46 324:51 1791.23 1890.33 667.02 N -256.18 W 561840.34E 596946625 N 10.65 -667.02 24 2242,58 67.44 325.15 1827.49 1926.59 736.68 N -305.26W 561790.70 E 5969535.49 N 1.23 -736.66 25 2335.66 66.78 325.57 1863.70 1962.80 807.23 N -354.OOW 561741.38E 5969605.63 A~ 0.82 -807.23 26 2423.22 66.75 326.52 1900.21 1999.31. 877.78 N -401.51 ~w 561693.30E 5960675.76 N 0.94 -8'77.76 27 2521.11 64.45 324.33 1938.59 2037.69 947.43 N -449:49 W 561644.75E 596974503 N 3.28 -947,43 28 2615,10 63.51 323.94 1979.82 : 2078.92 1015.88 N -498.98 w 561594.72E '5969813:06 N 1.07 -101'.°3 29 2707.10 62.50 324.15 2021.58 ?120.68 1082.24 N -547.7.1 W 561546.04 E 5969879.01 N 1.12 -108" ~~ 30 2500.78 64.21 3?3.38 2063.59 2162.69 1149.77 N -596.60 561496.00E 5969946.13 N 1.97 -ll49,77 31 2892.1)3 67.26 323.39 2101.45 ?200.55 1217.19 N -646.70 t4 561445.36E 5970013.13 N 3.31 -1217.19 32 2965.54 68.00 324.42 2136.70 2235.80 1286.39 N -697.15 C~ 561394.34E 5970031.90 N 1.30 -128r3~~ 33 ;076.47 66.03 320.60 2173.00 2272.10 1354.27 N -7=19.13 ~ 561341.76E 59711149..34 N 4.34 -135-+._' 34 3I7L.18 66.09 321.65 2210.62 2309.72 1420.23 N -802.37 ~ 561288.04 E 5970214.6h N lA4 -1420.23 35 3264;02 65.93 323.72 2248.37 2347.47 1487.24 N -654.37Vv 561235.50E 597028].43 N 1.07 -1487.24 36 33.57.30 66.16 323.91 2286.24 2365.34 1555.60 N -905.30 W 561184.02E 597034-9.36 N 1.19 -1555.60 37 3450.65 66.32 ;23.79 2323.85 2422.95 1624.59 N -955.70Vv 561133.06 E 5970417.92 N 0.21 -)624.59 • Page 1 of 5 .: •`~y ~;LL j 5~~~' ~'ID Inc Azim, SSTVD ?~'D Vii`-~ E/-~l' k Y DLS ~%.S. Canuuents # jf't} (Deg) (Deg) (ftj {ft) (ft) (ft) (ft) (ft) °ll00ft (ft) 38 3.500.00 6690 321.58 2343.44 2442,54 1660.61 N -983.16 Vv 561105.31E 5970453.71 N 4.27 -1660.61 39 350020 6690 321.58 2343.52 2442.62 1660.75 N -9x3.27 W 561105.19E 5970453.86 N 0.00 -1660.75 9 5/8" TOW - MWD+IRR-AK-CAZ-SC (3) 40 3600.00 66.90 322.58 2382.68 2481.78 1733.17 N -1039.68 ti~ 561048.20E 5970525,80 N 0.92 -1.733.17 41 3650,00 66.90 323.08 2402,29 250L39 1769.82 N -1067.47 W 561020.11E 5970562.22 N 0.92 -1769.82 42 3700.00 66.90 323.08 2421.91 252L01 1806..59 N -1095.09 V1' 560992.19E 5970598.75 N 0.00 -1806._59 43 3800.00 66.90 323.08 2461.14 2560.24 1880.13 N -1150.35 ~ 560936.34 E 5970671.83 N 0.00 -1880.13 44 3900.00 66.90 323.08 2500.37 2599.47 1953.67 N -1205.60 ~ 560880.49E 597074490 N 0.00 -1953.67 45 4000,00 66.90 323.08 2539.61 2638.71 2027.21 N -1260.85 ~ 560824.64E 5970817.98 N 0.00 -2027.21 46 4100.1)0 6690 323.08 2578.84 26?7.94 2100.74 N -1315.10 W 560768.79E 5970891.05 N 0.00 -2100.74 47 4200.00 66.90 323.04 2618.07 2717.17 2174.28 N -1371.;6 ~~ 560712.95E 5970964.13 N 0.00 -2174.28 4R 430U,Ot) 66.90 323.04 2657.30 2756.40 2247.82 N -1426.61 titi 560657.10 E 5971037.20 N 0.00 -2247.82 49 -1400.00 6690 .323.08 2696.53 2795.63 2321.36 N -J 48J .86 Vv 560601.25 E 5971110.Zt3 N 0,00 -2321;36 50 4500.00 66,90 323.08 2735.77 2834.87 2394.90 N -1537.11 W 560545.40E 597114335 N 0.00 -2;94.90 51 4600:00 6690 323.08 2775.00 2874.10 2468.44 N -1592.36 ~ 560489.55 E 5971256.43 N 0.00 -2464.44 52 4700.00 66.90 323.08 2814.23 .2913 ;3 2541.98 N -x,47.62 ~ 560433.70E .5971329.50 N OAO -25.41.94 53 472(1.00 66.90 323.08 2822.08 2921.18 2556.69 N -1658.67 560422.53 E 5971344.12 N 0.00 -2556.69 54 4800.00 66.98 318.28 2853.41 2952.51 2613.62 N -170529 W 560375,45 E 5971400.65 N 5.52 -2613.62 55 4900.00 67.08 312.24 2892,44 2991.54 2679.01 N -1770.05 ~~ 560310.16E 5971465.50 N 5.52 -2679;01 56 5000.00 67.18 306.24 293130 3030.40 2737.32 N -144134 W 560238.41 E 5971523.22 N 5.53 -2737.32 57 5100.00 67.28 30024 2970.00 3069.1ti 2787.89 N -1918.39 ~ 560160.95E 5971573.16 N 5.53 -2747.89 58 5200.00 6738 294.28 3008.54 3107.64 2830.17 N -2000.36 ~ 560078.64E 5971614.75 N 5.54 -2830.17 59 5300.00 67.48 244.28 3046.92 3146,02 2863.67 N -2086.36 559992.38E 5971647.54 N 5.54 -2463.67 60 5400.00 67.58 242.28 3085.14 3.I 84.24 2888.01 N -2175.46 ~ 559903.09 E 5971571. I5 N 5.55 -2488.01. 61 5500.00 67.68 276.28 3123.20 3222.30 290292 N -2266.69 bV 559811.76 E 5971685.31 N 5.55 -2902.92 62 5600.00 67.78 270,28 3161.09 3260.19 2908.21 N -2359.04 W 55971938 E 5971689.4%1 N 5.55 -2904.21 63 5700.110 67.88 254,.28 3198.83 3297.93 2903.82 N -2451.50 VW 559626.97 E _5971684.69 N 5.56 -2903:82 64 5800:00 67.98 258.24 3236.40 3335.50 2889.78 N -2543,06 559535.54E 5971669.90 N 5.56 -2559.'?8 65 5900.00 68.08 . 25228 3273.81 3372:91 2866.23 N -2632.71 ti4 559446.09E 5971645.62 N 5.56 -2.466.2; 66 6000.00 68.18 246.28 3311.06 3410.16 2833.41 N -2719.47 Z~ 559359.61E 5971612.(19 i~ 5.57 -283.3.41 67 6100.00 68.28 240.28 3348.14 3447.24 2791.68 N -2802.39 W 559277.05E 597156).68 N 5,57 -2791.63 68 6200.00 6838 234.28 3385.07 3484.17 2741.47 N -2880.54 55919932 E 5471518,44 N 5.58 -2741.7 69 6300,00 68.48 .228.28 3421.83 3520.93 268332 N -2953.07 ~ ,559127.28E 5971460,1 i 1vr 5.58 -2683.32 70 6400.00 68,58 2__ _. 3458.43 3557.53 2617.87 N -30i9.16~ 559061.73E 5971394.13 N 5.58 -2617.87 71 6500:00 68.68 21 n.2t~ 3494.87 .3593.97 2545.82 N -307R.09~ 559003.40E 5971321:60 I~ 5.59 -2545:82 72 6600.00 68.78 210.24 3531.14 363024 2467.95 N -312).21 ~~ 558952.94 E 5971243.33 N 5.59 -24Ci795 73 6.684.02 68.87 205.00 3562.94 36~2.0~{ 2395.27 N -3167.27 ~ 558915.47E 597 L170.34 N 5.60 -2395.27 ?4 6700.00 6938 205.33 3567.20 366630 2385.14 N -3172.03 558910,80 E 5971160.77N SA0 - 3~~~.1-t 75 6760,57 72.00 206.94 3587.23 368(,.33 2333.83 N -3197.21W 558886.05E 5971108.66N 5.00 -23:13.83 76 ~7882h 72.00 20694 3595.78 3694.85 231035 N -3209.14 ~ 55887431E 5971085.10N O.OU -?311.35 77 r>,00.00 72.21 .206.36 359939 3698.49 230036 N -3214,15.-41 55886938E 5971075.07 N 5.00 -~ ,~?n .,~, 78 6900.00 74A8 201.52 362839 3727.49 2212.92 N -325296 W 55883130E 8970947.32 N 5.00 -2212.92 • Page 2 of 5 4,~_v.~ €`~, ,..~..,, ,..~ SVT 1Rb Inc Aim. SST4'D T~'D ~l-S E/-~V ti ]" DLS ti'.S. Com~iients ~ (~? (Deb) (~~~g) (Fr) (t~t) (ft) (ft) (fr) (f'e) °l100ft (fe) 79 7000,00 76.06 196.76 3654.17 375327 2121.66 N -328=1.61 ~4 558800.40E 597(1895.81 ~! 5,00 -2121.6E 80 7100.00 78.13 192.09 3676.52 3775.62 2027.29 N -3308.87 W 558776.92E 597080126 N 5.00 -2027.29 81 7200,00 80.27 187.49 3695.27 379437 1930.53 N -3335.56 W 558761.03 E 5971170437 N 5.00 -1930.53 82 7300.00 82.47 182.95 3710.29 3809.39 1832.10 N -3334.54 W 558752.86E 5970605.89N 5.00 . -1832.10 83 732L09 82.94 182.0(7 3712.96 3812.06 1811.20 N -3335.44 ~w 558752.13E 597058498N 5.00 -1811.20 84 74(10.00 82.94 182.00 3722.66 3821.76 1732.94 N -3338.18 w 558750.04 E 5970506.71 N 0.00 -1732.94 85 7471.09 82.94 1.82.00 3731.40 3830.50 1662.43 N -3340.64 ~w 558748.15E 5970436.19 N 0.00 -1662.43 86 7=182:30 82.94 18197 3732.78 3213LR8 1651.31 N -334L03 V~~ 558747.86E 5970325.07 N 0.25 -1651.31 1C-172A MB_A3 Heel (12-19-07) 87 750Q00 82.94 ] 81,93 3734.95 3534.05 1633.76 N -3341.62 W 558747.41E 5970407.52 N 0.25 -1633.76 88 760Q00 82.94 181.67 3747.24 384634 1534.56 N -3314.'74 W 558745.11 E 597030831 N 0.25 -1534,56 89 7700.00 82.94 181.41 3759.53 3858.63 143536 N -3347.41 W 558743.25E 5970209.10 N 0.25 -1435.36 90 7800.00 82,94 181.16 3771.82 3870.92 1336.14 N -3349.64 ~ 558741.84 E 597010y.88 N 0.25 -13,6,14 91 7900.00 82.94 180.90 3784.10 3883.20 1236.91 N -3351.42 558740.87E 5970010.65 N 0.25 -1?36.91 92 80E10.00 82,95 180.65 379638 . 3895.48 1137.68 N -3352.76 W 55874034E 5969911.42 N 0.25 -1137 fib 93 805237 82.95 180.51 3802.81 3901.91 1085.71 N -3353.29 ~~ 558740.24E 5969859.46 N 0.25 -1085.71 94 8100.00 82.95 180.51 3808.66 3907.76 1038.44 N -3353.71 V. 558740.21E 5969812.19 N 0.00 -1038.44 T'ie-On 8117.00 82.95 180.51 3810.75 ..3909.85 1021.57 N -3353.86 ~y 558740.20E 5969795:32 N 0.00 -1021.57 2 8117.01 82.95 180.51 3810.75 3909.85 1021.56 N -3353,86 ~ 558740.20E 59E,979531 N 0.01 -1021,56 L1: 7 5/8" TOW cz; 8117' MD, 3910' TVD; 415' RNI 3 8121.03 83.59 180.51 3811.22 391(132 1017.57 N -335390 558740.19E 596979133 N 15.92 -1017.57 10-172A MB_A3 Tl (12-19-07) 4 8125.00 84.22 180.51 381 L64 3910.74 1013.62 N -3353.94 t 558740.19E '5969787.38 N 15.92 -1013.62 5 8L29.00 84.86 180.51 3812A2 3)11.12 1009.64 N -335397V~~ 558740.19E 5969783.39 N 15.90 -1009.64 6 8159.00 84.86 186.51 3814.71 3913..81 979.76 N -3354.24 W 558740.17 E .5969753.52 N 0.00 -979,76 7 8204.011 86.07 180.67 3817.95 3917.05 938.89 N -3354.6E Vv 558740.08E 5969712.65 N 3.00 -938.89 8 8300.00 89.05 181.06 3822.21 3921.31 839A1 N -3356.18 W 55873938E 5969612.77 N 3.00 -839.01 9 8400.00 92.02 181.45 3821.27 3920,37 739.05 N -3358..37 w 558738.01E 5969512.81 N 3.00 -739.05 10 8436.75 93.12 181,.60 3819.62 3918.72 702.35 N -335935 ~~ 55873734E 59694'76.11 N 3.00 -702.35 11 5500.00 93.12 t8L60 3816.18 391528 639.22 N -336110~h 558736.10E 596941297 N 0.00 -639,22 12 .860{1.00 93.12 181.60 3810.74 3909.84 539.40 N -3363.88 ~'v 558734.14E 5969313.15 N 0.00 -539.40 13 8700.00 93.12 181.60 3805.31 3904.41 439.59 N -3366.66 by 558732.18E 59E~9213.33 N 0.00 --139.59 14 ~ 8759.33 93.12 181.60 3802.08 3901.18 380.32 N -3368.31 W 558731.02E 59691.54,05 N 0.00 -380.32 15 8785.06 92.11 181.37 3800.91 3900.01 354.67 N -336R.98W 558730.56E 5969128.40 N 4.00 -354.ti7 1C-172A MB_A3 T2 (12-19-07) 16 8800:01) 91.53 18124 3800.43 389y.53 339.75 N -336932 ~ 55873035E 5969113.48 N 4.00 -339.75 17 .8822.30 90.66 18105 3800.00 3899 t0 317.45 N -3369.77 u~ 558730.08E 5969091.18 N 4.00 -317.45 18 890b.00 90.66 .181.05 3799.11 3598 21 239.77 N -3371.19 ~ 55872930 E 5969Q13:50 N 0.00 -239."" 19 9~i00.00 90.66 181.05 3797.96 ,x97.06 139.80 N -3373.02W 558728.29E 596R913.53N 0.00 -l3'~ 8f'~ 20 `>u'230 90.66 181.05 3797.70 ;96.80 117.50 N -3 ~, 7.43 W 558728.06E 596~~`11..23 N 0.00 -11~.>!~ IG172AMB_A3 T2 (12-17-07) 21 9100.00 91.99 1 ~~ L,~6 3795.90 3~s95,0(~ 39.85 N -3375.40 t~ 558726.73 E ti96~`~ l x.58 N 2.00 3' ~.`~_~ 22 9113.89 92.23 182.00 379539 . 3894.49 25.98 N -3375.87 ~ti 55872638 E 59687y9.7t1 N 2.00 ?5.98 23 9200.00 92.23 182.00 3792.05 3891.15 -60.01 S -3378.87 Z 558724.08E 5968713.70N 0.00 6D.01 24 9300.00 92.23 182.Of1 3788.16 3887.26 -159.88 S -3382.3'6 558721.41E 5963613.82 N 0.00 159.88 25 94i~0.00 92,23 182.00 3784.28 388338 -259.74 S -3385.85 Vv 558718.75E 5968513.95 N 0.00 259,74 26 9422.(,6 92.23 182.00 3783.40 388~.7(T -28237 S -_ ~~~~.~~~ Vu 558718.14E 596849131 N 0.00 282.37 1C-172AMB A3 T3 (12-19-U7) ~~ Page 3 of 5 ..,,~ .,:..~ .m. _ _:~'' ~_~~' S~'P SID Inc Azim. SSTF'D T'ti'D ~l-S EI-11' k ~' DLS '<'.S. C`ottutie~tts # (ft) (Deb') CDeg) (2't) (ft) (ft) (ft) (t't) (ft) °/lOUff (ft) 27 9500.00 39.91 182.92 378196 3331.06 -359.65 S -3389.28 R 558716.14 E 5968414.03 N 3.00 359.65 28 9519.72 8932 1.81.$9 3782.09 3881.19 -37936 S -3389.93 ~ 558715.64 E 59683943/ N 3.00 379.36 29 9600:00 8932 181.89 3783.05 3882.15 -459.59 S -3392.59 u 558713.65E 5968314.08 N 0.00 459,59 30 9700.00 8932 281.89 3784.25 3883.35 -559.52 S -339590 t4 558711.16E 5963214.23 N 0.00 559.52 31 980{1.00 8932 181,89 3785.44 3884.54 -659.46 S -3399.20 W 558708.68E 5968114.18 N 0.00 659.46 32 9900.00 8932 .182.89 3786.63 3885.73 -759.40 S -3402.51 ~~ 558706.19E 5968014.23 N 0.00 759.40 33 10000.00 89.32 181.89 3787.83 3586.93. -85934 S -3405.81 ~~ 558703.71E .5967914.28 N 0.00 85934 34 1002296 89.32 181.89 3788.10 3887.20 -882.29 S -3406.57 tw 558703.14 E 5967892 33 N 0.00 882.29 2C-172A MB_A3 T4 (22-19-07) 35 10100.18 90.86 182.00 3787.98 3887.08 -959.46 S -3409.20 ~•' 558701.15E 5967414.24 N 2.00 959.4h 36 1020Q00 90.86 182:Ot) 3786.49 3885,59 -1059.21 S -3412.69 W 558698.48E 5967714.38 N 0.00 2059.21 37 10300.0f) 90.86 182.00 3785.00 3884.10 -1159.13 S -3416.18 ~ 558695.80E 5967614.44 N 0.00 1159.13 38 10400.00 90,86 i 82.00 3783.50 3882.60 -2259A6 S -3419.68 W 558693.13E 5967514.50 N 0.00 1259.06 39 2h500.00 90.86 182.40 3782A2 3881.11 -1358.99 S -3423.13~V 558690.45E 596741:1.56 N 0.00 2358.99 40 10600.00 90,86 18200 3780.51 3379.61 -1458.92 S -3426,67 W 558687.78E 5967314.62 N 0.00 ]453.92 41 10700.00 90.86 282.00 3779.01 3873.21 -1558.84 S -3430,179>u 558685.10E 5967214.63 N (1.00 1558.84 42 108OQ00 90.86 232,00 3777.52 3876.62 -1658.77 S -3433.66w 558682.43 E 596'7ll4.74 N 0.00 1658.77 43 10900.00 90.86 132.00 3776.02 3875.12 -1758.70 S -3437.26 ~ 558679.76E 5967014.80 N 0.00 1758.70 44 11000.00 90.86 182.0(1 3774.53 3873.63 -1858.63 S -3=440,6(1 Z~ 558677.08E 5966914.8E, N OAO 1858.63 45 12100.00 90.86 18200 3773.03 3872.13 -1958,55 S -3444.15~V 558674.41E 5966824.91 1V O.OU 1958.55 46 11200.00 90.86 .182.00 3772.54 3870.64 -2058.48 S -3447.65 `~i 558671.73E 596671497 N 0.00 2458.43 47 11222.63 90.86 18200 3772.20 3$70.30 -2082.20 S -3448.44 W 558671.13E 596669236 N Q00 2081.10 2C-172A MB_A3 T5 (12-29-07) 48 11?36.63 90.22 282.10 3770.60 3869.70 -2245A5 S -3450.73 55866936 E 5966628.39 N 2.00 2145,05 49 ll300.00 90.22 182.10 3770.54 3869.61 -2158.42 S -3451.22 ~~ 558668.98E 5966615.0; N 0.00 2258.4:2 50 11400.00 90.22 132.2f) 3770.15 3849.25 -225834 S -3454.8'8 W 558666.14E 5966515.08 1`,T 0.00 .2258.34 52 11500.00 90.22 ]2;2.10 3769.76 3868.86 -2358.28 S -3458.54' 55866330 E 59fi6415.13 N 0.00 2353.28 52 11600.00 9Q22 182.10 376937 3868.47. -2458.21 S -3462.21 ~r 558660.46E 5966325.29 Al 0.00 2458.21 53 l 1'700.00 90.22 282.10 3768.98 3868.08 -2558.24 S -3465.87 W 558657.62E 5966215.24 N 0.00 2558,14 54 11800.00 90.22 . 182.20 3768.59 3867.69 -2658.07 S -3469.53 Vv 558654.78E 5966115.29 N 0.00 265$.07 55 11822.94 90.22 182:.20 3768.50 3367.60 -2680.99 S -3474:37 W 558654.22E 596609237 N 0.00 268099 1C-272A MB_A3 T6 (12-28-07) 56 11840.74 9034 181.96 3768.42 3867.52 -2698.78 S -3471.01 ~>v 558653.64E 5966074:58 N 2.00 2698.73 57 1190{).00 90.34 18296 3768.06 386?16 -2758.02 S -3473.03 'W 558652.20E .5966015.34 N 0.00 2758.0.1 58 .12000.00 90.34 2819(, 3767.48 3866:53 -2857.95 S -34'76.46 ~ 558649.50E 5965915.39 N 0.00 2857.E?5 59 [210UA0 9034 181.96 3766.89 3865.99 -2957.89 S -3479.88 ~ 558646.89E 5965815.44 N 0.00 2957:89 60 42200.40 9034 18 1.96 376630 3865.40 -3057.83 S -343331 ~ 558644.29E 5965715.49 N 0.00 . 305" ~' 62 12300.00 9034 21.96 3765.71 3864.81 -3257.77 S -3486.73 `~ 558642.69E 5965625.53 N 0.00 . 315Z~, 62 12400,00 9034 1 ~~ 1.96 3765.22 3864.22 -3257.71 S -3490,15 ll 558639.09E 5965515.58 N 0.00 3257J1 63 12500.00 90.34 ]~I.96 3764.53 3863.63 -3357.65 S -3493.58 ~~ 558636.49E 5965415.63 N 0.00 3357.65 64 12600.00 9034 1 ~~ 196 3763.94 38~> .~r4 -3457.59 S -3497.00 W 558633.88E 5965315.68 N UAU 3457.59 65 ('700.00 9034 1 ~ 1 96 376335 33~~:.-15 -3557.53 S -35(N).42 W 558631.28E 5965215.72 Id 0.00 X557.53 66 12800.00 90.34 1 ~~ I .gab 3762.76 3861,86 -3657.47 S -3503.85 R 558628.68E 5965215.77 N 0.00 3657.47 67 12900.(xT 90.34 1,82.96 3762.18 3861,28 -3757.42 S -3507.27 558626A8 E 5965015.82 N 0.00 3757.42 68 13000.00 90.34 28296 3761.59 ~t~r,~~.~,9 -385735 S -3510.70b 558623.47 E 5964915.87 N 0,00 385".~ Page 4 of 5 SVl' #~ 1ID (ft) Inc (Deg) A~inx. (Deb) SSTVI) (ft) T~`D (ft} ~l-S Eft) E~-«' (ft) k (ft) 5~ (ft) I>L~S °IIfiUft ~`.S. (I't) Comments 69 70 71 13100.00 13166.56 131.67.54 9U.34 90.34 90.34 181.96 18196 1.81.96 3761.00 3760.61 3760.60 3860,10 3R_59.71 • 3859.70 -3957.29 S -4023.80 S -4024.79 S ,3514.12W -3516.40 ~ -3516.43 W 558620.87E 558619.14E 558619.11E 590481591 N 5964749.39 T~ 596=1748.41 N 0.00 O,oo 0.00 1957.29 4033.80 4023,79 4 112" - MWD (4) Ll: 4 1/2" Liner @ 13168' MD, 3860' TVD; 181' FN • i Page 5 of 5 Vertical Section Plot Section Distance Plan View Plot 5973000 5972000 5971000 5970000 5969000 5968000 5967000 5966000 5965000 5964000 ~-- 558000 558500 559000 559500 560000 560500 561000 561500 562000 1 C-172 ~ targets 1 C-172A (wp08) 1 C-172A L1 (wp08) -- -1 C-172A L2 (wp08) 562500 ~J 1C-172A~ Drilling Hazard~Summary (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 weight, backreamin to clean hole Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumpin out, backreamin 1C-172AL1 Drilling Hazards Summary.doc prepared by Steve Shultz ~..~ 1/15/08 r ~ 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 TOW of the A4 sand @ 7,646' MD " 3,852' TVD ~`'~ ~~' 9 5/8' Intermediate Casing ~~ ~' ''~ `,: 13,164' TD A4 Lateral 3,796' TVD \ `C,- ~+l a ~ ~ 13,168' TD A3 Lateral TOW of the 3 sand .~. -__- _ -_-_-__- _- _- -_ _- 3,860' TVD 117' MD 3,910' tv , A2 Sand -_ _ 3,914' TVD Top of A-2 --- Liner @ +/-8,150' 4 1/2", 12.6#, L-80, BTC Liners slotted and blank 7 518" shoe @ 8,400' MD 3,944' TVD ORIGfNAL • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~- l ~" ~ ~~~~ PTD# ~~ ~_ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: `-c_- ,c~GL.~! ~`v~ ` POOL: cvP-~S ~ ©tc \ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS W~-r (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /C~~ 0~' ~~Z--~ ' (If last two digits in permit No. Z-~g -Q7g, API No. 50- Gz9-~-~. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/I (/2008 WELL PERIWIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 WeILName: KUPARUK RIV U WSAK 1C-172AL1 Program DEV Well bore sag ^~ PTD#:2080090 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal Administration 1 Pe[mitfee attached- - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - ~ 2 Lease number appropriate- _ _ . _ _ - _ _ _ - _ _ - - _ - - _ _ _ _ _ _ _ _ Yes _ Surface and top prod interval in At?l• 25649; TD in northermost-portion ofADh26650_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 UniquBwell_nameandnumber------ - -- -- - - - --- Yes -- --- - - - - - ---- - - - - - -- - 4 Well located in edefined-pool____________________________ ________Yes__ ___KUparukRiver,West$akOilPool-49Q150,-governed by CO 40613___--__--______-________ 5 -1Nell located proper distance from drilling unit_boundary_ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ CO 4058, Rule 3; no restrictions as-to well spacing except that no_pay shall be gpened in a well closer - _ - _ _ _ _ 6 Well located proper distancefrom other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ than 500 feet to-an exte[naLproperty line where ownership-or landownership changes. - - - - - - - - - - _ _ _ _ _ _ _ 7 Sufticientacreageavailable in-drilling unit_ _ _ _ _ - . _ _ - - _ _ _ _ _ - _ _ Yes - - - _ _ - Well is more than-500 feet from an external property line. _ _ _ - - _ _ - _ _ _ _ _ - _ _ _ _ _ - _ _ - _ _ _ 8 If_deviated,iswellb4repl$t-included_______--________________ _________ Yes___ ______-__- -------------------------------------------------------------- 9 Operatotonlyaffectedparb'---- - ---- -- -- -- - -- - - -Yes -- --- - - -- - -- -- - -- - --- --- 1D Operator has_appropriate bond in force - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - 11 Permitcanbeissuedwithouiconservationorder----.______--__._ _--____--Yes--- --------------------------------------------------------------- - Appr Date 12 PermitcanbBissuedwitbouiadministrative_apptoval---------------- ---------Yes--- -----------,-------------------------------------------------------- SFD 112412008 13 Can permit beaARrovedbefcrel4-dayv~it-------------------- --------Yes--- ------------------------------------------------------------------ i 14 1Nelllocatedwithinareaartd-strataauthcrizQdby_InjeCtionOrder#(puti9#in-comments)(For- NA____ ________________--_________-________________________-______-_______ ~ 15 All wells-within 114-mile arse of Ceyiew identified (For service wail only) - - - - N_A- - - - - - - - - - - - - - - 16 Pre•producedinjector;durationofpra-production lessthan$months-(For servicewelionly)__NA____ _____________________________________________-__-__--__-______-___-____ 17 Nonconyen, gas cpnforms3o AS3.1,0$.03QfL1.A)~(G2.A-D) - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - Engineering 16 Conductor string-provided_____--__.___-__--____-__-_-_ __------ NA---_ ----Con_duciorsetin1C•172(_203.095).--------------------------------------- -_-_ 19 Surfacec8singprotectsallknownUSDWs______________________ _________ NA ___ ___Allaquifersexempted,40CFR-147.1Q2(b)(3).-______--__---____--__--________-___ 20 CMTvoladequate-tccitculateon-ccnductor&surf-csg______--__-_ ________NA____ ____Surfarecasing setin_1O.172,-----__________________________________-______ 21 CMT_votadequate-totie•inlcngatringtosurfcsg______--------_ -________ NA____ ____Production-casing set in-1Cr172A(20$-0Q@)___________________-__--___-____._______ 22 CMT wilt coverall knownplrodtrGtivehorizorts_____________________ __________N_o____ ____Sl4tledlinercomplQtionplanned,-____-_____________--_____--_--__--________ 23 Casing designs adequate for G, ~ 6 & permafrosi- - - - - - - - - - - - - - - - - - - - _ _ _ NA_ _ _ O[iginal well_and redrill met design-specifications._ NA for slotted liner._ - _ - _ _ _ . - _ - - _ _ _ _ _ _ _ 24 Adequate tankaga_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ -Rig equipped with steel pits, Nolesenre pit planned.- Alt waste_to approved disposal well(s), _ _ _ - - _ _ _ 25 Ifa_re~dril[,has-at0~4D3forabandonmentbeenapproved_-_----___ -__-- NA--_- ________-_____--________-_________--____-------------- ----- 26 Adequate wellbore ssparatjon proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ Traveling cylinder path calculated.- Nearest segment is A~ segment 30' - 5Q'tvd-deeper._ _ - - - - - - - - - - _ _ _ _ 27 Ifdverterrequired,doesit_meetregulati9ns____----____________ ________ NA____ ____BOPSiackwillal[eady_beinplaca,_--____--_-________-__________--___________ Appr Date 28 Drilling fluid-program schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ Maximum expected formation pressure-$,4_EMW._ MW planned 8.4.8.5ppg. - - _ _ . - _ _ - _ _ - - _ _ _ _ TEM 112512008 29 BOPEs, do theymeetregulation - - - - - - - - - - - - - - - - - - YeS - - - - - - - - - - - - - - - - - - - - - - - - (~„ , A ~ v 30 BOP):_ptess rating appropriate; test ko_(pui psis in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated x11274 psi, $K stack arrangement and BOP test planned._ - _ _ _ - _ _ - - _ _ _ _ _ _ - - _ _ _ _ _ , I,H' %y ~ 6R 31 Choka_manifold comRlies wIAPI_RP-53 (_May $d) - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - t V 32 Work will occurwhhoutoperaiicnshutdown-------------------- --------Yes--- -------------------------------------------------------------------- ~33 I& pr®sence of H2S gas probable _ - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -Yes _ _ _ _ _ _H2S is teported-in 1C WS-wells.- Mud-should preclude-H2S on ng._ Rig equipped with sensors and-alamis,_ _ _ 34 MachanicalcondhiorlofwellswithinAORveri1ied(Forservicewellonlya_____ -_______ NA_--_ ____--__________________________.________-_---------------.--------- t3eology 35 Pemlitcan be issued win hydrogen sulfide measures _ - _ - _ _ _ _ _ No_ _ - _ 1C-Pad West Sak wells measure from 4 to-170 PPM-H2S, Precautions are-advisable, _ - - _ _ _ _ _ _ _ _ - 36 Data-presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ F.Xpected reservolrpressure is 8,4-ppg EMW; prod interval will be drilled with 6,4 to t3.5 ppg oil-base _mud, - Appr Date 37 Seismlcanalysiscfshallowgas_zones_______________________ _______NA--- --__Mutilateral---____ ---------------------------------------------------- SFD 112412008 38 Seabedcondjtionsurvey_(rfoff•shore)__________--_-- - - - - - - - ~A- --------------------------------~------------------ - - - - 39 Coniactnamelphoneforweekly_progressreporfsCexploratoryonty)-------- --- ----NA__- --_----___--__-____--_______-_______________--______-_ -- Geologic Engineering Publ' Data: Date Date Multilateral producer targeting the Wesi Sak A3 interoal. Anticoliision is a concern here. This wellbore will pass within 250' of Commissioner: o fission Co m er ~~~~~~ l Z~'~~ l' three nearby wells. ~o- QCP 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. 1C172AL1004182008SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu ]un 12 16:28:16 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 LI5 Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/06/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LI5 writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: 1C-172A L1 API NUMBER: 500292315960 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 12-JUN-08 JOB DATA 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 5 MWD RUN 6 Job NUMBER: w-0005476893 w-0005476893 LOGGING ENGINEER: R. WILSON R. WILSON OPERATOR WITNESS: M. THORTON F. HERBERT SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: l0E FNL: 1436 FSL: FEL: FWL: 1096 Page 1 ~-(~ ~ l Cs~ ~c~ 1C172AL1004182008SSN.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 7819.0 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 WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7819'MD/3888'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 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 2,3,6 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 RUN 6. 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 1-3,5,6 REPRESENT WELL 1C-172A L1 WITH API#: SO-029-23159-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13102'MD/3851'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. Page 2 1C172AL100418200855N.txt 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.......5T5LI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM FET RPD 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 13053.0 13060.0 13060.0 13060.0 13060.0 13060.0 13102.5 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 BIT RUN NO MERGE TOP MERGE BASE 1 3513.5 3549.0 2 3549.0 3620.0 3 3620.0 7819.0 5 7819.0 7853.0 6 7853.0 13102.5 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 Page 3 r: 1C172AL1o04182008SSN.txt Name servi ce 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3505 13102.5 8303.75 19196 3505 13102.5 RPD MWD OHMM 1.22 2000 20.4988 19105 3508 13060 RPM MWD OHMM 0.47 2000 22.9291 19105 3508 13060 RPS MWD OHMM 3.38 2000 21.8556 19105 3508 13060 RPX MWD OHMM 2.88 2000 20.6861 19105 3508 13060 FET MWD HR 0.14 283.28 1.93249 19105 3508 13060 GR MWD API 5 126.27 70.2426 19097 3505 13053 ROP MWD FPH 0.27 506.52 189.697 19179 3513.5 13102.5 First Reading For Entire File..........3505 Last Reading For Entire File...........13102.5 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... .......STSLIB.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.......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 Page 4 ~ ~ 1C172AL10041820085SN.txt LOG HEADER DATA DATE LOGGED: 31-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 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 (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 Page 5 1C172AL1o0418200855N.txt 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 TyPe ................L0 Next File Name...........STSLIB.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.......STSLIB.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 RPM 3508.0 3567.5 RPx 3508.0 3567.5 FET 3508.0 3567.5 RPS 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): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 6 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 • 1C172AL100418200855N.txt 65.7 67.0 BOTTOM) TOOL TYPE TOOL NUMBER DUAL GAMMA RAY 250050 ELECTROMAG. RESIS. 4 230203 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 9.875 3513.0 Fresh water Gel 9.00 53.0 9.5 500 9.0 .000 .0 .000 59.0 .000 .0 .000 .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 First Last Name service unit Min Max Mean Nsam Reading Reading Page 7 • ~ 1C172AL1o0418200855N.txt 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.......08/06/12 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.......5T5Li6.003 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 7819.0 RPx 3568.0 7819.0 RPM 3568.0 7819.0 RPS 3568.0 7819.0 RPD 3568.0 7819.0 GR 3576.5 7819.0 RoP 3620.5 7819.0 LOG HEADER DATA DATE LOGGED: 04-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): Page 8 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DG R EwR4 1C172AL1004182008SSN.txt 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 ROP MwD030 FPH 4 1 68 28 8 Page 9 ~ ~ 1C172AL100418200855N.txt First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3568 7819 5693.5 8503 3568 7819 RPD MWD030 OHMM 3.38 102.98 13.1065 8503 3568 7819 RPM MWD030 OHMM 3.16 89.64 12.0667 8503 3568 7819 RPS MWD030 OHMM 3.38 112.34 11.9215 8503 3568 7819 RPX MWD030 OHMM 3.86 113.12 11.3352 8503 3568 7819 FET MWD030 HR 0.27 11.18 0.971263 8503 3568 7819 GR MWD030 API 5 126.27 71.4322 8486 3576.5 7819 ROP MWD030 FPH 4.72 506.52 146.257 8398 3620.5 7819 First Reading For Entire File..........3568 Last Reading For Entire File...........7819 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 ................LO 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.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH OP 7819.0 7853.0 $ LOG HEADER DATA DATE LOGGED: 15-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 10 1C172AL1004182008SSN.txt MINIMUM ANGLE: 83.9 MAXIMUM ANGLE: 84.8 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): 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 Mineral oil Base 9.30 54.0 .0 155000 .0 .000 .0 .000 .0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD050 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7819 7853 7836 69 7819 7853 ROP MWD050 FPH 0.69 50.06 10.3951 69 7819 7853 First Reading For Entire File..........7819 Last Reading For Entire File...........7853 Page 11 i 1C172AL1o0418200855N.txt File Trailer Service name... .......STSLIB.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.......STSLIB.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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 7819.5 RPD 7819.5 GR 7819.5 FET 7819.5 RPM 7819.5 RP5 7819.5 RoP 7853.5 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 13060.0 13060.0 13053.0 13060.0 13060.0 13060.0 13102.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 18-APR-08 Insite 74.11 Memory 84.8 93.8 TOOL NUMBER 87225 159436 6.750 Page 12 ~ ~ 1C172AL1004182008SSN.txt DRILLER'S CASING DEPTH (FT): 7819.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (5): 58.0 MUD PH: ,0 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 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 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 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7819.5 13102.5 10461 10567 7819.5 13102.5 RPD MWD060 OHMM 1.39 2000 24.766 10482 7819.5 13060 RPM MWD060 OHMM 1.88 2000 31.768 10482 7819.5 13060 RPS MWD060 OHMM 3.97 2000 29.857 10482 7819.5 13060 RPX MWD060 OHMM 3.73 2000 28.2118 10482 7819.5 13060 FET MWD060 HR 0.14 283.28 2.41859 10482 7819.5 13060 GR MWD060 API 35.04 110.69 69.5317 10468 7819.5 13053 ROP MWD060 FPH 2.53 392.52 227.738 10499 7853.5 13102.5 First Reading For Entire File..........7819.5 Page 13 1C172AL10041820085SN.txt Last Reading For Entire File...........13102.5 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 ................L0 Next File Name...........STSLIB.007 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 writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/12 0ri9in ...................5T5 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
