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208-008
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 13,101 feet N/A feet true vertical 3,915 feet N/A feet Effective Depth measured 13,068 feet 6,985', 7,455', 7,926', 7,961'ft true vertical 3,915 feet 3,785', 3,851', 3,901', 3,905'ft Perforation depth Measured depth 8,487'-8,568'; 8,570'-10,239'; 10,410'-12,602'; 12,773'-13,028'feet True Vertical depth 3,945'-3,946'; 3,946'-3,927'; 3,929'-3,911'; 3,912'-3,915'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 3,915 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. 320-289 263 Size 3,600 8,261 5,146 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-172A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-008 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 13,072 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 11:50:57 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson By Samantha Carlisle at 9:50 am, Aug 06, 2020 SFD 8/10/2020 VTL 8/11/20 RBDMS HEW 8/6/2020 DSR-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. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1C-172A lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Jet Pump, Closed CMU, & Installed GLD 7/23/2020 1C-172Azembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 110.0 Set Depth (TVD)… 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE Post S/T OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 40.1 Set Depth (ftKB) 3,640.2 Set Depth (TVD)… 2,501.0 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-M Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.80 Top (ftKB) 49.1 Set Depth (ftKB) 8,310.0 Set Depth (TVD)… 3,939.3 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd 513 Casing Description WINDOW L2 OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 7,357.0 Set Depth (ftKB) 7,367.0 Set Depth (TVD)… 3,841.2 Wt/Len (l… 29.70 Grade L-80 Top Thread Casing Description WINDOW L1 OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 7,820.0 Set Depth (ftKB) 7,830.0 Set Depth (TVD)… 3,890.1 Wt/Len (l… 29.70 Grade L-80 Top Thread Casing Description WINDOW A OD (in) 7 ID (in) 6.00 Top (ftKB) 3,513.0 Set Depth (ftKB) 3,523.0 Set Depth (TVD)… 2,452.4 Wt/Len (l… 29.70 Grade L-80 Top Thread Casing Description AL2 Liner LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 6,984.9 Set Depth (ftKB) 7,236.0 Set Depth (TVD)… 3,828.3 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 6,984.93,784.9 75.82 PACKER ZXP LINER TOP PACKER 4.950 7,003.9 3,789.5 76.12 SBE BAKER SEAL BORE EXTENSION 190-47 4.750 7,023.6 3,794.2 76.42 XO BUSHING CROSSOVER BUSHING 3.950 7,060.0 3,802.4 77.40 NIPPLE CAMCO DB-6 NIPPLE 3.750 7,096.6 3,810.0 78.93 HANGER LEM ABOVE HOOK HANGER 4.000 7,103.4 3,811.3 79.28 HANGER LEM INSIDE HOOK HANGER 3.688 7,232.7 3,828.0 84.71 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description AL2 Liner HH OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,354.7 Set Depth (ftKB) 7,608.0 Set Depth (TVD)… 3,867.6 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,354.7 3,840.084.36 HANGER BAKER B-1 HOOK HANGER INSIDE 5.630 7,371.0 3,841.6 84.25 HANGER BAKER B-1 HOOK HANGER OUTSIDE 3.980 7,472.63,852.883.72 ECP PAYZONE EXTERNAL CASING PACKER 3.960 7,577.1 3,864.2 83.68 BENT JT BENT SIB 4.000 Casing Description AL1 Liner LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,455.2 Set Depth (ftKB) 7,964.0 Set Depth (TVD)… 3,905.1 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,455.2 3,850.9 83.55 PACKER ZXP LINER TOP PACKER 4.950 7,474.2 3,853.0 83.74 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 7,493.9 3,855.1 83.94 XO BUSHING CROSSOVER BUSHING 3.980 7,810.0 3,887.9 83.94 HANGER LEM ABOVE HOOK HANGER 4.000 7,817.5 3,888.7 83.87 HANGER LEM INSIDE HOOK HANGER 3.688 7,887.13,896.4 83.44 NIPPLE CAMCO 'DB-6' NIPPLE 3.563 7,960.7 3,904.8 83.87 SEAL ASSY BAKER SEAL ASSEMBLY 3.910 Casing Description AL1 Liner HH OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,818.3 Set Depth (ftKB) 8,082.1 Set Depth (TVD)… 3,917.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,818.33,888.883.87HANGER H292-71-1026; 1018217155.600 7,835.0 3,890.6 83.75 HANGER H292-71-1026; 101821715 3.980 7,940.4 3,902.6 83.57 ECP H301-37-2402; 101800984; Payzone ECP - Shear Valve 2600 psi, Control Valve 575 psi 3.930 Casing Description LINER A OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,925.9 Set Depth (ftKB) 13,072.0 Set Depth (TVD)… 3,915.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,925.93,900.983.36 PACKER ZXP HRD LINER TOP PACKER 4.970 7,944.9 3,903.1 83.64 NIPPLE RS PACKOFF SEAL NIPPLE 4.870 7,947.83,903.4 83.68 HANGER FLEX LOCK LINER HANGER 4.850 7,957.6 3,904.5 83.82 SBE 190-47 CASING SEAL BORE EXTENSION 4.740 7,976.5 3,906.4 84.09 XO BUSHINGCROSSOVER BUSHING3.890 Tubing Strings Tubing Description TUBING 2017 RWO String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 35.8 Set Depth (ft… 7,265.0 Set Depth (TVD) (… 3,831.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-m Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 35.835.80.00 HANGER Vetco Tubing Hanger C2057135-2 (4-½" x 10-¾" IBTM)3.900 6,757.7 3,714.8 68.68 Sliding Sleeve (Closed) Baker CMU (CLOSED-7/21/2020) 3.812 7,241.0 3,828.7 84.60 LOCATOR GBH-22 Locator Sub (Bottom of Locator Spaced Out 4') 3.870 7,242.2 3,828.8 84.58 SEAL ASSY Baker 20' GBH 22 Seal Assembly total length 22.81' 3.870 1C-172A, 7/23/2020 6:36:10 PM Vertical schematic (actual) LINER A; 7,925.9-13,072.0 SLOTS; 12,773.0-13,028.0 SLOTS; 10,410.0-12,602.0 SLOTS; 8,570.0-10,239.0 SLOTS; 8,487.0-8,568.0 INTERMEDIATE; 49.1-8,310.0 AL1 Liner HH; 7,818.3-8,082.1 AL1 Liner LEM; 7,455.2-7,964.0 WINDOW L1; 7,820.0-7,830.0 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 Sliding Sleeve (Closed); 6,757.7 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 KUP PROD KB-Grd (ft) 33.39 Rig Release Date 6/24/2003 1C-172A ... TD Act Btm (ftKB) 13,101.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292315901 Wellbore Status PROD Max Angle & MD Incl (°) 92.75 MD (ftKB) 9,285.83 WELLNAME WELLBORE Annotation Last WO: End Date 1/27/2017 H2S (ppm) 90 Date 8/12/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,487.0 8,568.0 3,945.6 3,946.0 WS A2, 1C- 172A 4/13/2008 32.0SLOTS 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 8,570.0 10,239.0 3,946.0 3,927.6 WS A2, 1C- 172A 4/13/2008 32.0SLOTS 10,410.012,602.03,928.7 3,911.2 WS A2, 1C- 172A 4/13/2008 32.0SLOTS 12,773.0 13,028.0 3,911.6 3,914.8 WS A2, 1C- 172A 4/13/2008 32.0SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Ty pe Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 3,407.1 2,406.2 CAMCO KBMG 1 GAS LIFT GLV BTM 0.188 1,554.0 7/23/2020 2 6,688.6 3,689.1 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 7/23/2020 Notes: General & Safety End Date Annotation 8/17/2008 NOTE: VIEW SCHEMATIC w/AlaskaSchematic9.0 5/9/2008 NOTE: WELL SIDETRACKED TO 'A', AL1, AL2, NEW PROD CSG 1C-172A, 7/23/2020 6:36:12 PM Vertical schematic (actual) LINER A; 7,925.9-13,072.0 SLOTS; 12,773.0-13,028.0 SLOTS; 10,410.0-12,602.0 SLOTS; 8,570.0-10,239.0 SLOTS; 8,487.0-8,568.0 INTERMEDIATE; 49.1-8,310.0 AL1 Liner HH; 7,818.3-8,082.1 AL1 Liner LEM; 7,455.2-7,964.0 WINDOW L1; 7,820.0-7,830.0 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 Sliding Sleeve (Closed); 6,757.7 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 KUP PROD 1C-172A ... WELLNAME WELLBORE 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 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): 13,101 N/A Casing Collapse Conductor Surface Production Liner 12. Attachments:Proposal Summary Wellbore schematic 13. W ell 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 Authorized Signature: 7/23/2020 13,0725,146 4.5" 3,915 Perforation Depth MD (ft): 8,487'-8,568'; 8,570'-10,239'; 10,410'-12,602'; 12,773'-13,028' L-80 70 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 3,600 11016 TVD 3,9397 5/8 8,310 9 5/8 7,265' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25638 2,501 N/A Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY Size Burst 110 1,019 208-008 COMMISSION USE ONLY Authorized Name: P.O. Box 100360, Anchorage, Alaska 99510 50-029-23159-01 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 KRU 1C-172A 3,915 13,101 3,915 3,945'-3,946'; 3,946'-3,927'; 3,929'-3,911'; 3,912'-3,915' Tubing MD (ft): m n s 66 tc 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 320-289 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 17:55:24 Foxit PhantomPDF Version: 9.7.0 Stephanie Thomson ADL0025650 DLB DLB 07/08/2020 DSR-7/8/2020 10-404X -00 DLB X VTL 7/15/20 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 17:55:45 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. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ - ~ Q~ Well History File Identifier Organizing (done) RESC N olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: ~ Maria Production Scanning Stage 1 Page Count from Scanned File:~_ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ `~ / ~ © /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s Il I I I ~I II I II II I 1 II Scanning is complete at this point unless rescanning is required. ReScanned (I I II II I) I I III (IIII BY: Maria Date: /s/ Comments about this file: Quality Checked III (IIII) III IIII II wo-sided IIIIIIIIIIIIIIIIIII DI ITAL DATA Diskettes, No. ^ Other, No/Type: Date: a„v~~~ara iuium~imiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ Date: iiiiuuuuiiim ~P x 30 = ~ + ~ =TOTAL PAGES (Count does not include cover sheet) narP• I ~~l n ///1 /s/ 10/6/2005 Well History File Cover Page.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1C-172A Run Date: 7/17/2010 August 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-172A Digital Data in LAS format, Digital Log Image file N., , 1 CD Rom 50-029-23159-~ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ~~ ~ ... Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.woodnhalliburton com Date: ~~: ~~~ '~~,l, Signed: ~ . ~c~~~~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1C-172A Run Date: 7/17/2010 • August 11, 2010 o,r ~~~ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-172A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23159-00 c~~ °`- " ~'`a~v PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.woo 1' o Date: Al1G ~ ~.2~1 ~A Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 .~ ~ .~. , RE: Packer Setting Record: 1C-172A Run Date: 7/ 14/2010 July 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-172A Digital Data in LAS format, Digital Log Image file 50-029-23159-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE; TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ~a~ `~~~. /`~~y~- rafael.barreto . .~~~ ~ ?' r Date: Df~ . y~.~ Signed: DATA SUBMITTAL COMPLIANCE REPORT 1 /14/2009 Permit to Drill 2080080 Well Name/No. KUPARUK RIV U WSAK 1C-172A Operator CONOCOPHILLIPS ALASKA INC MD 13101 ND 3915 Completion Date 5/12/2008 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA iNF~RMATION Types Electric or Other Logs Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number .Name pt LIS Verification v€D C Lis 16499 rlnduction/Resistivity f=D D Asc Directional Survey Directional Survey 'vLog Induction/Resistivity y!t/o~ Induction/Resistivity TED C 16716 See-Nvtes r~-- /~-- I'ED C Pds 16912 Production tyLog Production QED C Pds 16913~9arveq~'lisC Sp«~~r r/Log Sufbzp-f~c Tp ~ ~......~- i l _ ---_-- __ _ _ _ . _ __--- --- -- Well Cores/Samples Information: Name Samples No API No. 50-029-23159-01-00 UIC N Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 3508 13101 Open 6/24/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 3508 13101 Open 6/24/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX, ROP 0 13101 Open 6/24/2008 ' 0 13101 Open 6/24/2008 II 25 Col 3513 13101 Open 8/8/2008 MD ROP, DGR, EWR 25 Col 2448 3915 Open 8/8/2008 ND, DGR, EWR -6- " ~A- 6 t~ ~ 8/8/2008 ND and MD for EWR logs j 35 / 1 ~ 3i0.~ in PDS, EMF and CGM graphics 100 7900 Case 9/17/2008 PPL w/MaxTrac 19-Aug- 2008 j 5 Blu 100 7900 Case 9/17/2008 PPL w/MaxTrac 19-Aug- 2008 30 7230 Case 9/17/2008 GLS, FBHP, Pres, Temp, Gradio, Spin 19-Aug-2008 25 Blu 30 7230 Case 9!17/2008 GLS, FBHP, Pres, Temp, Gradio, Spin 19-Aug-2008 i Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 1 /14/2009 Permit to Drill 2080080 Well NamelNo. KUPARUK RIV U WSAK 1C-172A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23159-01-00 MD 13101 TVD 3915 Completion Date 5/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? ~ "V Daily History Received? N ~ @~ N Chips Received? Formation Tops T Analysis /1 N Received? Comments: Compliance Reviewed By: _ ___ Date: •i •i • :~~ `~; y ~ PROACTIVE DIAGNOSTIC SERVICE5~ (NC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of'this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey '130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 05-0ct-09 1 C-172 1 Report / Elm 50-029.23159-01 2) ~~~--~~ l'6~~~Oy _ _ _~_ , Signed : Date Print Name: PROACTIVE DIA<3NOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RO SUITE C, ANCHORAGE, AK 99518 PHONE: (907j245-8951 FAX: (907j245-88952 E-MAIL : ,.__ _ __ .:~ WEBSITE : _ . C:\Documen~s and Settings\OwnedDeskfop\Transmit_Conow-dog Mem©ry MuItNF'Inger Caliper Log Results Summary -.-~~ !, Company: ConocoPhillips Alaska, Inc. WefC 1C-172A ', Log Date: October 5, 2009 Field: West Sak Log No.: 10593 State: Alaska '~ ' Run No.: 2 (MIT) API No.: 50-029-23159-01 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBT-M Top Log Intvll.; Surtace Pipet Use: Tubing Bot. Log lntvl1.: 6,760 Ft. {MD) i Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of G4M 2 ~ 6,692' (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing logged is in goad condition wikh no significant wall penetrations, areas of cross-sectional wall loss or LD. restrictions recorded. This is the second time a PDS caliper has been run in this welt. The caliper recordings indicate a change in tubing completion in the time between the current and previous log (March 15, 2008). 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 11 %) are recorded throughout the tubing logged. 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3°r6) are recorded throughout the tubing logged. 4.5" TUBING -MAXIMUM RECORDED 1D RESTRICTIONS: Na significant I.D. restrictions are recorded throughout the tubing logged. Field Engineer: G. Etherton Analyst: C. Waldrop Witness: C. Kennedy ProACtive Diagnostic Services, Inc, J P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (8$8} 565-9085 Fax: (281} 565-1369 E-mail: PDS(~~memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Pipe 1 Correlation of Recorded Damage to Borehole Profile 4.5 in (23.2' - 6747.3') Well: 1 C-172A Field: West Sak Company: Conoco Phillips Alaska, Inc. Country: USA Survey Date: October 5, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 23 778 50 1550 75 2314 100 3076 ~ v GLM 1 ~ _' ~ ~ .S Z s •0 125 3856 Q 150 4627 175 5396 200 6163 GLM 2 `i 218 6747 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottorr~ of Survey = 218 PDS Report Overview ~~~- S~. Body Region Analysis Well: 1 C-172A Survey Date: October 5, 2009 Field: West Sak Toot Type: UW MFC 24 No. 212330 Company: ConocoPhiAips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 IBT-M 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 250 - 200 5 1 0 0 10 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal s ed total = 226 pene. 6 217 3 loss 155 71 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 GLM 1 GLM 2 Bottom of Survey = 218 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey pate: ELATION SHEET 1 C-172A West Sak ConocoPhillips Alaska, Inc. U5A October 5, 2009 Joint No. Jt. Depth (Ft) I'e~n. Utnc~t (Ins.) Pen. Body (Ins.) Pen. `;4, Metal L~>ss `io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 23 a 0.01 3 I 3.96 1.1 54 t~ 0.01 2 I 3.96 PUP 1. 62 t i 0.01 3 1 .97 UP 2 72 t ~ 0.02 3.93 3 102 ~ ~ 0.01 ? 1 3.93 4 133 (~ 0.01 3 I 3.97 5 162 l~ 0.01 4 I 3.92 6 192 t ~ 0.01 2 I 3.96 7 224 U 0.01 3 1 3.94 8 254 0 0.01 2 I 3.96 9 285 ~? OA1 i 1 3.95 10 316 U 0.0 2 I 3.95 11 347 ~ ~ 0.01 I 3.96 12 378 n 0.01 ~ 3.94 13 408 ~.~ 0.01 ~ I 3.94 14 438 ~? 0.01 4 I 3.89 15 468 U 0.01 1 3.95 15.1 499 tI 0 0 t) 3.88 4.5" Camco DB-Ni le W 3.875" Profile 16 501 [) 0.01 3 1 3.96 17 532 t) O.U1 3 1 3.94 18 563 t) 0.01 Z I 3.93 19 594 t) Q01 ; I 3.95 20 625 t~ 0.01 4 I 3.96 21 656 (~ 0.01 ? I 3.95 2 687 t ~ 0.01 ~ 1 3.96 23 716 i_~ 0.01 4 i 3.95 24 748 `a 0.01 3 I 3.9 25 778 t? 0.01 3 I 3.94 26 809 t! 0.01 2 I 3.97 27 840 O 0.01 6 I 3.93 28 871 (1 0.01 ~ I 3.95 29 901 a 0.01 3 I 3.95 30 932 ~~ 0.01 4 1 3.95 31 964 a 0.01 4 1 3.96 32 995 I ~ 0.01 ~ 1 3.94 33 1027 t) 0.03 10 S 3.95 34 10 8 O 0.01 2 1 3.95 35 1089 U 0.01 3 1 3.94 36 1119 U 0.01 (3 1 3.95 37 1151 i) 0.01 Z 1 3.95 38 1181 t) 0.01 ,! I 3.93 39 1212 U 0.01 t> I 3.93 40 1243 O 0.01 4 I 3.94 41 1272 U 0.01 -3 I 3.96 42 1301 t i 0.01 ~ 1 3.96 43 1334 a 0.02 t3 3.95 44 1366 U 0.01 4 3.96 45 1396 ~ ~ 0.01 3 1 3.96 46 1427 t~ 0.01 ? 3.96 47 1458 ~.? 0.00 1 s ~ 3.93 Ton Mash. ,Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf I -80 IBT-M Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ELATION SHEET 1 C-172A West Sak ConocoPhillips Alaska, Inc USA October 5, 2009 Joint No. )t. Depth (FL) Nc~n. Ut~si~t (Ins.) Pen. Body (Ins.) Pen. % ~ic~tal I ~~ss °~~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1489 t) 0.01 2 1 "3.93 49 1519 O 0.01 ? I 3.95 50 1550 t i 0.01 4 I 3.95 51 1580 t) 0.01 ~ I 3.89 52 1612 t) 0.01 Z I 3.95 53 1643 t) 0.03 IU ~ 3.95 54 1674 O 0.01 ~ I 3.95 55 1704 i) 0.00 I ~ ~ 3.95 56 1736 t) 0.01 3 I 3.93 57 1766 t> 0.01 2 i 3.95 58 1796 O 0.03 11 t 3.93 59 1827 t) 0.01 E~ I 3.95 60 1856 l) 0.01 a I 3.96 61 1888 i) 0.01 2 I 3.94 62 1919 t) 0.02 t3 3.93 Ton Mash. 3 1947 U .01 ~ 3.95 64 1979 U 0.00 I ~ ~ 3.87 65 2006 t? 0.02 - 3.92 Ton Mash. 66 2038 i) 0. 1 ~' I 3.93 67 2069 +) 0.01 Z I 3.95 6 2101 U 0.03 10 ~ 3.94 69 2131 t) 0. 1 2 1 3.94 70 " 162 t) 0.01 2 1 3.95 71 2193 n 0.01 Z 1 3.95 72 2224 l) 0.01 Z I 3.88 73 2253 U 0.02 i _' 3.94 74 2283 U 0 02 ') ~' 3.92 Ton Mash. 75 2314 O 0.01 3 1 3.94 76 2344 O 0. 1 2 1 3.96 77 2375 n 0.03 lf) 3.93 78 2405 O 0.01 2 I 3.94 79 2435 t) 0.01 I 3.94 80 2465 t) 0.01 1 3.93 81 2496 U 0.01 (~ I 3.95 82 2527 tl 0.01 I .91 83 2558 i) 0.01 ? 1 3.94 84 2589 t) 0.01 ~ 1 3.88 85 2619 O 0.01 3 1 3.95 86 2648 t) 0.01 a 1 3.94 87 2678 i) 0.01 3 1 3.96 88 2708 U 0.02 7 2 3.94 89 2739 U 0.02 Fi 2 3.94 90 2769 t) 0.01 ~ 1 3.94 91 2799 O 0.01 I 3.95 92 2830 U 0.01 ~' i 3.93 93 2860 ~) 0.01 _' I 3.93 94 2891 t) 0.01 I 3.94 95 2922 U 0.01 _' 1 3.93 96 2953 ~) 0.01 ~t I 3.95 97 2983 U 0.01 3.94 Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 IBT-M Welf: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ELATION SHEET 1 C-172A West Sak ConocoPhillips Alaska, Inc. USA October 5, 2009 Joint No. Jt. Depth (Ft.) I'cn. L11»c~t (InS.) Pen. Body (Ins.) Pen. % Metal I oss `;~, Min. LD• (Ins.) Comments Damage Profile f% Wall) 0 50 100 98 3014 U 0.01 3 I 3.94 99 3045 t ~ 0.01 2 I 3.94 100 3076 t} 0.01 2 I 3.95 101 3105 t) 0.03 1 U ~ 3.91 102 3136 tl 0.01 ~' I 3.93 103 3167 (~ 0.0 _' 3.93 104 3198 U 0.02 6 ~' 3.94 105 3228 t~ 0.01 I 3.95 10 3259 t~ 0.02 9 .' 3.96 107 3290 U 0.01 3 1 3.95 108 3320 tl 0.01 ? 1 3.93 109 3352 U 0.02 ~) ~' 3.95 109.1 3383 ti 0.00 I t! 3.94 PUP 1 9.2 3389 (t 0 t) i1 N A GLM 1 L tch ~ 1 :30 109.3 3396 U 0.01 ; 1 3.93 PUP 110 3401 U 0.01 Z 1 3.95 111 3432 U 0.00 1 U 3.92 112 3463 11 0.0 7 ? 3.9 113 3494 t I 0.02 t3 _' 3.94 114 3524 U 0.01 4 I 3.94 115 3552 tt D.01 4 1 3.87 116 358 t; 0.03 ! 1 3.95 117 3612 i1 0.01 ~ I 3.92 118 3645 t) 0.02 8 ? 3.95 119 3673 t~ .03 10 ~ 3 9 120 3703 t~ 0.01 ~' 1 "3.96 121 3734 a 0.02 8 2 3.94 122 3765 t1 0.03 10 ~ 3.94 123 3797 t ~ Q02 7 ~' 3.92 124 3826 t? 0.01 ~' 1 3.95 125 3856 t! 0.01 1 I 3.96 126 3887 t~ 0.01 i I 3.94 127 3917 t7 0.0 1 i7 ~ 3.95 128 3947 (! 0.03 ~_) ~' 3.93 129 3978 a 0.03 !ti s 3.96 130 4008 U 0.01 3 I 3.93 131 4039 U 0.01 3 I 3.94 132 4069 U 0.02 8 ~' 3.94 133 4099 t~ 0.01 4 I 3.91 134 4131 !_~ 0.02 7 3.88 135 4164 U 0.01 ~' i 3.92 136 4195 t) 0.01 3 i 3.96 137 4226 U 0.02 9 3.93 138 4256 to 0.01 ? I 3.95 139 4286 it 0.01 ~' I 3.9 140 4316 t ~ 0.02 f3 ~' 3.94 141 4347 t, 0.02 ~1 _' 3.88 142 4379 t? 0.02 i 3.95 143 4411 t ! 0.01 I 3.88 144 4443 ~' 0.01 i I 3.91 _ Penetration Body Metal Loss Body Page 3 ~- PDS REPORT J OINT TABUL ATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: 1C-172A Body Wall: 0.271 in Field: West Sak Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: October 5, 2009 Joint No. Jt. Depth (Ft.) Ncn. UI>,et (Ins.) Pen. Body (Ins.) Nen. °4, :Vic~t.il Los, °~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 45 4474 n 0.01 ? 1 3. 4 146 4504 U 0.03 1 t) 3 3.92 147 4536 U 0.02 7 ' 3.95 148 4566 i ~ 0.00 1 ~' 3.94 149 459 U 0.03 l U 3.90 Ton Mash. 150 462 7 t) 0.01 4 I 3.92 15 4658 t) 0.0 7 _' 3.89 152 4689 l~i 0.01 3 I .90 15 4720 U 0.0 9 ~ 3.93 154 4752 t) 0.02 8 3.93 1 5 4783 0 0.02 7 :' 3.91 156 4814 U 0 01 1 1 3.94 157 4846 i ~ 0.01 2 I 3.93 158 4877 ti 0.01 Z i 3.94 159 4907 i ~ 0.03 1 U 3.94 160 4940 t) .03 1 U i 3.92 161 4971 U 0.02 f3 _' 3.86 T n Mash. 16 5002 t~ 0.03 lU ~3 3.93 163 5032 U 0.01 ? I 3.94 164 5062 a 0.0 7 ~ 3.86 Ton M h. 165 509 t) 0.01 Z 1 3.88 166 5122 ! ~ 0.01 2 I 3.93 167 515 t) 0.0 t3 3.92 Ton Mash. 168 5183 t) 0.01 ~ 1 3.94 169 5214 U .0 t3 ' ~ 3.9 170 5244 U 0.03 1l) ; 3.87 Ton Mash. 171 5 73 t) 0.01 2 1 3.93 172 5304 O 0.01 ~ 1 3.94 173 5335 U 0.0 1 t) 3 3.92 174 5366 ! ~ 0.01 4 1 3.94 75 539 t) 0.0 ti ~ 3.93 176 542 6 c) 0.01 2 1 3.93 177 5457 t) 0.03 1 t) ~ 3.94 178 5488 U 0.01 3 1 3.94 179 5518 t) 0.03 it) 3 3.91 180 5548 r ~ 0.01 ~ 1 3.94 181 5579 a 0.01 l 1 3.94 182 5610 i) 0.03 1(~ ; 3.93 183 564 t ~ 0.01 .} 1 3.95 184 5671 i) 0.01 I 3.93 185 5703 U .03 ~) ~' 3.88 Ton h. 186 5733 U 0.01 3 I 3.94 187 5763 O 001 Z I 3.94 188 5794 U 0.03 l U 9 3.85 Ton Mash. 189 5823 U 0.01 Z I 3.95 190 5855 t ~ 0.01 3 1 3.94 191 5886 (~ 0.03 10 3 3.90 Ton Mash. 192 5917 (~ 0.01 .1 1 3.94 193 5948 ~ ~ 0.02 {) 3.92 1 4 5977 t ~ Q01 3.92 Penetration Body Metal Loss Body Page 4 PDS REPORT J OINT TABUL ATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT-M Well: 1C-172A Body Wall: 0.271 in Field: West Sak Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 5, 2009 Joint No. Jt. Depth (Ft.) I'c~n. llpsc•t (Ins.) Pen. Body (Ins.) PE>n. % ~1ct,il Lass `%~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 195 6008 a 0.01 2 I 3.94 196 6038 t) 0.01 3 1 3.88 197 6070 t) 0.02 9 ~ 3. 9 198 6101 a) 0.02 c) 3.93 199 6132 a 0.02 ti 3.93 00 6163 U 0.01 -1 1 3.92 201 6192 ~) 0.01 1 I 3.92 202 6223 U 0.01 l 1 3.93 203 6253 U 0.02 t3 ~ 3.90 204 6285 t) 0.01 3 I 3.93 205 6316 ! i 0.01 2 1 3.95 206 6347 ~ i 0.02 9 3.94 207 6377 U 0.01 ? I 3.95 2 8 6408 ~ i 0.01 ? I 3.9 209 6438 ~ i 0.03 ci ~ 3.88 210 6471 ~ ? 0.01 2 I 3.83 211 6500 U 0.02 ti ? 3.91 12 6532 U 0.03 I O i 3.85 Ton Mash. 213 6563 ti 0.01 2 1 3.95 214 6595 ~ ~ 0.01 ? 1 3.94 215 662 5 ! ? .03 1 t) ~ 3.89 Ton Mash. 216 6656 (? 0.02 ti 3.95 216.1 6685 ~~ 0.03 11 3.92 PUP 216.2 6692 t) 0 u t) N A GLM 2 Latch @ 10:30 16.3 6700 ~) 0.01 .1 I 3.96 PUP 217 6705 ii 0.01 ,_' I 3,95 217.1 6736 (a 0.02 f~ ~ 3.95 PUP 217.2 6742 ti 0 O ~) 4.50 Discha e Cau e Carrier 17.3 6744 a .0 t3 3.92 PUP 218 6747 ti 0.01 3 I 3.94 Penetration Body Metal Loss Body Page 5 KUP 1 C-172A Weft AttrWutes Mau An le & MD TD orc A Nano s rt M r) t3) tm ) 500292315901 WEST SAK PROD 92.75 9.28583 13,101.0 omm H ) n KB-Grtl {RI Rlg Release e _ _ SSSV~ NIPPLE 0 7/1!2008 Lasi WO: 5/13/2008 33.39 6/24!2003 on ) e 0 Last Tag- Rev Reason: SCHEMATIC CORRECTIONS 2/212009 ' "~' Casio Strin s HANGER. 3a Cas6g Deurlp6on 56610 -- OP ~ R... )... 8tr6g .. ... SI oP CONDUCTOR 16 15.062 D.0 110.0 110.0 62.50 H30 WELDED strtg on Str6g 0... _ op B) SM Depth ._ Set ) ... ng _ >a Tap SURFACE 9 5B 8.697 0.0 6,712.0 3,697.9 40.00 L-80 BTC-M Casig sclpbon etr61g 0... SmnB _. Top Reel Set Deptt R-. SM DepM )..- S[ting .. 9trNg ... Tap d coNDUCroR, INTERMEDIATE 7518 6.800 49.1 8.310.0 3,939.8 29.70 L-80 H 513 a11o Cas6lg Dascrlptlon 7im1g 0.. ro_ tap lRKal Sat DeW1R- SR Dep6117YD)-• >krYIY WL_ >adn9 - Rrbg ~ ~ NIPPLE, 571 - A2 CSG WINDOW 75/8 6.875 3,513.0 3,523.0 2,450.4 29.70 L-80 NEAT TRACE. sitg ShNS _. ... W IRK ) ». _ Op ~ A4 CSG WINDOW 7 5B 6.875 7,357.0 7,367.0 _ 3,841.2 29.70 L-80~ Cas61g Desufptlon >R O_. 110 ro ... Top RIKeI t Depth R... oepn ) ... tmg YYL.. sting •- 8fr61g op GAS UFr. A3 CSG WINDOW 75/8 6.875 7,820.0 7,830.0 3,890.1 29.70 L-BD 3,3a6 ~ Ca961g n ... tlg ... Op ... )... ., SflLlg ._ Op A2 LINER 4112 4.000 7,923.9 13,070.0 3,915.2 11.60 L-80 BTC Az csG ~ Liner Details winnow, op pm 3,513-3,523 (TM~ TOp tni R~1 r! Rem m conutnry GAS LIFT, 7,923.9 3,903.1 85.60 PACKER °HRD° L'eler Top Petlcer 5.50"X7.63" 4.970 6ssz - 7,942.9 3,904.3 85.37 NIPPLE 'RS" Padcoif Seal N" 1Pple 5.5" (4.87" IDx 6.05" O ) 4.870 suRFACE, 7,945.8 3,904. 85.33 HANGER Flexlodc Liner Hanger (4.85" IDx 6.58" OD) 4.850 D-s'71z .6 3,905.2 85.21 SBE 19037 Casing Seal Bore Ext. 4.74°IDx 6.26° OD 4.740 DlscHaRGE, - 7,874. 3,906.6 84.98 XO XO Bushing 5-112" Hyd 563 x4-112" Hyd 521 LD. 3.89". O.D. 6.04" 3.890 6.T4D 7, 76.0 3,906.8 84.96 XO BUSHING Pup Jt. -4-112', 12.6 ppt, L-80, Hydrd 521 3.920 Tubi grin s RuTED SUB. Desalptlon 0... ro._ Top _ NR_ ng._ op e.7a3 TUBING 41/2 3.958 35.8 7,265.4 3,831.1 12.60 L,80 IBT-m SLEEVE. 8,784 ^ ^ _ FLUTED SUB, On Detaihi 6,788 Top p61 (1VD) Top Intl T QDCR) Real 1'1 Rem an tartttttntt ro xa, s,az4 35.8 35.8 -0.01 HANGER Vetco Cray MB228 (10-314" x4-1/2') attar! m9 hngr w/ penetr OD 3.900 GAUGE,6s2s m 1o.a125^ XO. 6,83D 511.3 511.2 2.96 NI LE 41/2"Cemco Nipple, DB profile, w/3.875" profile, IBT-m O 5.21°, ID 3.875 3.875" 6,739.8 3,708.2 68.46 DISC RGE carrier, whng presslre jet poop discharge OD 6.40" 4.5D0 6,783.5 3,724.1 68.53 SL VE akar CMD w/ 3.812", " B" profile OD 5.48" x 1D 3.812" 3.812 6,823.8 3.738.4 69.91 XO x-o pup 4-112" 12.7 ppt I pin x 4-1/T E Eirrod box OD .55" , ID 3.958 3.958" 6,829.4 3,740.3 70.10 GAUGE I-Pump TCS glwge 4-1P2`EUE pinxpin OD 6.60°, ID 3.9' 3.95 6,829.9 3,740 5 70.12 XO x-o pup 4-112" EUE-mod box x 4-1fY' 12.75 ppf IBT pin OD . 3" , ID 3.958 3.958" 7,240.9 3,828.6 .20 LOCATOR Baker Locator OD 5.50" x ID 4.00" 4.000 7,242.6 3,828.8 84.20 SEAL ASSY GBH-22 Locator Seal Assembly, 4.73° OD Seats, 4 1/2" IBTM P 3.870 L6,985-T 236 Other In Hole VYirelill! retrievable lu s valves um fish etc. LOCATOR, Top ]z41 (1VD) Topmtl Seal AsZ~v. Top pots) P1Ka) r! Desorlptlon con.ttalt Rut I>Me ro Ilry A4 csG 35.8 35.8 -0.01 HEAT TRACE HEAT TRACE 511512008 0.000 wNDOW, 7 357-7.367 L2 -A6 HK Paforatlons HNGR, a T 355-7.698 Top IIVD) 0611 (TVD) Dens - Top RRCq B6n (RK8) R~1 MKaI 7.one Date Ish- type Canararil 8,48 .0 8,568.0 3, .1 3.946.0 WS AZ, 1C-772A 4113!2008 32.0 SLOTS 8,570.0 10,239.0 3,946.0 3,929.2 WS A2, 10172A 4/13/2006 32.0 SLOTS A3 csG 10410.0 12,602.0 3,928.7 3,912.9 WSA2, 1C-172A 4/13/2008 32.0 SLOTS WINDOW, ?e2a7,a3D 12.773.0 13,028.0 3,913.0 3.914.7 WS A2, iC-172A 4/13/200 32.0 SLOTS L1,A3 LEM, 7,455-7.860 NOt@S: General ~[ 6117/2008 NOTE: VIEW SCHEMA C w/Alaska5chemalic9.0 Mandrel Details TERMEDIATE, Top Tap PoK 49-8,910 11VD) 6111 OD Wyse lattlt Slu 7RORU1 861 To IRKS) (°) Mtlce Nbdel pnl Sarr 7YPe 11Ne 1e11 giq) Run Oahe Comm.. sLOrs.~ ~ 1 3,394.5 2,400.6 65.64 CA O KBMG 1 GasLitt GLV BK 0.156 1.263.0 &14/2008 8487.568 2 6,692. 3,690.4 67.61 CAMCO 1 Gas LiR OV BKO-3 0.0 8/14!2008 Pats 3/8" x 7/16" SLOTS, 8,570-10,239 SLOTS. 10410-12,602 SLOTS, a 12 77313 028 A2 LINER. 1.929-13 070 TD IiC-172A), I3 101 ConocoPhillips al. n;.n ,, ~. ~_ E I`I lr'/tea ~_~_rl tti::l 'L~~l 3 .~ .,~,~; i U~ I •rudf~u~~ -G, rsUF,fy 1 ~i(1 r~~31 ~J P1 --- 1C-17?A Jet. Pump Completion petait wen: 1C•172J1 __- . 4.1/2" ?2.6 f w' -8 /J9T-rn bin Gate: 611oJ2008 ' C~oracc~iiiip~ ~~~: Doya~ ,~__ ~~ .n N..enCar ,;oi-.rs WollEquipmeM~esCr mments ~_ _ "~ ir~tgth Taps - _. --______4 _.m- ~ - To of String crr Top of Fiance _ _~. _ . ~_ _ t3c~' on Rig 1S RK3 to upeer Irac~cdowri scre~,n~ ts~'~3"i -- 35.79 ~.'e'ro C~~y NE~22g x;14-3~~t" x M12') eccer tGg h'7c w•t penat° .'3q ~ v.312d" _ Z i6 3579 4.1 r2' t2.6~pf, L.BO, I@TM pi-~ x Pin au ~.s• ~u x.n~- 3C-~3 37.95 .._ 4 1 f2", 12.6 , ~-$0 I BTPJI '-ubin S ace Out Pup _.__ - ~ 7.s0 68.08 ~ 1~2". 12.6ppf. L-J30, iBTP~A "'Ming Spada Out Pup _.__ ~.sii . 75.88 ,Jts 218ta z,-i ia.:~~ _. _._.r_ ~.-1i2" 12.6 pcf i_-84 IBT-•nad tubing GD 4.92" x i~ 3.958' D-I`t 3,9':` Z25.8fi ~-.. t~sas : 4-1J2" Cameo Ni 8, DB raffle, w/ 9.876" profiles, iBT-m OD 5.21°', I!3 9.875" . 1.~8 5t 1 45 ,1ts >=~a ~~ ~l7 1Q Jt~ ~fj- +t2" 12.6 pof L-80 IBT-read tubir:~ co ,ar ~~~ d,SZ" X I~ 3,958" 43G.74 -- --"- 512.5.: JJe 124 a 2G _ __ r ~~ JJ~ ~ " ~4-1i2 '12.6 P;of L-80IBT--mod tubing, co,la~ C}Q S :~0' x ID 3.958 2445.2 943.87 4-'+?" vu t i2.c ppf ! -8r IBl`•mad :collar 4'~D ~ 2.d" x IQ 3.958" __ 5.77 338fl.69 ~----- GamCO 4-112" x 1" KBNiG GLM, wl DCK-2 Shea Valve, B£K Jatch, l3D 6Mt37"~ 7.2~ 4- F ~2'~n.p it t2,6 ppf L-~~ ik3T~rnod ,. c411a~ ~~ x.20" x IQ 3.958" 5 7r 3354.46 3a0~ ~rc ;; ~t° s 17 ir) 123 1f1t J s,4-1+2" 1?-,6 ppf 1.8C IBT-rn4d °ub ncJ, catiar OD 5..20" x it?_3 958" 3278.63 3aG~'.~47 -1i2" 't 12.8 ppf L-8Q !BT-rtod , coilar Oa 5,20" x ID 3.958„ s.s5 r3s66,10 ` _ ' Cameo 4-112" x i" KBAAG GLM, wJ d+ umrnY ~VaivB, $K-5 Jatch, fll} ", ~ 31 ',23 BA3 ? ~ 66916.5 ~-._ ___.. _ _ _ 5.81 4-1!2':pwp !t 12. Ei ppf ~-a0 iBT-r7od ,collar OD 5.20" x tD 3.958°~ w - __ w4._ - G394.'8 _ _ _ .lts t8 to ~B t its 4-112" 92.8 f L~J Il~'T-mod t~b~ng, ~alar ©t7 5.2t?" x IU 3.958'" 249E 6: D4 99 -f.2°' u ~t 12,ti `L-8t)16T-moc .collar OD 4.93' x IQ 3.958" S.BC 6733.95 t3uage carrier, tubing pressure jet pump discharge QD 6.4t1" ek x739.75 4-1,'?.'' up j 12.6 pof L-&0 IFJT-r-od , ~Jla: 00 c.93" x iD 3,958"' v.C7G 6744 58 Jts ~5 ~~ 1~ ~ ~t~ .-. _ _ ~-11?" t2 3p~f L-80 68T mod tubing, oc~ffar {?G 5.20.. x lD 3_''x58'.. ,_ 3 ~.3E 67b5.S8 4-1,`2" u :12.6 of L-80 IBT-recd , :,attar OD 4.92" x IG 3.958" 5_a'8 s: 16,94; Flutrd wire protector sub aD 6.00" x ID 3.96" y _ __. :;8 6782.T2' _.~___ _ _ . __-__--- Baker GPJA'U.wJ 3.812", ' D6" profile C}D 5.48" x if3 3.812"' ~.do x783 s0 Fluted wiry protector sut7 OD 6.00" x IC 3.96" - 78 6789 30 -- ~ _ ,_ 1 _ 4.1,2 pup~t 12 &ppf I.-8tji IBT-irad co tar GCl 4 9z" x 'D 3 9513" 5.74 678+.08 aq n 1~ .n5 . . t ,Ms , _._ __ f-iiZ" 117..6, -1.-80 IQT-m •C tubin , cc.[ar Ca 5.23" x I~ 3.95a" z9.o1 s7sas2. ~ ~ x-a pc.p 4.112'' 1¢.?'~ ~c IBT din x ~-1 M" ~UE•r`cd r~.~ ~Q 5a~` , ID 3.958" 3.52 5823.83 .. 1-Pum_p TCS~uagE 4-112" EUE pin x~in OD 6.50" ID 3.95" Sz ee~.ss x-o up 4-'!2' EUE-mod box x 4-1!2" 12 r5 p` IBT pu^I OD ~ :i3° , IJ 3.558" -- - 4.90 6825,87 . .lts ~ to 13 . t3 Jts^ 4-1i2" 12.6 ppf .--c3{? IBT rr d t,:bfrtg, CCllar GD 5.2D' x JD 3.958" 4~t1;34 6x3+1 rr '~+-112"Pint 12 ~.PP:_I--8^~ IF3~ -rnad , cc ia~ :3u 4.93" x lD 3 958'`... 5.;5 7235.t~ Baker Locator OD 5.5C" x J~ 4.~' 1.71 7246.86 _, ..,_.,....Y.,.~. _._,__ GeH-22 Locator seat Asserr~bly, 4,73" t7 [) Seats, 4 912" iBTM Box U ~ 22.81 7242:67 ___ _ :_ ~u ~. ,~ .~.._.._..~__ 1 r'Zf "'I~kS; l.p rta4 1 ~5 K _ ~•~ Vdt 108 K QJack Wt 7G K ~_ _...__..____.______r~ _~__..__,.______ w,~,.._._,._._...~,_._.. Supervisors. Mike 7'horrrton 15cai# Lapiene f'C~ .i_ lv t;•i!;~I :'Etrj'? k'.~~; t l t ~.,t r.',ii!`:? t i.' 1~ !'.J~S~'riacJh:~s~ ~i.t ~f Nun^,nu s., r~ Well Equipment t7~uscrtiption and Gatmmetrrts :.,age 2 Lar.g#h Tops 7265.39 _~ ~zs~.3s .w~ _- __ ,. _ r 2'65.38 ~..._~__ n...._~. _,_.. _~~.~. _ .~.., y.. m.~~ _ _ , _ _. _ _ 7266.34 . . 7265_.38 . . _.. ~ .Y_ .__ ....:.- T?85.39 . ~ 7zss ~s LnC3ted oath 'c~t:a:or ~ ?2ati 96' a^d mule 5^~~ " 7;~8A.77'. - 7265.98 7265.3$ $p'+ced ~u ~i.39' above `utN ICSCated_ _._ - 7285.38 _. - ____.... ,_ _ Lcca^~a_ r~ 1740.$ and rrn.e slice Q ?2c"5.38' _ - __.._ r _._ 72~s5.3s ' Ta!!y of 4-'r'2 tubing ~ ???' di'fer~rrf rc~pEr) tha~. 4-1~1" iir.rr i21" 7265.95 ~ ± 2f35.36 Canncm cE3mp count and i-1/4" stainless bands: _ ._ . i'285.3E ,# ._. _ a --- _ _ __ _. ~;annon 4-l.r' acrass -he collar si~~gler clamp (303131, = i25~ 7Ni5.38 _ Cannon 4-11?_" across the :.o~lar duo r.!amp ia03129- - 5~2 7265.34 Canrwn d-''+'?." ci;rtrr'3 c d.:.d,t ~r1 H ~ charnel i3i13115, - 47;; _____~_ _ - - 72.38 . _~ __ a _.. ~arnz~n C-1+2" ::IawrF 4' ~':d jt ~+r H c':arr~1 ;333130) - 2 I 7265.34 ;;amen ~-1+2" clamF 3` e9id t •~r H:` charne: +30312,) = 3 ~;.ar.nc~n %• ,+2" •~ar~F 2-ii2' slid : vr,' HT c'tcnneJ ;303'. <7} ~, ~ _ r265.3E - 7265.3E ~:annr.~n ~-1rz" clarzp 2" +Air ]t '~tr+ H? rharrei f303" 28) = k 7265 38 ~arncn ~-'+2"' clamp het` lace enc sFoe ~3y31321 - 1 12H5.38 7265.38 . ?2t35 38 , 1265,36' ?ass.~a 72s5. 1zs r2~~ sa - ---_r ~...,.,__ _ w __w_.. ___ 72$x. ~ Firs; 203 GdR:S Uf tubing are used it peci fr or c~in3-: w'i;h 5.2' CU s,:~`t8r5 _ *265,38 .... _. . ?255.38 12s~.aa Heat Trace from 3,Q21' To Surface 72>a~ sa Top of Joint # t35 = 3,02't.51' 72s _~ 7285 36 7~s~,sa rc+~n>iarrs tscrrorr ~~evn ar ern y _- _-• _I rcw.so; l _.__ . _ ~.~.._..._._.~ ._.. - 1~___ ___..__ __ _ ,_ , _ _ .w_ .-,. ~_.,o.,,,_.__. ~.._ . _.. . _____..._. L_. Supervrsor~: A~ikv 7'homton /$cott Lapre»a 1~~~~ ,~~5 ~ d~b~ ~b~53 Schtu~gberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 89503-2838 ATTN: Belh Well Job N NO. 5359 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD iJ-105 7J-136 tE-166 1C-172A lY-O6A 82WY-00017 82WY-00024 82WY-00025 A%BD-00042 AP30-00056 MEM INJECTION PROFILE - MEM INJECTION PROFILE ~ MEM PRODUCTION PROFILE MEM PRODUCTION PROFILE - SFRT - 0723/09 0824/09 0825Po9 0829/09 09/05!09 1 / 1 1 1 t t 7 t ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. osn vos y.. M., ~s ~~ ;i; )[; U 5~~6~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~U~ 0 ~ 2009 1~61~It~lt~ log Description N0.5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/03/09 2U-15 AZCM-00012 GLS - 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE / / 05/10/09 1 1 1C-172A B04C-00048 GLS 05/1.1/09 1 1 3G-11 B04C-00050 PRODUCTION PROFILE .- 05/12/09 1 1 2A-05 B14B-00048 DDL - 05/15/09 1 1 2A-16 8148-00047 LDL - 05/15/09 1 1 3G-16 6148-00049 INJECTION PROFILE p .- 05/16/09 1 1 3G-18 B14B-00050 PRODUCTION PROFILE ~ 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE 05/21/09 1 1 1 E-15 614B-00058 LDL - 05/24/09 1 1 3H-33 B04C-00006 CH EDIT PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • '~ Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Monday, February 02, 2009 1:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Page 1 of 3 Subject: FW: 1C-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 Oif Tool schematics, and the liner/hook hanger detail sheets. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907} 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com From: Allsup-Drake, Sharon K Sent: Monday, February 02, 2009 1:00 PM To: Reilly, Patrick J Subject: FW: 1C-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: 1C-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Pat - Below is the breakdown of blank intervals for each of the laterals for 1 C-172A for your review before forwarding to Tom Maunder. I will also send him paper copies of the schematic, wellbore diagram and casing detail sheets of each lateral. 1 C-172A: entice liner is slotted except for the following blank intervals - 7925'-8487' MD 3901'-3945' ND ^~ 10239'-10410' MD 3927'-3929' ND 12601' -12773` MD 3911'-3912' ND 13027'-13072' MD 3914'-3915' ND 1 C-172AL1: entire liner is slotted except for the following blank intervals - 7818'-8103' MD 3904'-3904' ND 9863'-9990' MD 3881'-3880' ND 12533'-12705' MD 3856'-3855' ND 1304T-13092' MD 3851'-3851' ND 1 C-172AL2: entire liner is slotted except for the following blank intervals - 7354'-7622' MD 3846'-3845' ND 7752'-7880' MD 3853'-3850' ND 8352'-8522' MD 3840'-3832' TVD 10757'-10917' MD 3803'-3801' TVD 12947'-12991' MD 3783'-3784' TVD Thank you, Sharon 263-4612 Page 2 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, November 15, 2008 8:21 AM To: Reilly, Patrick J Cc: McKeever, Steve; Allsup-Drake, Sharon K Subject: RE: 1C-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Pat and Sharon, Lets talk on Monday before you redo the 407s. I am all in favor of the correct information, however 1 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: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Tom, Sorry about the confusion on this. Sharon and I reviewed the 407 and we think we have come up with a better way to describe the liner/blank placement. The liner is all slotted except for the specific depths listed (which are blank). We will send over new 407's with a clearer description. We will also send over a drawing similar to the proposed drawing. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.]. 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: 1C-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) Hi Tom - My apologies for the incomplete information. How soon do you need it? The reason I ask is I am ofF on vacation for a couple of weeks at the end of this week. If I get it to you in the first week of December, will that be soon enough? If not, I will find someone else to get it to you. Steve McKeever Drilling Superintendent, Greater Kuparuk ConocoPhillips Alaska, Inc. ofFce: 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: iC-172A (208-008), -172AL1 (208-009) and -172AL2 (208-010) Steve, I am not sure which engineer was responsible for this well, so you get the message. I have just reviewed the completion reports for these wells and have some questions. 1. On block 23 on all 407, some amount of liner detail is given. There are depth gaps. Is the liner solid/blank in the gaps? It is somewhat confusing how it is listed. 2. Please provide the completion details sheet for each leg. 3. Please provide a wellbore drawing. I believe an earlier message was exchanged regarding a completion drawing similar to the proposed drawing provided in the permit applications. A drawing similar to that would be appreciated. Thanks in advance. Call or message with any questions. Tom Maunder, PE 2/2/2009 Cc~nocoF~h~ltips ... I _ _.yA-eA Qo flg ~T172A e/2312G~5'.Q855 PM _.__ _St;pemr.[c Arrual ~p~~ HANGER. 36 -- -- - I -- P :. j 3 CONDUCTOR, ' I` e-11fl ~ NIPPLE,Stt------- ~i'~ - HEATTRACE, _ y 3fi ( GAS LIFT, _ _.. _ 3.394 A2 CSG WINDOW....--. _ 3.513-3,523 GAS LIFT,_ _- 6,692 SURFACE. _.- 0-6,712 SNSR MNORL. _ _ _ _ _ 6,740 FLUTED SUB, -___ 6,]83 SLEEVE 6,]84 - FLUrEOsue, _ xo. s,e24 -- -- GAUGE,6.629 - - " XO, 6.830 - -- L2 - A4 LE M, 6,985-],236 LOCATOR, ],241 SEAL ASSY. A3 CSG WINDOW 7820-],830 ''. L1-A3 LEM. '~, ~` ,~_ NTERMEDIATE, _ - _-._ 49-8,310 SLOTS, fl,48]-8,568 k h SLOTS, tl 8,570-10.239 ~ i I SLOTS, 10,410-12.602 I SLOTS, 12,77313.028 A2 LINER, 7,924-13,070 '. TD (1 G-172A). 13,101 KUP • 1 C-172A ima ~ Prodlln)Well Type Well status lncl (°) MD (ftKel TD (nax)(ft... SAK / PROD l 98.94 7,717.55 13,102.0 H25 (ppm) Date Annotation End Dafa I KB-Grd (N) Rig Release Date 0 71112008 (Last WO ._5/1312008 33.39 _.I 6124/2003.__. 'End Date Annotation End Date Rev Reason: ADD FISH in L2 9!22/2008 ling 0... String ID .. .' Top (ftK8) set Depth (f... Set Depth (TVD) .. String Wt... Stnng Gr... String Top Thrd 16 15.062 I 00 110.0 1100 62.50 H-00 WELDED :ring 0... String ID _ . Top (ftK8) Set Depth (f... Set Dep[h (TVD) ... String Wt... String Gr... String Top Thrd 9 5/8 8.697 0 0 6,712.0 3,697.9 40.00 LBO BTC-M sing 0... String ID .. . Top (ftK8) Sat Depth (f... set Depth (TVD) .. String Wl... String Gr... String Top Thrd 7 vR 6 800 49 1 8 310 0 3 939 8 29.70 L-80 Hvtl 513 Description string 0... 511.31 511.2 6,739.8; 3 708 2 6,783.5 3,724.1 6,823.8 3,738.4 9 Pl P ( P R str6.875 ~~~ •TO3,513 0 ~ISe3 523 Oc.. Set D2,450.4 DI ._ string w 29.70 String ID ...ITop (ftK8) /set Depth (f... Set Depth (rVDI. ~, String W 6.875 7,357.0 7,367.0 i 3841.2 ~ 29.70 Str ng ID ... Top (kK6) Sat Depth (f... Set Depth (TVD) . String W 6.875 7,820.0 7,830.0 3,890.1 29.70 String ID ... Top (ftK8) Set DepM (f... Set Depth (TVD) ... String w 7,240 9 3,828 6 84.20 LOCATI 7,242.6'~I 3,828.A 84.20 SEALA Other In Hole (Wireline retr ~I Top Depth (NDI Top Top (kKe) (KKe) Iecl (°) Descri 35.81 35.81 -0.011HEAT II 'HRD' ZXP Liner Top Packer 5 50" X 7.63" 4.970 - -_-_ "RS" Packoff Seal Nipple 5.5" (4.87" ID x 6.05' OD) __- 4.870 __- _- FlezLock Liner Hanger (4.85" ID x 6.58" OD) _ _. 4.850 190-47 CasingSeal Bore Ext. 4.74"ID x 6.26" OD 4.740 XO Bushing 5-1/2" Hyd 563 x 4-1 /2' Hyd 521 I D. 3.89", O.D. 6.04" __ - 3.890 Pup Jt -4-1/2", 12.6 ppf, L-80, Hytlel 521 3.920 Crossover 4 112', 12.6 ppf, L-80, Hydril 521 box x 4 1/2' BTC pin 3.958 String Top Thrd st g G1 Set Depth (f .. /Set Depth (TVD) . Str ng Wt_. fop (ftK8) . 1 / 35 8 7,265 4 IL 3 831.1 12 60 L-80 IBT m comment ID pn1 Vetco Gray M6228 (103!4" x 4-1 /2') eccen tbg hngr w/ penetr OD 3.900 10.8125" 4-1/2" Camco Nipple, DB profile, w! 3.875" prof le, IBT-m OD 5.21", ID 3.875 3.875" _ - -_ Guage career, tubing pressure jet pump tlischarge OD 6.40" __ _-_ 4.500 Baker CMD w13.812", "DB' prof le OD 5.48" x ID 3.812" 3.812 z-0 pup 4-1/2' 12.75 ppf IBT pin x 4-1/2" EUE-mod boz OD 5 55' , ID 3.958 3.958" I-Pump TCS guage 4-1/2"EUE pin z pin OD 6.60", ID 3.95" _ _ 3.950 x-o pup 4-1/2" EUE-motl box x 4-112" 1275 ppi IBT pin OD 5.53" , ID 3-958 3.958" Baker Locator OD 5.50" x ID 4.00" ~, 4.000 GBH-22 Locator Seal Assembly, 473" OD Seals, 4 112" IBTM Box Up e plugs, valves, pumps, fish, etc. _ _ - 3.870 _ Comment _-_ Run Date ID (in) _ HEAT TRACE 5/15/2008 0.000 ~ snot Den s Zone Datai (sh.,. ~i Typa _ _ Comment IS A2, iC-172A 4/1372008 32.0 SLOTS IS A2, 1C-172A 4/13/2008 32.0 SLOTS rS A2, 1C-172A 4/13/2008 32.0 SLOTS rS A2, iC-172A 4/13/2008 32.0 SLOTS landrel Details 'Top Depth Top I Port (TVD) Inc! OD Valve Latch S¢e TRO R n Top (ftK8) (ftK8) (°) ' Make Model (in) serv Type Typa (In) (psi) R nDate Ca of 3,394.51 2,400.6 65.64CAMCO KBMG 1 -Gas Llft GLV BK 0 156 1,2630 8114/2008 ., i a ao~ n ~ eon n F~ at rannrn- Kannr. 1 r:ac I Mfr- n\/ RKn-3 0 00 8/14/2008 (Dual • ~:~,.' Slotted and Blank Liner Detail Well: 1C-172A Conoco ~ hil li ps 1C-172A A2 Lateral 4-1/2" Slotted Liner Date: 4/13/2008 Alaska, Inc. Rig: Doyon 15 Depth Jt Number Num of Jts Well EquipmPlt Description and Comments ~ Page 1 Length Tops Crossover 4" XT-39 Box x 3-1/2" IF Pin .93 7913.47 Liner Running Tool 3-112" IF" (Does nat stay in hole j 11.58 7914.40 "HRD" ZXP Liner Top Packer 5.50" X 7.63" 19.05 7925.98 "RS" Packoff Seal Nipple 5.5" (4.87" ID x 6.05" OD) 2.55 7945.03 FlexLock liner Hanger (4.85" ID x 6.58" OD) 9.s2 7947.88 190-47 Casing Seal Bore Ext. 4.74"ID x 6.26" OD 19.64 7957.70 XO Bushing 5-1 /2" Hyd 563 x 4-1/2" Hyd 521 I.D. 3.89", O.D. 6.04" 1.48 7977.34 Pup Jt. - 4-1/2", 12.6 ppf, L-80, Hydril 521 1.68 7978.82 Jts 107 to 118 12 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Casing 506.91 7980.50 Jts 105 to 106 ~ Jts 4-12",11.6 ppf, L-80, Hydril 521 Si~;?ted Casing 81.03 8487.41 Crossover 4 1/2', 12.6 ppf, L-80, Hydril 521 box x 4 1t2' BTC pin 1.65 8568.44 JtS 66 t0 104 39 Jts q-1 ~".1 `I.v }'3p*s. ~-~£~, STC Sia<a~ , t"z~sirlg Va+ ~;~;elt~s' ~ :~~ 1669.18 8570.09 Jts 62 to 65 a Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing w! Torque rings 170.88 10239.27 Jts 56 to 61 u Jts 4-112",11.6 pert, L-80, BTG Slotted Casn~g w( Torque ris~°: 25721 10410.15 Jts 11 to 55 45 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 1934.52 10667.36 Jts 7 to 10 4 Jts 4-112", 11.6 ppf, L-80, BTC Blank Casing 171.17 12601.88 Jts 1 to 6 6 Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing 254.76 12773.05 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.34 13027.81 4-112" BTC Silver Bullet Float Shoe (O.D. 4.95") 1.65 13071.15 Bttm of Tail =_> 13072.80 13072.80 13072.80 TD 6 3/4" hole @ 13101' MD / 3914' TVD 13072.80 4-1/2" Shoe @ 13072' MD / 3,915' TVD (Rat Hole 29') 13072.80 13072.80 Intermediate 7-5/8" Shoe @ 8,301' MD/ 3,939' TVD 13072.80 13072.80 Total Parts used: 105 HydroForm Centralizers 13072.80 Run 1 HydroForm Centralizer per joint floating 13072.80 f/ Jt#1 thru Jt#110 (4.5" X 6.3") (Coverage from 13,027' to 8,319') 13072.80 Installed Torque rings in # 56 Thru #104 Total of 49 13072.80 13072.80 DO NOT RUN HYDROFORMS ON CONSTRICTOR JOINTS 13072.80 Total of 5 Constrictor Packers ran @ 12,747', 12,632', 10,407' 13072.80 10,262', 8,457'. 13072.80 Remarks: Ran total of 21 jts Blank= 893.95' (inc. shoe jt.) and 98 jts Slotted= 4196.70' ,Slots are up wt 230K w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers Rot wt 163K staggered 18 deg., 3 ft. non-slotted ends Dn Wt OK Used Run-N-Seal thread compound on all connections. Block wt 7oK Drifted casing to 3.875" w/ teflon rabbit. Torque 8-10K 16" Conductor, K-55, set at 107' XXX" x 41/2" Wellhead, 5,000 psi Tubing, 4712", 12.6#, IBTM, Spedal Dnn above 7.875 BD nipple 577' MD-1.875" DB Nipple, 510 ND (3 deg) ~ Sl%'MD-GLM, Cameo KBMG, 4712"X1", 239J (88 tleg) Whipstock Casing Exit TOW 1,517'+l-, 2,240' ND 9-518" 40#, BTC is-172 Tubin9 3tdng / 4712" 12.6# L-80, IBTM 3.958" ID, a.e33° Ddn 7338' MD- 5-712' X ]-518"2XP Liner / Top Packer wl Hold Downs 7265' MD - Bottom of Seal Assembly 4.75" Seal OD 6692' MD -GLM, Cameo KBMG, 4112" X 1", 1819 ND (6] tleg) 6783' MD-CMD Slitling Sleeve, w/3.81" DB Profile, 3838 ND (88 tleg! ColnocoPhillips West Sak 7-5/8" Producer 1C-172a ST Tri-Lateral Completion As Completed ~/rY® HUGHES Baker Oil Tools Lateral Entrv Module (LEMI With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector !Running/Retrlewng ~ (1.00' Length) Snap In/Snap Out I rBack Pressure Valve f Positive Locatingti (1.60' Length) Collet Lateral Isolation" ~ Flow-Thru Swivel Seals (1.25' Length) ~ Lateral Diverter '/ /Hydraulic Ramp ' - Disconnect ~~ Isolation/ Mainborer (1.50' Length) Diverter Sleeve ~~ GS Spear ~~ (1.50' Length) Lateral Isolation 6 .85 h Approx. Seals OAL' 'Jars may be required in highly deviated or deep applications (6' approx length). 78.5' Diverter Length 18.5' Sleeve Length 7255' MD-Casing Sealbor¢ Rttepbcle, 20' Length 7311' MO -3.75" DB-8 Nipple, J875 ND (84 deg( 7397' MD-Lateral Entry Motlule(LEM) / 7357'MD-A4SandWlndow,3%3'ND184degl 'A4' Sand Lateral 74]3' MD - Peyzone ECP 4711" 17.6# L-00 Slotletl and Blank Liner '~ ,,,.,. s ~,.,a ~. .. 3-t12°cwae shoe 7355'MD-4112"X7-518" seal Bores Mndel'B' NOON Hanger s68" ID ]456' MD - 5-112" %7618" ZXP Liner Top Packer wl Holtl Downz Casing Sealbore Receptacle 4.75" ID Orienting Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correa 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 ©Baker Hughez 2005. This document may not be reproducetl or dlslnbuteq In whole or In part, In tiny forth or by any means eledronle or mechanical, including photocopying, reeording, or by any information storage and reldeval system now known or hereaRer Inv¢nted, without written permisslce from Baker Hughes Inc. 4112" Guitle Shoe 13892' MD - 4112" Liner Shce, 11.8#, L.80 BTC, 3850'ND T9%' MD-Bottom or Seal Assembly {.7s^ sem oD 'A2' Sand Lateral 4112° ns# L-fio sialetl and 81ank Liner 4112"Eecen[rle GUiOe 7957' MD -Casing Sealbore lit Receptacle, 20' Length - tWm 8701' MD - 7618" 29.]# Casing, L80, Hytldl 517, J979' ND (90 tleg) Eauinment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Dritt: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3,88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 41/2" Lateral Entry Module Mainbore Drill: 3,65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Dritt, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +l- 18.5' Shce ~~ ~ ~~ 13072' MD-4712" Casing Shce,11.8#, L-00 BTC, 3975' ND A mb r~ 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs ~7559'MD-5-112"Tlebaek Slceve 11011'MD-4112"Doer Shoe, 77.8#, L-00 BTC, 3850' NO MD -bottom of 4112" bent muleshoe 7{87' MD -Bottom of Seal Assembly {.7s^sealoD 7810' MO-Lateral Entry Motlule(LEMI 7475'MD-Casing Sealbore Receptacle ]820'MD-A3-6antl Window, 7978'NDI%deg( 'A3' Sand Lateral 20' Length .... 7840' MD-Pal/ one ECP 4112" 11.6p L-00 Slottetl and Blank Dner 7818'MD-4112"X7518" Model'B'HOOK Hanger "` "'"- "` °`~ reel Bores ' -t^ "s . 8878' MD - 5-112" Tieback Sleeve 1.64 ID 8082' MD -Bolcom a14112" bent muleshoe 411]" 126p Tubln9 7887' MD - 7.582" OB-0 NIPPIe, .e1T' Dnn Sa.958 ID 3896 ND (83 deg! svx^ x 7-s16^ zxP Llcer Top Paeker won H¢ltl DDwna 5-112" X 7618" Flex Lock 7928'MD-Liner Hanger) Packer Assembly Dner Hanger ConocoPhillips August 19, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Steve McKeever GKA Drilling Superintendent Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6826 Subject: Well Completion Reports for 1 C-172A, 1 C-172AL1 and 1 C-172AL2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 C-172A, 1 C-172AL1 and 1 C- 172AL2. If you have any questions regarding this matter, please contact me at 265-6826 or Pat Reilly at 265-6048. Sinter y, /~ ~~~~~ ~~ S.w--M'~T{eever GKA Drilling Superintendent CPAI Drilling SM/skad STATE OF ALASKA ~ AU a 2 ~ 200 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska OII & Gay Cans. Cammi8SlQt~ WELL COMPLETION OR RECOMPLETION REPORT ANC~,rls~6ga ta. Well Status: Oil 0 Gas Plugged ^ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^/ - Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., f ~ or Aband.: Jul , V 12. Permit to Drill Number: 208-008 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: R. April 1, 2008 ' 13. API Number: 50-029-23159-01 ' 4a. Location of Well (Governmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11N, R10E, UM 7. Date TD Reached: April 11, 2008 14. Well Name and Number: 1C-172A • Top of Productive Horizon: 525' FNL, 2256' FEL, Sec. 11, 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: 182' FNL, 2427' FEL, Sec. 14, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 13072' MD / 3915' TVD West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562102 y- 5968801 Zone- 4 10. Total Depth (MD + TVD): 13101' MD / 3915' TVD ' 16. Property Designation: ALK 25649, 25650 TPI: x- 558742 y- 5969685 Zone- 4 Total Depth: x- 558615 • - 5964748 Zone- 4 11. SSSV Depth (MD + TVD): landing nipple @ 511' MD / 511' TVD 17. Land Use Permit: 467, 468 18. Directional Survey: Yes Q No^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (lVD): approx. 2439' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 4J 3S,(~ /~-'1,D GR/RES ~ ~~D •p 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REC RD 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 7926' 13073' 3901' 3915' 6.75" slotted liner 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7265' 7926' 7925'-8487' MD 3901'-3945' TVD 10239'-10410' MD 3927'-3929' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12601'-12773' MD 3911'-3912' TVD DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED blank intervals from 13027'-13072' MD 3914'-3915' TVD na 26. PRODUCTION TEST Date First Production flowback starting 6/13/08 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 7/9/2008 Hours Tested 6 hours Production for Test Period --> OIL-BBL 556 GAS-MCF 686 WATER-BBL 0 CHOKE SIZE 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 (corn) 20 deg. 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~~ NONE DATE S• 12 IIfRIF ED Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE S ~~~: SFP ~ 9 20Q8 ~''• 8•oS C /"~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q/ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground Surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3490' 2439' needed, and submit detailed test information per 20 AAC 25.071. West Sak A2 8158' 3926' West Sak A3 7648' 3872' West Sak A4 7272' 3832' N!A Formation at total depth: West Sak A-2 30. LIST OF ATTACHMENTS ~j - /' ,, Summary of Daily Operations, Directional Survey .~'a' ~ 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly 265-6048 Printed Name teve Mc ever Title: GKA Drillino Superintendent N 2 ~7 ~~ Signature Phone Date Sharon Allsup-Drake -' 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 Corto~c~P'hilips Time Log & Summary We/N7ew Web Repor[tng Report Well Name: 1 C-172 Rig Name: DOYON 15 Job Type: DRILLING SIDETRACK Rig Accept: 3/27/2008 2:00:00 AM Rig Release: 5/13/2008 12:00:00 AM Time Lois _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/25/2008 2a hr summary Prepare to move rig approx 5.6 miles to 1C-172A, move rockwasher to 1C pad, seperate utility module, skid rif floor, move drilling module off of well 1 D-141A, line up at the pad exit, move off pad @approx 2300 hrs with both modules movin a rox 1 m h. 13:30 17:00 3.50 0 0 MIRU MOVE RURD P Prepare rig Doyon 15 for move to 1 C-172A: Prepare rig floor to skid, rig down handiberm, blow down steam and water to rig floor, blow down pump room, prepare rockwasher for move, remove beaver slide. 17:00 18:00 1.00 0 0 MIRU MOVE RURD P Skid rig floor to moving position. Blow down pit module. Move rockwasher. 18:00 19:00 1.00 0 0 MIRU MOVE RURD P Open cellar doors, raise stomper feet, continue to rig down handiberm, lay 3" x 12" boards along side of the matting boards for rolling modules off the mats. 19:00 20:30 1.50 0 0 MIRU MOVE DMOB P Jack up the pit module. Move off the mats, install steering drag links, move to ad entrance/exit. 20:30 22:00 1.50 0 0 MIRU MOVE DMOB P Function drilling module moving system. Jack up the drilling module, raise stomper feet and secure, move off well and then to the exiUentrance of the ad. 22:00 23:00 1.00 0 0 MIRU MOVE MOB P Move the rock washer to 1 C pad. Line up the pit module behind the drilling module in preparation of movin to 1C ad. 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Move both modules towards 1C pad. Movin a rox 1m h. 3/26/2008 Move rig and pit module f/ 1 D pad to 1 C pad, lay herculite and mats, move sub over well 1 C-172A, move pit module onto mats -then mat up with the drilling module, lower stomper feet on the drilling module (preload to 750 psi), skid rig floor to drilling position, install roof caps and handrails on the pipe shed, rig up steam system, berm around rig, retract braces in the pipe shed, rig up flow line to pits, rig up mud lines and interconnect lines. Move two small cam s, sho ,and arts houses from 1 D ad to 1 C ad. 00:00 10:00 10.00 0 0 MIRU MOVE MOB P Continue to Move Rig module and pit module f/ 1D-141A to 1C-172A; Rig on Pad 10:00 14:00 4.00 0 0 MIRU MOVE OTHR P Lay Rig Mats for Rig Positioning / Pre Pad for Drillin Activities 14:00 14:30 0.50 0 0 MIRU MOVE MOB P Move Rig module onto the mats. 14:30 16:00 1.50 0 0 MIRU MOVE OTHR T Trouble shooting moving system 16:00 16:30 0.50 0 0 MIRU MOVE MOB P Move/ Spot Rig module over well 1 C-172A. r~a~~ 1 of ~t3 ~~ Time Logs - _ _ _ _-- - From To Dur S. Depth E. Depth Phase Code Subcode T Comment _ Date _ 3/26/2008 z4 hr summary Move rig and pit module f/ 1 D pad to 1 C pad, lay herculite and mats, move sub over well 1C-172A, move pit module onto mats -then mat up with the drilling module, lower stomper feet on the drilling module (preload to 750 psi), skid rig floor to drilling position, install roof caps and handrails on the pipe shed, rig up steam system, berm around rig, retract braces in the pipe shed, rig up flow line to pits, rig up mud lines and interconnect lines. Move two small cam s, sho ,and arts houses from 1 D ad to 1 C ad. 16:30 18:30 2.00 0 0 MIRU MOVE MOB P Move pit module close to the mats, remove drag links for steering, crab module onto the mats, spot along side of the drilling module. Lower the stompers on the drilling module and reload to 750 si. 18:30 18:45 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on skidding ri floor to the drillin osition. 18:45 20:00 1.25 0 0 MIRU MOVE SKID P Skid rig floor over well 1C-172A. Install roof caps on the pipe shed. Install handrails. 20:00 23:00 3.00 0 0 MIRU MOVE RURD P Rigging up: Hooking up steam lines, mud lines, flow line, interconnects, berming around the rig. Pickup tools and debris. Raise braces in the pipe shed and secure. Moving two small camps, shop, arts houses from 1 D ad to 1C ad. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Install beaver slide on drilling module. Continue working on the steam s stem. 3/27/2008 Continue to rig up, Rig accepted @ 0200 hrs 3/27/2008. Pull BPV usiing a lubricator, rig up on tree to circulate to a 400 bbl horizontal open top tank. Press test pump line to 1500 psi. Displace wellbore fluids to open top tank, pumping 600 bbls. Shut down, monitor pressures. Blow down lines. Rig up to pump down tubing taking returns to the pits. Returns had a good bit of diesel. Circulated till ran out of seawater (total of 870 pumped), ordered more seawater to pump. Change out saver sub on the top drive to 4-1/2" IF while waitin on trucks. Started um in a ain. A total of 240 bbls more um ed midni ht 4b m w/ 260 si . 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Continue rigging up pump room, cellar area, cellar pump. Doyon 15 Rig accepted @ 0200 hrs 3/27/2008. 02:00 04:30 2.50 0 0 MIRU WELCTL OTHR P Prep Cellar for Well Kill! fluid swap 04:30 06:00 1.50 0 0 MIRU MOVE OTHR P Spread Herculite f/ Rock Washer, La Ri Mats for Loadin Dock 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Rig down equipment used to pickup the beaver slide. Organize rig floor and cellar. Move and spot the rockwasher. Berm the rockwasher. Move and spot the change house. Work on steam system. Test Gas alarms. 09:00 10:00 1.00 0 0 INTRM1 WELCTL OTHR P Pickup the lubricator. Lubricate out the BPV, la down lubricator. 10:00 11:00 1.00 0 0 INTRM1 RPCOM RURD P Rig up 2" hardline from the choke, then horizontal open top tank and annulus (9-5/8" x 4-1/2"). Rig up a hot air heater to the house. ~- i k'acga 2 of ~iQ Time__Logs _ _ Date From To Dur S. De th E. Depth Phas Code Subcode T_ Comment _ 11:00 11:30 0.50 0 0 INTRMI RPCOM SFEQ P Rig up diesel to the test pump. Pressure test the hard line w/ 100 psi air. Fill line with diesel, then test to 2000 si, no leaks. 11:30 12:00 0.50 0 0 INTRM1 RPCOM OTHR T Thaw out vacum truck suction line & Stand Pi eon the O en To Tank. 12:00 12:30 0.50 0 0 INTRM1 RPCOM SFEQ P Fill secondary kill line from the pumps to the well with seawater. Pressure test lines to 1500 si. OK. 12:30 12:45 0.25 0 0 INTRM1 RPCOM SFTY P Pre job safety meeting for displacement from wellbore fluids (mostly diesel w/ some seawater) to 8.5 seawater. 12:45 18:00 5.25 0 0 INTRM1 RPCOM CIRC P Displace well bore fluids to 8.5 ppg seawater. Pumping down the 9-5/8" x 4-1 /2" annulus with the rig pumps, taking returns through the tubing to choke skid, then to open top horizontal 400 bbls tank. Initial circulating rate and pressure 1/2 BPM / 10 Psi. Final circulating rate and pressure 4 BPM / 250 Psi. After 600 Bbl Pumped Returns to Tank Showed a Mixture of Crude, and Sea Water; Shut Down and Observed Well for Pressure Build Up; Annulus Pressure Built to 40 Psi After 30 Minutes. 18:00 18:30 0.50 0 0 INTRM1 RPCOM RURD P Blow Down Lines f/Tree to Tank and R!U to Circulate Through the 4 1/2" Tubing and Up the 9 5/8" X 4 1!2" Annulus. 18:30 19:00 0.50 0 0 INTRM1 RPCOM CIRC P Circulate down 4-1/2" tubing, taking returns through rig choke manifold and poor boy degasser. Pumping 4 bpm w/ 260 psi. Returns dirty diesel, dumping same. Ran out of seawater, did not clean up. Shut down. Monitor ressures. 19:00 23:00 4.00 0 0 INTRMI RPCOM OTHR P While waiting on another 580 bbls of 90 deg seawater to arrive and trucks to haul off the returns: Change saver sub on the to drive to 4-1/2" IF. 23:00 00:00 1.00 0 0 INTRM1 RPCOM CIRC P Circulate down 4-1/2" tubing, taking returns through rig choke manifold and poor boy degasser. Pumping 4 bpm w/ 260 psi. Returns started to clean up a little after pumping 150 bls of seawater. Continue to pump seawater to cleanup well. A total of 240 bbls um ed midni ht Page 3 of fig Time Logs __ Date_ From To Dur S. Depth E__De t~h Pha_se Code Subcode T_ Comment 3/28/2008 24 hr Summary Continue to displace well to clean 8.5 ppg seawater. Pumped a total of 360 bbls more (4bpm w/ 260 psi). Note: test floor safety valve 250 psi low and 3000 psi high while circulating. Monitor well- static, install back pressure valve, nipple down 4-1/6" 5m tree, nipple up 13-5/8" BOP stack, install 3-1/2" x 6" variable rams in top pipe rams, install 7-5/8" rams in lower pipe rams. Rig up with 4-112" test joint and Vetco/Gray test dart to shell test BOP stack (tested against upper pipe, manual kill valve and manual choke valve). Witness of test waived by AOGCC inspector John Crisp. Tested 250 psi low and 3000 psi high, held each test 5 minutes, charted test. Pull test dart, rig down test equipment, blow down lines. Pull backpressure valve. Using 4-1/2" landing joint (4.909 MCA), screw into hanger, pull to rig floor (PU wt 145k to pull free, then 125k). Cut and remove TEC wire for downhole guages, remove clamps. Lay down hanger, two 10' pups, then stand back 3 stands of 4-1/2" IBT-m tubing in the derrick. Change out elevators, rig up to run Baker retievamatic storm packer, run in the hole 90', turn to left one turn, then set down. Pull out of the hole with running tool and lay down. Test packer against blind rams to 1000 psi f! 5 minutes- good test. Nipple down BOP stack (set to the side). Rig up to remove Vetco/Gray wellhead (tubing head assembly # 0800108-01-2, part # C-800-108-01 ). Remove wellhead, clean up the neck of the 9-5/8" hanger. Set Vetco/GRay multibowl, orient with conductor punch marks. Measure rig floor to top of starting flange to be 41.23' RKB (Starting head 2" (.17') above pad level = 41.40'= ad level. 00:00 01:30 1.50 0 0 INTRM1 RPCOM CIRC P Contined circulating to Clean Up Liner /Annulus; Returns Cleaned Up; Pumped another 360 Bbls @ 4 BPM / 260 Psi. Note: While circulating: Tested rig floor safety valve (4-1/2" IF) to 250 psi low and 3000 psi high. Charted test. 01:30 02:00 0.50 0 0 INTRM1 RPCOM OWFF P Observe Well for Flow (Static); Blow Down Lines & Choke manifold. 02:00 02:30 0.50 0 0 INTRM1 WELCTI OTHR P Install 4" BPV 02:30 03:30 1.00 0 0 INTRM1 RPCOM NUND P Nipple Down Vetco 4-1/16" 5m Horizontal Tree. 03:30 09:00 5.50 0 0 INTRM1 WELCTL NUND P Nipple Up 13-5/8" 5m BOPE & Associated Lines. Cleaning pits and loading pipe shed with a total of 255 jts (85 stands 5" drill i e. 09:00 10:45 1.75 0 0 INTRM1 WELCTL OTHR P Change BOP Rams and Configure as Follows; 3 1/2" X 6" Variable (Top pipe rams), and 7 5/8" (Bottom pipe rams . 10:45 11:30 0.75 0 0 INTRM1 WELCTI OTHR P Pickup 4-1/2" test joint, make up Vetco Gray test plug, run in hole and set test dart. Fill stack with water. 11:30 12:00 0.50 0 0 INTRM1 WELCTL BOPE P Shell Test BOPE: Witness of test waived by AOGCC Inspector John Crisp. Tested Upper (3 1/2" X 6") Rams Against Manual Choke & Kill Valves to 250 psi low and 3000 psi high. Held each test 5 minutes. Charted test. Tested Good. 12:00 12:30 0.50 0 0 INTRM1 WELCTL OTHR P Rig Down /Blow Down Lines & E ui ment f/ BOP Test 12:30 12:45 0.25 0 0 INTRMI WELCTL OTHR P Remove Vetco test dart, lay down test 'oint. 12:45 13:30 0.75 0 0 INTRM1 WELCTI OTHR P Pull BPV Page 4 caf bit Time Logs Date From To_ _Dur S. De th E. De th _____ __ Phase Code Subcode T_Comment __ 13:30 15:30 2.00 0 0 INTRM1 RPCOM TRIP P Screw Into Hanger and Pull Hanger to the rig floor, Cut & Remove TEC Line and Clamps, UD hanger w/ pup, and two 10' pup jts, Pull & Stand Back 3 Stands of 4 112" 12.6 ppf L-80 IBT-m tubing. Pulled free with 145k on weight indicator. Then PU wt was 125k as expected. PU wt 120k, SO wt 110k, blocks 70k. 15:30 15:45 0.25 0 0 INTRM1 RPCOM RURD P Change Elevators and R!U to Run 9 5/8" Storm Packer (Baker model "EA" Retrievamatic . 15:45 17:15 1.50 0 0 INTRM1 WELCTL OTHR P RIH & Set 9 5/8" Storm Packer (one turn to left, then set down all weight to block wt of 70k on the indicator) at 90' MD 17:15 17:30 0.25 0 0 INTRM1 WELCTL TRIP P Pull out of the hole with Baker running tools. Stand back stand of 5" d. 17:30 17:45 0.25 0 0 INTRM1 RPCOM RURD P Lay down Baker Oil Tools running tools. 17:45 18:15 0.50 0 0 INTRMI RPCOM DHEQ P Test Baker model "EA" retrievamatic storm packer. Used Blind Rams kill line manual valve and Choke HCR to 1000 Psi f/ 5 Minutes Good 18:15 20:00 1.75 0 0 INTRM1 WELCTI NUND P Nipple down 13-5/8" BOP stack by removing flowline, tie down chains, and flowline. Rig up and attach bridge cranes, rig down choke hose, break bolts on the 11" 5m DSA to the wellhead. Pick up stack and move to the side. 20:00 23:00 3.00 0 0 INTRM1 WELCTL OTHR P Rig up to remove the Vetco/Gray 11" 5m wellhead (tubing head assembly # 0800108-01-2, part # C-800-108-01 ). Attempted to pull with tugger, soaked lockdown holes with aerokroil, steam wellhead, hammer on wellhead, try pulling side to side. Rigged up rig up slings to top drive. Pulled 16k with top drive, re-rigged and pulled to 24k w/ top drive several times, pulled 16k with blocks and pulled with big tugger and finally ulled free a rox 30k to ull free . 23:00 00:00 1.00 0 0 INTRM1 WELCTI OTHR P Move wellhead to the side in the cellar. Dress and prepare neck of 9-5/8" hanger for new wellhead. Clean Graylock ring. Install New wellhead with another profile for the 7-5/8" casing to be run. Orient wellhead with punch marks on the conductor. Verified alignment with unch marks. P~~e raf ~0 ~ ~ Time Logs --- _ _ --- Date From To Dur S. Depth E Depth Phase Code Subcode T Gomment 3/29/2008 za hr summary Measure rig floor to top of starting flange to be 41.23' RKB (Starting head 2" (.17') above pad level = 41.40' for pad level. Lounsberry drawing CEA-D1 CX-6103D31 Rev 6 dated 5/12/03 says original ground level 53.8' and pad 59.1', therfore RKB = 100.5' MSL for Doyon Rig 15. Note: Difference between Doyon Rig 141 and Doyon Rig 15 is 13.3' to 13.67'. Orient Vetco Gray multibowl, tighten lockdown screws, test graylock to 500 and 1000 psi for 10 min- good test. Installed double valve on annulus. Set 13-5/8" BOP stack with 11" 5m adapter spool on wellhead and tighten same, nipple up BOP system. Rig up to test BOPE. Fill stack with water. Test BOPE: Tested annular with 4-1/2"and 4" test joint, test upper pipe rams (3-1/2" x 6") with 4-1/2", 4" and 5" test joint. Test lower pipe rams with 7-5/8" test joint. Test blind rams. Test 4" XT-39 floor safety valve and Dart valve. Test 4-1/2" IF dart valve. Test upper and lower IBOP on top drive. Test all valves in choke manifold, and tested manual and HCR valves on kill and choke line. Performed Koomey test with 3100 psi initial, after operating rams 1600 psi, 200 psi build up in 42 seconds, full charge in 3 min 20 seconds, 5 bottle average .All tests were held 5 minutes and charted. Tested to 250 psi low and 3000 psi high.Witness of test waived by AOGCC inspector John Crisp. Rig down testing equipment, blow down choke manifold, choke and kill lines. Set Vetco Gray wear bushing. Run in with Baker Oil Tools retrieval tool to engage 9-5/8" retrievamatic, close floor safety valve, screw into retrievamatic, open valve- well static, release packer, well static, break floor safety valve, pull out of the hole with retrievamatic, break and lay down. Rig up to pull and stand back the 4-1/2" 12.6 ppf L-80 IBT-m tubing string. Pulling tubing, removing clamps, spool up TEC wire for the guages. Strap pipe in derrick. Depth @ midni ht 2970' Do on 15 RKB a Total of 109 'ts out of the hole + first GLM and u s . 00:00 00:30 0.50 0 0 INTRM1 WELCTL NUND P Orient New wellhead with punch marks on the conductor. Verified alignment with punch marks. Tighten lockdown screws to 9-/8" hanger extended neck to approximately 300 ft lbs. 00:30 01:15 0.75 0 ~ 0 INTRM1 WELCTL OTHR P Install double valves on the annulus. Test graylock connection to 500 and 1000 psi for 10 minutes each. Good test. 01:15 01:30 0.25 0 0 INTRM1 WELCTL NUND P Set 13-5/8" BOP stack w/ 11" 5m spool on the Vetco/Gray multibowl wellhead. 01:30 04:00 2.50 0 0 INTRM1 WELCTL NUND P Install tiedowns, install choke hose, be-I nipple and flowline. Install drip pan. tighten bolts on the 11" 5m flan e. 04:00 05:30 1.50 0 0 INTRM1 WELCTL OTHR P Rig up to test BOPE. Fill stack with water. Page 8 of fa€t ~ ~ Time Logs __ Date From __ To Dur S. Depth De th E. Phase Code Subcode T Comment_ 05:30 17:15 11.75 0 _ 0 INTRM1 WELCTL BOPE P Test BOPE. Tested annular with 4-1/2"and 4" test joint, test upper pipe rams (3-1/2" x 6") with 4-1/2", 4" and 5" test joint. Test lower pipe rams with 7-5/8" test joint. Test blind rams. Test 4" XT-39 floor safety valve and Dart valve. Test 4-1/2" IF dart valve. Test upper and lower IBOP on top drive. Test all valves in choke manifold, and tested manual and HCR valves on kill and choke line. Performed Koomey test with 3100 psi initial, after operating rams 1600 psi, 200 psi build up in 42 seconds, full charge in 3 min 20 seconds, 5 bottle average .All tests were held 5 minutes and charted. Tested to 250 psi low and 3000 psi high.Witness of test waived by AOGCC inspector John Cris . 17:15 17:45 0.50 0 0 INTRM1 WELCTL OTHR P Rig down testing equipment. Blow down the choke and kill lines. Blow down the choke manifold. 17:45 18:00 0.25 0 0 INTRM1 RPCOM OTHR P Install Vetco Gray wear bushing. 10-1/2" OD, 9-3/4" ID, 4.73' long. Run in 2 lockdown screws. 18:00 19:30 1.50 0 0 INTRM1 WELCTL OTHR P Rig up to retrieve the 9-5/8" storm packer (Model "EA" retrievamatic). Run in with running tool, close floor safety valve, screw into packer, open valve- well static, pull packer free, well static, release packer, slackoff and break and remove floor safety valve. Pull packer to the floor, break and la down same. 19:30 21:00 1.50 0 0 INTRM1 RPCOM RURD P Rig up to pull the 4-1/2" 12.6 ppf L-80 IBT-m completion. Rig up Baker spooling unit for the TEC wire. Rig up GBR casing tools. Install stripping rubbers, Cavins air slips. Make up floor safety valve with crossover to 4-1 /2" IBT. Hold prejob safety meetin 21:00 00:00 3.00 0 0 INTRM1 RPCOM TRIP P Pull out of the hole w/ 4-1/2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap stands. Spool up the TEC wire. Monitor well on the trip tank.A total of 109 jts plus the first GLM is out of the hole. rage 7 ~t 60 ~ ~ Time Logs __ _ de T Comment i Date From To Dur S. Depth E. Depth Phase Code Subco 3/30/2008 _ 2a hr summary Continue to pull out of the hole with the 4-1 /2" completion assembly, standing back a total of 66 stands, layind odwn last 5 joints along with the rest of the jewelry. Rig down GBR casing equipment. Pickup and make up BHA #1 (9-5/8" scraper), pickup 5"drill pipe and run in the hole to 5328', circulate, slip and cut drilling line, inspect derrick, service rig, pull out of the hole, lay down scraper. Pickup/makeup Baker "K-1" Mech cement retainer (size 6AA/9.6", Comm. No. H400-21-6322), pickup more drill pipe and run in the hole to 2958', run 6 stands from the derrick, then pick up a jt of 5" HWDP, set retainer top @ 3535', lay down a jt of 5" HWDP, rig up then test casing and retainer to 3000 psi f/ 30 minutes, charted test- good test. Rig down test equipment. Pull out of the hole with running tool and lay down. Pickup and run in the hole 30 jts of 5" HWDP for the whi stock run.. 00:00 02:45 2.75 0 0 INTRM1 RPCOM TRIP P Continue to pull out of the hole w/ 4-1/2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap stands. Spool up the TEC wire. Monitor well on the trip tank. A total of 198 jts (66 stands} plus one GLM removed from well. 02:45 04:00 1.25 0 0 INTRM1 RPCOM PULD P Continue to pull out of the hole w/ 4-1 /2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap jewlery and 5 more jts + cut off jt 22.30', another GLM, and Baker guage carrier, and Baker CMU. Spool up the TEC wire. Monitor well on the trip tank. Calculated fill 31.5 bbls, actual 34.5 bbls (difference because of clamps. A total of 203 jts plus two GLM's, guage carrier, sliding sleeve and cut off jt removed from well. Sixty six stands in the derrick, five loose jts + cut off jt. Total length removed from well= 6334.45'. Removed a total of 209 across the collar clamps, and 12 mid jt clamps. Removed The splice clamp (splice of both lines from ua es) and TEC Gua a clam . 04:00 05:00 1.00 0 0 INTRM1 RPCOM RURD P Rig down GBR equipment. Clear and organize floor. Brak out crossover from floor safe valve. 05:00 08:15 3.25 0 0 INTRM1 STK OTHR P Pickup and makeup BHA #1. Make up 8-1/2" bit, 9-5/8" scraper, bit sub with float, one stand of 5"drill pipe, jars, 5 jts of 5" HWP, then continue to pickup/makeup/ run in the hole from the pipe shed, 5"drill pipe Rabbit to 2-5/16" . 08:15 08:30 0.25 0 0 INTRM1 STK CIRC P Filled pipe @ 2663' and circulated, pumping 800 gpm w/ 760 psi. Circulated 151 bbls. 08:30 10:45 2.25 0 0 INTRM1 STK OTHR P Continue to pickup/makeup/ run in the hole from the pipe shed, 5" drill i e Rabbit to 2-5/16" . 10:45 11:15 0.50 0 0 INTRM1 STK CIRC P Filled pipe @ 5328' and circulated, pumping 1160 gpm w/ 760 psi. Circulated 262 bbls. PU wt 160k, SO wt 132k. Pae~e 8 ca{ fiQ ~ ~ Time Lo s ~_ ---- -- Date From To Dur 5 De th E. De th Phase Code_Subcode T Comment __ ___ 11:15 11:30 0.25 0 0 INTRM1 RIGMNT SFTY P Pre job safety meeting on slip and cuttin drillin line. 11:30 12:45 1.25 0 0 INTRM1 RIGMNT SVRG P Slip and cut 114' of 1-3/8"drilling line. Adjust brakes on the drawworks. Monitor well on the trip tank. 12:45 13:15 0.50 0 0 INTRM1 RIGMNT SFTY P Perform derrick inspection. 13:15 14:15 1.00 0 0 INTRMI RIGMNT SVRG P Service top drive, blocks, and drawworks. 14:15 15:30 1.25 0 0 INTRM1 STK TRIP P Pull out of the hole on elevators with BHA #1 (9-5/8" scraper). Monitor well on the tri tank. 15:30 16:00 0.50 0 0 INTRM1 STK PULD P Lay down Baker 9-5/8" scraper. 16:00 16:30 0.50 0 8 INTRM1 STK PULD P Pickup/makeup Baker 9-5/8" Bridge plug (Baker "K-1" Mech Cement Retainer, Size 6AA/9.6", Comm No. H400-21-6322 . 16:30 18:45 2.25 0 0 INTRMI STK TRIP P Trip in the hole picking up 5"drill pipe from the pipe shed. Monitor well on the trip tank. PU wt 125k, SO wt 115k. A total of 93 ~ts icked u . 18:45 19:30 0.75 0 3,535 INTRM1 STK TRIP P Continue to run in the hole with the 9-5/8" bridge plug. Run 6 stands from the derrick, then pickup a single of 5" HWDP. PU wt 135k, SO wt 120k. 19:30 19:45 0.25 3,535 3,535 INTRM1 STK OTHR P Set bride lu to 3535'. Then la down the 5" HWDP. 19:45 20:15 0.50 3,535 3,535 INTRM1 DRILL RURD P Rig up testing equipment to test casing. Fi112" hose with fluid. circulate air out of the kill line. 20:15 21:15 1.00 3,535 3,535 INTRM1 DRILL DHEQ P Test the 9-5/8" casing and brid e plug to 3000 psi. Test for 30 minutes. Chart test. Pumped @ 4 spm w/ a ~ total of 36 strokes pumped. Good test. 21:15 21:30 0.25 3,535 3,535 INTRM1 DRILL RURD P Rig down testing equipment. Blow down the kill line. Bring whipstock tools to the floor. 21:30 22:45 1.25 3,535 3,535 INTRM1 STK TRIP P Pull out of the hole with Baker runnin tool. 22:45 23:00 0.25 3,535 3,535 INTRMI STK PULD P Lay down the Bridge plug running tool. 23:00 00:00 1.00 3,535 3,535 INTRM1 STK PULD P Pickup and run in the hole 30 jts of 5"drill i e. Rabbit to 2-5/6". Pride gat 6(t Time Logs - - ---- Date From___To Dur S. Depth E Depth Ph„e__Code Suhcode T Comment _ 3/31/2008 zahrSummarv Pull out of the hole with 10 stands of 5" HWDP, strap same. Pickup/makeup Baker 8-5/8" milling assembly with Sperry Sun MWD, stand back in the derrick. PU whipstock, bolt mills to whipstock w 45k shear bolt. Orient MWD to whipstock face. Upload MWD, continue to build BHA, shallow pulse test MWD @ 1050'. Trip in with the whipstock assembly to 3430', makeup top drive to next stand, orient whipstock to 60? right of high side, makeup a single 5" HWDP, set down on the Baker "K-1"retainer which was set @ 3535', shear anchor, shear bolt on mills, lay down single 5" HWDP, displace well to 9.0 ppg LSND mud. Acquire slow pump rates. Rotate to the top of 9-5/8" whipstock @ 3513' and proceed to mill window, bottom of window @ 3530' starter mill (8-1/2") to 3549'. Circulate a sweep while working to clean up window. Pull out of the hole one stand, rig up to perform Leak Off Test, Perform LOT to 12.2 ppg (420 psi, 8.9 ppg MW, 2455' TVD), rig down testing equipment, monitor well, pump dry job, pull out of the hole, download Sperry MWD, upload MWD, stand back. Finish pulling out of hole with mills, gauge and lay down same- OK. Wash stack with stack washing tool. Blow down the choke and kill lines, blow down the top drive. Service wear bushing. Clean and clear rig floor. 00:00 00:45 0.75 1,050 0 INTRM1 STK TRIP P Pull out of the hole with 10 stands of 5" HWDP. Stra drill i e. 00:45 02:00 1.25 0 0 INTRM1 STK WPST P Pickup milling BHA: Make up mills with MWD, stand back in the derrick. 02:00 02:30 0.50 0 27 INTRM1 STK PULD P Pickup 9-5/8" whipstock, make up to the mills. wei ht 10k . 02:30 03:00 0.50 27 27 INTRM1 STK OTHR P Orient Sperry Sun MWD to whi stock. 03:00 04:15 1.25 27 100 INTRM1 STK OTHR P Upload software for Sperry Sun MWD. 04:15 05:30 1.25 100 1,050 INTRM1 STK TRIP P Pickup Baker bumper sub, then run 10 stands of 5"drill i e. 05:30 05:45 0.25 1,050 1,050 INTRM1 STK OTHR P Shallow pulse test MWD. Pumping 650 gpm w/ 1360 psi. PU wt 120k, SO wt 125k. 05:45 07:45 2.00 1,050 3,430 INTRM1 STK TRIP P Trip in the hole with 9-5/8" whipstock. Fill pipe every 25 stands.Monitor well on the trip tank.. PU wt 150k, SO wt 125k. 07:45 08:15 0.50 3,430 3,520 INTRM1 STK OTHR P Fill pipe. Orient whipstock to 60 deg right of high side. Work pipe from 3430' to 3520'. Pumping 625 gpm w/ 1540 si. 08:15 08:30 0.25 3,520 3,535 INTRM1 STK TRIP P Pick up a single of 5" HWDP, RIH to set down on the retainer @ 3535'. Set down, observed shear @ 105k on the weight indicator (20k) to shear anchor. Slacked off a couple of times with bumper sub to shear mills bolt. whi tock 3513'. After Free from whipstock: PU wt 150k, SO wt 128k. 08:30 08:45 0.25 3,535 3,505 INTRM1 STK OTHR P Lay down single of 5" HWDP. Pre job safety meeting on displacement from 8.5 ppg seawater to 9.0 ppg LSND mud. 08:45 09:00 0.25 3,505 3,505 INTRM1 STK CIRC P Displace well to 9.0 ppg LSND mud. Pumping 625 gpm w/ 1310 psi. Pum ed a total of 251 bbls. 09:00 09:15 0.25 3,505 3,513 INTRM1 STK CIRC P Obtain slow pump rates. Rotate down to the top of the whipstock @ 3513'. 60 m 8-9k ft Ibs of for ue. ~...-...... ~._ f'~~~ 1~ oaf 6i1 Time Logs _ _ _ Date From To Dur S. Depth__E_Depth Phase. Code Subcode T Comment 09:15 12:00 2.75 3,513 3,522 SURFA( STK WPST P Mill window in the 9-5/8" 40ppf L-80 BTC-M casing from 3513' to 3522'. Rotate 80 rpm w/ 7-8k ft Ibs of torque t on bottom and 6-7k ft Ibs off bottom. 1 Weight on mills 4K. Pumping 425 gpm w/ 680 psi. PU wt 150k, SO wt 128k. Rotating weight 138k. Pump a 40 bbls high vis sweep while milling @ 3520' (middle of window). Observed 20% increase in cuttin s. 12:00 14:00 2.00 3,522 3,549 SURFA( STK WPST P Continue to mill window in the 9-5/8" 40ppf L-80 BTC-M casing from 3522' to bottom of the window @ 3530' continue milling to 3459' to get upper mill to the bottom of the window. Weight on mills 4K. Rotate 80 rpm w/ 7-9k ft Ibs of torque on bottom and 7k ft Ibs off bottom. Pumping 425 gpm w/ 680 psi. PU wt 150k, SO wt 128k. Roting weight 138k. Top of window @ 3513' (2448' ND), Bottom of window @ 3530' 2455' ND . 14:00 15:30 1.50 3,549 3,549 SURFA( STK CIRC P Circulate and work window. Pump a 40 bbls high vis sweep. Pump two bottom's u .Hole cleaned u ood. 15:30 16:00 0.50 3,549 3,507 SURFA( STK TRIP P Pull out of the hole one stand. Blow down the top drive. Rig up for leak off test. 16:00 16:45 0.75 3,507 3,507 SURFA( DRILL LOT P P rm leak off test using 8.9 ppQ LSND mud. Hole depth 3549' (2463' ND), TOW 3513' (2448' ND), BOW 3530' 2455' ND .LOT was 12.2 EMW with 420 si.. 16:45 17:15 0.50 3,507 3,507 SURFA( DRILL RURD P Rig own testing equipment. 17:15 18:00 0.75 3,507 3,057 INTRM1 DRILL OWFF P Monitor well. Mix dry job, clean trip tank. 18:00 18:15 0.25 3,057 3,057 INTRM1 STK CIRC P Pump a 30 bbl dry job, 2 ppg over mud weight. Install stripping rubbers and air sli s. 18:15 19:15 1.00 3,057 1,032 INTRM1 STK TRIP P Pull out of the hole with the milling assembly. Monitor well on the trip tank. 19:15 19:45 0.50 1,032 75 INTRM1 STK TRIP P Work the bottom hole assembly. Stand back 10 stands of 5"drill i e. 19:45 21:00 1.25 75 23 INTRM1 STK OTHR P Make up 10' pup jt. Pull out of the hole, Download Sperry Sun MWD. Upload MWD for drilling assembly. Stand back in the derrick. 21:00 21:15 0.25 23 0 INTRM1 STK PULD P Break and lay down Baker upper string mill (8-5/8"), flex joint, lower string mill (8-3/8"), and window mill ('-1/2"). Gauge mills. Starter mill was 1/8" under gauge, upper mill 8-5/8" OK. t'age 91 ~t 6t4 ~~~- H ~~~ ~ ~ Time Logs _ ~ _____ _ __ ___ Date _ From_To Dur S. De th E Depth Ph~,Se_Code Subcode T_Comment __ 21:15 22:15 1.00 0 0 INTRM1 STK CIRC P Makeup stack washing tool, run in to 45'. Wash stack by rotating while pumping 650 gpm. Work up and down. 22:15 22:45 0.50 0 0 INTRM1 STK OTHR P Blow down and flush choke and kill line. Blow down the to drive. 22:45 23:45 1.00 0 0 INTRM1 STK OTHR P Pull Vetco Gray Wear bushing (10-1/2" OD x 9-3/4" ID x 4.73" long.) Clean u ,ins ect and reinstall same. 23:45 00:00 0.25 0 0 INTRMI DRILL OTHR P Clean and clear rig floor. 4/01 /2008 Pre job safety meeting, lay down 9 stands of 5"drill pipe from derrick, change out Sperry Sun pulsar while waiting on motor with correct bit box (4-1/2" regular), u load MWD and stand back. Pickup/Makeup BHA #4( 9-7/8" bicenter bit w/ 1.76? deg motor), orient, continue to pickup/makeup bottom hole assembly to 356', trip in the hole to 3549', obtain slow pump rates. Drill 9-7/8" intermediate hole f/ 3549' to 3620' before unable to acquire surveys (MWD problem with pulsar. Trouble shoot MWD problems, pump dry job, pull out of the hole, look at the bit- ok, function blind rams and kill and choke line HCR valves, run in, download MWD, change out pulsar, upload MWD, run in hole to 356', shallow test MWD, continue to run in the hole to 3620', drill 9-7/8" intermediate hole to 4160'. 00:00 00:15 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on laying down 5" drill i e from the derrick. 00:15 01:30 1.25 0 0 INTRM1 DRILL PULD P Lay down 9 stands of 5" drill pipe from the derrick. 01:30 02:00 0.50 0 0 INTRM1 DRILL OTHR T Clean and clear ig floor. 02:00 03:15 125 0 0 INTRMI DRILL PULD T Change out Sperry Sun pulsar. while waiting on motor with correct bit box 4-1 /2" Re ular . 03:15 04:00 0.75 0 0 INTRM1 DRILL OTHR T Upload Sperry Sun MWD. 04:00 04:15 0.25 0 0 INTRM1 DRILL TRIP T Stand back MWD. 04:15 04:45 0.50 0 80 INTRM1 DRILL PULD P Pick up and makeup BHA #4 (9-7/8" bi-center bit and Sperry drill motor w/ 1.76? bend. 04:45 05:00 0.25 80 80 INTRM1 DRILL OTHR P Orient Sperry MWD with SperryDrill motor. 05:00 05:45 0.75 80 356 INTRM1 DRILL PULD P a nick up/makeup BHA #4. Drift Flex drill collars to 2.34" while ickin u from the i e shed. 05:45 08:15 2.50 356 3,549 INTRM1 DRILL TRIP P Trip in the hole w/ BHA #4. Monitor dis lacement on the tri tank. 08:15 08:30 0.25 3,549 3,549 INTRM1 DRILL TRIP P Obtain slow pump rates.Pump # 1: 20 spm 170 psi, 30 spm 210 psi. Pump # 2: 20 SPM 170 psi, 30 SPM 210 si. 08:30 09:45 1.25 3,549 3,620 INTRM1 DRILL DDRL P Dril19-7/8" intermediate. 09:45 11:00 1.25 3,620 3,620 INTRMI DRILL OTHR T Sperry Sun MWD problems. Pulsar problem??. Not getting surveys. S er Sun trouble shoot roblem. 11:00 11:15 0.25 3,620 3,620 INTRM1 DRILL OWFF T Monitor well. Install air slips, install stri in rubbers. 11:15 11:30 0.25 3,620 3,620 INTRM1 DRILL CIRC T Pump a dry job. 11:30 12:45 1.25 3,620 356 INTRM1 DRILL TRIP T Pull out of the hole for MWD problem. Monitor wwellon the trip tank. I~~ge 12 ref 6~ Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T Comment 12:45 13:45 1.00 356 80 INTRM1 DRILL OTHR T Stand back BHA. Pull out- look at bit. Functioned blind rams, Kill and choke line HCR valves. Run in hole. 13:45 14:45 1.00 80 80 INTRM1 DRILL OTHR T Download MWD. Change out pulsar. 14:45 15:15 0.50 80 356 INTRM1 DRILL TRIP T Make up BHA. 15:15 15:30 0.25 356 356 INTRM1 DRILL OTHR T Shallow pulse test Sperry Sun MWD. Pumping 550 gpm w/ 1050 si. 15:30 17:00 1.50 356 2,735 INTRM1 DRILL TRIP T Trip in the hole. Monitor well on the tri tank. 17:00 17:15 0.25 2,735 2,735 INTRM1 DRILL CIRC T Fill pipe. Blow down top drive. 17:15 17:30 0.25 2,735 3,620 INTRM1 DRILL TRIP T Continue to trip in the hole. 17:30 18:00 0.50 3,620 3,683 INTRM1 DRILL DDRL P Directional drill 9-7l8" intermediate hole from 3620' to 3683'. 18:00 00:00 6.00 3,683 4,160 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole from 3683' to 4160'. /02/2008 Continue to directional drill 9-7/8" intermediate hole with bicenter bit and motor (1.76? bend) from 4160' to 6054'. Mutual Aid Drill (MAD) was held with Doyon Rig 15, ACS and ADEC. EMOC in Kuparuk was activated and IMT in Anchora a was activated. Started 0635 hrs, ended on the ri 1735 hrs. 00:00 06:00 6.00 4,160 4,586 INTRM1 DRILL DDRL P Continue to directional drill 9-7l8" intermediate hole from 4160' to 4586'. 06:00 12:00 6.00 4,586 5,110 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole from 4586' to 5110'. Max as 64 units. 12:00 18:00 6.00 5,110 5,587 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole from 5110' to 5587'. Max as 54 units. 18:00 00:00 6.00 5,587 6,054 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole from 5587' to 6054'. While drilling @ 5760', Max gas of 665 units. Top of Ugnu C picked @ 5411'. Mutaual Aid Drill (MAD) with ACS h d 3 d rs, en and ADEC. Started 06 5 e on rig @ 1735 hrs. EMOC activated in Kuparuk, IMT activated in Anchora e. 4/03/2008 Continue to directional drill 9-7/8" intermediate hole with bicenter bit and motor (1.76? bend) from 6054' to 6634', circulate 2 bottom's up, then pump a 60 bbl weighted hi vis sweep (11 ppg/200vis) to surface, backream to top of 9-5/8"window @ 3513', pump 2 bottom's up, then pump a 40 bbl hi vis weighted sweep to surface, service the ri ,run in the hole, continue to directional drill from 6634' to 6876'. 00:00 06:00 6.00 6,054 6,443 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. 06:00 09:30 3.50 6,443 6,634 INTRMI DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 1200 units. Page 13 of fi€t ~ ~ Tme Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 09:30 10:15 0.75 6,634 6,634 INTRM1 DRILL CIRC P Circulate bottom's up twice to clean up hole and lower ECD's. Rotate and reciprocate working pipe from 6634' to 6539'. Pumping 640 gpm w/ 2340 psi. Rotate 55 rpm w/ 9k ft Ibs of torque. Max gas 167 units. Initial ECD's 10.36 ppg while rotating, final 10.25 10:15 11:00 0.75 6,634 6,634 INTRM1 DRILL CIRC P Pump a 60 bbls weighted hi vis sweep (11ppg/ 200 vis) around. Continue to rotate and reciprocaate from 6634' to 6539'. Pumping 640 gpm w/ final circulating pressure of 2290 psi. Rotating 55 rpm w! 10k ft Ibs of torque. Max gas 62 units. - Initial ECD 10.25 ppg, Final ECD 10.06 ppg. PU wt 192k, SO wt 138k, Rot wt 160k. 11:00 16:15 5.25 6,634 3,513 INTRMI DRILL REAM P Backream out of the hole. Rotating 50 rpm. Pumping 640 gpm w/ initial pressure of 2450 psi. Heavy cuttings on last four stands out. Initial ECD 10.06 ppg, max ECD while backreaming 10.68 ppg, Final ECD 10.6 the window. 16:15 17:30 1.25 3,513 3,513 INTRM1 DRILL CIRC P Circulate inside the 9-5/8" casing to clean cutting from inside of the casing. Pump two bottom's up, then a 40 bbl weighted hi vis sweep (11 ppg/ 200 vis). Rotate and reciprocate. Pumping 640 gpm w/ 2250 psi. Initial ECD 10.6 ppg, final ECD 10.23 17:30 18:00 0.50 3,513 3,513 INTRM1 RIGMNT SVRG P Service rig, inspect top drive. 18:00 19:30 1.50 3,513 6,634 INTRMI DRILL TRIP P Trip in the hole. Record PU and SO wt's every 5 stands. Monitor displacement on trip tank. 3 bbls less than calculated. 19:30 00:00 4.50 6,634 6,876 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 119 units. 4/04/2008 Continue to directional drill 9-7/8" intermediate hole from 6876' to 7111', pull out of the hole to 7015', pump a 43 bbls weighted hi vis sweep (11.2 ppg/300 vis), reciprocate and rotate f/ 7015' to 6920' while circulating a total of 863 bbls, run in the hole to 7111', continue to directional drill the 9-7/8" intermediate hole section from 7111' to 7860', pump a 40 bbls weighted hi vis sweep (11 ppg/ 250 vis) while working pipe, continue to directional drill 9-7/8" intermediate hole f/ 7860' to 8310'. Circulate 3 open hole volumes (2 bottom's up), obtain slow pump rates, monitor well f/ 30 minutes- static, circulate and condition mud and hole for casing by um in a 43 bbl swee 10 / 300+ vis ,follow with 150 bbls of mud at midni ht. 00:00 03:30 3.50 6,876 7,111 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Page 1 ¢ of SQ Time La~s___ __ _ u Date From To Dur 5 De th E. De th T Comment Phase Code Subcod e 03:30 03:45 0.25 7,111 7,015 INTRM1 DRILL _ _ REAM _ P Survey then backream from 7111' to 7015'. Load the drill pipe with 43 bbls of weighted hi vis sweep (11.2 ppg/300+ vis). Rotate 60 rpm w/ 11-12k ft Ibs of torque. Pumping 640 gpm w/ 2250 psi. Stand back a stand. 03:45 04:45 1.00 7,015 6,920 INTRM1 DRILL REAM P Backream from 77015' to 6920'. Rotate 60 rpm w/ 11-12k ft Ibs of torque. Pumping 640 gpm w/ 2250 psi. Rotating PU wt 152k. Initial ECD's were 10.23 ppg, final ECD's were 10.15 ppg EMW. Pumped a total of 863 bbls. Increase of cuttings were observed from the higher flow rate and the sweep brought back an increase of a rox 50% as well. 04:45 05:00 0.25 6,920 7,113 INTRM1 DRILL TRIP P Trip in the hole, no problems. 05:00 06:00 1.00 7,113 7,205 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 1220 units. 06:00 12:00 6.00 7,205 7,586 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 3750 units. 12:00 15:00 3.00 7,586 7,860 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 3750 units. 15:00 16:15 1.25 7,860 7,860 INTRM1 DRILL CIRC P Circulate a 40 bbls weighted hi vis sweep (11 ppg! 250 vis). Work pipe 95' f/ 7860' to 7765'. Pumping 640 gpm w/ 2550 psi initial and 2480 psi final. Rotate 60 rpm w/ 10k ft Ibs of torque. ECD's dropped to 10.62 ppg. Observed 40% increase in cuttings with swee . 16:15 18:00 1.75 7,860 8,045 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 650 units. 18:00 20:45 2.75 8,045 8,310 INTRM1 DRILL DDRL P Continue to directional drill 9-7/8" intermediate hole. Max gas 823 units. 20:45 21:30 0.75 8,310 8,310 INTRM1 DRILL OTHR P Acquire final MWD sum. Re-shoot survey's two more times. 86.93 deg/ 181.09 deg azmuith. Max gas 1924 units. 21:30 22:00 0.50 8,310 8,310 INTRM1 DRILL CIRC P Circulate, rotate and reciprocate f/ 8310' to 8225'. Rotate 60 rpm w/ 11 k ft Ibs of torque. Pumping 640 gpm w/ 2720 psi, 9.3 ppg MW and ECD's 10.83 ppg initial. Including surveys -- pumped about 3 open hole volumes or 2 Bottom's u . 22:00 22:15 0.25 8,310 8,225 INTRM1 DRILL TRIP P Stand back stand #84. E~~a~ ~5 of 6i? • Time Logs __- ' Date Fram To Dur S. De th E. De th Phase Code Subcode T Comment 22:15 23:00 0.75 8,225 8,225 INTRM1 DRILL CIRC P Circulate bottom's up while conditioning mud and hole for casing. Circulate, rotate and reciprocate f/ 8225' to 8135'. Rotate 60 rpm w/ 11 k ft Ibs of torque. Pumping 640 gpm w/ 2720 psi, 9.3-9.2 ppg MW and ECD's 10.83 ppg initial, final 10.48 ppg w/ 9. 2 ppg MW. Pumped Bottom's up + . Obtain slow um rates. 23:00 23:30 0.50 8,225 8,225 INTRM1 DRILL OTHR P Monitor well. Work pipe 90' with pumps off. Observe well with pumps off for 30 minutes. Hole appears to be in ood condition- static. 23:30 00:00 0.50 8,225 8,225 INTRM1 DRILL OWFF P Circulate: Pump 100 bbls then 43 bbl Hi vis sweep (10 ppg/ 300+ vis), followed with 150 bbls of mud @ midnight. Pumping 640 gpm w/ 2650 psi. Rotate 60 rpm w/ 12k ft Ibs of for ue. 4/05/2008 Continue to circulate and condition mud and hole for casing by pumping a 43 bbl sweep (10 ppg/ 300+ vis),to surface, backream out from 8135' to 7945', work on rheostat on the driller's console (#2 mud pump), continue to backream out of the hole to the window @ 3513', circulate to clean up casing, pump a 40 bbl sweep (9.5 ppg/300+ vis), spot steel tube pill (65 bbls), pump steel tube- follow with dry job to leave in the annulus of the 9-5/8" casing up to 2250', drop HAGGARD ID mud wiper (Mud Dog), pull out of the hole laying down 5"drill i e, download MWD la down BHA, clean floor, ull wear bushin , ri u to run 7-5/8" casin . 00:00 00:45 0.75 8,225 8,225 INTRM1 DRILL CIRC P Finish pumping 43 bbl sweep (10 ppg/300+ vis) out of the hole. Pumping 640 gpm w! 2650 psi. Rotate 60 rpm w/ 12k ft Ibs of torque. Pumped a total of 906 bbls. Worked i e from 8225' to 8135'. 00:45 01:00 0.25 8,225 8,135 INTRM1 DRILL OWFF P Stand back stand. Monitor well for flow- static. 01:00 01:30 0.50 8,135 7,945 INTRM1 DRILL REAM P Backream out of the hole. Pulling speed 15 to 20 ft minutes. Pumping 640 gpm w/ 2650 psi. Rotate 60 rpm w/ 12k ft Ibs of torque. Clean hole ECD's 9.92 ppg. Initial ECD's while backreamin 10.36 01:30 04:30 3.00 7,945 7,945 INTRM1 RIGMNT RGRP T Repair rheostat on driller's console for controllin # 2 mud um . 04:30 06:00 1.50 7,945 7,494 INTRM1 DRILL REAM P Continue to backream out of the hole. Pulling speed 15 to 20 ft minutes. Pumping 640 gpm w/ 2650 psi. Rotate 60 rpm w/ 12k ft Ibs of torque. Clean hole ECD's 9.92 ppg. Initial ECD's while backreaming 10.36 06:00 06:30 0.50 7,494 7,200 INTRM1 DRILL REAM P Continue to backream out of the hole. Pulling speed 15 to 20 ft minutes. Pumping 640 gpm w/ 2650 psi. Rotate 60 rpm w/ 12k ft Ibs of torque. Clean hole ECD's 9.92 ppg. Initial ECD's while backreaming 10.30 E~~~ 16 of 62) ! • _ Time Logs __ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 06:30 07:30 1.00 7,200 6,730 INTRM1 DRILL REAM P Continue to backream out of the hole. Pulling speed 20 to 25 ft minutes. Pumping 640 gpm w/ 2650 psi to 2110 psi. Rotate 60 rpm w/ 12k ft Ibs of torque. Clean hole ECD's 9.92 ppg. Initial ECD's while backreamin 10.30 07:30 08:45 1.25 6,730 6,730 INTRM1 RIGMNT RGRP T Repair rheostat on driller's console for controlling # 2 mud pump. Circulate with # 1 mp, pumping 445 gpm w/ 1120 psi. Rotating 60 rpm w/ 9-10 k ft Ibs of torque. ECD's 9.98, max as 120 units. 08:45 12:00 3.25 6,730 4,810 INTRM1 DRILL CIRC P Continue to backream out of the hole. Pulling speed 20 to 25 ft minutes. Pumping 640 gpm w/ 2110 to 1950 psi. Rotate 60 rpm w/ 17k ft Ibs of torque. ECD's 9.76 ppg. PU wt 165k, SO wt 130k, Rot wt 148k 12:00 14:30 2.50 4,810 3,497 INTRM1 DRILL REAM P Continue to backream out of the hole. Pulling speed 20 to 25 ft minutes. Pumping 640 gpm w/ 1950 to 1720 psi. Rotate 60 rpm w/ 4 k ft Ibs of torque. ECD's 9.76 ppg. PU wt 140k, SO wt 125k, Rot wt 137k 14:30 15:45 1.25 3,497 3,497 INTRM1 DRILL CIRC P Circulate and condition mud and hole (casing) for casing. Circulate bottom's up by pumping 650 gpm w/ initial pressure of 1840 psi. Rotate and work pipe from 3497' to 3402'. Rotate 60 rpm w/ 4k ft Ibs of torque. Initial ECD's 9.76 ppg, Pump 60 bbl sweep with good cuttings returns on sweep. Continue to curculate a total of 5 bottom's up. Final circulating pressure was 1750 psi. and final ECD's were 9.66 15:45 16:15 0.50 3,497 3,497 INTRM1 DRILL CIRC P Circulate and spot 60 bbls of steel tube pill (6%), with top of pill @ 2250'. Pill was pumped, chased with 31 bbls of mud, then 20 bbl dry job, chased with 12 bbls of mud. Drop the HAGGARD ID pipe wiper (Mud Dog). Blow down the to drive. 16:15 18:00 1.75 3,497 2,598 INTRM1 DRILL PULD P Pull out of the hole laying down the 5"drill pipe. Monitor well on the trip tank. 18:00 20:30 2.50 2,598 356 INTRM1 DRILL PULD P Continue to pull out of the hole laying down the 5"drill pipe. Monitor well on the tri tank. 20:30 21:00 0.50 356 80 INTRM1 DRILL PULD P Lay down BHA. Break and grade bit. 21:00 21:30 0.50 80 80 INTRM1 DRILL P Download Sperry Sun MWD. 21:30 22:30 1.00 80 0 INTRM1 DRILL PULD P Lay down BHA. 22:30 23:00 0.50 0 0 INTRM1 CASING OTHR P Pull Vetco Gray wear bushing (10-1 /2" OD x 9-3/4" I D x 4.73 " Ion ). Face 1? of fi{i I Time Logs Date From Ta Dur S. Depth E. De th Phase Code Subcode T Comment __ 23:00 00:00 1.00 0 0 INTRM1 CASING RURD P Ri u to run 7-5/8" 29.7 f L-80 H dri1513 intermediate casin . 4/06/2008 Continue to rig up to run 7-5/8" casing, pre job safety meeting, run 7-5/8" 29.7 ppf, L-80 Hyd 513 intermediate casin er detail to 8302', Ri u Dowell/Schlumber er cement head and lines. 00:00 01:45 1.75 0 0 INTRM1 CASING RURD P Continue to rig up to run 7-5/8", 29.7 ppf, L-80, Hydril 513 intermediate casin . 01:45 02:15 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting on running intermediate casing. Rig Crew, casing crew, Hydril reps (Unique Machine 02:15 06:00 3.75 0 525 INTRM1 CASING RNCS P Run casing. Baker lock to the pin of jt #4. Circulate 30 bbl through float equipment after joint #4. Installing Centek 7-5/8" x 9-7/8" centralizers with sto son the center of the ~oints. 06:00 13:30 7.50 525 3,480 INTRM1 CASING RNCS P Continue to run 7-5/8", 29.7 ppf, L-80, Hydril 513 intermediate casing. Obtain PU and SO wt's per rig en ineer. Good dis lacement. 13:30 14:00 0.50 3,480 3,480 INTRM1 CASING CIRC P Circulate bottom's up above the window. Pumping 3.5 bpm w/ 360 psi, 29 % flow. Pumping 4 bpm w/ 330 psi, 29% flow. Pumping 4.5 bpm w/ 370 psi, 30 % flow. Pumping 5 bpm w/ 420 psi, 32% flow. Pumped a total of 121 bbls. PU wt 142k, SO wt 92k, blocks 73k. 14:00 17:00 3.00 3,480 5,727 INTRM1 CASING RNCS P Continue to run 7-5/8", 29.7 ppf, L-80, Hydril 513 intermediate casing. Obtain PU and SO wt's every 10 jts, after jt # 50. Good displacement to 5769' then dis lacement became a little less than calculated. PU wt 180k, SO wt 122k, blocks 73k. 17:00 18:00 1.00 5,727 5,809 INTRM1 CASING RNCS P Circulated with Frank's fillup tool while running casing f/ 5769' to 5809'. Pumping 3.5 bpm w/ 420 psi. Circulated enough to Move open hole volume up inside of the 9-5/8" casing. Change shaker screens to 170 mesh. 18:00 20:00 2.00 5,809 7,140 INTRM1 CASING RNCS P Continue to run 7-5/8", 29.7 ppf, L-80, Hydril 513 intermediate casing. Obtain PU and SO wt's every 10 jts. Monitor dis lacement. 20:00 20:30 0.50 7,140 7,140 INTRMI CASING CIRC P Circulate and condition mud. Pumping 4 bpm w/ 450 psi, 30% flow. Increase rate to 5.5 bpm w/ 550 psi and 33% flow. Pumped a total of 138 bbls. PU wt 210k, SO wt 135k. E~ago 18 of 60 • ...Time Logs Dat_e_ From _ To _ Dur S Depth E_ Depth Phase Code Sub_codeT _ T Comment 20:30 22:30 2.00 7,140 8,310 INTRM1 CASING RNCS P Continue to run 7-5/8", 29.7 ppf, L-80, Hydril 513 intermediate casing. Obtain PU and SO wt's every 10 jts. Changed out jt # 205 for jt # 194 (bad box). Monitor displacement. Running s eed 40 to 60 ft/min. 22:30 22:45 025 8,310 8,310 INTRM1 CASING CIRC P Circulate and condition mud. Pumping 4 bpm w/ 460 psi, 30% flow. Circulate a total of 50 bbls prior to removal of Frank's fillup tool. PU wt while pumping 205k, SO wt 128k. 22:45 23:15 0.50 8,310 8,310 INTRM1 CASING RURD P Remove Frank's fillup tool. Blow down the to drive. 23:15 23:30 0.25 8,310 8,310 INTRM1 CASING RNCS P PU/MU a 19.62' pup jt, then a 4.63' pup jt, then the landing joint and run in the hole. PU wt 235k, SO wt 132k. 23:30 00:00 0.50 8,310 8,310 INTRM1 CEMEN" RURD P Remove GBR spiders, makeup Dowell/Schlumberger cementing head and cement lines. Blow line down to the cemenet trucks- ood. 4/07/2008 Circulate 564 bbls of mud, conditioning mud/ hole for pumping cement. Held pre job safety meeting, Dowell pumped 38.6 bbls of Mud push II(10.5 ppg), dropped bottom plug, mixed and pumped 195.1 bbls of DeepCrete (12 ppg) (2.46 cuft/sx yield) (445 sx), dropped top plug, pumped 10 bbls water, rig displaced and bumped plug with calculated strokes and bumped with 1600 psi, held 5 minutes, checked floats-OK. CIP 0430 hrs 4/7/2008. Rig down cementing equipment. Vacuum out the landing joint, break and pickup the BOP stack with upper wellhead, install casing slips. Set 110k on the slips (Weight indicator of 180k). Cut 7-5/8" casing, lay down landing joint, dress casing for packoff and install same, tighten lockdown screws, set upper wellhead and BOP's back on lower spool. Tighten connection. Test packoff to 5000 psi. Perform LOT on 9-5/8" x 7-5/8" annulus (13.8 ppg) 600 psi with top of cement @ 4751', 9-5/8" window top at 3513' (2448.5' TVD), flush annulus with a total of 77.6 bbls of water. Lay down 5" drill pipe from derrick (43 stands 5" = 10 stands of 5" HWDP). Change saver sub on the top drive to 4" XT- 39. Service rig, install Vetco Gray wear bushing, install mouse hole in the rotary table, pre job safety meeting, Pickup/makeup, stand back in the derrick a total of 10 stands of hybrids ((2) 5" DC's with a 4" HWDP on top) @ midnight.. Little Red freeze protected the 9-5l8" x 7-5/8" annulus with 50 bbls of diesel (2584' +RKB 40'= 2624' RKB 2081' TVD 00:00 02:00 2.00 8,310 8,310 INTRM1 CEMEN" CIRC P Circulate and condition mud and hole for cementing. Start w/Initial circulating rate of 3.5 bpm w/ 330 psi, 28% flow for 60 bls, then increase to 5 bpm w! 380 psi, 33% flow until OH volume of 183 bbls total was pumped. Continue to pump increasing rate to 6 bpm w/ 490 psi, 34% flow. Reciorocated oioe 35' to 40' str ke. Circulated a total of 564 bbls. Held PJSM while circulating. Prior to circulating PU wt 235k, SO wt 132k with no pumps. After circulating hole PU wt 235k, SO wt 140k. ®~~ ~ P~~ 19 ofi 6fl • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 02:00 03:15 1.25 8,310 8,310 INTRM1 CEMEN" OTHR P Shut down pumping. Turn over to Dowell cementers. Dowell pump 5 bbls water, 3" line in cellar leaking (Rig). Blow down line. Replace seal ring in union. Dowell pump 2.5 bbls water, then pressure test to 3600 psi-OK. Dowell mix and pump 38.6 bbls MudPush II (10.5 ppg) @ 5.6 bpm w/ 310 psi- shut down, drop bottom plug, mix and pump 195.1 bbls DeepCrete cement (12 ppg) (2.46 cuft/sx) (Mix water 8.249 gal/sx) (total of 445 sx), pumping 6 bpm average with initial pressure of 290 psi and final of 72 psi. Drop top plug, Dowell displace with 10 bbls of water pumping 6 bpm w/ 4 si then turn over to the ri . 03:15 04:45 1.50 8,310 8,310 INTRM1 CEMEN- DISP P Rig displaced cement by pumping 9.1 ppg MOBM @ 6 bpm w/ initial of 250 psi until 337 bbls were displaced, then slowed to 3 bpm w/ initial of 850 psi. Final circulating pressure was 1025 psi, bumped plug with 3670 strokes with 1600 psi, held five minutes, bleed off pressure- floats held. CIP 0430 hrs 4/7/2008. Pipe was reciprocated 35-40' until cement rounded the shoe (PU wt 220K, SO wt 135k), then reciprocated 25' strokes (PU 210k, SO 130k), then 15' (PU 200k, SO 105k) and finally 5' (PU 230K, SO 85K) until ran out of down wt with 97 bbls of cement around the shoe, Quit reciprocating with pipe 1' high of planned depth.. Held 220k on the wei ht indicator. 04:45 06:00 1.25 8,310 8,310 INTRM1 CEMEN" RURD P Rig down cementing head and lines. Drain BOP stack. Vacuum MOBM fluid from the 7-5/8" landing joint. Nippling down BOP stack,clean and clear ri floor. 06:00 08:00 2.00 8,310 8,310 INTRM1 WELCTt NUND P Separate Vetco Gray MultiBowl wellhead then Raise BOP Stack with upper wellhead.. Wash out the load shoulder for the 7-5/8'' casing slips. Ri u to erform annulur flush. ~ ~~~~ z~ ~~ s~ Time Logs Date From To Dur S Depth E Depth Phase Code Subcode T Comment _ 08:00 09:45 1.75 8,310 . 8,310 INTRM1 WELCTt OTHR P __ Set 7-5/8" casing slps. With weight indicator showing 180k, (Block wt of 70k), set maximum recommended (Vetco Gray) weight of 110k on the slips. Cut Casing above Slips using casing cutter. Lay down landing joint, 4.63' pup and cutoffjoint. Prepare stump for packoff. Install packoff. Run in lockdown screws. Continue cleaning pits. Lay down casing tools from the ri floor. 09:45 10:30 0.75 8,310 8,310 INTRM1 WELCTI NUND P Lower BOP Stack and Tree onto Well Head; Torque all Lock Down Screws and Through Studs. Install flowline and tiedown lines. 10:30 11:15 0.75 8,310 8,310 INTRM1 WELCTL OTHR P Pumped Sealant and Repaired Leaks on Lock Down Screws & Tested Tree to Well Head Connection to 4900 psi f/ 10 Minutes 11:15 12:15 1.00 8,310 8,310 INTRM1 DRILL LOT P Perform LOT on 9 5/8" x 7 5/8" Annulus; Leak Off Occured at 600 psi (13.8 PPG wi ro es Pumped; Pumped a Total of 3.8 Bbls; After Shut In: Pressure Bled Down to 380 Psi after 10 Minutes. Cement was in place 0430 hrs 4/7/2008. Top of cement estimated @ 4751'. Top of window in 9-5/8" casing @ 3513' (2448.5' TVD). No circular chart- did not work. 12:15 13:00 0.75 8,310 8,310 INTRM1 DRILL OTHR P Flush 9 5/8" X 7 5/8" Annulus w/ 77.6 Bbls of Fresh Water at 1.8 BPM 650 Psi. Ri down um in lines. 13:00 17:30 4.50 8,310 8,310 INTRM1 DRILL PULD P Lay down 10 stands of 5" HWDP plus 43 stands of 5"drill pipe from the derrick. Little Red freeze protection on the 9-5/8" x 7-5/8"annulus. Pumped 50 bbls of 7 ppg diesel. Initial pump rate of 1.4 bpm w/ 800 pis, final rate of 1.4 bpm w/ 900 psi. Final static ressure 710 si. 17:30 18:00 0.50 8,310 8,310 INTRM1 DRILL OTHR P Change elevators, remove the mouse hole, clean and clear the ri floor. 18:00 20:30 2.50 8,310 8,310 INTRM1 RIGMNT SVRG P Change out the saver sub on teh top drive from 4-1/2" IF to 4" XT-39. Change bell guide for 4" drill pipe. Chan a heads in the rabber. 20:30 21:15 0.75 8,310 8,310 INTRM1 RIGMNT SVRG P Service top drive, blocks and crown. 21:15 22:00 0.75 8,310 8,310 INTRMI DRILL OTHR P Install Vetco Gray short wear bushing (1.96' long x 10-1/2" OD x 7-3/4" I D . 22:00 22:30 0.50 8,310 8,310 INTRM1 DRILL OTHR P Install the mouse hole in the rotary table to PU 4" drill i e. 22:30 22:45 0.25 8,310 8,310 INTRM1 DRILL SFTY P Pre job safety meeting on picking up, making up, and standing back 4" tubulars. Page 21 ~t 6£~ • Time Logs _ Date From To Dur 5 De th E. De th Phase Code Subcode T Gomment 22:45 00:00 _ 1.25 8,310 8,310 INTRM1 DRILL PULD P Pickup /makeup /standback in the derrick a total of 10 of planned 15 stands of hybrids ((2 5" DC's with a joint of 4" HWDP on top). Drifted to 2.38". 4/08/2008 Continue to pickuplmakeup, stand back in the derrick a total of 15 stands of hybrids ((2) 5" DC's with a 4" HWDP on top), then 10 stands of 4" S-135 dp with WWT super sliders installed on the center of each joint, then 43 stands of drill pipe, pull mouse hole from the rotary table, PJSM, Pickup/makeup BHA, single in from the i e shed with 4"drill i e. 00:00 00:30 0.50 INTRM1 DRILL PULD P Finish picking up /makeup / standback in the derrick a total of 15 stands of hybrids ((2 5" DC's with a joint of 4" HWDP on top). Drifted to 2.38". 00:30 02:15 1.75 INTRM1 DRILL PULD P Pickup/ makeup/ standback 10 stands of 4" S-135 Weatherford dp with a Western Well Tools super slider installed in the center of each ~oint. Drifted to 2.38". 02:15 06:30 4.25 INTRM1 DRILL PULD P Pickup/ makeup/ standback 43 stands of 4" S-135 Weatherford dp. Drifted to 2.38". 06:30 07:15 0.75 INTRM1 DRILL RURD P Remove mouse hole from rotary table, lay down 5" handling e ui ment, clear and clean ri floor. 07:15 08:45 1.50 INTRM1 DRILL PULD P Pick up and make up BHA #5, 5200 GeoPilot w/6-3/4" bit. 08:45 09:30 0.75 INTRM1 DRILL PULD P Download MWD 09:30 10:30 1.00 0 369 INTRM1 DRILL PULD P Continue to pick up and make up BHA. 10:30 11:30 1.00 369 369 INTRM1 DRILL PULD P Re-torque super slider clamps on 10 stands in derrick. 11:30 12:00 0.50 369 650 INTRM1 DRILL TRIP P Single in with slick drill pipe from shed. Drifting to 2.38". Breaking in new drill i e. 12:00 12:30 0.50 650 650 INTRM1 DRILL DHEQ P Shallow test MWD, pumping 250 gpm / 1530 psi, rotating 30 rpm. Test Geo-skid. All tested ood. 12:30 17:00 4.50 650 3,570 INTRM1 DRILL TRIP P Continue tripping in hole from pipe shed. Filling pipe every 25 stands. Breakin in new drill i e. 17:00 18:45 1.75 3,570 3,570 INTRM1 DRILL SFTY P Perform stripping drill. Simulated with 350 si on well. 18:45 19:15 0.50 3,570 3,570 INTRM1 DRILL SFTY P Secure from drill. Blow down lines 19:15 21:00 1.75 3,570 4,428 INTRM1 DRILL TRIP P Continue tripping in hole from pipe shed. Monitoring well via trip tank. Breakin in new drill i e. 21:00 00:00 3.00 4,428 6,963 INTRM1 DRILL TRIP P Continue tripping in hole from pipe shed, recording weights every 5 stands. Monitoring well via trip tank. Fill pipe @ 5083' MD and tested MWD -good, pumping 306 gpm / 2360 psi, rotating 35 rpm. PU wt 150k, SO wt 105k, rot wt 112k, rot PU wt 130k, rot SO wt 108k ~~® 6 P~€,~ 22 ~sf 6f7 • Time Logs _ __ _ Date Fram To Dur S Depth E. Depth Phase Code Subcode T Com_m__ e_ nt 4/09/2008 24 hrsummarv Cut & slip drilling line, service rig. Test casing, drill float equipment and perform FIT (no leak off, stopped at 16.0 a .Drill A2 lateral. 00:00 01:45 1.75 6,963 8,193 INTRM1 DRILL TRIP P Continue tripping in hole from pipe shed, recording weights every 5 stands. Monitoring well via trip tank. Fill pipe @ 7438' MD and tested MWD -good, pumping 306 gpm / 2780 psi, rotating 35 rpm. PU wt 150k, SO wt 105k, rot wt 118k, rot PU wt 180k, rot SO wt 108k 01:45 02:30 0.75 8,193 8,193 INTRM1 DRILL CIRC P Circulate hole clean, pumping 319 gpm / 3120 psi. rotating 35 rpm. PU wt 180k, SO wt 105k, rot wt 118k. 02:30 03:00 0.50 8,193 8,193 INTRM1 RIGMNT SVRG P Blow down top drive and hang blocks. 03:00 03:15 0.25 8,193 8,193 INTRM1 RIGMNT SFTY P PJSM -cut and slip drilling line 03:15 04:45 1.50 8,193 8,193 INTRM1 RIGMNT SVRG P Cut and slip 100' drilling line. 04:45 05:45 1.00 8,193 8,193 INTRM1 RIGMNT SVRG P Inspect brakes and rollers. Adjust brakes. 05:45 06:15 0.50 8,193 8,193 INTRM1 CASING RURD P Rig up for casing test. 06:15 07:00 0.75 8,193 8,193 INTRM1 CASING DHEO P Perform casin test. Pressure. up to 3100 and hold for 30 minutes - ressure held. Charted test. 07:00 07:30 0.50 8,193 8,1.93 INTRM1 CASING RURD P Rig down from casing test. y 07:30 09:30 2.00 8,193 8,310 INTRM1 CEMEN" COCF P Drill shoe track pumping 320 gpm / 3120 psi. Tagged float equip on de th. 09:30 10:15 0.75 8,310 8,330 INTRM1 DRILL DDRL P Drill 20' of new hole. 10:15 11:15 1.00 8,330 8,330 INTRM1 DRILL CIRC P Circulate 2 bottoms up, pump 320 gpm / 3100 psi, rotating 80 rpm. Max as 196 units 11:15 11:30 0.25 8,330 8,330 INTRM1 DRILL RURD P Rig up for LOT 11:30 12:00 0.50 8,330 8,330 INTRM1 DRILL LOT P Perform LOT. Formation did not leak off. Sto ed at 16.0 ppge mud wei ht. 12:00 18:00 6.00 8,330 8,759 PROD1 DRILL DDRL P Drilling A2 lateral. Obtain surveys for Cassandra as directed b DD. 18:00 00:00 6.00 8,759 9,205 PROD1 DRILL DDRL P Drilling A2 lateral 4/10/2008 Drilling A2 lateral. Observing connection gas as high as 1500 units. Increase mud weight from 9.0 ppg to 9.2 00:00 06:00 6.00 9,205 9,700 PROD1 DRILL DDRL P Drilling A2 lateral. 06:00 12:00 6.00 9,700 10,272 PROD1 DRILL DDRL P Drilling A2 lateral. Pumped 30 bbl, 9.0 ppg, 300 vis sweep @ 9982' MD, no increase in returned cuttings observed. Began increasing mud weight due to address connection as, 9.1 12:00 18:00 6.00 10,272 10,958 PROD1 DRILL DDRL P Drilling A2 lateral. Continue increasing mud weight until reachnig 9.2 I ~ P~q~ 23 of fii1 • Time Logs - ~ I _ _- - ---- -- Date From To Dur S. De th E. De th Phase Code Subcode T Comment __ 18:00 00:00 6.00 10,958 11,434 PROD1 DRILL DDRL P Drilling A2 lateral. Pumped 40 bbl, 9.2 ppg, 300 vis sweep @ 11016' MD, observed 35% increase in cuttin s when swee returned. 4/11 /2008 Drilled A2 lateral to TD, 13101' MD / 3916' TVD. Circulate bottoms up, circulate sweep around, observe well for flow and circulate another bottoms u to check for as. 00:00 06:00 6.00 11,434 11,988 PROD1 DRILL DDRL P Drilling A2 lateral 06:00 12:00 6.00 11,988 12,290 PROD1 DRILL DDRL P Drilling A2 lateral. Raise mud weight from 9.2 pgg to 9.3 ppg to address connection as. 12:00 17:30 5.50 12,290 13,101 PROD1 DRILL DDRL P Drilled A2 lateral to TD. 17:30 18:15 0.75 13,101 13,101 PROD1 DRILL CIRC P Circulate bottoms up, pumping 310 gpm / 3780 psi, rotating 135 rpm, ECDs 12.5 ppge. PU wt 227k, SO wt Ok, rotating wt 130k, torque 9-10k ft lbs. 18:15 20:00 1.75 13,101 13,101 PROD1 DRILL CIRC P Pump 35 bbl, 9.3 ppg, 250 vis sweep and circulate out of hole. Observed 20% increase in cuttin s returned. 20:00 20:30 0.50 13,101 13,101 PROD1 DRILL OWFF P Monitor well while working pipe. Well static. 20:30 20:45 0.25 13,101 13,101 PROD1 DRILL CIRC P Record slow pump rates. 20:45 22:00 1.25 13,101 13,101 PROD1 DRILL CIRC P Circulate bottoms up to check for gas. Pump 314 gpm / 3820 psi, rotate 135 rpm. PU wt 220k, SO wt Ok, rotating wt 132k, torque 8k. Max as observed 50 units. 22:00 22:15 0.25 13,101 13,101 PROD1 DRILL OWFF P Monitor well -static 22:15 00:00 1.75 13,101 12,140 PROD1 DRILL REAM P Backream out of hole. 4/12/2008 Backreamed to shoe. Set storm packer and tested BOPE. Reaming back to bottom. 00:00 07:00 7.00 12,140 8,290 PROD1 DRILL REAM P Backreaming to shoe. No troubles or ti ht s ots Burin backreamin . 07:00 09:30 2.50 8,290 8,290 PROD1 DRILL CIRC P Circulate casing clean. Pump 320 gpm / 3040 psi, rotate 135 rpm, torque 6k.Pumped 36 bbl 9.35 ppg 250 vis sweep. Observed moderate increase in cuttings returned. Circulated total of 5 bottoms u . 09:30 11:15 1.75 8,290 8,187 PROD1 WELCTI TRIP P Pull out of hole 2 stands, pick up and run in hole with storm packer, set and tested with 500 psi for 5 min. Pressure held. 11:15 12:45 1.50 8,187 8,187 PROD1 WELCTL OTHR P Rig up for testing BOPE. Pull wear ring, drain stack, make up and set test lus. Fill stack and manifold. 12:45 17:15 4.50 8,187 8,187 PROD1 WELCTL ROPE P Test BOPE. 35 components tested and passed. Tested to 250 psi low and 3000 psi high. Draw down test starting pressure 3100 psi, draw down to 2100 psi: 200 psi increase in 34 sec and full recovery in 3 min 4 sec. Test witnessed by AOGCC, Chuck Sheve. Pa~~ 2~ cif 6t} ! ~ Time Logs _ ___ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:15 18:00 0.75 8,187 8,187 PROD1 WELCTL OTHR P Rig down test equipment and blow down choke. 18:00 19:15 1.25 8,187 8,100 PROD1 WELCTL TRIP P Trip in hole and pull storm packer. La down storm acker. 19:15 19:30 0.25 8,100 8,100 PROD1 WELCTI OTHR P Blow down kill line 19:30 20:00 0.50 8,100 8,100 PROD1 RIGMNT SVRG P Service top drive, blocks and drawworks. Ins ect saver sub. 20:00 21:45 1.75 8,100 9,421 PROD1 DRILL TRIP P Trip in hole for displacement to SFOBM. Wash and ream thru tight s of at 8724' M D 21:45 00:00 2.25 9,421 10,732 PROD1 DRILL REAM P Ran out of weight and began washing and reamin to bottom 4/13/2008 Wash and reamed to TD. Circulated hole clean and tripped out of hole on elevators with drilling BHA. Rigged u and ran 50'oints of 4-1/2" slotted liner. 00:00 04:15 4.25 10,732 13,101 PROD1 DRILL REAM P Wash and ream to TD. 04:15 08:45 4.50 13,101 13,101 PROD1 DRILL CIRC P Circulating hole clean. Circulated one bottoms up, max gas 72 units, then 40 bbl, 9.3 ppg, 250 vis sweep at 310 gpm / 3990 psi, rotating 130 rpm, max gas 88 units, ECDs 12.37 ppge. PU wt 220k, SO wt Ok, rotating wt 130k. Observed slight increase in cuttings returned with sweep. Continued circulating until hole clean, total four bottoms u . 08:45 10:30 1.75 13,101 13,101 PROD1 DRILL CIRC P Displace well to 9.3 ppg SFOBM pumping 310 gpm / 3800 psi, rotating 135 rpm. PU wt 220k, SO wt 75k. Obtain slow um rates. 10:30 10:45 0.25 13,101 13,101 PROD1 DRILL OWFF P Monitor well -static 10:45 17:30 6.75 13,101 368 PROD1 DRILL TRIP P Trip out of hole on elevators, monitoring well via trip tank, recording weights every 5 stands. Hole took 8 bbls more fill than calcuated. 17:30 18:00 0.50 368 65 PROD1 DRILL TRIP P Stand back HWDP and flex collars. 18:00 19:00 1.00 65 65 PROD1 DRILL PULD P Download MWD 19:00 20:15 1.25 65 0 PROD1 DRILL PULD P Lay down BHA 20:15 20:45 0.50 0 0 COMPZ CASING RURD P Clear and clean rig floor 20:45 21:00 0.25 0 0 COMPZ CASING SFTY P Post job review of Laying Down BHA. PJSM - Riggin up 4-1/2" liner handlein tools 21:00 22:00 1.00 0 0 COMPZ CASING RURD P Pick up and rig up 4-1/2" liner handllin tools. 22:00 22:15 0.25 0 0 COMPZ CASING SFTY P PJSM -running liner 22:15 00:00 1.75 0 2,175 COMPZ CASING RUNL P Running 4-1/2" A2 lateral liner. PU wt 100k, SO wt 98k. 50 ~oints in hole 4/14/2008 Ran and set 4-1/2" A2 lateral liner X3072' MD. Tripped out of hole and rigged up to run whipstock for A3 lateral. Picked u whi stock and millin assembl . F~~e ~5 cat fi€7 Time Logs T Comment Date From To Dur S Depth E. De th Phase Code Subcode 00:00 02:00 2.00 2,175 5,092 COMPZ CASING _ RUNL P Running 4-1/2" A2 lateral liner. PU wt 112k, SO wt 100k. 118 'oints in hole 02:00 02:45 0.75 5,092 5,158 COMPZ CASING RUNL P Pick up and run in with seal bore extension, liner hanger and liner top acker. 02:45 03:00 0.25 5,158 5,251 COMPZ CASING RUNL P Run in hole one stand of drill pipe. 03:00 03:30 0.50 5,251 5,251 COMPZ CASING RUNL P Clear and clean rig floor of liner handlin tools. Ins ect saver sub. 03:30 03:45 0.25 5,251 5,251 COMPZ RIGMNT SFTY P PJSM -changing top drive saver sub. Post 'ob review on runnin liner. 03:45 05:15 1.50 5,251 5,251 COMPZ RIGMNT SVRG P Change out saver sub and dies in rabber. 05:15 06:00 0.75 5,251 5,251 COMPZ RIGMNT SVRG P Service blocks, topdrive and drawworks. 06:00 13:15 7.25 5,251 13,040 COMPZ CASING RUNL P Trip in hole on elevators with 4-1/2" liner. Monitoring displacement via trip tank. Recording Torque and Drag every 5 stands. Strapping in hole. Pu wt 230k, So wt Ok, rotating wt 150k, for ue 7-8k ft lbs. 13:15 13:45 0.50 13,040 13,104 COMPZ CASING RUNL P Trip in hole rotating liner @ 50 rpm, torque 7-8k, rotating wt 130k. Calculated displacement 82.7 bbls, actual displacement 68.5 bbls. Lost 14.2 bbls on tri in hole. 13:45 14:15 0.50 13,104 13,072 COMPZ CASING RUNL P Pick up while rotating to set set liner on depth. Drop ball and pump down. Ball seated at 699 strokes. Pressure up to 2000 psi, bleed off pressure and slack off from 140k to block wt. 14:15 14:30 0.25 13,072 13,072 COMPZ CASING RUNL P Pressure up to 2000 psi, bleed off and slack off to block wt. Pressure up to 3000 psi & hold, pressure up to 4000 psi and bleed off. Pick up 7' to confirm liner released. PU wt 185k, SO wt 130k 14:30 15:00 0.50 7,921 7,921 COMPZ CASING DHEQ P Test liner top packer. Open HSR kill and close annular. Pressure up to 2500 si - ressure held. 15:00 15:15 0.25 7,921 7,852 COMPZ CASING RUNL P Pull out of hole, monitoring well via tri tank. PU wt 185k SO wt 130k. 15:15 15:45 0.50 7,852 7,852 COMPZ CASING CIRC P Circulate bottoms up at 336 gpm / 2200 si. Max as 30 units. 15:45 16:00 0.25 7,852 7,852 COMPZ CASING OTHR P Monitor well -static 16:00 19:45 3.75 7,852 45 COMPZ CASING RUNL P Pull out of hole on elevators, monitoring well via trip tank, recording weights every 10 stands. Clean and inspect super sliders on tri out. 19:45 20:45 1.00 45 0 COMPZ CASING RUNL P Lay down liner running tools & subs. 20:45 21:00 0.25 0 0 COMPZ CASING RURD P Clear and clean rig floor. Blind rams shut. 21:00 21:15 0.25 0 0 PROD2 DRILL SFTY P PJSM -picking up whipstock and millin assembl . 21:15 22:15 1.00 0 0 PROD2 STK WPST P Pick up whipstock and milling BHA 1 ~ . ~'ar~~ 25 of 6Q `~ ~~ Time Lois _ _ Date From To Dur S De th E De th Phase Code Subcode T__ Comment 22:15 22:45 0.50 0 0 PROD2 STK WPST T Directional survey tools extend 2.5" past pin end of tools interfering with float /float sub. Attempted to rearrange BHA to fit stick out. Located and made up cross overs with enough internal clearance to fit directional tools. 22:45 23:45 1.00 0 193 PROD2 STK WPST P Continued picking up whipstock and millin BHA. 23:45 00:00 0.25 193 193 PROD2 STK WPST P Downloading MWD. Monitor well via tri tank. 4/15/2008 Trip in hole with whipstock and milling BHA. Set whipstock 11 degrees left, shear off and mill window. Cut 22' of new hole and circulated clean. Tri ed out of hole and laid down mills and flushed surface a ui ment. 00:00 00:30 0.50 193 193 PROD2 STK WPST P Finish downloading MWD. Monitoring well via tri tank. 00:30 01:00 0.50 193 302 PROD2 STK WPST P Trip in hole on elevators with whipstock and milling BHA monitoring well via trip tank. Shallow pulse test MWD pumping 200 gpm / 580 psi -good test. PU wt 85k SO wt 85k 01:00 06:00 5.00 302 7,220 PROD2 STK WPST P Trip in hole on elevators with whipstock and milling BHA monitoring displacement via trip tank. Fill pipe every 25 stands: 2848' MD / 188 gpm / 770 psi 5207' MD / 200 m / 1050 si 06:00 06:45 0.75 7,220 7,269 PROD2 STK WPST P MAD pass to confirm depths. 06:45 07:45 1.00 7,269 7,895 PROD2 STK WPST P Trip in hole on elevators. Monitor displacement via trip tank. PU wt 190k, SO wt 130k. 07:45 08:00 0.25 7,895 7,926 PROD2 STK WPST P Orient to 14 degrees left while running in hole, pumping 290 gpm / 69 spm. Calculated displacement 55.8 bbls, actual 53.5, lost 2.3 bbls Burin tri . 08:00 08:15 0.25 7,926 7,926 PROD2 STK WPST P Landed whipstock @ 11 degrees left and sheared bolt to milling BHA with 40k down weight. Top of whipstock 7820' M 08:15 08:30 0.25 7,917 7,917 PROD2 STK WPST P PJSM -displacing SFOBM with OBM 08:30 09:15 0.75 7,917 7,820 PROD2 STK WPST P Displace well with 320 bbls OBM, um in 310 m / 2840 si. 09:15 12:00 2.75 7,820 7,836 PROD2 STK WPST P Milling window for A3 lateral. Pumping 280 gpm / 2460 psi, rotating 60 rpm, torque 8k ft lbs. Pumped 30 bbl 9.3 ppg 300 vis sweep halfway thru milling window, observed 20% increase in cuttin s. 12:00 13:45 1.75 7,836 7,853 PROD2 STK WPST P Continue milling window and cut 22' of new hole. Pumping 280 gpm / ,,,/~' 2460 psi, rotating 60 rpm, torque 8k ~} ft lbs. F'ag~ 2T ~a~ 6~ • Time Logs J ,~ ' _ Date From__To D__ur S. De th E. Depth P_hase_ Code Subcode TTComment _ 13:45 14:15 0.50 7,853 7,820 PROD2 STK WPST P Work mills thru window. No overpull. PU wt 185k SO wt 132k. Top of Window 7820' MD / 3889' TVD; Bottom of Window 7833.7' MD / 3890.4' TVD 14:15 15:30 1.25 7,820 7,853 PROD2 STK WPST P Pump 30 bbl sweep & 2 bottoms up @ 320 gpm / 3050 psi. PU wt 185k, SO wt 132 k, rotating wt 145k, torque 5-6k ft lbs. Observed 40% increase in cuttin s. 15:30 15:45 0.25 7,853 7,853 PROD2 STK WPST P Monitor well -static 15:45 16:30 0.75 7,853 6,707 PROD2 STK WPST P Pull out of hole on elevators, monitoring hole fill via trip tank. Record weights every 10 stands. PU wt 170k, SO wt 120k 16:30 16:45 0.25 6,707 6,707 PROD2 STK WPST P Pump 15 bbl, 11.3 ppg, 72 vis dry job and blow down to drive. 16:45 19:45 3.00 6,707 488 PROD2 STK WPST P Pull out of hole on elevators, monitoring hole fill via trip tank. Record weights every 10 stands. PU wt 170k, SO wt 120k 19:45 20:00 0.25 488 193 PROD2 STK WPST P Lay down milling BHA, monitoring hole fill via tri tank. 20:00 20:30 0.50 193 193 PROD2 STK WPST P Download MWD 20:30 22:00 1.50 193 0 PROD2 STK WPST P Continue laying down milling BHA, monitoring hole fill via trip tank. Mills were full gauge when pulled out of hole. 22:00 00:00 2.00 0 0 PROD2 DRILL CIRC P Flush stack and choke manifold. Blow down choke and kill lines. 4/16/2008 Picked up and made up A3 lateral Geo-Pilot drilling BHA. Ran in hole to top of window and stopped to service rig and cut drilling line. Recorded baseline ECD 11.46 ppg and drilled to 8669' MD. Pumps kicked off while drillin and inclination increased 1 de ree. Trou hed until inclination back to tar et. 00:00 00:15 0.25 0 0 PROD2 DRILL RURD P Rig up tools to make up drilling BHA. Blind rams shut. 00:15 00:30 0.25 0 0 PROD2 DRILL SFTY P PJSM -making up BHA 00:30 01:45 1.25 0 87 PROD2 DRILL PULD P Pick up and make up geo-pilot drillin BHA. 01:45 02:30 0.75 87 57 PROD2 DRILL PULD P Upload MWD, monitor well via trip tank 02:30 03:15 0.75 57 386 PROD2 DRILL PULD P Continue to make up BHA. Shallow ulse test MWD um in 200 m. 03:15 06:00 2.75 386 7,728 PROD2 DRILL TRIP P Trip in hole on elevators. Record weights every 10 stands. Fill pipe every 25 stands: 2730' MD pumping 200 gpm / 1050 psi 5092' MD pumping 200 gpm / 1250 si 06:00 06:45 0.75 7,728 7,728 PROD2 RIGMNT SVRG P Service rig, blocks, top drive, crown and iron rou hneck P~r~e 2~ of 60 ~ rme Logs ' Dade From To Dur S. Depth E. De th Phase Code Subcode T Comment 06:45 07:00 0.25 7,728 7,728 PROD2 RIGMNT SVRG P Blow down top drive. 07:00 07:15 0.25 7,728 7,728 PROD2 RIGMNT SVRG P Hang blocks for cutting and slipping drillin line. 07:15 07:30 0.25 7,728 7,728 PROD2 RIGMNT SFTY P PJSM -cut & slip drilling line. 07:30 09:00 1.50 7,728 7,728 PROD2 RIGMNT SVRG P Cut and slip 87' of drilling line. Unhan blocks. 09:00 09:30 0.50 7,728 7,853 PROD2 DRILL TRIP P Trip in hole on elevators. Wash and ream last 13' to bottom. Pump 320 gpm / 3180 psi, rotating 40 rpm, torque 8k ft lbs. PU wt 155k, SO wt 110k, rotatin wt 122k. 09:30 10:15 0.75 7,853 7,918 PROD2 DRILL DDRL P Drilling A3 lateral 10:15 11:00 0.75 7,918 7,800 PROD2 DRILL CIRC P Pull up inside casing and get ECD baseline. 320 gpm 3200 psi 80 rpm 11.34 ppge 320 gpm 3200 psi 110 rpm 11.46 ppge 280 gpm 2460 psi 80 rpm 11.05 ppge 280 gpm 2460 psi 110 rpm 11.17 e 11:00 12:00 1.00 7,918 7,920 PROD2 DRILL DDRL P Drilling A3 lateral. Experienced high torque stalling topdrive 7918' - 7924'. Noted that stabilizer was on whi stock slide durin this eriod. 12:00 16:45 4.75 7,920 8,252 PROD2 DRILL DDRL P Drilling A3 lateral. Pump kicked off. Found 1 degree of inclination more than tanned. 16:45 17:00 0.25 8,252 8,235 PROD2 STK KOST T Turn pumps back on and pick up to trou h. 17:00 20:45 3.75 8,235 8,252 PROD2 STK KOST T Troughing to reduce hole angle 20:45 00:00 3.25 8,252 8,669 PROD2 DRILL DDRL P Resume drilling A3 lateral 4/17/2008 Drilling A3 lateral. Max ECDs 12.16 and max gas 1121 units. 00:00 06:00 6.00 8,669 9,365 PROD2 DRILL DDRL P Drilling A3 lateral. 06:00 12:00 6.00 9,365 9,983 PROD2 DRILL DDRL P Drilling A3 lateral. 12:00 18:00 6.00 9,983 10,530 PROD2 DRILL DDRL P Drilling A3 lateral. 18:00 00:00 6.00 10,530 11,277 PROD2 DRILL DDRL P Drilling A3 lateral. 4/18/2008 Drilled A3 lateral to TD, 13102' MD / 3847' TVD. Circulated 30 bbl sweep around and began backreaming at 4 stands er hour after swee returned to surface. 00:00 01:30 1.50 11,277 11,392 PROD2 DRILL DDRL P Drilling A3 lateral. 01:30 02:30 1.00 11,392 11,298 PROD2 DRILL CIRC P Observed increase in loss rate. Monitor well -static after 3 minutes. Check surface equipment - ok. Circulate bottoms up, pumping 320 m / 3580 si. Max as 481 units. 02:30 06:00 3.50 11,298 11,861 PROD2 DRILL DDRL P Drilling A3 lateral 3'~c~~ 29 of fiQ ~ ~ Time Logs _ _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 06:00 12:00 6.00 11,861 12,504 PROD2 DRILL DDRL P Drilling A3 lateral 12:00 16:30 4.50 12,504 12,799 PROD2 DRILL DDRL P Drilling A3 lateral 16:30 17:30 1.00 12,799 12,799 PROD2 DRILL REAM P Backream at 2 fpm to clean hole and reduce ECDs. Pumping 300 gpm / 3410 psi. ECDs before 12.26 ppg, after 12.08 17:30 20:45 3.25 12,799 13,102 F'ROD2 DRILL DDRL P Drilled A3 lateral to TD. 20:45 22:30 1.75 13,102 13,102 FROD2 DRILL CIRC P Obtain SPRs & Torque and Drag data. Pump 30 bbl, 9.3 ppg, 250 vis sweep @ 290 gpm / 3230 psi, rotating 120 rpm. Observed 40% increase in cuttings when sweep returned. 22:30 22:45 0.25 13,102 13,079 F'ROD2 DRILL REAM P Backream and lay down single. Install stri in rubbers and air sli s. 22:45 00:00 1.25 13,079 12,891 F'ROD2 DRILL REAM P Back reamimg out of hole at 4 stands er hour. 4/19/2008 Backreamed until inside casing. Slowed rpms whit BHA across whipstock. Circulated casing clean with 40 bbl swee and 4 bottoms u . 00:00 06:00 6.00 12,891 10,736 PROD2 DRILL REAM P Continue backreaming out of hole @ 4 stands per hour. Stop and get surve s as directed b DD. 06:00 12:00 6.00 10,736 8,576 PROD2 DRILL REAM P Backreaming out of hole. 12:00 13:45 1.75 8,576 7,925 F'ROD2 DRILL REAM P Backreaming out of hole. Slowed rotation to 40 rpm while pulling BHA across whi stock. 13:45 14:15 0.50 7,925 7,728 F'ROD2 DRILL CIRC P Pump out of hole @ 320 gpm / 3050 psi. PU wt 170k, SO wt 110k. Calculated hole fill on trip 29.7 bbls, actual fill 69.5 bbls, lost 39.8 bbls 14:15 16:30 2.25 7,728 7,728 F'ROD2 DRILL CIRC P Circulate sweep to clean casing and total of 4.4 bottoms up. Pumping at 320 gpm / 3050 psi. Rotating 80 rpm, torque 61 ft Ibs, PU wt 170k, SO wt 110k, ECDs 11.16. Pumps off rotating wt 130k, torque 6k ft Ibs. Observed 25% increase in cuttings return with sweep. ECDs at end of curculation 10.85 16:30 17:30 1.00 7,728 7,728 F'ROD2 DRILL - OWFF P Monitor well -breathing. Static after 1 hour. Well returned 1.5 bbls. Sim ops, service blocks, crown, rou hneck and ins ect saver sub. 17:30 18:30 1.00 7,728 8,763 F'ROD2 DRILL TRIP P Trip in hole for swap to SFOBM. Lost down weight @ 8382' MD, began washing & reaming in hole. Pumping 100 gpm, rotating 50 rpm, torque 7k ft Ibs. 18:30 20:00 1.50 8,763 12,611 F'ROD2 DRILL TRIP P Tripping in hole on elevators. Monitor displacement via trip tank. Fill pipe every 25 stands, record torque and dra eve 10. t~az~~ 3tl of 60 Time Logs _ _ __ Dur S Depth E. Depth Phase Code Subcode T Comment__ __ Date From T o 20:00 _ _ 21:00 1.00 12,611 13,102 PROD2 DRILL REAM P Wash and ream to TD. Pumping 100 gpm, rotating 50 rpm, torque 8k ft lbs. PU et 190k, SO wt 72k. 21:00 23:45 2.75 13,102 13,019 PROD2 DRILL CIRC P Circulate on bottom and pump 35 bbl, 9.3 ppg, 250 vis sweep. Pumping 300 gpm / 3580 psi, rotating 120 rpm, torque 9k ft lbs. Circulated total of 2.5 bottoms up. Observed 80% increase in cuttings returned with swee . 23:45 00:00 0.25 13,019 13,019 PROD2 DRILL CIRC P Begin displaceing well over to SFOBM, pumping @ 300 gpm / 3730 psi. 1074 strokes into displacement at midni ht. 4/20/2008 Displaced well over to SFOBM. Pulled 2 stands out of hole and hole not takeing proper fill, breathing. Pumped out of hole stopping to check for flow and attempting to pull on elevators. Pumped out to 8199' MD, shoe at 7833' MD. Pulled 30k over at 8267' MD, reamed hole and pulled on elevators. Layed down MWD and rigged u 4-1/2" liner runnin tools. Ran in hole with liner and liner runnin tools. 00:00 01:15 1.25 13,019 13,102 PROD2 DRILL CIRC P Continue displaceing well over to SFOBM. Pumping 310 gpm / 3720 psi, rotating 120 rpm. PU wt 195k, SO wt 125k, torque 8k ft lbs. Overdisplaced 40 bbls. Torque with um s off 30 r m 8-9k ft lbs. 01:15 01:30 0.25 13,102 13,102 PROD2 DRILL CIRC P Record slow pump rates and torque & dra data. 01:30 01:45 0.25 13,102 13,102 PROD2 DRILL OWFF P Monitor well -breathing then static 01:45 02:00 0.25 13,102 12,894 PROD2 DRILL TRIP P Lay down single and pull on elevators. Monitoring well via trip tank. Fluid level in stack not fallin . 02:00 06:00 4.00 12,894 9,608 PROD2 DRILL TRIP P Pump out of hole, 170 gpm / 1070 psi. Attempt to pull on elevators every 5 stands. PU wt 200k, SO wt 72k. Monitoring hole fill via active s stem. 06:00 08:30 2.50 9,608 8,199 PROD2 DRILL TRIP P Continue pumping out of hole, 170 gpm / 1020 psi. PU wt 200k So wt 90k. Monitoring well via active system. Observed 30k overpull at 8267' MD, slacked off, no down weight. Pull up to rotating wt 120k, washed and reamed down to 8296' MD, torque and pressure good. Backreamed to 8199' MD. Trip in to 8296' MD, 90k SO wt. Pull out of hole 200k PU wt. Dropped 1.90 rabbit on wire at 8670' MD 08:30 09:30 1.00 8,199 7,728 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitor well via trip tank. PU wt 170k SO wt 110k, rotating wt 130k, torque 7-9k ft Ibs 09:30 10:00 0.50 7,728 7,728 PROD2 DRILL OWFF P Monitior well -falling. Clean rig floor. F'~ge 31 of 6£~ i • Time Logs -.Date Frem To Dur. 5. De^th E. De^th,P;~ase Cone .Suhcede T Comment ~ -- - _ - 10:00 10:15 0.25 7,728 7,728 PROD2 DRILL TRIP P Blow: down top. drive, install stripping rubbers and air sli s_ 10:15 14:30 4.25 7,728 368 PROD2 DRILL -TRIP P Pull out of hole on elevators, monitoring well via trip tank. PU wt 90k, SO wt 90k. Monitor well @ 4330' MD -static. Recorded weights every 10 stands on tri out of hole. 14:30 14:45 0.25 368 368 PROD2 DRILL OWFF P Monitor well -static 14:45 -15:30 0.75. 368 88 PROD2 DRILL TRIP P Pull and rack back HWDP, jars, bumber sub and flex collars. Lay down stabilizer and float sub. Recovered rabbit from to of float. 15:30 16:45 1.25 88 88 PROD2 DRILL PULD P Download MWD, clear and clean rig floor. 16:45 18:00 1.25 88 0 PROD2 DRILL PULD P Lay down BHA. 18:00 1.8:15 0.25 0 0 COMPZ CASING KURD P Clear and clean rig floor. 18:15 19:15 1.00 0 0 COMPZ CASING RURD P Pick up and rig up 4-1 /2" liner handling equipment. Monitoring hole via tri tank. 19:15 19:30 A.25 0 0 COMPZ CASING SFTY P PJSM -running liner with GBR and Baker Oil Tools re s. 19:30 22:00-- 2.50 0 4,998 COMPZ CASING RUNL P Run 116 joints of 4-1/2" liner. PU wt 110k; SO wt 100k. -22:00 22:45 0.75 4,998 5,069 COMPZ CASING RUNL P Run plop & Drop reciptacle joint and settin sleeve. 22:45 23:15 0.50 5,069 5,069 COMPZ CASING RURD P Rig down and lay down liner running tools,. clear rig floor: Monitoring well via tri tank. 23:15 23:45 0.50 5,069 5,069 COMPZ CASING SFTY P Post job safety review. Recapping lessons learned. Monitoring well via tri tank. 23:45 00:00 0.25 5,069 5,069 COMPZ CASING SFTY P PJSM -tripping in hole with liner on drill i e. 4/21 /2008 Run 4-1/2" A3 lateral "plop & drop" liner on drill pipe. Trip out of hole. Pick up, make up and run in hole with whi stock retrievin BHA. Attem t to latch whi stock. 00:00. 01:15 1.25 5,069 7,710 COMPZ CASING RUNL P Trip in hole on elevators with liner on 4-1/2"drill pipe. Monitor displacement via trip tank. PU wt 145k, SO wt 100k, rotating @ 30 r m wt 115k for ue 4k ft lbs. 01:15 02:30 1.25 7,710 7,71.0 COMPZ RIGMN7 SVRG P Change out saver sub on top drive. 02:30 05:15 2.75 7,710 13,063 COMPZ CASING RUNL P Continue tripping in hole with liner on drill i e. 05:15 05:30 0.25 13,063 13,102 COMPZ CASING RUNL P Rotate in hole and tag bottom. PU wt 240k, So wt 75k, rotating 30 rpm wt 155k 05:30. 06:00 0.50 13,102 13,092 COMPZ CASING RUNL P Pulf liner with elevators to 13063' MD, break stand and dro ball 06:00 06:15 .0.25 13,092 13,092 COMPZ CASING CIRC P Pump ball down to release running tool. Pumping 130 gpm / 650. psi. Ball on seat at 691 strokes. Pu wt 225k, SO wt 80k. Page 32 of 6fl • • Time Logs _ _ ~sDate From To Dur S De th E th Phase Code Subcode T Corrrer~nt ~ _ 06:15 07:00 0.75 13,092 8,026 COMPZ CASING RUNL P Pressure up to 2500 psi and slack. off to 80K to release liner. Pick up to 225k, still have liner. Slack off to 140k and pressure up to 3000 psi and pick up to 190k. Liner released. Pull up 20' and pressure up to 4000 b. shear. Ri u test ump and ressure u .Sheared at 4800 si. 07:00 07:15 0.25 8,026 7,976 COMPZ CASING OTHR P Pull out of hole and monitor well static 07:15 12:00 4.75 7,976 440 COMPZ CASING RUNL P Pull out of hole on elevators. Monitoring well via trip tank. Record wei hts eve 10 stands on tri out. 12:00 12:15 0.25 440 440 COMPZ CASING OTHR P Monitor well -static 12:15 12:30 .0.25 440 440 COMPZ CASING SFTY P PJSM -laying down liner7unning tools. 12:30 13:00 0.50 440 0 COMPZ CASING RURD P Lay down liner running tools and clear ri floor. 13:00 13:30 0:50: 0 0 COMPZ FISH PULD P Pick up tools for retrieving whipstock: 13:30 13:45 0.25 0 0 COMPZ FISH SFTY P PJSM -Making up whipstock retrieving BHA with Baker Fishing re . 13:45 -15:45 2.00 0 130 COMPZ FISH PULD P Make up whipstock retrieving BHA includin MWD tools. 15:45 18:30 2.75 130 7,290 COMPZ FISH TRIP P Trip in hole on elevators with whipstock retrieving BHA. Filling pipe every 25 stands. Shallow pulse test 600' MD - ood test. 18:30 19:00 0:50 7;290 7,290 COMPZ FISH CIRC P` Break circulation pumping 200 gpm / 1300 psi. Observed 155 uriits of gas. Circulated until 0 units. '19:00 19:45 0.75 7,290 7,820 COMPZ FISH TRIP P Continue'trip in hole on elevators with whipstock retrieving BHA. PU wt 170k, SO wt 129k. Orient toolface and run into to of whi stock. 19:45 00:00 4.25 7,820 7,820 COMPZ FISH WASH P Wash slot in whipstock face and m t to latch into whi stock. 4/22/2008 Fished for and Hooked Whipstock; Jarred Whipstock Loose and Circulated Bottoms Up (No gas); Pulled Out-of-Hole f/ 7725' - 6827 MD; Hole Took 38 Bbls and Gave 21 Back (Breathing); Pumped Out-of-Hole f/ 6827' - 3623' MD; Pulled Out-of-Hole on Elevators f/ 3623° - 0' MD; Layed Down Whipstock /MWD. Assemblies; Picked Up and Made Up A3 Liner Hook Hanger Assy; Initial MWD Shallow Test Failed; Chan ed Pulser Orifice; Checked Good; Ran In Hole w/ Hook Han er f/ 366' - 5270' MD 00:00 00:45 0.75 7,820 .7,820 COMPZ FISH WASH P Continue to Hook Whipstock Slot per. BOT Rep; P/U 190, S/O 129;.200 GPM 1330 Psi 00:45 01:00 0.25 7,820 7,820 COMPZ FISH FISH P Latched Whipstock and Jarred Loose er BOT Re 01:00 01:15 0.25 7,820 7,725 COMPZ FISH OTHR P Pull 1 Std & OWFF (Static) 01:15 02:00 0.75 7,725 7,725 COMPZ FISH CIRC P CBU; 310 GPM @ 3130 Psi; No gas 02:00 02:30 0.50 7,725 7,725 COMPZ FISH OTHR P OWFF -- Breathin ~ Flow Out 3% w/ Pum s Off, 6 BPH f/ First 10 Minutes, 1 BPH f/ 2nd 10 Minutes; Then Sto ed Static Page 33 of Btl • • Time Logs -Date Frgm To Dur S De th E. De th t~nase_ Code __ Subcode T_ Dvrr~iT~ent _ 02:30 04:30 2.00 7,725 6,827 COMPZFISH TRIP P POOHf/7725'-682TMD; Monitor Fill on Trip Tank; Hole Took 38 Bbls on Fill and Gave 21 Bbls Back After Pumps Shut Down; Totaf Loss 17 Bbls 04:30 05:00 0.50 6,827 6,827 COMPZ FISH CIRC P CBU; 310 GPM @2600 Psi; No Gas 05:00 05:15 0.25 6,827 6,827 COMPZ FISH OTHR P OWFF -- Breathing 05:15 10:30 .5.25 6,827 3,623 COMPZ FISH TRIP P Pump Out of Hole f/ 6827° - 3623' MD; 168 GPM 610 Psi 10:30 13:00 2.50 3,623 240 COMPZ FISH TRIP P POOH on Elevators f/ 3623' - 240' MD; Fill Pi a Eve 25 Stds 13:00 13:15 0.25 240 240 COMPZ FISH OTHR P Plug Iri & Turn Off MWD 13:15 16:30 3.25 240 0 COMPZ FISH. PULD P POOH w/ Whipstock Hook BHA; Break & UD Baker Hook Assy, Whipstock, Whipstock Subs, and MWD er Baker / S er Re s 16:30 17:00 0.50 0 0 COMPZ RPCOM RURD P Rig Up to Run Hook Hanger Assy; Closed Blind. Rams 17:00 17:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for M/U Hook Hanger Assy 17:15 19:00 1.75. 0 271 COMPZ RPCOM PULD P P/U & M/U Baker Hook Hanger Assy er BOT Re 19:00 19:30 0.50 271 271 COMPZ RPCOM DHEQ P Orient MWD % Hook Hanger & M/U Hook Hanger to ECP BHA per MWD / BOT Re 19:30 19:45 0.25 271 366 COMPZ RPCOM DHEQ P Change Elevators and RhH w/ 1-Std t/ 366' MD & Shallow Test MWD.@ 100 GPM w/ 370 psi then 120 GPM w/ 450 si; Weak Si nal f/ Pulser 19:45 20:15 0.50 366 271. COMPZ RPCOM TRIP T Stand Back 1 - Starid & Unscrew Hook Han, er f/ BHA 20:15 .20:30 0.25 271 271 COMPZ RPCOM DHEQ T Change Pulser Otifice f/ 1:6625" to 1..5625" 20:30 21:00 0.50 271 366 COMPZ RPCOM DHEQ T Screw Hook Hanger Back into BHA and RIH w/ 1 Stand to 366' MD; Shallow Test Good @ 90 GPM w/ 470 si 21:00 21:15 -0.25 366 366 COMPZ RIGMN7 OTHR P Blow Down Top Drive 21:15 00:00 2.75 366 5,270 COMPZ RPCOM TRIP P RIH on Elevators w/ Hook Hanger Assy f/ 366' - 5270' MD; Run Speed 75 - 90 FPM; Record P/U & S/O Eve 10 Stds 4/23/2008 Continue to run in the hole w/ Hook Hanger assembly f/ 5270' to 8065' (17' above hook point), orient, obtain PU and SO wt's, Hook window with indication of 39 deg right of highside, pickup, orient 1.80 deg, slack off 4' past hook point, pickup orient to 39 deg right, hook window, set down 40k on the hook (top of hook hanger @ 7818') (Window hooked @ 7835'), drop 1-3/4" ball pump down and inflate external casing packer w/ approx 8.4 gallons of mud; pull inner string from Hook Hanger, circulate bottom's up, monitor well, pullout of hole (adjust Western Well Tools super sliders on 4"drill pipe), lay down running tools, PJSM, PU/MU/RIH w! LEM assembly, tag up with LEM on top of Hook Hanger with indication of 21 deg. right of highside, pickup 15k over #o verify latchup, drop 1-3/4" ball, pump ball to seat, Set HR ZXP packer (top @ 7456'), test packer to 2900 psi f/ 5 minutes (chart test), bleed off, lay down a jt of 4"drill pipe, monitorwell-static, run in to tag'ZXP with dog sub on running tool to confirm depth (:73' deeper than Hook hanger tally-7456.76'), pull out of the hole with runnin tools to 7365' midni ht Page 34 of B£T Time Lo s~ _-- __ _ ~ ~ Date From To Dur S. Depth E_ Depth Phase Ccxie__ Sut~c;o~e T Cun~Enent 00:00 A2:30 2.50 - 5,270 7,980. COMPZ RPCOM TRIP P Continue TIH w/ Hook Hanger f/ 5270' - 7980' MD; Above the top of window 7820', P/U 185, S/O 135 02:30 04:15 1.75 7,980 8,082' COMPZ RPCOM TRIP P P/U Single and then Last Stand (#83); Pumping 102 GPM @ 960 psi; Obtain MWD Tool Face Position; Position Hanger at 4 Right with hook hanger 1T above hook point (8065' mule shoe depth), slack off and MWD showed 39 Deg Right when hooked & Set 30K Down on Hook; Pickup with 30k overpull, rotate 180 deg, work torque, then slackoff 4' past where window had hooked, Picked up, oriented to 39 right, worked torque, set back. down and hooked window at same depth (7835'), with same MWD indication of 39 deg right of highside. Set down 40k on the hook. Top of Hanger @ 7818' MD, Hooked Window @ 7835' MD; Mule Shoe @ 8082' MD; P/U 195, 8/O 135 04:15 05:15. 1.00 7,980 8,082 COMPZ RPCOM OTHR P Drop 1-3/4" Ball; Pumped Down 24 SPM w/ 950 psi for 500 strokes, then slow pumps to .5 bpm w/ 270 si. Ball On Seat 597 Strokes. 05:15 05:30 0,25 8,082 8,082 COMPZ RPCOM PACK P Set 40k on hook hanger, then Inflate per BOT Rep; Pressure Up t/ 1500 & Hold 1 Min; then 2300 psi to Shear Bolts; Pressure Bled. Off; Pressure Up t/ 2800psi 3 Times, Bled to 2000 psi, Pressure Up to 3000 psi to Verify Inflation: Appears to take 2 strokesto inflate ECP (8.4 allons . 05:30 05:45 0.25 8,082 7,61.5 COMPZ RPCOM TRIP P Pull Inner String Out of Hook Hanger and POOH f/ 8082' - 7615' MD -05:45 06:30 .0.75 7,615 7,615 COMPZ RPCOM CIRC P . Circulate bottom's up-- pumping 400. GPM w! 3000 si 06:30 06:45 0.25 7,615 7,615 COMPZ RPCOM OWFF P OWFF -= Breathing then Static. Blow down top drive, install air slips and the stri in rubbers: 06:45 14:15 7.50 7,615 0 COMPZ RPCOM TRIP P POOH f/ 7615' - 0' MD; Adjust Western Well Tools 4" Super Sliders on DP while Tripping out ; UD Slim MWD and Hook Hanger Inner String. Calculated displacement 55.67 bbls, actual 61 bbls, loss of 5.33 bbls. 14:15 14:45 0.50 0 0 COMPZ RPCOM KURD P . Clean & Clear Rig Floor, Rig Up to Run LEM, SBE, and ZXP Packer per BOT Re .14:45 15:00 0.25. 0 0 COMPZ RPCOM SFTY P PJSM on Running LEM, SBE, & ZXP Packer Ass 15:00 16:45 1.75 0 518 COMPZ RPCOM RCST P Make up the LEM assembly, orient with S er Sun slimhole MWD. Page 35 of 60 ~ ~ I Time Logs __- - _ J,I - - - --- ~ Date From To Dur 5. De th E Ue th'F'hase Code Subcode _ T Comn-~en_t __ __ __ 16:45 18:00 1.25 518 3,539 COMPZ RPCOM TRIP P Trip in the hole with the LEM from. 518'to 3539'. Monitor well on the trip tank.. Shallow pulse tested MWD @ 608', pumping 100 gpm w/ 580 psi, O K. 18:00 20:30 2.50 3,539 7,772 COMPZ RPCOM TRIP P Continue to trip in the hole with the LEM from 3539' to 7772''. Monitor well on the trip tank. Record PU and SO wt's per Rig Engineer. Obtain PU wt of 180k and SO wt of 130k while 46' above the to of the hook han er. 20:30 21:00 0.50 7,772 .7,953 COMPZ RPCOM TRIP P While pumping 105 gpm w/ 1000 psi, orientation of 16 Right. of highside, slackoff and pass through the top of the Hook Hanger @ 7818' to LEM assembl seals de th of 7953'. 21:00 21:30 0.50 7,953 7,965 COMPZ RPCOM TRIP P Pickup a single of 4".drill pipe and. make a top drive connection. Rig up chart recorder. Pumping 105 gpm w/ 1000 psi: MWD indication of 13 right. Slack off and index LEM into the. Hook hanger with MWD indication of 21 Right of highside. Set 30k down on Hook Hanger. Pickup 15k over (195k) to verify LEM installed. Depth of seals 7965.54' (.73' deep to the hook han er tall 21:30 22:00 0.50 7,965 7;965 CbMPZ RPCOM CIRC P Drop a 1-3I4" ball, pump ball down by pumping 103 gpm w/' 1000 psi, slowed to 65 gpm with 560 psi after pumping 500 strokes. Ball on seat with 566 strokes um ed. 22:00 22:15 . 0:25 7,965 7,965 COMPZ RPCOM OTHR P` Set Baker HR ZXP packer: Pressure. to 2000 .tfaea.incr~ase to 3400 si to activate pusher tool for setting ZXP, hold, thenpressure toto 4000 psi to neutralize the pusher tool. Bleed off ressure. Picku 1'. 22:15 22:45 0.50 :7,965 7,965 COMPZ RPCOM DHEQ P Test ZXP packer. Break top drive from drill pipe (drill pipe open to atmoshere). Pump into kill line with the top pipe rams closed. Pumped a total of 34 strokes. to pressure up to approx 3000 psi. Shut in pump. Hold 2900 si for 5 min., chart test.-Z oocT testa Bleed off pressure. Open top i e rams. .22:45 23:00 0.25 7,965 7,861 COMPZ RPCOM TRIP P Lay down single of 4"drill pipe. Stand back stand #79. Blow down the to drive and kill line. 23:00 23:15 .0.25 7,861 7,861 COMPZ RPCOM OWFF P Observe well for flow. Static: 23:15 23:30 0.25 7,861 7,965 COMPZ RPCOM TRIP P Run in the hole to reconfirm. depth of ZXP packer with the dog sub on the running toot: Tagged top of ZXP packer @ 7456.76', (seals of LEM assembl 7965.54' . Page 3S of HO' ~ ~ ~ Time Logs _ - _ Date From To Dur S.Depth E Det#~~Phase Code Subcoae T Gamment __ - - - - - - 23:30 00:00 0..50 7,965 7,365 COMPZ RPG©M TRIP P Pull out of the holewith LEM running tools. Monitor displacement on the tri tank. 4/24/2008 Continue to pull out of the hole with LEM running tools from 7365' ,lay down LEM running tools, PU . Whipstock°assembly for the A4 lateral (1C-172A L2) (PROD 3), orient MWD with whipstock, shallow test MWD, trip in, MAD Pass seal depth 6694' to 6742' (Gamma depth .6515' to 6563'), continue trip in orient whipstock to 31 deg left of high side, set down 15k on the ZXP packer of the A3 lateral @ 7456.76', pickup 10k over pull to verify ahchor set, shear bolt on whipstock/mills (Top of whipstock @ 7456.76'), displace well from 9:3 ppg SFOBM to 9.3 ppg OBM, acquire slow pump rates, milling window from top of window. @ 7357 to starter mill depth of 7377 at midnight. Note: To of window 7357,27, bottom of window 7371'. 00:00 03:00 3.00 7,365 0 COMPZ RPCOM TRIP P POOH w/ LEM running tools f/ 7365' - 0' MD; Monitor Hole on Trip Tank; .Hole Took Pro er Fill 03:00 03:45 0.75 0 0 COMPZ RPCOM PULD P UD LEM Running Tools &MWD 03:45 04:00 0.25 0 0 COMPZ RPCOM OTHR P Clean & Clear Rig Floor of LEM Tools 04:00 04:30. 0.50 0 0 PRODS STK OTHR P P / U Whipstock Tools f/ A4 Lateral & Brin to Ri Floor 04:30 07:00 2.50 0 207 . PRODS STK PULD P M/U A4 Lateral WhipstockAssy & MWD. Orient whi stock to MWD. 07:00 07:45 0.75 207 207 PRODS STK. OTHR P Install MWD Pulser Spacer and U load MWD Software 07:45 08:15 0.50 207 302 PRODS STK OTHR P P/U 1 Stand & Shallow Test MWD 250: GPM wl 730 si; Good 08:15 .11:00 2:75 302 6;694 PRODS STK TRIP P RIH w/ Whipstock BHA f/ 302' - 6694' MD. Filf pipe every 25 stands (2463' & 4825' . 11.:00 11:45 0.75 6,694. 6,742 PRODS STK OTHR P MAD Pass f/ 6694' - 6742' MD of seals (Gamma at Depth of 6515' - 6563' MD); Circulated:@ 220 GPM / 1550 psi During Pass. Travel speed of 3'/min. 11:45 13:30 1.75 6,742 7,457 PRODS STK TRIP P RIH w/ Whipstock BHA f! 6742' - 7456.76' MD; Orient Whipstock Slide to 31 Degrees Left; Tagged Top of ZXP on Depth @ 7456.76. PU wt 165k, SO wt 125k 13:30 13:45 0.25 7,457. 7,357 PRODS STK OTHR P i ock: Set Anchor by Setting 15K Down Weight on BHA; Verified Anchor Set by P/U 10K Overpull; Attempt to Shear Milling Assy Bolt by setting 40K Down - Bolt Sheared; Then Find Free Point (138k), apply 10K ft Ibs of right hand torque -Mills Free; TOW at 7357.27 MD' 13:45 14:45 1.00 7,357 7,357 PRODS 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. PRODS STK CIRC P Obtain slow pump rates prior to millin window. 15:00 18:00 3:00 7,357 7,365. PRODS STK WPST P Milling 6 3/4" Window for A4 Lateral f/ 7357 - 7365'. Pumping 300 gpm w/ ~ ~' \ ~ ~ ~~ ~~ ~ ~ 2280 psi. Rotate 110 rpm w/ 5-8k ft Ibs of for ue. Page 37 of B€l ! • Time Logs - Date_ From To Dur S: Depth E Depth Phase Code SuCcode T _Comment 18:00 19:15. 1.25 7,365 7,371 PROD`S 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 Ibsof torque, 10-12k weight on mills. PU wt 165k, SO wt 125k, Rotating weight 138k. Note: Pumped a 40 bbl highvis sweep (250 vis), while milling window @ 7370'. Observed a 20% increase ' in cuttin s. 19:15 00:00 4.75 7,371 7,377 PRODS 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 11b 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 PRODS STK WPST P Cont. Milling & Dress Window F/737T MD 7/7378' MD. Average ROP=0.8ft./hr. Unsucessfully Varied arameterstot to Im rove ROP. 01:30 01:45 0.25 7,378. 7,378 PRODS STK OWFF P Monitor well. Static. Prepare to POOH to Chan a mill: 01:45 -05:00 3.25 7,378- 107 PRODS STK TRIP T POOH for low ROP (suspect concretion) F/7378' MD T/107MD, monitor well on trip tank, hole taking ro er fill 05:00 06:00 1.00 107 0 PRODS STK PULD T L/D milling BHA & MWD. Starter mill nose worn, and slight ringing towards outside ed a of face. 06:00 07:00 1.00 0 145 PRODS 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 PRODS STK TRIP T RIH f/145' MD T/7302' MD 10:30 10:45 0.25 7,302 7,302 PRODS RIGMNT SFTY P PJSM, Cut & slip drill line 10:45 12:00 1.25. 7,302 7,302 PRODS RIGMNT SVRG P Cut & Slip 170' of 1-3/8" Drill Line 12:00 12:15 0.25 7,302 7,302 PRODS RIGMNT SFTY P PJSM for Changing Out Swivel Packin Page 38 of HCi Time Logs _ Date From To Dur S Cie th E; De th Phase Code Subcode T_ Comment 12:15 13:30 1.25 7,302 7,302 PRODS RIGMNT SVRG P Change Uut Swivel Packing. Spill revention measure. 13:30 13:45 0.25 7,302 7,378 PRODS 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. PRODS 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 PRODS STK OTHR P Pump 25 bbl - 9.3 PPG, 300 Vis 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 735T to 7371' . 16:00 16:15 0.25 7,391. 7,391' PRODS STK TRIP P OWFF - Static.lnstall air slips and stri in rubbers.. 16:15 19:15 3.00 7,391 145 PRODS STK TRIP P POOH on Elevators f/ 7391.- 145 19:15 20:00 0.75 145 0 PRODS. 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 PRODS STK OTHR P Clean. & Clear Rig Floor of BOT Millin Parts 20:15 21:00 0.75 ` 0 0 PRODS WELCTL OTHR P M/U Stack Washing Tool &-Flush Kill & Choke Manifolds and Stack of Millie Debris; 420 GPM 200 si 21:00 21:30 0.50 0 0 PRODS RIGMNT SVRG P Rig Service 21:30 22:00 0.50 0 0 PRODS RIGMNT OTHR P Blow Down Topbrive & Choke /Kill Lines 22:00 22:15 0.25 0 0 PRODS WELCTI OTHR P R/U to Test BOPE; Pull. Wear Bushin ,Set Vetco Test. Plu 22:15 00:00 1.75 0 0 PRODS WELCTL BOPS P Fill Stack. & Attempt to Test Blinds, & Choke Pur e Air f/ Lines 4/26/2008 Two week BOPS test: ~~ltnesa of test waived by AOGCC ingp?ct~r rho irk S .h .vP, Tested #op 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 Iowand3000 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, directiona4 drill A4 lateral to 7630'.... Page 9 of 60 Time Logs Date From To Dur S. De~h Depth E Phase Code Subcode T Comment__ _ 00:00 __ 06:00 6.00 _ 0 , 0 _ PRODS _ 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-chokemanifold; kill line valves, choke line valves, floor safety valve and IBOP, top drive upper IBOP and lower m8nuel BOP valve. All tests were 250 psi low and 3000 psi high and held for 5 minutes each. Tests were charted. All tests passed. Accumulatortested. Gas alarms tested. 06:00 07:00 1.00 0 0 PRODS WELCTL OTHR P Blow down the choke and poor boy degasser, kill line and choke line:. Drain stack and rig down testing e ui merit. 07:00 07:15 0:25 0 0 PRODS RIGMNT SFTY 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 PRODS RIGMNT SVRG NP Service Top Drive; Repair Shot F'in Assy; Change Swivel packing again- sli ht leak low ressure. 08:30 09:00 0:50 0 0 PRODS DRILL PULD P Pickup subs and handling e ui merit for BHA. Blind rams shut 09:00 09:15 0.25 0 0 PRODS DRILL SFTY P PJSM P/U A4 Lateral BHA (6-3/4" bit and Geo ~ilot) 09:15 11:00 1.75 0 88 PRODS 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 PRODS 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 PRODS DRILL.: DHEQ T Replace Defective Gamma / Resistivity Sensor (Shorted Connector 12:30 13:15 0.75 45 45 PRODS DRILL DHEQ T Upload Software-- Unucccssful 13:15 14:45 1.50 45 45 PRODS DRILL DHEQ T Replace Dead Gamma / Resistivity Sensor Batte .14:45 15:30 0.75 45 45 PRODS DRILL DHEQ T Upload MWD Software -- Successful 15:30 16:00 0.50 45 371 PRODS 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 PRODS DRILL DHEQ P Shallow Pulse Test MWD Directional Suite; pumping 300 GPM w/ 1530 si 16:30 18:00 1.50 371 6,029 PRODS DRILL TRIP P RIH f1371.3' - 6028.87 MD; Record Up and Down Weights Every 10 Stands; Fill Pipe Every 25 Stands. - Monitor dispiacment on the trip tank. Pressure tested the swivel packing to 3000 psi-good. PU wt 150k, SO wt 110k 6028'. Page 4D of 6Q • Time Logs_ _ - _ _ -- - - __ - _ Date__ From To Dur _,___ S Depth E Depth Phase Code Subcode T Comment _ _ 18:00 18:45 0.75 6,029 7,319 PRODS DRILL TRIP TP Continue trip in the hole. PU wt 162k, SO wt 162k, Rot wt 128k, Tor ue off bottom 6k ft Jbs 40 r m: 18:45 19:15 -0.50 7,319. 7,319 PRODS 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 PRODS DRILL TRIP P Trip in the hole 19:30 20:00 0.50 7,391 7,440 PRODS DRILL DDRL P Directional drill the A 4 ateral. 20:00 20:15 0.25 7,440. 7,440 PRODS DRILL CIRC P Circulate and establish PWD baseline ECD's after drilling 49' of new hole. Pumping 320 gpm w/ 31.10 psi and ECD'a of 11.23 ppg with 9.3 ppg mud weight, 20/16 PV/YP. RPM 120 w/ 6-7k ft Ibs of'tor ue. 2Q:15 00:00 3:75 7,440 7,630 PROp3 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 PRODS DRILL DDRL P Directional drill the A 4 lateral. Max as 650 units. 06:00 12:00 6:00 8,230 8,952 PRODS pRILL DDRL P Directional drill the A 4_IateraL Max as 983 units. 12:00 18:00 6.00 8,952. 9,515 PRODS DRILL. DDRL P Directional drill the A 4 lateral: Max as 1165 units. 18:00 21:30 3.50 9,515 9;890 PRODS DRILL DDRL ' P Directional drill the A 4 lateral. Max as 'i 100 units. 21:30 00:00 2.50 9,890 10,126 PRODS DRILL DDRL P Directional drill the A 4 IateraL 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', pulF 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 dr'iIG 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 theA4lateral to 11485'. - 00:00 00:30 0.50. 1.0,126 10,170 PRODS 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 PRODS 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 PRODS DRILL DDRL P Directional drill the A 4 IateraL 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 41 of 60 • • Time Low Date From To Dur 5. Depth E__Dept_h 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 he 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 vrt 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 dill 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 T.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 RIGMN7 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 or ue. 11:15 12:00 0.75 10,452 10,545 PROD3 DRILL DDRL P Continue to directional drill the A 4 lateral. Max asobsenred 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 42 of 6Q • • Time Logs -' - - -_ __ - Date 5-_ Depth E_ Depth Phase C_ ode Subco~e T_ Comment. From To Dur 4/29/2008 _ zahrSummarv 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 hold 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 #ish 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 cleacri floor, service ri ,Chan 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, FinaF 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 IateraL-Max as observed 120 units. 08:30 41:30 3.00 11,907 12,320 PRODS 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 PRODS 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 PRODS -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 PRODS DRILL OTHR T Lost 1200 psi pump pressure. Trouble shooYcause. 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 1.4:30 0.50 12,424 11,955 PRODS 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 PRODS DRILL OWFF T Monitor the well-- static. 14:45 18:00 3.25 11,955 6,970 PRODS DRILL TRIP T Continue to pull out of the hole: - Monitordisplacement onthe trip tahk. Hole taking proper dis lacement. 18:00 20:30 2.50 6,970 185 PRODS DRILL TRIP T Continue to pull out of the hole: Monitor displacement on the trip tank. Hole taking proper. dis lacement. Page 43 of 60 Time Logs Frorn To Dur S Depth E Oz t~h .Phase .Code.. Subcode T_Com~nent _ _ _ __ _ __ -__ Date . _ __ 20:30 21:15 0.75 185 0 PROD3 DRILL TR-P 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 r 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 PRODS DRILL OTHR T Clean and clear the rig floor. 21:45 22:45 1.00 0 0 PRODS RIGMNT SVRG T Service the rig. Grease crown, blocks and to drive. 22:45 00:00 1.25 0 0 PRODS RIGMNT OTHR T Change out the 4" XT39 saver sub on the#o 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 hale). 00:00 00:45 0.75. 0 0 PRODS RIGMNT OTHR T` Continue to change out the 4" XT39 saver sub on the to drive. 00:45 01.30. -0.75 0 0 PRODS 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 PRODS FISH PULD T Makeup fishing BHA to recover 191' A To of fish 12 233'). .03:00 06:00 3.00 225 8,526 PRODS FISH TRIP T Trip in the hole with fishing BHA: , Stand # 65 QusYabove the window: PU wt 155k; SO 110k 06:00 07:00 1..00 8,526 9,840. PRODS 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 PRODS FISH CIRC T Begin rotating and washing as needed to reachthe 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 PRODS FISH FISH T En a e fish while um in 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 44 of ~Q Time Los - ~' Date From - To - Dur __ Deptfi S E Deptn Phase Code Subcode T Comment _ 12:15 19:15 7.00 . _ _ 12,424 0 _ PRODS _ 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. Contihue 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 PRODS 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 PRODS FISH OTHR T Clear and clean floor. 19:45 20:15 0.50. 0 0 PRODS FISH PULD T Bing Baker fishing tools tothe rig floor. 20:15 21:15 1.00 0 229 PRODS FISH PULD T MU second attmept BHA (to#ry and catch the 4.96" OD crossover sub below the remains cf 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 PRODS 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 in to 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 PRODS RIGMNT SFTY T Pre job safety meeting on slip and cut drillin line. 00:15 01:30 1.25 7,300 7,300 PRODS RIGMNT SVRG T Slip and cut 1-3/8"drilling line. 01:30 02:15 0.75 7,300 8,138 PRODS FISH TRIP T Run irrthe 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 PRODS FISH TRIP T Run in the hole with fishirig 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 4b of H0 • Time Logs Date__ From Tc Dur S. De~_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 PROIJ3 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 Rumin the hole with fishing BHA #2. Continue rotating in the hole from 9890' to 10250': Pumping 25 spmw/ 450 psi. Rotate 40 rpm w/ 8k ft Ibs of torque to get in-the hole. Torqued up totor ue limit set 12k ft Ibs: 07:30 08:30 1.00 10,250 10;390 PROD3 FISH CIRC T Circulate bottoms up while reaming in from 10250' to 10390'. Pumping 310 gpm w/ 2230 psi. Rotating 50 r m w/ 8-9k ft Ibs of tor_ 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 86 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 2g5 gpm w/ 2425 psi, 33% flow. Rotating 155 rpm w/ 8-9k ftibs oftorque. PU wt 210k, SO wt 85k, Rot wt 130k. Final circu-ating pressure 2230 psi w/ 34% flow. Pace 4& of 66 r Time Lomas 'Date From To Dur S ~!h _E_._ Depth_ Phase Code Subcolz T _ Co_mment_ _ 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 lbs. Lossing some mud at hi her 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 4.25 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/ Sk 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 41825'. Work tight hole withand without pumps: Pumping 59 spm(250 gpm) w/ 1940 psi. 35%0 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, totatin w_ t 140k. 17:00 17:30 0.50 41,815 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 fiole 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 torquewhile 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°lo 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 throw fi circulatin . 23:15 23:30 0:25 10,970 10,970 PROD3 FISH OTHR T Monitor well for flow- static. Page 47 of 6E3 ~ ~ I Time Lois -- - - - - - ~ Date From To Dur S. De th E Depth Phase_ Code Subcode_ T Ccn;ment 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 abovethe 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',: ruh 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 S0 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 tarik. 05:30 06:00 0.50 7,303 7,303 PRODS 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 PRODS fISH OTHR T Blow down the top drive, monitor _ well- static. 06:30 09:15 2.75 7,303 229 PRODS 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 PRODS FISH PULD T Lay down fishing BHA. 10:15 10:45 0.50. 0 0 PRODS FISH OTHR T Clear and clean rig floor. 10:45 11:00 0.25 0 17 PRODS DRILL PULD T Pickup arid make up cleanout BHA. 11:00 11:30 0.50. 17 74 PRODS DRILL PULD T RU Sperry Sun MWD tools. 11:30 -12:00 0.50 74 74 PRODS DRILL OTHR T Upload MWD. 12:00 13:00 1.00 74 ~ 355 PRODS 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 PRODS DRILL OTHR T Shallow pulse test MWD. Pumping 280 m w/ 870 si 37% flow. Page 4$ of 6tl a ~ ~ Time Logs _ _. - - - _ - Date _ From _To Dur _ 5. D~th E Depth__ Phase _Code Subco_de T_ Comment _ __ 13:15 15:45 2.50 355 7,350 PROD3 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 735T, 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 grid ream in the hole from 9971' to 11740'. Pumping 420 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 1.2233'. Pumping 250 gpm w/ 2180 pi 32% flow. Rotate 450 rpm w/ 8 to 9k ft lbs of torque. Traveling 6 to 8Yminute. 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 umping 35 spm (150 gpm}w/ 1010 psi 29% flow. No down weight. Then Rotated 40 rpm w/ 9-10k ft bs of torque. Ti-aveling 6'/min rotating down with rotating down wt of 150k. Tagged upon 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 feet/min. Obtain PU and SO wt's every 10 stands. 5/03/2008 Continue to backream from 12045' to 7333', circulate bottom's up, pump a 41 bbl sweep, continue #o 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 49 of n£t =- Time'Logs_ Date From To _ Dur _ S__Depth E De}~th Phase_ Code _Subcode T _Comment 00:00 02:15 2.25 12,015 10,909 PRODS 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 PRODS 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 lbs of torque. ECD's 11.6 ppg to 11.1 ppg. Pulling speed 10 to 15 feet/min. 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 PRODS DRILL REAM T Backream out of the hole from 9690' to 9310' .Pumping 320 gpm w/ 2450 psi 34% flow. Rotating 150 gpm vr/ 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 PRODS 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 PRODS' 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 wYs every 10 stands. 11:00 13:00 2.00 7;333 7,333 PRODS 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. PRODS DRILL OWFF T Monitorwell-static.. 13:15 13:30 0.25 7,333 7,333 PRODS DRILL CIRC T Pump a 20 bbl dry job (11ppg), install stri in rubbers. 13:30 16:30 3.00 7,333 355 PRODS DRILL TRIP. T Pullout 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 PRODS DRILL TRIP T Work the BHA 17:00 17:15 0.25 74 74 PRODS DRILL OTHR T Download MWD. .Page 50 of B(1 s Time Logs Dur 5. D_ epth E Depth Phase Code__ Subcode _T Comment _ _ _ From To i Da te _ _ ___ 17:15 17:30 0.25 74 0 PROD3 DRILL. PULD T Lay down the hole opener and ghost reamer and crossovers. 17:30 19:45 225 0 228 PROD3 FISH PULD T _. Pickup m~ke.itR~d attmepf #ishinq 19:45 00:00 4.25. 228 10,124 PROD3 FISH FISH T Run in the hole f/ 228' to 1Q124' 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, S0 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 lbs 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 pu4ses-.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 1.2172' bit depth. Pull ouf 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 TRtP T Run in the hole f/ 1.0124' to 11430 with Baker fishing BHA #3 o recover drilling assembly. Monitorretums on the trip tank. Properdisplacement. ' 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 slowpump rates. PU wt 200k, SO wt 100k. Pane 51 of 60 ..Time Logs - ~ Date From To Dur S. Depth E, Depth Phase Ccde Su_bcod~ T__ Comment - -- - - 05:00 05:15 0.25 ..11,987 12,173 PRODS FISH TRIP T Run in the hole, stand # 126 and #127. Pumping 30 spm w/ 660 psi. PU wf 203k, SO wt 105 to 110k. -05:15 05:30 0..25 12,173 12,233 : PRODS FISH FISH T Make up stand # 128, run in he 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 PRODS FISH FISH T Enoaae 6sh• Rotate nvPr and cwal~ow 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 wC 3500 psi and ood MWD detection. 05:45 06:30 -0.75 12,233 12,172 PRODS FISH TRIP T Continue to pump and pull 3 stands with the pumps. Once the cleaned out hole was reached (1223,3'), lost 30-40k drag to 205k PU wt: Maximum overpulLwas 350k on the wei ht indicator. 06:30 10:45 4.25 12,172 7,300 PRODS FISH TRIP T Pull out on elevators with'fish (drilling assembly). MonitoF 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 PRODS FISH CIRC T Monitor well- sfatic. 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 PRODS 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 PRODS FISH FISH T Continue to pull ouf 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 PRODS FISH PULD T L/D Fishing Tools (fishing BHA # 3 ), ,then lay down (Sperry Sun BHA #10) (Wellview BHA #15) from the Broken Bumper Sub (par# of the overall jar measurement). Lay down fish: The crossover;'then (3) flex. collars. Page 52 of fi~ Time Los ~ _ _ - - __ 9 - - - - ~ Date From To Dur 5 De th E De th` Phase Mode 5ubcodP T Comment - 15:30 16:45 1.25 85 85 PRODS FISH PULD T .Download MWD /Clear and organize floor. Lay down fishing tools from rig floor. 16:45 17:45 1.00 85 0 PRODS 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 PRODS 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 PRODS DRILL OTHR T Upload Sperry Sun MWD. 19:30 20:00 0.50 90 374 PRODS DRILL PULD T Continue to make up bottom hole assembl . 20:00 20:30 0.50 374 374 PRODS DRILL DHEQ 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 PRODS DRILL TRIP T Trip in the hole with drillirig assembly to 9145'. No pPoblems 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 Caaandra survey's every 10' from 12282' to 12362', excessive dogleg indicated, pull out of the hole to 12055' foropen 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 PRODS 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 S0 wt's eve 10 stands. 01:15 -01:30 0.25 10,177 10,455 PRODS 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 PRODS 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 PRODS DRILL TRIP T Continue to trip in the hole with drilling assembly from 1D270' 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 PRODS DRILL REAM T Wash & Ream in Hole. f/ 11350' - 121b0' MD; 320 GPM @ 3830 psi; 50 RPM, Torque 7 - 8K; No Down Wei ht 05:00 05:30 .0.50 12,100 12,282 PRODS DRILL REAM T Wash & Ream in Hole f/ 121D0' 12282' MD; 320 GPM @3830 psi;` 50 RPM, Torque 7 - 8K; No Down Wei ht Page 53 of fQ ~; ', Time Logs _ ' Daie From To Dur S _Depth E Depth Phase Code Subcode T Comment 05:30 07:00 1.50 12,282 92,372 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/lf 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' 121.00' 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 $K, 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 DriII 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 P-ROD3 STK TRIP T POOH f/ 12168' - 11969' MD; RIH U 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 1.2,424 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 13,01.8 93,018 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 Pullout 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. Page 54 of B0 ~~ Time Logs _ From To _Dur _ _S_ Depth E_ Depth Phase _Code _ Subcode T .Comment Date _ _ 14:15 17:.30 3.25 12,055 7,351 PRODS 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 PRODS RIGMNT SVRG P Cut & Slip 112' of drilling line 19:30 20:00 0.50 7,351 7,351 PRODS RIGMNT SVRG P Inspect drawworks, brakes, rollers, ads and a ualizer bar. 20:00 00:00 4.00 7,351 2,163 PRODS 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 PRODS 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 PRODS 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 PRODS 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 PRODS DRILL PULD P Download MWD, serViCe top drive and drawworks 03:30 04:30 1.00 85 0 PRODS 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 KURD 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 06D0 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 b5 of Hfl Time Logs _ _ -~ Date__ From To Dur S Depth _ E Depth_ Phase _Code SubCOde T_ __ Cornment i 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 oufof 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 lines 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 Tri in in hole-with whi stock retrievin BHA. 00:15 01:00 0.75 343 343. COMPZ RIGMN7 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 tum 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 WELCTL OWFF P Monitor well - brea4hing: 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 vrhipstock per Baker re .Clear ri floor. 1-4:45 15:30 0.75 0 0 COMPZ RPCOM RURD P Pickup 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 acker. Run in hole:. 18:00 18:30 0.50 262 262 COMPZ RPCOM DHEO P Shallow test MWD pumping 90 gpm / 480 si. Tested ood. Page 56 of a(7 ~ ~ Time Logs Date From To Dur S Depth_ E, De th Phase Code Suocode - T Comrnerrt __ - - - -- 18:30 .18:45 0.25 262 262 COMPZ RPGOM TRIP P Blow down topdrive _18:45 23:45 5..00 262 7,595 COMPZ RPCOM TRIP P Trip in hole with A4lateral 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 psie PU wt 190k SO wt 140k. 5/09/2008 . _ Landed hook hanger and inflated ECP. Release hanger and tripped out of hole. Test BOPS, 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 / 1020psi. PU wt 190k So wt 1,40k. - Set 40k on hook observed toolface rotate to 13 degrees right. Pulled to 200k to confirm hooked. Unhooked aY210k, pulled up 20' rotated toolface to 100R and run hook thru window. Pick up 30' rotate toolface to 8L. 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 dowry at 103 gpm / 960-psi. When ball on seat pressure up to 1-500 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 . 1.50.. 0 COMPZ RPCOM PULD P Lay down hook hanger running tools 07:45 09:00 1.25 0 0 COMPZ WELCTt BOPE P Pull wear bushing and drain stack. Set test plug, fill stack, manifold and. lines: Page 57 of 6#3 i • Time Los °Date Fram T o Dur S,_ Depth _E De th Phase_ Code Subcode ~ T CwTiment _ __ __ 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 intil200 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 WELCTI ROPE P Rig dowri BOPE test equipment, Blow dowry topdrive, manifold and lines. Run wear yin . 15:1.5 15:30.. 0.25 0 0 COMPZ RPCOM SFTY P PJSM - ruhning LEM 15:30 17:15 1.75 0 265 COMPZ RPCOM PULD P Pick u and make u LEM acker and runriin tools er Baker re . 17:15 17:30 0.25 265 265 COMPZ RPCOM DHEQ 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 ihstall 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. Bet 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 wFien ball landed oh seat. Stage pressure up to 4200 psi and hold. Bleed off pressure and slack off to 90k. Pick up to 160k and test acker with 1000 si 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 Pullout of hole with LEM running tools. Lay down drill pipe and remove supersliders. Rig up and start running 4-1/2" com lefion strin 00:00 .00'30 0.50 7,.123 7,423. 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 ki111ine. 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. Page 5H of &0 ~ ~ Time Logs - --- ~ Date From To Dur S. De th Es De th 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 bblsc 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 drilPcollars and drill i e from derrick. 15:00 15:45 0:75 0 0 COMPZ RPCOM OTHR P Pull wear bushing, clearand clean, ri floor. 15:45 18:00 2:25 0 0 COMPZ RPCOM RURD P Rig up to run 4-172"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 aril 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 8.50 537 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 RP_COM RCST P Continue tripping in hole with 4-172" 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 nippleup 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 KURD 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 up on nogo. Calculated displacement 33.5 bbls, actual 32 bbls, lost 1.5 bbls during completion run. Page 59 of 6(7 ,/ • Time Logs _ E De Sh Fhase wdc Subcode From To Dur 5. De th Gate 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 1.0 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 test4ubing hanger void to 5000 psi for 10 minutes - 6od test. Chari 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 shutin 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 aPCOM RURD P Ri lubricator and set BP ,Empty remainder SFOBM frompit, Clean ouf cellar. **' Release Rig at 24:00 hours 5/12/08 "" Page 60 of 6Q ~ i ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1C Pad 1 C-172A 50-029-23159-01 S tr,,.. Definitive Survey Report 03 June, 2008 ._ yam.:, ~.. ~ ,.~; :. .. Sperr~yr ~f!r~l[~~»~ Services ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit ND Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172A Survey Calculation Method: Minimum Curvature Design: 1G172A Database: CPAI EDM Production Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor -- -- -- - - Well 1C-172 Well Position +N/S 0.00 ft Northing: 5,968,801.43 ft Latitude: 70° 19' 31.051 N +E/-W 0.00 ft Easting: 562,101.96 ft Longitude: 149° 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 59.10ft Wellbore -~- - 1C-172A - I Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 12/17/2007 18.05 79.76 57,268 BGGM2007 3/29/2008 17.93 79.77 57,280 Design 1C-172A _ _ - _ - - __ _ ~ -_ Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,452.05 'i Vertical Secti on: Depth From (ND) +W-S +E!-W Direction lft) lft) lft) (°) 41.40 0.00 0.00 150.00 Survey Progr am Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 158.30 279.40 1C-172 Gyro (atdb) (1G172) CB-GYR©-SS Camera based gyro single shot 11/11/2004 403.29 3,452.05 1C-172 (1G172) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2004 3,513.00 13,062.56 1 C-172A MWD+SAG+CA+IIFR+MS (1 G MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1!2008 12: - Survey - _ -1 ~ Map Map Vertical ', MD Inc Azi ND NDSS +N!-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 41.40 0.00 0.00 41.40 -59.90 0.00 0.00 5,968,001.43 562,701.96 . 0.00 0.00 UNDEF4NED 158.30 0.16 315.00 158.30 57.80 0.12 -0.12 5,968,801.54 562,101.84. 0.14 -0.12 CB-GYRO-SS (1) 279.30 1.25 26.00 279.29 178.79 1.42 0.34 5,968,802.85 562,102.29 1.00 -1.42 CB-GYRO-SS (1) 403.29 2.39 36.29 403.22 302.72 4.72 2.47 5,968,806.17 562,104.39 0.95 -4.72 MWD+IFR-AK-CAZ-SC (2) 492.25 2.61 30.94 492.09 391.59 7.95 4.61 5,968,809.42 562,106.50 0.36 -7.95 MWD+IFR-AK-CAZ-SC (2) 582.80 4.26 27.22 582.48 481.98 12.71 7.20 5,968,814.20 562,109.06 1.84 -12.71 MWD+IFR-AK-CAZ-SC (2) 672.63 5.90 24.61 671.95 571.45 19.88 10.65 5,968,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 763.75 8.53 18.02 762.34 661.84 30.56 14.70 5,968,832.11 562,116.40 3.02 -30.56 MWD+IFR-AK-CAZ-SC (2) 853.71 11.70 14.76 850.89 750.39 45.73 19.08 5,968,847.31 562,120.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) j 944.17 12.70 10.82 939.31 838.81 64.37 23.29 5,968,865.98 562,124.71 1.44 -64.37 MWD+IFR-AK-CAZ-SC (2) 1,033.78 15.64 1.05 1,026.20 925.70 86.13 25.36 5,968,887.76 562,126.60 4.22 -86.13 MWD+IFR-AK-CAZ-SC (2) 6/3/2008 2:28:17PM Page 2 COMPASS 2003.16 Build 42F • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1C-172 North Reference: Wellbore: 1C-172A Survey Calculation Method: Design: 1C-172A Database: Survey Map MD Inc Azi ND NDSS +NIS +EI-W Northing lft) (°) (°) lft) (ft) (ft) lft) (ft) 1,128.53 19.91 351.25 1,116.42 1,015.92 114.86 23.14 5,968,916.47 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 16.65 5,968,949.00 1,315.26 21.18 341.57 1,290.78 1,190.28 179.74 7.40 5,968,981.21 1,407.39 26.12 338.05 1,375.15 1,274.65 214.36 -5.45 5,969,015.72 1,502.67 33.63 335.74 1,457.71 1,357.21 257.94 -24.16 5,969,059.13 1,594.46 35.67 335.01 1,533.22 1,432.72 305.37 -45.91 5,969,106.38 1,687.13 40.07 334.38 1,606.35 1,505.85 356.78 -70.23 5,969,157.58 1,780.29 44.74 331.67 1,675.13 1,574.63 412.71 -98.78 5,969,213.27 1,873.69 50.50 330.33 1,738.06 1,637.56 473.01 -132.24 5,969,273.28 1,965.93 53.61 328.47 1,794.77 1,694.27 535.60 -169.28 5,969,335.55 2,058.38 56.75 326.71 1,847.56 1,747.06 599.65 -209.97 5,969,399.26 2,151.37 66.46 324.51 1,891.73 1,791.23 667.02 -256.18 5,969,466.25 2,243.98 67.44 325.15 1,927.99 1,827.49 736.68 -305.26 5,969,535.49 2,337.06 66.78 325.57 1,964.20 1,863.70 807.23 -354.00 5,969,605.63 2,429.62 66.75 326.52 2,000.71 1,900.21 877.78 -401.51 5,969,675.77 2,522.51 64.45 324.33 2,039.09 1,938.59 947.43 -449.49 5,969,745.02 2,616.50 63.51 323.94 2,080.32 1,979.82 1,015.88 -498.98 5,969,813.05 2,708.50 62.50 324.15 2,122.08 2,021.58 1,082.24 -547.11 5,969,879.00 2,802.18 64.21 323.38 2,164.09 2,063.59 1,149.77 -596.60 5,969,946.11 2,894.33 67.26 323.39 2,201.95 2,101.45 1,217.19 -646.70 5,970,013.11 2,986.94 68.00 324.42 2,237.20 2,136.70 1,286.39 -697.15 5,970,081.88 3,079.87 66.03 320.60 2,273.50 2,173.00 1,354.27 -749.19 5,970,149.32 3,172.58 66.09 321.65 2,311.12 2,210.62 1,420.23 -802.37 5,970,214.84 3,265.42 65.93 322.72 2,348.87 2,248.37 1,487.24 -854.37 5,970,281.40 3,358.70 66.16 323.91 2,386.74 2,286.24 1,555.60 -905.30 5,970,349.33 3,452.05 66.32 323.79 2,424.35 2,323.85 1,624.59 -955.70 5,970,417.90 3,513.00 67.04 321.07 2,448.48 ~ 2,347.98 1,668.94 -989.82 5,970,461.96 3,585.84 64.84 325.52 2,478.19 2,377.69 1,722.23 -1,029.58 5,970,514.92 3,617.05 65.36 327.47 2,491.33 2,390.83 1,745.84 -1,045.21 5,970,538.39 3,649.50 65.28 328.01 2,504.88 2,404.38 1,770.77 -1,060.94 5,970,563.19 3,695.80 66.04 327.17 2,523.96 2,423.46 1,806.38 -1,083.55 5,970,598.61 3,744.69 65.69 327.41 2,543.95 2,443.45 1,843.92 -1,107.66 5,970,635.95 3,792.85 67.28 327.08 2,563.17 2,462.67 1,881.06 -1,131.56 5,970,672.88 3,840.82 66.20 327.01 2,582.11 2,481.61 1,918.04 -1,155.53 5,970,709.66 3,883.87 66.07 326.56 2,599.53 2,499.03 1,950.98 -1,177.10 5,970,742.41 3,935.75 67.35 324.51 2,620.04 2,519.54 1,990.26 -1,204.06 5,970,781.47 3,982.32 68.29 324.70 2,637.63 2,537.13 2,025.41 -1,229.04 5,970,816.41 4,030.80 68.76 323.33 2,655.37 2,554.87 2,061.92 -1,255.55 5,970,852.69 4,080.64 68.81 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 4',125.49 68.28 323.84 2,689.81 2,589.31 2,132.61 -1,308.30 5,970,922.93 We111 C-172 1 C-172A @ 100.50ft (Doyon 15) 1 C-172A @ 100.50ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Vertical Fasting DLS Section (ft) (°/100') (ft) Survey Tool Name 562,124.14 5.49 -114.86 MWD+IFR-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) 562,075.67 7.97 -257.94 MWD+IFR-AK-CAZ-SC (2) 562,053.53 2.27 -305.37 MWD+IFR-AK-CAZ-SC (2) 562,028.78 4.77 -356.78 MWD+IFR-AK-CAZ-SC (2) 561,999.78 5.38 -412.71 MWD+IFR-AK-CAZ-SC (2) 561,965.82 6.26 -473.01 MWD+IFR-AK-CAZ-SC (2) 561,928.27 3.73 -535.60 MWD+IFR-AK-CAZ-SC (2) 561,887.05 3.74 -599.65 MWD+IFR-AK-CAZ-SC (2) 561,840.30 10.65 -667.02 MWD+IFR-AK-CAZ-SC (2) 561,790.64 1.23 -736.68 MWD+IFR-AK-CAZ-SC (2) 561,741.32 0.82 -807.23 MWD+IFR-AK-CAZ-SC (2) 561,693.24 0.94 -877.78 MWD+IFR-AK-CAZ-SC (2) 561,644.68 3.28 -947.43 MWD+IFR-AK-CAZ-SC (2) 561,594.64 1.07 -1,015.88 MWD+IFR-AK-CAZ-SC (2) 561,545.97 1.12 -1,082.24 MWD+IFR-AK-CAZ-SC (2) 561,495.92 1.97 -1,149.77 MWD+IFR-AK-CAZ-SC (2) 561,445.27 3.31 -1,217.19 MWD+IFR-AK-CAZ-SC (2) 561,394.25 1.30 -1,286.39 MWD+IFR-AK-CAZ-SC (2) 561,341.66 4.34 -1,354.27 MWD+IFR-AK-CAZ-SC (2) 561,287.94 1.04 -1,420.23 MWD+IFR-AK-CAZ-SC (2) 561,235.39 1.07 -1,487.24 MWD+IFR-AK-CAZ-SC (2) 561,183.90 1.19 -1,555.60 MWD+IFR-AK-CAZ-SC (2) 561,132.94 0.21 -1,624.59 MWD+IFR-AK-CAZ-SC (2) 561,098.45 4.26 -1,668.94 MWD+IFR-AK-CAZ-SC (3) 561,058.26 6.34 -1,722.23 MWD+IFR-AK-CAZ-SC (3) 561,042.44 5.91 -1,745.84 MWD+IFR-AK-CAZ-SC (3) 561,026.50 1.53 -1,770.77 MWD+IFR-AK-CAZ-SC (3) 561,003.60 2.33 -1,806.38 MWD+IFR-AK-CAZ-SC (3) 560,979.18 0.84 -1,843.92 MWD+IFR-AK-CAZ-SC (3) 560,954.98 3.36 -1,881.06 MWD+IFR-AK-CAZ-SC (3) 560,930.71 2.26 -1,918.04 MWD+IFR-AK-CAZ-SC (3) 560,908.87 1.00 -1,950.98 MWD+IFR-AK-CAZ-SC (3) 560,881.58 4.39 -1,990.26 MWD+IFR-AK-CAZ-SC (3) 560,856.32 2.05 -2,025.41 MWD+IFR-AK-CAZ-SC (3) 560,829.51 2.80 -2,061.92 MWD+IFR-AK-CAZ-SC (3) 560,801.34 0.68 -2,099.09 MWD+IFR-AK-CAZ-SC (3) 560,776.18 2.16 -2,132.61 MWD+IFR-AK-CAZ-SC (3) 6/3/2008 2:28:17PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Surv ey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We111C-172 Project: Kuparuk River Unit ND Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Refere nce: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-1 72 North Reference: True Wellbore: 1C-1 72A Survey Ca lculation Meth od: Minimum Curvature Design: 1C-1 72A Database: CPAI EDM Production .Survey Map Map Vertical MD Inc Azi ND NDSS +Nl-S +EI-W Northing Easting D LS Section (ft) (°) (°} (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,175.33 67.30 325.15 2,703.65 2,608.15 2,170.17 -1,335.10 5,970,960.27 560,749.08 3.13 -2,170.17 MWD+IFR-AK-GAZ-SC (3) 4,220.69 66.91 328.35 2,726.31 2,625.81 2,205.11 -1,358.01 5,970,995.01 560,725.88 6.56 -2,205.11 MWD+IFR-AK-CAZ-SC (3) 4,273.07 67.39 327.31 2,746.65 2,646.15 2,245.96 -1,383.71 5,971,035.65 560,699.85 2.05 -2,245.96 MWD+IFR-AK-CAZ-SC (3) 4,315.29 67.35 326.13 2,762.89 2,662.39 2,278.54 -1,405.09 5,971,068.05 560,678.20 2.58 -2,278.54 MWD+IFR-AK-CAZ-SC (3) 4,360.35 67.02 324.56 2,780.37 2,679.87 2,312.71 -1,428.71 5,971,102.01 560,654.30 3.29 -2,312.71 MWD+IFR-AK-CAZ-SC (3) 4,409.23 67.34 323.59 2,799.32 2,698.82 2,349.19 -1,455.14 5,971,138.27 560,627.57 1.94 -2,349.19 MWD+IFR-AK-CAZ-SC (3) 4,457.69 67.78 323.19 2,817.82 2,717.32 2,385.14 -1,481.85 5,971,174.00 560,600.56 1.19 -2,385.14 MWD+IFR-AK-CAZ-SC (3) 4,506.21 68.87 323.19 2,835.74 2,735.24 2,421.24 -1,508.87 5,971,209.87 560,573.25 2.25 -2,421.24 MWD+IFR-AK-CAZ-SC (3) 4,551.46 68.80 321.91 2,852.08 2,751.58 2,454.74 -1,534.52 5,971,243.15 560,547.32 2.64 -2,454.74 MWD+IFR-AK-CAZ-SC (3) 4,601.20 68.93 320.38 2,870.02 2,769.52 2,490.87 -1,563.63 5,971,279.04 560,517.92 2.88 -2,490.87 MWD+IFR-AK-CAZ-SC (3) 4,652.27 68.66 317.69 2,888.49 2,787.99 2,526.82 -1,594.84 5,971,314.72 560,486.42 4.94 -2,526.82 MWD+IFR-AK-CAZ-SC (3) 4,695.93 67.82 314.97 2,904.68 2,804.18 2,556.15 -1,622.83 5,971,343.81 560,458.18 6.10 -2,556.15 MWD+IFR-AK-CAZ-SC (3) 4,741.75 66.56 312.96 2,922.44 2,821.94 2,585.47 -1,653.23 5,971,372.88 560,427.55 4.89 -2,585.47 MWD+IFR-AK-CAZ-SC (3) 4,791.17 65.32 309.76 2,942.60 2,842.10 2,615.29 -1,687.09 5,971,402.41 560,393.45 6.42 -2,615.29 MWD+IFR-AK-CAZ-SC (3) 4,837.62 65.20 307.28 2,962.04 2,861.54 2,641.56 -1,720.09 5,971,428.41 560,360.23 4.86 -2,641.56 MWD+IFR-AK-CAZ-SC (3) 4,885.47 65.86 304.28 2,981.86 2,881.36 2,667:01 -1,755.42 5,971,453.57 560,324.70 5.87 -2,667.01 MWD+IFR-AK-CAZ-SC (3) 4,931.69 66.66 302.49 3,000.47 2,899.97 2,690.29 -1,790.75 5,971,476.55 560,289.18 3.94 -2,690.29 MWD+IFR-AK-CAZ-SC (3) 4,979.93 66.49 300.50 3,019.65 2,919.15 2,713.41 -1,828.49 5,971,499.36 560,251.26 3.80 -2,713.41 MWD+IFR-AK-CAZ-SC (3} 5,026.88 66.90 298.16 3,038.23 2,937.73 2,734.53 -1,866.08 5,971,520.17 560,213.50 4.66 -2,734.53 MWD+IFR-AK-CAZ-SC (3) 5,075.65 67.48 296.20 3,057.13 2,956.63 2,755.07 -1,906.07 5,971,540.36 560,173.34 3.89 -2,755.07 MWD+IFR-AK-CAZ-SC (3) 5,122.83 66.43 292.82 3,075.61 2,975.11 2,773.08 -1,945.56 5,971,558.05 560,133.71 6.96 -2,773.08 MWD+IFR-AK-CAZ-SC (3) 5,171.43 66.75 290.26 3,095.15 2,994.65 2,789.41 -1,986.94 5,971,574.04 560,092.19 4.86 -2,789.41 MWD+IFR-AK-CAZ-SC (3) 5,218.47 66.25 287.55 3,114.14 3,013.64 2,803.36 -2,027.66 5,971,587.64 560,051.37 5.28 -2,803.36 MWD+IFR-AK-CAZ-SC (3) 5,267.44 67.09 285.02 3,133.53 3,033.03 2,815.96 -2,070.81 5,971,599.89 560,008.11 5.04 -2,815.96 MWD+IFR-AK-CAZ-SC (3) 5,312.08 67.20 282.82 3,150.87 3,050.37 2,825.86 -2,110.74 5,971,609.45 559,968.11 4.55 -2,825.86 MWD+IFR-AK-CAZ-SC (3) 5,361.27 66.28 279.48 3,170.30 3,069.80 2,834.60 -2,155.07 5,971,617.83 559,923.71 6.51 -2,834.60 MWD+IFR-AK-CAZ-SC (3) 5,412.46 66.84 275.53 3,190.67 3,090.17 2,840.73 -2,201.62 5,971,623.57 559,877.12 7.16 -2,840.73 MWD+IFR-AK-CAZ-SC (3) 5,457.39 66.76 273.44 3,208.37 3,107.87 2,843.96 -2,242.79 5,971,626.46 559,835.93 4.28 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 5,512.09 67.69 270.51 3,229.55 3,129.05 2,845.69 -2,293.18 5,971,627.77 559,785.52 5.22 -2,845.69 MWD+IFR-AK-CAZ-SC (3) 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,627.07 559,748.35 5.19 -2,845.30 MWD+IFR-AK-CAZ-SC (3) 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,624.22 559,702.54 5.37 -2,842.82 MWD+IFR-AK-CAZ-SC (3) 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,619.84 559,661.20 4.55 -2,838.78 MWD+IFR-AK-CAZ-SC (3) 5,696.76 66.30 .261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,613.53 559,616.72 3.38 -2,832.85 MWD+IFR-AK-CAZ-SC (3) 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,606.05 559,575.01 4.90 -2,825.70 MWD+IFR-AK-CAZ-SC (3) 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 559,532.36 6.07 -2,816.23 MWD+IFR-AK-CAZ-SC (3) 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,584.50 559,490.72 4.59 -2,804.86 MWD+IFR-AK-CAZ-SC (3) 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 559,447.91 6.88 -2,790.79 MWD+IFR-AK-CAZ-SC (3) 5,933.84 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,971,554.19 559,407.88 5.40 -2,775.22 MWD+IFR-AK-CAZ-SC (3) 5,978.50 67.04 245.10 3,413.51 3,313.01 2,758.63 -2,709.25 5,971,537.28 559,370.24 5.39 -2,758.63 MWD+IFR-AK-CAZ-SC (3) 6,028.43 66.58 242.95 3,433.18 3,332.68 2,738.53 -2,750.50 5,971,516.84 559,329.15 4.06 -2,738.53 MWD+IFR-AK-CAZ-SC (3) 6/3/2008 2:28:17PM Page 4 COMPASS 2003.16 Build 42F • i ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We111C-172 Project: Kuparuk River Unit ND Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172A Survey Calculation Method: Minimum Curvature Design: 1C-172A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E/-W Northing Easting DLS Section lft) (~) (~) (ft) (ft) lftl Ift1 (ft) (ft) (°1100') (ft) Survey Tool Name 6,074.69 67.49 240.86 3,451.23 3,350.73 2,718.47 -2,788.07 5,971,496.43 559,291.75 4.60 -2,718.47 MWD+IFR-AK-CAZ-SC t3) 6,123.77 67.64 238.03 3,469.96 3,369.46 2,695.41 -2,827.13 5,971,473.10 559,252.89 5.34 -2,695.41 MWD+IFR-AK-CAZ-SC (3) .6,169.08 66.75 235.65 3,487.52 3,387.02 2,672.57 -2,862.10 5,971,449.97 559,218.12 5.23 -2,672.57 MWD+IFR-AK-CAZ-SC (3) 6,218.69 67.03 233.61 3,507.00 3,406.50 2,646.16 -2,899.30 5,971,423.25 559,181.14 3.82 -2,646.16 MWD+IFR-AK-CAZ-SC (3) 6,267.43 67.88 230.95 3,525.69 3,425.19 2,618.62 -2,934.90 5,971,395.42 559,145.77 5.33 -2,618.62 MWD+IFR-AK-CAZ-SC (3) 6,374.03 66.91 229.11 3,543.60 3,443.10 2,590.99 -2,967.87 5,971,367.52 559,113.03 4.20 -2,590.99 MWD+IFR-AK-CAZ-SC (3) 6,358.62 66.68 226.98 3,561.17 3,460.67 2,563.59 -2,998.35 5,971,339.88 559,082.79 4.42 -2,563.59 MWD+IFR-AK-CAZ-SC (3) 6,409.08 66.96 224.00 3,581.04 3,480.54 2,531.08 -3,031.42 5,971,307.09 559,049.99 5.46 -2,531.08 MWD+IFR-AK-CAZ-SC (3) 6,455.79 66.97 221.59 3,599.32 3,498.82 2,499.54 -3,060.62 5,971,275.31 559,021.05 4.75 -2,499.54 MWD+IFR-AK-CAZ-SC (3) 6,505.16 67.34 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 558,992.00 5.37 -2,464.77 MWD+IFR-AK-CAZ-SC (3) 6,551.22 66.83 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 558,966.37 4.48 -2,431.19 MWD+IFR-AK-CAZ-SC (3) 6,599.24 66.93 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 558,941.23 5.33 -2,395.09 MWD+IFR-AK-CAZ-SC (3) 6,650.05 68.21 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 558,916.38 5.57 -2,355.45 MWD+IFR-AK-CAZ-SC (3) 6,696.47 67.69 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 558,895.30 5.08 -2,318.13 MWD+IFR-AK-CAZ-SC (3) 6,750.16 68.65 204.63 3,712.07 3,611.57 2,273.58 -3,210.20 5,971,048.15 558,873.36 7.06 -2,273.58 MWD+IFR-AK-CAZ-SC (3) 6,791.15 68.79 203.77 3,726.95 3,626.45 2,238.74 -3,225.86 5,971,013.18 558,858.00 1.98 -2,238.74 MWD+IFR-AK-CAZ-SC (3) 6,841.03 70.50 201.93 3,744.30 3,643.80 2,195.65 -3,244.01 5,970,969.95 558,840.20 4.87 -2,195.65 MWD+IFR-AK-CAZ-SC (3) 6,887.05 72.42 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 558,824.71 4.97 -2,154.99 MWD+IFR-AK-CAZ-SC (3) 6,937.09 75.14 200.64 3,772.91 3,672.41 2,110.03 -3,276.77 5,970,884.07 558,808.16 5.44 -2,110.03 MWD+IFR-AK-CAZ-SC (3) 6,981.79 75.77 197.68 3,784.14 3,683.64 2,069.16 -3,290.96 5,970,843.09 558,794.30 6.56 -2,069.16 MWD+IFR-AK-CAZ-SC (3) 7,032.37 76.56 195.96 3,796.23 3,695.73 2,022.15 -3,305.17 5,970,795.97 558,780.48 3.65 -2,022.15 MWD+IFR-AK-CAZ-SC (3) 7,076.80 77.92 193.87 3,806.05 3,705.55 1,980.28 -3,316.32 5,970,754.01 558,769.68 5.52 -1,980.28 MWD+IFR-AK-CAZ-SC (3) 7,124.94 80.37 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 558,758.92 5.18 -1,934.34 MWD+IFR-AK-CAZ-SC (3) 7,171.02 83.10 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 558,748.90 6.01 -1,889.94 MWD+IFR-AK-CAZ-SC (3) 7,217.39 84.93 191.34 3,826.57 3,726.07 1,844.86 -3,347.55 5,970,618.35 558,739.58 523 -1,844.86 MWD+IFR-AK-CAZ-SC (3) 7,266.96 84.23 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 558,731.41 5.58 -1,796.26 MWD+IFR-AK-CAZ-SC (3) 7,312.29 84.28 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 558,726.26 7.09 -1,751.51 MWD+IFR-AK-CAZ-SC (3) 7,361.90 84.37 182.83 3,840.70 3,740.20 1,702.27 -3,365.19 5,970,475.63 558,723.12 5.20 -1,702.27 MWD+IFR-AK-CAZ-SC (3) 7,398.79 83.89 181.24 3,844.47 3,743.97 1,665.60 -3,366.49 5,970,438.96 558,722.12 4.48 -1,665.60 MWD+IFR-AK-CAZ-SC (3) 7,430.40 83.26 181.28 3,848.01 3,747.51 1,634.20 -3,367.18 5,970,407.55 558,721.69 2.00 -1,634.20 MWD+IFR-AK-CAZ-SC (3) 7,457.31 83.57 180.37 3,851.09 3,750.59 1,607.47 -3,367.57 5,970,380.82 558,721.53 3.55 -1,607.47 MWD+IFR-AK-CAZ-SC (3) 7,500.41 84.00 180.84 3,855.76 3,755.26 1,564.62 -3,368.02 5,970,337.98 558,721.43 1.47 -1,564.62 MWD+IFR-AK-CAZ-SC (3) 7,552.19 83.41 180.13 3,861.44 3,760.94 1,513.16 -3,368.46 5,970,286.52 558,721.42 1.78 -1,513.16 MWD+IFR-AK-CAZ-SC (3) 7,601.90 83.95 179.73 3,866.91 3,766.41 1,463.75 -3,368.40 5,970,237.12 558,721.89 1.35 -1,463.75 MWD+IFR-AK-CAZ-SC (3) 7,642.67 83.74 179.26 3,871.28 3,770.78 1,423.22 -3,368.04 5,970,196.59 558,722.58 1.26 -1,423.22 MWD+IFR-AK-CAZ-SC (3) 7,684.06 84.46 178.53 3,875.54 3,775.04 1,382.05 -3,367.25 5,970,155.44 558,723.71 2.47 -1,382.05 MWD+IFR-AK-CAZ-SC (3) 7,732.79 84.58 178.47 3,880.19 3,779.69 1,333.56 -3,365.98 5,970,706.97 558,725.39 0.28 -1,333.56 MWD+IFR-AK-CAZ-SC (3) 7,825.10 83.81 177.35 3,889.53 3,789.03 1,241.79 -3,362.63 5,970,015.23 558,729.49 1.47 -1,241.79 MWD+IFR-AK-CAZ-SC (3) 7,917.92 83.25 177.62 3,899.99 3,799.49 1,149.65 -3,358.58 5,969,923.14 558,734.30 0.67 -1,149.65 MWD+IFR-AK-CAZ-SC (3) 8,008.96 84.56 179.37 3,909.65 3,809.15 1,059.16 -3,356.20 5,969,832.68 558,737.43 2.39 -1,059.16 MWD+IFR-AK-CAZ-SC (3) 6/3/2008 2:28: f7PM Page 5 COMPASS 2003.16 Buifd 42F ConocoPhillips Definitive Survey Report • Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Nell 1C-172 Project: Kuparuk River Unit ND Reference: 1C-1 72A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Refere nce: 1C-1 72A @ 100.50ft (Doyon 15) Well: 1C-1 72 North Reference: True Wellbore: 1C-1 72A Survey Ca lculation Met hod: Minimum Curvature Design: 1C-1 72A Database: CPAI EDM Production ,Survey Map Map Vertical MD Inc Azi ND NDSS +NIS +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 0,102.44 83.42 178.73 3,919.44 3,818.94 966.22 -::,354.18 5,969,769.77 558,740.22 1.80 -566.22 MWD+IFR-Ah-GAZ-SG (3) 8,194.99 82.81 178.62 3,930.54 3,830.04 874.38 -3,351.57 5,969,647.96 558,743.59 0.84 -874.38 MWD+IFR-AK-CAZ-SC (3) 8,274.62 86.93 181.09 3,937.66 3,837.16 795.09 -3,351.38 5,969,568.68 558,744.44 6.03 -795.09 MWD+IFR-AK-CAZ-SC (3) 8,343.98 88.55 182.01 3,940.39 3,839.89 725.81 -3,353.25 5,969,499.40 558,743.14 2.69 -725.81 MWD+IFR-AK-CAZ-SC (3) 8,438.19 87.25 182.53 3,943.84 3,843.34 631.74 -3,356.98 5,969,405.31 558,740.19 1.49 -631.74 MWD+IFR-AK-CAZ-SC (3) 8,532.62 90.03 184.38 3,946.08 3,845.58 537.52 -3,362.67 5,969,311.06 558,735.28 3.54 -537.52 MWD+IFR-AK-CAZ-SC (3) 8,626.92 90.15 183.59 3,945.94 3,845.44 443.45 -3,369.22 5,969,216.94 558,729.51 0.85 -443.45 MWD+IFR-AK-CAZ-SC (3) 8,721.25 92.01 186.47 3,944.16 3,843.66 349.52 -3,377.49 5,969,122.95 558,722.02 3.63 -349.52 MWD+IFR-AK-CAZ-SC (3) 8,815.64 90.46 182.99 3,942.12 3,841.62 255.49 -3,385.27 5,969,028.87 558,715.02 4.04 -255.49 MWD+IFR-AK-CAZ-SC (3) 8,910.27 91.82 180.35 3,940.24 3,839.74 160.93 -3,388.03 5,968,934.30 558,713.04 3.14 -160.93 MWD+IFR-AK-CAZ-SC (3) 9,004.58 90.77 179.28 3,938.11 3,837.61 66.64 -3,387.72 5,968,840.03 558,714.13 1.59 -66.64 MWD+IFR-AK-CAZ-SC (3) 9,098.34 90.77 182.05 3,936.85 3,836.35 -27.09 -3,388.81 5,968,746.30 558,713.81 2.95 27.09 MWD+IFR-AK-CAZ-SC (3) 9,191.71 90.09 179.23 3,936.15 3,835.65 -120.44 -3,389.85 5,968,652.95 558,713.54 3.11 120.44 MWD+IFR-AK-CAZ-SC (3) 9,285.83 92.75 184.28 3,933.81 3,833.31 -214.45 -3,392.73 5,968,558.93 558,711.44 6.06 214.45 MWD+IFR-AK-CAZ-SC (3) 9,330.10 89.60 181.37 3,932.91 3,832.41 -258.65 -3,394.91 5,968,514.72 558,709.63 9.69 258.65 MWD+IFR-AK-CAZ-SC (3) 9,380.05 89.10 178.55 3,933.47 3,832.97 -308.59 -3,394.88 5,968,464.79 558,710.08 5.73 308.59 MWD+IFR-AK-CAZ-SC (3) 9,424.10 90.03 176.48 3,933.81 3,833.31 -352.60 -3,392.97 5,968,420.80 558,712.35 5.15 352.60 MWD+IFR-AK-CAZ-SC (3) 9,474.75 90.34 175.41 3,933.64 3,833.14 -403.12 -3,389.38 5,968,370.32 558,716.35 2.20 403.12 MWD+IFR-AK-CAZ-SC (3) 9,568.76 89.54 177.98 3,933.74 3,833.24 -496.96 -3,383.97 5,968,276.53 558,722.55 2.86 496.96 MWD+IFR-AK-CAZ-SC (3) 9,661.26 89.97 178.51 3,934.14 3,833.64 -589.42 -3,381.13 5,968,184.11 558,726.14 0.74 589.42 MWD+IFR-AK-CAZ-SC (3) 9,755.95 89.66 178.22 3,934.44 3,833.94 -684.07 -3,378.43 5,968,089.49 558,729.63 0.45 684.07 MWD+IFR-AK-CAZ-SC (3) 9,849.45 89.66 179.51 3,935.00 3,834.50 -777.55 -3,376.58 5,967,996.04 558,732.25 1.38 777.55 MWD+IFR-AK-CAZ-SC (3) 9,944.08 90.34 180.63 3,935.00 3,834.50 -872.17 -3,376.69 5,967,901.43 558,732.92 1.38 872.17 MWD+IFR-AK-CAZ-SC (3) 10,037.87 .91.58 181.93 3,933.43 3,832.93 -965.92 -3,378.79 5,967,807.67 558,731.60 1.92 965.92 MWD+IFR-AK-CAZ-SC (3) 10,131.32 92.69 181.19 3,929.94 3,829.44 -1,059.27 -3,381.33 5,967,714.31 558,729.83 1.43 1,059.27 MWD+IFR-AK-CAZ-SC (3) 10,223.21 90.15 181.33 3,927.67 3,827.17 -1,151.10 -3,383.35 5,967,622.48 558,728.57 2.77 1,151.10 MWD+IFR-AK-CAZ-SC (3) 10,318.40 89.97 182.35 3,927.57 3,827.07 -1,246.24 -3,386.41 5,967,527.32 558,726.30 1.09 1,246.24 MWD+IFR-AK-CAZ-SC (3) 10,411.62 88.55 184.01 3,928.77 3,828.27 -1,339.31 -3,391.58 5,967,434.23 558,721.91 2.34 1,339.31 MWD+IFR-AK-CAZ-SC (3) 10,506.48 89.35 185.07 3,930.51 3,830.01 -1,433.85 -3,399.09 5,967,339.64 558,715.18 1.40 1,433.85 MWD+IFR-AK-CAZ-SC (3) 10,599.30 91.02 185.22 3,930.21 3,829.71 -1,526.29 -3,407.41 5,967,247.14 558,707.62 1.81 1,526.29 MWD+IFR-AK-CAZ-SC (3) 10,693.58 91.20 185.51 3,928.38 3,827.88 -1,620.14 -3,416.22 5,967,153.23 558,699.59 0.36 1,620.14 MWD+IFR-AK-CAZ-SC (3) 10,787.32 91.02 182.76 3,926.57 3,826.07 -1,713.61 -3,422.98 5,967,059.71 558,693.61 2.94 1,713.61 MWD+IFR-AK-CAZ-SC (3) 10,881.61 90.96 180.41 3,924.94 3,824.44 -1,807.85 -3,425.59 5,966,965.47 558,691.78 2.49 1,807.85 MWD+IFR-AK-CAZ-SC (3) 10,975.43 89.85 182.25 3,924.28 3,823.78 -1,901.63 -3,427.76 5,966,871.68 558,690.38 2.29 1,901.63 MWD+IFR-AK-CAZ-SC (3) 11,069.49 90.65 183.41 3,923.87 3,823.37 -1,995.57 -3,432.41 5,966,777.71 558,686.51 1.50 1,995.57 MWD+IFR-AK-CAZ-SC (3) 11,163.30 90.22 181.50 3,923.15 3,822.65 -2,089.29 -3,436.43 5,966,683.97 558,683.27 2.09 2,089.29 MWD+IFR-AK-CAZ-SC (3) 11,255.98 91.58 182.48 3,921.70 3,821.20 -2,181.90 -3,439.64 5,966,591.35 558,680.82 1.81 2,181.90 MWD+IFR-AK-CAZ-SC (3) 11,351.11 89.29 183.58 3,920.97 3,820.47 -2,276.89 -3,444.67 5,966,496.33 558,676.58 2.67 2,276.89 MWD+IFR-AK-CAZ-SC (3) 11,445.76 89.72 183.22 3,921.79 3,821.29 -2,371.37 -3,450.28 5,966,401.82 558,671.75 0.59 2,371.37 MWD+IFR-AK-CAZ-SC (3) 11,539.46 91.14 181.09 3,921.09 3,820.59 -2,464.99 -3,453.81 5,966,308.18 558,669.00 2.73 2,464.99 MWD+IFR-AK-CAZ-SC (3) fi/3/2008 2:28:17PM Page 6 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well1C-172 Project: Kuparuk River Unit ND Reference: iG172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: iC-172A @ 100.50ft (Doyon 15) Well: 1C-172 North Reference: True Wellbore: 1C-172A Survey Ca lculation Met hod: Minimum Curvature Desiyn: 1C-172A Database: CPAI EDM Production Survey Map Map Vertical ', MD Inc Azi ND NDSS +NIS +E/-W Northing Easting DLS Section (ft) (~) (~) (ft) (ft) (ft) (ft) (f{) (ft) (°1100') (ft) Survey Tool Name 11,633.31 90.09 180.88 3,820.08 3,819.58 -2,558.82 -3,455.42 5,966,214.35 558,868.16 1.14 2,558.82 MWD+If=R-AK-CAZ-SG (8) 11,727.15 89.60 183.90 3,920.34 3,819.84 -2,652.57 -3,459.33 5,966,120.58 558,665.03 3.26 2,652.57 MWD+IFR-AK-CAZ-SC (3) 11,821.39 92.14 184.99 3,918.90 3,818.40 -2,746.50 -3,466.64 5,966,026.60 558,658.50 2.93 2,746.50 MWD+IFR-AK-CAZ-SC (3) 11,914.67 91.21 183.96 3,916.18 3,815.68 -2,839.46 -3,473.91 5,965,933.59 558,652.00 1.49 2,839.46 MWD+IFR-AK-CAZ-SC (3) 12,008.01 90.40 182.69 3,914.87 3,814.37 -2,932.63 -3,479.32 5,965,840.39 558,647.36 1.61 2,932.63 MWD+IFR-AK-CAZ-SC (3) 12,102.50 90.65 180.44 3,914.00 3,813.50 -3,027.07 -3,481.90 5,965,745.94 558,645.56 2.40 3,027.07 MWD+IFR-AK-CAZ-SC (3) 12,195.95 89.11 180.01 3,914.20 3,813.70 -3,120.52 -3,482.27 5,965,652.50 558,645.96 1.71 3,120.52 MWD+IFR-AK-CAZ-SC (3) 12,290.06 89.60 183.05 3,915.26 3,814.76 -3,214.58 -3,484.78 5,965,558.43 558,644.23 3.27 3,214.58 MWD+IFR-AK-CAZ-SC (3) 12,383.82 91.27 183.41 3,914.54 3,814.04 -3,308.18 -3,490.07 5,965,464.80 558,639.72 1.82 3,308.18 MWD+IFR-AK-CAZ-SC (3) 12,477.56 90.40 182.68 3,913.18 3,812.68 -3,401.78 -3,495.04 5,965,371.17 558,635.52 1.21 3,401.78 MWD+IFR-AK-CAZ-SC (3) 12,570.85 91.27 182.09 3,911.82 3,811.32 -3,494.98 -3,498.93 5,965,277.95 558,632.41 1.13 3,494.98 MWD+IFR-AK-CAZ-SC (3) 12,665.04 90.71 181.04 3,910.19 3,809.69 -3,589.12 -3,501.50 5,965,183.80 558,630.62 1.26 3,589.12 MWD+IFR-AK-CAZ-SC (3) 12,758.72 88.06 180.64 3,911.20 3,810.70 -3,682.77 -3,502.87 5,965,090.15 558,630.02 2.86 3,682.77 MWD+IFR-AK-CAZ-SC (3) 12,851.88 89.72 183.45 3,913.00 3,812.50 -3,775.84 -3,506.20 5,964,997.06 558,627.47 3.50 3,775.84 MWD+IFR-AK-CAZ-SC (3) 12,945.34 89.41 184.13 3,913.71 3,813.21 -3,869.09 -3,512.37 5,964,903.77 558,622.06 0.80 3,869.09 MWD+IFR-AK-CAZ-SC (3) 13,039.36 89.04 182.65 3,914.98 3,814.48 -3,962.94 -3,577.93 5,964,809.89 558,617.28 1.62 3,962.94 MWD+IFR-AK-CAZ-SC (3) 13,062.56 89.91 182.53 3,915.20 3,814.70 -3,986.11 -3,518.98 5,964,786.71 558,616.42 3.79 3,986.11 MWD+IFR-AK-CAZ-SC (3) 13,101.00 89.91 182.53 3,915.26 3,814.76 -4,024.52 -3,520.68 5,964,748.30 558,615.04 • 0.00 4,024.52 PROJECTED to TD fi/3/2008 2:28:17PM Page 7 COMPASS 2003.16 Build 42F 09/15/08 i ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # - ,, ~ a; N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD r 1 ~ I ~~ Log Description 1 C-172A 11978478 PRODUCTION PROFILE '~- 08/19/08 1 1 1C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT CyZS - {(n 9/L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~ a0$ -O'~ ~ l ~c~l ~~ 08/27/08 1 1 2U-06 12080428 LDL _p( - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE -D 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - f~ / Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE (p 09/05/08 1 1 1C-174 12096539 INJECTION PROFILE - D 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ 09/09/08 1 1 30-01 11975792 LDL `~-U~ 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 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 RESISTNITY & GAMMA RAY Logs: 1 Color Log 50-029-23159-01,60,61,70, 71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23159-01,60,61,70,71 Digital Log Images 1 CD Rom 5 0-02 9-2 315 9-O 1, 60, 61, 70, 71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _ J , l BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 I/ ~o~r-o0 ~ i~ olio Signed:~~~ --~ a o~=ot~S i ~'~'~ ~ aa~ _~ 1 ~,~r ~ • C~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 C Pad 1 C-172A 50-029-23159-01 Definitive Survey Report 03 June, 2008 D~~=iNITIVE r ~ ~ f I ~. ~ ..~ ,~~. ~' :.:; ;. 3 °.~sperry C~rillr~~ Sr~vic~a • ConocoPhillips Definitive Sur~~ey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C-172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) ..Well: 1C-172 North Reference: True Wellbore; 1C-172A Survey Caiculation Method: Minimum Curvature Design:. 1C-172A Database: CPAI EDM Production Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution.) System C)atum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1C-172 ---- ~~ Well Position +N/-S 0.00 ft Northing: 5,968,801.43 ft Latitude: 70° 19' 31.051 N ~ +E/-W 0.00 ft Easting: 562,101.96 ft Longitude: 149° 29' 47.110 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Graund Level: 59.10ft Wellbore 1C-172A Magnetics Model Name Sample Date Declination Dip Angie Fir;ld Strength BGGM2007 12/17!2007 BGGM2007 3/29/2008 ~°),) 18.05 17.93 `(°) 79.76 79.77 (nT) 57,2tits 57,280 __ Design _ --- 1C-172A - _ --- __. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,452.05 Vertical Sect ion: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) ~ 41.sri ri-r_i0 -- ~ ~ ni 180.00 Survey Progr am Date From To (ft) (ft) Survey (Wellbore) Tool Name Description vey ~-il=: 158.30 279.40 1C-172 Gyro (atdb) (1C-172) CB-GYRU-S:S Camera based gyro single shot 11/111'1004 403.29 3,452.05 1C-172 (1C-172) MWD+IFR-A,K-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2004 3,513.00 13,062.56 1C-172A MWD+SAG+CA+IIFR+MS (1C- MWD+IFR-ArK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2008 12: Survey I MD Inc Azi TVD TVDSS +N/-5 (ft) C7 ('~) (ft) Ift? (ftp 41.au uA0 u.uu 41.40 -5b.1u O.vu 158.30 0.16 315.00 158.30 57.80 0.12 I 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 1,033.78 15.64 1.05 1,026.20 925.70 86.13 Map Map Vertical +E/-W Northing Easting DLS Section (ft} (ft) (ft) (°1100') (ft) Survey Tool Name u.00 5,968,801.43 562,301.9b 0.00 u.uu UNDEFINED -0.12 :5,968,801.54 562,901.84 0.14 -0.12 CB-GYtZO-SS (1) 0.34 ..5,968,502.85 562,102.29 1.00 -1.42 CB-GYRO-SS (1) 2.47 5,968,806.17 562,104.39 0.95 -4.72 MWD+iFR-AK-CAZ-SC (2) 4.61 :5,968,809.42 562,906.50 0.36 -7.95 MWD+ifR-AK-CAZ-SC (2) 7.20 3,968,814.20 562,109.06 1.84 -12.71 MWD+tFR-AK-CAZ-SC (2) 10.65 5,968,821.39 562,112.45 1.84 -19.88 MWD+IFR-AK-CAZ-SC (2) 14.70 5,968,832.11 562,116.40 3.02 -30.56 MWD+fFR-AK-CAZ-SC (2) 19.08 .5,968,847.31 562,320.66 3.58 -45.73 MWD+IFR-AK-CAZ-SC (2) 23.29 :5,968,865.98 562„124.71 1.44 -64.37 MWD+tFR-AK-CAZ-SC (2) 25.36 5,968,887.76 562,126.60 4.22 -86.13 MWD+IFR-AK-CAZ-SC (2) 6/3/2008 2:28:17PM Page~~ COMPASS 2003.16 Build 42F • ConocoPhillips • Definitive Survey Report Company:. ConocoPhillips(Alaska) Inc. Local Co-orcfinate Reference: Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C-172A @ 100.50ft (Doyc~+~ 15) Site: Kuparuk 1C Pad MD Reference:.. 1C-172A ~ 100.50ft (Doy~r~ 15) Well: 1C-172 "North Re ference: Tr ue Wellbore: 1C-172A Survey. C alculation Method: Minimum C urvature Desiyn: 1C-172A Database: CPAI EDNf Production Survey - - - - - Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E;-W rforthing Fasting DLS Section (ft) (°) (°) (ft)_ (ft) (ft) (ft) (ft) (ft} (°.1100'} (ft) ' Sara/ey Tool Name 1,128.53 19.9'1 351.25 1,116.42 1,015.92 114.$6 13.14 5,968,916.47 562,124.14 5.49 -114.86 MW'J+IFR-AK-CAZ-ac l2) 1,222.75 21.43 346.42 1,204.58 1,104.08 147.46 16.65 5,968,949.00 562,117.39 2.42 -147.46 MV4~+IFR-AK-CAZ-SC (2) 1,315.26 21.18 341.57 1,290.78 1,190.28 179.74 7.40 5„968,981.21 562,107.87 1.92 -179.74 MW~+IFR-AK-CAZ-SC (2) 1,407.39 26.12 338.05 1,375.15 1,274.65 214.36 -5.45 5,969,015.72 562,094.74 5.57 -214.36 MW~+lFR-AK-CAZ-SC (2) 1,502.67 33.63 335.74 1,457.71 1,357.21 257.94 -24.16 5,969,059.13 562,075.67 7.97 -257.94 MW~7+IFR-AK-CAZ-SC (2) 1,594.46 35.67 335.01 1,533.22 1,432.72 305.37 -45.91 5,969,106.38 562,053.53 227 -305.37 MWr•<7+IFR-AK-CAZ-SC (2) 1,687.13 40.07 334.38 1,606.35 1,505.85 356.78 -70.23 5,969,157.58 562,028.78 4..77 -356.78 MW~"7+IFR-AK-CAZ-SC (2) 1,780.29 44.74 331.67 1,675.13 1,574.63 412.71 -98.78 5,969,213.27 561,999.78 5.3$ -412.71 MWI~+IFR-AK-CAZ-SC (2) 1,873.69 50.50 330.33 1,738.06 1,637.56 473.01 -132.24 5,969,273.28 561,565.82 6.26 -473.01 MW~+IFR-AK-CAZ-SC (2) 1,965.93 53.61 328.47 1,794.77 1,694.27 535.60 -169.28 5,969,335.55 561,928.27 3.73 -535.60 MW~]+IFR-AK-CAZ-SC (2) 2,058.38 56.75 326.71 1,847.56 1,747.06 599.65 -209.97 5,969,399.26 561,887.05 3.74 -599.65 MW~+IFR-AK-CAZ-SC (2) 2,151.37 66.46 324.51 1,891.73 1,791.23 667.02 -256.18 5,969,466.25 561,840.30 10.65 -667.02 MWtFJ+IFR-AK-CAZ-SC (2) 2,243.98 67.44 325.15 1,927.99 1,827.49 736.68 -305.26 5,969,535.49 561,790.64 1.23 -736.68 MWH~+IFR-AK-CAZ-SC (2) 2,337.06 66.78 325.57 1,964.20 1,863.70 807.23 -354.00 5,969,605.63 561,741.32 0.82 -807.23 MW~+IFR-AK-CAZ-SC (2) 2,429.62 66.75 326.52 2,000.71 1,900.21 877.78 -401.51 5,969,675.77 561,693.24 0.94 -877.78 MW~+IFR-AK-CAZ-SC (2) 2,522.51 64.45 324.33 2,039.09 1,938.59 947.43 -449.49 5,969,745.02 561,644.68 3.28 -947.43 MW~+IFR-AK-CAZ-SC (2) 2,616.50 63.51 323.94 2,080.32 1,979.82 1,015.88 -498.98 5,969,813.05 561,594.64 1.07 -1,015.88 MW~+IFR-AK-CAZ-SC (2) 2,708.50 62.50 324.15 2,122.08 2,021.58 1,082.24 -547.11 5,969,879.00 561,545.97 1.12 -1,082.24 MWlD+IFR-AK-CAZ-SC (2) 2,802.18 64.21 323.38 2,164.09 2,063.59 1,149.77 -596.60 5,969,946.11 561,495.92 1.97 -1,149.77 MW~+IFR-AK-CAZ-SC (2) 2,894.33 67.26 323.39 2,201.95 2,101.45 1,21.7.19 -646.70 5,970,013.11 561,445.27 3.31 -1,217.19 MW~+tFR-AK-CAZ-SC (2) 2,986.94 68.00 324.42 2,237.20 2,136.70 1,286.39 -697.15 5,970,081.88 561,394.25 1.30 -1,286.39 MW~+IFR-AK-CAZ-SC (2) 3,079.87 66.03 320.60 2,273.50 2,173.00. 1,354.27 -749.19 5,970,149.32 561,341.66 4.34 -1,354.27 MW~+IFR-AK-CAZ-SC (2) 3,172.58 66.09 321.65 2,311.12 2,210.62 1,420.23 -802.37 5,970,214.84 561,287.94 1.04 -1,420.23 MWL3+iFR-AK-CAZ-SC (2) 3,265.42 65.93 322.72 2,348.87 2,248.37 1,487.24 -854.37 5,970,281.40 561,235.39 1.07 -1,487.24 MWI~+tFR-AK-CAZ-SC (2) 3,358.70 66.16 323.91 2,386.74 2,286.24 1,555.60 -905.30 5,970,349.33 561,183.90 1.19 -1,555.60 MWE)+PFR-AK-CAZ-SC (2) 3,452.05 66.32 323.79 2,424.35 2,323.85 1,624.59 -955.70 5,970,417.90 561,132.94 0.21 -1,624.59 MW~+IFR-AK-CAZ-SC (2) 3,513.00 67.04 321.07 2,448.48 2,347.98 1,668.94 -989.82 5,970,461.96 561,098.45 4.26 -1,668.94 MWt~+PFR-AK-CAZ-SC (3) 3,585.84 64.84 325.52 2,478.19 2,377.69 1,722.23 -1,029.58 5,970,514.92 561,058.26 6.34 -1,722.23 MWD)+tFR-AK-CAZ-SC (3) 3,617.05 65.36 327.47 2,491.33 2,390.83 1,745.84 -1,045.21 5,970,538.39 561,042.44 5.91 -1,745.84 MWL3+tFR-AK-CAZ-SC (3) 3,649.50 65.28 328.01 2,504.88 2,404.38 1,770.77 -1,060.94 5,970,563.19 561,026.50 1.53 -1,770.77 MWEJ+tFR-AK-CAZ-SC (3) 3,695.80 66.04 327.17 2,523.96 2,423.46 1,806.38 -1,083.55 5,970,598.61 561,003.60 2.33 -1,806.38 MWG3+IFR-AK-CAZ-SC (3) 3,744.69 65.69 327.41 2,543.95 2,443.45 1,843.92 -1,107.66 5,970,635.95 560,979.18 0.84 -1,843.92 MWE'3+IFR-AK-CAZ-SC (3) 3,792.85 67.28 327.08 2,563.17 2,462.67 1,881.08 -1,131.56 5,970,672.88 560,954.98 3.36 -1,881.06 MWCa+IFR-AK-CAZ-SC (3) 3,840.82 66.20 327.01 2,582.11 2,481.61 1,918.04 -1,155.53 5,970,709.66 560,930.71 2.26 -1,918.04 MWD')+IFR-AK-CAZ-SC (3) 3,883.87 66.07 326.56 2,599.53 2,499.03 1,950.98 -1,177.10 5,970,742.41 560,908.87 1.00 -1,950.98 MWF,7+kFR-AK-CAZ-SC (3) 3,935.75 67.35 324.51 2,620.04 2,519.54 1,990.26 -1,204.06 5,970,781.47 560,881.58 4.39 -1,990.26 MWG+IFR-AK-CAZ-SC (3) 3,982.32 68.29 324.70 2,637.63 2,537.13 2,025.41 -1,229.04 5,970,816.41 560,856.32 2.05 -2,025.41 MWit?+IFR-AK-CAZ-SC (3) 4,030.80 68.76 323.33 2,655.37 2,554.87 2,061.92 -1,255.55 5,970,852.69 560,829.51 2.80 -2,061.92 MWG)+IFR-AK-CAZ-SC (3) 4,080.64 68.81 322.97 2,673.41 2,572.91 2,099.09 -1,283.41 5,970,889.63 560,801.34 0.68 -2,099.09 MWEr>+IFR-AK-CAZ-SC (3) 4,125.49 68.28 323.84 2,689.81 2,589.31 2,132.61 -1,308.30 5,970,922.93 560,776.18 2.16 -2,132.61 MWEh+IFR-AK-CAZ-SC (3) 6/3/2008 2:28:97PM Page 3 COMP;~~SS 2003.16 Build 42F ConocoPt~illips • Definitive Survey Report Company: Co nocoPhillips(Alaska) I nc. Local~Co -ordinate Refe rence: Well 1C-b 72 Project: Kuparuk River Unit TVD Reference: 1C-172A @ 100.50ft (Doyon 15) Site; Kuparuk 1C Pad MD Reference: 1C-172A @ 100.50ft (Doyon 15) Well: 1 C-172 North Re ference; True Wellbore: 1C-172A Survey C alculation Met hod: Minimurra Curvature Design: 1C- 172A Database:. CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS 'Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Namc 4,175.33 67.30 325.15 2,708.65 2,608.15 2,170.17 -1,3s5.i0 5,970,you.tl 560,749.08 3.33 -2,170.11 MWD+iF~2-AK-CAZ-SC 13) ~ 4,220.69 66.91 328.35 2,726.31 2,625.81 2;205.11 -1,358.01 5,970,995.01 560,725.88 6.56 -2,205.11 MWD+IF12-AK-CAZ-SC (3) 4,273.07 67.39 327.31 2,746.65 2,646.15 2,245.96 -1,383.71 5,971,035.65 560,699.85 205 -2,245.96 MWD+IF~-AK-CAZ-SC (3) j 4,315.29 67.35 326.13 2,762.89 2,662.39 2,278.54 -1,405.09 5,971,068.05 560,678.20 2.58 -2,278.54 MWD+IF1a-AK-CAZ-SC (3) 4,360.35 67.02 324.56 2,780.37 2,679.87 2,312.71 -1,428.71 5,971,102.01 560,654.30 3.29 -2,312.71 MWD+IF1.2-AK-CAZ-SC (3) ~ 4,409.23 67.34 323.59 2,799.32 2,698.82 2,349.19 -1,455.14 5.,971,138.27 560,627.57 1.94 -2,349.19 MWD+IFft-AK-CAZ-SC (3) 4,457.69 67.78 323.19 2,817.82 2,717.32 2,385.14 -1,481.85 5,971,174.00 560,600.56 1.119 -2,385.14 MWD+IFS2-AK-CAZ-SC (3) i 4,506.21 68.87 323.19 2,835.74 2,735.24 2,421.24 -1,508.87 5,971,209.87 560,573.25 2.25 -2,421.24 MWD+IFF2-AK-CAZ-SC (3) 4,551.46 68.80 321.91 2,852.08 2,751.58 2,454.74 -1,534.52 5,:971,243.15 560,547.32 2.64 -2,454.74 MWD+IF9~-AK-CAZ-SC (3) 4,601.20 68.93 320.38 2,870.02 2,769.52 2,490.87 -1,563.63 5,971,279.04 560,517.92 2.88 -2,490.87 MWD+IF~2-AK-CAZ-SC (3) 4,652.27 68.66 317.69 2,888.49 2,787.99 2,526.82 -1,594.84 5,971,314.72 560,486.42 4.94 -2,526.82 MWD+IFA2-AK-CAZ-SC (3) 4,695.93 67.82 314.97 2,904.68 2,804.18 2,556.15 -1,622.83 5.,971,343.81 560,458.18 6.'10 -2,556.15 MWD+IFp2-AK-CAZ-SC (3) ~ 4,741.75 66.56 312.96 2,922.44 2,821.94 2,585.47 -1,653.23 5,971,372.88 560,427.55 4.89 -2,585.47 MWD+IF92-AK-CAZ-SC (3) 4,791.17 65.32 309.76 2,942.60 2,842.10 2,615.29 -1,687.09 5,971,402.41 560,393.45 6.x}2 -2,615.29 MWD+IF~2-AK-CAZ-SC (3) 4,837.62 65.20 307.28 2,962.04 2,861.54 2,641.56 -1,720.09 5x971,428.41 560,360.23 4.86 -2,641.56 MWD+IF&~-AK-CAZ-SC (3) 4,885.47 65.86 304.28 2,981.86 2,881.36 2,667.01 -1,755.42 5x°971,453.57 560,324.70 5.87 -2,667.01 MWD+IF92-AK-CAZ-SC (3) i 4,931.69 66.66 302.49 3,000.47 2,899.97 2,690.29 -1,790.75 5,971,476.55 560,289.18 3.94 -2,690.29 MWD+IFR3-AK-CAZ-SC (3) 4,979.93 66.49 300.50 3,019.65 2,919.15 2,713.41 -1,828.49 5;971,499.36 560,251.26 3.80 -2,713.41 MWD+IF~R-AK-CAZ-SC (3) 5,026.88 66.90 298.16 3,038.23 2,937.73 2,734.53 -1,866.08 5,'571,520.17 560,213.50 4.66 -2,734.53 MWD+-F62-AK-CAZ-SC (3) 5,075.65 67.48 296.20 3,057.13 2,956.63 2,755.07 -1,906.07 5,971,540.36 560,173.34 3.89 -2,755.07 MWD+IFB2-AK-CAZ-SC (3) 5,122.83 66.43 292.82 3,075.61 2,975.11 2,773.08 -1,945.56 5,:971,558.05 560,133.71 6.96 -2,773.08 MWD+IFf?-AK-CAZ-SC (3) 5,171.43 66.15 290.26 3,095.15 2,994.65 2,789.41 -1,986.94 5,971,574.04 560,092.19 4.86 I -2,789.41 MWD+IF63-AK-CAZ-SC (3) 5,218.47 66.25 287.55 3,114.14 3,013.64 2,803.36 -2,027.66 5.971,587.64 560,051.37 5.28 -2,803.36 MWD+IF&~-AK-CAZ-SC (3) 5,267.44 I 67.09 285.02 3,133.53 3,033.03 2,815.96 -2,070.81 5;:971,599.89 560,008.11 5.04 -2,815.96 MWD+IFfd-AK-CAZ-SC (3) 5,312.08 67.20 282.82 3,150.87 3,050.37 2,825.86 -2,110.74 5,971,609.45 559,968.11 4.55 -2,825.86 MWD+IF9x-AK-CAZ-SC (3) ~ 5,361.27 66.28 279.48 3,170.30 3,069.80 2,834.60 -2,155.07 5,971,617.83 559,923.71 6.51 -2,834.60 MWD+IFF3-AK-CAZ-SC (3) 5,412.46 66.84 275.53 3,190.67 3,090.17 2,840.73 -2,201.62 5,971,623.57 559,877.12 7.'16 -2,840.73 MWD+IFR-AK-CAZ-SC (3) 5,457.39 66.76 273.44 3,208.37 3,107.87 2,843.96 -2,242.79 5=971,626.46 559,835.93 4.?8 -2,843.96 MWD+IFR-AK-CAZ-SC (3) 5,512.09 67.69 270.51 3,229.55 3,129.05 2,845.69 -2,293.18 Sp971,627.77 559,785.52 5.22 -2,845.69 MWD+IFPR-AK-CAZ-SC (3) j 5,552.33 67.36 268.28 3,244.94 3,144.44 2,845.30 -2,330.36 5,971,627.07 559,748.35 5.119 -2,845.30 MWD+IF~-AK-CAZ-SC (3) 5,602.24 66.47 265.53 3,264.51 3,164.01 2,842.82 -2,376.20 5,971,624.22 559,702.54 5.3:7 -2,842.82 MWD+IFf2-AK-CAZ-SC (3) 5,647.65 66.09 263.31 3,282.78 3,182.28 2,838.78 -2,417.58 5,971,619.84 559,661.20 4.55 -2,838.78 MWD+IFtR-AK-CAZ-SC (3) i 5,696.76 66.30 261.51 3,302.60 3,202.10 2,832.85 -2,462.11 5,971,613.53 559,61.6.72 3.38 -2,832.85 MWD+IFR-AK-CAZ-SC (3) 5,743.14 65.81 259.08 3,321.43 3,220.93 2,825.70 -2,503.89 5,971,606.05 559,575.01 4.00 -2;825.70 MWD+IFR-AK-CAZ-SC (3) I~ 5,791.05 66.23 255.93 3,340.90 3,240.40 2,816.23 -2,546.62 5,971,596.22 559,532.36 6.07 -2,816.23 MWD+IFFR-AK-CAZ-SC (3) I 5,838.28 66.50 253.58 3,359.84 3,259.34 2,804.86 -2,588.36 5,971,584.50 559,490:72 4.59 -2,804.86 MWD+IF~-AK-CAZ-SC (3) 5,887.33 67.71 250.16 3,378.93 3,278.43 2,790.79 -2,631.29 5,971,570.09 559,447.91 6.8$ -2,790.79 MWD+IFR~-AK-CAZ-SC (3) 5,933.84 I 68.04 247.47 3,396.45 3,295.95 2,775.22 -2,671.46 5,971,554.19 559,407.88 5.4k0 -2,775.22 MWD+IFR-AK-CAZ-SC (3) i 5,978.50 I 67.04 245.10 3,413.51 3,313.01 2,758.63 -2,709.25 5,'971,537.28 559,370.24 5.39 -2,758.63 MWD+IFr~-AK-CAZ-SC (3) i I 6,028.43 66.58 242.95 3,433.18 3,332.68 2,738.53 -2,750.50 5:971,516.84 559,329.15 4.06 -2,738.53 MWD+IFR-AK-CAZ-SC (3) ~~ 6/3/2008 2:28:17PM Page 4 COMPASS 2D03.16 Build 42F • Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1C Pad 1 C-172 1C-172A 1 C-172A MD Jnc Azi' 6,074.69 67.49 240.86 6,123.77 67.64 238.03 6,169.08 66.75 235.65 6,218.69 67.03 233.61 ConocoPhillips • Definitive Survey Report 'Local Cw-ordinate Reference: Well 1C-172 TVD Reference: 1C-'172A @ 100.50ft (Doy4n 15) MD Reference: 1C-172A @ 100.50ft (Doyon 15) North Refierence: True Survey Calculation`Method: Minimum Curvature Database: CPAI EDM Production TVD TVDSS +NI-S 3,451.23 3,350.73 2,718.47 3,469.96 3,369.46 2,695.41 3,487.52 3,387.02 2,672.57 3,507.00 3,406.50 2,646.16 Map +E/=W Northing. (ft) (ft) -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 6,267.43 67.88 230.95 3,525.69 3,425.19 2,618.62 -2,934.90 5,971,395.42 6,314.03 66.91 229.11 3,543.60 3,443.10 2,590.99 -2,967.87 5,971,367.52 6,358.62 66.68 226.98 3,561.17 3,460.67 2,563.59 -2,998.35 5,971,339.88 6,409.08 66.96 224.00 3,581.04 3,480.54 2,531.08 -3,031.42 5,971,307.09 6,455.79 66.97 221.59 3,599.32 3,498.82 2,499.54 -3,060.62 5,971,275.31 6,505.16 67.34 218.74 3,618.49 3,517.99 2,464.77 -3,089.96 5,971,240.31 6,551.22 66.83 216.57 3,636.42 3,535.92 2,431.19 -3,115.88 5,971,206.52 6,599.24 66.93 213.79 3,655.28 3,554.78 2,395.09 -3,141.32 5,971,170.22 6,650.05 68.21 211.06 3,674.67 3,574.17 2,355.45 -3,166.50 5,971,130.37 6,696.47 67.69 208.58 3,692.10 3,591.60 2,318.13 -3,187.89 5,971,092.88 6,750.16 68.65 204.63 3,712.07 3,611.57 2,273.58. -3,210.20 5,971,048.15 6,791.15 68.79 203.77 3,726.95 3,626.45 2,238.74 -3,225.86 5,971,013.18 6,841.03 70.50 201.93 3,744.30 3,643.80 2,195.65 -3,244.01 5,970,969.95 6,887.05 72.42 200.62 3,758.93 3,658.43 2,154.99 -3,259.84 5,970,929.16 6,937.09 75.14 200.64 3,772.91 3,672.41 2,110.03 -3,276.77 5,970,884.07 6,981.79 75.77 197.68 3,784.14 3,683.64 2,069.16 -3,290.96 5,970,843.09 7,032.37 76.56 195.96 3,796.23 3,695.73 2,022.15 -3,305.17 5,970,795.97 7,076.80 77.92 193.87 3,806.05 3,705.55 1,980.28 -3,316.32 5,970,754.01 7,124.94 80.37 193.40 3,815.11 3,714.61 1,934.34 -3,327.47 5,970,707.98 7,171.02 83.10 192.94 3,821.74 3,721.24 1,889.94 -3,337.85 5,970,663.50 7,217.39 84.93 191.34 3,826.57 3,726.07 1,844.86 -3,347.55 5,970,618.35 7,266.96 84.23 188.65 3,831.25 3,730.75 1,796.26 -3,356.12 5,970,569.69 7,312.29 84.28 185.42 3,835.79 3,735.29 1,751.51 -3,361.64 5,970,524.89 7,361.90 84.37 182.83 3,840.70 3,740.20 1,702.27 -3,365.19 5,970,475.63 7,398.79 83.89 181.24 3,844.47 3,743.97 1,665.60 -3,366.49 5,970,438.96 7,430.40 83.26 181.28 3,848.01 3,747.51 1,634.20 -3,367.18 5,970,407.55 7,457.31 83.57 180.37 3,851.09 3,750.59 1,607.47 -3,367.57 5,970,380.82 7,500.41 84.00 180.84 3,855.76 3,755.26 1,564.62 -3,368.02 5,970,337.98 7,552.19 83.41 180.13 3,861.44 3,760.94 1,513.16 -3,368.46 5,970,286.52 7,601.90 83.95 179.73 3,866.91 3,766.41 1,463.75 -3,368.40 5,970,237.12 7,642.67 83.74 179.26 3,871.28 3,770.78 1,423.22 -3,368.04 5,970,196.59 7,684.06 84.46 178.53 3,875.54 3,775.04 1,382.05 -3,367.25 5,970,155.44 7,732.79 84.58 178.47 3,880.19 3,779.69 1,333.56 -3,365.98 5,970,106.97 7,825.10 83.81 177.35 3,889.53 3,789.03 1,241.79. -3,362.63 5,970,015.23 7,917.92 83.25 177.62 3,899.99 3,799.49 1,149.65 -3,358.58 5,969,923.14 8,008.96 84.56 179.37 3,909.65 3,809.15 1,059.16 -3,356.20 5,969,832.618 Map Vertical Fasting DL5 Section {ft) (°/100') (ft) Survey Tool. Name 559,291.75 4.60 -2,718.47 Iv1WD+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 MW'®+IFR-AK-CAZ-SC (3) 559,181.14 3.82 -2,646.16 MWID+IFR-AK-CAZ-SC (3) 559,145.77 5.33 -2,618.62 MWp+IFR-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 MW®+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 MW®+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 MWp+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-AIC-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-AiC-CAZ-SC (3) 558,739.58 5.23 -1,844.86 MWD+IFR-AAC-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-A3t-CAZ-SC (3) 558,723.12 5.20 -1,702.27 MWD+IFR-AIK-CAZ-SC (3) 558,722.12 4.48 -1,665.60 MWD+IFR-A9C-CAZ-SC (3) 558,721.69 2.00 -1,634.20 MWD+IFR-A9C-CAZ-SC (3) 558,721.53 3.55 -1,607.47 MWD+IFR-ARC-CAZ-SC (3) 558,721.43 1.47 -1,564.62 MWD+IFR-AR<-CAZ-SC (3) 558,721.42 1.78 -1,513.16 MWD+IFR-AIK-CAZ-SC (3) 558,721.89 1.35 -1,463.75 MWD+IFR-AlK-CAZ-SC (3) 558,722.58 1.26 -1,423.22 MWD*IFR-A&C-CAZ-SC (3) 558,723.71 2.47 -1,382.05 MWD+IFR-ARC-CAZ-SC (3) 558,725.39 0.28 -1,333.56 MWD+IFR-ARC-CAZ-SC (3) 558,729.49 1.47 -1,241.79 MWD+IFR-ARC-CAZ-SC (3) 558,734.30 0.67 -1,149.65 MWD+IFR-ARC-CAZ-SC (3) 558,737.43 2.39 -1,059.16 MWD+IFR-AR<-CAZ-SC (3) 6/3/2008 2:28:17PM Page :5 COMP7a,SS 2G~03.16 Suiid 42F • ConocoPhillips • Definitive Survey Report Company:. ConocoPhillips(Alaska) Inc. LocaFCo-ordinate Reference:' Well 1C-172 Project: Kuparuk River Unit TVD Reference: 1C -172A @ 100.50ft (Doyon 15) Site: Kuparuk 1C Pad MD Reference: 1C -172A @ 100.50ft (Doyon 15) Welf: 1C- 172 `North Reference: Tru e Wellbore: 1C- 172A Survey C alculation Met hod: Minimum Curvature Design: 1C- 172A Database : CPAI EDM Production S~irvey Map: Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Eastnc~ DLS Section ', (ft) (°) (°) (ft) (ft) (ft) (ft} (ft) (ft) (°/100') (ft) Survey Tool Name 8,102.44 83.42 178.13 3,919.44 3,818.94 966.22 -3,354.18 :x,969,739.77 558,740::_22 1.80 -966.22 M4~VD+IFR-AK-CAZ-SC (3) 8,194.99 82.81 178.62 3,930.54 3,830.04 874.38 -3,351.57 5,969,647.96 558,743'.59 0.84 -874.38 MEND+IFR-AK-CAZ-SC (3) 8,274.62 86.93 181.09 3,937.66 3,837.16 795.09 -3,351.38 5„969,568.68 558,744:.44 6.03 -795.09 MWD+IFR-AK-CAZ-SC (3) 8,343.98 88.55 182.01 3,940.39 3,839.89 725.81 -3,353.25 5,969,499.40 558,743.14 2.69 -725.81 MWD+IFR-AK-CAZ-SC (3) 8,438.19 87.25 182.53 3,943.84 3,843.34 631.74 -3,356.98 5,969,405.31 558,740k.19 1.49 -631.74 M1dVD+tFR-AK-CAZ-SC (3) 8,532.62 90.03 184.38 3,946.08 3,845.58 537.52 -3,362.67 5,;969,311.06 558,735.:28 3.54 -537.52 MWD+lFR-AK-CAZ-SC (3) i 8,626.92 90.15 183.59 3,945.94 3,845.44 443.45 -3,369.22 5;;969,216.94 558,729.51 0.85 -443.45 MFA/D+fFR-AK-CAZ-SC (3) 8,721.25 92.01 186.47 3,944.16 3,843.66 349.52 -3,377.49 5,969,122.95 558,722:.02 3.63 -349.52 MWD+IFR-AK-CAZ-SC (3) 8,815.64 90.46 182.99 3,942.12 3,841.62 255.49 -3,385.27 5;;969,028.87 558,715::02 4.04 -255.49 MfAJD+{FR-AK-CAZ-SC (3) 8,910.27 91.82 180.35 3,940.24 3,839.74 160.93 -3,388.03 5„968,934.30 558,713::04 3.14 -160.93 M1~9lD+IFR-AK-CAZ-SC (3) 9,004.58 90.77 179.28 3,938.11 3,837.61 66.64 -3,387.72 5,„'968,840.03 558,714-.13 1.59 -66.64 MWD+IFR-AK-CAZ-SC (3) 9,098.34 90.77 182.05 3,936.85 3,836.35 -27.09 -3,388.81 5„968,746.30 558,713.81 2.95 27.09 MUOID+IFR-AK-CAZ-SC (3) 9,191.71 90.09 179.23 3,936.15 3,835.65 -120.44 -3,389.85 5,968,652.95 558,713::.54 3.11 120.44 MVIID+IFR-AK-CAZ-SC (3) 9,285.83 92.75 184.28 3,933.81 3,833.31 -214.45 -3,392.73 5,968,558.93 558,711!.:-04 6.06 214.45 M1PWD+IFR-AK-CAZ-SC (3) 9,330.10 89.60 181.37 3,932.91 3,832.41 -258.65 -3,394.91 5968,514.72 558,709,x63 9.69 258.65 M10!/D+tFR-AK-CAZ-SC (3) 9,380.05 89.10 178.55 3,933.47 3,832.97 -308.59 -3,394.88 5„968,464.79 558,710::08 5.73 308.59 MV9iD+IFR-AK-CAZ-SC (3) 9,424.10 90.03 176.48 3,933.81 3,833.31 -352.60 -3,392.97 52968,420.80 558,712.:35 5.15 352.60 MVVrD+kFR-AK-CAZ-SC (3) 9,474.75 90.34 175.41 3,933.64 3,833.14 -403.12 -3,389.38 5,.968,370.32 558,716:.:35 2.20 403.12 MV69D+IFR-AK-CAZ-SC (3) 9,568.76 89.54 177.98 3,933.74 3,833.24 -496.96 -3,383.97 5,968,276.53 558,722:;:55 2.86 496.96 M1AOD+IFR-AK-CAZ-SC (3) 9,661.26 89..97 178.51 3,934.14 3,833.64 -589.42 -3,381.13 5,„968,184.11 558,726..14 0.74 589.42 MVtidD+IFR-AK-CAZ-SC (3) 9,755.95 89.66 178.22 3,934.44 3,833.94 -684.07 -3,378.43 5,968,089.49 558,729~fi3 0.45 684.07 MVmD+IFR-AK-CAZ-SC (3) 9,849.45 89.66 179.51 3,935.00 3,834.50 -777.55 -3,376.58 5,967,996.04 558,732..:25 1.38 777.55 MWD+IFR-AK-CAZ-SC (3) 9,944.08 90.34 180.63 3,935.00 3,834.50 -872.17 -3,37fi.69 5,967,901.43 558,732::92 1.38 872.17 MVV<'°D+IFR-AK-CAZ-SC (3) 10,037.87 91.58 181.93 3,933.43 3,832.93 -965.92 -3,378.79 5,967,807.67 558,731..:60 1.92 965.92 MV19D+IFR-AK-CAZ-SC (3) 10,131.32 92.69 181.19 3,929.94 3,829.44 -1,059.27 -3,381.33 5,967,714.31 558,729:.83 1.43 1,059.27 MWlD+IFR-AK-CAZ-SC (3) 10,223.21 90.15 181.33 3,927.67 3,827.17 -1,151.10 -3,383.35 5,967,622.48 558,728;.:57 2.77 1,151.10 M1MD+IFR-AK-CAZ-SC (3) 10,318.40 89.97 182.35 3,927.57 3,827.07 -1,246.24 -3,386.41 5,J67,527.32 558,726..:30 1.09 1,246.24 MVY'D+IFR-AK-CAZ-SC (3) 10,411.62 88.55 184.01 3,928.77 3,828.27 -1,339.31 -3,391.58 5,967,434.23 558,721..:91 2.34 1,339.31 MV19D+IFR-AK-CAZ-SC (3) 10,506.48 89.35 185.07 3,930.51 3,830.01 -1,433.85 -3,39)9.09 5,967,339.64 558,715.:18 1.40. 1,433-85 MVWD+IFR-AK-CAZ-SC (3) 10,599.30 91.02 185.22 3,930.21 3,829.71 -1,526.29 -3,407.41 5,967,247.14 .558,707.:62 1.81 1,526.29 MW"D+IFR-AK-CAZ-SC (3) i 10,693.58 91.20 185.51 3,928.38 3,827.88 -1,62:0.14 -3,4'R6.22 5,'967,153.23 558,699..159 0.36 1,620.14 MVttD+IFR-AK-CAZ-SC (3) 10,787.32 91.02 182.76 3,926.57 3,826.07 -1,713.61 -3,422.98 5n967,059.71 558,693<:61 2.94 1,713.61 Md~6D+IFR-AK-CAZ-SC (3) j 10,881.61 90.96 180.41 3,924.94 3,824.44 -1,807.85 -3,425.59 5,~J66,965.47 558,691.:78 2.49 1,807.85 MW'D+IFR-AK-CAZ-SC (3) 10,975.43 89.85 182.25 3,924.28 3,823.78 -1,901.63 -3,427.76 5,966,871.68 558,690..:38 2.29 1,901.63 M+IFR-AK-CAZ-SC (3) 11,069.49 90.65 183.41 3,923.87 3,823.37 -1,99.5.57 -3,432.41 5,966,777.71 558,686s 5i 1.50 1,995.57 MW1)+IFR-AK-CAZ-SC (3) 11,163.30 90.22 181.50 3,923.15 3,822.65 -2,089.29 -3,436.43 5,966,683.97 558,683.:27 2.09 2,089.29 MVO+IFR-AK-CAZ-SC (3) 11,255.98 91.58 182.48 3,921.70 3,821.20 -2,181.90 -3,439.64 5,966,591.35 558,680.:82 1.81 2,181.90 MVViD+IFR-AK-CAZ-SC (3) 11,351.11 89.29 183.58 3,920.97 3,820.47 -2,276.89 -3,444.67 5,966,496.33 558,676.:_58 2.67 2,276.89 MW';D+IFR-AK-CAZ-SC (3) ~ 11,445.76 89.72 183.22 3,921.79 3,821.29 -2,371.37 -3,450.28 5,966,401.82 558,671_:75 0.59 2,371..37 MW4J+fFR-AK-CAZ-SC (3) I I 11,539.46 91.14 181.09 3,921.09 3,820.59 -2;464.99 -3,453.81 5,5166,308.18 558,669:.00 2.73 2,464.99 MW~+IFR-AK-CAZ-SG (3) 6/3/2008 2:28:17PM Page 6 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-172 Weltbore: 1C-172A Design: 1C-172A Survey ConocoPhi!lips . Definitive Survey Report Local Co-ordinate Reference: VVe111C-172 TVD Reference: 1C-172A @ 100.50ft (Doyon 15) MD Reference: 1C-172A @ 100.50ft (Doyon 15) North Reference' Tfue Survey Ca6culation Method: Minimum Curvature Database: CPAI EDM Production Map Map` ` Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) {ft} (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,633.31 90.09 180.88 3,920.08 3,819.58 -2,55a.uz -3,455.42 5,966,214.35 558,668.16 1.14 2,558.82 MWD~*IFR-AK-CAZ-SC (3) 11,727.15 i 89.60 183.90 3,920.34 3,819.84 -2,652.57 -3,459.33 5,966,120.58 558,665.03 3.26 2,652.57 MWD+~IFR-AK-CAZ-SC (3) I 11,821.39 92.14 184.99 3,918.90 3,818.40 -2,746.50 -3,466.64 5,9`66,026.60 558,658.50 2.93 2,746.50 MWD+{FR-AK-CAZ-SC (3) j 11,914.67 91.21 183.96 3,916.18 3,815.68 -2,839.46 -3,473.91 5,965,933.59 558,652.00 1.49 2,839.46 MWD+IFR-AK-CAZ-SC (3) I 12,008.01 90.40 182.69 3,914.87 3,814.37 -2,932.63 -3,479.32 5,965,840.39 558,647.36 1.61 2,932.63 MWD+{FR-AK-CAZ-SC (3) j 12,102.50 90.65 180.44 3,914.00 3,813.50 -3,027.07 -3,481.90 5,965,745.94 558,645.56 2.40 3,027.07 MWD+-IFR-AK-CAZ-SC (3) !, 12,195.95 89.11 180.01 3,914.20 3,813.70 -3,120.52 -3,482.27 5,965,652.50 558,645.96 1.71 3,120.52 MWD+IFR-AK-CAZ-SC (3) 12,290.06 89.60 183.05 3,915.26 3,814.76 -3,214.58 -3,484.78 5,965,558.43 558,644.23 3.27 3,214.58 MWD~FR-AK-CAZ-SC (3) 12,383.82 91.27 183.41 3,914.54 3,814.04 -3,308.18 -3,490.07 5,9P65,464.80 558,639.72 1.82 3,308.18 MWD+{FR-AK-CAZ-SC (3) 12,477.56 90.40 182.68 3,913.18 3,812.68 -3,401.78 -3,495.04 5,965,371.17 558,635.52 1.21 3,401.78 MWD+lFR-AK-CAZ-SC (3) 12,570.85 91.27 182.09 3,911.82 3,811.32 -3,494.98 -3,498.93 5,965,277.95 558,632.41 1.13 3,494.98 MWD+iIFR-AK-CAZ-SC (3) 12,665.04 90.71 181.04 3,910.19 3,809.69 -3,589.12 -3,501.50 5,965,183.80 558,630.62 1.26 3,589.12 MWD+-IfR-AK-CAZ-SC (3) 12,758.72 88.06 180.64 3,911.20 3,810.70 -3,682.77 -3,502.87 5,965,090.15 558,630.62 2.86 3,682.77 MWD+#fR-AK-CAZ-SC (3) 12,851.88 89.72 183.45 3,913.00 3,812.50 -3,775.84 -3,506.20 5,964,997.06 558,627.47 3.50 3,775.84 MWD+IER-AK-CAZ-SC (3) 12,945.34 89.41 184.13 3,913.71 3,813.21 -3,869.09 -3,512.37 5,964,903.77 558,622.06 0.80 3,869.09 MWD+[ER-AK-CAZ-SC (3) 13,039.36 89.04 182.65 3,914.98 3,814.48 -3,962.94 -3,517.93 5,9+64,809.89 558,617.281 1.62 3,962.94 MWD+IfR-AK-CAZ-SC (3) 13,062.56 89.91 182.53 3,915.20 3,814.70 -3,986.11 -3,518.98 5,9'54,786.71 558,616.42 3.79 3,986.11 MWD+IFR-AK-CAZ-SC (3) 13,101.00 89.91 182.53 3,915.26 3,814.76 -4,024.52 -3,520.68 5,964,748.30 558,615.04• 0.00 4,024.52 PROJECTED to TD 6/3/2008 2:28:17PM Page 7 OOMPASS 2003.16 Build 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-172A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,452.05' MD Window /Kickoff Survey: 3,513.00' MD (if applicable) Projected Survey: 13,101.00' 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 ,~y / ~ ~ s Date ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment{s) WELL LOG TRANSMITTAL To: State of Alaska June 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1C-172A AK-MW-5476893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23159-01 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: ~~ - - V ~ Signed: ~~ ~p~-p0~ /~L!`"~S t ~, ~,, t !, i' v i~ ~A_ I ff~ e :. ~ dd a I ~_ k { ~~ r '~ p AI.A5SA OIL A11TD GA5 COI~TSER`QATIOI~T COl-Il-II55IOrIT Randy Thomas Drilling Team Leader Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALfN, 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, 1 C-172A Conoco Phillips Alaska, Inc. Permit No: 208-008 Surface Location: 1436' FNL, 1096' FWL, SEC. 12, T11N, R10E, UM Bottomhole Location: 181' FNL, 2423 FEL, SEC. 14, T11 N, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and 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 ,many required test, contact the Commission's petroleum field inspector at (9~l) 6~9-3607 (pager). DATED thisc~ day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 ~~~~~ /~n Email: Randy.L.Thomas@conocophillips.com !f 1.~ January 15, 2008 Alaska Oil & Gas Gans. ~arrlmissan Alaska Oil and Gas Conservation Commission AnChOreAe 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1C-172A, 1C-172AL1 and iC-172AL2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a tri-lateral horizontal well in the West Sak "A2","A3"and "A4" sands. The main bore of the well will be designated 1C-172A, and the lateral bores of the welt will be designated iC-172AL1 and iC-172AL2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1C-172A is March 15, 2008. If you have any questions or require any further information, please contact Steve Shultz at 265-6178. Sincerely, .~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ISSION PERMIT TO DRILL ~l ~- 20 AAC 25.005 ~" RECEIVED JAN 2 3 200$ Alaska Oi! & Gas Cons. Commission 1a. Type of Work: Drill ^ Re-drill ^/ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 • 11. Well Name and Number: 1C-172A ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13169' TVD: 3914' 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: 664' FNL, 2262' FEL, Sec. 11, T11 N, R10E, UM 8. Land Use Permit: ALK 467, 468 13. Approximate Spud Date: 3/15/2008 Total Depth: 181' FNL, 2423' FEL, Sec. 14, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to' ~~~• ~.5 ,*« Nearest Property: ~t~.a 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 i•23•~ Well within Pool: 1 C-102 , 56' 16. Deviated wells: Kickoff depth: 3500 ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1735 psig Surface: 1301 psig ' 18. Casing Program ecifications S Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD 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 4969' 8400' 3944' 13169' ~ 3914' slotted 19 PRESENT WELL CONDITION SUMMARY (To be completed 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 Q 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 ~ ` `-~.--a Phone j~~,(~7~~ Date 'l ~f S l® $ n All D k Commission Use Only Permit to Drill Number: ~'~~- API Number: Permit Appr val 50-~~'~- ~~~'~° ~ ` Date~~ ' ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed thane, gas'hyd ales, or gas contained in shales: ?~~ ~~ ~~~ ~5.~ Samples req'd: Yes ^ No [~ ~ ud log req'd: Yes ^ No [v]~ Other: ` Q,~ \ H2S measures: Yes Qi °No irec onal svy req'd: Yes ['~ No ^ '~~~-l1cx`~~~~ `xJ~~S"''~~~~v~UCC.~~U~~t. ~=h~~~~'rc Et`S~E,~~'~~'~`~D~~~t ~ ~ APPROVED BY THE COMMISSION DATE: ~ `~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 / Submit in Duplicate /•Z3 •~S ~~ A~tion for Permit to Drill, Well 1 C-172A Revision No.O Saved: 23-Jan-08 Permit It -West Sak Well #1 C-172A •~°d r.~ ~i~ .Producer ~~ ~'~1~Wll Application for Permit to Drill Document ~ ~ x ; ~, i will yvlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fJ ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .....................................................•-•--......................................... 2 Requirements of 20 AAC 25.050(b) .....................................•-•-•--•---•--.................................---................ 3 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ...................................................•-•--.......................................... 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) .................................•-•-•--•---•--•--................................................. 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) .....................................................•---.......................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Intermediate Hole Mud Program (LSND) .........................................•--•--................................................ 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 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 ............................................................................................... 6 1C-172A PERMITIT.doc Page 1 of 8 Printed: 23-Jan-08 ORIGINAL A~ion for Permit to Drill, Well 1 C-172A Revision No.O Saved: 23-Jan-O8 Requirements of 20 AAC 25.005 (c)(12) ......................................................................:......................... 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC'2.5.040(b). For a we// with muttipte we// branches, each branch must similarly be identified by a unique name andAPf number by adding a suffix to the name designated for the weU by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-172A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pemait to DriAl must be accompanied by each of the fo/towing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property`s owners and showing (A)the coordinates of the proposed Joeation of the we// at the surface, at the top of each objectr"ve formation, and at Iota/depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey m the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1 436' FNL 1 096' FWL Section 12 T11N R10E ASPZone 4 NAD 27 coordinates RKB Elevation 99.0' AMSL Northings: 5,968,801 ~ Eastings; 562,102 Pad Elevation 59.0' AMSL Location at Top of Productive Interval West Sak "A-2" Sand 664' FNL, 2262' FEL, Section 11, T11N, R10E ASP Zone 4 NAD 27 Coordinates MedSU/"ed De th, RKB: 8,400' Northings: 5,969,544 Eastings: 558,737 Total ~erticalDe th, RKB: 3,944' Total I/ertica/ De th, SS•• 3 845' Location at Total De th 181' FNL, 2423' FEL, Section 14, T11N R10E ASP Zone 4 NAD 27 Coordinates MeaSU/'ed De th, RKB: 13,169' Northings: 5,964,748 Eastings: 558,619 Total l/ertica/ De th, RKB: 3 914' Total 1/ertical De th SS.• 3,815' and (D) other information requr"red by 2D AAC 25. ©SO(b); ORIGINAL 1C-172A PERMIT/T.doc Page 2 of 8 Printed: 23-Jan-08 A~tion for Permit to Drill, Well 1 C-172A Revision No.O Saved: 23=Jan-08 Requirements of 20 AAC 25.050(b) Ifa well is to be mtentianally deviated, the application for a Permit to Oril/ (Form i0-401) must (I) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, inc/uding a/I adjacent we//bores within 200 feet of any portion of the proposed we!!; Please see Attachment 1: Directional Plan 1C-172A and (2) for al/ we//s within 200 feet of the proposed we//bare (A) list the names of the operators of those wells, to the extent that those names are known or drscoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only off ected 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 followmg items, except for an item already on fi/e with the commission and identified in the application; (3) a diagram and description of the blowout prevention equipment (BOPS) as required by ZO A,4C 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" X 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1C-172A. 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. When we initially move on 1C-172A, we will be installing a 7 5/8" casing head below the existing tubinghead. During the pre-rig well work we will be pumping a cement plug to isolate the West Sak formation. A pressure test of the tubing and annulus will be performed after the cement squeeze to verify that the ormation as been plugged off. Therefore, we will have a cement plug in place in addition to a kill weight fluid in the hole prior to the drilling rig moving on the well. S~il~Ec~"Oc'w~vS~~-v~~~t`~sS ~~~ S ~~`~ ,~3 `S- With the cement plug in place and kill weight fluid in th ho e, it is requ~s hit ~ddiiSi~ initial nipple up of the BOPE on Doyon 15, that we perform a lronnet test. Once we have the tubing hanger out of the hole with several joints of the 4 '/z" tubing, we would like to make up a storm packer and run in and set at +/- 90 feet. Then we can ND the BOPE install the spool and nipple back up. Upon that NU a full BOPS test would be performed prior to any. further work. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to ®rill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (9) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 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 1,301 psi, calculated thusly: MPSP = (3,944 ft TVD)(0.44 - 0.11 psi/ft) = 1,301 psi ` 1C-172A PERMIT IT.doc Page 3 of 8 Printed: 23-Jan-08 o~i~in~~ (B) data an potentialgas zones; The well bore is not. expected to penetrate any gas zones. A~tion for Permit to Drill, Well 1C-172A Revision No.O Saved: 23-Jan-08 and (C) data concerning potential causes of hole problems such as abnormal/y geo pressured strata, /osY circa/anon zones, and zones that have a propensity far differential sticking; Please see Attachment 2: 1C-17ZA Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready an file with the commission and identified in the application: (S) a description of the procedure far conducting formation integrity tests, as required under 20 AAC 25, 030(fJ; 1C-172A will be completed with a 7-5/8" intermediate casing landed at the top of the West Sak A-2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Uril! must be accompanied by each of the fallawmg items, except for an item already on frle with the commission and identified in the applicatian.• (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slotted liner, pre- perforated liner, ar screen to be insta/led; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 16" 20~~ 109 K55 Welded 80 40 / 40 121 / 121 , 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 9 7/8" 29.7 L-80 Hydril 513 8317 40 / 40 8,400' / 3,944' u~Nu 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) - _ 3 4" A-3 Sand 12.6 L-80 BTC 5051 8,117'/ 3,910' 13,168' / 3,860' Slott - slotted Lateral - L1 4-1/2 6 3/4"A-4 Sand 12.6 L- 18 7, 64' 3,796' Slotted- no cement slotted Lateral iC- ,~_~, 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready an fle with the commission 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 20 AAC 25.035(h)(2); N/A 1C-172A PERMIT IT.doc Page 4 of 8 O (~"~ ~ ~ ~ A ~ ~ t Printed: 23-Jan-08 d: A~ion for Permit to Drill, Well 1C-172A `~ Revision No.O Saved: 23-Jan-08 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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 identifrecl in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI VersaPro Mineral Oil ° Base) A-2, A-3 and A-4 sand laterals 9 5/8"Csg Window to 7-5/8"Csg Point Value Density (ppg) 9.0 - 9.2 Funnel Viscosity 45 - 60 seconds Plastic Viscostiy 12 - 18 Ib/100 s Yield Point 15-19 cP API Filtrate 4 - 6 cc / 30 min Chlorides (mg/-) <500 pH 9.0 - 9.5 MBT <20.0 Value Densit 8.4 - 8.5 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18.28 cP HTHP Fluid loss (ml/30 min @ <4.0 200 si 8 150° Oil /Water Ratio 70 / 30 Electrical 650 - 900 Stabili Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication far a Permit to Drill must be accompanied by each of the fo/%wmg items, except for an item a/ready on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel% a tabu/ation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC25.033(t); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fo0%wing items, except for an item already on file with the commission and identified in the app/ication: (10) for an exploratory or stratigraphic test wel/, a seismic refraction or reflection analysis as required by ZO AAC25.061(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 application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application; 1C-172A PERMITIT.doc Page 5 of 8 Printed: 23-Jan-08 ORIGINAL i ~~ I ~C~~`' Ap~ion for Permit to Drill, Well 1 C-172A Revision No.0 Saved: 23-Jan-08 (11) for a well drilled from an ot5`shore p/atform, mobi/e bottom-founded structure, jack-up rig, or tJoating drif/ing vess% an ana/ysis ofseabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to L?ri/I must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (ZZ} evidence showing that the requirements of20 AAA' 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 app/ication for a Permit to Dril/ must be accompanied by each of the following 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. Please refer also to Attachment 4, Well Schematic. 1. Move in /rig up Doyon Rig 15. Circulate the well clean and ensure the well is dead (production zone has been previously P&A'd), ND tree and NU BOPE and perform bonnet test, Notify AOGCC 24 hrs before test. Pull several stands of 4 ~/z" production tubing and stand back in derrick. 2. PU and run a storm packer to 90 feet and set, ND tubinghead, install 13 5/8" X 5000 psi casinghead for landing the 7 5/8" casing. 3. Install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi), Pull storm packer and 4 ~/2" tubing and stand back in derrick. (Notify AOGCC 24 hrs before test BOPE) 4. MU permenant 9 5/8" BP, RIH to +/-3500' while picking up 5"drill pipe and set same, POOH 5. MU whipstock assembly, RIH to 3500' MD/2435' TVD, set whipstock, shear off mill and mill window. 6. POOH, MU 8 ~/z" X 9 7/8" bi-center bit with 6 3/a"directional assembly, RIH, drill 20' of new hole, perform LOT 7. Directionally drill to 7-5/8" casing point at 8,400' MD / 3,944' TVD which is the prognosed top of the A-2 ~ sand. ~~~~"~ 8. Run 7 5/8", 27.9# L80 Hydril 513 casing to surface and cement in place, displace with OBM. 9. Flush 9-5/8" x 7-5/8"annulus with water, followed by diesel. 10. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 11. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak ofF, recording results. 12. Directionally drill 6 3/4" hole to TD at +/- 13,169' MD / 3,914' TVD as per directional plan. 13. Back reaming out of lateral to 7-5/8"shoe. TIH to bottom & displace to solids-free oil based mud. Pull out of Hole.. 14. PU and run 4-1/2" slotted liner. 15. Land liner, set liner hanger @ +/- 8,156' MD / 3,9o5'ND. POOH. Note: Remaining operations are covered under the 1C-172A-L1 Application for Permit to Drill, and are provided here for information only. ORIGINAL 1C-172A PERMITIT.doc Page 6 of 8 Printed: 23-Jan-08 C~ Aion for Permit to Drill, Well 1C-172A Revision No.O Saved: 23-Jan-08 16. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 8,117' MD / 3,910' TVD, the top of the A-3 sand. 17. Mill 6 3/4" window. POOH. 18. Pick up 6 3/4"drilling assembly with LWD, MWD, PWD and conventional motor. RIH. 19. Drill to TD of A-3 sand lateral at +/- 13,168' MD / 3,860' TVD, as per directional plan. 20. Back ream out of lateral to window.. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 21. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 22. PU and run 4-1/2" slotted liner. 23. RIH and hang off liner hanger. 24. 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. 25. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 7,646' MD / 3,852' TVD, the top of the A-4 sand. 26. Mill 6 3/4" window. POOH. 27. Pickup 6 3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 28. Drill to TD of A-4 sand lateral at +/- 13,164' MD / 3,796' TVD, as per directional plan. 29. Back ream out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 30. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 31. PU and run 4-1/2" slotted liner. 32. RIH and hang off liner hanger. 33. Release hanger running tool. Pull out of hole laying down drillpipe as required. 34. PU ]et pump completion with gas lift back up as required and RIH to depth. Land tubing. Set BPV 35. Nipple down BOPE, nipple up tree and testa Pull BPV. 36. Freeze protect well with diesel by pumping into 7 5/8" X 9-5/8"annulus, taking returns from tubing and allowing to equalize. 37. Set BPV and move rig off. 38. Rig up wire line unit. Pull BPV. 39. Set gas lift valves in mandrels. Use jet pump to clean up well. 40. 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 Drit/ must be accompanied by each of the fo/lowing items, except for an item a/ready orr ~!e with the commission and identified in the application: (I4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.lJ80 for an annular disposal operation in the well.; 1C-172A PERMIT IT.doc Page 7 of 8 Printed: 23-Jan-08 ~~~r~~~ ~ A~tion for Permit to Drill, Well 1C-172A Revision No.O Saved: 23-Jan-08 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. 15. Attachments Aftachment 1 Directional Plan Aftachment 2 Drilling Hazards Summary Aftachment 3 CemCADE Summary Attachment 4 Well Schematic 1C-172A PERMIT ITdoc Page 8 of 8 Printed: 23-Jan-08 oRieinr,~ Operafor; C:onocoPhillips (Alaska;}.Inc.-Kupl Surface I_,oc;ation: 5968$01.43 N 562101,96 E Well: IC-172A(wp08) Grid Coordinate-System: NorthAnlericanDatum1927 E"'~~~L~BURT~N Field: Kuparuk River Unit Grid Convergence: Alaska. Zone 4 Rig: Doyon 141 Vertical Section Plane: 180.00° RKB Height: 99.1 ft Sp®rry ®riling Services Date: 18-Tan-08 Unwrapped Displacement: 11371.88 DDI: 7.031 S~~' MD Inc Azim. SSTVD TVD ~/-S E/-lZ' X Y DLS V.S. Comments # (ft) (Deg} (Deg) (ff) (ft) (ff) ('ft) (ft) (ft) °/106ft (ft) 1 40.00 0.00 0.00 -59.10 ~ 40.00 0.00 N 0.00E ~ 562101.96E •59688(11.43 ~1 0.00 . 0,00 2 156.90 0.16 315.00 57.80 156.90 0.12 N -0.12 ~~ 562101.84E 5968801.54 N 0.14 -0.12 CB-GYRO-SS (1) 3 277.90 1.25 26,(i0 178.79 277.89 1.42 N 0.34E 562102.29E 5968802:85 N lA0 -1.42 4 401.89 2.39 36.29 302.72 401:82 4.72 N 2.47 E 562104.39E 5968806.17 N 0.95 -4.72 MWD+IFR-AK-CA~SC (2) 5 490.85 2.61 30.94 391.59 490.69 7.95 N 4.C,1 E 562106.50E 59(8809.42 N 0.36 -795 6 5&1.40 4.26 27.22 481.98 581.08 12,71 N ~ 7.20E 562109.06E 5968814.20 N L84 -12.71 7 <71.23 5.90 . 24.61 571.45 670.55 19.88 N 10.65E 562112.45 E 596882139N 1.84 -19.88 8 762.35 8.53 18.02 661.84 760.94 30.56 N 14.7{} E 562116.40 E 5968832.11 N 3.02 -30.56 9 852.31 11.70 . 14.7b 750.39 849.49 45.73 N 19:08 E 562120.66E 5968847.31 N 3.58 -45.73 Q 10 942,77 12.70 10.82 838.81 937.91 64.37 N 2329E 562124.71E 5968865.98 N 1.44 -6437 11 .1032.38 15.64 1.05 925.70 1024.80 86.13 N 25.36E 562126.61E 5968887.75 N 4.22 -86.13 ,,,,,,,,,.. 12 1127.13 19.91 35(.2.5 1015.92 L115.g2 114.86 N 23.14E 562124.15E 5968916.47 N 5.49 -114.86 13 1221.35 21.43 346.42 1104.08 1203.18 147.4b N 16.65 E 562117.40E 5968949.00 N 2.42 -147.46 14 L313.R6 21.18 341.57 1190.28 1289.38 179.74 N ?.46 E 562107.88E 596898i.Z0 N 1.92 -179.74 15 140599 26.12 . 338.05 1274.65 1373.75 214.36 N -5.45 b1 562094.75 E 5969015.72 N 5.57 -214:36 16 1501.27 33.63 335.74 1357.21 14.56,31. 257,94 N -24:1E ~~ 562075.69E 5969059..13 N 7.97 -25794 17 1593.06 35.67 335,01 1432.72 .1531.82 305.37 N -45.91 V. 562053.55E 5969106.35 N 2.27 -305.37 18 .`1685.73 40,07 334.38 1505.85 1604.95 356.78 N -70.23 « 562028.81 E 5969157.58 N 4.77 -356.78 19 1778.89 44.74 33].67 1574.63 1673.73 412,71 N -98.78 W 561999.81E 59692.13:27 N 5.38 -412.71 20 1872.29 50.50 330.33 1637.56 173f.,:(6 473.01 N -132.24 ~ 561965.85E 596927328 N 6.26 -473.(11. 21 1964.53 53.61 328.47 1694.27 1793.37 535.60 N -169.28 ~~ 561928.30E 59E~9335.55 N 3.73 -535.6(1 22 2056.98 56.75 326.71 1747.06 1846.T6 599.65 N -209.9:7 ~ 561887.09 E 5969399.26 N 3.74 -599.65 23 2249.97 66.46 324.51 1791.23 189(1.33 667.02 N -256.13 561840.34E 5969466.25 N 10.65 -667.02 24 2242,58 67.44 325.15 1827.49 192b.59 736.68 N -305.26 561790.70E 5969535.49 N 1.23 -736.68 25 2335.66 66,78 325.57 1863.70 1962.80 807.23 N -354.OO ~~, 561741.38E 5969605.63 N 0.82 -507.23 26 '428.22 66,75 326.52 1900.21 1999.31 877.78 N -401:51 ~~ 561693.30E 5960675."78 N 0.94 -877.78 27 2521.11 64.45 324.33 1938.59 2037:65 947.43 N -449.4 W 561644.75E 5969745.03 N 3.28 -947.43 28 2615.10 63.51 3"'3 ~~~1 1979.82 . ?0"'~~.~h 1015.88 N -498.98 Vd 561594.72E 5969813.06 N 1.07 -1015.$8 29 2707.10 62.50 3 , ~ 1 > 2021.58 21 t ~ ~. 5 _~ 1082.24 N -547.11 W 561546.04E 5969879.01 N 1.12 -1082.2.4 30 '-~!~+~ 3 64.21 3-3.38 2063.59 162,h9 1149.77 N -596.60 Vv 561496.00 E 5969946.13 N 1.97 -1149.77 31 _'~~+,.`~3 67.26 33._49 2101.45 2200.55 1217.19 N -646.70 561445.36E .5970013.13 N 3.31 -121''.1`i 32 ~~?,ti~ ~4 68.00 3"24.42 2136.70 2235.80 1286.39 N -697.15 « 561394.34E 597(1081.90 N 1.30 -1286.3~~ 33 3U;s.47 66.03 3?'~ hO 2173.00 2272.10 1354.27 N -749.19 561341.76E 5970149.34 N 4.34 -1,5x._7 34 31'71.14 66.09 =~' 1.6.5 2210.62 .2309.72 1420.23 N =80237L4 561288.04E 5970214.86. N 1.04 -142023 35 3264.02 65.93 322.72 2248.37 2347.47 1487.24 N -854.37 ~ 561235.50E 5970281.43 N 1.07 -148".~~ 36 3357,30 66.16 323.91 2286.24 2385.34 1555.60 N -905.30 W 561184.02 E 5970349.36 N 1.19 -1555.60 37 3450.65 66.32 .323.79 2323.85 242295 1624.59 N -955.70 W 561133.06E 5970417.92 I*1 0.21 -162-4.59 Page 1 of 5 S~'~' ~1D Inc r~~inx. SSTLD Tl'D '~!-S E~/-~~~ Y I DLS V.S. Comments # (ftj (Deg) (Deg) (fr) (ftj (ft) (ft) (fr) (ft) °/1UOft (fr) Tie-On 3504.00 6690 321.58 2343.44 .?442.54 1660.61 N -9$3.16 56110531E 597Q453:7 l N 4.27 -1660.61 Tie-on Depth L 3500' MD 2443' `I'VD; 225' FSL, 11 /~ - 2 3504.26 6690 321.58 2343.52 2442.62 1660.75 N -983.27 w 561105.19 )r 5970453.86 N 0.00 -1660,75 9 518" TOW - MWD+IFR-AK-CAZ-SC (3) 3 3600.00 66.90 322.58 2382.68 2481.78 1733.17 N -1039.68 W 561048.20E 5974525.80 N 0.92 -1733.17 4 3650.b(1 66.90 323.08 2402.29 .2501,,9 1769.82 N -1067.47 W 56102011E 5970562.22N 0.92 -1769.82 5 3700.00 66.90 323.08 2421.91 2521.01 1806.59 N -1095.09 ~~,~ 560992:19 E 5970598.75 N 0.00 -1846.59 6 3800.00 66.90 323.08 246L14 ?560:24 1880.13 N -1 150.35 ~'~~ 560936.34E 5970671.83 N OAO -1880.13 7 3900.00 6690 323.08 2500.37 2599.47 1953.67 N -1205.60 ~'v 560880.49E 59707=1490 N 0.00 -1953.67 8 4000.00 66.90 323.08 2539.61 2638:71 2027.21 N -1264.85~~ 560824.64E 5970817.98 N OAO -2027.21 9 4100,00 6690 323.08 2578.84 2677.94 2100.74 N -1316,10W 560768.79E 597089L05 N 0.00 -2100.74 10 4200:00 66.90 323,08 2618.07 2717.17 2174.28 N -1371,361 560712.95 E 5970964.1.3 N OAO -2174.28 11 4300.00 6690 323.08 2657.30 2756;40 2247.82 N -1426,61 1 560657.10E 5971037.20 N OAO -2247.82 12 4400.40 6690 323.08 2696.53 2795.63 2321.36 N -1481.$6 W 560601.25E 5971170.28 N 0.00 -2321.36 13 4500.00 6690 323.08 2735.77 2834.87 239490 N -1537.11 W 560545.40E 5971183:35 N OAO -239490 14 4600.00 66.90 323:08 2775.00 2874.10 2468.44 N -1592.36 ~& 560489.55E 5971256.43 N 0.00 -246;3.44 15 4700.00 66.90 323.023 2814.23 2913.33 2541.98 N -1647.62 W 560433.70E 5971329.50 N 0.00 -2541.98 16 4720.00 66.90 323.08 2822A8 2921.18 2556,69 N -1658.67 W 560422.53 E 597134=412 N 0.00 -2556.69 17 4800.00 66.98 318.28 2853.41 2952.51 2613.62 N -1705.29 W 560375.45E 5971400.65 N 5.52 -2613.G2 18 4900.00 67.08 31'.28 2892.44 2991.54 2679.01 N -1770,05 W 560310.16 B 5971465.50 N 5.52 -~C>79.01 ~^°~~----~~ /ti-~ 19 5000.00 67.18 306.28 2931.30 3030.46 2737.32 N -184:1.34 u' 560238.41E 5971523.22 N 5,53 -`'737.32 ^ 20 5100,00 67.28 300.28 297UA0 3069.10 2787.89 N -1918.39 W 560160.95E Sy71573.i(, N 5.53 -2787.89 ~- ~ U ! 21 5200.00 67.38 294.28 3008.54 3107.€4 2830.17 N -2000.36 a 560078.64E 5971614.75 N 5.54 -2830.17 "" - "~ 22 5300.00 67.48 288.28 3046.92 314h.42 2863.67 N -208b.3(i ~ 559992.38E 5971647.54 N 5.54 2863.67 23 ~40t1.00 67.58 282.28 3085.14 3.184.24 2888.01 N -2175.46 Vv 559903.09E 5y7167L15 N 5.55 -2.8$8.01 ~, 24 5=156.32 67.69 277.10 3118.00 3217.10 2901.44 N -2254.12 W 559824,34E 5971(8393 N 5.55 -2901.44 UgnuC 25 5500 00 68 67 276 28 3123.20 3222.311 2902.92 N 2266.69 R~ 559811.76E 597168531 N 5.56 -''9029"? 26 . 560000 . 67.78 . 270.28 3161.09 3260.1) 2908.21 N -3359.04 ~ 55971938E 5971689.84 N 5.55 -2908.21 27 .5700.00 67.88 264.28 3198.83 323793 2903.82 N -2451.50 W 559626.97E 5971684.69 N 5.56 -2903.82 28 5800.00 67.98 258?8 3236.40 .3335.50 2889.78 N -2543.06W 559535.54E 5971669.91) N 5.56 -28$9.78 29 Sy04.00 68.08 252.28 3273.81 3372.9] 2866.23 N -2632:711 559446.09E 5971645.62 N 5.56 -2866.23 30 6640.04 68.18 246.28 3311.06 341016 2833.41 N -2719,47 W 559359.61E 5971612.09 N 5.57 -2833.41 31 6100.00 68.28 240.28 3348.14 3447?4 2791.68 N -280239 559277.05E 5y71569.68 N 5.57 -2791.68 32 6183.5 6839 235.27 3379.00 3478:10 275030 N -2868.031 559211.76E 597252,7:77 N 5.58 -2750.30 UgnuB 33 6200.41) 6838 234.28 3385.(17 3484.17 2741.47 N -2$80.54 \ 55919932E 5921518,84 N 5.58 -274L47 34 6295.01 68.51 ~ 5.;~ 3420AU 351910 2686.40 N -2949.59 559130.73E 59?1463.32 N 5.58 -2686.40 UgnuA 35 6300.00 68.48 2 ~ _ 3421.83 352093 268332 N -295;.07 ~ 559127.28E 5971460.11 N 5.63 -X68332 36 6404.00 68.58 222.2` 3458.43 3557.53 2617.87 N -3019.16 559061.73E 5971394.13 N 5.58 -2617.87 37 6500.40 68.68 21(;.28 3494.87 3593.97 2545.82 N -3078.09 ,t1 559003.40E 5971321.60 N 5.59 -2~4~.r,~ 38 6600.00 68.78 .210.28 3531.14 3634.24 2467.95 N -3129.21V~ 558952.94E .5971243.33 N 5.59 -2467.95 39 6648:02 68.87 . 205:46 3562.94 3662.04 2395.27 N -37.67.27 558915.47 E 5)71170.34 N 5.60 -2395.27 40 6699.42 69.36 205.31 3567.00 366610 2385.63 N -3171,80 W 558911.03E 597ll60.67 N 5.00 -2385.6.3 K 13 41 6700.06 6938 20533 3567.20 3666.30 2385.14 N -3172.03 ~ 558910.80E 5971160/7 N 5.00 -2385.14 lr 1 u Page2of5 '1..~.J -~~ ~;.;~ SV~' ~>~LD Inc Azinl. SSTVD TVD ~I-S E/-ti'R' ~ 1 DLS V.S. Continents # (ft) (Deg) (Deg) (ft) (ft) (f't) (ft) (f't) (ft) °/100ff (ft) 42 6760.57 72.00 206,94 3587.23 3686.3 3 2333.83 N -3197.21 Vv 558886.05 E 5971108.66 N 5.00 ' -2333.H3 43 6788.26 72.00 206.94 3595.78 3694.88 2310.35 N -32f>914 W 558874.31E 5971085/0 N 0.00 -231035 44 6800:00 72.21 20636 3599.39 3698.49 2300.36 N -3214.15 a 55886938E 5971075.07 N SAO -2300.36 45 6900.00 74.08 201.52 362839 3727.49 2212.92 N -325296 ~ 55883130E 597098732 N 5.00 -2213.92 46 699930 76.0.5 196,80 3654AO 3753.10 212231 N -3284,41 ~ 558800.59E 5970896.46 N 5.00 -2122.31 W SakD 47 7000.00 76.06 196.76 3654.17 3753:27 2121.66 N -3284,61 \ 558800.40E 5970895.81N 5.00 -2721.66 48 708790 77.87 192.65 3674.00 3773.10. 2038.86 N -3.306.34 W 55877936E 5970812.84 N 5.00 -3038.8(, W Sa1cC 49 T100.0U 78.13 192.09 3676.52 3775.62 2027.29 N -33(15.87 ~~ 55877692E 5970801.26 N 5,00 -2027.29 50 7175.41 79.73 188.62 3691.00 3790. [ 0 1954.51 N -3322. l6 W 558764.23E 5970728.38 N 5.00 -1.954.51 W Sak B 51 7200.00 80.27 187.49 3695.27 3794,37 1930.53 N -3325.56 ~ 558761.03 E 59711704.37 N 5.00 -1930.53 52 7300.00 82.47 18295 3710.29 3809.39 1832.10 N -3334.54 W 558752.86E 5970605.89 N 5.00 -1832.10 53 7321.09 82,94 182.00 3712.96 3812A6 1811.20 N -3335.44 ~b 558752,13 E 5970584:98 N S.OU -i81T.20 54 7400.00 82.94 782,00 3722.66 3821.76 1732.94N -3338.78 W 558750.04E 5970506.71 N 0,(10 -1732.94 55 7467.84 82.94 182.00 3731.00 3830.10 1665.66 N -3340S3Vv 558748.24 E 5970439.42 N 0,00 -16(5.66 W Saka4 56 7471.09 82,94 182.00 3731.40 . 3830.50 1662.43 N -3340,64 ~ 558748.15E 5970436.t9N 0.00 -16(,2.43 57 7474.71 82.94 181.99 3731.84 3830.94 1658.84 N -3.140,76 ~~ 558748.06 E 597043261 N 0.25 -1658.84 1~-172A MB_A4 Heel (12-19-07) 58 7482.30 82,94 181.97 3732.78 3831.88 1651.31 N -3341.b3 ~ 558747.86E 5.970425.07 N 0.25 -165131 1C-172A MB_A3 Heel (12-19-07) 59 7488,60 8294 181.96 3733.55 3832.65 1645A7 N -3341.24 ~~ 558747.70E 5970418.83 N 0.25 -1645.07 1C-172A MB_A2 Heel (12-19-07) 60 7500.00 82.94 181.93 3734.95 3834.05 1633.76 N -3341.62 W 558747.41E 5970407.52 N 0,25 -1633.7< 61 76.00.00 82.94 181.67 3747.24 384634 1534.56 N -3344.74 558745.11E 597(1308.31 N 0.25 -1534.56 62 7700.00 82.94 181.41. 3759.53 3858.63 1435.36 N -3347.41 W 558743.25E 597020910 N 0.25 -1435.36 63 7800.00 82.94 18116 3771.82 387092 1336.14 N -3349:64 558741.84E 5970109.88 N 0.25 -1336.14 64 7801.49 82,94 151:15 3772.00 .3871.10 1334.66 N -3349.67 « 558741.82E 5970108.40 N 0.25 -1334.66 W Sakai 65 7900.01) 82.94 180.90 3784.10 3883.20 1236.91 N -3351.42 W 558740.87E 5970010.65 N 0.25 -1236.91 66 8000.00 82,95 ] 80.65 3796.38 3895.48 1137.68 N -3352.76 W 558740.34E 596991 L43 N 0.25 -7.137.68 67 805237 82.95 . 180.51 3802.81 3901.91 1085.71 N -3353.29 1u 558740.24E 596959:46 N 0.25 -1085.71 68 8100.00 82.95 180.51 3808.66 3907,7h 1038.44 N -3353.71 ~~ 558740.21E 5969812,19 N 0.00 -1038,44 69 8113.46 82.95 1.80.51 381031 3909.41 1025.09 N -3353:83 by 558740.20E 5969793.84 N OAO -1025.09 1C-172A MB_A4 Tl (12-19-07) 70 8121.03 82.95 180,51 3811.24 39.1034 1017.58 N -3353.90 ~~ 558740.19E 5969791.33 N 0.00 -1017.55 1C-172A MB_A3 Tl (12-19-07) 71 8124.97 82.95 1.81).51 3811.73 3910.83 1013.66 N -3353.93 W 558740.19 E 5969787.41 Zvi 0.00 -1013.66 1C-172A MB_A2 Tl (12-19-07) 72 8178,52 82.95 .180,51 381830 3917.40 960.52 N -3354.41 W 558740.15 E 5969734.28 N 0.00 -960.52 1C-172A (wp07) AZ Landing 73 5195,36 83.06 181.35 382035 3y19.45 943.80 N -335.65 9 558740,02 E 5969717.56 N SAO -943:80 74 8200.00 83.06 181,35 3820.91 3920.01 939.20 N -3354.79\~ 558739.95E 596971296 N 0.00 -939.20 75 83f~~ n0 83.06 1 ~l 35 3833.00 393210 839.96 N -3357.14_~w 558738.41E 5969613.72 N 0.00 -83996 76 ~83(it.,6 83.06 1s! 35 3834.00 3933.10 831.77 N -3357.33 W 558738.29E 5969605.52 N 0.00 -831.77 W Sak a2 77 8367.68 83.06 181.35 3841.18 39x0:28 772.80 N -3358.73 ~~ 558737.38E 596954(,.55 N 0.00 " -772,80 78 8400.60 84.67 181.30 3844.64 .3943,74 740.67 N -3359.47 W 558736.90E 5969514.42 N SAO -740.67 7 5/8" Casing @ 8400' MD, 3944' TVD; 696' FNL, 2 79 8404.00 84.87 181.29 3845.00 3944.10 736.69 N -3359.56 « 558736.84E 5969510.44 N SAO -736.69 7 5/8" 80 8486.40 88.99 181.16 3849.41 3948.51 654.44 N -??6132 ~ 558735.75E 5969428.19N S.UO -654.44 81 8500,00 88.99 18116 3849.65 3948.75 640.85 N -.~.~~~1.60W 558735.59E 5969414.60 N 0.00 -Ei40.85 82 8600,00 88.99 181.16 3851.41 3950.51 540.89 N -3363.62~~ 55873439E 5969314.b3 N 0.00 . -540.89 83 5700.00 88.99 t81.16 3853.18 3952.28 44092 N -3365.65 ~ 558733.19E 5969214.67 N U.OO -440.92 Page 3 of 5 r..~.~ fi~'~~ 17D. 1IlC :7171). SSTi'D TL'D ~~-S ~~'~~' ~ 1~ D)_.S. ~'.~. ~~OI11IIieI1fS # (ft} (Deg) (Deg) (ft) tf't} (ft) (ft) (1't) (ft) °/1001't (ft} 84 8785.87 88.99 18].]6 3854.69 3953.79 355.08 N -336739 558732.15 ~ 5909128,83 N OAO -3x5.08 1C-172AA2 Landing(vmp06) 85 8786.40 88.99 181.16 3854.70 3953.8(1 354.55 N -33('7.40 Vv 558732,15E 596912830 N O.OU -354.55 1C-172A MB_A2 T2 (12-19-07) 86 8800:00 89.26 181.21 3854.91 3954.01 340.96 N -3307.68 a 558731.98E 59(,9114.70 N 2.00 -34096 87 8900.00 91.22 181.01 3854.49 3953.59 240.99 N -337014 ~w 55873034E 5969014.73 N 2.00 -240.99 88 8952.64 92.25 181.83 385290 3952.00 188.40 N -3371.71 W 558729.20E 5968962.13 N 2A0 -188.40 89 9000.00 92.25 181.82 3851.04 3950.14 141.10 N -3373.21 ~ 558728.09E 59b8914.83 N 0.00 -141.10 90 9100.00 92.25 .181.82 3847.12 3946.22 41.23 N -337638 w 558725.74 E 5968814.95 N 0.00 -41.23 91 9200:fH) 92.25 151.82 3843.19 3942.29 -58.64 S -3379.54 ~~ 558723.40E Sy08715.07 N OAO 58.64 92 9300.00 92.25 181.82 3839.27 3938:37 -158.52 S -3382.7[ VJ 558721.05E 5968615.18 N 0.00 158..52 93 9400.00 92,25 (81.82 383534 5934.44 -25839 ~ -3385.88 W 558718,71E 596851530 N O.OU 258.39 94 9424.01 92.25 18L82 3834.40 393-3,50 -28237 S -3386.64 ~ 558718.14E 59684913 t N 0.00 '282.;7 1C-172A MB_A2 `T3 (12-19-07) 95 9500.00 89.97 181.89 3832.93 3932:03 -35830 S -3389.09 W 558716.31E 5908415.58 N 3.00 358.30 96 :9527.34 89.15 181.91 3833.14 393224 -385.63 ~ -3391).00 W 558715.63E 5968388.05 N 3.00 585.(,3 97 961)0.00 89.15 18L91 3834.21 3933.31 -458.23 S -3392.42 ~ 558713.81E 5903315.43 N OAO ' 458.2'3 98 9700.00 89.15 18191 3835.70 3934:80 -558.17 S -3395.70 ~ 558711.29E 5968215.45 N 0.00 .55817 99 9800.00 89.15 181.91 3837.18 3936.28 -658.10 S -3399.09 ~ 558708.78E 59681 15.54 N O.UO 658.10 100 9900.00 89.15 181.91 3838.66 3937:76 -758.03 S -34b2.43 Vv 558706.26E 5968015.59 N 0,00 758.03 101 10(100.00 89.15 18191 3840.14 . 3939.24 -857.97 S -3405.76hv 558703.75E 5967915.65 N 0.00 857.97 102 [002433 89.15 1.81.91 3840.50 3939.60 -882.29 S -3406.57~~~ 558703.14 E 590789133 N 0.00 882.29 1G172A MB_A2 ~"4 (12-19-07) 103 10100.37 90.67 (32.00 3840.62 .3939.72 -958.27 S -3409.17 558'70L17 E 5967815.33 N 2.00 958.27 104 10200.00 90.67 182.00 3839.46 3938.56 -1057.84 S -3412.65 ~ 558698.50E 5907715,75 N 0.00 1057.84 105 10300.00 90,67 182.00 3838.29 3037.39 -1157.77 S -3416..15 558695.83 E Sy07615.81 N 0.00 1157.77 106 10400.01) 90.67 182.00 3837.12 3936.22 -1257.70 S -3419.64 Vv 558693.16E 5967515.86 ICI 0.00 1257.70 107 1f)SOO.OD 90.67 182.00 3835.95 3935.05 -1357.63 S -342314 by 558690.48E 590711592 N OAO 1357:03 108 10600.00 90.67 182.00 3834.79 3933.89 -1457.57 S -3426.63 W 558687.81E 5967315.97 N 0.00 1457.57 109 111700.00 90.67 182.00 3833.62 3932.72 -1557.50 S -3430.13 W 5586$5.14 E 5967216.(.12 N 0.00 .1557.50 110 10800:00 90.67 182.00 3832.45 3931.55 -1657.43 S -5433.62 ~~ 558682.46E 596711(.08 N 0.00 1(,57.43 111 10900,00 90.67 182.00 3831.28 393038 -175736 S -3437J21w 558679.79E 5967010.13 N 0.00 1757:36 112 11000:Q0 90.67 183.00 3830.12 392922 -1857.29 8 -3449.61 ~ 558677.12E 590h916.19 N O.UO 1857.29 113 11100.00 90.67 182,00 3828.95 3028,(15 -1957.23 S -344411 Vti 558674.44E 596081(.24 N 0.00 1957.23 114 11200.00 90.67 182.00 3827.78 3920.88 -2057.16 S -3447.60 ~ 558671.77E 596(716.30 N OAO .2057.10 115 11223.96 90,67 182.00 3827.50 3926.60 -2081.10 S -3448.44 Vv 558671.13E 596669236 N 0.00 20$1.10 1C-172A MB_A2 T5 (12-19-07) 116 11270.71 90.21 13210 3827.14 393624 -2127.82 S -3:150.11 ~ 558669.84E 5966645,63 N 1.00 2127.82 117 11300.00 90.21 t.~~10 3827.03 ~~~26.13 -2157.09 S -3451.18 V~ 558669.01 E 59C>661635 N 0.00 .215"` t~~ 118 ll400.00 90.21 is2.10 3826.66 3':25.76 -2257A2 S -3454.84ti~ 558666.17 B 5966516.40 N OAO 235- ~~_ 119 11500:00 90.21 182.10 382630 3925,40 -2356.95 S -3458.~Ow 558663.33E 5966416.46 N 0.00 235r~.~>~ 120 11fiU0.00 90.21 182.10 3825.93 3925.03 -2456.89 S -3462.17 W 558660.49 B 5966316.51 Iv 0.00 245~~.~~~~~ 121 11700.00 90.21 182:10 3825.56 3924.66 -2556.82 S -3465.E ~ w 558657.65 E 59E~6216.56 N 0.00 255n.~_' 122 1x.800.00 90.21 182.Iti 3825.19 3934:29 -2656.75 S -3469.-~Jw 558654.81E 591>61i6.62N 0.00 ?(x5~,.~> 123 11824 26 90.21 182..10 3825.10 3924.20 -2680.99 S -3470.37 ~ 558654.12E 596E~09237 N 0.00 2680.99 1G172A MB_A2 T6 (12-19-07) 124 11852.12 90.45 18196 3824.94 392=1.04 -2708.83 S -347:1. ~~~ W 55865337E 596Ei064S3 N 1.00 2708.83 125 11900.00 90.45 181.06 3824.56 3923.66 -2756.69 S -?x ~.~~~~ ~ 558652.12E 5966016.67 N 0.00 2756.69 Page 4 of 5 ~..... ~--+ t S~'1~' # l~L~ (1t) Inc (Deg) ALini. ('Deg) SSTVD (ft) T6B Eft) ~N~/-S (ft) EI-\~~~ (ft) ~ ('ft) I' (ft) DLS °/1UOft 4.5. (ft) Conunents 126 127 128 12000.00 12100.00 12200.00 90.45 90.45 90.45 18196 181.96 189.96 3823.77 3822,97 3822.18 3922.87 3922,07 3921.28 -2856.63 S -2956.56 S -3056.50 S -3x76.42 w -3479.85 ~w -3483.27 ~'~~ 558649.52E 558646.92E 558644.32 E 5965916.72 N 5965816.76 N 5965716.81 N 0.00 0.00 0.00 2856.63 2.956.56 3056.50 129 130 131 12300.00 12400,00 12500.00 90.45 90.45 90.45 18196 181,96 1.8L96 3821.39 3820.60 3819.80 3920.49 3919.70 391890 -3156.44 S -3256.38 S -3356.32 S -3486.69 «~ -3490;11 « -3493.54 ~~ 558641.72E 558639.12E 558636.51 E 5965616.86 N 5965516.91 N 5965416.96 N 0.00 0.00 0.00 3156.44 . 3256.38 33632 132 133 134 12600.00 12700.00 12800.00 90.45 90.45 90.45 18196 14L96 181.96 3819.01 381822 3817.42 391$.11 39.1732 3916.52 -345626 S -3556.19 S -3656.13 S -349h.96 w -3500.;8 ~& -3503.81 W 558633.91E 558631.31E 558628.71E 5965317.01 N 5965217.06 N 5965117.11 N O.UO 0.00 0.00 3456.26 3556.19 3656.13 135 136 137 12900.00 13000.00 13100.00 90.45 90.45 90.45 18196 ' 183,06 18196 3816.63 3815.84 3815.05 3915.7, 3914.94 391x.15 -3756.07 S -3856.01 S -3955.95 S ~ 3507.23 1~ -3510.65 by -3514.07 ~ 558626,11E 558623.51 E 55862091E 5965017:16 N 59649]7.21 N 5964817.25 N 0.00 OAO 0.00 :1756.07 3856.01 395595 138 ~ 131t~8.88 90.45 18 L96 3814.50 ~ 3913.fi0 -4024.78 S -3516.43 W ~ 558619.11 E 5964748.41 N 0.00 4024.78 4 1!2" Liner @ 13169' MD, 3914' `TVD; 181' FNL, 2 • C Page 5 of 5 Vertical Section Plot Section Distance 0 r~ !I Plan View Plot F 5972000 - __ - - ---- - --- __ _.-_ --.-- - ------- 5973000 -- 5971000 5970000 5969000 Z 5968000 r~ 5967000 5966000 5965000 ~n ~< 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 •I •I ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1 C-172 Plan: 1C-172A 1 C-172A (wp07) ~~.~. _; Anticollision Report 17 January, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1C Pad - 1C-17Z - Plan: 1C-172A - 1C-172A (wp07) Well Coordinates: 5,968,553.19 N, 1,702,133.88E (70° 19' 30.01" N, 149° 29' 58.29" W) Datum Height: 1C-172: @ 87.20ft (1C-172:) Scan Range: 3,500.00 to 8,500.00 ft. Measured Depth. Scan Radius is 1,130.63 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Interval: 25.00 __.;. ~ , ,~. ,,. ~., .; t z. ~... ~~ e .~ w.. ~ ~~ ~~ ~ ~.. a , ~~.. x l ~i er _ { ~isJ Xl ~ ..~' r ~ ~ a°se ~ I~ X11` ~l' ~ ?~ ~ 4::. ~ ~ L?~ k~ ~ :~' _ __ -_ _ _ _____ ~~r v~_ _~-.--___ __ ~____ ____~ _._ _ _ ~___~_ Units: API - US Survey Feet P ~ Datum: 1C-172: 87.20ft (tC-172:) ~ r TVDs to System Local ~ Slot y.-~ North: True Object: X: ~ MD: (_.__-_.._.. Inc: ~.-_..._.~.. Az: '. Y: ~- TVD: ~- NJS: (~- EJW: r-- Plan: l C-172A (wp07) (] C-172lP1an: 1C-172A) ,r'~ `"~ ,. ~ 1 ~(~ 300 ~ 100 ,,. .. I'. ,r 1.1 ~ f ' • -w --I C1C1 -1 l~ '? (1~~ ^l! ?1 0 Tray-zlliil~ (='~-linclzr _-~ziiiluth (TFC=}+ ~' 'or Help, press Fl Screen clipping taken: 1/17/2008, 12:48 PM .a ..,` i! '~~ ~` ~i , 1 ~ Y. 7000' - 8367' MD with Major Risk ti{"1 ..I CC! , ' ryrr `/ :/ `) i '1 { ~-~+ {_+Clltl'Z t0 ~_~Clltl'~ ~zl~Ill'2l>~ll~lt ~ftj Common Well Name Unit System: API - US Survey Fe Angles: ° Depths: Ft Map: Ft File Edit View Analysis Plot Report TraveQing Cylinder View Tools Window Help s: iAPI - US Survey Feet P ~ Datum: 1C-172: (q1 87.20ft (IC-172:) ~ 1~ TVDs to System Local: ~'. Sbt~~~ I er ~„~_` 1 S_i ?c~ ._. ._ __.,,__, .. r._ ___.. ._.___... _a..„-.,.~_ _. ~_. _~..,._.__.__ Q rue ~ Plan: 1C-1?2A (wp07) (1C-172lP1an: 1C-172A) 7011' to 7446' (top A4) with Major Risk. Top A4 is at 3818' TVD just inside the O cairtinn araa of the AC Renprt CiU --1>(l _.1 C-0 ~~ :~~ -;t~ ~~ _.__. ~ U `? -C> >f) __ 1 C>C~ - 1St} -, C)0 T1 ~~'ellttl~ ~~"1111C1~T ~=~zillnith (TFt~+~~ZI~} [`-'~ ~-5 C~lltl-z tc~ C:zlltl-z S~pal•~ltlt~ll [f~~ ~ _--- ,, Common Well Mame }Unit System: API - US Survey Fs Angles: ° Depths; ft '•,Map: ft Screen clipping taken: 1/17/2008, 1:04 PM • '~~( 1>0 11)~:- [1 50 ~1(~0 1 >CM ?+~lf) -fi Plan: 1C-172A (wp07) (1C-172lP1an: ]C-172A) Once below the 7446' MD we are below any possible contact with 1 C- 102 and can use formation depth C) control to avoid it. Tra~-elling ~~~'1111C~~1 _~Zlllllltll ~TFt_)+ °or Help, press F3 Screen clipping taken: 1/17/2008, 12:51 PM (} ~~i E ~~"'~ ~-S ~~Zlltl'~ t0 ~~~llt1'~ ~~~171'~it1C711 ~ft~ ~ Common Wefl Name ~ ~ Unit System: API - U5 Survey Fe Angles: ° Depths: ft ~ Map: ft ,~,,, j Q ___. _.__ Q ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Report for 1 C-172/1 C-172A (wp07) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1C Pad - 1C-17 - 1C-17 Scan Range: 3,500.00 to 8,500.00 ft. Measured Depth. Scan Radius is 1,130 .63 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimi ted Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft- (ft) (ft) Bearing Bearing Factor Warning 5,145.24 3,075.57 16.26 4,575.00 2,891.53 47.43 348.85 206.72 166.48 -178.53 -115.27 1.913 Pass -Major Risk 5,174.26 3,086.69 16.36 4,600.00 2,903.60 47.78 336.65 205.48 155.84 179.39 -115.60 1.862 Pass -Major Risk 5,202.30 3,097.42 16.46 4,625.00 2,915.80 48.13 323.99 204.15 144.87 177.50 -115.81 1.809 Pass -Major Risk 5,229.16 3,107.69 16.55 4,650.00 2,928.13 48.48 310.92 202.76 133.59 175.83 -115.87 1.753 Pass -Major Risk 5,255.10 3,117.60 16.64 4,675.00 2,940.53 48.82 297.50 201.26 122.18 174.39 -115.75 1.697 Pass -Major Risk 5,280.14 3,127.15 16.73 4,700.00 2,952.93 49.15 283.81 200.00 110.69 173.21 -115.43 1.639 Pass-Major Risk 5,304.24 3,136.33 16.81 4,725.00 2,965.34 49.49 269.91 198.72 99.22 172.32 -114.87 1.581 Pass-Major Risk 5,327.31 3,145.10 16.88 4,750.00 2,977.76 49.82 255.87 197.44 87.83 171.77 -114.05 1.523 Pass-Major Risk ....~~ 5,349.54 3,153.56 16.95 4,775.00 2,990.20 50.16 241.79 196.12 76.72 171.56 -112.92 1.465 Pass-Major Risk 5,370.97 3,161.70 17.02 4,800.00 3,002.64 50.50 227.76 194.77 66.07 171.76 -111.44 1.409 Pass-Major Risk 5,391.60 3,169.53 17.09 4,825.00 3,015.08 50.83 213.90 193.40 56.08 172.41 -109.55 1.355 Pass-Major Risk 5,411.39 3,177.03 17.15 4,850.00 3,027.54 51.17 200.35 192.03 46.98 173.59 -107.18 1.306 Pass -Major Risk +~.~ 5,430.39 3,184.23 17.20 4,875.00 3,040.01 51.51 187.31 190.67 39.11 175.39 -104.24 1.264 Pass -Major Risk ~7 5,448.69 3,191.17 17.26 4,900.00 3,052.48 51.84 175.01 189.31 32.88 177.87 -100.65 1.231 Pass -Major Risk 5,466.33 3,197.84 17.31 4,925.00 3,064.97 52.18 163.71 187.95 28.68 -178.85 -96.33 1.212 Pass -Major Risk 5,483.32 3,204.26 17.36 4,950.00 3,077.48 52.51 153.74 186.57 26.84 -174.73 -91.18 1.211 Pass -Major Risk 5,499.71 3,210.45 17.41 4,975.00 3,090.08 52.85 145.43 185.20 27.43 -169.73 -85.20 1.232 Pass -Major Risk 5,515.44 3,216.39 17.45 5,000.00 3,102.75 53.18 139.21 183.87 30.05 -163.89 -78.41 1.275 Pass -Major Risk 5,530.63 3,222.12 17.49 5,025.00 3,115.50 53.51 135.45 182.78 33.59 -157.35 -70.96 1.330 Pass -Major Risk 5,545.30 3,227.65 17.53 5,050.00 3,128.32 53.85 134.46 181.73 36.26 -150.38 -63.12 1.369 Pass-Major Risk 5,559.47 3,232.99 17.57 5,075.00 3,141.21 54.18 136.39 180.67 36.46 -143.34 -55.23 1.365 Pass -Major Risk 5,573.17 3,238.15 17.61 5,100.00 3,154.19 54.51 141.19 179.63 34.82 -136.58 -47.64 1.327 Pass -Major Risk 5,586.41 3,243.14 17.64 5,125.00 3,167.23 54.85 148.65 178.59 34.16 -130.38 -40.65 1.298 Pass -Major Risk 5,600.00 3,248.25 17.68 5,150.00 3,180.35 55.18 158.48 177.46 36.04 -124.97 -34.42 1.294 Pass -Major Risk 5,611.55 3,252.59 17.71 5,175.00 3,193.55 55.51 170.30 176.57 40.79 -120.17 -28.93 1.315 Pass -Major Risk 5,623.50 3,257.08 17.73 5,200.00 3,206.82 55.85 183.79 175.59 48.52 -116.19 -24.23 1.359 Pass -Major Risk 5,635.07 3,261.42 17.76 5,225.00 3,220.12 56.18 198.68 174.62 58.85 -112.88 -20.23 1.421 Pass -Major Risk 5,646.26 3,265.62 17.79 5,250.00 3,233.37 56.51 214.78 173.66 71.44 -110.17 -16.85 1.498 Pass -Major Risk 5,657.09 3,269.69 17.82 5,275.00 3,246.57 56.85 231.88 172.71 85.89 -107.98 -14.00 1.588 Pass -Major Risk 5,667.58 3,273.62 17.84 5,300.00 3,259.71 57.18 249.80 171.78 101.84 -106.20 -11.60 1.688 Pass -Major Risk 5,677.72 3,277.43 17.87 5,325.00 3,272.80 57.52 268.40 170.86 119.01 -104.79 -9.57 1.797 Pass -Major Risk • 17 January, 2008 - 12:31 Page 4 of 14 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Anticollision Report for 1 C-172/1 C-172A (wp07) Kuparuk River Unit Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1C Pad - 1C-102 - 1C-102 Scan Range: 3,500.00 to 8,500.00 ft. Measured Depth. Scan Radius is 1,130.63 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 6,981.62 3,739.35 18.45 5,500.00 3,510.69 52.49 307.05 151.96 226.42 -2.82 161.17 3.808 Pass -Major Risk • 7,010.97 3,746.82 18.43 5,525.00 3,522.37 52.49 296.82 153.58 214.60 -4.37 160.95 3.610 Pass -Major Risk 7,040.08 3,753.87 18.41 5,550.00 3,533.49 52.49 286.95 155.15 203.11 -5.80 160.83 3.423 Pass -Major Risk 7,068.95 3,760.52 18.38 5,575.00 3,544.06 52.49 277.45 156.67 192.01 -7.10 160.81 3.247 Pass -Major Risk 7,097.39 3,766.73 18.36 5,600.00 3,554.24 52.48 268.07 158.11 181.05 -8.24 160.94 3.081 Pass -Major Risk 7,125.36 3,772.49 18.34 5,625.00 3,564.09 52.47 258.70 159.83 170.25 -9.19 161.22 2.925 Pass -Major Risk 7,152.83 3,777.83 18.32 5,650.00 3,573.62 52.46 249.41 161.70 159.67 -9.94 161.69 2.779 Pass -Major Risk 7,179.82 3,782.75 18.30 5,675.00 3,582.85 52.45 240.21 163.49 149.35 -10.46 162.35 2.644 Pass -Major Risk 7,206.26 3,787.26 18.28 5,700.00 3,592.00 52.43 230.93 165.21 139.10 -10.76 163.20 2.515 Pass -Major Risk 7,232.12 3,791.37 18.26 5,725.00 3,601.13 52.42 221.60 166.87 128.94 -10.82 164.26 2.392 Pass -Major Risk 7,257.42 3,795.11 18.24 5,750.00 3,610.22 52.41 212.27 168.45 118.90 -10.61 165.56 2.273 Pass -Major Risk 7,282.15 3,798.48 18.22 5,775.00 3,619.29 52.40 203.02 170.14 108.98 -10.10 167.14 2.159 Pass -Major Risk 7,305.53 3,801.43 18.20 5,800.00 3,628.36 52.38 193.90 171.40 99.32 -8.72 169.28 2.050 Pass -Major Risk 7,326.65 3,804.02 18.19 5,825.00 3,637.43 52.37 185.24 171.06 90.05 -5.64 172.36 1.946 Pass -Major Risk 7,347.80 3,806.62 18.17 5,850.00 3,646.50 52.36 177.17 170.72 80.22 -2.28 175.72 1.827 Pass -Major Risk 7,368.96 3,809.22 18.15 5,875.00 3,655.58 52.35 169.76 170.36 70.02 1.37 179.37 1.702 Pass -Major Risk 7,390.06 3,811.82 18.14 5,900.00 3,664.67 52.34 163.08 170.00 59.63 5.37 -176.63 1.576 Pass -Major Risk 7,411.10 3,814.40 18.12 5,925.00 3,673.79 52.33 157.24 169.62 49.25 9.73 -172.27 1.456 Pass -Major Risk • 7,432.08 3,816.98 18.11 5,950.00 3,682.92 52.32 152.37 169.22 39.14 14.43 -167.57 1.346 Pass -Major Risk 7,453.22 3,819.58 18.09 5,975.00 3,691.95 52.31 148.64 168.88 29.82 19.29 -162.70 1.251 Pass -Major Risk 7,474.66 3,822.21 18.08 6,000.00 3,700.80 52.29 146.08 168.65 21.67 24.07 -157.87 1.174 Pass -Major Risk 7,496.39 3,824.88 18.06 6,025.00 3,709.45 52.28 144.63 168.43 14.86 28.76 -153.12 1.115 Pass -Major Risk 7,518.41 3,827.59 18.04 6,050.00 3,717.88 52.26 144.20 168.26 9.49 33.30 -148.52 1.070 Pass -Major Risk 540.71 7 3,830.33 18.03 6,075.00 3,726.00 52.23 144.74 168.15 5.63 37.61 -144.15 1.040 Pass -Major Risk , 7,563.28 3,833.10 18.01 6,100.00 3,733.79 52.20 146.15 168.05 3.24 41.63 -140.08 1.023 Pass -Major Risk 7,586.11 3,835.91 18.00 6,125.00 3,741.23 52.17 148.27 167.94 2.17 45.31 -136.34 1.015 Pass -Major Risk 7,609.17 3,838.74 17.98 6,150.00 3,748.33 52.13 150.95 167.89 2.20 48.65 -132.94 1.015 Pass -Major Risk 42 7 632 841.60 3 17.97 6,175.00 3,755.14 52.09 154.07 167.87 3.15 51.67 -129.86 1.021 Pass -Major Risk , . 7,655.86 , 3,844.48 17.95 6,200.00 3,761.64 52.04 157.52 167.84 4.85 54.36 -127.11 1.032 Pass -Major Risk 679.46 7 3,847.38 17.94 6,225.00 3,767.83 52.00 161.18 167.82 7.13 56.75 -124.67 1.046 Pass -Major Risk , 7,703.26 3,850.31 17.92 6,250.00 3,773.60 51.94 164.94 167.87 9.79 58.78 -122.57 1.063 Pass -Major Risk (~~ ~/ 1 ~-- O 17 January, 2008 - 12:31 Page 10 of 14 COMPASS ' ~ MAL~~BU ,- ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1 C-172/1 C-172A (wp07) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1C Pad - 1C-102 - 1C-102 Scan Range: 3,500.00 to 8,500.00 ft. Measured Depth. Scan Radius is 1,130.63 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimi ted Uncertainty Data for Refere nce Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,727.31 3,853.26 17.91 6,275.00 3,778.78 51.88 168.66 167.95 12.67 60.41 -120.88 1.081 Pass -Major Risk 7,751.56 3,856.24 17.89 6,300.00 3,783.37 57.83 172.22 168.02 15.64 61.66 -119.57 1.100 Pass -Major Risk • 7,775.98 3,859.24 17.88 6,325.00 3,787.36 51.77 175.57 168.11 18.54 62.56 -118.61 1.118 Pass -Major Risk 7,800.53 3,862.25 17.86 6,350.00 3,790.76 51.69 178.64 168.28 21.26 63.14 -117.97 1.135 Pass -Major Risk 7,825.17 3,865.28 17.85 6,375.00 3,793.57 51.62 181.42 168.47 23.78 63.42 -117.62 1.151 Pass -Major Risk 7,849.87 3,868.32 17.84 6,400.00 3,795.79 51.55 183.88 168.66 26.08 63.42 -117.56 1.165 Pass -Major Risk ~; 7,874.59 3,871.35 17.82 6,425.00 3,797.44 51.47 186.01 168.85 28.14 63.16 -117.75 1.178 Pass -Major Risk 7,899.34 3,874.39 17.81 6,450.00 3,798.94 51.39 187.81 169.06 29.88 62.79 -118.06 1.189 Pass -Major Risk 7,924.07 3,877.43 17.80 6,475.00 3,800.23 51.31 189.50 169.29 31.55 62.34 -118.45 1.200 Pass -Major Risk 948.78 7 3,880.46 17.79 6,500.00 3,801.12 51.24 191.36 169.50 33.43 61.78 -118.94 1.212 Pass -Major Risk , 7,973.45 3,883.49 17.78 6,525.00 3,801.61 51.16 193.40 169.72 35.52 61.13 -119.53 1.225 Pass -Major Risk 7,998.08 3,886.52 17.76 6,550.00 3,807.77 51.08 195.60 169.91 37.84 60.40 -120.20 1.240 Pass -Major Risk 8,022.72 3,889.54 17.75 6,575.00 3,801.94 51.00 197.86 170.09 40.22 59.69 -120.85 1.255 Pass -Major Risk 8,047.47 3,892.58 17.74 6,600.00 3,802.13 50.93 200.11 170.22 42.63 59.07 -121.44 1.271 Pass -Major Risk !"~ 8,072.29 3,895.63 17.73 6,625.00 3,802.24 50.85 202.24 170.30 44.97 58.46 -122.06 1.286 Pass -Major Risk F 8,097.09 3,898.67 17.72 6,650.00 3,802.22 50.78 204.35 170.39 47.32 57.81 -122.71 1.301 Pass -Major Risk 8,121.86 3,901.72 17.71 6,675.00 3,801.97 50.70 206.69 170.47 49.92 57.13 -123.38 1.318 Pass -Major Risk 8,146.64 3,904.76 17.69 6,700.00 3,801.77 50.63 209.11 170.47 52.64 56.50 -124.02 1.336 Pass -Major Risk 8,174.21 3,908.13 17.68 6,725.00 3,801.92 50.55 211.34 168.79 56.37 57.53 -123.82 1.364 Pass -Major Risk • 8,199.06 3,911.13 17.66 6,750.00 3,802.26 50.48 213.21 168.77 58.51 57.01 -124.35 1.378 Pass -Major Risk 8,223.91 3,914.14 17.64 6,775.00 3,802.59 50.41 214.91 168.91 60.38 56.44 -124.91 1.391 Pass -Major Risk 8,248.76 3,917.14 17.63 6,800.00 3,802.86 50.34 216.53 169.16 62.11 55.85 -125.50 1.402 Pass -Major Risk 8,273.60 3,920.14 17.62 6,825.00 3,803.05 50.27 218.10 169.40 63.83 55.23 -126.13 1.414 Pass -Major Risk 8,298.42 3,923.14 17.61 6,850.00 3,803.08 50.19 219.75 169.62 65.66 54.57 -126.78 1.426 Pass -Major Risk 8,323.21 3,926.14 17.60 6,875.00 3,802.92 50.12 221.60 169.84 67.71 53.90 -127.46 1.440 Pass -Major Risk 8,348.18 3,929.16 17.59 6,900.00 3,802.46 50.05 223.68 170.00 70.12 53.18 -128.18 1.457 Pass -Major Risk 8,376.35 3,932.17 17.58 6,925.00 3,801.71 49.98 225.79 169.88 73.68 52.40 -128.91 1.484 Pass -Major Risk 8,404.66 3,934.51 17.57 6,950.00 3,800.76 49.90 227.67 169.68 77.03 51.72 -129.54 1.511 Pass -Major Risk 8,433.12 3,936.16 17.56 6,975.00 3,799.68 49.83 229.25 169.71 79.79 51.13 -130.08 1.534 Pass -Major Risk 8,461.70 3,937.11 17.55 7,000.00 3,798.52 49.76 230.44 169.75 82.06 50.64 -130.53 1.553 Pass -Major Risk 17 January, 2008 - 12:31 Page 11 of 14 COMPASS ~" ~~ CanacaPhilli~s Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1C-172A L2 (wp08) 1/4 Mile Pool Scan Sperry Drilling Services January 21, 2008 \ 1) ~~ _ HAl~L1~UR"TCf Sperr~jp C?rilE~rtg Rervicesi • HALLIBi,.IRTQN Sperry Drilling Services 4ooD~ ,C ~~ ?ooo ~~tt nFTwu_s: Ica n Grotmd Le~~el: 59,10 *NJ-S 'FI-W Northing Fasting Latimtde Longitude Slot 0.00 0.00 5968553.19 1702133.88 7U° 19' 30.006 N 149° 29' 58288 W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well 1C-172, True North Vertical (TVD) Reference: 1C-172A D15 @ 99.10ft (D15 (40+59.1)) Measured Depth Reference: 1C-172A D15 @ 99.10ft (D15 (40+59.1)) Calculation Method: Minimum Curvature CASING DETAILS TVD TVDSS NID Size Name 2442.622343.52 3500.20 9-5/8 9 5/8" TOW 3852.003752.90 7646.01 7-5l8 7 5/8" 3795.803696.70 13163.63 4-]i2 41/2" L_J tooD Project: Kuparuk River Unit I Site: Kuparuk 1C Pad Well: 1C-172 Wellbore: Plan: 1C-172A L2 Plan: 1C-172A L2 (wp08) )~.110P~~ ~~ °c o ~-~y o z - ] U00 ,~ o -2000 • T M Azimuths to True North Magnetic North: 23.07° Magnetic Field Strength: 57630.4snT Dip Angle: 80.84° Date: 12!16/2007 Model: BGGM2007 -6000 ~ -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 West(-)/East(+) (1500 ft/in) 1000 200D 3000 4000 5000 'r ConocoPhillips .~ - . \P-j0~ ~ ~~~ Closest in POOL ~°'~ f,,~ ~ Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1C-102 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth. Incl. An le TRUE Azi. ND E + /W - 180°) Comments m istance POOL Min Disfance (56.1 ft) in POOL (56.1 ff) in POOL (6999 - 13163.63 MD) ,; i/ (6999 - 13163.63 MD) ~ to 1C-172A L2 (wp08) fo 1 C-102 (6270 - Plan (6270 - 10570 56.1 12050 90.42 181.96 3707.06 5965612.2 1698678 2912.53 10570 MD) 10570 89.38 177.42 3651.212 5965616.1 1698674 2908.577 MD) Closest A roach: Reference Weil: 1C-172A L2 w 08 Plan Offset Well: 1C-172 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An Ie TRUE Azi. ND E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments L Mm istance POOL Min Distance (123.62 ft) in POOL (123.62 ff) in POOL (6999 - 13163.63 MD) ' ~/ (6999 - 13163.63 MD) / to 1 C-172A L2 (wp08) to 1 C-172 (6368 - Plan (6368 - 11970 123,62 11600 90.23 182.1 3709.593 5966062 1698690 2462.825 11970 MD) 10893.66 98.47 181.38 3720.2 5966059.2 1698813 2466.65 MD) Closest A roach: Reference Weil: 1C-172A L2 w 08 Plan Offset Well: W SAK SW PT 1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. TVD E(+)AN - 180° Comments Depth Incl. An le TRUE Azi. ND E + !W - 180° Comments ~n is ante POOL Min Disfance (249.96 ft) in POOL v (249.96 ft) in POOL ~ (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) to W SAK SWPT 1 Plan (3720 - 4129 249.96 8550 90.61 181.17 3746.67 5969110.6 1698764 -585.03 (3720 - 4129 MD) 3843 0.57 91.24 3743.66 5969097.6 1699014 13.96 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Weil: 1D-108 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. ND E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W - 180° Comments P L Min Disfance POOL Min Distance (275.33 ft) in POOL (275.33 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) fo 1 D-108 (6583 - Plan (6583 - 7046 275.33 13163.63 90.42 181.96 3698.897 5964499 1698649 4025.463 7046 MD) 6817.22 20.05 342.58 3783.26 5964240.6 1698605 -4765.53 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1C-170PB1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Inci. An le TRUE Azi. TVD E + /W - 180° Comments De fh Incl. An le TRUE Azi. ND E + M/ - 180° Comments in istance POOL Min Distance (590.11 ft) in POOL (590.11 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) fo 1 C-172A L2 (wp08) to 1 C-170P61 (5912 - Plan (5912 - 7328 590.11 7000 76.06 196.76 3656.052 5970647.1 1698831 -2120.908 7328 MD) 5890.16 82.9 335.24 3663.43 5970928 1699349 -2375.06 MD) 1C-172a (wp08) POOL Summary.xls 1!21/2008 2:47 PM ~J Closest in POOL ~..~ °~~r~ a~..~, ClosestA roach: Reference Weil: 1C-172A L2 w 08 Plan Offset Well: 1C-03 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Disfance. Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depfh Incl. An le TRUE Azi. ND E + /W - 180° Comments in istance POOL Min Disfance (609.71 ff) in POOL (609.71 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) fo 1C-172A L2 (wp08) fo 1 C-03 (4932 - 5636 Plan (4932 - 5636 6U9.71 10725 90.89 182 3719.18 5966936.6 1698714 1588.45 MD) 5650 52.12 253.46 4036.81 5966913.2 1699234 1469.56 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1 C-08 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + NV - 180° Comments P L Min isfance POOL Min Disfance (646.39 ft) in POOL (646.39 ff) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1C-172A L2 (wp08) to 1 C-08 (4547 - 5249 Plan (4547 - 5249 646.39 8025 91.79 180.87 3753.24 5969635.5 1698771 -1109.88 MD) 5250 54.87 291.72 4023.4 5969621.3 1699358 -895.67 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1C-111 COOrdS. - COOrd S. - ASP ASP 3-D ctr•ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+}/S(-) View VS Distance. Depfh Incl. An le TRUE Azi. ND E + NV - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W - 180° Comments in istance POOL Min Distance (813.82 ft) in POOL (813.82 f[) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) fo 1C-172A L2 (wp08) fo 1 C-111 (6290 - Plan (6290 - 6731 813.82 '' 7050 77.08 194.42 3667.66 5970600.1 1698818 -2074.07 6731 MD) 6274 25.53 307.61 3615.9 5970783.4 1698027 -2332.11 MD) Closest A roach: Reference Weli: 1 C-172A L2 w 08 Plan Offset We11 1 C-125.... Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + iW - 180° Comments P L Min Disfance POOL Min Distance (936.63 ft) in POOL (936.63 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) fo 1 C-125 (6739 - Plan (6739 - 7564 936.63 12275 90.42 181.96 3705.41 5965387.3 1698672 3137.4 7564 MD) 6725.48 58.3 206.58 3517.52 5965406.3 1697754 3110.84 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1G-117 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /4V - 180° Comments P L Min Disfance POOL Min Disfance (945.33 ff) in POOL (945.33 ff) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) fo 1 C-172A L2 (wp08) to 1 C-117 (4502 - Ptan (4502 - 4918 945.33 8825 91.4 181.56 3743.44 5968835.6 1698761 -310.11 4918 MD) 4778 9.78 286.39 3894.04 5968816.3 1699694 -401.7 MD) 1C-172a (wp08) POOL Summary.xls 1/2112008 2:47 PM Closest in POOL '---``~~ ./'\..J .,...... Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1C-119 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + NV -) 180° Comments POOL Min Distance POOL Min Distance (1041.29 ft) in POOL (1041.29 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) to 1 C-119 (5984 - Plan (5984 - 6432 1041.29: 8872.45 91.8 181.76 3742.03 5968788.2 1698760 -262.7 6432 MD) 5981.08 29.67 276.5 3591.01 5968812.8 1697730 -430.93 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Weil. 1C-121 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (1043.86 ft) in POOL (1043.86 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1C-172A L2 (wp08) to 1 C-121 (6254 - Plan (6254 - 6710 1043.86 10650 90.89 182 3720.34 5967011.6 1698716 1513.5 6710 MD) 6241 23.69 209.34 3538.18 5967049 1697689 1315.11 MD) Closest A roach: Reference Well: 1C-172A L2 w OS Plan Offset Well:. 1C-127 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance POOL Min Distance (1066.14 ft) in POOL (1066.14 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) to 1C-127 (5861 - Plan (5861 - 6312 1066.14 12650 90.42 181.96 3702.66 5965012.4 1698662 3512.17 6312 MD) 6100 12.07 215.83 3823.89 5964976.4 1699721 3353.98 MD) Closest A roach: Reference Well: 1C-172A L2 w 08 Plan Offset Well: 1C-123 Coords. - Coords. - ASP ASP 3-D ctr•ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (1093.43 ft) in POOL (1093.43 ft) in POOL (6999 - 13163.63 MD) (6999 - 13163.63 MD) to 1 C-172A L2 (wp08) to 1 C-123 (4857 - Plan (4857 - 5304 1093.43 10975 90.89 182 3715.29 5966686.8 1698707 1838.26 5304 MD) 5121.21 10.2 230.83 3859.7 5966647.4 1699790 1886.469 MD) 1C-172a (wp08) POOL Summary.xls 1!21/2008 2:47 PM 1C-172~Drillin~ Hazards ~.immary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 9 5/8" Surface Casing already in place 9-7/8" Open Hole / 7-5/8" Casing Interval (81/2" X 9 7/8" Bi-Center Bit) Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud wei ht, use wei hted swee s. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 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 weight. Stuck Pipe Low Good hole cleaning, PWD tools, decreased mud weight, backreaming to clean hole Lost Circulation Low Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumpin out, backreamin 1C-172A Drilling Hazards Summary.doc n t ~ prepared by Steve Shultz 1/15/08 ' ' Schlumberg~r CemCADE' Preliminary Job Design 7.625" Intermediate Casin reliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Client: ConocoPhillips Alaska, Inc. Revision Date: 1/22/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com a - Previous Csg. < 9 5/8", 40.0# casing at 3,500' MD < Top of Tail at 4,900' MD I i < 7 5/8", 29.7# casing in 9 7/8" OH TD at 8,400' MD (3,944' TVD) Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 3500' MD above the intermediate casing shoe. Maximum dynamic pressure experienced during cement job is expected to be 11.6 ppg. Tail Slurry Minimum thickening time: 230 min. (Pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.59 ft3/sk 0.2148 ft3/ft x 3500' x 1.40 (40% excess) = 1052.5 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 1052.5 ft3 + 20.6 ft3 = 1073.1 ft3 1073.1 ft3! 2.59 ft3/sk = 414.3 sks Round up to 420 sks BHST = 84`F, Estimated BHCT = 75~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) [min) Drop Bottom Plug 10.0 10.0 MudPUSH II 5 40 8.0 18.0 Tail Slurry 6 194 32.3 50.3 Drop Top Plug 5.0 55.3 Pump Water 4 20 5.0 60.3 Switch to Rig Pum 5.0 65.3 Displacement 6 332 55.3 120.6 Slow Rate 3 30 10.0 130.6 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, P~ < 10, TY < 10. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, P~ = 19-22, TY w 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. :, Schlumberger CemCAD E*well cementing recommendation for Intermediate Operator : ConocoPhillips Well 1C-172ATLP Country : US of A Field State :Alaska Prepared for :Steve Shultz Location 1 C pad Proposal No. : V2 (prelim) Service Point Prudhoe Bay Date Prepared : 01-22-2008 Business Phone (907) 659-2434 FAX No. (907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Address mtorrie@slb.com ~~~~~ 4 {~ e ~~ 941~ATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model inclutliny various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well orwells accordingly. Prices quoted are estimates only and are goad for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ;~~~,Y~ • Client ConocoPhillips Well 1 C-172A TLP String Intermediate District Prudhoe Bay Country US of A Loadcase Intermediate Section 1: w ell description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :8400.0 ft BHST : 90 degF Bit Size : 8 1/2 in tt ~, ~; ~~ ':"Jell Lithulagy Previous String MD OD Weight ID ft in Ib/ft in 3500.0 9 5/8 40.0 8.835 Landing Collar MD :8320.0 ft Casing/liner Shoe MD :8400.0 ft 0 ~chlcmrgcr tx 1 UOU) psi ~, ~ 3 4 l }. l_ i .~ '... y l~ ~._.l r l 4 x ';. ~ __+, 1 _ s. t Furrnation i-'rE!SS. Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) si 8400.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 LTC 1C-17%A,V2.cfw;01-22-2006; Loadcase lnCennediate;Versionwcs-cem452_07 Page 2 (~RIt~INAL • Client ConocoPhillips Well 7 C-172A TLP String Intermediate District Prudhoe Bay Country US of A Loadcase Intermediate Mean OH Diameter :9.875 in Mean Annular Excess :40.0 Mean OH Equivalent Diam eter: 10.643 in Total OH Volume :539.1 bbl (including excess) Max. Deviation Angle :136 deg Max. DLS :38.016 deg/100ft Directional Survey Data MD TVD Deviation Dogleg Sev. ft ft de de /100ft 0.0 0.0 0.0 0.000 3500.0 2345.0 85.2 2.435 4900.0 2981.0 39.1 -3.292 5486.0 3217.0 91.6 8.947 7646.0 3928.0 49.1 -1.967 8117.0 3910.0 135.8 18.404 8400.0 3944.0 28.2 -38.016 Formation Data MD Frac. Pore Name Lithology ft Ib1 al Ib/ al 8400.0 12.00 8.00 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1300.0 1234.9 30 0.4 8346.0 3901.9 89 1.6 8400.0 3944.0 90 1.6 (x 1 UUUj ft ~~~Irg~r -Huri. Ctepan.~ sS Q ~ _3..{ ~ `.. CV ~ k - `-- .~ ~ 7 P.,.j C^ _-~ ~ r %~~ d ~ ~ ... ~f .~t..: N , ,~..~. O `7 r.. ~._; - G ` v . i C .j CJ Y " tv 1 , . -; (n . ~ > ~1 Huri. C~epartlare 1C-172A,V2ciw;01-22-2008; Loadcase lnternrediate;Versionwcs-cem452_OI • Paye 3 ORIGINAL • • Client ConocoPhillips ~ ~ ~l Well 1 C-172A TLP rg r c String Intermediate District Prudhoe Bay Country US of A Loadcase Intermediate Section 2: ce ntralizer placement Top of centralization :3500.0 ft Bottom Cent. MD :8350.0 ft Casing Shoe :8400.0 ft NB of Cent. Used :187 NB of Floating Cent. :187 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint °io ft 4840.0 11 1/3 1231275-7 5/8-6-12 (1/8")A 0.0 4814.1 8360.0 176 2/1 1231275-7 5/8-6-12 1/8" A 43.6 8350.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD {in) (in) Force Force in in (Ibf Ibf) 1231275-7 5/8-6-12 7 5/8 9.126 8.374 No Houma 8-500 332.72 1805.22 1/8" A {1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 1C-172A, VZcfw; 01-22-2008; Loadcase Intermediate; Version wcs-cem452_07 ORlGlNAL • Client ConocoPhillips ~ l Well 1C-172A TLP ~ r~~r String Intermediate District Prudhoe Bay Country USofA Loadcase Intermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8,801b/gal Rheo. Model : HERSCHEL_B. k : 9.35E-31bf.s^n/fl2 At temp. :120 degF n :0.461 Tv :1.911bf/100ft2 Gel Strength :11.74 Ibf/100ft2 MUD Mud Type : WBM Job volume :362.0 bbl Water Type :Fresh VOLUME FRACTION Solids : 2.0 Oil : 0.0 Water :98.0 MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 2.54E-2 Ibf:s^n/fl2 At temp. : 80 degF n :0.420 Ty :13.041bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :40.0 bbl 12 ppg DeepCRETE DESIGN Fluid No: 4 Density : 12.00 Iblgal Rheo. Model : HERSCHEL_B. k : 7.84E-31bf.s^Nft2 At temp. : 64 degF n :0.781 Ty :13.121bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid :10.671 gal/sk Yield :2.59 ft3/sk Porosity :55.1 Density :8.321b/gal Job volume :191.1 bbl Quantity :414.37 sk Solid Fraction :44.9 Base Fluid :10.621 gal/sk 1C-172A, V2.c(w;01-22-2008; Loadcase Intermediate; Version wcs-cem452_07 ~~ Page 5 • Client ConocoPhillips ~ Well 1C-172ATLP ~~~~ String Intermediate District Prudhoe Bay Country USofA Loadcase Intermediate Section 4: fluid sequence Job Objectives: To bring cement to 4900'MD (2981 TVD) to cover the upper most lateral by 500'. Original fluid Mud 8.80 Ib/gal k : 9.35E-3 Ibf.s^n/ft2 n :0.461 Tv :1.91 Ibf/100ft2 Displacement Volume 382.0 bbl Total Volume 613.1 bbl TOC 4900.0 ft --- _ Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbQ ft ft Ib/ al MUDPUSH II 40.0 747.0 4153.0 10.50 k:2.54E-2 Ibf.s^Nft2 n:0.420 Tv:13.04 Ibf/100ft2 12 ppg DeepCRETE 191.1 3500.0 4900.0 12.00 k:7.84E-3 Ibf.s^Nft2 n:0.781 Tv:13.12 Ibf/100ft2 Water 20.0 7884.4 8.32 viscosity:3.000 cP Mud 362.0 0.0 8.80 k:9.35E-31bf.s^Nft2 n:0.461 Tv:1.911bf/100ft2 Static Security Checks Frac 389 psi at 3600.0 ft Pore 97 psi at 3500.0 ft Collapse 4400 psi at 7881.5 ft Burst 6890 psi at 0.0 ft Cs .Pum out 47 ton Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. de F MUDPUSH II 5.0 40.0 8.0 40.0 80 12 ppg 6.0 191.1 31.8 191.1 80 DeepCRETE Water 4.0 20.0 5.0 20.4 80 Mud 6.0 329.5 54.9 329.5 80 Mud 3.0 30.0 10.0 359.5 80 Total 01:49 610.6 bbl hr:mn D namic Securi Checks Frac 85 psi at 8400.0 ft Pore 97 psi at 3500.0 ft Collapse 4371 psi at 125.8 ft Burst 6282 si at 0.0 ft Temperature Results API BHCT 85 degF Simulated Max HCT 91 degF Simulated BHCT 76 degF Max HCT Depth 7881.5 ft CT at TOC 71 degF Max HCT Time 00:00:00 hr:mnac 1C-172A,VZciw;01-22-2008; LoadCaselntermediate;Versionwcs-cem452_07 Page 6 f T. ! v''" ~ ~!. ~ n Client ConocoPhillips Well 1C-172A TLP String Intermediate District Prudhoe Bay Country US of A Loadcase Intermediate ft o~ O C`') O. O cD O Fluid Sequence 0 0 0 o_ X N QO N N N d O Ib/gal 7.5 10.0 12.5 --- - Hydrostatic I o ~ --~ ~ Calc. Rnrp Press. tvLn. Hydrostatic ~~ Calc. WFP PAax. Dynamic ~ - - tv5n. Dynamic ~ ~o _ ~.., Frac .Q~ -Pore `- = o N -! O 0 250 500 750 Pumped Volume (bbl) Depth = 8400 ft ~ ~ Annular Velocd C O ~.- p (`') ~ U U O N OO~ ~ N C 0 250 500 750 Dynamic Well Security Pumped Volume (bbl) Depth = 8400 ft Collapse Burst ~~ Pseudo Fydrostatic 0 100 200 300 400 500 600 700 Pumped Volume (bbl) Depth = 8400 ft r.p -f ,~~ ~ ---- _---. _.. _ _ _. _. - N I _.. .. - - N T ~ Pore ~ - o~ ~ Hydrostatic Q ~ Dynamic N O ~o_ m ur r a c c Q ~ ~ TTT -T1~ 0 100 200 300 400 500 600 700 Pumped Volume (bbl) 1C-172A, V2 cfw;01-22-2008; Loadcase lntermediate;Version wcrcem452_07 aR~~i~~L ~c~lr~g~r Page 7 • Client ConocoPhillips Well 1C-172ATLP String Intermediate District Prudhoe Bay Country US of A Loadcase Intermediate Secti on 6: WELLCLEAN I I Simulator ft 0 50 100 0 100 0 o { - Std Betw. Gent. -Mud Contamination -Cement Coverage - Uncontanrnated Slurry o M ~~ O O ~~ • S~~Irg~r Fluid Sequence Cement Coverage Uncontaminated Slurr) Deviation Risk P.4t-td on tl7e'a ~•:tall Fluids l.r~r~centr3tions ~ ~ ~ ~ ~ ~s~lv z ; s$v~~ ~' X040 _ X006 4040 ;~ d006 4 ~ , ' s54o- ~ Boa s~4o ~ . ^ a~oa - Sa40- u 5400 salvo-~ ~''y SSGR-~ ' ~~ ~ *- f- ~ ~~~ Sooa 594 ~SGO 5500 ~ ,g ~ ~ ,; ,~~;; i 6040- ~ 6006 f e. 6040- ~ V' ~ ~ ~ ~ ~ fi004 a ''- w - a° o $5114- ~ ,k~"' ' 5506 a 0 6500- 554a o f ?0{10- 7440 7Q{l©- ~ ~~' 740a 'SU4 - 7548 '`5{i 4 7540 $6{~b- •=- 8006 $040 AbbO d ; Z L T ~ 4 ~ p O ~ G S T ~ O S S r O ? r h:1~_ld ®Higl-~ Li_o:~t ® '•:'•aater 0 Paedium ~ ~d~~r~e ~ 7 ~ PRg UeepLRETE 0 tal_IDF'U~H II Page 8 1C-172A,V2.cfw;01-22-2008; LoadCaselntermediate;Versionwcs-cem452_07 ~R~~INAL ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~'~~~ r~" C ~~ PTD# ~~ C~C>~ Development. Service Exploratory Strati ra hic Test Non-Conventional Well g p ~~vt~~ FIELD: ~. POOL: ~~ ~ (~~~ \ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in API number well permit No. ,API No. 50- - - 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 i SAMPLE n no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw h tar et zones. Non-Conventional Well please note the following. special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Companv Namel 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 testin g ro ram. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool Weli Name: KUPARUK RIV U WSAK 1C-172A Program DEV Well bore sag ^ PTD#:2080080 Company c'ONOCOPHILLIPS ALASKA INC Initial Class/Type DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore ~ Annular Disposal ^ Administration 1 Petm~feeattached- ---- --- - --- - --- NA-- ---- - -- - -- - --- --- -- -- ---- 2 lease ns~mber appropnate_ _ _ _ _ _ . _ _ _ - - _ _ _ - - _ _ _ - _ _ . _ _ _ - - _ _ . -Yes _ _ - - Surface and top prod inieaal in AQi, 25649; TAin norkhermostportion ofAOJ. 25650. - _ _ - - - _ _ _ _ _ - 3 Uniquevrell_nameandnumber------- -- - ----- --- - --- -Yes -- --- -- - - ----- -- ---- - - - -- 4 Welliocatedina-defned_pool--______-_--__--______-___ _.______Yes_ _.____KOPatukRiver,Wast_SakOilPo4i~49015Q,-goyernedbyC04069-_-------------_--.__--_- 5 Well located proper dis}ante from drilling urtit_bosrndary- - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ - CQ 406B, Rule 3; no restrictions as-to well spacing except that no_payshall -bQ opened in a well closer - _ - - _ _ _ 6 Well located proper dis}once from other wells_ _ _ - - _ - - _ - - _ _ _ - _ .Yes _ _ - _ - _ than 500 feet }o-an ex#ernal_property line where ownership orlandownership changes, - - . _ _ - _ _ _ 7 Sufficientacreageavailabiein-driUingunjt_______________________ _________Yes- -____Wellis more than-500 fee}from an-extemalproperty line._____-____-__--_--__-_-________- 8 If deviated, iewellbore piatincluded - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Opera}otonly affected party----- - ---- -- -- --- - Yes- - -- --- - -- - ---- ------ -- ---- --- 10 Opera}or has_approprla}ebond in force - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - 11 Pemlitcanbeissuedwithouioonsentatioflorder--__----______ ____-Yes- ------------------------------------------------------------- - - Appr Date 12 Permitcanba}ssuadwth2u}administra}ive_app[oval---------------- ---------Yes- ---------.-------------.--------------------------------------- ---- 13 Can permit be apRrevedbefore l5-day_wok- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 112312008 14 .Welliocatedwithinareaarlds}rataauth4rizedbY-Injeotion4roar#(put14#in_comments)-(FOr_ NA-- ------------------------------------------------------------------------- i5 Aliwe}Jswkhin114_mileareaof[eyiewdenlifiad(Forservicewell9nly)______ _________ NA__ _________.-__------- ---------- t6 Pte-prgducedinjsc~or.duratiooolgrg~roductiontessthan3morlths-(For service weltoNy)---NA- ----------------------------------------------------------- -- -- 17 Jdanconyen, gas_c9nforms3c AS31:05,03Q(41.A)~f1.2.A-D) - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 CoDductorstrirtgprovfded__________________----_------ ---__--NA-- _--_.Qonduotorset_irt14-172{203.095).-----___---_--____-________-__--_________-- 19 Su_rfacecasinaprotectsallknownUSDWs_______---____--__ ___---_--tJA-- _ -All aquifers exempted, 40CFR_147.102-(b)(3).--__-______--____-__--_.--------.__-- '~ 20 CMTvoiedequa}e_tocirculeteonconductor&surfcsg_-___-_______ _________ NA_ __-__Surfacecas}ngsetirtlC-172,______-_-_____--_.-_-__--_-___--______-________ 21 CMT-voladequa}e to}ie-iAJQngstringtosuLfcsg ----------------- --------- No-- -----TQQplannadaboveUgnu.-------------------------------------._------------ 22 CMT-wiilcover all known_ptoduotivehorizons--------------------- ---------N°-- -_----Slotted liner-completion planned•-------------------.---.----------.------------ 23 Casing desgns adequate for C, T B_8~ permafcost - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate iankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ - Rig equipped with sisal pits. No-reserve pit planned._ AI}waste-to apprQVed disposal wail(s), _ _ _ _ _ _ _ - _ - - _ _ 25 Ifa_rs-drill,has-a10-003forabandcnmentkeen apRroved------------ ---------Yes- -----203.095------------------------------------------------------------- 26 Adequate weilbote separation proposed _ - - . _ _ - - _ _ - _ - . _ _ _ . _ - _ _ - - _ _ - _ _ Yes _ _ _ _ - -Proximity analysis performed, Traveling cylinder path calculated, - - - - _ _ _ _ _ _ - _ _ _ - _ _ _ _ 27 If-diverterrequi-red, does ltmeetregulations_----_-_--_____--_ -_ __---NA-- ------BQPSta(~c_willalreadY-bainplace----------------------------------------------- Appr Date 28 Dulling flu}d_program schematic & equip list adQquate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - - _ Maximum expected formation pressure 8,4-EMW.- Planned MW 8,4.8,5-ppg.- - - - _ _ - _ - _ - _ _ - - _ _ _ _ _ _ _ TEM 1125!2008 29 BOPEs,-dotheymeetregulation___________________------- ---------Yes- -------------------------------------------------------------------- ~~-,,~~ An rr • 30 BOPS-press rating appropriate; test to.(put psig in comments)- _ - - _ _ - . _ _ - - Yes - - _ _ - - _ MASP calculated a} 1301 psi. 3K stack arrangement and BOP test planned__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~~ r t 31 Chcke_m>rnifold compNeswIAPLRP-53 (May 84)- - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work willoccu[withoutoperationshutdown__________---___ _-_-__--Yes- ------------------------------------------------------------------------ 33 is presence-of H2S gas prpbable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - - _ _ H2$ is reported_in 1C W$welis._ Mud shook! preoipdeon-rig._ Rig eghipped with sensprs and-alarms._ _ - - _ _ _ _ 34 Mechan}cal condition ofyrQllswithinAQRverffied(ForseNicewelipnlya----- -------- NA-- -------------------.----------------- Geology 35 Permitcan be i~suedwlo hydrogen sulfide measyres _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ - - _ _ -1C-Pad West Sak wells_measure from 4 to-170 PPM H2S, Precau}ions are-advisable, - - _ _ - _ _ - - _ _ _ _ _ _ 36 Deta-presented on potential overpreessur_ezcnea _ . - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ - - -Expected reservoirpressure is 8,4-ppg EMW; prod lrttenral will be drilled with, 8.4 to 8,5 ppg oil-basemud, - Appr Date 37 SeismlcanaNsis,ofshallowgaaaones_------_--___-_--__--_ ______.NA_- --_._Redrill___-___--_--------------------------------------------___ -- SFD 1l23I2008 38 ___ Seabed condition survey-(rf_ off-shore) - - - - - - - - ---_-_--NA_- ._____----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39 Contact Hemelphone (orwoekly.pregre_ss reports_(exploratory only! - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Oats Data: ' Date Redrilled producer targeting the West Sak A2 iMenal, Anticoliision is a concern here. This wellbore vnB pass within 250' of Commissioner: Co er signer: ~+~Q~~~ 7~ three nearby wells. This will be the main well bore for a trilateral production well. C 'A _ /~ 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. 1c-172a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 12 16:03:30 2008 Reel Header Service name .............LISTPE Date . ...................08/06/12 Ori9in ...................5T5 Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/06/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LI5 writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: 1C-172A 500292315901 ConocoPhillips Alaska Inc. Sperry Drilling ,services 12-JUN-08 MWD RUN 1 MWD RUN 2 MWD RUN 3 w-0005476893 w-0005476893 w-0005476893 B. HENNINGSE B. HENNINGSE B. HENNINGSE F. HERBERT F. HERBERT M. THORNTON MWD RUN 4 w-0005476893 B. HENNINGSE M. THORNTON 12 11N l0E 1436 1096 Page 1 ~~-~Cj~S l~o~~ 1c-172a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 100.50 GROUND LEVEL: 59.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3513.0 2ND STRING 6.750 7.625 8301.0 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 3513'MD/2448'TVD IN THE 1C-172 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 2-4 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 4. 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 1-4 REPRESENT WELL 1C-172A WITH API#: 50-029-23159-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13101'MD/3915'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 Page 2 1c-172a.tapx 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.......sTSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPS RPM RPD RPX 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 13043.5 13050.5 13050.5 13050.5 13050.5 13050.5 13101.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 3513.5 2 3549.0 3 3620.0 4 8310.0 REMARKS: MERGED MAIN PASS. Data Format specification Record MERGE BASE 3549.0 3620.0 8310.0 13101.0 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 MWD OHMM 4 1 68 4 2 Page 3 1c-172a.tapx RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3505 13101 8303 19193 3505 13101 RPD MWD OHMM 1.22 2000 19.5803 19011 3508 13050.5 RPM MWD OHMM 0.47 2000 16.5444 19011 3508 13050.5 RPS MWD OHMM 3.38 2000 15.2252 19011 3508 13050.5 RPX MWD OHMM 2.88 2000 14.578 19011 3508 13050.5 FET MWD HR 0.18 112.23 1.11401 19011 3508 13050.5 GR MWD API 5 126.27 70.0904 19078 3505 13043.5 ROP MWD FPH 0.27 506.52 174.235 19176 3513.5 13101 First Reading For Entire File..........3505 Last Reading For Entire File...........13101 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5Li6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 3513.5 3549.0 LOG HEADER DATA DATE LOGGED: 31-MAR-08 SOFTWARE Page 4 • SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 1c-172a.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum Specification Block sub-type...0 • Insite 74.11 Memory 3549.0 3513.0 3549.0 67.0 67.0 TOOL NUMBER 8.500 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 ROP MWDO10 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 5 • 1c-172a.tapx DEPT FT 3513.5 3549 3531.25 ROP MWDO10 FPH 0.27 64.31 15.8885 First Reading For Entire File..........3513.5 Last Reading For Entire File...........3549 File Trailer Service name... .......STSLIB.002 service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3505.0 RPD 3508.0 RPx 3508.0 RPM 3508.0 FET 3508.0 RP5 3508.0 ROP 3549.5 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: • 72 3513.5 3549 72 3513.5 3549 header data for each bit run in separate files. 2 .5000 STOP DEPTH 3576.0 3567.5 3567.5 3567.5 3567.5 3567.5 3620.0 O1-APR-08 Insite 74.11 Memory 3620.0 3549.0 3620.0 65.7 67.0 Page 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 TOOL NUMBER 250050 230203 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 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 Page 7 1c-172a.tapx ! • 1c-172a.tapx RPS MWD020 OHMM 3.73 1501.03 26.8414 120 3508 3567.5 RPX MWD020 OHMM 2.88 1501.2 25.9054 120 3508 3567.5 FET MWD020 HR 0.77 38.4 27.5827 120 3508 3567.5 GR MWD020 API 24.01 94.2 51.6914 143 3505 3576 ROP MWD020 FPH 11.43 278.28 120.048 142 3549.5 3620 First Reading For Entire File..........3505 Last Reading For Entire File...........3620 File Trailer service name... .......STSLIB.003 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.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3568.0 8257.0 RPx 3568.0 8257.0 RPM 3568.0 8257.0 RPD 3568.0 8257.0 RPS 3568.0 8257.0 GR 3576.5 8266.0 OP 3620.5 8310.0 $ 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): 8310.0 TOP LOG INTERVAL (FT): 3620.0 BOTTOM LOG INTERVAL (FT): 8310.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 8 • i MINIMUM ANGLE: MAXIMUM ANGLE: 1c-172a.tapx 65.2 86.9 TOOL NUMBER 250050 230203 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service Order DEPT RPD MWD030 RPM MWD030 RPS MWD030 RPX MWD030 FET MWD030 GR MWD030 ROP MWD030 Name Service Unit 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 units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HR 4 1 68 20 6 API 4 1 68 24 7 FPH 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading Page 9 s ~ 1c-172a.tapx DEPT FT 3568 8310 5939 9485 3568 8310 RPD MWD030 OHMM 3.38 102.98 12.5993 9379 3568 8257 RPM MWD030 OHMM 3.16 89.64 11.6125 9379 3568 8257 RPS MWD030 OHMM 3.38 112.34 11.4566 9379 3568 8257 RPX MWD030 OHMM 3.86 113.12 10.9031 9379 3568 8257 FET MWD030 HR 0.22 11.18 0.940348 9379 3568 8257 GR MWD030 API 5 126.27 72.5064 9380 3576.5 8266 ROP MWD030 FPH 4.72 506.52 149.191 9380 3620.5 8310 First Reading For Entire File..........3568 Last Reading For Entire File...........8310 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8266.5 13043.5 RPx 8295.0 13050.5 RPD 8295.0 13050.5 FET 8295.0 13050.5 RPM 8295.0 13050.5 RPS 8295.0 13050.5 ROP 8310.5 13101.0 LOG HEADER DATA DATE LOGGED: 11-APR-08 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13101.0 TOP LOG INTERVAL (FT): 8310.0 Page 10 • i 1c-172a.tapx BOTTOM LOG INTERVAL (FT): 13101.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88:1 MAXIMUM ANGLE: 92,$ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8301.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 83.0 MUD PH: ,0 MUD CHLORIDES (PPM): 2800 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 120.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 Page 11 1c-172a.tapx i First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8266.5 13101 10683.8 9670 8266.5 13101 RPD MWD040 OHMM 7.18 2000 24.5462 9512 8295 13050.5 RPM MWD040 OHMM 4.41 2000 21.3568 9512 8295 13050.5 RPS MWD040 OHMM 5.13 2000 18.7946 9512 8295 13050.5 RPX MWD040 OHMM 5.02 2000 18.0585 9512 8295 13050.5 FET MWD040 HR 0.18 112.23 0.951329 9512 8295 13050.5 GR MWD040 API 38.79 119.61 67.9939 9555 8266.5 13043.5 ROP MWD040 FPH 4.01 356.83 200.744 9582 8310.5 13101 First Reading For Entire File..........8266.5 Last Reading For Entire File...........13101 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 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 Reel Trailer Service name .............LISTPE Date . ...................08/06/12 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical services Page 12
