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207-038
Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other: OA Cement ShoeCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment Service 6. API Number:Stratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 17735'feet 9048'feet feet11100'feet3512'true vertical measuredEffective Depth 9048' feet 9033', 9167'feet feet3518', 3539'feet3520'true vertical Measured depthPerforation depth True Vertical depth 3525' TVD9075' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth) 9033' MDPackers and SSSV (type, measured and true vertical depth) 9167' MD N/A 3518' TVD 3539' TVD N/A 13a. Prior to well operation: Subsequent to operation: West Sak Oil Pool13b. Pools active after work: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: 2215'3463' CollapseBurst D Sand Liner B Sand Liner 9778' 254' 8555' Casing 3604' 3559' 5-1/2" 9819' 9352' 3512'17722' 3419' 122'Conductor Surface Intermediate 20" 13-3/8" 79' measured TVD 9-5/8" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-038 50-029-23349-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL0025662, ADL0380058 Kuparuk River Field/ West Sak Oil Pool KRU 1J-135 Plugs measuredJunk Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 122' ~~~ ~Well Remains Shut-In ~ ~ 324-242 Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Packer: Baker Premier Packer Packer: MLZXP Liner Top packer SSSV: None Jan Byrne jan.byrne@conocophillips.com 265-6471Staff Well Interventions Specialist 9829-11845', 11847-17681' 3605-3584', 3584-3513' Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2379-3463' MD Treatment descriptions including volumes used and final pressure:Pumped Outer Annulus (OA) Cement shoe: 70 bbls 15.8 ppg Cement w/ II LCM, Final pressure 500 psi By Grace Christianson at 11:47 am, Sep 09, 2024 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.09.09 10:23:27-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 8/1/2024 REPAIR WELL OA INJECTION TEST PUMP 30 BBLS DSL DOWN OA FROM .5 BPM TO 3 BPM RECORDING T/I/O JOB COMPLETE 8/16/2024 REPAIR WELL PUMP OA CEMENT SHOE FLUSHED OA w/ 205 BBLS OF CISW. HES CEMENT PUMPED 70 BBLS OF 15.8ppg CEMENT w/ II LCM. LRS PUMPED DIESEL FREEZE PROTECT PLACING TOC @ ~2379' RKB. WAIT 72 HOURS & TURN OVER TO DHD TO CONTIUE SCLD. IN PROGRESS. 1J-135 OA Shoe Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,035.0 1J-135 2/27/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pump OA Cement Shoe 1J-135 8/16/2024 claytg Notes: General & Safety Annotation End Date Last Mod By NOTE: GLM @ 2472' RKB IS BELLY DOWN 6/18/2013 haggea NOTE: WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT 5/27/2013 osborl NOTE: MULTI-LATERAL WELL - 1J-135 (B-SAND), 1J-135L1 (D-SAND) 5/23/2007 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 20 19.25 43.7 122.2 122.2 94.00 WELDED SURFACE 13 3/8 12.41 43.6 3,462.8 2,215.4 68.00 L-80 BTC INTERMEDIATE 9 5/8 8.83 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod D-SAND WINDOW 9 5/8 8.00 9,097.0 9,107.0 3,529.8 D-SAND LINER HH 5 1/2 4.95 9,093.7 9,352.4 3,558.9 15.50 L-80 BTC-mod B-SAND LINER 5 1/2 4.95 9,167.0 17,722.5 3,512.5 15.50 L-80 BTC-Mod Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.9 Set Depth 8,989.0 Set Depth 3,510.5 String Max No 4 1/2 Tubing Description TUBING WO 2013 Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.9 23.9 0.00 HANGER 10.812 VETCO GRAY TUBING HANGER 3.958 477.9 477.9 0.60 NIPPLE 5.250 CAMCO 'DB' LANDING NIPPLE 3.875 2,471.6 1,959.3 73.39 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 7,360.3 3,214.3 76.32 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 8,931.3 3,501.2 80.72 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,932.3 3,501.3 80.72 SLEEVE - O 5.500 BAKER CMU SLIDING SLEEVE - Closed 3/29/2016 3.812 8,936.9 3,502.1 80.71 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,953.5 3,504.8 80.67 GAUGE 6.290 GUARDIAN SENSOR GAUGE CARRIER ASSEMBLY 3.960 8,969.9 3,507.4 80.64 LOCATOR 5.210 BAKER LOCATOR 4.800 8,970.5 3,507.5 80.64 SEAL ASSY 4.800 BAKER GBH-22 SEAL ASSEMBLY 4.670 Top (ftKB) 8,986.0 Set Depth 9,075.0 Set Depth 3,524.6 String Max No 5.21 Tubing Description TUBING WO 2013 Lower Wt (lb/ft) Grade L-80 Top Connection TC II ID (in) 3.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,986.0 3,510.0 80.61 SETTING SLV 5.500 'HR' LINER SETTING SLEEVE 3.812 8,999.4 3,512.2 80.59 SBE 5.210 BAKER SEAL BORE EXTENSION 3.870 9,033.3 3,517.8 80.57 PACKER 8.430 BAKER PREMIER PACKER w/ 29/32'' Ball 3.930 9,058.5 3,521.9 80.55 NIPPLE 5.250 CAMCO DB NIPPLE w/3.75" PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG 5.200 WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,048.0 3,520.2 80.56 PLUG DB PLUG AND PRONG WITH G BAITSUB. PLUG OAL = 2.19'. PRONG W/ BAITSUB OAL = 8.29'. 11/13/2023 0.000 11,100.0 3,600.9 90.01 FISH - IBP. Deeper then 11,100' Attempted to retrieve packer on 2/18-19. Run to 11,100' No indication if packer 5/27/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,471.6 1,959.3 73.39 1 GAS LIFT GLV RK 1 1/2 1,361.0 2/28/2017 0.188 7,360.3 3,214.3 76.32 2 GAS LIFT OV RK 1 1/2 0.0 2/28/2017 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,121.1 3,532.0 81.13 XO BUSHING 7.670 CROSSOVER BUSHING CPAI 4.950 9,218.1 3,545.5 83.11 ECP 7.020 BAKER PAYZONE EXTERNAL CASING PACKER Baker Isozone Payzone ECP 4.920 9,278.1 3,551.9 84.53 XO Reducing 5.500 Crossover 5 1/2" BTC-mod box x 4-1/2" BTC pin CPAI 3.940 9,167.0 3,538.8 81.93 PACKER 8.320 MLZXP LINER TOP PACKER 7.500 9,193.5 3,542.4 82.49 XO BUSHING 7.630 XO BUSHING 4.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,829.0 11,845.0 3,605.0 3,583.7 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg MULTIPLE LATERALS, 1J-135, 9/6/2024 4:57:09 PM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SHOE; 17,720.8-17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 SHOE; 9,817.3-9,819.0 COLLAR; 9,745.1-9,746.6 D-SAND LINER HH; 9,093.7- 9,352.4 LINER BENT JOINT; 9,322.0- 9,352.4 SBE; 9,194.9-9,214.6 XO BUSHING; 9,193.5-9,194.9 HANGER; 9,188.2-9,193.5 PACKER; 9,167.0-9,188.2 XO BUSHING; 9,121.1-9,122.5 HANGER; 9,114.8-9,121.1 D-SAND WINDOW; 9,097.0- 9,107.0 HANGER; 9,093.7-9,114.8 WLEG; 9,073.6 NIPPLE; 9,058.5 PLUG; 9,048.0 PACKER; 9,033.3 SBE; 8,999.4 SETTING SLV; 8,986.0 SEAL ASSY; 8,970.5 LOCATOR; 8,969.9 GAUGE; 8,953.5 PROTECTOR; 8,936.9 SLEEVE - O; 8,932.3 PROTECTOR; 8,931.3 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 Weatherford Model 303 Sure Seal Float Shoe; 3,461.2- 3,462.8 Weatherford Model 402 Sure Seal Float Collar; 3,379.5- 3,380.9 Cement Squeeze; 2,379.0 ftKB GAS LIFT; 2,471.6 NIPPLE; 477.9 CONDUCTOR Insulated 34"; 43.7-122.2 ABB Vetco Gray 18-3/16 X 12- 1/2" Casing Hanger & P; 43.6- 47.9 HANGER; 23.9 KUP PROD KB-Grd (ft) 44.00 RR Date 5/23/2007 Other Elev 1J-135 ... TD Act Btm (ftKB) 17,735.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334900 Wellbore Status PROD Max Angle & MD Incl (°) 92.54 MD (ftKB) 11,921.47 WELLNAME WELLBORE1J-135 Annotation Last WO: End Date 5/27/2013 H2S (ppm) 80 Date 9/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,847.0 17,681.0 3,583.6 3,513.2 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,379.0 3,462.8 1,933.3 2,215.4 Cement Squeeze Pumped 70 bbls of 15.8 ppg Cement w/ BridgeMaker II LCM. Displaced TOC to 2379' RKB with 142 bbls of Diesel. 8/16/2024 MULTIPLE LATERALS, 1J-135, 9/6/2024 4:57:10 PM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SHOE; 17,720.8-17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 SHOE; 9,817.3-9,819.0 COLLAR; 9,745.1-9,746.6 D-SAND LINER HH; 9,093.7- 9,352.4 LINER BENT JOINT; 9,322.0- 9,352.4 SBE; 9,194.9-9,214.6 XO BUSHING; 9,193.5-9,194.9 HANGER; 9,188.2-9,193.5 PACKER; 9,167.0-9,188.2 XO BUSHING; 9,121.1-9,122.5 HANGER; 9,114.8-9,121.1 D-SAND WINDOW; 9,097.0- 9,107.0 HANGER; 9,093.7-9,114.8 WLEG; 9,073.6 NIPPLE; 9,058.5 PLUG; 9,048.0 PACKER; 9,033.3 SBE; 8,999.4 SETTING SLV; 8,986.0 SEAL ASSY; 8,970.5 LOCATOR; 8,969.9 GAUGE; 8,953.5 PROTECTOR; 8,936.9 SLEEVE - O; 8,932.3 PROTECTOR; 8,931.3 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 Weatherford Model 303 Sure Seal Float Shoe; 3,461.2- 3,462.8 Weatherford Model 402 Sure Seal Float Collar; 3,379.5- 3,380.9 Cement Squeeze; 2,379.0 ftKB GAS LIFT; 2,471.6 NIPPLE; 477.9 CONDUCTOR Insulated 34"; 43.7-122.2 ABB Vetco Gray 18-3/16 X 12- 1/2" Casing Hanger & P; 43.6- 47.9 HANGER; 23.9 KUP PROD 1J-135 ... WELLNAME WELLBORE1J-135 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,400.0 1J-135L1 10/28/2009 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: GLV C/O, Pulled PUMP, Closed Sleeve 1J-135L1 4/8/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT 5/27/2013 osborl NOTE: MULTI-LATERAL WELL - 1J-135 (B-SAND), 1J-135L1 (D-SAND) 5/23/2007 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.48 9,308.8 17,923.0 3,420.2 11.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,308.8 3,548.0 88.18 SLEEVE 6.430 BAKER HR SETTING SLEEVE Baker HR 5.750 9,369.9 3,549.3 89.27 XO Reducing 5.730 5 1/2" Hydril 521 Box X 4 1/2" Hydril 521 Pin X/O (3.94" I.D.) CPAI 3.940 17,878.0 3,420.1 89.83 BENT JT 5.000 BENT JOINT CPAI 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,375.0 12,949.0 3,549.4 3,494.9 WS D, 1J-135L1 5/17/2007 32.0 SLOTS 2.5" Long x .125" wide, 4 circumferencial rows/ft, 3" centers, staggered, 18 deg. 12,951.0 17,878.0 3,494.9 3,420.1 WS D, 1J-135L1 5/17/2007 32.0 SLOTS 2.5" Long x .125" wide, 4 circumferencial rows/ft, 3" centers, staggered, 18 deg. MULTIPLE LATERALS, 1J-135L1, 9/6/2024 4:57:11 PM Vertical schematic (actual) D-SAND LINER; 9,308.8- 17,923.0 SHOE; 17,921.4-17,923.0 BENT JT; 17,878.0-17,921.4 SLOTS; 12,951.0-17,878.0 SLOTS; 9,375.0-12,949.0 SLEEVE; 9,308.8-9,321.5 INTERMEDIATE; 40.9-9,819.0 D-SAND LINER HH; 9,093.7- 9,352.4 HANGER; 9,093.7-9,114.8 WLEG; 9,073.6 NIPPLE; 9,058.5 PLUG; 9,048.0 PACKER; 9,033.3 SBE; 8,999.4 SETTING SLV; 8,986.0 SEAL ASSY; 8,970.5 LOCATOR; 8,969.9 GAUGE; 8,953.5 PROTECTOR; 8,936.9 SLEEVE - O; 8,932.3 PROTECTOR; 8,931.3 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 Weatherford Model 303 Sure Seal Float Shoe; 3,461.2- 3,462.8 Weatherford Model 402 Sure Seal Float Collar; 3,379.5- 3,380.9 Cement Squeeze; 2,379.0 ftKB GAS LIFT; 2,471.6 NIPPLE; 477.9 CONDUCTOR Insulated 34"; 43.7-122.2 ABB Vetco Gray 18-3/16 X 12- 1/2" Casing Hanger & P; 43.6- 47.9 HANGER; 23.9 KUP PROD KB-Grd (ft) 44.00 RR Date 5/23/2007 Other Elev 1J-135L1 ... TD Act Btm (ftKB) 17,935.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334960 Wellbore Status PROD Max Angle & MD Incl (°) 93.65 MD (ftKB) 13,201.90 WELLNAME WELLBORE1J-135 Annotation Last WO: End Date 5/27/2013 H2S (ppm) 80 Date 9/10/2016 Comment SSSV: NIPPLE 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: OA Cement Shoe 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 17735'11100' Casing Collapse Structural Conductor Surface Intermediate D Sand Liner B Sand Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-6558 Intervention Engineer KRU 1J-135 3512' 9048' 3520' 9048' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: allen.eschete@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9033' MD and 3518' TVD 9167' MD and 3539' TVD N/A Allen Eschete STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025661, ADL0025662, ADL0380058 207-038 P.O. Box 100360, Anchorage, AK 99510 50-029-23349-00-00 Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst 9075' MD 122' 2215' 3604' 122' 3463' 3559'9352' 20" 13-3/8" 79' 9-5/8"9778' 3419' 9819' 9829-11845', 11847-17681' 254' 5-1/2" 3605-3584', 3584-3513' 5-1/2" Perforation Depth TVD (ft): 5/15/2024 17722'8555' 4-1/2" 3512' Packer: Baker Premier Packer Packer: MLZXP Liner TP Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:39 pm, Apr 23, 2024 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.04.23 13:44:47-08'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete 324-242 VTL 6/24/2024 DSR-4/23/24 10-404 A.Dewhurst 24JUN24 X *&:JLC 6/24/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.24 15:22:47 -08'00'06/24/24 RBDMS JSB 062624 1J-135 OA Shoe Procedure Date: 3/19/2024 Network Number: 10452915 Prepared by: Allen Eschete 661-348-2949 _________________________ Approved by: Erica Livingston 907-265-1588 _________________________ Contents Contents ........................................................................................................................................................ 1 Objective ....................................................................................................................................................... 1 Job Design Data ............................................................................................................................................. 1 Risk/Job Concerns: ................................................................................................................................... 1 Design Envelope: ...................................................................................................................................... 1 Volumes: ................................................................................................................................................... 1 OA Shoe Cement ........................................................................................................................................... 2 Appendix ....................................................................................................................................................... 3 1 Objective 1J-135 has a surface casing leak as well as an open OA shoe. The open shoe allows fluid to flow back into the OA while doing diagnostics to determine the depth of the surface casing leak. The goal of this job is to pump a competent OA shoe so the surface casing leak diagnostics can be performed. Job Design Data RRisk/Job Concerns: x This job requires a 10-403 and a 10-404. x OA x ATM x LOT @ 3493' RKB (2224’ TVD) from 4/18/07 shows 12.9 ppg EMW = 1491 psi. x Surface casing = 3462' RKB = 2215' TVD x 11/14/23: Passed CMIT and passed MITT x 11/12/23: well secured with DPB plug at 9058'. x 5/20/23: SCLD, ~400 psi returns, OA-FL at 24'. Pressured to 600 psi and OA-FL at 42'. x 5/19/23: SCLD, Returns to conductor seen between 300-500 psi. 24'-36', FTS when bleeding OA. x 5/18/23: SCLD, inject N2, see dripping at 400 psi. 24'-30'. FTS when bleeding OA. x 4/23/07: Flushed OA with 230 bbls water at 2BPM at 600 psi. x 13-3/8" 68#/ft L80 Yield Rating = 5,020 psi @ 80% = 4016 psi x 9-5/8" 40#/ft L80 Collapse Rating = 3,090 psi @ 80% = 2472 psi x IA liquid packed with diesel to 2493’ RKB (1965’ TVD) and 1% CISW from 2493’ RKB – 9033’ RKB (1965’ TVD – 3518’ TVD). x IA hydrostatic @ surface casing shoe = 806 psi. Design Envelope: Surface Casing: 13-3/8”, 68.0 #/ft, L-80, Internal Yield Rating = 5,020 psi = 4016 psi @ 80%. Intermediate Casing: 9-5/8, 40.0 #/ft, L-80: Collapse Rating = 3,090 psi = 2472 psi @ 80% Volumes: OA Volume= (0.0597 bbl/ft x 3462.8’ RKB) = 206.7 bbls Cement Volume = (0.0597 bbl/ft x 1000’ RKB) + 10 bbls = 69.7 bbls Diesel FP, to 2000’ TVD = 2613’ RKB = (0.0597 x 2613’ RKB) = 156 bbls ***Unable to pump full amount due to cement/OA volume. 2 OA Shoe Cement AOGCC 10-403 and 10-404 Sundry are required for pumping an OA Shoe. 1. Vac truck needed to handle potential returns to surface in catch drum/conductor. 2. Pressure up IA to at least 1500 psi. 3. RU hardline to OA with ability to divert to tank to flush lines post job. 4. RU cementers. 5. Pump 30 bbls of warm diesel (step rates from 0.5 – 3.0 bpm in 0.5 bpm increments) a. Record Rates/Pressures in WSR. b. Do not exceed 2500 psi. 6. Pump 205 bbls (~1 OA volume) of warm seawater to flush OA. a. Do not exceed 2500 psi. 7. Pump 30 bbls of fresh water spacer. a. Do not exceed 2500 psi. 8. Pump 5 bbls of neat cement. a. Do not exceed 2500 psi. 9. Pump 65 bbls of cement with 5 lb/bbl LCM. a. Do not exceed 2000 psi. 10. Pump 5 bbls of corrosion inhibited fresh water spacer. a. Do not exceed 2000 psi. 11. Pump 142 bbls of diesel to displace the cement and freeze protect the OA. a. Slow rate to 1 BPM @ 131 bbls of displacement (1 bbl before cement gets to formation). b. Slow rate to 0.5 BPM @ 136 bbls of displacement (1 bbl before LCM loaded cement gets to formation). c. Do not exceed 2000 psi. 12. Shut down pumps @ 142 bbls of displacement. a. Do not pump more than 142 bbls of total displacement. b. If squeeze pressure develops and builds to 500 psi over treating pressure with cement at the shoe, Shutdown pumps, SI the OA, and trap the OA pressure. c. If squeeze pressure begins to climb rapidly, prior to cement reaching the shoe, swap to diesel to Freeze Protect as much of the OA as possible before we pressure out. 13. Do not bleed the OA. 14. Estimated TOC in OA is 2379’ RKB (assuming 10 bbls squeezed (5bbls neat + 5 bbls with LCM). 15. Send OA cement shoe field blend UCA results to allen.eschete@conocophillips.com 16. After WOC for 72 hours, turn well over to DHD crew to perform SCLD. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,035.0 1J-135 2/27/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DB plug & prong 1J-135 11/13/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: GLM @ 2472' RKB IS BELLY DOWN 6/18/2013 haggea NOTE: WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT 5/27/2013 osborl NOTE: MULTI-LATERAL WELL - 1J-135 (B-SAND), 1J-135L1 (D-SAND) 5/23/2007 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 20 19.25 43.7 122.2 122.2 94.00 WELDED SURFACE 13 3/8 12.41 43.6 3,462.8 2,215.4 68.00 L-80 BTC INTERMEDIATE 9 5/8 8.83 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod D-SAND WINDOW 9 5/8 8.00 9,097.0 9,107.0 3,529.8 D-SAND LINER HH 5 1/2 4.95 9,093.7 9,352.4 3,558.9 15.50 L-80 BTC-mod B-SAND LINER 5 1/2 4.95 9,167.0 17,722.5 3,512.5 15.50 L-80 BTC-Mod Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.9 Set Depth … 8,989.0 Set Depth … 3,510.5 String Max No… 4 1/2 Tubing Description TUBING WO 2013 Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.9 23.9 0.00 HANGER 10.812 VETCO GRAY TUBING HANGER 3.958 477.9 477.9 0.60 NIPPLE 5.250 CAMCO 'DB' LANDING NIPPLE 3.875 2,471.6 1,959.3 73.39 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 7,360.3 3,214.3 76.32 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 8,931.3 3,501.2 80.72 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,932.3 3,501.3 80.72 SLEEVE - O 5.500 BAKER CMU SLIDING SLEEVE - Closed 3/29/2016 3.812 8,936.9 3,502.1 80.71 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,953.5 3,504.8 80.67 GAUGE 6.290 GUARDIAN SENSOR GAUGE CARRIER ASSEMBLY 3.960 8,969.9 3,507.4 80.64 LOCATOR 5.210 BAKER LOCATOR 4.800 8,970.5 3,507.5 80.64 SEAL ASSY 4.800 BAKER GBH-22 SEAL ASSEMBLY 4.670 Top (ftKB) 8,986.0 Set Depth … 9,075.0 Set Depth … 3,524.6 String Max No… 5.21 Tubing Description TUBING WO 2013 Lower Wt (lb/ft) Grade L-80 Top Connection TC II ID (in) 3.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,986.0 3,510.0 80.61 SETTING SLV 5.500 'HR' LINER SETTING SLEEVE 3.812 8,999.4 3,512.2 80.59 SBE 5.210 BAKER SEAL BORE EXTENSION 3.870 9,033.3 3,517.8 80.57 PACKER 8.430 BAKER PREMIER PACKER w/ 29/32'' Ball 3.930 9,058.5 3,521.9 80.55 NIPPLE 5.250 CAMCO DB NIPPLE w/3.75" PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG 5.200 WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,048.0 3,520.2 80.56 PLUG DB PLUG AND PRONG WITH G BAITSUB. PLUG OAL = 2.19'. PRONG W/ BAITSUB OAL = 8.29'. 11/13/2023 0.000 11,100.0 3,600.9 90.01 FISH - IBP. Deeper then 11,100' Attempted to retrieve packer on 2/18-19. Run to 11,100' No indication if packer 5/27/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,471.6 1,959.3 73.39 1 GAS LIFT GLV RK 1 1/2 1,361.0 2/28/2017 0.188 7,360.3 3,214.3 76.32 2 GAS LIFT OV RK 1 1/2 0.0 2/28/2017 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,121.1 3,532.0 81.13 XO BUSHING 7.670 CROSSOVER BUSHING CPAI 4.950 9,218.1 3,545.5 83.11 ECP 7.020 BAKER PAYZONE EXTERNAL CASING PACKER Baker Isozone Payzone ECP 4.920 9,278.1 3,551.9 84.53 XO Reducing 5.500 Crossover 5 1/2" BTC-mod box x 4-1/2" BTC pin CPAI 3.940 9,167.0 3,538.8 81.93 PACKER 8.320 MLZXP LINER TOP PACKER 7.500 9,193.5 3,542.4 82.49 XO BUSHING 7.630 XO BUSHING 4.950 MULTIPLE LATERALS, 1J-135, 4/23/2024 1:20:43 PM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 D-SAND LINER HH; 9,093.7- 9,352.4 D-SAND WINDOW; 9,097.0- 9,107.0 PLUG; 9,048.0 PACKER; 9,033.3 GAUGE; 8,953.5 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 GAS LIFT; 2,471.6 CONDUCTOR Insulated 34"; 43.7-122.2 KUP PROD KB-Grd (ft) 44.00 RR Date 5/23/2007 Other Elev… 1J-135 ... TD Act Btm (ftKB) 17,735.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334900 Wellbore Status PROD Max Angle & MD Incl (°) 92.54 MD (ftKB) 11,921.47 WELLNAME WELLBORE1J-135 Annotation Last WO: End Date 5/27/2013 H2S (ppm) 80 Date 9/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,829.0 11,845.0 3,605.0 3,583.7 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg 11,847.0 17,681.0 3,583.6 3,513.2 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg MULTIPLE LATERALS, 1J-135, 4/23/2024 1:20:43 PM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 D-SAND LINER HH; 9,093.7- 9,352.4 D-SAND WINDOW; 9,097.0- 9,107.0 PLUG; 9,048.0 PACKER; 9,033.3 GAUGE; 8,953.5 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 GAS LIFT; 2,471.6 CONDUCTOR Insulated 34"; 43.7-122.2 KUP PROD 1J-135 ... WELLNAME WELLBORE1J-135 From:Byrne, Jan To:Loepp, Victoria T (OGC) Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]KRU 1J-135 (PTD 207-038, Sundry 324-242) OA Shoe cement Date:Friday, June 21, 2024 12:55:44 PM Some people who received this message don't often get email from jan.byrne@conocophillips.com. Learn why this is important Victoria, To answer your questions. 1. The surface casing leak is known to be shallower than ~30’ based on previous Surface Casing Leak Detects. Due to the open shoe the fluid level moved during the string lining process (confirmation of the echo meter shots), but it repeated multiple times at ~24’ with the max being ~30’. All depths that can be reached by excavation. Once an OA cement shoe has been pumped, we plan to repeat the SCLD to pinpoint the surface casing leak depth and then move toward excavation and repair subsequent sundry approval. 2. Based off the previous SCLD diagnostics an excavation and sleeve repair will be utilized to repair the shallow damage. 3. Our view is the Ugnu oil is immobile and will not escape its interval due to cold reservoir temperatures, low API, and high viscosities. Additionally, if it is water, it is not a hydrocarbon zone that requires covering nor must it be protected due to the aquifer exemption in place. 4. The OA fluids are currently diesel to ~1816’MD/1665’TVD and fresh water below that depth to the surface casing TD. Please let me know if you need further clarification or have additional questions. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, June 11, 2024 10:54 AM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]KRU 1J-135 (PTD 207-038, Sundry 324-242) OA Shoe cement Jan, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thank you for the information. 1. Do you have an idea of where the surface casing leak is? Shallow or deep? 2. What options are available to repair the surface casing leak depending on location? 3. Further explain why uncemented Ugnu is not a concern. 4. What is the fluid in the OA? Thank you, Victoria From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, May 23, 2024 12:02 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]KRU 1J-135 (PTD 207-038, Sundry 324-242) OA Shoe cement Victoria, Sorry for the delay in response. We’ve had some changes in our group- Allen moved to a WSC Operations position and I will begin working CPF1 Interventions. For 1J-135 Intermediate casing cement we are calculating Top of Cement at 7718’ MD / 3294’ TVD. This was calculated with 25% wash out. No losses were reported (I’ve attached the cementing data from the report) The schematic showing intermediate casing cement and hydrocarbon bearing zones is attached. Of note a portion of the Ugnu is above calculated TOC, but the Ugnu is immobile and not considered a concern. Please let me know if you need any additional information. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, May 8, 2024 11:26 AM To: Eschete, Allen <Allen.Eschete@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]KRU 1J-135 (PTD 207-038, Sundry 324-242) OA Shoe cement CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Allen, Please provide a WBS showing intermediate casing cement and hydrocarbon bearing zones. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1J-135 20” 94# L-80 Conductor at 122' MD/ 122' TVD 9.625" 40# L-80 Intermediate at 9819' MD/ 3604' TVD 4-½” 12.6# L-80 Tubing at 9075' MD/ 3524' TVD 13-3/8" 68# L-80 Surface Casing at 3462' MD/ 2215' TVD Slots: 9829' – 17,681' MD/ 3513' - 3605' TVD Calculated Top of Cement at 7781'' MD/ 3294' TVD 9.625" x OH (12.25") + 25% for washout Ugnu Interval HC Depths 7387' -7424' MD/ 3220'- 3229' TVD 7462' -7559' MD/ 3238' - 3260' TVD 7610' - 7789' MD/ 3271' - 3310' TVD Ugnu Interval HC Depths 7387' -7424' MD/ 3220'- 3229' TVD 7462' -7559' MD/ 3238' - 3260' TVD 7610' - 7789' MD/ 3271' - 3310' TVD West Sak HC Depths 9106'- 9489' MD 3535' - 3571' TVD 9772' MD/ 3600' TVD (Landed in WSAK B). West Sak HC Depths 9106'- 9489' MD 3535' - 3571' TVD 9772' MD/ 3600' TVD (Landed in WSAK B). 5-½” 15.5# L-80 B-Sand Liner at 17,722' MD/ 3512' TVD Nipple at 478' GLM at 2471' GLM at 7360' Packer at 9033' MD/ 3518' TVD Sleeve –O 8932' MD/ 3501' TVD MLZXP Liner Top Packer at 9167''MD/ 3539' TVD N interval HC Depths 8038' - 8103' MD. 3356' - 3369' TVD. 8855' - 8893' MD. 3409' - 3495'. N interval HC Depths 8038' - 8103' MD. 3356' - 3369' TVD. 8855' - 8893' MD. 3409' - 3495'. 1J-135 Cement Calcs 9.625" Intermediate casing set at 9819' MD/3604' TVD 12.25" Intermediate hole 12.25" x 1.25= 15.3125" (added 25% for wash out) 15.3125²- 9.625²/ 1029.4=0.137779 bb/ft 289.5 bbls/ 0.137779 = 2101' of cement 9819'- 2101' Intermediate cement TD- cement column= TOC= 7718' MD/3294' TVD 1J-135 Cementing information from drilling report 4/22/2007 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: SC Repair 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: KUPARUK RIVER N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 17735'11100' Casing Collapse Conductor Surface Intermediate D Sand Liner B Sand Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Brennen Green / Roger Mouser Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Preimer: 9033' MD / 3518 TVD; MLZXP: 9167' MD / 3539' TVD KUPARUK RIV U WSAK 1J-135N/A WEST SAK OIL 3512'9048' BAKER PAYZONE EXTERNAL SSSV - Camco DB Landing Nipple SSSV-478' Payzone: 9218' MD / 3545' TVD Subsequent Form Required: Suspension Expiration Date: n1927@conocophillips.com 907-659-7506 W.I. Field Superviosor BAKER PREMIER / MLZXP LINER TOP Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025661 / ADL0025662 / ADL0380058 207-038 PO Box 100360. Anchorage, Alaska 99510 500292334900-00 ConocoPhillips Alaska, Inc. Proposed Pools: TVD Burst 8989' MD 122' 2215' 3604' 3463' 3559'5 1/2'9352' 9819' 122'78'20" 13 3/8" 9 5/8'9778' 3418' 9,829'-17,681' 254' 5 1/2" 3,605'-3,513' 2/1/2024 17722'8555' 4 1/2" 3512' L-80 m n P 66 t r N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2023.11.17 16:46:27-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green 323-641 By Grace Christianson (grace.christianson@alaska.gov) at 8:20 am, Nov 27, 2023 DSR-11/29/23SFD 12/26/2023 50-029-23349-00-00 SFD VTL 01/04/2024 10-404X Photo documentation of all steps of the repair required *&:JLC 1/4/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.04 13:53:48 -09'00'01/04/24 RBDMS JSB 010924 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 17, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well, KRU 1J-135 (PTD 207-038), to repair the Surface Casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.11.17 16:45:47-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. KUPARUK WELL 1J-135 (PTD 207-038) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 17, 2023 This application for Sundry approval for Kuparuk well 1J-135 is for the inspection and repair of a leak in the Surface Casing. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the suspected Surface Casing leak. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in the tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate well. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,035.0 1J-135 2/27/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DB plug & prong 1J-135 11/13/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: GLM @ 2472' RKB IS BELLY DOWN 6/18/2013 haggea NOTE: WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT 5/27/2013 osborl NOTE: MULTI-LATERAL WELL - 1J-135 (B-SAND), 1J-135L1 (D-SAND) 5/23/2007 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 20 19.25 43.7 122.2 122.2 94.00 WELDED SURFACE 13 3/8 12.41 43.6 3,462.8 2,215.4 68.00 L-80 BTC INTERMEDIATE 9 5/8 8.83 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod D-SAND WINDOW 9 5/8 8.00 9,097.0 9,107.0 3,529.8 D-SAND LINER HH 5 1/2 4.95 9,093.7 9,352.4 3,558.9 15.50 L-80 BTC-mod B-SAND LINER 5 1/2 4.95 9,167.0 17,722.5 3,512.5 15.50 L-80 BTC-Mod Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.9 Set Depth … 8,989.0 Set Depth … 3,510.5 String Max No… 4 1/2 Tubing Description TUBING WO 2013 Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.9 23.9 0.00 HANGER 10.812 VETCO GRAY TUBING HANGER 3.958 477.9 477.9 0.60 NIPPLE 5.250 CAMCO 'DB' LANDING NIPPLE 3.875 2,471.6 1,959.3 73.39 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 7,360.3 3,214.3 76.32 GAS LIFT 7.031 GLM 4 1/2'' x 1.5'' MMG CAMCO MMG 3.958 8,931.3 3,501.2 80.72 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,932.3 3,501.3 80.72 SLEEVE - O 5.500 BAKER CMU SLIDING SLEEVE - Closed 3/29/2016 3.812 8,936.9 3,502.1 80.71 PROTECTOR 5.960 FLUTED WIRE PROTECTOR SUB 3.910 8,953.5 3,504.8 80.67 GAUGE 6.290 GUARDIAN SENSOR GAUGE CARRIER ASSEMBLY 3.960 8,969.9 3,507.4 80.64 LOCATOR 5.210 BAKER LOCATOR 4.800 8,970.5 3,507.5 80.64 SEAL ASSY 4.800 BAKER GBH-22 SEAL ASSEMBLY 4.670 Top (ftKB) 8,986.0 Set Depth … 9,075.0 Set Depth … 3,524.6 String Max No… 5.21 Tubing Description TUBING WO 2013 Lower Wt (lb/ft) Grade L-80 Top Connection TC II ID (in) 3.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,986.0 3,510.0 80.61 SETTING SLV 5.500 'HR' LINER SETTING SLEEVE 3.812 8,999.4 3,512.2 80.59 SBE 5.210 BAKER SEAL BORE EXTENSION 3.870 9,033.3 3,517.8 80.57 PACKER 8.430 BAKER PREMIER PACKER w/ 29/32'' Ball 3.930 9,058.5 3,521.9 80.55 NIPPLE 5.250 CAMCO DB NIPPLE w/3.75" PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG 5.200 WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,048.0 3,520.2 80.56 PLUG DB PLUG AND PRONG WITH G BAITSUB. PLUG OAL = 2.19'. PRONG W/ BAITSUB OAL = 8.29'. 11/13/2023 0.000 11,100.0 3,600.9 90.01 FISH - IBP. Deeper then 11,100' Attempted to retrieve packer on 2/18-19. Run to 11,100' No indication if packer 5/27/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,471.6 1,959.3 73.39 1 GAS LIFT GLV RK 1 1/2 1,361.0 2/28/2017 0.188 7,360.3 3,214.3 76.32 2 GAS LIFT OV RK 1 1/2 0.0 2/28/2017 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,121.1 3,532.0 81.13 XO BUSHING 7.670 CROSSOVER BUSHING CPAI 4.950 9,218.1 3,545.5 83.11 ECP 7.020 BAKER PAYZONE EXTERNAL CASING PACKER Baker Isozone Payzone ECP 4.920 9,278.1 3,551.9 84.53 XO Reducing 5.500 Crossover 5 1/2" BTC-mod box x 4-1/2" BTC pin CPAI 3.940 9,167.0 3,538.8 81.93 PACKER 8.320 MLZXP LINER TOP PACKER 7.500 9,193.5 3,542.4 82.49 XO BUSHING 7.630 XO BUSHING 4.950 MULTIPLE LATERALS, 1J-135, 11/16/2023 5:18:12 AM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SHOE; 17,720.8-17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 SHOE; 9,817.3-9,819.0 COLLAR; 9,745.1-9,746.6 D-SAND LINER HH; 9,093.7- 9,352.4 LINER BENT JOINT; 9,322.0- 9,352.4 SBE; 9,194.9-9,214.6 XO BUSHING; 9,193.5-9,194.9 HANGER; 9,188.2-9,193.5 PACKER; 9,167.0-9,188.2 XO BUSHING; 9,121.1-9,122.5 HANGER; 9,114.8-9,121.1 D-SAND WINDOW; 9,097.0- 9,107.0 HANGER; 9,093.7-9,114.8 WLEG; 9,073.6 NIPPLE; 9,058.5 PLUG; 9,048.0 PACKER; 9,033.3 SBE; 8,999.4 SETTING SLV; 8,986.0 SEAL ASSY; 8,970.5 LOCATOR; 8,969.9 GAUGE; 8,953.5 PROTECTOR; 8,936.9 SLEEVE - O; 8,932.3 PROTECTOR; 8,931.3 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 Weatherford Model 303 Sure Seal Float Shoe; 3,461.2- 3,462.8 Weatherford Model 402 Sure Seal Float Collar; 3,379.5- 3,380.9 GAS LIFT; 2,471.6 NIPPLE; 477.9 CONDUCTOR Insulated 34"; 43.7-122.2 ABB Vetco Gray 18-3/16 X 12- 1/2" Casing Hanger & P; 43.6- 47.9 HANGER; 23.9 KUP PROD KB-Grd (ft) 44.00 RR Date 5/23/2007 Other Elev… 1J-135 ... TD Act Btm (ftKB) 17,735.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334900 Wellbore Status PROD Max Angle & MD Incl (°) 92.54 MD (ftKB) 11,921.47 WELLNAME WELLBORE1J-135 Annotation Last WO: End Date 5/27/2013 H2S (ppm) 80 Date 9/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,829.0 11,845.0 3,605.0 3,583.7 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg 11,847.0 17,681.0 3,583.6 3,513.2 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg MULTIPLE LATERALS, 1J-135, 11/16/2023 5:18:13 AM Vertical schematic (actual) B-SAND LINER; 9,167.0- 17,722.5 SHOE; 17,720.8-17,722.5 SLOTS; 11,847.0-17,681.0 FISH - IBP. Deeper then 11,100'; 11,100.0 SLOTS; 9,829.0-11,845.0 INTERMEDIATE; 40.9-9,819.0 SHOE; 9,817.3-9,819.0 COLLAR; 9,745.1-9,746.6 D-SAND LINER HH; 9,093.7- 9,352.4 LINER BENT JOINT; 9,322.0- 9,352.4 SBE; 9,194.9-9,214.6 XO BUSHING; 9,193.5-9,194.9 HANGER; 9,188.2-9,193.5 PACKER; 9,167.0-9,188.2 XO BUSHING; 9,121.1-9,122.5 HANGER; 9,114.8-9,121.1 D-SAND WINDOW; 9,097.0- 9,107.0 HANGER; 9,093.7-9,114.8 WLEG; 9,073.6 NIPPLE; 9,058.5 PLUG; 9,048.0 PACKER; 9,033.3 SBE; 8,999.4 SETTING SLV; 8,986.0 SEAL ASSY; 8,970.5 LOCATOR; 8,969.9 GAUGE; 8,953.5 PROTECTOR; 8,936.9 SLEEVE - O; 8,932.3 PROTECTOR; 8,931.3 GAS LIFT; 7,360.3 SURFACE; 43.6-3,462.8 Weatherford Model 303 Sure Seal Float Shoe; 3,461.2- 3,462.8 Weatherford Model 402 Sure Seal Float Collar; 3,379.5- 3,380.9 GAS LIFT; 2,471.6 NIPPLE; 477.9 CONDUCTOR Insulated 34"; 43.7-122.2 ABB Vetco Gray 18-3/16 X 12- 1/2" Casing Hanger & P; 43.6- 47.9 HANGER; 23.9 KUP PROD 1J-135 ... WELLNAME WELLBORE1J-135 STATE OF ALASKA AL.OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing E Operations Shutdown E Performed: Suspend r Perforate E Other Stimulate n Alter Casing E Change Approved Program Plug for Redrill n Perforate New Pool r Repair Well E Re-enter Susp Well E Other: Crystal Seal Trtment l" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Evloratory 207-038 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic "', Service f- 50-029-23349-00 7.Property Designation(Lease Number): ' 8.Well Name and Number: ADL 25661,ADL 25662,ADL 380058 KRU 1J-135 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 17735 feet Plugs(measured) None true vertical 3512 feet Junk(measured) None Effective Depth measured 17720 feet Packer(measured) 0 true vertical 3512 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 122 122 SURFACE 3419 13 3/8 3463 2215 INTERMEDIATE 9778 9 5/8 9819 3604 B-SAND LINER 8556 5 1/2 17723 3513 RECF NOV 16 2016 Perforation depth: Measured depth: 9829-11845, 11847-17681 True Vertical Depth: 3605-3584, 3584-3513 34J0 C Tubing(size,grade,MD,and TVD) 4.5 x 5.5, L-80, 9075 MD, 3525 ND Packers&SSSV(type,MD,and TVD) PACKER=BAKER Premier Packer @ 9033 MD and 3518 ND PACKER=MLZXP Liner Top Packer @ 9167 MD and 3539 ND NONE-Type Not Found(Manual Entry Required)@ 0 MD and 0 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): p pp 31 r :i.r Treatment descriptions including volumes used and final pressure: S NNEU `.. .. 2 20 l f 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation Shut-In 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development € Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data fl GSTOR E WINJ r WAG r GINJ rSUSP E SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-765 Contact John Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date i i/16, j j ,� Vr` 312ss1/� Form 10-404 Revised 5/2 15 RB®MS 0�N a� Submit Original Only 1ew 1J• 36 to 1J-135 • DTTMS.JOBTYP SUMMARYOPS 2/2/16 MECH RIH WITH HES TCP PERFORATING GUNS, FIRE GUNS FROM TOP SHOT AT ZONE MOD 10,625' TO BOTTOM SHOT AT 10630' CTMD, 6 SPF, PERFORM INJECTIVITY TEST THROUGH CT AT 2 BPM (120 WHP), F/P TBG TO 2500', AT SURFACE IT IS DICOVERED THAT THE INJECTOR CHAINS ARE WORN AND NEED TO BE CHANGED, RIG DOWN CTU FOR INJECTOR SWAP IN DEADHORSE, JOB IN PROGRESS. 2/3/16 MECH TAKE CTU TO DEADHORE TO REPAIR INJECTOR, JOB IN PROGRESS. ZONE MOD 2/4/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/5/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/6/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/7/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/8/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 4/28/16 MISC. CAPACITY B&C CTU#1: PERFORM MBE TREATMENT DOWN COIL TUBING WITH NOZZLE SUSTAINMENT PARKED ABOVE SLOTTED LINER AT 9700'. PUMP 420 BBLS OF SEA WATER WITH 4510#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF -1000 PSI. WELL LEFT SHUT IN AND FREEZE PROTECTED. WILL RETURN IN THE MORNING FOR FCO. 4/29/16 MISC. CAPACITY B&C CTU#1: PERFORM F&S FILL CLEAN OUT FROM CRYSTAL SEAL TAG AT SUSTAINMENT 9780'TO COIL LOCKUP AT 13645'WITH SLICK SEA WATER AND DJN. WELL LEFT SHUT IN AND FREEZE PROTECTED. TREATMENT COMPLETE. KUP PPD 1J-135 ConocoP'hiH ips b ; Well Attribut Max Angle TD • Alaska.Inc pryWellbore APIIUWI Field Name Wellbore StatusIncl(°) MD(ftKB) Act Btm(ftKB) Gp Ps 500292334900 WEST SAK PROD f 92.54 11,921.47 17,735.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-1J135,11/16/20166:40:53 AM SSSV:NIPPLE 25 12/21/2015 Last WO: 5/27/2013 44.00 5/23/2007 Vertical schematic.(sable° Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,23.9 (..::•..„.:T.,.:..•!..• qua_ - Last Tag:SLM 7,400.0 10/29/2009 Rev Reason:GLV C/O pproven 5/29/2016 Casing Stnngs •' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 20 19.250 43.7 122.2 122.2 94.00 WELDED • Insulated 34 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread a ;` SURFACE 13 3/8 12.415 43-6 3,462.8 2,215.4 68.00 L-80 ETC I I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread INTERMEDIATE 9 5/8 8.835 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND WINDOW 95/8 8.000 9,097.0 9,107.0 3,529.8 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread D-SAND LINER HH 5 1/2 4.950 9,093.7 9,352.4 3,558.9 15.50 L-80 BTC-mod CONDUCTOR Insulated 34•, Liner Details 43.7-122.2 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;4 9 _ 9,093.7 3,527.7 80.65 HANGER BAKER MODEL'B-1'HOOK HANAGER 9 5/8"x 7.470 7"(Inside csg) T 9,114.8 3,531.1 81.02 HANGER BAKER MODEL'B-1'HOOK HANGER 9 5/8"x 6.290 7"(Outside csg) 9,121.1 3,532.0 81.13 XO BUSHING CROSSOVER BUSHING 4.950 GAS LIFT,2,471.8 F, '` 9,218.1 3,545.5 83.11 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.920 9,278.1 3,551.9 84.53 XO Reducing Crossover 5 1/2"BTC-mod box x 4-1/2"BTC pin 3.940 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread B-SAND LINER 51/2 4.950 9,167.0 17,722.5 3,512.5 15.50 L-80 BTC-Mod SURFACE,43.6-3,462.8-- , Liner Details Nominal ID 1 Ili Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT,7,360.3 9,167.0 3,538.8 81.93 PACKER MLZXP LINER TOP PACKER 7.500 9,188.2 3,541.7 82.36 HANGER FLEXLOCK LINER HANGER 6.090 9,193.5 3,542.4 82.49 XO BUSHING XO BUSHING 4.950 9,194.9 3,542.6 82.53 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 2013 4 1/2 3.960 23.9 8,989.0 3,510.5 12.60 L-80 )BTM Upper • Completion Details Nominal ID Top(ftKB) Top(ND)IRKS) Top Incl(°) Item Des Com (in) ini:....:.......:... 23.9 23.9 0.00 HANGER VETCO GRAY TUBING HANGER 3.958 477.9 477.9 0.60 NIPPLE CAMCO'DB'LANDING NIPPLE 3.875 • 8,931.3 3,501.2 80.72 PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 PROTECTOR;893/.3 8,932.3 3,501.3 80.72 SLEEVE-0 BAKER CMU SLIDING SLEEVE-Closed 3/29/2016 3.812 SLEEVE-O;8,932.3 PROTECTOR;8,936.9 +i1 8,936.9 3,502.1 80.71 PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 ._'i 8,953.5 3,504.8 80.67 GAUGE GUARDIAN SENSOR GAUGE CARRIER ASSEMBLY 3.960 GAUGE,8,953.5 i 8,969.9 3,507.4 80.64 LOCATOR BAKER LOCATOR 4.800 LOCATOR;8,969.9 8,970.5 3,507.5 80.64 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 4.670 SEAL ASSY;8,970.5 -- .1 Tubing Description 'String Ma...1 ID(in) 'Top(ftKB) Set Depth(tt..J Sot Depth(ND)(...IWI(Ib/ft) I Grade I Top Connection SETTING SLV,8,986.0 e=1 TUBING WO 2013 5.21 3.870 8,986.0 9,075.01 3,524.6 L-80 TC II Ani Lower SBE;8,999.4 Completion Details. l Nominal ID ME Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) PACKER;9,033.3 8,986.0 3,510.0 80.61 SETTING SLV'''HR'LINER SETTING SLEEVE 3.812 IL NIPPLE;9,056.5 - 8,999.4 3,512.2 80.59 SBE BAKER SEAL BORE EXTENSION 3.870 lir 9,033.3 3,517.8 80.57 PACKER BAKER PREMIER PACKER w/29/32"Ball 3.930 MB WLEG;9,073.6 in 9,058.5 3,521.9 80.55 NIPPLE CAMCO DB NIPPLE w/3.75"PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG WIRELINE ENTRY GUIDE 4.000 D-SAND WINDOW,9,097.0- Perforations&Slots 8,107.0 Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date ft) Type Com 9,829.0 11,845.0 3,605.0 3,583.7 WS B,tJ-135 4/30/2007 32.0 SLOTS 2.5"long X.125"wide,4 circumferencial rows/ft, 3"centers staggered 18 I deg 11,847.0 17,681.0 3,583.6 3,513.2 WS B,1J-135 4/30/2007 32.0 SLOTS 2.5"long X.125"wide,4 circumferencial rows/ft, si 3"centers staggered 18 deg 1 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,471.6 1,959.3 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,341.0 5/26/2016 D-SAND LINER HH,9,093.7- 2 7,360.3 3,214.3-CAMCO MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 5/26/2016 9352.4 Notes:General&Safety End Date Annotation 5/23/2007 NOTE: MULTI-LATERAL WELL-1J-135(B-SAND),1J-135L1(D-SAND) INTERMEDIATE;40.9-9,819.0 • 3/18/2008 NOTE:WORKOVER SLOTS;9,829.0-11645.0 ! 8/9/2008 NOTE:View Schematic wl Alaska Schematic9.OREV 2/9/2010 NOTE:WORKOVER SLOTS;11,8470-17,681 0 i 5/27/2013 NOTE:WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT . I 6/18/2013 NOTE:GLM @ 2472'RKB IS BELLY DOWN B-SAND LINER,9,167.0- 17.722 5.s. - 17722.5 ,, oF7 • • ew���\I%%�s, THE STATE Alaska Oil and Gas A °f Conservation Commissi®n it., LAsKAL tWri� 333 West Seventh Avenue ~ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O %11:;41‘P.- P Main: 907.279.1433 ALASY� Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, LLC P.O. Box 100360 SCANNED FEB6 201 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, WSAK 1J-135 Permit to Drill Number: 207-038 Sundry Number: 315-765 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /77-44.-1511- Cathy . Foerster Chair DATED this Aay of January, 2016. L RBDMS JAN 1 12016 m � • STATE OF ALASKA 1110 -,:r, �a ALASKA OIL AND GAS CONSERVATION COMMISSION ' �� APPLICATION FOR SUNDRY APPROVALS ��OG ` 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate E Repair Well E Operations Shutdown 1"-- Suspend Suspend fl Perforate I- Other Stimulate E Pull Tubing E Change Approved Program Plug for Redrill fl Perforate New Pool E Re-enter Susp Well n Alter Casing E Other: Crystal Spa! F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc.• Exploratory tT Development F 207-038 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service I- 50-029-23349-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a • Will planned perforations require a spacing exception? Yes r No ✓ WSAK 1J-135 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,25662, 380058 , Kuparul River Pool/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,735' 3,512' • ' 17720 3512 - 1400 None None Casing Length Size MD ND Burst Collapse Structural Conductor 78' 20" 122' 122' Surface 3,419' 13" 3,463' 2,215' Intermediate 9,778' 10" 9,819' 3,604' Production B Liner 8,555' 5.5 17,723' 3,513' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9829-11845, 11847-17681 . 3605-3584,3584-3513 4.5 L-80 9,075' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): MLZXP Liner Top Packer,Baker Premier Packer 9167=MD,3538=TVD,9033=MD,3517=TVD SSSV: Nipple 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic E Development F 'Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/20/2016 OIL F - WINJ I— WDSPL Suspended 16.Verbal Approval: Date: GAS E WAG E GSTOR E SPLUG Commission Representative: GINJ E Op Shutdown Abandoned r" 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce Email John.W.Peirce(a conocophillips.com Printed Name John Peirce@265-6471 Title Sr.Wells Engineer irt,f:)Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316-146 Plug Integrity El BOP Test El Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 0 No Er Subsequent Form Required: APPROVED BY / // Approved by: U ,92,tCOMMISSIONER TH� MISSION Date: r e- SQ 0RtO1aNn1aldForm 10403Reve 1 15 for 12 month ONrv4l. t I)(p A ment/ to 1 • • 1J-136 to 1J-135 B MBE Retreatment with Crystal Seal Proposal 1J-136 dual-lateral injector with 4-1/2" L-80 tubing was completed December 2006 in West Sak B and D sands. Both laterals have 5-1/2" slotted liners with Constrictors (Swell Packers). A Matrix Bypass Event (MBE) occurred 2/23/10 in 1J-136 B lat to producer 1J-135 B lat. An IPROF of 3/15/11 in 1J-136 showed a B MBE between 10150' - 10680' MD. This interval is mostly covered by a 358' blank liner section. Most PWI appeared to be exiting the liner above this blank. On 12/14/11, 'big hole' perfs were shot at 10173 - 10178' RKB. On 12/15/11, CT pumped 1776 lbs of Crystal Seal (CS) to seal off the B MBE. The B lat was then cleaned out to remove excess CS and restore PWI to both the D & B laterals. This treatment held a few years. 0 On 8/9/15, an IPROF detected a 93% PWI split entering the B lateral. This showed that a B MBE was again becoming evident. PWI continued until a B MBE occurred 9/19/15. A D Iso-Sly was set 11/26/15, and an IPROF was run on 11/27/15 in the B lateral that found a temperature anomaly at -11650' RKB indicating the likely presence of the B MBE location. It is proposed that CT convey a 2" OD x 5' perf gun to shoot perfs in the B lat at 10625' MD (above a B MBE at -10650' RKB). Next, the B MBE would be sealed with Crystal Seal slurry pumped down CT at -2 bpm to the MBE. After the treatment, 1J-136 will be returned to B sand only PWI to verify that the B MBE has been sealed. After verification that the MBE is sealed, CT will perform an FCO in the B lat and then the D Iso-Sly will be pulled to restore PWI to D lat. 1J-136 Proposed Wel!work Procedure: Coil Tubing: 1. RIH with a 5' OAL x 2" OD Perf gun to shoot 'big hole' perfs, 6 spf, 60 deg ph, in 5.5" slotted liner at 10625 - 10630' RKB. POOH. Verify ASF. 2. Verify 1J-135 is shut-in, then RIH with CT Nozzle BHA to 10610' RKB to pump a Crystal Seal Treatment to the B MBE at -10650' RKB. Park nozzle at 10610' RKB and perform a short SRIT pumping Seawater down CT to determine a preferable constant treating rate, then swap to Crystal Seal Slurry consisting of Seawater with 0.25 ppg of 1,2,4 mm mesh Crystal Seal pumped down CT at an established constant rate (-2 bpm expected). Pump Slurry while slowly POOH with CT until achieving -1000 psi WHIP (to bring WHIP near frac pressure), and then go to Flush pumping 15 bbls of Seawater, followed by Diesel FP to surface, followed by SD. RD. 3) - RIH with Jet Swirl Nozzle to jet through excess Crystal Seal left in the B lateral liner. Perform an FCO jetting Seawater to as deep as possible. POOH & FP with Diesel. RD. 4) Run a post-treatment memory IPROF log in B lateral to verify that the B MBE is sealed. 5) RIH & pull the D Iso-Sleeve (set 11/26/15) to restore PWI to the D lateral. Return 1J-136 to PWI service to the West Sak B and D sands. JWP 12/29/2015 z KUP PPD 1J-135 ConocoPhillips g Well Attribute Max Angle o TD + Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) OxMcoi'hithps`p" 500292334900 WEST SAK PROD92.54 11,921.47 17,735.0 ,. Comment M2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date MULTIPLE LATERALS-12-135,12/28/20157',15.49 AM SSSV:NIPPLE Last WO. 5/27/2013 44.00 5/23/2007 Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date MANGER;23.9 -_0-1),;.,,. Last Tag'SLM 7,400.0 10/29/2009 Rev Reason:GLV C/O,SET JET PUMP hipshkf 5/7/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.250 43.7 1222 1222 94.00 WELDED 11 Insulated 34" ,„„k,„„n,e,.,nee,,one,,,o,m,,,o,,, .+,„. �.,,,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 11 SURFACE 13 3/8 12.415 43.6 3,462.8 2,215.4 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ID-SAND WINDOW 95/8 8.000 9,097.0 9,107.0 3,529.8 CONDUCTOR Insulated 31'; Casing Description OD 5n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 43.7-122.2 D-SAND LINER HH 51/2 4.950 9,093.7 9,3524 3,558.9 15.50 L-80 BTC-mod Liner Details NIPPLE;477.9 Nominal ID Oil Top(ftKB) Top)TVD)(ftKB) Top Incl(°) Item Des Com (in) 9,093.7 3,527.7 80.65 HANGER BAKER MODEL'B-1'HOOK HANAGER 9 5/8"x 7.470 7"(Inside csg) 9,114.8 3,531.1 81.02 HANGER BAKER MODEL'B-1'HOOK HANGER 9 5/8"x 6.290 7"(Outside csg) fa GAS LIFT;2,471.6 9,121.1 3,532.0 81.13 XO BUSHING CROSSOVER BUSHING 4.950 9,218.1 3,545.5 83.11 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.920 I I 9,278.1 3,551.9 84.53 XO Reducing Crossover 5 1/2"BTC-mod box x 4-1/2"BTC pin 3.940 L Casing Description IOD(in) (ID(in) I Top(MKB) 'Set Depth(ftKB( 'Set Depth(TVD)...I Wt/Len(1...I Grade Top Thread SURFACE,43.6-3,462.8-° ` 6-SAND LINER 5 1/21 4.950 9,167 0 17,722.5 3,512 5 15.50 L-80 BTC-Mod Liner Details GAS LIFT;7,360.3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 9,167.0 3,538.8 81.93 PACKER MLZXP LINER TOP PACKER - 7.500 9,188.2 3,541.7 82.36 HANGER FLEXLOCK LINER HANGER 6.090 9,193.5 3,542.4 82.49 XO BUSHING XO BUSHING 4.950 9,194.9 3,542.6 82.53 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma...j ID(in) Top(ffKB) Set Depth(ft..Set Depth(TVD)(...Wt(113/ft) Grade Top Connection TUBING WO 2013 4 1/21 3.960 23.9 8,989.01 3,510.5 12.60 L-80 IBTM Upper Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Teel(°) Item Des Corn (in) • 23.9 23.9 0.00 HANGER VETCO GRAY TUBING HANGER ' 3.958 PROTECTOR;8,831.3 •. PUMP;8,932.2 - ' 477.9 477.9 0.60 NIPPLE CAMCO'DB'LANDING NIPPLE 3.875 SLEEVE-O;8,932.3, tellii 8,931.3 3,501.2 80.72'PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 PROTECTOR;8,936.9 7-- III 8,932.3 3,501.3 80.72 SLEEVE-0 BAKER CMU SLIDING SLEEVE-Open 4/25/15 3.812 GAUGE;8,953.5 07 8,936.9 3,502.1 80.71 PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 LOCATOR;8,969.9 8,953.5 3,504.8 80.67 GAUGE GUARDIAN SENSOR GAUGE CARRIER ASSEMRI Y 3.960 SEAL ASSY;8,970.5 Mr'r 8,969.9 3,507.4 80.64 LOCATOR BAKER LOCATOR 4.800 t7-':SLV;8,986.0 ,1 8,970.5 3,507.5 80.64 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 4.670 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection SBE,8,999.4 TUBING WO 2013 5.21 3.870 8,986.0 9,075.0 3,524.6 L-80 TC II '/1 Lower t Completion Details PACKER;9,033.3 '" I Nominal ID it Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) 8,986.0 3,510.0 80.61 SETTING SLV 'HR'LINER SETTING SLEEVE 3.812 NIPPLE,9,058.5 All 8,999.4 3,512.2 80.59 SBE BAKER SEAL BORE EXTENSION 3.870 WLEG;9,073.6 }_{ 9,033.3 3,517.8 80.57 PACKER BAKER PREMIER PACKER w/29/32"Ball 3.930 9,058.5 3,521.9 80.55 NIPPLE CAMCO DB NIPPLE w13.75"PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG WIRELINE ENTRY GUIDE 4.000 D-SAND WINDOW;9,097.0. 9,107.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ffKB) V) Des Com Run Date ID(in) 8,932.2 3,501.3 80.72 PUMP 3.813"JET PUMP(SIN:PH-1030,11C RATIO,11 5/4/2015 0.000 NOZZLE,13 THROAT Perforations&Slots ® Shot ® Dens Top)TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com e 3 9,829.0 11,845.0 3,605.0 3,583.7 WS B,1J-135 4/30/2007 32.0 SLOTS 2.5"long X.125"wide,4 circumferencial rows/ft, 3"centers staggered 18 deg 11,847.0 17681.0 3,583.6 3,5132 WS B,1J-135 4/30/2007 32.0 SLOTS 2.5"long X.125"wide,4 circumferencial rows/ft, 3"centers staggered 18 deg D-SAND LINER MN;6.093.7- Mandrel Inserts 9,352.4 St all N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn INTERMEDIATE,40.9-9,819.0 1� 2,471.6 1,959.3 CAMCO MMG 1 1/2'GAS LIFT DMY RK 0.000 0.0 5/1/2015 Belly .i 1 Down SLOTS;9,8290-11,845.0- 1 1 2 7,360.3 3,214.3 CAMCO .MMG 1 1/2'GAS LIFT DMY RK 0.000 0.0 5/26/2013 Notes:General&Safety End Date Annotation SLOTS;11,647an,661.0-I 5/23/2007 NOTE: MULTI-LATERAL WELL-1J-135(B-SAND),1J-135L1(D-SAND) 3/18/2008 NOTE:WORKOVER B-SAND LINER;9,167.1)- l 17,772.5' KUP POD • 1J-135 ConocoPhillips ,. A isk<I Int.. CorgcOPhMips • MULTIPLE LATERALS-1.1-135,12/28/2015 7.15'.50 AM Vertical schematic(actual) HANGER;23.9 y;I.;..' :'.., Notes:General&Safety ; ./.... ....f.• End Date Annotation 8/9/2008 NOTE:View Schematic w/Alaska Schematic9.0REV 2/9/2010 NOTE:WORKOVER 5/27/2013 NOTE:WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT 6/18/2013 NOTE:GLM @ 2472'RKB IS BELLY DOWN CONDUCTOR Insulated 34",. 43.7-122.2 NA NIPPLE;477.9 I 116 GAS LIFT;2,471.6 11, SURFACE,43.63,462.8— RIM GAS LIFT;7,380.3 PROTECTOR;8,931.3 `" PUMP;8932 2-, _' '- SLEEVE-0;8932.3 1 PROTECTOR;8,936.9 I SRC 111 GAUGE;8,953.5 .._7 LOCATOR;8969.9 SEAL ASSY;8,970.5 iiSETTING KV;8,986.0 � '1 SBE;8,999.4 mas { 1 PACKER;9,033.3 Il NIPPLE;9,058.5 WLEG;9,073.8 ;_',,;. D-SAND WINDOW,9,097.0- 9,107 0 - 9,1070 a i D-SAND LINER HH;9,093.7- l 9,352.4 1 INTERMEDIATE;409-9,819.0 SLOTS;8,829.0-11,845.0 I I SLOTS;11,847.6-17,681.0 I I —.B-SAND LINER;9,167.0- 17,722.5 Ima a Pro°ect Well Histo File Co~r Pa e 9 1 ~/ g XHVZE This page identifies those items that were not scanned during the initial production scanning- phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. `~ ~ ~ - Q ~~ Well History File Identifier Organizing tdone> RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ 1_.. Project Proofing BY: Maria _ ~~~..--- Scanning Preparation BY: Maria Production Scanning Stage 1 Page Count from Scanned File: V (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~ ~ Q /s/ r ~/ 1, Q q III Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. "iuiuuuiiium Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III o,.a,a~ uiuiiniuiuuii DIGITAL DATA Diskettes, No. '~ ^ Other, No/Type: ^ Rescan Needed II I II'I (I II I I II I III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: oa~,~ ,~P 9 IIIIIMIIIIIIIIIII ~P Date: Date: (~ I ~T , _ !~ x 30 = ~ a o + =TOTAL PAGES ~~ fount does not incude cover sheet) Date: /s/ ~~ III IIIIIIIIIII IIIII 3g 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA 1 AL OA OIL AND GAS CONSERVATION CO4SION ," ii;. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon i Repair w ell r Rug Perforations fi Perforate f"" OthJ 4 .'r ' ' . r Alter Casing r Pull Tubing f 'Stimulate-Frac r Waiver fi Time Extension Change Approved Program f'"`Operat. Shutdown Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development '✓ Exploratory r _ 207-038 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-23349-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25662,380058 1J-135 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool • 11.Present Well Condition Summary: Total Depth measured 17735 feet Plugs(measured) none true vertical 3512 feet Junk(measured) none Effective Depth measured 17720 feet Packer(measured) 9033, 9167 true vertical 3512 feet (true vertical) 3518,3539 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 121 121 SURFACE 3419 18.187 3463 2213 INTERMEDIATE 9778 9.625 9819 3604 B-SAND LINER 8556 8.32 17723 3512 Perforation depth: Measured depth: 9829-11845, 11847-17681 SCANNED NOV 0 8 20 True Vertical Depth: 3605-3585,3585-3513 Tubing(size,grade,MD,and TVD) 4.5, L-80,9075 MD,3525 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER @ 9033 MD and 3518 TVD PACKER-MLZXP LINER TOP PACKER©9167 MD and 3539 TVD NIPPLE-CAMCO'DB'LANDING NIPPLE @ 478 MD and 478 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 2085 1 — 215 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory fl Development f✓ Service r Stratigraphic I- 16.Well Status after work: Oil rti Gas f—' WDSPL f Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Dan Bearden @ 263-4864 Email James.D.Beardenna.cop.com Printed Name {{`` Dan Bearden Title Drilling Engineer Signature `) + � ! Phone:263-4864 Date 8,13 `r\ �,_.h O�O -- vivr- RBDMS JUL - 2 2 Arl ti 1 /3 l if Form 10-404 Revised 10/2012 `� Submit Original Only 1J-135 Pre-Rig Workover Well Work Summary DATE SUMMARY • 4/15/2013 Displaced IA w/360 bbls and tubing with 63 bbls of 180 deg F diesel @ 1-1.3 bpm. DHD to return in a few days to take pressure and get fluid levels.Note: See attached pump report for more detail. 4/18/2013 (RWO) : T FL @ 3206' (28 BBLS), IA FL @ 3146' (139 BBLS). VALVE SHOP HAS NOT BEEN CALLED TO SET BPV. ■ r KUP 4111/ 1J-135 ConocoPhilhips 44 Well Attributes Max Angle&MD TD Alaska(nC Wellbore API/UWI Field Name Well Status Inc!(°) MD(RKB) Act Btm(ftKB) Abp,= 500292334900 WEST SAK PROD 92.54 11,921.47 17,735.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date We SSSV:NIPPLE 120 8/14/2012 Last WO: 5/27/2013 44.00 5/23/2007 Well Cantle'MULTIPLE LATERALS-1J-135.6,6/2013 9'.39:09 AM ( Schematic-Actual Annotation Depth 01KB) End Date Annotation Last Mod By End Date P Last Tag'.SLM 7,400.0 10/29/2009 Rev Reason:WORKOVER osborl 6/6/2013 HANGER,24 Casing Strings --- --- -' Casing Description String 0... String ID...To P(ftKB) Set Depth(f...Set Depth)TVD).., String Wt...Strin g..String Top Thrd CONDUCTOR 20 19.250 43.7 122.2 122.2 94.00 WELDED Insulated 34" , Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd -�SURFACE 133/8 12.415 43.6 3,462.8 2,215.3 68.00 L-80 BTC Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 95/8 8.835 40.9 9,819.0 3,604.2 40.00 L-80 BTC-mod Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd D-SAND WINDOW 95/8 8.000 9,097.0 9,107.0 3,528.4 Casing Description String 0... String ID...Top(k)(B) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR D-SAND LINER HH 5 1/2 4.950 9,093.7 9,352.4 3,558.9 15.50 L-80 BTC-mod Insulated 34",-- 44-1n Liner Details IMP Top Depth NIPPLE,478 SW (ND) Top Inc! Nom,... Top(kKB) (kKB) (4) Item Description Comment ID lin) 9,093.7 3,525.6 80.02 HANGER BAKER MODEL'B-1'HOOK HANAGER 9 5/8"x 7"(Inside csg) 7.470 9,114.8 3,529.9 80.54 HANGER BAKER MODEL'B-1'HOOK HANGER 95/8"x 7'(Outside csg) 6.290 9,121.1 3,531.1 80.70 XO BUSHING CROSSOVER BUSHING 4.950 MIN 9,218.1 3,546.1 84.41 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.920 GAS LIFT, 2.472 9,278.1 3,551.9 84.58 XO Reducing Crossover 51/2"BTC-mod box x 4-1/2"BTC pin 3.940 .'y. Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd B-SAND LINER 51/2 4.950 9,167.0 17,722.5 3,512.5 15.50 L-80 BTC-Mod $ Liner Details SURFACE,- A l Top Depth ill_443.463 (TVD) Top loci Nomi... Top(kKB) (flK8) (°) Item Description Comment ID(in) GAS LIFT, 7,,380 365 9,167.0 3,538.8 81.84 PACKER MLZXP LINER TOP PACKER 7.500 _ 9,188.2 3,543.1 84.35 HANGER FLEXLOCK LINER HANGER 6.090 9,193.5 3,543.6 84.36 XO BUSHING XO BUSHING 4.950 9,194.9 3,543.8 84.37 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth)ND)...String Wt...String... String Top Thrd TUBING WO 2013 41/2 3.960 23.9 8,989.0 3,510.5 12.60 L-80 IBTM Upper Completion Details Top Depth (ND) Top Incl Nom,... Top(kKB) (kKB) 11 Item Description Comment ID(in) t--- 23.9 23.9 -0.04 HANGER VETCO GRAY TUBING HANGER 3.958 PROTECTOR. E.. 477.9 477.9 0.60 NIPPLE CAMCO'DB'LANDING NIPPLE 3875 8,931 8,931.3 3,501.2 80.64 PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 PROTECTOR, TOR. ' * PROTECTOR, 3.812 8.937 '�-' 8,932.3 3,501.3 80.64 SLEEVE BAKER CMU SLIDING SLEEVE GAUGE,8,953 C=2 8,936.9 3,502.1 80.64 PROTECTOR FLUTED WIRE PROTECTOR SUB 3.910 LOCATOR, WM 8,953.5 3,504.7 80.63 GAUGE GUARDIAN SENSOR GAUGE CARRIER ASSEMBLY 3.960 8,970- 4.800 SEAL ASSY, 8,969.9 3,507.4 80.62 LOCATOR BAKER LOCATOR 8.971 i. 4.670 SETTING SLV, 8,970.6 3,507.5 80.61 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY opf'8.986 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SSE,8,999 TUBING WO 2013 5.21 3.870 8,986.0 9,075.0 3,524.6 L-80 TC II Lower ENE Completion Details Top Depth PACKER,9,033 it �' nl No ,.,, Top(ftKB) (kKB) Top Inc! tern Description Comment ID(in) AIR 8,986.0 3,510.0 80.60 SETTING SLV 'HR'LINER SETTING SLEEVE 3.812 NIPPLE,9,058 i 8,999.4 3,512.2 80.59 SBE BAKER SEAL BORE EXTENSION 3.870 WLEG,9,074 -' 9,033.3 3,517.8 80.57 PACKER BAKER PREMIER PACKER w/29/32"Ball 3.930 9,058.5 3,521.9 80.55 NIPPLE CAMCO DB NIPPLE w/3.75"PROFILE 3.750 9,073.6 3,524.4 80.54 WLEG WIRELINE ENTRY GUIDE 4.000 D-SAND W NDOW. Perforations&Slots 9,097-9,107 Shot xar+ Top(TVD) Btm(TVD) Dens ■ Top(kKB)Btm(kKB) (kKB) (kKB) Zone Date (sh... Type Comment 9,829.0 11,845.0 3,605.0 3,585.2 WS B,1J-135 4/30/2007 32.0 SLOTS 2.5"long X.125"wide,4 circumferencial rows/ft,3"centers staggered 18 deg i )_l 11,847.0 17,681.0 3,585.0 3,5132 WS B,1J-135 4/30/2007 32.0 SLOTS 2.5"Iong X.125"wide,4 circumferencial rows/ft,3"centers staggered 18 deg Notes:General&Safety End Date Annotation 5/23/2007 NOTE:MULTI-LATERAL WELL-1J-135(B-SAND),1J-135L1(D-SAND) 3/18/2008 NOTE:WORKOVER 8/9/2008 NOTE:View Schematic w/Alaska Schematic9.0REV 2/9/2010 NOTE:WORKOVER D-SAND LINER 5/27/2013 NOTE:WORKOVER CONVERTED WELL FROM ESP TO GAS LIFT HH, 9.094-9,352 i NTERMEDIATE, 4. 41-9,819 SLOTS, 9,829-01,845-� III Details Top Depth Top Port 1 g (TVD) Inc! OD Valve Latch Size TRO Run SLOTS. • N...Top(RKB) (kKB) 1") Make Model (in) Sery Type Type OM (Psi) Run Date Com... 11,847-17881 e 1 2,471.6 1,959.3 73.28 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 5/26/2013 13-SAND I7723\ 1 1 2 7,360.4 3,214.3 76.32 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2013 9,187-17.723 \ J ` TD(IJ-135), 17,735 • • Conoco hllips Time Log & Summary WelMew Web Reporting Report 16 • �� � ��'������a i���i�k�idOlG����ol ii � �;`�v � �o�l���i iii llN�ti) Well Name: 1J-135 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/20/2013 2:30:00 PM Rig Release: 5/27/2013 3:00:00 PM Time LOS 11,1i1f3GI ry bate From To' ° ,IDur S.Depth E'Deoth Phase erode Subcode I 'T AGqinment 1011 05/20/2013 24 hr Summary Accept rig @ 1430 hrs 5/20/2013 after rig commissioning and BOP test. Blow down the choke and kill lines, choke manifold. Rig down testing equipment.Check pressures on IA(4 psi),bleed off pressure. Remove blanking plug,pull BPV. Rig up to pull ESP. 14:30 16:00 1.50 0 0 COMPZ WHDBO OTHR P Blow down the choke manifold, kill line and choke line. 16:00 16:30 0.50 0 0 COMPZ WHDBO OWFF P Monitor the IA(9-5/8"x 3-1/2"),bleed off 4 psi. 16:30 17:30 1.00 0 0 COMPZ WHDBO OTHR P Pick up the 3-1/2"IF drill pipe test joint.Make up Vetco gray tool to retrieve the blanking plug. Retrieve plug. Pull the type"H"4"BPV. 17:30 00:00 6.50 0 0 COMPZ RPCOM RURD P Pickup third party tools to the rig floor. Rig up to pull the 3-1/2"ESP completion. Rigging up Baker Centralift 05/21/2013 Pulled 3 1/2"ESP Completion. Recovered complete. 00:00 01:00 1.00 0 0 COMPZ RPCOM RURD P Complete rigging up the Floor to handle the 3 1/2"ESP Completion. 01:00 03:00 2.00 7,341 7,317 COMPZ RPCOM THGR P Make up Landing Joint. Record well head pressures as follows: Tbg=0 psi, IA=10 psi,OA=250 psi. Bleed IA to"0"psi. BOLDS. Tubing Hanger broke free at 150 K. Pulled Tubing Hanger to the Floor at 125 K. Lay down same. Fill hole with 9 bbls. Estimated static fluid level was at 140-ft. 03:00 00:00 21.00 7,310 89 COMPZ RPCOM PULL P Single down the 3 1/2"Completion Tubing while spooling ESP Cable. Lay down jewelry pieces. (Note:the Sliding Sleeve was jammed in the closed position by a piece of rubber. Also the ESP Cable had been impregnated by gas in manny areas). 9 5/8"Y-Tool/ESP Assembly at surface. Hole fill= 10 bbls. Monitor fluid falling very slowely. 05/22/2013 Pulled and singled down the 3 1/2"ESP Completion. 00:00 00:30 0.50 89 89 COMPZ RPCOM SFTY P Hold PJSM with crew coming on Tower. Discuss laying down the Y-Tool/ESP Assembly. Page 1 of 7 • Tittle Log3 �i r u 4" € o Date= „. Profit To 'Dur S.Deatt .„b �er th'?Phase ��Code ``Subcode td,T ..romme,f i�491ii phi, 00:30 06:00 5.50 89 0 COMPZ RPCOM PULL P Lay down 2 7/8"Flush Joint Tailpipe Tubing, ESP Assembly,and the Y-Tool. Recovered 120 ea Cannon Clamps,complete. Recovered 5 ea Y-Tool Clamps,complete. Note: ESP Motor had areas on the housing with bad corrosion pits. The Pump was packed with sand...no rotation. Rig down floor. Clear and clean floor. 06:00 06:30 0.50 0 0 COMPZ WELLPF RURD P Install Wear Bushing(10 1/8"I.D.). 06:30 09:30 3.00 0 90 COMPZ WELLPF PULD P Make up BHA#1 as follows: Bull Nose Jet Nozzle,X-Treme Magnet, XO,8 1/2"Smooth OD String MIII, Flex Jt, Flex Jt, 8 1/2"Smooth OD String Mill, Double Pin Sub,7"Boot Basket,7"Boot Basket, Bit Sub, X-Treme Magnet,4 3/4"Bumper Sub,4 3/4"Oil Jar, Pump-Out-Sub. Total Length=89.73-ft. 09:30 00:00 14.50 90 6,396 COMPZ WELLPF PUTB P Pick up 165 ea joints of 3 1/2" E-Grade Drill Pipe. Rattle Drill Pipe. Break circulations every 30 joints to clear Drill Pipe. Beging to pick-up 3 1/2"Heavy Weight Drill Pipe. 35/23/2013 Clean-out Well Bore to 9,066-ft.Trip out with BHA#1,standing back 3 1/2" Drill Pipe.Make-up Lower Baker Completion Assy.Start TIH. 00:00 04:30 4.50 6,396 9,010 COMPZ WELLPF PULD P Finish in with 126 jts of heavy weight 3 1/2"S Grade Drill Pipe. (Note:Set down on a bridge at 8,139-ft. Second attempt fell through). Continue down to 9,010-ft with no problems. 04:30 06:00 1.50 9,010 9,066 COMPZ WELLPF WASH P Park Jet Nozzle at 9,010-ft. With the Drill Pipe side shut in, line up pump #1 down the IA and perform an injection step rate test as follows: 1.0 bpm/60 psi,2.0 bpm/117 psi,3.0 bpm/222 psi,4.0 bpm/319 psi,5.0 bpm/420 psi. Wash down to 9,066-ft at 5.0 bpm/620 max pressure with no problems. Pull back up to 9,010-ft. Bring on both pumps at 8.0 bpm, pumping down the Drill Pipe and the IA. Wash down to 9,066-ft at 8.0 bpm/1,026 psi. Pull back up to 9,010-ft End Washing. Total fluid volume injected=85 bbls. 06:00 07:30 1.50 9,010 9,010 COMPZ WELLPF OWFF P Monitor Well and observe a slight flow due to"ballooning effect". Continue to monitor.Allow well to go static.Continue to observe well to see fluid falling in the stack. 07:30 13:30 6.00 9,010 90 COMPZ WELLPF TRIP P Trip out of hole observing proper displacement.Monitor well at the BHA. Static. Page 2`of 7 • • Time Log rr „ Date ' 'From To Dur S.,Deoth E.Depth Phase Code u'Subcode T ''Cotnment 13:30 16:00 2.50 90 0 COMPZ WELLPF PULD P Break out and lay down BHA. Observed Crude cap in well and taking time to clean tools.Observed approximately 1/2 gallon of sand& sludge recovered in Junk Baskets, and approximately 2 lbs of scale recovered on magnets.Jet sub was plugged with sand. Well static. SIMOPS: Load pipe shed with 4 1/2" Completion tubing. Load Lower completion assembly in pipe shed. 16:00 17:15 1.25 0 0 COMPZ WELLPF PULD P Clean&clear rig floor area of BOT clean out tools.Continue clean crude form rig floor area and manage housekeeping issues. Load tools on truck. 17:15 18:15 1.00 0 0 COMPZ WELLPF RURD P Pull GBR power tongs to rig floor. Rig up to run Lower completion assembly. Install 4 1/2"tubing elevators.Secure safety valve& crossover.Verify 4 1/2"hand slips ready. 18:15 18:45 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with crew, BOT rep and Co. Man. Discuss safety and hazard recognition issues. Discuss procedure to make up and run Lower completion assembly as per detail. 18:45 21:30 2.75 0 96 COMPZ RPCOM PULD P Make-up the Lower Baker Completion pre Baker Rep as follows: WLEG, Pup Jts, DB Nipple w/3.750"profile(verified x 2), Baker 9 5/8"x 4 1/2"Premier Packer Assembly, Baker Seal Bore Extension Assembly. Dump 5 gals of Pal Mix down the Tie-Back Sleeve (to keep any debris form getting into the Running Tool). 21:30 00:00 2.50 96 5,424 COMPZ RPCOM RCST P Trip in the hole with the Lower Completion section on 3 1/2"Drill Pipe. Up Weight=55K. Down Weight=45K. Running speed @ 90 ft/minute as per BOT rep. 05/24/2013 Ran Lower completion.Set Packer. Release Setting Tool.Test Annulus. POOH and single down Drill Pipe. Prep for the Upper 4 1/2"Completion. 00:00 06:30 6.50 5,424 9,075 COMPZ RPCOM RCST P Continue to trip in with the Lower Completion Assembly on 3 1/2"Drill Pipe from 5,424-ft. Drift Heavy Weight Drill Pipe w/1.90"Drift(Baker Back up Setting Ball=1.750"). Running speed at 90 ft/minute as per BOT rep. Observed changing out 5 jnts of HWDP as they would not drift. Edit tally as needed. Observed proper displacement and no issues getting packer on depth. UP WT= 125K,SO WT=55K. Page 3 of 1 • • Time Logs„"" ig `,. w 1411,, �� a Date ''`From ,To o a Dur, ebth E.°;Depth Phase Code Subcode T x Comn enf 06:30 06:45 0.25 9,075 9,075 COMPZ RPCOM SFTY P Held PJSM with Crew, BOT rep,and Co. Man. Discuss safety&hazard recognitioon issues. Discuss procedure to pump and set packer. Discuss High Pressure issues. 06:45 08:30 1.75 9,075 9,075 COMPZ RPCOM RCST P Drop 29/32"Ball down drill string. Pump down DP at 2.7 BPM-765 PSI,chasing ball. Observed ball on seat in 10 Min with 819 stks. Pressure to 500 PSI-5 minutes. Pressure to 3000 PSI-10 minutes. Bleed pressure to 0 PSI.Set down 20K, PU to 150K.Set down 20K. Pressure to 3000 PSI to release Hydraulic setting tool. Bleed pressure to 0 PSI.Work string to verify setting tool released. Note: RKB difference from Doyon 15 to Nabors 7ES=12.36'.WLEG @ 9075', Baker Premier Packer setting depth=9033'MD. 08:30 09:00 0.50 9,075 9,075 COMPZ RPCOM PRTS P Rig up,close upper pipe rams and pressure test annulus to 3500 PSI- 30 minute test. Record on chart. Good test. Bleed all pressure. 09:00 09:30 0.50 9,075 9,075 COMPZ RPCOM RCST P Pressure down drill string to 4365 PSI to shear ball seta in setting tool. Bleed pressure,and slowly pull up hole to observed setting tool free of Liner Setting Sleeve. Rack back one stand of DP. 09:30 11:30 2.00 9,075 9,000 COMPZ RPCOM CIRC P Circulate bottoms up staging pumps to 6 BPM-2160 PSI.Observed minimal fluid loss. No gas. 11:30 12:00 0.50 9,000 9,000 COMPZ RPCOM OWFF P Monitor well-static. Establish static loss rate of 5.5 BPH. Pump 42 BBLS of 90 deg, heated brine with surfactant wash down Drill pipe to clean same. 12:00 22:30 10.50 9,000 45 COMPZ RPCOM PULD P POOH laying down 3 1/2"DP. Observed proper displacement. Observed pipe coming very clean as surfactant wash over top of hole aidiing in cleaning crude off of DP. 22:30 23:00 0.50 45 0 COMPZ RPCOM PULD P Break out and lay down Baker Liner Hanger Running Tool Assy. Found the Setting Ball on seat. However, there was also a lot of scale in the Ball Seat. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Clear and Clean Floor. Continue to load and tally the 4 1/2"Completion Tubing in the Pipe Shed. Rig up GB&R tubing handling equipment. Rig up Centrilift Air Spooler w/TEC Wire. Verify Upper Completion equipment with Baker Service Rep. Page 4 of 7` • • Time Logs �ii�� � �F�d � �� _ � i i '''6411111,11;1'L u'""" ,,Date :r.;: From ,To m Dur SADeDth E.Depth`Phase Code Subco)e s T oinment — ;, I G161 05/25/2013 24 hr Summary Lay down the 3 1/2"Drill Pipe. Finish loading,drifting,and tally the 4 1/2 Upper Completion Tubing. Rig up to run the 4 1/2"Upper Completion. 00:00 05:30 5.50 0 0 COMPZ RPCOM RURD P Continue to load,drift,and tally 4 1/2"Tubing. Continue to rig up GB&R equipment. Continue to rig up Centrilift Air Spooler w/TEC Wire. Pull Wear Bushing. 05:30 06:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discussed hand,eye,and hearing safety. Discussed overhead loads keeping the work area clear of tripping hazards,and line of fire. Also working around several operations going on at the same time. Reviewed the running order of the Upper Completion. 06:00 06:30 0.50 0 65 COMPZ RPCOM RCST P Pick up Jewelry as follows: Baker GBH-22 Seal Assembly, Locator Sub,3 ea 4 1/2"12.6 lb/ft L-80 IBTM Pup Joints,Guardian Sensor Gauge Carrier Assembly,2 ea 4 1/2"12.6 lb/ft L-80 IBTM Pup Joints, Fluted Wire Protector Sub, Baker CMU Sliding Sleeve(in the closed position)w/3.812"DB profile, Fluted Wire Protector Sub,4 1/2"12.6 lb/ft L-80 IBTM Pup Joint. 06:30 00:00 17.50 65 6,696 COMPZ RPCOM RCST P Begin to single in with the 4 1/2" 12.6 lb/ft, L-80, IBTM Upper Completion Tubing with TEC Wire as per designed program to 6,696-ft. Up Weight=78K. Down Weight=47K. Check TEC Wire every 1,000-ft. 05/26/2013 Finish running 4 1/2"Completion. Circulate Corrosion Inhibited 3%KCL. Land Completion.Set TWCV and test. ND BOPE. NU Production Tree. 00:00 05:00 5.00 6,696 24 COMPZ RPCOM RCST P Continue running the 4 1/2"Upper Completion Tubing with TEC Wire from 6,696-ft as per program. Check TEC Wire every 1,000-ft. 05:00 06:00 1.00 24 24 COMPZ RPCOM RCST P Up Weight=95K. Down Weight= 48K. Sting into the SBR at 8,988.5-ft.. Space out the final Completion as follows: No-Go on Jt# 288 with 18-ft in. Lay down Jts# 288,287,and 286. Add 23.88-ft KB to the Lock Down Screws,2.13-ft Tubing Hanger, 1 Jt Tbg 31.28-ft (note:this jt is not in the running tally...it is bucked up to the bottom of the Vetco Gray Hanger),7.0-ft of Seal Section"stick-up"from No-Go, Pup Joints needed=13.49-ft. Page 6 of 7 . • • Time Lo S � tll u Date =, From To Dur Q p E.17epth Phase erode:-. Subcode T Commen 06:00 07:00 1.00 24 24 COMPZ RPCOM RCST P Add Pup Joints as needed(1 ea 9.83-ft and 3.81-ft) Pick up a full Joint along with the Tubing Hanger. Blow down Top Drive. Install the dummie ESP Penetrator in the Tubing Hanger. Check TEC Wire. Good. Final Cannon Clamps used= 293 ea. 285 tallied Jts ran. 15 tallied Jts remain in the Pipe Shed. 20 Jts outside not in the tally. 320 total Jts delivered to Location. 320 Jts accounted for. 07:00 10:00 3.00 24 24 COMPZ RPCOM CIRC P Circulate and condition Well with Corrosion Inhibited 3%KCL Brine. 10:00 11:00 1.00 24 0 COMPZ RPCOM RCST P Drain BOP Stack. Land Completion. RILDS. Test Upper and Lower Hanger Seals as per Vetco-Gray Rep at 5,000 psi x 10 minutes. Good test. Lay down Landing Joint. 11:00 13:00 2.00 0 0 COMPZ RPCOM PRTS P Pressure test the 9 5/8"x 4 1/2"IA in 500 psi steps x 10 minutes each. Good test. The SOV sheared at 3,400 psi. 13:00 14:00 1.00 COMPZ RPCOM SFTY P After Action Drill. Rig Evacuation Drill with Rig Crew, Drill Site Operator,Company Man,and others on Location. Drill went well. 14:00 19:00 5.00 COMPZ WHDBO NUND P Install TWCV. Blown down Choke Line, Fill Line,and Mud Line. Nipple down BOPE and set back on Stump. 19:00 23:30 4.50 COMPZ WHDBO NUND P PJSM. Nipple up new Adaptor Flange. Nipple up Vetco-Gray 4 1/16"x 5 K Horizontal Production Tree. 23:30 00:00 0.50 COMPZ WHDBO PRTS P Test Hanger void at 250/5,000 psi x 10 minutes. Good. Attempt to perform a low pressure test on the tree. Leak on the top flange. Abort test to tighten. 05/27/2013 Continue nipple down BOP's and Nipple up tree.Test same. Rig up with Little Red,and held PJSM. Displace well with 185 BBLS of freeze protect diesel at 2 BPM-650 PSI.Allow to U-tube until balance.SITP-200 PSI,SICP-150 PSI.Secure tree and valves. Both crews reported to KOC-EMOC room for completion of IFC training as planned. Return to rig.Clean cuttings tank,and cellar. Rig released at 1500 HRS form 1J-135. Prep to move to 2W-12. 00:00 01:00 1.00 COMPZ WHDBO PRTS P Pressure test the Production Tree at 250/5,000 psi. High pressure test lost—100 psi in 10 minutes. Good test. Recorded test on chart. 01:00 01:30 0.50 COMPZ WHDBO MPSP P PJSM. Pull TWCV. 01:30 05:00 3.50 COMPZ WHDBO FRZP P PJSM with Lil'Red and Rig Crew. Rig up lines to Freeze Protest. Pressure test line at 2,500 psi. Lil' Red pump 190 bbls of Diesel down the IA at 2.0 bpm/650 psi. End pumping. Page6of7 r • • Date From Our I' Death E.DeotEr Phase Code'' SuU"oiie. T =Comment alit-,' a. 05:00 06:00 1.00 COMPZ WHDBO FRZP P Hook up line and allow well to U-Tube. Well freeze protected to 2,600-ft and/2,000-ft tvd. Retest I-Wire and observed good test with the bottom hole pressure reading of 1540 PSI, Bottom hole temperature of 69 Deg. Phase to ground reading- 70K OHMS.All Good. 06:00 06:30 0.50 COMPZ WHDBO FRZP P Blow down lines and rig down equipment in cellar. 06:30 08:00 1.50 COMPZ WHDBO SEQP P Rig up lubricator with Wetco wellhead rep. Install BPV as planned.Observed well underbalanced with 200 PSI on gauge. 08:00 09:00 1.00 COMPZ WHDBO SISW P Secure tree and install gauges. Observed 200 PSI on the tubing. Observed 150 PSI on the IA.Secure tree cap.Suck out fluid in celalr. 09:00 14:00 5.00 COMPZ WELLPFSFTY P Both crews reported to KOC-EMOC room for planned IFC training.3 hands left on rig to remove remaing fluid from pits and monitor rig. SIMOPS: Check all tire pressures with Peak tire man. 14:00 15:00 1.00 COMPZ WELLPF RURD P Crews back to rig.Suck out cuttings bin.All fluid gone. Rig released form 1J-135 at 1500 H RS. Page 7of7' STATE OF ALASKA ALAI OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r plug Perforations r Stimulate r Other n ESP to temp gas Alter Casing r Pull Tubing r Perforate New pool CJ Waiver r Time Extension lift Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p p Exploratory r 207 -038 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 r a 50 - 029 - 23349 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: r ADL- 380058, ADL- 25662, ADL -2661 1J -135 9. Field /Pool(s): , Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17735 feet Plugs (measured) None true vertical 3512 feet Junk (measured) None Effective Depth measured 17723 feet Packer (measured) 7146 true vertical 3513 feet (true vertucal) 3163 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 122 122' SURFACE 3419 13.375 3463 2215 B LINER 8556 5.5 17723 3513 V Perforation depth: Measured depth: 9829 11845; 11847 - 17681 . 1 `' D RE True Vertical Depth: 3605 -3585; 3585 -3513 JUN C X 9 2012 (size, grade, MD, and TVD) A0GCC Tubing ( 9 ) 3.5, L -80, 7340 MD, 3210 TVD Packers & SSSV (type, MD, and TVD) NIPPLE - CAMCO 2.813" DS NIPPLE @ 7146 MD and 3163 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Shut in Shut in Shut in Shut in Shut in Subsequent to operation 183 80 0 1306 179 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development n 4 Service r Stratigraphic r 15. Well Status after work: d Oil n Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact Bob Christensen / Darrell Humphrey Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature ` . Phone: 659 -7535 Date (D I /, /2 BDMS JUN 2 0 201 � 74" 6 zr. Form 10-404 Revised 10/2010 � i " 'emit Original Only • • 1J -135 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/28/12 SET 1/4 OV @ 2299' RKB. PULLED SLIP STOP CATCHER @ 2284' RKB. COMPLETE 1 1 1 1 " KUP • 1J-135 ConocoPhillips 0$ Well Attributes Max Angle & MD TD Yl1yM1 � Wellbore APIIUWI Field Name Well Status Inc! ( MD(ftKB) Act Btm (ftKB) 1. ,mov4+weps 500292334900 WESTSAK PROD 92.54 11,921.47 17,735.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' _ SSSV: NONE 120 8/8/2010 Last WO: 2/9/2010 44.00 5/23/2007 Well Cont 9: MULTIPLE LATERALS - 12-135, 529201210'.36.02 AM Schematb - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,400.0 10/29/2009 Rev Reason: GLV C/O ninam 5/29/2012 J- IANGee ae� Ca gs _ Casing Strings Casing Casing Strin String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.250 43.7 122.2 122.2 94.00 11■1111I.. g ailing Description String 0... String ID ... Top (FMB) Set Depth (f... Set Depth )TVD) ... String Wt... String ... String Top Thrd SURFACE 133/8 12.415 43.6 3,462.8 2,215.3 68.00 L BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 95/8 8.835 40.9 9,819.0 3,604.2 40.00 L BTC - mod Casing Description String 0... String ID ... Top (1ti(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd DSAND WINDOW 95/8 8.000 9,097.0 9,107.0 3,528.4 ' Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B LINER 51/2 4.950 9,167.0 17,722.5 3,512.5 1550 L - 80 BTC CONDUCTOR, 14122 Liner Details 1 11 Top (TVD) (TVD) Top Inc! Nomi... Top (RKB) (RKB) (1 Item Description Comment ID (!n) 9,167.0 3,538.8 81.84 PACKER MLZXP Liner Top Packer 9-5/8" (7.50" X 8.32") 7.500 9,188.2 3,543.1 84.35 HANGER 'FlexLock Liner Hanger 7" x 9 -5/8" (6.09" X 8.30 ") 6.090 Mandrels, 2,299 i 9,193.5 3543.6 84.36 XO BUSHING XO Bushing 4.95" ID, 7.63" OD 4.950 9,194.9 3,543.8 84.37 SBE 190-47 Casing Seal Bore Ext. 4.75" ID x 6.28" OD 4.750 Tubing Strings Tubing Description String 0... String ID ... Top (1198) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, ESP Com 1 3 1/2 I 2.990 I 38.5 I 7,341.0 I 3,209.6 I 9.30 I L -80 I EUE 8rd 44- 3 Completion Details SLIPSTOP, MIE Top Depth 7,146\ VALVE, 7,146 (TVD) Top Inc' Noml... VALVE, 7,146 � Top MKS) (ftK8) ( °) Item Description Comment ID (i^) IF 38.5 - 38.5 - 0.01 HANGER Vetco - Gray 11'x4 1/2 "Hanger w/full jt of 4 1/2" tubing w14.0909" Top 3.900 SLEEVE, 7,183 Conn I MIL 40.5 40.5 0.00 XO - Reducing Tubing w/ X over 4 1/2" x 31/2" EUE 8 rd 2.990 7,146.2 3,162.3 75.42 NIPPLE Camco 2.813" DS Nipple 2.813 PUMP i 203 7,163.0 3,166.7 75.66 SLEEVE Baker "CMU" SLIDING SLEEVE (CLOSED) 2.812 SENSOR??, E ' 7,211.5 3,178.3 75.83 SENSOR ?? 31/2" A -Well Discharge Pressure Sub 2.990' 7212 PUMP ;r9 I•} 7,257.5 3,189.6 75.98 NIPPLE Top Nipple 2.81" PTX Nipple 2.820 212 7,258.9 3,190.0 75.99 Y - BLOCK 95/8" Y - Tod Assembly 2.880 DISCHARGE, 7 224 7,260.3 3,190. 75.99 NIPPLE By Pass Nipple 2.75" XN Nipple w/ Standing Valve in Place 2.750 ESP PUMP, \ 3 7,224 7,261.7 3,190.6 75.99 Teleswivel Telescopic Swivel, w/20" stroke 2.990 DISCHARGE, 1 ESP PUMP 7237 , Wireline Entry Guide - 27/8" PT - X Box Up 2.360 7 238 - 4 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd Gas separator, 255 ESP Pump,Motor 5.13 7,202.6 7,317.4 3,204.0 NIPPLE, 7,257 System SEPARATOR, Completion Details Y- BLOCK, 7259 Top Depth NIPPLE, 7,280 + (TVD) Top Intl Nomi... Telessevel, i! Top (ftKB) (RKB) ( ") Item Description Comment ID (In) 7262 7,212.4 3,178.5 75.83XO Reducing Xover 3.5 New Vam x 2.875 EUE 8rd 1.500 Seal As+y, 2990 7,262 7,213.2 3,178.7 75.84 PUMPTBG Pump Sub MOTOR, 7,276 SEAL ASSY. 7,223.0 3,181.2 75.87 DISCHARGE Discharge Head 400 Series 0.000 7,287 MOTOR, 7,301 7,223.6 3,181.3 75.87 XO - Reducing Xover 3.5 New Vam x 2.875 EUE 8rd 1.500 SENSOR, 7,312 7,224.4 3,181.5 75.87 DISCHARGE Discharge Head 400 Series 0.000 Plug, 7,314 SENSOR, . 7,224.9 3,181.6 75.88 ESP PUMP Centrilift Pump 400 series FC 1600 0.000 7.315 PLUG, 7,317 7,238.0 3,184.9 75.92 ESP PUMP Centrilift Pump 400 series FC 1600 0.000 • 7,251.2 3,188.1 75.96 Gas separator Centrilift Gas Separator 0.000 WLEG, 7,340 1 7,256.6 3,189.4 75.98 Seal Assy Centrilift Lower Seal 513 Series 0.000 7,270.4 3,192.8 76.02 SEPARATOR Centriilift Gas Separator 0.000 7,275.9 3,194.1 76.04 SEAL ASSY Centrilift Lower Seal 513 Series 0.000 7,289.7 3,197.4 76.09' MOTOR Centrilift Upper Motor 562 Series 0.000 7,300.7 3,200.0 76.12 SENSOR Centrilift Sensor 0.000 7,302.8 3,200.5 76.13 MOTOR Centrilift Upper Motor 562 Series 0.000 7,313.8 3,203.1 76.16 SENSOR Centrilift Sensor 0.000 7,315.8 3,203.6 76.17 Plug Dummy Neck 0.000 7,316.6 3,203.8 76.17 PLUG Dummy Neck 0.000 D -SAND Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) WINDOW, Top Depth 9,097 -9,107 HANGER (TVD) Top Incl D -SAND, Top (1468) (RKB) (°) Description Comment Run Date ID (In) 9,094 L 7,144 3,161.8 75.39 SLIPSTOP 2.72 "SLIPSTOP 2/13/2010 7,146 3,162.3 75.42 VALVE 2.812" D CAT STANDING VALVE 2/13/2010 Mandrel Details Top Depth Top Port f (TVD( Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) 11 Make Model (in) Sery Type Type (19) (psi) Run Date Com... 1 2,298.8 1,908.7 70.98 CAMCO KBMG 1 ESP OV BK 0.250 0.0 5/28/2012 NTERMEDIATE, • 41 -9,819 • LOT3, 9 S 929 -„ B/S 1 ■ SLOTS. a 11,847- 17.681 � ' B LINER, 9,187 - 17.723 ` TD (1J-135), ` 17.735 - KUP 1J -135 - Conoc Ph 164 c_onocasntap KB-Grd (K) Rig Release Date ... 44.00 5/23/2007 Well Confi9. MULTIPLE LATERALS - 1J- 135, 5292012 10'36'.02 AM - � Schematic - Actual _HANGER, 4 Perforations & Slots Shot Top (TVD) 8tm (TVD) Dena � Top (ftKB) Btm (ft68) (RKB) (MO) Zona Date ( Type Comment 9,829 11,845 3,605.0 3,585.2 WS B, 1J- 135 4/30/2007 32.0 SLOTS 2.5 "long X .125 "wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg 11,847 17,681 3,585.0 3,513.2 WS B, 1J -135 4/30/2007 32.0 SLOTS 2.5 "long X .125 "wide, 4 crcumferencial rows/ft, 3" centers staggered 18 deg CONDUCTOR, _, Notes: General & Safety H -122 End Date Annotation 5/23/2007 NOTE: MULTI - LATERAL WELL -1J -135 (BSAND), 1J -135L1 (D -SAND) 8/9/2008 NOTE: View Schematic w/ Alaska Schematic I Mandrels, 2,299 - SURFACE, • 44 -3,463 SLIPSTOP, Eli 7,144 NIPPLE, 7,146 VALVE, 7,146 • lr SLEEVE, 7,163 MB Era PUMP SUB. 7,203 i 6E86087 ?, -.i 7,212 PUMP 2 i 7212 12 a DISCHARGE, 7,224 ■ ESP PUMP, 7224 DISCHARGE, , 7,237 ■ ESP PUMP, 7,238 Gas sap 7,2 7,251 s! NIPPLE, 7,257 El SEPARATOR, 7257 _\ , I1 Y-BLOCK. 7,259 l : NIPPLE, 7,260 Inc ■ Teleswlvel, Mk gmi 7,262 Seal Assy, = 7,262 MOTOR, SEAL A ,276- El SEAL ASSY, 7,287 MOTOR, 7,301 Mt SENSOR, i 7,312 Plug, 7,314 SENSOR, t 7,315 sr PLUG, 7,317 WLEG, 7,340 11 N D -SAND WINDOW, 9,097 -9,107 HANGER D4.93D, J 9,0 -SAN0, I _ I 1 1 NTERMEDIATE, 41 -9,819 SLOTS, _ill a 9,829-11,B45 i • SLOTS, 11847- 17,681 + ' 1 B LINER, Jf 9,167 - 17,723 TD (1J -135), _ Y t 17,735 i • 7r ,~ ~~ . ~~...= ~~ -~ a '~-~ ~. ,~ ~R- ~ a~ .MICROFILMED. 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Micro6lm_Marker.doc STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~1 REPORT OF SUNDRY WELL OPERATIONS ~. operations Pertormed: Abandon """' Repair well ~/ Rug Perforations ~°"` Stimulate Other Alter Casing Pull Tubing ~ Perforate New Pbol "'~"' Waiver "°"; Time Extension ; Change Approved Program Operat. Shutdown ~'°' Perforate Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory """ 207-038 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-00 7. Property`Resigna~on: ~ 8. Well Name and Nu ber: ~ ~ ~ ~ ~~ ADL 2566 , 25662, 380058 1 J-135 ~ 9. Field/Pool(s): Com~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17735 feet Plugs (measured) None true vertical 3512 feet Junk (measured) None Effective Depth measured 17720' feet Packer (measured) 9167 true vertical 3512' feet (true verucal) 3539 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 121' 121' SURFACE 3421 13.375 3463 2215' INTERMEDIATE 9778 9.625 9819 3604' B LINER 8556 5.5 17723 3513' d• T ' f ~ ~ "~ ~~ : Perforation depth: Measured depth: 9829'-11845', 11847-17681' F "`:-~~-'~~~= i~~~ :. ~~' t ~ ~~' True Vertical Depth: 3605'-3585', 3585'-3513' Tubing (size, grade, MD, and TVD) 4.5, L-80, 7548 MD, 3258 TVD ~~~~~a ,~® V Packers & SSSV (type, MD, and TVD) MLZXP Liner Top packer MD= 9167 TVD= 3539 11. Stimulation or cement squeeze summary: Intervals treated (measured): 11011@ ~~~'~~~~~~ Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 312 45 11 -- 218 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service . Well Status after work: Oil /' Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG "; GASINJ WIND ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Erik Nelson @ 263-4693 Printed Name ~k N Title Wells Engineer Signature `l Phone: 263-4693 Date Form 10-404 Revised 7/2009 RB~S MAR 0 9 Z~I~I~~_ ~' 3•/o.~v Submit Original Only `,, ~, ~ ,, - KU P ~ t ~OCtOCtj~11~~Ip5 1 Well Attributes Max 'aIs}k~,1116., ( ~ Wellhore APVUWI Field NameWell Statu. I~~I (-, ( 500292334900 WEST SAK (PROD 92` < nt N25 !pplnl Date An otation IEntl Date well comg;.Ml1LTIPLE IATegnts u ~ SV. NONE i 1U 7/1012009 (Last WO: 2/92010 SGtemau Apu4l A otation Depth (ftK8) IEntl D t Annotation L t i.fg: SLM 7,400.0 1012 I U~ Rev Reason: Wol kover. Sat Sllpstop/CAT S _v._. ___ _.. _. _ _ _ _ - ... Casing Strings _ g p n g g IU ... Top (ftK8) Sef D pth (t Sef D pth (ND) ... HANGER 38 ~ ';,. C Ds f IiStr O ~SUi ---- -- -- CONDUC I (JR 20 'I I _. 1 ~ 43 7 I 122 2 122.2 _ __ C slog Descnp[IOn (Str g O Str g ID ... CONDUCTOR, 4d-122 Mandrels, 2.299 SURFACE, 44-3,663 NIPPLE, 7,146 SLEEVE. ],163 sENSOR~?. ~,z~z NIPPLE. ] 25] V-BLOCK. ] 255 NIPPLE. 7.260 Ttlesvnvel. ~ 7 262 \ PUMP TDG. ' ~ 26U DiscnARC~, ],271 -. ESP PUMP. ],2]t SEPARATOR, _ ] 284 SEAL ASSY. _ ].29U MOTOR. 7,304 SENSOR. 7,315 PLUG, 7,31 ] WLEG. ] 34U D-SAND I WINDOW. 9,09]-9.10] MANGER D SAND. ERMEDIATE, 41-9,819 SLOTS, r r mlg~:41,0 9.829-11,845 SLOTS, 1'.,84]-t ].681 r 1 a'S_.$ 9,094-9.352 Description String 0... R 5 1/2 -Details _ _ Top Depth (ND) Top Intl I pth (f .. Sat D pth (ND) ... 462.8 2,215.3 lapth (f... Sat Depth (ND) ... 819-0 3 604.2 lepih (i... Set Dep[h (ND) ... 107.0 3,528 4 leoth (i... Set Daoth /NDI ... 1 1 J-135 I TD IACt Btm (ftK8) ~ 17.735.0 .Rig Release Dat ' 5/23/2007 Motl ... (End Date ,g Top Thn BTC-mod Top (HKB) (kK6) (°) Item Description Comment ID (in) 9,167.0 3,538.8 81.84 PACKER MLZXP Liner Top Packer 9-5/8" (7.50" X 8.32") 7.500 9,188-2 3,543-1 84.351 HANGER FlexLOCk Liner Hanger 7" x 9-518" (6.09" X 8.30") 6.090 USHIN3 O D g D 7 ] 9,1949. 3,543.81 4.75" ID x 6.28" OD Bore Ex t. 1 0-07 Cas ing Seal 84.3 158E i 4 50!, , Tubing Strings f bing Des ption Suing O._ 'Str q ID .. Top (ftK8) Set Depth (f... Set Depth (ND) .. Str rig WL.. Str g String Top ThM ~ LSP Completion '~ 3 1/2 _590 38 5 7,341.0 3,209.6 9 30 i L 80 EUE 8rd Comm~lletion Det ails Top Depth (ND) Top Intl : Nom^.. Top (ftK8), (flKB) i (°) (tam Description Comment _ ID (1 ). 38.5 38.5 -0.O7 HANGER Vetco-Gray 11"x4 72"Hanger w/full jt of 4 12" tubing w/4.0909" lop coon 3.900 405 40.5 0.00 XO - I~Mur.ing Tubing wl X over 4 1/2" x 3 V2" EUE 8rd 2.990 7,146.2 3,162.3 75.42 NIPPLE Camco 2.873"DS Nipple 2.813 7,763.0 3,166.7 __ 7S.66ISLEEVE Baker"CMU"SLIDING SLEEVE (CLOSED) 2.812 7,211-5 3,178.31 75.83'SENSOF:?? 312"A-Well Discharge Pressure Sub 2.990 ~ 7,257.51 3,189.6, 75.98 NIPPLE Top Nipple 2.81" PTX Nipple 2.820 7,258.9 3,190.0 75.99 Y-BLOCK 9 5/8" Y-Tool Assembly - _ - 2.880 7,2603 3,790.3 75.99 NIPPLE By Pass Nipple 2.75" XN Nipple wl Standing Valve in Place 2.750 7,261.7 3,190.6 75.99 Teleswivel Telescopic Swivel, w/20" stroke 2.990 7,340.2 3,2094 76.25 WLEC, iWireline Entry Guide-27/5" PT-X Bax Up 2.360 Tubing Description Set Depth (f... Set Depth (ND) ... String Wt... Str rig .. (String Top Thrd String 0... String ID ... Top (ftK8) ESP Pump,Motor ( 5.13 7,260.0 7,3174 3,204.0 1 System Comple tion D_ et ails _ ~-~ ,. ~ .:_s._ Top Depth (ND) Top Intl Nomi... Top (ftK8) (ftK8) (°) Item Description Comment ID (in) 7.260.0 3,19Q2 75991,pUMp -:'BG Pump Sub 2990 7,269.8 3,192.6 76.021X0 -Reducing Xover 3S New Vam x 2 875 EUE 8rd 1-500 7,270.7 3,192.8'1 76.02 DISCHARGE Discharge Head 400 Series ~ 0.000 7,271.2 3,192.9 76A3 ESP PUMP Centrilift Pump 400 series FC 1600 0.000 7,284.3 3,196.1 76.07 SEPA,RAI OR Cenirlilift Gas Separator 0.000' 7,289.8 3.1974 76.09 SEP.L .4S S'r' Centrilift Lower Seal 513 Series 0.000 7,303.6 3,200.7 76-13 MO-I OR Centrilift Upper Motor 562 Series 0.000 7,314.6 3,203.3 76.17 SENSLIR Centrilift Sensor 0.000 7.316.6 3,203-8i 76.17 PLUG Dummy Neck 0.000 ~ 1 ~ _.. _. __ ...--'^ _-__- -- _ Rerfora tions $ Slots. ._ -- .. ___ ---- -- snot ' Top(rvo) BnnfrvD) '. Dana Top (flKB) Bim (flKB) (ftK8) )ftK8) Z n Date (sh. Typa Comment _ 9,829 11,845 3,605 0 3, ;852 WS B, iJ-135 4/30/2007 32.0 SLOTS 25"long X .125'Wide, 4 circumferential rows/ft, 3" centers staggered 18 deg 11 E47 17,681 3,585.0 3,513-2 WS B, 1J-135 4/30/2007 32.0 SLOTS 2.5"long X .125'wide.4 circumferential rowslft, 3" centers staggered 78 deg Notes: General & Safes > _ End Date _ AnnoUhon 5/23/2007 NOTE: MULTI-L~IEI=AL WELL-1J-135 (BSAND), iJ-13SL1 (D-SAND) 8/9/2008 NOTE: VIEW SCti[IV41 fIC w/9.0 TOp Depth Top Port (ND) Intl OD Vaiva Latch Size TRO Run >p (ftK6)~ (flKB) (°) Make Model lint Serv TYPe TYPe (In) (Psi) Run Date__ C_om... 2,298.81 1,908.7 70-98 CA'oICOKBIvIG 1 ESP SOV BEK 0.000 0.0 2/7/2010 B LINER, 9,167-17,]23 \ TD (1 J-135), 17,]35 1J-135 Pre and Post Rig Events DATE SUMMARY 12/3/09 PRE RWO T-POT (PASSED ), T-P~T (PASSED ), UT-POT (PASSED ), UT- PPPOT (PASSED ), LT-POT (PASSED ), LT-PPPOT (FAILED ), IC-POT PASSED ), IC- PPPOT (PASSED ), FT-LDS ALL NORMAL. 1/4/10 MEASURED SBHP @ 7011' SLM( 1170 psi ). GRADIENT @ 1300' SLM (514 psi) & GRADIENT @ 100' SLM (98 psi ). COMPLETE 1/30/10 PERFORMED TRACTOR DEPLOYED MIT CALIPER LOGGING PREPARATION: SWAPPED UNIT TO BIG CABLE; OPERATIONAL CHECKS OF HEAD AND WELTEC TRACTORS; OPERATIONAL CHECKS OF HES AND PDS SONDEX 24- FINGER AND 40-FINGER CALIPER TOOLS. 1/31/10 PERFORMED TRACTOR DEPLOYED MIT CALIPER LOGGING PREPARATION: SWAPPED UNIT TO BIG CABLE; OPERATIONAL CHECKS OF HEAD AND WELTEC TRACTORS; OPERATIONAL CHECKS OF HES AND PDS SONDEX 24- FINGER AND 40-FINGER CALIPER TOOLS. 2/1/10 STANDBY FOR TRACTOR DEPLOYED MIT (PDS) CALIPER LOG. 2/4/10 STANDBY FOR TRACTOR DEPLOYED MIT (PDS) CALIPER LOG. 2/5/10 CABLE HEAD SHORTED ON OUR FIRST WELLTEC TRACTOR/ PDS 40 ARM CALIPER RIH. REHEADED CABLE AND MAKING SECOND ATTEMPT TO COMPLETE CALIPER RUN AT THIS TIME. IN PROGRESS... 2/6/10 ATTEMPTED TRACTORING PDS MIT TOOL. TRIED USING 2 DIFFERENT CABLEHEADS THAT BOTH CHECKED GOOD ON SURFACE BUT FAILED DOWNHOLE. TOOLSTRING WORKED ON 3RD ATTEMPT BUT TRACTORS COULDN'T GET ENOUGH POWER TO OPERATE. POOH AND RIGGED DOWN PER COMPANY MAN. CURRENTLY INVESTIGATING PROBLEM ON E-LINE UNIT. 2/13/10 SET 2.812" D CAT STANDING VALVE IN DS NIPPLE AT 7149' RKB. SET 2.72" SLIP STOP ON TOP OF STANDING VALVE. FREEZE PROTECT TUBING W/ 30 BBLS DIESEL. WELL LEFT SHUT-IN. JOB COMPLETE Conoc©Phillips Time Log & Summary We/Iview 4Ye4 ReAorUn9 Report Well Name: 1J-135 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/21/2010 3:00:00 PM Rig Release: 2/9/2010 11:59:00 PM Time Lo s Date. From To Dur S. De th E. De th Phase Code Subcode T Comment 1/21/2010 24 hrsummarv RDMO off 1J-162, Move and spot double mats, MIRU Nordic Rig 3. 12:00 19:00 7.00 COMPZ MOVE MOB P Move Nordic Rig 3 off of 1J-162 and s of at 1 J-135 Move and set double rig mats on well. Accepted Nordic Rig 3 at 15:00 hrs on 01/21/2010 b R. Dolcater. 19:00 23:00 4.00 COMPZ MOVE RURD P Move Rig over 1J-135 Wellhead. Center and level Rig. Spot and rig up support equipment. Load Pits with 8.7 KCL water. Rig up circulating lines in cellar. 23:00 00:00 1.00 COMPZ WELCTI MPSP P Pick up Lubricator. Pull BPV. Lay down same. Tubing pressure = 40 psi, IA pressure = 990 psi. OA = 500 psi. No communications between the Tubin and the IA. 1 /22/2010 Complete rig up on 1J-135. Test lines. Bleed gas from IA. Circulate and kill well. Install BPV. ND Tree and NU BOPE. Test BOPE. Pull Blanking Plug and BPV. Un-seat Tubing Hanger. Pump HOT Seawater/6% KCL down Tubin to clean u Well. 00:00 00:30 0.50 COMPZ WELCTI SFTY P Held PJSM on PT lines @ 250/2,500 si . 00:30 06:30 6.00 COMPZ WELCTI CIRC P Pressure test lines at 250/2,500 psi. with water. Blow down lines. Open IA with 990 psi and bleed gas through choke to Tiger Tank. Bleed IA from 990 psi down to 250 psi. Pressure has stabi-ized at -250 psi. Line up to pump down the IA with Pump #2. Open Tubing. "0" pressure. Bring Pump on line at 2.0 bpm/340 psi. Increase rate to 4.0 bpm (69 spm) at 450 psi. 50 bbls pumped away at 350 psi. Increase rate to 5.0 bpm (86 spm) at 330 psi with 100 bbls pumped away. 200 bbls pumped away at 210 psi. With 440 bbls pumped away at 230 psi. Noticed a slight diesel "dripple" comin from the tubin . Page 1 of 19 ~~ TLme Lo' `s ..:Date From To Dur S. De th E De th Phase-..Code Subcode T .Comment 06:30 08:00 1.50 COMPZ WELCTL CIRC P Strap tank and had recovered 197 bbls of diesel. Pump down TBG @ 6 bpm ICP of 350 psig and FCP 90 psig after 121 bbls pumped. Strap kill tank and monitor well -had 100 psig on the IA. Pump 100 bbls down TBG @ 100 psig @ 6 bpm with IA on Full O en choke. 08:00 09:30 1.50 COMPZ WELCTL OWFF P Monitor well with 0 psig on the TBG and 20 psig on the IA. Bleed IA off to Kill tank and Blow down lines. Open up well and SITP @ 250 psig. and SIICP 30 si . 09:30 10:00 0.50 COMPZ WELCTL CIRC P Pump 50 bbls 6% KCL Seawater down TBG. 10:00 11:30 1.50 COMPZ WELCTL OWFF P Monitor well while emptying Kill Tank and Loading pits w/ 6% KCL. Pit Volume @ 621 bbls. SITP @ 90 psig and SIICP @ 90 psig, Open TBG and IA to choke and slowly bleed off ressure to 0 si . 11:30 12:15 0.75 COMPZ WELCTL CIRC P Fill TBG w/ 134 bbls 6% KCL Seawater using rig charge pump with IA o en to kill tank. 12:15 12:45 0.50 COMPZ WELCTL OWFF P Monitor well -TBG and IA both on a vacuum. 12:45 13:00 0.25 COMPZ WELCTL OTHR P Blow down lines to kill tank. 13:00 13:30 0.50 COMPZ WELCTL MPSP P Install 4" HBPV 13:30 14:00 0.50 COMPZ WELCTL SFTY P Held PJSM on Nipple down of tree. 14:00 15:00 1.00 COMPZ WELCTL NUND P ND Tree and Adapter, set Blanking lu . 15:00 15:30 0.50 COMPZ WELCTL SFTY P Held PJSM on NU BOPE. 15:30 19:30 4.00 COMPZ WELCTL NUND P PU and Install 13 5/8 BOP and riser. (Spot Crane and swap out ESP reels on S oolin Unit . 19:30 00:00 4.50 COMPZ WELCTL BOPE P Test BOPE er CPAI/A requirements at 250/2,500 psi. Perform Koomey draw down test. State's right to witness test was waived b C. Scheve. 1 /23/2010 ° r floor. Be in t sin le down 4 1/2" ESP Com I tion. 00:00 01:30 1.50 COMPZ WELCTL BOPE P Complete BOPE test. Good tests. Blow down lines. Rig down test e ui ment. 01:30 02:00 0.50 COMPZ WELLPF MPSP P Pull Blanking Plug and BPV. Lay down same. Well on vacuum. 02:00 04:00 2.00 COMPZ RPCOM THGR P Ready floor to un-seat Tubing Hanger, Pick up Landing Joint. Back out lock down pins. Pull Tubing Hanger free at 145K. Tubing movin free at 120K. Page 2 of 19 e~ 1 J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 04:00 04:30 0.50 COMPZ RPCOM SFTY P PJSM with Lil' Red, Rig Crew, Mud Man, and Vac Truck Drivers. Discussed Pressure testing and working around hot water. Reviewed tanned o erations. 04:30 13:30 9.00 COMPZ RPCOM CIRC P Lil' Red pressure test line at 250/2,500 psi. Good test. Stage Vac Trucks. Lil' Red began pumping 180+ deoree Seawater/6%KCL down the Tubin at 2.0 bpm/500 psi. No returns from IA. Pumped away 230 bbls at 2.0 bpm/0 psi. No returns. Change over to the IA and pump 253 bbls of 880 bbls @ 2 bpm @ 500 psi and started taking returns. Pumped 627 bbls after gaining circulation and recovered a total 13:30 14:00 0.50 7,566 7,557 COMPZ RPCOM SFTY P Held PJSM on laying down pipe and awareness of hot tubulars. 14:00 15:30 1.50 7,557 7,530 COMPZ RPCOM PULD P Pull hanger to rig floor, String sheave, and continue to POOH and Laying down decompletion, Stra in and tall in all. 15:30 00:00 8.50 7,530 3,332 COMPZ RPCOM PULD P Have 135 Joints of 4 1/2" Tubing singled down at Midnight. Continue pulling from 3,332-ft spooling ESP Cable. Strin wei ht 75K. 1 /24/2010 n " Pi Ram finish loading Pipe Shed with remaining 5" Drill Pipe. Make up 6 1/4" Hybred and rack back in derrick. MU BHA #1. RIH picking up Drill Pi e. 00:00 06:30 6.50 3,332 222 COMPZ RPCOM PULD P Continue to single down 4 1/2" ESP Com letion. 140 'ts total. 06:30 07:00 0.50 222 71 COMPZ RPCOM OTHR P Strip flat guards, Protectolizers, and la down u er'ewel above intake 07:00 09:30 2.50 71 0 COMPZ RPCOM ALFT P Jear down and inspect ESP components, Found Heavy scale around the top of the motor section in the Pot head area, Coupling was stuck in the intake and TTC Crossover. Burn on the pot head. Brunt oil in the motor and the motor was also grounded. The Lower Splice megged good. Recovered: 15 of 20 SS Bands, 128 Cannon Clamps, 3 Protectolizers, and 2 Flat uards. 09:30 11:30 2.00 0 0 COMPZ RPCOM OTHR P Wrap ESP Cable spool, Clean and clear rig floor, and RD TBG Equipment. Load ESP in Boxes and offload all decom letion. 11:30 14:30 3.00 0 0 COMPZ RPEQPI OTHR P Continue to load 5" DP in pipe shed. Ran out of stri in . 14:30 16:00 1.50 0 0 COMPZ WELCTt BOPE P Install test plug on 5" DP and RU Test equipment. Test Lower VBR's, ~~ Upper VBR's and Annular, Ibop and TIW valve 250/2,500 si . Page3 of 19 a Time Lo s 'Date ...From To Dur S. De th E. De th Phase Gode Subcode T .Comment 16:00 16:30 0.50 0 0 COMPZ RPEQPI OTHR P Set wear ring 16:30 19:00 2.50 0 0 COMPZ RPEQPI OTHR P Continue to load 5" DP and 8 - 6.25" DC's in Pipe shed. Load Baker E ui ment and Tall all. 19:00 19:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss the hazards in picking up 6 1/4" Drill Collars and making up the stands of Push Pipe. Also covered picking up the BHA for the drift run 19:30 22:00 2.50 0 0 COMPZ RPEQPI PULD P Make up Push Pipe Assemblies (4 stands and stand in Derrick. 22:00 00:00 2.00 0 91 COMPZ RPEQPI PULD P Make u BHA #1. Dumm Drift Run 1 /25/2010 RIH with BHA #1 to -7 400-ft Reverse in with a 30 bbl 776 Mud Lube sweep and chase with 400 bbls SW/KCL. Continue RIH to 8,556-ft. Wash and ream through sections of scale down to the final target depth of 9,080-ft with no roblems. Circulate Well. 00:00 10:00 10.00 91 7,396 COMPZ RPEQPI PULD P RIH with BHA #1, Dummy Drift for LEM Assembly. Single in with 5" Drill Pipe from Pipe Shed. Begin gathering T & D @ 5,900' 135k up wt, 65k do wt.; 6,900' 150k up wt, 60k do wt.; 7,396' jt# 231 155k up wt, 58k do wt. 10:00 14:00 4.00 7,396 7,396 COMPZ RPEQPI CIRC P RU to reverse circ. Pump 30 bbl 1% 776 Mud tube / .5 Ib bbl polymer 34 funnel visc 6% KCL water (Apparent Visc of 10 cps. w/ PV of 5 and YP of 10) followed by 400 bbls of 6% KCL water 14:00 14:30 0.50 7,396 8,778 COMPZ RPEQPI PULD P Continue to RIH to 8,655' and set down 20k, picked and ran back down to 8,685' took wt. Ream thru @ 25 rpm's W/ 7k torque. Ream thru from 8,653' to 8,778'. 14:30 17:30 3.00 8,778 8,778 COMPZ RPEQPI CIRC P Reverse circulate 300 bbls (2 DP Vol.) had gas and oil influx, Shut down and RU to tiger tank to send returns to. Continue to reverse circulate 5 b m 120 si . 17:30 20:30 3.00 8,778 8,935 COMPZ RPEQPI REAM P Continue to ream down from 8,778' to 8,935'. Attempt to make a connection. However, Well is out of balance and flowing back up the tubing. Circulate Tubing volume x 2 at 5.0 b m/125 si. Page 4 of 19 ~~ 'Time Lo s Date From.. To Dur S._De th E. De th Phase Gode Subcode T Comment 20:30 22:00 1.50 8,935 9,080 COMPZ RPEQPI REAM P Continue to ream and wash down with no problems from 8,935-ft. to 9,065-ft. at 4.5 bpm/120 psi. Non-rotating up weight = 150k. Non-rotating down weight = 65k. Rotating up weight = 125k. Rotating down weight = 95k. RPMs = 25. Torque = 10k. Short-trip each joint. "Slide" the final 15-ft down to the target depth at 9,080-ft. Back ream to 9,065-ft. Run back into 9,080-ft and ark BHA. 22:00 00:00 2.00 9,080 9,080 COMPZ RPEQPI CIRC P Reverse circulate tubing volume x 2 at 5.0 bpm/150 psi. Swap over to circulate the long way. Pump a 20 bbl 776 Mud Lube sweep and chase with 161 bbls of SWlKCL. 1 /26/2010 Continue chase pill. POOH from 9080'. Breakout, lay down BHA. Clean JB's recovering 20# of iron debris. Sli & cut drillin line. Load tools, Mu BHA #2, TIH to 6073 with Snozzolator assm . 00:00 03:30 3.50 9,080 9,080 COMPZ RPEQPI CIRC P Continue with circulating the long way. Pumped a second 20 bbl 776 Mud Lube sweep and chase with 650 bbls SW/KCL. Estimated 60 - 70 returns through out circulation. Saw both sweeps go across the Shaker. However, saw no solids. 03:30 09:30 6.00 9,080 91 COMPZ RPEOPI TRIP P Ready floor. Trip out with 5" Drill Pipe and BHA #1, standing Drill Pipe back in Derrick. Pick up weight off target depth = 165k. Pulled 5 stands with normal weight. Monitor hole. Good. Test Crown-O-Matic. Good. Doub-e pipe displacement while TOOH. From 8,000-ft up to 7,750-ft notice a 10 k over pull increase, then dropped back to normal up weight. Weight check at 7,000-ft, up 165k, down 68k. Weight check at 6,000-ft, up 155k, down 65k. Continue POOH. 09:30 12:00 2.50 91 0 COMPZ RPEQPI PULD P Clean magnet's and empty boot baskets. Recovered 4.5 SS Bands. 20 Ibs of metal shavings and misc. metal from cutting window at start of well. Off load BHA #1 from ri . 12:00 14:00 2.00 0 0 COMPZ RIGMNT RGRP P Slip and Cut 84' of drill line. 14:00 14:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM w/ crew and third party services on Snozzlator BHA #2 14:30 15:30 1.00 0 COMPZ RPEQPI PULD P Pull tools to rig floor. Prep rig floor for makin u BHA. 15:30 21:00 5.50 202 202 COMPZ RPEQPI PULD P Make up BHA #2. BHA consisted of Snozzolator assembly with wash tools spaced out accordingly, with junk baskets and string magnets. Total BHA len th = 202.28' Page 5 of 19 Time Lo s Date From To Dur S. De th -E. De th Phase Code Subcode T Comment 21:00 00:00 3.00 202 6,073 COMPZ RPEQPI TRIP P Trip in hole with BHA#2 from 202' - 6073'. Up Wt - 127K, SO WT - 70K. Observed well taking entire displacement plus. Fill hole with 10 - 15 bbls / hr. Fluid loss for the day = 244 BBLS. 1 /27/2010 Continue TIH with Snozzolator assm from 6073' - 9040'. RU and wash down through Hook Hanger down to 9135' DPM. Observed hard tag and could not wash past this point. RU & Reverse circulate annulus volume pumping a 45 BBL Hi Visc sweep with 776 Lube. Re- attempt to make hole with no success. POOH, rack back DP. Lay down BHA, recovering approximately 20# of iron and aluminum debris, & SS bands. Make up 2 7/8" Mule shoe assembly, Trip in hole to wash down from 903' - 9324' DPM midnigt depth. No hard tag observed. Fluid loss for 24 HRS - 1543 BBLS 00:00 01:30 1.50 6,073 9,040 COMPZ RPEQPI TRIP P Continue trip in hole with BHA #2 from 6073' - 9040' DPM. Up Wt - 152K, SO WT - 67K. Observed well taking entire displacement plus. Fill hole with 10 - 15 bbls / hr. 01:30 04:00 2.50 9,040 9,135 COMPZ RPEQPI CIRC P Obtain parameters. Begin washing down @ 5 BPM - 750 PSI, no rotation, from 9040' through hook hanger assmy @ 9093', down to 9135' with the bullnose. We observed the assembly stop, and repeated attempts to gain hole, with various pump rates from 2 to 9 BPM. Max set down weight = 8-10K. Up WT - 152K, SO WT - 67K. The drill string had free movement when working it. Fluid losses remained steady taking everything we pumped, with no returns. Suspect bullnose may be plugging or packing off, as we observed a slight increase in pump pressure when setting on bottom at 9135'. 04:00 06:30 2.50 9,135 9,135 COMPZ RPEQPI FCO T Discuss options with engineer. Decision to close annular, pump down annulus at rates to flush the annulus, and spot a 45 BBL pill on bottom. After 50 BBLS, pull on drill string to verify assembly remained in free movement. rates from 3-8 BPM. Continue checking free movement in strip . 06:30 07:00 0.50 9,135 9,138 COMPZ RPEQPI FCO T Attempt to clean out fill and made 3' and was unable to get any deeper. Blow down To drive. 07:00 13:00 6.00 9,138 202 COMPZ RPEQPI TRIP T Pooh for BHA change to 202' 13:00 15:00 2.00 202 0 COMPZ RPEQPI PULD T POOH w/ BHA #2 and clean magnet's -recovered mist metal shavings and chunks of iron approximately 10 lbs., boot baskets had small amount of fines and 1 large piece of aluminum -looks like 9 5/8" cmt equipment. Nogo showed no si ns hap u in hook hap er. Page 6 of 19 Time to s _ Date From To Dur S: De th E. De th Phase Code Subcode T Comment 15:00 16:00 1.00 0 0 COMPZ RPEQPI OTHR T Load and Un-load tools, prep pipe shed for BHA ick u .Held PJSM. 16:00 18:00 2.00 0 352 COMPZ RPEQPI PULD T PU and MU BHA #3. 2 7/8" Mule shoe assembly with 289' of 2 7/8" DP. Total BHA len th = 351.76'. 18:00 22:30 4.50 352 9,063 COMPZ RPEOPI TRIP T Trip in hole from 351' - 9063'. Observed well taking displacement lus. 22:30 00:00 1.50 9,063 9,324 COMPZ RPEQPI WASH T Make up Top Drive and obtain parameters. UP WT = 160K, SO WT = 63K. Pumps at 5 BPM - 180 PSI. Begin washing down, observing mule shoe through Hook hanger with no issues. Continue to 9150'. Pull up, and repeat. Pull up and turn mule shoe to attempt identify wellbore we are entering. Slack off and tag at 9110' DPM. repeat. Suspect that we had tagged upon bottom of the window. Pull up and turn mule shoe again, slacking off to tag at 9167', which is the top of the MLZXP in mother bore. Work through 9167, contiuing washing down to 9324' with no issues. Observed 2-5K WOB, allowing sand to wash away. Fluid loss for the da = 1543 BBLS total. 1 /28/2010 Continue wash down from 9324' - 9354'. reverse circulate a 30 BBL pill, and chase with 670 BBLS. POOH, racking back DP. Make up Snozzilator wash tool assmy. TIH. Wash through Hook Hanger assmy down to 9137'. Tagged up, contnue work string to gain hole to 9142' (5'). Reverse Circulate while pumping a sweep to aid in cleanin tools. Unsuccessful in ainin more hole. 00:00 01:00 1.00 9,324 9,354 COMPZ RPEQPI WASH T Continue washing down with 2 7/8" mule shoe assembly from 9324' - 9354' DPM. Observed 2-5 K WOB allowing sand to wash away. Repeat wash last stand. Pumps at 5 BPM - 200 PSI 01:00 03:30 2.50 9,354 9,354 COMPZ RPEQPI CIRC T RU, Reverse Circulate 30 BBLS of Hi Visc pill with 776 Lube, chase with 670 BBLS of 6% KCI, at 5 BPM - 120 PSI. Observed minimal returns of approximately 1!2 to 1 BBL/ min. Work string every 50 BBLS to verify free movement. O en annular. 03:30 04:00 0.50 9,354 9,354 COMPZ RPEQPI OWFF T Monitor well, verify fluid dropping in stack.Held PJSM. Discuss safety & hazard recognition issues. Discuss rocedure to POOH, rackin DP. 04:00 10:30 6.50 9,354 351 COMPZ RPEOPI TRIP T POOH slowly, observing free movement, no overpull. Pull to top of hook hanger at 9094'. Contiue POOH racking back 5" DP. Observed hole takin dis lacement lus. 10:30 12:00 1.50 351 0 COMPZ RPEQPI PULD T Lay down BHA #3 recovered small amount of metal fines 12:00 13:00 1.00 0 0 COMPZ RPEQPI OTHR T Clean out boot baskets and bend 'oint of 3 1/2 8rd to 15°. Page 7 of 19 i Time Lo s • Date .> From To Dur S. De th E. De th .Phase .Code Subcode T Comment 13:00 13:30 0.50 0 0 COMPZ RPEOPI SFTY T Held PJSM on making up BHA. 13:30 15:00 1.50 0 202 COMPZ RPEOPI PULD T Make up BHA #4 15:00 19:30 4.50 202 9,008 COMPZ RPEOPI TRIP T RIH f/ 202'to 9008' DPM. Observed well takin all dis lacement lus. 19:30 00:00 4.50 9,008 9,142 COMPZ RPEOPI WASH T MU Top drive. Obtain parameters. UP WT = 157K, SO WT = 76K. Pumps at 5 BPM - 540 PSI. Slack off to wash through Hook Hanger with no issues. Tag up at 9137' DPM. Repeat tag. Continued with repeated attempts to verify wellbore, and wash down, we reverse circulated ,and pumped a high visc sweep down the drill string utilizing max rates with success only to 9142' (5'). Reverse circulated 50 BBLS before POOH. 1 /29/2010 POOH from 9142' to 5885'. At 0230 HRS, Security announced Phase 3 Conditions. Stabbed valve in drill string. Shut down, wait on weather. Load 280 jts of 2 7/8 DP in pipe shed. RU, pull wear bushing, set test plug. and perform scheduled BOP test. Witness of test waived bu AOGCC rep Bob Noble. Fluid loss today = 349 BBLS 00:00 02:30 2.50 9,142 5,885 COMPZ RPEQPI TRIP T POOH from 9142' - 5885' DPM. Observed hole taking all dis lacement lus. 02:30 23:30 21.00 5,885 5,885 COMPZ RPEOPI OTHR T Security announced Phase 3 conditions field wide. Shut down. Secure well. Wait on weather. Fill hole with 20 BBLS 6% KCL every hour, continuing to monitor well. Conserve Fuel & Water. Held PJSM with crew. Minimize all operations, and stop traffic movement on pad except to clear a path from rig to rig camp. Load 280 jts of 2 7/8 DP in pipe shed while waitng for weather to clear.Held PJSM. SDiscuss safety & hazard recognition issues. Discuss procedure to test BOP's. Rig up and pull Wear bushiing, Install Test plug. Test BOP's. 23:30 00:00 0.50 5,885 5,885 COMPZ RPEOPI BOPE T Security lifted the Phase 3 conditions. Continue test BOP's. choke manifold, HCR valves and all rig floor safety valves. Fluid loss toda = 349 BBLS 1 /30/2010 Complete BOP Test. Witness of test waived by AOGCC rep Bob Noble. -Complete loading 280 jnts of 2 7/8" PAC DP. Phase 3 conditions lifted. Install wear bushing. Continue POOH with BHA #4. lay down washng tools. MU 2 7/8°' Mule shoe assembly. TIH. To work through Hook hanger and MLZXP packer in B Lat with no issues. Continue wash 5 1/2" slotted liner to 9463' DPM. Total fluid losses toda = 1146 BBLS. Page 8 of 19 1 ~ .Time Logs Date From To Dur S. De th E. De th Phase .Code _ Subcode T Comment 00:00 02:30 2.50 5,885 5,585 COMPZ RPEQPI BOPE T Continue test BOP's. choke manifold, HCR valves and all rig floor safety valves. Perform Koomey test with 200 PSI increase in 16 seconds, and full 3000 PSI in 2 min - 28 seconds. 02:30 04:00 1.50 5,585 5,585 COMPZ RPEQPI BOPE T Rig down test equipment. Blow donw lines, choke & degasser. Pull test plug, install wear bushing. Install mouse hole. Prep floor for POOH. Held PJSM, discussing safety & hazard reco nition issues. 04:00 08:00 4.00 5,585 0 COMPZ RPEQPI TRIP T POOH with BHA #4 from 5585' to surface. Breakout & lay down snozzilator wash tool assembly. Observed hole taking displacement plus. Fill backside with 20 BBLS eve hour. 08:00 11:00 3.00 0 0 COMPZ RPEQPI PULD T Break out & lay down BHA. Inspect wash tools and stop sub. Wear marks on stop sub indicated Hook Hanger may have been repositioned, or turned some. Recovered approximately 10# of fne iron on the string magnets. Decision to make up _ 7/8" Mule shoe assembl . 11:00 12:00 1.00 0 0 COMPZ RPEQPI OTHR P Clean & clear rig floor area. Prep tools for next BHA. Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to pick up DP from the i e shed. 12:00 21:00 9.00 0 8,884 COMPZ RPEQPI PULD P Make up 2 7/8" Mule shoe on PAC DP. Continue trip in hole picking up a total of 280 jnts of PAC DP. BHA lenagth = 8883.88'. Observed hole taking displacement plus. Fill backside with 20 BBLS eve hour. 21:00 21:30 0.50 8,884 8,884 COMPZ RPEQPI PULD P Change out DP running equipment, and RU for 5" DP. 21:30 22:30 1.00 8,884 8,884 COMPZ RPEQPI PULD P Make up Crossovers and remaining BHA including BJ, OJ and P.O. Sub. Run 3 stands of 5" DP. .Page 9 of 19 • • Time Lo s Date. From To Dur S. De th E. De th Phase Code Subcode T Comment 22:30 00:00 1.50 8,884 9,463 COMPZ RPEOP~ WASH P Make up Top Drive. Obtain parameters. UP WT = 95K, SO WT _ 63, ROT WT = 73K, with 14 RPM's and 2K TO. Pumps on at 3 BPM - 800 PSI. work through Hook Hanger area at 9094 with no issues, and down to top of MLZXP at 9167'. Tag up verify depth. Repeat tag. Pull up and begin slowly rotating down through MLZXP with no issues. Continue washing down each stand at 10-12 FUMin, with 3 BPM, and pumping tubed fluid in annulus to aid in friction reduction. No tag up or torque issues observed. Midnight dpth = 9463' DPM -Total fluid lost toda = 1146 BBLS 1 /31 /2010 Continue wash 5 1/2" slotted liner to 13824' DPM. Pump sweeps as need in order to clean hole, Observed no sand returns at surface. Avg pump rate @ 6 BPM - 900-2600 PSI. Observed possible rubber plug being pushed into the hole as pump pressure increase to 3000 PSI when on bottom. Mix & pump a HiVisc Lube sweep, reverse circulating entire 672 BBL annulus volume, while working drill string up through closed annular. Fluid loss for the da = 2161 BBLS. 00:00 10:30 10.50 9,463 12,487 COMPZ RPEOPI WASH P Continue wash 5 1/2" slotted liner from 9463' - 11,266' DPM. Obtain parameters. UP WT = 115K, SO WT = 71, ROT WT = 75K, with 14 RPM's and 2K TO. Pumps on at 3 BPM - 800 PSI, washing down each stand at 10-12 FUMin, with 3 BPM, and pumping tubed fluid in annulus to aid in friction reduction. No tag up or for ue issues observed. 10:30 14:00 3.50 12,487 12,487 COMPZ RPEOPI CIRC P Circulate 40 bbl Lube pill surface to surface @ 5 bpm @ 1,650 psig while reciprocating in 90' intervals. Increase PR to 6 bpm @ 3,000 psig ICP and 2,600 si FCP at BU. 14:00 15:30 1.50 12,487 12,847 COMPZ RPEOPI WASH P Continue wash 5 1/2" slotted liner from 12,487' - 12,847' DPM. Obtain parameters. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 2K TO. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 FUMin, @ 6 BPM, and pumping tubed fluid in annulus to aid in friction reduction. Acts as if fighting rubber ahead, but no torque issues observed. Page 10 of 19 l I' Time dogs `Date From. To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 17:30 2.00 12,847 12,942 COMPZ RPEQPI WASH P Circulate 40 bbl Lube pill @ 6 bpm @ 3,200 psig continue to wash down from 12,847' to 12,942' @ 14 rpms @ 3K torque @ 6 bpm @ 3,000 psig w/ 115k up wt while rot, and 85k do wt while rot. Lost 438 bbls while circulating since 12:00 hrs - equivilant to 80 returnsWash from 12847' - 12942'. DPM 14 RPM's 6 BPM - 3000 PSI. 17:30 18:30 1.00 12,942 12,942 COMPZ RPEQPI CIRC P Pump a 30 BBL sweep at 6 BPM. 18:30 21:30 3.00 12,942 13,727 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 12,942' - 13727' DPM. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 4K TO. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 FUMin, @ 6 BPM. 21:30 00:00 2.50 13,727 13,727 COMPZ RPEQPI CIRC P Discussion with Rig engineer. Mix up total of 150 BBLS of 3 PPB Flo-Visc, 3 %Lube 776. Rig up, Close annular bag with drill string on bottom. Pump 50 BBLS of the sweep, chasing with 6% KCL, reverse circulating @ 6 BPM - 120 PSI, while slowly pulling the string up 1 stand. When full stand pulled. Stop pumping, open annular. Rotate drill string and pump at 2 BPM to get back to bottom. Close annular and repeat operation as above, until pumped and entire 672 BBLS annulus volume. Observed no sand returns at surface, with fluid losses at 240 BPH. Total fluid losses for the da = 2161 BBLS. 2/01 /2010 Continue wash 5 1/2" slotted liner from 13824' - 17507' DPM. Pump sweeps as need in order to clean hole. Stop at depths of 15618, 16094, 17034, and 17507, closing annular and Reverse circulating 2 DP volumes, while working drill string up through annular. Avg pump rate @ 5-6 BPM 2600-3300 PSI. Fluid loss for the da = 2043 BBLS. 00:00 08:00 8.00 13,727 15,618 COMPZ RPEQPI WASH P Continue wash 5 1/2" slotted liner from 13,727' - 15,618 DPM. UP WT = 115K, SO WT = 85, ROT WT = 80K, with 14 RPM's and 4K TQ. Pumps on at 6 BPM - 3,000 PSI, washing down each stand at 10-12 FUMin, @ 6 BPM. Observed initial pump pressure up to 3400 PSI indicating we may have loaded the drill string up with sand debris. Observed pressure steadily come back down to 2700 PSI 6 BPM. 08:00 10:30 2.50 15,618 15,618 COMPZ RPEQPI CIRC P Pump 40 BBL Lube pill surface to surface 6 BPM 2,800 si . Page 11 of 19 C~ Time'Lo s Date From To Dur S. De th E. De th Phase Code ;> Subcode T Comment 10:30 13:00 2.50 15,618 16,094 COMPZ RPEQPI WASH P Continue to Clean out f! 15,618' t/ 16,094'. 140k up wt w/ no rot. 115k up wt and 90k w/ rot. Circ @ 6 BPM @ 2,670 psig @ 14 rpms @ 5k for ue. 13:00 14:30 1.50 16,094 16,094 COMPZ RPEQPI CIRC P Reverse Circulate 2 DP Vol. (320 BBLS) @ 6 BPM @ 250 psig w/ 240 bbl losses durin circ. 14:30 16:00 1.50 16,094 16,565 COMPZ RPEQPI WASH P Continue to Clean out f/ 16,094' t/ 16,565'. 140k up wt w/ no rot. 125k up wt and 85k w/ rot. Circ @ 6 BPM @ 2,700 psig @ 14 rpms @ 6k for ue. 16:00 17:30 1.50 16,565 16,565 COMPZ RPEQPI CIRC P Reverse Circulate 2 DP Vol. (320 BBLS) @ 6 BPM @ 250 psig w/ 240 bbl losses durin circ. 17:30 00:00 6.50 16,565 17,507 COMPZ RPEQPI WASH P Continnue wash 5 1/2" B Lat liner from 16565' - 17507' DPM. 140k up wt w/ no rot. 115k up wt and 90k w/ rot. Circ @ 6 BPM @ 3050 psig @ 14 rpms @ 7k torque. Stop and reverse circulate at depth of 17034' and 17507', while stripping drill string up through the annular to keep pipe moving. Fluid loss for the day = 2043 BBLS. 2/02/2010 Continue wash 5 1/2" slotted liner from 17507' - 17717' DPM.We stayed 5' off of bottom. Pump sweeps as need in order to clean hole. Close annular and pump 2 DP volumes down drill string, while working drill string up through annular. Avg pump rate @ 5-6 BPM 3300 PSI. Observed formation charged up. Allow fluid to bleed back to pits, gaining 114 BBLS. Monitor welll, Circulate bottoms up to ensure well dead. POOH Laying down 5" DP f/ 17,717' U 16,092'. Standby for Phase 3 Conditions, maintaining circulation and rotation. Fluid loss to formation for the da = 871 BBLS. 12,862 bbls total. 00:00 01:00 1.00 17,507 17,717 COMPZ RPEQPI WASH P Continue wash 5 1/2" B Lat liner from 17507' - 17717' DPM. 145k up wt w/ no rot. 125k up wt and 100k w! rot. Circ @ 6 BPM @ 3260 psig @ 14 r ms 7k for ue. 01:00 02:30 1.50 17,717 17,717 COMPZ RPEQPI CIRC P Rig up, close annular, and pump down drill string at 5 BPM, 3000 PSI for 2 drill string volumes. Stop pumps. Observe formation charged u ,with 28% flow. 02:30 04:30 2.00 17,717 17,317 COMPZ RPEQPI OWFF P Blow down Top Drive. Monitor well, observing 137 bbls flowed back. Watch well until small trickle of flow, slowly pulling 4 stands, no swasbbing, but fluid did not fall and 2.5 BBLS gained. Decision to circulate bottoms u . 04:30 06:30 2.00 17,317 17,317 COMPZ RPEQPI CIRC P Circulate bottoms up @ 5 bpm - 2430 psi. Periodically work drill string to observe free movement. 06:30 07:00 0.50 17,317 17,317 COMPZ RPEQPI OWFF P BDTD and monitor well 07:00 09:00 2.00 17,317 16,092 COMPZ RPEQPI PULD P POOH laying down 5" DP f/ 17,317' t/ 16,092' Page 12 of 19 • Time Lo s Date From To Dur S. De th E. De` th Phase Code Subcode T Comment 09:00 17:30 8.50 16,092 16,092 COMPZ RPEQPI CIRC T Field went to Phase 3 weather conditions -Screwed in TD and Circulated @ 2 bpm @ 420 psig - took 10 bbls to fill hole -maintaining 40 bbl / hr losses. 17:30 22:00 4.50 16,092 16,092 COMPZ RPEQPI CIRC T Field went to Phase 3 weather conditions -Screwed in with TD and Circulating @ 2 bpm @ 420 psig - Pumped 10 bbl tube pill @ 17:30 hrs and continue to circulate - maintaining 40 bbl / hr losses. Have 300 bbls in pits and 290 bbls on truck that is un accessable at this time. 22:00 00:00 2.00 16,092 16,092 COMPZ RPEQPI CIRC T Blow down Top drive. Begin filling hole every hour with 20 bbls and reciprocating drill string for 90' periodically. Fluid loss to formation for the day = 681 BBLS. Total Fluid Losses to formation = 12,862 BBLS 2/03/2010 Continue to standby for phase 3 conditions, filling hole every hr w/ 20 bbls and reciprocating drill string.Phase 3 lifted at 0300 HRS. Plow snow & clean rig area. RU to thaw out & unpack snow from elevators for laying down DP. Continue POOH laying down 5" DP, stopping to unload pipe shed as needed. Observed hole taking 2 x dis lacement lus 20 BBLS / HR. Fluid loss for the da = 688 BBLS. Total losses = 13617 BBLS. 00:00 06:00 6.00 16,092 16,092 COMPZ RPEQPI CIRC T Blow down Top drive. Begin filling hole every hour with 20 bbls and reciprocating drill string for 90' periodically. Went to Phase 2 @ 03:00 hrs -Waiting on rig loader to clear pad area around rig to resume operations. Continue to fill hole every hour w/ 20 bbls and reciprocate drill string for 90'. Ri went off Phase 3 as of 06:00 hrs 06:00 06:30 0.50 16,092 16,092 COMPZ RPEQPI SFTY P Held PJSM on POOH and Laying down 5" Drill Pi e. 06:30 07:00 0.50 16,092 16,092 COMPZ RPEQPI OTHR P Fill pits. Blow down Top Drive. 07:00 08:00 1.00 16,092 15,143 COMPZ RPEQPI PULD P POOH laying down 5" DP f/ 16,092' t/ 15,143', double displacing the hole fill. @ 07:15 hrs employee smashed left pinky tip while releasing tongs - taken to Medic - recieved wound care and splint for finger -Employee returned to work. 08:00 11:00 3.00 15,143 15,143 COMPZ RPEQPI OTHR T Elevator on the drillers side of the rig was snow packed and had to to be thawed before off loading 5" Drill pipe from i e shed. Page 13 of 19 l l J Time -Lo s Date From To Dur S. De th E De th Phase_ _ Code Subcode T Comment 11:00 12:00 1.00 15,143 15,143 COMPZ RPEQPI OTHR P Offload pipe shed of 5"drill pipe. 12:00 00:00 12.00 15,143 8,893 COMPZ RPEQPI PULD P POOH laying down 5" drill pipe and offloading the same f/ 15,143' t/ 8893' -double displacing the hole fill. Total fluid loss for the day = 688 BBLS. Total for well = 13617 BBLS 2/04/2010 Slip & Cut Drilling line. Inspect & Service Top Drive. Wash down through hook hanger assembly down to MLZXP in B lat, and to 9303' DPM. Observed auger line & trough packed off while taking returns. Clean crude from shaker area and pit room. POOH lay down 5" DP .Continue thaw out kill line. Rev. Circulate 20 BBLS tube sweep, taking crude returns form DP until clean. Lay down all DC"s , 5" DP, and 4 3/4" BHA. prep rig floor for 2 7/8" DP. Rig crews held Safety Stand up meetings with management. Fluid loss for the day = 764 BBLS. Total = 13281 BBLS 00:00 02:30 2.50 8,893 8,893 COMPZ RPEQPI SLPC P Held PJSM. Discuss safety & Hazard recognition issues. Discuss procedure to slip & cut drilling line. Hand Blocks and Top Drive. RU & slip & cut 120' of drilling line. Inspect & Service to drive. 02:30 04:00 1.50 8,893 8,893 COMPZ RPEQPI RGRP T Service Top drive and change out rabber dies 04:00 04:30 0.50 8,893 9,183 COMPZ RPEQPI WASH P Make up top drive, wash into hole , through the Hook hanger @ 9094', continuing down through the MLZXP @ 9067' to 9,183'. Pump Pressure at 540 PSI - 2 BPM. PuII back throu h washin same. 04:30 06:00 1.50 9,183 9,183 COMPZ RPEQPI OTHR T The chute below the auger in the shaker room had plugged off during the blizzard and extreme cold temperatures. As oil was returned over the shakers and backed up causing an estimated 2 gal. oil spill on the snow, that was immediatly cleaned up. PIR was filed and securi was notified. 06:00 08:30 2.50 9,183 9,183 COMPZ RPEQPI WASH P Wash up f/ 9,183' t/ 9,088' and back down @ 2 bpm @ 540 psig increasing pump rate to 4 bpm @ 880 psig. Locate the top of the MLZXP 9,167'. 08:30 10:00 1.50 9,183 9,303 COMPZ RPEQPI WASH P Make connection and began to wash f/ 9,183' to 9,303', circulating @ 3 bpm @ 1,100 psig, returning oil. Stop operation to send oil returns to kill tank -found reverse line had an ice blocks e. 10:00 12:00 2.00 9,303 9,303 COMPZ RPEQPI WASH T Offload 5" DP and Load Completion quipment into pipe shed while thawin out line. 12:00 14:30 2.50 9,303 9,303 COMPZ RPEQPI CIRC P Reverse circulate 20 bbl Lube Pill @ 6 bpm @ 150 psig ICP with minimal to no returns. 250 psig FCP. Recovered 128 bbls in kill tank during reverse o erations. 14:30 15:00 0.50 9,303 9,303 COMPZ RPEQPI OTHR P Blow down Top drive, hard line and kill line. Page 14 of 19 l • Time Lo s ,.Date Fram To Dur S. De th E. De th Phase°-Code Subcode T Comment 15:00 16:00 1.00 9,303 9,847 COMPZ RPEOPI TRIP P RIH w/ remaining 2 stds of drill pipe from derrick and 4 stds ush i e. 16:00 19:00 3.00 9,847 8,900 COMPZ RPEQPI PULD P POOH laying down Push pipe and 5" DP 19:00 19:30 0.50 8,900 8,900 COMPZ RPEQPI SFTY P Crew Change out. Pre-Tour Meeting afrer Safte Stand u at KOC. 19:30 20:30 1.00 8,900 8,900 COMPZ RPEQPI RGRP P Observed break in Breakout Line. Change out same installing new one. Pull test same on the stum . 20:30 21:30 1.00 8,900 8,856 COMPZ RPEQPI PULD P Lay down pump out sub, fishing jars, LBS, X-O, X-O, X-O 21:30 00:00 2.50 8,856 8,856 COMPZ RPEQPI RURD P Change over to 2 7/8 equipment. Clear rig floor of 5" DP equipment. Unload shed. Begin POOH with 2 7/8" DP. Fluid loss for the day = 764 BBLS. Total = 13281 BBLS 2/05/2010 Held PJSM. POOH Lay down 2 7/8" DP & Mule shoe. ND & install shooting flange. RU HES wireline crew. MU Tools WLIH to 1400', observed short in cable head. WLOH repair same. MU Tools WLIH. Fluid loss for toda = 401 BBLS. Total for welll = 13482 BBLS 00:00 00:30 0.50 8,856 8,856 COMPZ RPEQPI SFTY P Held PJSM with crew. Discuss safety & Hazard recognition issues. Discuss la in down 2 7/8" DP. 00:30 06:00 5.50 8,856 4,746 COMPZ RPEQPI PULD P POOH lay down DP f/ 8,856' U 4,746' installing thread protectors and unloadin shed when needed. 06:00 12:00 6.00 4,746 0 COMPZ RPEQPI PULD P Continue to POOH lay down DP f/ 4,746' installing thread protectors and unloadin shed when needed. 12:00 14:00 2.00 0 0 COMPZ RPEQPI OTHR P RD and offload 5" and 2 7/8" Rental e ui ment 14:00 17:00 3.00 0 0 COMPZ RPEQPI ELOG P ND flow riser and NU 13 5/8 5m x 7" Otis shootin flan e. 17:00 17:30 0.50 0 0 COMPZ RPEOPI SFTY P Held PJSM with crew, HES reps. Discuss safety & hazard recogniiton issues. Discuss RU & Run wireline tali er assembl . 17:30 19:00 1.50 0 0 COMPZ RPEQPI ELOG P Pull sheaves and tools to rig floor. MU tools. Function test same. MU Lubricator on shootin flan e. 19:00 20:00 1.00 0 0 COMPZ RPEQPI ELOG P WLIH to 1400' WLM. Observed "short" in assembly. Trouble shoot same. Fillin hole with 20 BBLS / HR 20:00 23:30 3.50 0 0 COMPZ RPEQPI ELOG T WLOH. Breakout and lay down assembly. Inspect & repair cable head. Observed short in the cable head. MU toots, function test assembly. OK at surface. MU Lubricator on shooting flange. Filling hole with 20 BBLS / HR 23:30 00:00 0.50 0 0 COMPZ RPEQPI ELOG T WLIH with second run to 1400'. Observed repeat in short. Filling hole with 20 BBLS / HR Fluid loss for today = 401 BBLS. Total for well = 13482 BBLS Page 15 of 19 • Time Lo s Date From To Dur S. De th E:<De th-Phase Code - Subcode T Comment 2/06/2010 24 hr summary Continue WLIH to 1400' WLM, and observed repeat failure in cable head. WLOH. Trouble shoot & repair cable head. WLIH to 1400', observed repeat short in line. WLOH. Repair smae. MU tools, WLIH to 2400' WLM, Observed surge in unit generator, causing anothe short in the system. After troubleshooting, fated to regain sufficient power. RD HES wireline crew and shooting flange. RU & test BOP's. Witness of test waived by AOGCC rep John Crisp. Note: While ND shooting flange, dropped a cotton glove down the hole. Fishing will commence after BOP test. Fluid loss for the da = 405 BBLS, total for well = 13887 BBLS 00:00 00:30 0.50 0 0 COMPZ RPEQPI ELOG T WLOH with assembly to surface. Filliin hole with 20 BBLS / HR 00:30 03:00 2.50 0 0 COMPZ RPEQPI ELOG T Troubleshoot cable head verify short. Repar cable head. MU tool string with Caliper assembly. Function test same on ri floor. OK 03:00 04:00 1.00 0 0 COMPZ RPEQPI ELOG T WLIH to 1400'. All is good again. 04:00 05:30 1.50 0 0 COMPZ RPEQPI ELOG T Power up Tractor, experiencing power surges, short at surface. Trouble shoot down to slip ring assembly on drum. Repaired. Re-established communication with tools down hole @ 2450'. Ex eriencin same ower sur es. 05:30 09:00 3.50 0 0 COMPZ RPEQPI ELOG T Ordered out new power supply from Deadhorse. 09:00 11:00 2.00 0 0 COMPZ RPEQPI ELOG T Same problems with new power supply. Replace Umbellical cable from power supply to wire line, this did not remed the roblem. 11:00 14:00 3.00 0 0 COMPZ RPEQPI ELOG T POOH from +/- 2500'. RD a-line e ui ment. 14:00 17:00 3.00 0 0 COMPZ RPEQPI NUND P ND 13 5/8" x 7" 5M Otis Shooting flange. NU Flow Riser. While nippling down flange, accidently dropped orange cotton glove down hole. Continued to NU flow riser and will attempt to circulate glove out after ROPE test. 17:00 22:00 5.00 0 0 COMPZ RPEQPI BOPE P Funtion test and PT BOPE and choke manifold to 250/2500 psi. Test all floor valves. Perform Koomey test with the first 200 PSI gained in 22 secs, with fu113000 PSI in 1 min 57 secs. 22:00 00:00 2.00 0 0 COMPZ RPEQPI RURD P RD test equipment. reposition completion equipment in the pipe shed. Install wear bushing. RILDS. Pull fishing tools to rig floor. Fluid loss for the day = 405 BBLS, total for well = 13887 BBLS 2/07/2010 Continue RU to run 3 1/2"TBG. MU Crankshaft Rope Spear assy with drain sub. TIH picking up 3 1/2" tbg from shed to 1400' MD, Took weight. POOH, check spear, no fish. MU Reverse basket assmy. TIH to 3214'. Calculated top with volume added. POOH, breakout & lay down reverse basket with recovered fish. Clean floor area. RU to run ESP completion. MU Weatherford A-well gauge, observed fault when tested. Troubleshoot same. Call for Schlumberger Phoenix gauges with backup. Weatherford rep inspected and repaired gauge. Decision to run Weatherford. Fluid loss for the da = 448 BBLS. Total for well = 14120 BBLS. 00:00 01:00 1.00 0 0 COMPZ RPEQPI RURD P Continue rig up floor & equipment to run 3 1/2" TBG. Page 16 of 19 l J Time Lo s .Date From To Dur S., De th- E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew and BOT fishing rep. Discuss safety & hazard recognition issues. Discuss procedure to MU Rope spear assmy, and pick up tubing from the pipe shed. 01:30 02:00 0.50 0 18 COMPZ RPEQPI PULD T Make up Crankshaft Rope Spear assembly with drain sub crossed over to 3 1/2" 8rnd EUE. 02:00 03:30 1.50 18 1,410 COMPZ RPEQPI TRIP T TIH picking up 3 1/2" 8rnd EUE tubing to 1410". Calculated hole fill since glove dropped at 177 BBLS = 2335'. Planned depth. Observed takin wei ht at 1410' 03:30 05:30 2.00 1,410 0 COMPZ RPEQPI TRIP T POOH racking back 14 stands of 3 1/2" tbg from 1410'. Inspect rope spear for fish (empty). Broke down ro e s ear and LD. 05:30 10:30 5.00 0 3,116 COMPZ RPEQPI TRIP T Clean rig floor and tools. PU Reverse Circulating Junk basket w/8 1/2' shoe MU and RIH on 3 1/2" 8rd EUE tubin to 3116'. 10:30 11:30 1.00 3,116 3,116 COMPZ RPEQPI RURD T Change Saver Sub on Top Drive from 5" to 3 1 /2". 11:30 12:00 0.50 3,116 3,214 COMPZ RPEQPI FISH T MU 3 1/2" drillpipe, Washdown 4 BPM w/210 psi to 3214'. No returns until we washed down to 3214'. 12:00 14:30 2.50 3,214 0 COMPZ RPEQPI TRIP T POOH laying down 3 jts of 3 1/2" drillpipe, standing back 98 jts of 3 1/2" tubin . 14:30 17:00 2.50 0 0 COMPZ RPEQPI NUND T Broke down reverse basket and cleaned out. Recovered one "Orange Pinch Point Glove". LD fishing tools and break down load out. Clean rig floor and RU running equipment for ESP com letion run. 17:00 18:30 1.50 0 0 COMPZ RPEQPI RCST P Install & test Weatherford A-well gauge. Observed fault. repeat test. Intermittent faults. Remove for ins ection. 18:30 00:00 5.50 0 0 COMPZ RPEQPI EQRP T Discussion with Rig engineer on next step. Called for Sclumberger Phoenix gauge and back up. Obtain test box from Milne Point Centrilift. During standby, Weatherford repaired cracked insulator on A-Well gauge, function tested same.Good test. Decision to run Weatherford A-well gauge. Held Safety Meeting on Hand Awareness with ri crew. 2/08/2010 MU ESP Completion assembly with Y-Block.. Continue RIH with 3 1/2" Completion string installing 224jnts as per plan. Megger & commurnca ion es s ine very 1000'. Install hanger and landing joint. MU penetrator and tail. RU, and begin ESP cable splice as per Centrilift reps. Fluid loss for the day = 344 BBLS. Total Losses for well = 14464 BBLS Page 17 oft9 • r~ -Time Logs Date From To Dur S. De th E. De th Phase < `Code Subcode T Comment 00:00 06:00 6.00 0 0 COMPZ RPEOPI PULD P Make up ESP completion with Weatherford A-well gauge and Y-Block with 2 7/8" spacer pipe assembly as per Centrilift and Weatherford reps. Observed sheared thread on pump installation. Had to to out the bolt holes. 06:00 10:00 4.00 0 COMPZ RPCOM RCST P Continued making up pump, motor and seal section and servicing. Connected A-well Sensor. Ran cable over sheave, connected motor lead and tested same. Continue in hole and MU Unique discharge pressure sub, retest, ok. 10:00 15:00 5.00 0 3,247 COMPZ RPCOM RCST P MU CMU sliding sleeve (closed), MU 2.813"'DS Nipple, start running in hole on tubing from derrick, performing electrical inspection/tests on ESP power cable every 1000', insatlling Cannon crosscoupling clamps on 1st 6 connections and eve other one thereafter. 15:00 22:30 7.50 3,247 7,300 COMPZ RPCOM RCST P Oontinue RIH with ESP completion PU 3 1/2' tubing from pipe shed, performing electrical inspection/tests on ESP power cable every 1000', insatlling Cannon crosscoupling clamps on 1st 6 connections and everyother one thereafter. Fill hole eve hour with 20 BBLS. 22:30 00:00 1.50 7,300 7,300 COMPZ RPCOM RCST P Make up Vetco Gray hanger with 3 1/2" x 4 1/2" crossover to tubing string. Make up landing joint. Position hanger at floor. UP WT = 80K, SO WT = 55K. Measure ESP cable. RU and perform ESP cable splice as per Centrilift reps. Fluid loss for the day =344 BBLS. Total losses for the well = 14464 BBLS 2/09/2010 Continue Splice ESP cable. Land tubing hanger. RILDS. ND BOP's. NU Tree. Freeze protect Well. Secure Cellar. 00:00 03:30 3.50 7,300 7,300 COMPZ RPCOM RCST P Continue Splice ESP cable as per Centrilift reps. Inspect & perform electrical inspection/tests on ESP power cable. Fill hole with 20 BBLS eve hour. 03:30 04:30 1.00 7,341 7,341 COMPZ RPCOM RCST P Ensure stack drained. Land Tubins hanger. UP WT = 80K, SO WT Back out & lay down landing joint. Installtwo- way check as er Vetco Gra re . 04:30 12:00 7.50 0 0 COMPZ RPCOM NUND T ND riser, attempt to change out element in annular prreventor could not get top ring off. Broke threads loose and abandoned task. Will Chan a out element in DTH later. Page 18 of 19 a r~ Time to s ::Date From To Dur S. De th E: De th Phase Gode Subcode T Comment 12:00 13:30 1.50 0 COMPZ RPCOM NUND P Continue on with ND of BOP stack, choke & Kill Lines. Cleanin its. 13:30 14:30 1.00 COMPZ RPCOM NUND P NU tubin head adapter and.tree. PT the tree and hanger void/packoff to 5000 psi. Check the ESP cable/motor electrical integrity and record phase-to-phase and phase-to ground resistivity for all three phases at the hanger penetrator. Pressure sensor readings also good. Pressure test tree to 5000 si. 14:30 16:00 1.50 COMPZ WELCTI OTHR P RU lubricator, pulled two-way check. 16:00 19:30 3.50 COMPZ RPCOM FRZP P RU Little Red Hot OiI. Pumped 30 bbls of Diesel down the Tubing at 1.0 bpm/1,300 psi. Pumped 200 bbls of Diesel down the IA at 2.0 bpm/400 si. Ri down Little Red. 19:30 21:00 1.50 COMPZ RPCOM OTHR P Monitor WHP at 175 psi. Pick up Lubricator and install BPV. Lay down Lubricator. 21:00 00:00 3.00 COMPZ RPCOM OTHR P Clean Pits. Secure Cellar. Final pressures, Tbg = 175 psi, IA = 25 psi, OA = 400 psi. Prep to Move off Well Slot. Released Nordic Rig 3 at 24:00 hrs, 02/09/2010. Page 19 of 19 >, • • ~ • s ~a1'1aC0~'11~~Ir3S October 13, 2009 OCT 1 5 20Q9 Anchorage, AK 99501 ~~~ ~ ~ ~ ~ ~ ~,~, ~~~~~ ~ . ~~~~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7'h Ave. Ste. 100 Robert Christensen/llarrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fa~c: 659-7314 ~~VG~ Y G~ ~~es~C~ ~ii ~ Gas Gnns. ~orr~nission Anchorage Dear Mr. Maunder, onocoPhill' s Alaska, Inc. has changed the artificial lift method in the West Sak 1J-135 (PTD 207-038) d 1J-135L1 (PTD207-039) multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to GL (Gas lifted) due to a failed ESP (Electrical Submersible Pump). ~ If you have any questions regarding this matter, please contact me or Darrell Humphrey at 659-7535. Sinc ely, -- ~ ____:,-, ~~ Robert D. Christensen Attachments ~~~G1~ r • ~ OCT 1 ~ 2~109 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~laska Oil & Gas Cons. COtYNItISSI0t1 REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations PerFormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other Q Failed ESP to Alter Casing ^ Pull Tubing ^ Perrorate New Pool ~ Waiver ^ Time Extension ^ Gasiift Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development 0 Exploratory ^ 207-038 3. Address: Stratigraphic ^ Service ^ ~API IVumber: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-00 KB Elevation (ft): ~ Well Name and Number: B 123' 1J-135 8. Property De~signafrsn: ~ . Field/Pool(s): ADL 25661, 25662, 380058 Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Totai Depth measured . L 17735' feet ~ 3512' feet Plugs (measured) true vertical Effective Depth measured 17720' feet Junk (measured) true vertical 3512' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" 121' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" 9819' 3604' B SLOTTED LINE 8555' 5-1/2" 17722' 3513' Perforation depth: Measured depth: 9829'-11845'; 11847'-17681' true vertical depth: 3605'-3584'; 3584'- 3513' Tubing (size, grade, and measured depth) 4-1l2", L-80, 7548' MD. Packers & SSSV (type & measured depth) B sand MLZXP Liner Top 9167' None 72. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-MCf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 410 229 38 207 412 Subsequent to operation 396 238 43 894 230 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X ~4,~ Well Status after proposed work: Oil^~ Gas^ WAG~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certiy that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact B, Christensen/ D. Humphrey Printed Name be . hris n Title Production Engineering Specialist ~ Signature Phone: 659-7535 Date J~ ~ 2 ~ 6 6 J Form 10-404 Revised 04/2004 ~- ~'~~~11~ `1°~l ~ (~ ! ~ ' / ~a. ~c~ c~~ 7/"~ Submit Ori inal Only ~ 1 J-135 r - DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/27/09 PULLED 45.7' ESP FROM DEPLOYMENT SUB, LAY ON GROUND FOR CENTRALIFT,GAUGE TBG TO 3.80" STALLED OUT @ 3200' SLM DUE TO DEVIATION, ATTEMPT TO PULL STA# 1@ 2472' RKB, IN PROGRESS. 09/28/09 10/05/09 PULLED 1"SOV( VALVE HAD SEVERE FLOW CUT HOLE IN SIDE OF IT) @ 2453' RKB, SET NEW GLV @ 2453' RKB, COMPLETE. ATTEMPT TO TEST TBG @ 2500' SLM. PULLED GLV @ 2453' RKB. SANDS IN NOSE CONE & MINOR FLOW CUT BELOW LOWER PACKING. SET EXT PACKING DMY @ 2453' RKB. IN PROGRESS. TESTED TBG @ 6226',2503',2411',1006' & 509' SLM. ***FAILED***. LOST FLUID RAPIDLY EACH TIME AFTER UNSEATING HOLEFINDER . TBG NOT HOLDING FLUID. IN PROGRESS. .-~ Cor~ocoPhillips Alav4i. Ifx; WeIIConF ~.MULTIPLE S-1J~ etie- HANGER, 18 ~ . _ _ ._ _.- _- _ _ 7 CoNDUCTOR 4a-122 ESP MANDREL. 2,453 SUftFACE. 44-3.463 ESP MANDREL, 7 362 ~ISCHARGE, 7,91~ XOINTAKE, 7 4B7 SEAL, 7098 MOTOR, 7,510 •~~~~~sac I I D-SAND WINDOW, 9.W7-9.107 MANGER, 9.788 HANGER ~ o-snno. s.wa-s.asz 1 1 SLOTS,~ 1 1 , 9a~„~5 I l „ S~~TS.~ ~ ~ ' 11.8/]-17 6B1 ~ ~ 6 LINER. II~ 9,167-77,723 TD (iJ-735). 17 735 KUP 1J-135 s Max An le 8 MD TD FielO Nama WESTSAK Well SWtus PROD Incl (°) MD ~ftNB~ 92.54 11,921.47 Act etm (f[NB) 77,735.0 H2S (ppm) 0 Data 12Y2&2007 Mnotatlon Last WO: Ena Da[e 4/9/2008 K813rtl (It) 44.00 Rig Releasa Data 5/23/2007 :pt~ (FtHB) EnA Dab! Mnotation Rev Reason: G W C/O Last Motl ... Imosbor En0 Data 10/10/2009 3 String 0. 20 .. 5[ring 10 ... 19250 Top ~(tNB) 43.7 Set OepN ~f... 1222 Set Depth (TVD) ... 122.2 String Wt.. 94.00 String ... String Top ThrE String 0... 133/S String ID ... 12.415 Top ((tKB) 43.6 Sat Depth ~f... 3,462.8 Set ~eplh (TVD) ... 2,215.3 5[ring Wt... 68.00 String ... L-BO S[ring Top Thrtl BTC String 0. 9 SS .. Strlnp 10 ... 8.835 Top (HNB) 40.9 Sat Oept~ (f... 9,819.0 Set Dapth (TVD) ... 3,6042 String Wt... 40.00 String ... L-80 String Top Thrtl BTC-mod Strinp 0, 9 S~8 .. String ID ... 8.000 Top (ftl(B) 9,097.0 Set Dept~ (I... 9.107.0 Set ~epM (TVD) ... 3,528.4 String Wt... 341np ... SVing Top ThrO String 0. 51/2 .. Strlnp ID ... 4.950 Top (fH(B) 9,167.0 Set DepM (f... 17,722.5 Set Dept~ (TVD~ ... 3,512.5 Strinp Wt... 75.50 Strinp ... L-80 String Top T~rtl BTC-Mad ~ Top Incl .....~~~y..~....~y.~..~~ ...~~i~y..... ...~~i~yi..... ~vYl~u~nl av~vvy~i~~~... oe~vey~i~~~~u~... o~~~~~y...... ~.~~~~y... ~.~~~~y ~~sy ~~~~u TUBING 41/2 3.958 182 7,548.0 3,258.0 12.60 L-80 IBT-mod Com letion Detaiis Top Depth (TVD) Top Incl Top (fll(9) (ftNB) (°) IEem oeecriptlon Comment ID (in) 18.2 18.2 -0.06 HANGER Vetco Gray 11"x 4-1/2" Hgr w/ 4.909" MCA Top Conn. Made. This hanger 3.900 is a MB228 which the OD 10 7/8", Then the outer bushing is 137/16" OD. Inc Comment I Run Date I ID 7op~TVO) Btm (TVO~ Dens Top (ftl(B) B4n (RI(B) (RI(B) (RNB) Zona Dab Ish~~~ Type Comment 9,829 11,845 3,605.0 3,585.2 WS B, 1J-135 M30I2007 32.0 SLOTS 2.5"long X.125"wide, 4 circumferencial mws/ft, 3" centers staggered 18 deg 11,847 17,681 3,585.0 3,513.2 WS B, 1J-135 M30/2007 32.0 SLOTS 2.5"long X.125"wide, 4 circumferencial rows/ft, 3" centers staggered 18 deg Valve ~ Lah~ ~ Slze ~TRO Run PKG ~ ~ Page 1 of 1 Schwartz, Guy L (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Monday, October 19, 2009 3:24 PM To: Schwartz, Guy L (DOA) ~ Cc: CPF1 Prod Engr ~O ~- V Subject: 1 J-135 Guy- in response to your question re~arding the summary sheet information on this well; TESTED TBG @ 6226',2503',2411',1006' & 509' SLM. ***FAILED***. LOST FLUID RAPIDLY E~ 10/05/09 UNSEATING HOLEFINDER . TBG NOT HOLDING FLUID. IN PROGRESS. To summarize: The ESP was pulled and an GLV was set 2453' RKB. Initiaf attempts to bring the well on with gas !ift were unsuccessful so troubleshooting efforts were undertaken. The Wells Group was unable to set the hole finder tool after several attempts and the process was stopped. The Slickline Wells Group Supervisor attributed the unsuccessful hole finder troubleshooting attempts to the high angle of the wellbore. A fluid level was obtained on 10/7/09. The well was placed on lift gas again and after 2 days it unloaded and is now operating properly. The well was retumed #a seKwice 10/81~9 10-07-09 TBG & IA FL. T/I/O = 30/450/419. Well is shut in. TBG FL @ 888 ft(600 fps). IA FL @ 3986 ft. Hope this answers your questions. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Production Engineerir-g Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 10/20/~009 x ~ N tt~ v`Q_,. DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070380 Well Name/No. KUPARUK RIV U WSAK 1J-135 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23349-00-00 MD 17735 TVD 3512 Completion Date 5/22/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATA INFORMATION Types Electric or Other Logs Run: Gr/Res (data taken from Logs Portion of Master WeII Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 41 17735 Open 8/2/2007 ~ C Lis 15311 Gamma Ray 3438 17735 Open 8/3/2007 LIS Veri, GR, ROP, FET w.Graphics p 15311 LIS Verification 3438 17735 Open 8/3/2007 LIS Veri, GR, ROP, FET D C 18060 See Notes 0 0 5/21/2009 EWR Logs in PDS, EMF ~ and CGM graphics ~og Induction/Resistivity 25 Col 121 3512 Case 5/21/2009 TVD EWR, DGR og Induction/Resistivity 25 Col 121 17735 Case 5/21/2009 MD ROP, EWR, DGR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ Daily History Received? Chips Received? ~F,~At-. Formation Tops /Y,. / N Analysis Y4-Al- Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070380 Well Name/No. KUPARUK RIV U WSAK 1J-135 Operator CONOCOPHILLIPS ALASKA INC MD 17735 ND 3512 Completion Date 5/22/2007 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-029-23349-00-00 UIC N ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-135+L1+L1PB1 May 7, 2009 AK-MW-4957664 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-135+L1+L1PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23349-00,60,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23349-00,60,70 Digital Log Images 2 CD Rom 5 0-029-23 349-00,60,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bri- an . Ba~h~lliburton.com Date: ~ SAY 2 ~ Lllu'~ ~E BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~0~-03~ l~o~c~ ~v~. _ O39 ~ ~6~a • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~3'~ o3s ~~~ ao~_ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28!2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1 J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1 J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9!6/2008 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9!6/2008 MAY 1 3 200$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Gons. Commissial1 REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhilllps Alaska, InC. Development 0 ~ Exploratory ^ 207-038 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1J-135 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25662, 380058 Kuparuk River Field /West Sak Oil Pool " 11. Present Well Condition Summary: Total Depth measured 17735' feet true vertical 3512' feet Plugs (measured) Effective Depth measured 17720' feet Junk (measured) true vertical 3512' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 121' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" 9819' 3604' SLOTTED LINEF 8555' 5-1/2" 17722' 3513' Perforation depth: Measured depth: 9829'-11845', 11847'-17681' true vertical depth: 3605'-3584', 3584'-3513' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7548' MD. Packers &SSSV (type & measured depth) B-sand MLZXP liner pkr @ 9167' no SSSV 12. Stimulation or cement squeeze summary: ~ ~~~ Nia~~' ~ ~~~~ Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 968 411 52 -- 251 Subsequent to operation 518 ~ 131 157 -- 225 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Sundry Number or N!A if C.O. Exempt: 308-102 contact Brett Packer Printed Name Brett Packer Title Wells Group Engineer ®i~ Signature Phone: 265-6845 Date ~~(Z~O~ P ared b Sharon Allsu Drak 263-4612 ~1 Form 10-404 Revised 04/2006 ~~ ~ ~ ~ ~ A ~ spa' Submit.L~ngmal,Onl~, «' ~ ~ 1 %~i'G ;~ ~~~coPhitlip~ A;tas ~, inc. ~\ KRU 1J-135 1J-135 -- - _ __ ; __.... . ....__._._.. _...__. .. ...... ....._. Rf'I 500292334900 Weil T e: PRUD _ A le ~ TS: ; :v TUBING ~ SSSV T e:': NONE Ori Com letion: 5/23/2007 An le TD: 91 d 17735 ia7sas, Annular Fluid:' Last W/0: 4/912008 Rev Reason: ;ESP WORKOVER ID:as56} ~ ' _ Reference Log 41.4 RKB Ref Log Date:. __... _ . _ Last Update: 4/14/2008 ~"~ Last Tag TD: ; 17735 ftKB ' Last Tag Date: _ Max Hole Angle:: 93 deg lad 11921 ; Casir~ String -ALL STRINGS ^ SEALS {751a-7526, OD:S.t3t}} GAUGE p5szassa, OD:a.5D9) Uescriptioq _ _ _, Size Top t3ottom___ TVD _ Wt Grade Thread ............... . . _ __ _ CONDUCTOR 20.000 _.______________ 0 ___ 118 118 94.00 H-40 WELDED SURFACE 13.375 0 3462 _ 2215 ~ 68.00 L-80 BTC - INTERMEDIATE 9.625 0 9819 3604 40.00 L-80 BTCM B-SAND SLOTTED LINER 5.500 9167 17722 3513 _ t5.50 L-8_0 BTCM Tubinc ~StriOg -TUBING „ Size Top Bol[om _ _ I VI) Wt Grade Thread _ 4.500 0 __ 7538 _ ~5~ 12.60 L 80 _ IBTM Perforations_ Summary ' Interval tVD Lone Status ht SPF Date hype ___ Comment _. _ _ 9829 -11845 3605_- 3584 __ __ WS B 2016 32 4!3012007 SLOTS 2.5"long X .125"wide, 4 circumferencial rowslft, 3" centers sta erect 18 de 11847 -17681 3584 -3513 WS B 5834 32 4130!2007 SLOTS 2.5"long X .125"wide, 4 circumferencial raves/ft, 3" _ centers staggered 18 deg Gas Lift Mandrels/Valves St MI) TVD _ Man Mfr Man Type V Mfr _ V Type V UD Latch Port TRO ;Date Run Vlv Cmnt 2472 1 _'+__ 196Q~ CAMCO ~ KBMG SOV ~ 1 _1.0_._ ~BK-S _0_000__ ~.2000....4/13/2008_ L_....._._._._...~ . _ 2 '; ~ , ,0 ....._ 3219111 _ _ CAMCO -_ ............._ KBMG ._._..____... ...._..... .___ DMV .... I 1.0 ...._.. fff BK ~ ~ 0 0~ 0 ' 4!8t2C108 I I Other (plugs., equip., etc. -COMPLETION Sub ODEL'B-1' HOOK HANGER QNSIDE CSG~ _ ---- ~ 9097 ~ 3528~ . ~ ~D-SAND WINDOW 0.000 WIN OW Ot1~er lu~s,e ui _, etc. - B-SAND LINER DETAIL Depth TVD Type Description __ __ ID _ .. 9167 ~ 3539 PACKER __ _ _ 8-SAND MLZXP LINER TOP PACKER 7 500 9188 3542 HANGER B-SAND FLEXLOCK LINER HANGER 6090 9194 3542 XO Bushin B-SAND CROSSOVER BU~,~iING _ 4 950 9195 ~ 3542 5BE B-SAND 190-47 CASING $FAL BORE EXTENSION 4.750 -- 17721~3513 SHOE B-S~"JD SILVER BULLET SHOE 4.750 !General Notes Date :Nate / 512312007: NOTE: MULTI-LATERAL WELL -1J-135 f6-SAND). iJ-135L1 fD-SAND) XO Bushing (9194-9185, OD:7.63Q} ~onocoPhillips Time Log Summary Wetlvlew Web Reporting I Well Name: 1 J-135 Job Type: RECOMPLETION Time Logs ~ ___ D to From To Dur S. Depth E_. De th Phase Code Subcode T COM 03/18/2008 00:00 08:00 8.00 COMPZ MOVE MOB P Move from 3M Pad to 1J Pad @ 3M x 3A intersection as of 04:30 hrs and 1Q Pad as of 08:00 hrs. 08:00 11:00 3.00 COMPZ MOVE WOCC NP Wait on ConocoPhillips Field crew chan e. 11:00 17:00 6.00 COMPZ MOVE MOB P Continue to move Rig Nordic 3 from 3M Pad to 1J Pad. 17:00 18:00 1.00 COMPZ MOVE PSIT P Move in and spot over well. Accept Nordic 3 ri 18:00 hrs. 18:00 23:30 5.50 COMPZ RPCOh OTHR P Set down and install handi berm. RU Hardllines from cellar to well head and to tiger tank. Load lubricator and warm u. 23:30 00:00 0.50 COMPZ RPCOti OTHR P Lubricate out BPV and lay down lubricator. 0 Psi tbg, 850 psi IA, 400 si OA. 03/19/2008 00:00 01:30 1.50 COMPZ RPCOh SFEQ P Blow thru lines and PT @ 1,000 psi, Pump hot fluid thru lines to thaw out artiall blocked lines. 01:30 03:30 2.00 COMPZ RPCOh OTHR P Bleed off gas head on IA 850 psi initial ressure and bled down to 260 si. 03:30 04:00 0.50 COMPZ RPCOh CIRC P Bleed IA down from 260 psi to 180 psi. While pumping 50 bbls 6% sea water @ 2 bpm @ 0 psi down tbg to verify no blocka e. 04:00 09:00 5.00 COMPZ RPCOh CIRC P Reverse circulate @ 2 bpm w/ 170 psi ICP. No returns /press to tbg. Cont pump 425 bbls total do IA. No returns / press to tbg at any time. FCP 340 si. 09:00 10:00 1.00 COMPZ WELC OWFF P Monitor well. IA build to 360 psi. Tba "0„ Nsi• Attempt bleed IA 30 min to 350 psi and stable. Will not bleed. Crude / slud e / as returns. No chan a to tb while bleed. 10:00 18:30 8.50 COMPZ WELCT KLWL P PJSM, Plumb lines /test 2500 psi for pump do tbg. Commence well kill do tbg KOBE knock out confirmed open) to kill tank. Hold 280 psi backpressure on choke, ICP 50 psi on tbg. Linear decrease at IA while kill surface to surface. Open choke. 0 psi tbg / IA. Lar a uantities crude / slud e / as Burin kill. Plumb returns to rig pits, circ well clean. 3bpm / 400 psi. Condition fluids. ~~ Paga 1 of 14 Time Logs ___ _ Date From To Dur 5. De th E . De th Phase Code Subcode T COM 03/19/2008 18:30 19:30 1.00 __ COMPZ WELCT KLWL P PJSM, RU /bullhead 9-5/8 and liner volume below KOBE to perfs. 120 bbls down tbg ICP 190 psi tbg and 60 psi IA. @ 2 bpm; FCP 590 psi tbg, 440 si IA 2 b m. 19:30 23:00 3.50 COMPZ WELCT KLWL P Circ BU @ 2 bpm @ 220 psi tbg and 40 psi IA. Take returns to pits. FCP 200 si tb and 50 si IA. 23:00 00:00 1.00 COMPZ WELCT OWFF P monitor well and pain 13 bbls. Continue to monitor well with 0 gain. Well dead. 03/20/2008 00:00 01:30 1.50 COMPZ RPCO NUND P Install BPV. ND Tree 01:30 08:30 7.00 COMPZ RPCOh NUND P NU BOPE, all related equip. 08:30 10:30 2.00 COMPZ RPCO PULD P PJSM, load ESP equip to rig floor / i e shed with crane. 10:30 16:00 5.50 COMPZ WELCT BOPE P PJSM, test BOPE /.all related equip 250 - 2500 psi. Perform accumulator time /volume !press test. Inspect nitrogen bottles. All tests successful, no re-tests. WITNESS WAIVED MR. BOB NOBLE AOGCC ................... 16:00 17:00 1.00 COMPZ WELCT BOPE P Pull blanking plug /BPV. Note well on vacuum. RD BOP test tools. 17:00 21:00 4.00 COMPZ RPCOh PULD P PJSM, RU for ESP run. 21:00 21:30 0.50 7,549 7,480 COMPZ RPCO RCST P MU landing jt., BOLDS, Pull to 220k on hanger and work free. Pull hanger to ri floor 100k. 21:30 22:00 0.50 COMPZ RPCOh OTHR P Check continuity of esp cable and fill IA @ 2bpm takening 100 bbls to fill hole. 22:00 22:30 0.50 COMPZ RPCOh OTHR P String esp cable through sheave and tie into s ool. 22:30 00:00 1.50 7,480 7,015 COMPZ RPCOti RCST P Pooh laying down hanger and landing jt. Standing pipe in the derrick and driftin the same. 03/22/2008 00:00 04:00 4.00 0 0 COMPZ RPCOh DHEQ T Load, rack and Tally 3 1/2 DP 04:00 13:30 9.50 0 7,565 COMPZ RPCO DHEO T Rih PU 3 1/2 DP w/ 9.625 Baker Retrievamatic to 7565 ft. Slow going, tight clearance. Up 115, Dn 50. Circ PKR area. 13:30 15:30 2.00 7,565 7,371 COMPZ RPCOh DHEQ T PJSM set test PKR, attempt test 9-5/8 csg. No go. Suspect PKR leakin . POH to 7371 ft. Circ PKR area. Set PKR, attempt test csg, No o. PKR leakin .Flow back to DP. 15:30 16:00 0.50 7,371 7,000 COMPZ RPCOh DHEO T Determine insufficient wt on test PKR. POH, LD 12 jts DP for added DCs to top of work string with plans to tube high angle wellbore. 120k up wt and 50k do wt. Pag~2~t1~ Time Logs D e From To Dur S. Depth E. D th Ph s~TCod~ Subcode T COM 03/22/2008 16:00 18:00 2.00 7,000 7,365 COMPZ RPCOh DHEQ T Rack and Tally 11 4.75" OD Drill collars and Rih to 7,365' 125k up wt and 60k do wt. Make up top drive to circ. 18:00 23:30 5.50 7,365 COMPZ RPCO OTHR T Condition kill wt fluids w/lubricants. 23:30 00:00 0.50 7,365 COMPZ RPCO CIRC T Circulate condition kill wt fluids w/ lubr. and swap out 6% KCL Kill wt fluid. Took 43 bbls to fill DP, ICP @ 100 si 3 b m,. 03/23!2008 00:00 02:30 2.50 7,365 7,365 COMPZ RPCOti CIRC T Continue to circulate lubricated KW fluid surface to surface 3 b m. 02:30 03:00 0.50 7,365 7,365 COMPZ RPCOti DHEQ T 90k up wt and 75k do wt. Set packer @ 7,365'? to 2,500 psi. Release acker 03:00 04:00 1.00 7,365 7,548 COMPZ RPCO DHEQ T Continue to Rih to 7,548' Set packer , and test. Pressured up to 860 psi Ccil , 2 b m and be an um in awa . 04:00 06:00 2.00 7,548 7,442 COMPZ RPCOh DHEQ T Continue to move up hole in 30' increments pressure testing and pumping away @ 2 bpm @ 760 to 700 psi to 7,430'? then pressure up to ,500 si. Rih to 7,452' and pumped away @ 2 bpm @ 700 psi. Move up hole 7,447' and pumped away @ 2 @ 700 psi. Move up hole to 7,442' and pressure test to 2,500 psi and charted for 30 minutes. All tests on chart. 06:00 12:00 6.00 7,442 75 COMPZ RPCOh TRIP T PJSM, Release packer and Pooh. Conference call with CPAI Anchorage. Decision made to cmt s ueeze 9-5/8 cs hole. 12:00 13:00 1.00 75 0 COMPZ RPCO PULD T LD test PKR, clear floor. Flow check. Static losses 23 b h. 13:00 20:00 7.00 0 0 COMPZ RPCO WOEQ T WO arrival test /squeeze equip. Cmt s ueeze 'ob 9-5/8 cs hole endin . 20:00 20:30 0.50 0 COMPZ RPCOM1 SFTY T PJSM w/ Baker and Rig crew on hand placement and the do's and don'ts with runnin Bride lu s wJ Packers 20:30 21:00 0.50 COMPZ RPCOti OTHR T Build Test packer and BP BHA #2. Fill hole = 60 bbls. 21:00 00:00 3.00 0 7,393 COMPZ RPCO TRIP T Rih w/ BHA #2 on 3 1/2 DP to 7,393'? MD 87k u wt and 69k do wt. 03/24/2008 00:00 04:30 4.50 7,393 8,394 COMPZ RPCO TRIP T Continue to Rih to 8,515' and begin taking wt. Acts as if pushing fill. Pooh to 8,575'. Pooh and attempt to set RBP 8 394'. No Luck. Rih to 8,608' and set RBP. Release of off RBP and set Test packer @ 8,575' and attem t to pressure test leaking b @ 2 bpm @ 300 psi. Rih and Release RBP and Pull back to 8,394' and attempt to set RBP w/ no luck workin over a 60' interval. 04:30 05:00 0.50 8,394 8,394 COMPZ RPCO SFTY T PJSM on Pooh w/RBP. Fill hole w/ 81 bbls. i""2ge 3 of 1d Time Logs Da e From To Dur 5 De th E. De th Ph se Code Subcode T COM 03/24/2008 05:00 07:30 2.50 8,394 7,169 COMPZ RPCO TRIP T Pooh w/ Test packer and RBP. PKR han u at 7169 ft. 07:30 08:30 1.00 7,169 7,169 COMPZ RPCOti TRIP T No upward movement possible at 7169 ft. Continued up / do movement. Work free. Re-ci 60 ft strokes, confirm free. 08:30 14:00 5.50 7,169 25 COMPZ RPCO TRIP T Resume POH 3-1/2 Dp to PKR assy. Attempt test set RBP at 6500 ft. No test, will not set. Flow check. Resume POH. 14:00 15:00 1.00 25 0 COMPZ RPCOh PULD T Inspect RBP /test PKR. Slight scarring at retainer ring RBP. No sanding at internals. LD PKR BHA, clear floor. Fill hole. 68 bbls. Flow check. Static losses 20-2 15:00 18:00 3.00 0 0 COMPZ RPCO WOEQ T WO arrival addtnl clean out tools. 18:00 18:30 0.50 0 COMPZ FISH OTHR T Bring tools to rig floor, warm and stra . 18:30 19:30 1.00 0 COMPZ RPCOh CIRC T Fill hole, Took 140 bbls to fill. 19:30 21:30 2.00 0 382 COMPZ RPCOti PULD T Pu BHA #3 and Rih w/ 8.5" od Globe Basket, X-O, X-O, LBS, Fishing Jars, 11 - 4.75" OD DC's 21:30 00:00 2.50 382 3,281 COMPZ RPCO TRIP T Rih w/ DP from 382' U3,281' 80 up wt. and 60 do wt. 03/25/2008 00:00 03:00 3.00 3,281 7,140 COMPZ RPCO TRIP T Continue to Rih w/ C/O assy BHA# 3 f/ 3,281' to 7,140' 03:00 05:30 2.50 7,140 7,140 COMPZ FISH CIRC T Mix and Pump 82 bbl High visc pill to attempt in fluid losses and cleared DP w/ 53 bbls. ICP @2 bpm @ 125 psi. FCP @ 2 bpm @ 240 psi. Monitor well. DP on vacuum. Fill annulus 140 bbls. Attem t t irc returns. 05:30 07:00 1.50 7,140 8,611 COMPZ RPCO TRIP T RIH 3-1/2 DP 7140 - to tag fill at 8611 ft 07:00 08:30 1.50 8,611 8,740 COMPZ RPCO FCO T Wash do 8611 - 8740 ft. 4 bpm / 500 psi / 3K torque / 30 rpm. 50% returns. Trace san k r. 08:30 09:30 1.00 8,740 8,740 COMPZ RPCOh OTHR T Thaw shaker cuttings auger. 09:30 12:00 2.50 8,740 9,090 COMPZ RPCOh FCO T Resume wash 8740 - 9090 ft. 12:00 12:30 0.50 9,090 9,094 COMPZ RPCO FCO T Wash (no rotation) to hgr at 9094 ft. 12:30 13:30 1.00 9,094 9,094 COMPZ RPCO CIRC T Reverse circ 4 bpm / 310 psi. No sand to shakers. 90% returns. 13:30 14:00 0.50 9,094 8,929 COMPZ RPCO TRIP T PJSM, flow check, static losses 25 b h. POH 3-1/2 DP to8929 ft. 14:00 16:00 2.00 8,929 8,929 COMPZ RIGMN' RGRP T Repair rig wt indicator. 16:00 20:00 4.00 8,929 8,929 COMPZ RPCO TRIP T Resume POH 3-1/2 DP for csg test tool run f/ 8929' - 90'. 20:00 22:00 2.00 8,929 8,929 COMPZ RPCO PULD T PJSM, Break out / LD BHA, inspect Basket, no junk, loaded w/ chi s coatin or aint? . Page 4 raf'I~ ~' Time Loos ~' Da From To Dur S De th E. D th Phase Code Subcode T COM 03/25/2008 22:00 23:00 1.00 8,929 8,929 COMPZ RPCO6 OTHR T Clean /Clear floor, bring RBP & runnin tools to floor. 23:00 00:00 1.00 8,929 8,929 COMPZ RIGMN' SVRG T PJSM, Slip & Cut drill line. 03/26/2008 00:00 00:30 0.50 8,929 8,929 COMPZ RIGMN OTHR T Finish S&C Drill line. 00:30 01:30 1.00 8,929 8,929 COMPZ RPCOh PULD T PJSM, PU Halliburton RBP. 01:30 06:00 4.50 8,929 9,094 COMPZ RPCOti TRIP T TIH w/ RBP to tag hook hanger at 9094 ft. 06:00 07:00 1.00 9,094 9,094 COMPZ RPCOti PACK T PJSM, Set HOWCO RBP at 9075 ft. 07:00 09:00 2.00 9,094 7,045 COMPZ RPCOCV TRIP T PJSM, flow check, POH 3-1 /2 DP to 7045 ft. 09:00 09:30 0.50 7,045 7,045 COMPZ RPCOh CIRC T Pump wt pill. 09:30 10:30 1.00 7,045 7,045 COMPZ RIGMN SVRG T Service rig. 10:30 14:00 3.50 7,045 0 COMPZ RPCO TRIP T PJSM, resume POH 3-1 /2 DP for test PKR run. 14:00 15:00 1.00 0 0 COMPZ RPCO PULD T Inspect RBP run tool, LD same. Flow check. Clear floor. 15:00 15:30 0.50 0 0 COMPZ RPCO PULD T PJSM, MU Baker test PKR Retrievamatic. 15:30 18:00 2.50 0 2,000 COMPZ RPCO TRIP T Flow check, follow PKR assy with 3-1/2 DP to 2000'. 18:00 23:30 5.50 2,000 7,450 COMPZ RPCOh TRIP T PJSM, crew change. Continue RIH to 7450' w/ BOT Retreivamatic test acker usin d ca on DP. 23:30 00:00 0.50 7,450 7,450 COMPZ RPCOti PACK T Fill Pipe, PU 95 klbs, SO 65 klbs. Set packer perform prelim csg p-test w/ TD hooked up to verify csg integrity, OK. Disconnect TD, Blow down same, RU lines for chart recorder, reset acker 7450' and start cs test over interval from 7450' - 9075'. Be in 2500 si test for 30 min. 03/27/2008 00:00 01:00 1.00 7,450 7,450 COMPZ RPCOh DHEQ T Test 9 5/8" csg from 7450' - 9094' to 2500 psi f/ 30 minutes, OK. Unseat acker, RD test lines. 01:00 01:30 0.50 7,450 7,450 COMPZ RPCOh OTHR T PJSM, prepare floor f/ TOH w/ packer. 01:30 07:30 6.00 7,450 0 COMPZ RPCOh TRIP T TOH w/ test packer. 07:30 08:30 1.00 0 0 COMPZ RPCOh PULD T LD test pkr, clear floor. 08:30 14:30 6.00 0 0 COMPZ WELCT BOPE P PJSM, Test BOPE /all related equip 250 / 2500 psi. Perform time /volume / press test accumulator. All tests successful, no re-tests. 14:30 15:00 0.50 0 15 COMPZ CEME PULD T MU muleshoe BHA, RIH same. 15:00 19:00 4.00 15 9,075 COMPZ CEME~ TRIP T Follow BHA with 3-1/2 DP /Jars to taq RPB 19:00 20:00 1.00 9,075 9,075 COMPZ CEME~ OTHR T RU to pump sand. ~ r Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 03/27/2008 20:00 22:00 2.00 9,075 9,075 COMPZ CEME OTHR T PJSM, Start taking on fluid to pumps to blend polymer. Water cold, lines freezin . 22:00 00:00 2.00 9,075 9,075 COMPZ CEME OTHR T Thaw lines, wait on vac truck. Reroute lines to take warmer water off ri . 03/28/2008 00:00 01:45 1.75 9,075 9,075 COMPZ CEME OTHR T RU vac truck, bring fluid into pump van, vis-up, blend in sand and pump away. Start displacement using pump van. 01:45 02:00 0.25 9,075 9,075 COMPZ CEME OTHR T Had spill, blew fluid feed line from rig to pump van. Clean up same while reroute hoses to finish displacement usin ri um s. 02:00 02:30 0.50 9,075 9,000 COMPZ CEME OTHR T Displace sand into place using rig um s. 02:30 04:00 1.50 9,000 9,000 COMPZ CEME OTHR T Blend 114 bbls Hi-Vis ill, pump same and spot over top of sand plug. Pre are to POOH. 04:00 11:30 7.50 9,000 15 COMPZ CEME TRIP T TOH with drill pipe to PU Retainer. Flow check. Well static, no losses. 11:30 12:00 0.50 15 0 COMPZ CEME PULD T Inspect / LD muleshoe assy. 12:00 13:00 1.00 0 0 COMPZ RIGMN SVRG P Service rig. 13:00 13:30 0.50 0 15 COMPZ CEME PULD T MU cmt Baker Model K-1 cmt retainer, RIH same. 13:30 18:30 5.00 0 7,395 COMPZ CEME TRIP T PJSM, flow check, well static, follow BHA with 3-1/2 DP to 7395' 18:30 19:30 1.00 7,395 7,395 COMPZ CEME CIRC T Break circulation, noted sudden pressure increase on DP at 210 strokes: 10 spm @ 850 psi. Shut down, RU to reverse, able to pump at 3 bpm, 550 psi. Pump 1.3 DP volumes to clear possible obstruction with ful! returns, RU to circulate long way, again, Press 850 psi @ 10 spm. Decision made to POOH to inspect retainer ass . 19:30 20:30 1.00 7,395 6,527 COMPZ CEME TRIP T BD lines, POOH 6 stands DP t/ 6527', prepare to circulate again, further dia nostics. 20:30 22:00 1.50 6,527 6,527 COMPZ CEME CIRC T Pump results similar, pumping down DP @ 11 spm, pressure 850 psi. Swap lines to reverse, reverse circ @ 3 bpm, 560 psi full returns. Decide to POOH to ins ect retainer ass . 22:00 00:00 2.00 6,527 4,590 COMPZ CEME TRIP T BD lines, TOH with Baker retainer and runnin ass . 03/29/2008 00:00 03:00 3.00 4,590 0 COMPZ CEME TRIP T POOH to inspect retainer. Break out retainer and running tool. Clean and inspect, no obvious obstruction. Unable to achieve full throughput with hose. Load and to ship to shop for tear-down & rebuild. 03:00 07:00 4.00 0 0 COMPZ CEME WOEQ T Wait on replacement retainer. F'acJe fi zaf'I~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/29/2008 07:00 07:30 0.50 0 0 COMPZ CEME RURD T PU / MU new Baker Model K-1 Cmt Retainer. 07:30 10:00 2.50 0 . 3,775 COMPZ CEME TRIP T TIH w/ retainer to 3775'. Stop to . erform um -thru test on retainer. 10:00 10:30 0.50 3,775 3,775 COMPZ CEME CIRC T Break circulation, pump 2.6 bpm @ 220 si, OK. 10:30 13:30 3.00 3,775 7,390 COMPZ CEME TRIP T Continue TIH to 7390'. 13:30 14:00 0.50 7,390 7,390 COMPZ CEME CIRC T Break circulation, pump tbg volume, confirm clear, rate 3 b m 370 si. 14:00 15:00 1.00 7,390 7,390 COMPZ CEME PACK T Set Baker Model K-1 Mechanical set cement retainer i~U,Test IA 1000 psi, DP 3000 psi. erify injection at 3 b m, 1050 si. 15:00 16:00 1.00 7,390 7,390 COMPZ CEME RURD T RU cementers, Space out DP. 16:00 18:00 2.00 7,390 7,390 COMPZ CEME DISP T Mix /Pump cement, displace to retainer. 18:00 19:30 1.50 7,390 7,390 COMPZ CEME SQEZ T rf rm hesitations ueeze procedure. Squeeze #2: 4 bbls w/ DPi 19 si, DPs 192psi, DPf 207 psi, wait 10 min. ~ • ` Squeeze #3: 4 bbls w/ DPi 29 si, DPs \d\\ ~ 180psi, DPf 220psi, wait 10 min. Squeeze #4: 4 bbls w/ DPi 40 psi, S ~~ DPs 228psi, DPf 238psi, wait 10 min. (` _ i°' [~ ` '~-~ ` \` Squeeze #5: 6 bbls w/ DPi 74psi, DPs 258psi, DPf 267psi, wait 10 min. Final DP 80psi. Used 12 ppg DeepCRETE cmt system. Partial success, , pressures increasing at end each squeeze, final displace 4 bbls behind cement below retainer to leave wet 'nterval from retainer to cs hole. Order out additional cement. 19:30 20:30 1.00 7,390 7,390 COMPZ CEME CIRC T Unsting from retainer, reverse DP clean, had 10 bbls cement contaminate to surface on clean-up, circulate until clean, stab back into retainer and inject 4 bbls brine to insure wet, pump @ 19 spm & 210 si. 20:30 00:00 3.50 7,390 7,390 COMPZ CEME WOSP T Wait on additional cement. 03/30!2008 00:00 11:00 11.00 7,390 7,390 COMPZ CEMEC\ WOSP T Wait on cement for next squeeze rocedure. 11:00 13:00 2.00 7,390 7,390 COMPZ CEME RURD T Arrival new blend cmt. PJSM, RU Cementers, all related a ui . Wage 7 of 9~ ^~d r Time Logs Date From To Dur S. De th E. De th Pha e Code Subcode T COM 03/30/2008 13:00 15:30 2.50 7,390 7,390 COMPZ CEME SOEZ T PJSM, commence cmt squeeze to cs hole at 7442 ft. Sting in retainer, re-establish injection rate 2 bpm / 240 psi. Sting out. Line up returns to choke. Pump 3 bbls H2o, test lines 4000 psi, mix /pump 50 bbls 12 ppg LiteCrete, follow with, 5 bbls H2o. Displace with rig pump. Cease pumping as cmt exits DP. Close choke, open annular, sting in retainer, begin squeeze resulting in final of 4 sta es of 2000 si bleedin to si and stable. Total cmt to s ueeze (Behind Csg) 22 bbls slurry. 4 bbls below retainer. Stage 1 (20.7 bbls 2000 psi, bleed to 1534) Stage 2 (.35 bbls 2000 psi, bleed to 1690 psi), Stage 3, (.17 bbls, 2000 psi, bleed to 1800 psi), Stage 3 (.058 bbls, 2000 psi, bleed to 1900 psi). Sting out leaving press below retainer. Flow check, no flowback. 15:30 17:00 1.50 7,390 7,390 COMPZ CEME CIRC T Circ out cmt to surface. 133 bbls contaminate with approx 25 bbls cmi. Cont reverse 65 bbls brine. Clean returns. Flow check, wellbore balanced. 17:00 18:30 1.50 7,390 7,390 COMPZ CEMEt` RURD T RD Schlum, flush all flow lines /equip in cement return flow ath. 18:30 19:00 0.50 7,390 7,210 COMPZ CEME TRIP T TOH f/ 7390ft - 7270 ft. PU 120k1bs, SO 55klbs. Noted sudden overpull and i e stickin . 19:00 19:30 0.50 7,210 7,210 COMPZ CEME CIRC T MU Top Drive, circ/ rot/ recip pipe @ 190 spm, 1800 psi. Noted cmt in returns. Circ and recip until pipe drag and torq clear up. BD TD and prepare to continue TOH. 19:30 23:00 3.50 7,210 0 COMPZ CEME TRIP T TOH f/ 7270' -surface. BO DL retainer runnin tool. 23:00 00:00 1.00 0 0 COMPZ CEME OTHR T Clear and clean floor, send out running tool and test acker for load-out. 03/31/2008 00:00 02:00 2.00 0 0 COMPZ CEME OTHR T Drain and wash stack and wellhead for install of wear bushin . 02:00 04:00 2.00 0 0 COMPZ RIGMN' OTHR T Slip & cut drill-line. 04:00 04:30 0.50 0 0 COMPZ CEME TRIP T Shuffle DC's and MU BHA for drill-out. 04:30 08:30 4.00 0 1,200 COMPZ CEME TRIP T TIH with 8-1/2 drillin assy to 6730 ft. Take wt on cmt strin ers. 08:30 11:00 2.50 1,200 7,235 COMPZ CEME OTHR T Wash /drill cmt stringers to 7235 ft. 11:00 16:30 5.50 7,235 7,235 COMPZ CEME CIRC T Circ / cond fluids. Cmt contaminate to its. 16:30 18:00 1.50 7,235 7,385 COMPZ CEME CIRC T Precautionary wash /ream to tag retainer at 7385 ft. 18:00 00:00 6.00 7,385 7,385 COMPZ CEME DRLG T Drl on cmt retainer at 7385 ft. Vary arameters in attem t to drill out. E~age 8 csf 1~ i~ Time Logs Date From To Dur 5. De th E. De th Ph e Code Subcode T C_OM 04/01/2008 00:00 08:00 8.00 7,385 7,385 COMPZ CEME DRLG T Drilling on retainer. Vary parameters w/ attempting. drill out cmt retainer at 7385'. 08:00 08:30 0.50 7,385 7,529 COMPZ CEME DRLG T Drill out retainer, continue drill /clean out cmt from 7385' - 7529'. 08:30 09:30 1.00 7,529 7,529 COMPZ CEME CIRC T CBU @ 200 spm, 2050 psi w/ rotate at 50 r m to clean out cmt and debris. 09:30 10:00 0.50 7,529 7,430 COMPZ CASINC DHEO T RU and perform csg integrity test. Rack back (1) std. Achieved 680 psi w/ um ing @ 10 spm (.6 bpm). Total fluid pumped away 50 strokes (3 bbls). Call town and advise of test results. Pre are to POOH. 10:00 15:00 5.00 7,430 0 COMPZ CEMEC` TRIP T TOH w/bit f/ 7430' - surf. Pull wear rin ;break out bit. 15:00 18:30 3.50 0 7,450 COMPZ CEME TRIP T MU 8.50" bit, 9-5/8" 40# casing scraper, 2-7"junk baskets on 3-1 /2" drillpipe and RIH to 7450' for cleanout run. 18:30 19:30 1.00 7,450 7,450 COMPZ CEME CIRC T CBU 11 bpm & 1910 psi. 19:30 20:00 0.50 7,450 7,450 COMPZ CEME OTHR T BD top drive. Monitor well, static. 20:00 00:00 4.00 7,450 97 COMPZ CEME TRIP T PJSM, POOH f/ 7450' - 97' 04!02/2008 00:00 02:00 2.00 97 0 COMPZ CEME PULD T BOLDS, Finish TOH, break out and LD junk baskets, jars. Clear and clean floor and prepare to TIH w/ New Cmt Retainer. C/O of boot baskets yielded handful! of metal from drilled retainer and (1) partial ss esp cable band clam . 02:00 05:00 3.00 0 0 COMPZ CEME WOEQ T CIP. Decided to order out and run composite retainer in lieu of cast iron. Wait on new retainer. 05:00 09:30 4.50 0 7,397 COMPZ CEME PULD T PU / MU new retainer. Start RIH w/_ Halliburton Composite Cmt Retainer on 3 1/2" DP Workstrin . 09:30 12:30 3.00 7,397 7,397 COMPZ CEME PACK T On depth with Halliburton Fas Drill cement retainer ~Up wt 90K Dwn wt 60K. Pumped thru retainer @ 2 BPM w/250 psi.,Attemoted to set retainer several times by rotating with no luck. Spotted 30 bbls fresh water around retainer to clean off tube in mud system. Set retainer by rotating 30 turns to right, pick up and set with 50K over. Pulled up and sheared out at 150K. Lowered back down in test position and PT drillpipe to 3000 psi and annulus to 1000 psi. Set down opening sliding valve, pumped into hole to est. rate of .5 b m 800 si. Page 9 of '14 '~ C ~J Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T COM 04/02/2008 12:30 16:00 3.50 7,397 7,397 COMPZ CEME SQEZ T RU Schlumberger cement equip. PJSM. Test lines to 3000 psi. Mixed and um ed 76 bbls Class 'G' + 0.5%$2+0.3%D167+0.3%D65+ 0.2% D46, 15.8 ppg cement 3.5 bpm @ 975 psi, putting 20 bbls cement behind i e. Shut down, wait 10 min. to hesitate squeeze. Pump 5 bbls wait 10 min (two stages Q bbls per stage) With 30 bbls cement behind pipe, switched from Schlumberger to rig pump. Continued to hesitate squeeze 5 bbls waiting 10 min each stage pressures continuing to climb. When ress. was 1220 si, broke down to 850 si. Continue to squeeze with max pressure at 1200 psi. Slowly shut pump down and pressure stayed at 1130 psi. Total cement pumped 86 bbls. Total cement behind pine 67 16:00 17:30 1.50 7,367 7,367 COMPZ CEME CIRC T PU to sting out of retainer closing valve and trapped 1130 psi below retainer. LD single. RU and reverse circulate at 3 BPM 400 psi to clean up drill i e. RD and BD lines. 17:30 22:00 4.50 7,367 0 COMPZ CEME TRIP T POOH with drillpipe and setting tool f/ 7367' -surf. 22:00 23:00 1.00 0 0 COMPZ CEME PULD T BO and LD FAS Drill setting tool. Clear and clean floor. 23:00 00:00 1.00 0 0 COMPZ RIGMN RGRP T CO top drive saver sub. Svice top drive. 04/03/2008 00:00 01:00 1.00 0 0 COMPZ CEME PULD T Load additional drill collars in i eshed, stra and tall same. 01:00 01:30 0.50 0 0 COMPZ CEME PULD T Install wear bushing in wellhead, RILD. 01:30 02:00 0.50 0 0 COMPZ RIGMN SVRG T Svice rig and repair MU tong. 02:00 03:30 1.50 0 217 COMPZ CEME PULD T PU and RIH w/drilling bha assy to drill out retainer and cmt. 03:30 06:00 2.50 217 4,000 COMPZ CEME TRIP T TIH f/ 217' - 4000'. 06:00 08:00 2.00 4,000 7,330 COMPZ CEME TRIP T Crew change. Continue to TIH f/4000' to 7330'. 08:00 12:00 4.00 7,330 7,330 COMPZ CEME WOC T Wait on cement. Perform monthly derrick inspection. Clean rig floor and re for drillout. 12:00 12:30 0.50 7,330 7,375 COMPZ CEME DRLG T RIH f/7330' to 7375', tag TOC . Up wt 100K Dwn wt 70K. 12:30 16:00 3.50 7,402 7,402 COMPZ CEME DRLG T Drill cement fl7375' (hard). Drill cement retainer from 7393' to 7398'. Hard cement a ain from 7398' to 7402'. 16:00 16:30 0.50 7,140 7,140 COMPZ CEME OTHR T Bit plugged. POOH from 7402' to 7140'. t~~c~Q 1D of'iA Time Logs Date From To Dur S D th E. De th Phase Code Subcode T COM 04/03/2008 16:30 17:30 1.00 7,140 7,140 COMPZ CEME OTHR T R/U and attempt to reverse circulate and uplug bit. Pressured up to 1000 psi held for 15 min. Pressured up to 1500 si but could not un lu bit. 17:30 00:00 6.50 7,140 0 COMPZ CEME TRIP T TOH f/ 7140' - 185'. Noted hard sheath inside last three jts of DP and top of 1st DC. Cmt was breaking up and lu ed bit. 04/04/2008 00:00 00:30 0.50 0 0 COMPZ CEME PULD T Wash-out and clean out junk baskets. Cement and fiberglass debris f/ retainer in both. 00:30 01:00 0.50 0 0 COMPZ CEME OTHR T Clear /clean rig floor. 01:00 03:00 2.00 0 0 COMPZ WELC OTHR T Pull wear bushing, RU and wash-out BOP stack. BD Top drive, drain stack. Set test lu for BOP test. 03:00 08:00 5.00 0 0 COMPZ WELC ROPE T Testing BOPE 250/ 2500. AOGCC witness of test waived by Lou Grimaldi 3-Apr-08 and approving the waiting until drill out of squeeze complete and POH putting weekly BOP test starting 3 hrs into 4-April-08 (test date on inall 3-A ril-08 08:00 12:00 4.00 0 765 COMPZ CEME TRIP T Remove jets from bit. MU drillout BHA and start RIH cleaning out cement and debris from DCs and DP to 765'. 12:00 16:30 4.50. 765 7,336 COMPZ CEME TRIP T Continue RIH drifting pipe from 765' to 7336'. 16:30 18:30 2.00 7,366 7,452 COMPZ CEME DRLG T MU TOP Drive, tag top of cement @ 7402'. Drill cement from 7402' to 7452'. Pump rate 10 bpm @ 1640 psi. Up wt 105K Down wt 70K Rot. wt 85K. Tor ue 5270 FUIb WOB 10K. 18:30 19:00 0.50 7,452 7,430 COMPZ CEME CIRC T Picked up to 7430'. Circulate bottoms u to clean u hole. 19:00 20:00 1.00 7,430 7,430 COMPZ CEME OTHR T Blow down top drive. RU for casing inte ri test. 20:00 23:00 3.00 7,430 7,430 COMPZ CASIN DHEO T Fluid pack lines for testing ops. Test casing at 1500 psi f/ 30 minutes on c_ hart. Lost 50 psi / 30 min w/ final ressure 1450 psi. Reconfigure shut-in configuration, i.e. close rams instead of annular. Retest: Start pressure 1560 psi, @ 30 min 1510psi, @ 1 hr 1490 psi., @ 1hr 30 min 1490 psi. Discuss results w/ Lou Grimaldi AOGCC, casin inte rit OK'd. 23:00 00:00 1.00 7,430 7,530 COMPZ CEME DRLG T Dril cmt & retainer remnants f/ 7452' - 7530'. PU 105 klbs, SO 70 klbs, RotWt 85klbs, ONBTorq 5.5kft-Ibs, OFBTorq 4.5kft-Ibs. WOB 8 - 10 klbs. Significant cmt chips and residue in returns. 04/05/2008 00:00 08:00 8.00 7,530 7,728 COMPZ CEME DRLG T Drilling cmt and cmt strip ers out of 9 5!8" casin f/ 7530 - 7807'. E~~r?~ 1 ~ of 14~ ~' Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 04!05/2008 08:00 11:00 3.00 7,728 8,884 COMPZ CEME DRLG T Drilled thru @ 7807'. Attempted to RIH without rotating, still stacking out. Pum and rotated down to 8884'. 11:00 12:00 1.00 8,884 8,884 COMPZ CEME CIRC T Circulate bottoms up to clean hole. 10 b m 2000 si 80 RPM 12:00 13:00 1.00 8,884 9,055 COMPZ CEME DRLG T ,RIH f/8884' to 9050' tagged up. Dry drill (/9050' to 9055'. Soft ~iossibly 'ust sand . U wt 120K Dwn wt. 55K. 13:00 18:00 5.00 9,055 0 COMPZ CEME OTHR T POOH with drill out assembly. Break out BHA. Empty boot baskets. Both baskets full of pieces of Baker cement retainer. Clean rig floor and prep for next run. 18:00 19:30 1.50 0 130 COMPZ CEME PULD T PJSM, PU & MU Rev Circ Junk Basket & BHA. 19:30 00:00 4.50 130 9,020 COMPZ CEME TRIP T TIH f/ 130' - 9020' w/ 3 1/2" DP workstrin PU 120k1bs, SO 58klbs. 04/06/2008 00:00 01:00 1.00 .9,020 9,059 COMPZ CEME CIRC T Break circ, pump 30 bbls, drop ball, circulate @ 5 bpm - 1030 psi. Tag fill . at 9050'. Circulate f/ 9050' - 9059' (suck 9ft fill). Circulating at 9 bpm - 2900 psi. PU 120k1bs, SO 58klbs, RotWt 85klbs. Torq 4.23kft-Ibs @ 20r m. 01:00 01:30 0.50 9,059 9,020 COMPZ CEME OTHR T PU t/ 9020'. BD top drive w/ monitor well, static. 01:30 06:00 4.50 9,020 200 COMPZ CEME TRIP T TOH f/ 9020' - 200'. 06:00 07:30 1.50 200 COMPZ CEME TRIP T Break out BHA and clean out RCJB and 2 junk baskets. Recovered more feces of Baker cement retainer. 07:30 08:00 0.50 COMPZ CEME TRIP T MU BHA for another clean out run. 08:00 09:00 1.00 0 1,780 COMPZ CEME TRIP T RIH with DP to 1780'. 09:00 11:00 2.00 1,780 1,780 COMPZ RIGMN OTHR P Slip & Cut drill line. Service Blks, TO & Crown. 11:00 14:00 3.00 1,780 9,055 COMPZ CEME CIRC T Continue RIH to 9055'. Dropped ball and um ed down for RCJB. 14:00 17:30 3.50 9,055 9,068 COMPZ CEMEh CIRC T Washed down to to of RBP @ 9068'1. Circulated clean. Pumped Hi Vis Sweep, 6 bpm @ 2900 psi. Pump dry 'ob. 17:30 22:00 4.50 9,068 103 COMPZ CEME TRIP T POOH f/9068' - 103' 22:00 23:00 1.00 103 0 COMPZ CEME PULD T BO & LD BHA. 23:00 00:00 1.00 0 0 COMPZ CEME PULD T Break out RCJB and boot baskets. Empty and clean same. Noted handful! of metal pieces. Clear /clean floor for tri in. 04/07/2008 00:00 00:30 0.50 0 0 COMPZ CEME PULD T PJSM, PU & MU HOWCO RTTS runnin /retrieval tool. 00:30 04:30 4.00 0 8,998 COMPZ CEME TRIP T TIH w/ RTTS Running/retrieval tool on 3.5" DP to 8998'. PU 135 klbs, SO 53 klbs. E~~ge 12 of ~£~ ~.~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 04/07!2008 04:30 05:00 0.50 8,998 9,063 COMPZ CEME CIRC T MU TD, clean TJ and tube pipe OD. Line up manifold f/ rev circ. Break circulation, slowly ramp up rate to 7.5 b m 970 si. Work i e to 9063'. 05:00 08:00 3.00 9,063 9,063 COMPZ CEME CIRC T Continue Rev Circ w/working pipe, recip same at 7.5 bpm. Pump Hi Vis swee 6 BPM 1000 si. 08:00 09:00 1.00 9,063 9,063 COMPZ CEME CIRC T Pump down drill pipe @ 11 BPM, 2500 psi w/Hi Vis sweep. No visible sand or debris in returns, hole clean. 09:00 14:00. 5.00 9,063 9,063 COMPZ CEME WOEQ T Slow pump down to 3 BPM, 325 psi. Wait on trucks for hole swa . 14:00 15:00 1.00 9,063 9,063 COMPZ CEME CIRC T Pumped 30 bbls Hi Vis Pill, switched to 8.6 ppg 6% KCL clean brine and swa ed out hole fluids. 15:00 16:00 1.00 9,068 8,984 COMPZ CEME PACK T Latched onto Haliburton RBP, opened b ass. Well went on vacumm. Let elements on BP relax. Blow down TD, monitor well. 16:00 20:30 4.50 8,984 2,815 COMPZ CEME TRIP T PJSM. POOH from 8984' - 2815 racking back 6000' of drillpipe for next job. Laying down 3000' of drillpipe. Clear i e-shed. 20:30 00:00 3.50 2,815 300 COMPZ CEME TRIP T Clear pipeshed, unload 4 3/4" DC's, cont POOH f/ 2815' - 300', LD 3 1/2" DP. 04/08/2008 00:00 01:00 1.00 300 0 COMPZ CEME PULD T Finish POOH w/ laying DN DC's. Inspect RBP, Break out Ret tool, LD and remove both from floor. 01:00 02:00 1.00 0 0 COMPZ CEME OTHR T Clear, clean floor. Clear pipe-shed for cm Itn hase. 02:00 03:00 1.00 0 0 COMPZ RPCO RURD P RU equipment and prepare for running , ESP com I i n. 03:00 06:00 3.00 0 0 COMPZ RPCOb PULD P PU ! MU ESP, Motor, seal sections, etc... Hang ESP cable sheave. Checkin connections. Checkin oil. 06:00 10:00 4.00 0 220 COMPZ RPCOh PULD P RIH with ESP completion to 220'. 10:00 13:30 3.50 220 220 COMPZ RPCO PULD P PJSM with rig and Halliburton crew. RU and run the ESP, pack off assembly and slipstop. PT to 850 psi for 15 min. Good test confirmed ack off assembl is sealin .Pulled the SOV from mandrel to be set at _2500', will run it open to enable freeze protect after com letion is hun off. 13:30 00:00 10.50 220 5,594 COMPZ RPCO RCST P RIH with 4-1/2" completion string. Testing ESP cable every 1000'. from 220' to 5,594' 92k u wt; 55k do wt 04/09/2008 00:00 04:00 4.00 5,594 7,556 COMPZ RPCO RCST P RIH with 4-1/2" completion string. Testing ESP cable every 1000'. from 5,594' to 7,556'. Install hanger. Ran 128 cannon clamps, 3 protectolizers, 2 flatguards and 20 flat stainless steel bands. 04:00 11:00 7.00 7,556 7,556 COMPZ RPCO OTHR P Make cable splice, connect to enetrator, test cable. I~a~ 13 of 'I~ • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 04/09/2008 11:00 11:30 0.50 7,556 7,566 COMPZ RPCOti HOSO P Land tuging hanger with BPV installed, lock down. PT tubing pack off to 5000 si. 11:30 15:00 3.50 7,566 7,566 COMPZ RPCO NUND P Change upper rams to 3-1/2" and lower to 4-112", NP BOPE. 15:00 15:30 0.50 7,566 COMPZ RPCO DHEQ P Test ESP connection. Test conducted: 2.4 Phase to Phase, 1 gig ohms Phase to Ground, 1,033# intake pressure, 1,035# discharge pressure, 71?F Intake tempeture, 72 motor motor wind. 15:30 18:00 2.50 COMPZ RPCOti NUND P NU tree 18:00 19:00 1.00 COMPZ RPCO SFEQ P Pressure test tree to 5,000 psi. 19:00 20:00 1.00 COMPZ RPCO CIRC P Pump remaing pit vol of 93 bbls @ 4 b m 70 si down IA 20:00 21:00 1.00 COMPZ RPCOti OTHR P Move and equalize DP from side to side for ri move re aration. 21:00 21:30 0.50 COMPZ RPCOh SFTY P Held PJSM w/ LRS on freeze protect. 21:30 23:30 2.00 COMPZ RPCO FRZP P Pressure test lines to 2,500 psi and pump 50 bbls @ 2 bpm and freeze protect tbg to 2,500'. Then pump 150 bbls @ 2 bpm down IA and freeze rotect to 2,500' on IA. 23:30 00:00 0.50 COMPZ RPCO OTHR P Set BPV and ~telease Rig Ca) 23:59 on 4-9-08 ~~~~ rage ~~ of 1d 1J-135 BOP Test • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 11:15 AM To: 'Packer, J.Brett' Subject: RE: 1J-135 (207-038) BOP Test Page 1 of 2 Brett, I found a copy of the BOP test over here. The issue, as we discussed on the phone, was that the PTD number on the BOP test form was not that of 1 J-135. The PTD number on the report was 206-038 rather than 207-038. Assuring that the correct PTD number is entered eliminates some confusion as we check and file information. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Friday, Apri! 04, 2008 11:05 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-135 BOP Test Tom, Thanks for the quick reply. I've got the Rig Supervisors looking for that email and they will forward it to you when they find it. ,y Brett Wacker 2}rill'ng s~ ?Neils ~lNorkover Engineer ZUork# 265-6845 CeQ# 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, Apri104, 2008 10:43 AM To: Packer, J.Brett Subject: RE: iJ-135 BOP Test Brett, Thank you for the information. 1 do not believe it necessary to retest. With regard to the correct PTD number, I will have to review the sundry again. Do you or the rig have the message back regarding the 3/27/08 BOP test? If you could forward that, it would help. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Friday, April 04, 2008 10:31 AM To: Maunder, Thomas E (DOA) Subject: 1J-135 BOP Test 4/4/2008 1J-135 BOP Test Tom, Page 2 of 2 Yesterday t received the approved 1J-135 Sundry Application back from the state and I had aA intentions of sending it up to the rig immediatety, but you know how easy it can be to get sidetracked and pulled in another direction. Unfortunately, 1 forgot to send it up to the rig yesterday, and this mom'rng Nardic 3 performed their weekly BOP test but only tested to 250/2500 psi as was done on the first two BOP tests on 3/20/08 and 3/27/08. It is my fault for not getting the Sundry to the rig in time for the BOP test, thus, they did not know you had specified 3000 psi on the Sundry Application. 1 a~logize for this error, and now, knowing that you always request a 3000 psi test, 1 will keep that in mind for all upcoming BOP tests. Despite my error, { am requesting approval to continue with the workover operation using the 250/2500 psi BOP test, but if you feel it is necessary, we will repeat the BOP test to 3000 psi. The SBHP in this well is 1629 psi at mid-perf (3559' TVD) based upon our 8.8 ppg kill weight fluid currently in the hole and the MASP is 1273 psi using a 0.1 psUft gradient. Currently we are out of the hale and ready to run back in with our milling assembly to finish milling out the cement in the casing, but wilt wait for your approvat to continue or repeat the BOP test. Also, t have another concern that was brought up by the Rig supervisor. We have been using the mainbore PTD# 206-038 for this well because we are working in the mainbore well above the D-sand lateral. Following the 2nd BOP test on 3127/08, the state informed us that we were using the wrong PTl3# on the BOP test report and we should be using the D-sand lateral PTD# 206-039. is this correct, and if so, why? [t's not obvious to me why we would have to use the D-Lateral PTD#: The rig h~ ncrt sent the results of this ink BOP test bo the state yet because they want tQ verify that they are usir~ the carr®ct PTD# Please advise as to what you would like us to do n~arding the BOP test and the PTD#, we are currently on stand-by waiting to hear back from you. Thanks, Brett hacker ~ri~ng aZ `Welts ~m~over Engineer `Work# 265-6845 Celx# 23Q-8377 4/4/2008 t1 ALASSA OIL A1QD GA.S CO1~T5ERQA7'IOI1T COMl-II55IO1~T Brett Packer Wells Group Engineer ConocoPhillips Alaska., Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-135 Sundry Number: 308-102 Dear Mr. Packer: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice -far a representative of the- Cemrnissien ~ witness-.any _ -__ . _. __. required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such. further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2nd day of April, 2008 Encl. • c~ 2~ • R~CEiV STATE OF ALASKA , ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION M;qR 2 ~ 200 ~•'~ APPLICATION FOR SUNDRY APPR~~1 ~ ~~ 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ----~~-°-- aiver Ottler""Q Alter casing ^ Repair well ^/ ~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillipsAlaska, InC. Development 0~ Exploratory ^ 207-038 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23349-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS NO ~ 1J-135 9. Property Designation: 10. KB Elevation (ft): ~ o.Field/Pool(s): ~ ADL 25661, 25662, 380058 RKB 41' t~~~ ~/~L- uparuk River Field /West Sak Oil Pool 12. PRESENT WELL CON ITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17735' ~ 3512' ~ 17720' 3512' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 121' 121' SURFACE 3421' 13-3/8" 3462' 2215' INTERMEDIATE 9778' 9-5/8" 9819' 3604' SLOTTED LINER 8555' 5-1/2" 17722' 3513' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9829'-11845', 11847'-17681' 3605'-3584', 3584'-3513' 4-1/2" L-80 7548' Packers and SSSV Type: Packers and SSSV MD (ft) B-sand MLZXP liner pkr @ 9167' no SSSV no SSSV 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 28, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Group Engineer Signature ~~ Phone 265-6845 Date ?~z fl~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness °~77 ~~ - ~ ®C-°' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: '~ ®~~ per; e U~v v"'` ~~ Q ~S' \ ~ ` l V~~~~7~~ Subsequent Form Required: ~6 APPROVED BY ' / 2 ~ X ANproved by: C IS ONER H C MI SIGN Date: r U Form 10-403 Ravi d 06/2006 ~ {' Su mit in Du licate • M ConocaPhll!!ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 28, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 EcEwE~ t~ MAR 2 g 2008 SS10n ~ ~ Gas . Comte A~ p~har2-9e ~~; Dear Commissioner: ConocaPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to fix a casing leak found during the ongoing workover on West Sak well 1J-135 (PTD# 206-038). 1J-135 was originally completed as an ESP producer in 2007. The ESP went down in February 2008 and a plan was quickly developed to workover this well as soon as possible due to rate impacts. Due to wellbore deviation, we were not able to pull the pump pre-rig, so the pump was to be pulled once the completion was brought to the surface during the workover. Upon pulling the packoff above the pump, we discovered that the KOBE knockout had been eroded leaving a hole in the packoff. Upon pulling the remainder of the tubing, we found a similar hole in the tubing directly across from the KOBE knockout about 1" in diameter. Due to these circumstances, it was decided to run in with a test packer and test the casing to verify integrity. Upon testing, we discovered a leak in the 95/8" casing directly across from the hole in the tubing at approximately 7443' MD (3234' TVD). ~' The casing leak was a direct result of the jetting action of produced fluids out the tubing while the ESP was running, and not due to any corrosion issues as this is a brand new well. We set a retrievable bridge plug downhole at 9075' MD, just above the B-lateral hook hanger to isolate the wellbore from the laterals. The casing was tested good above and below the leak, verifying only one hole in the casing. The current plan is to cement squeeze the casing leak, test the casing to 1500 psi, and verify that we have casing integrity before we continue with the workover as planned. The casing leak was a surprise to us, as there was no way to have determined this pre-rig since the well is a packerless ESP completion. Currently, with a downhole plug set and 8.8 ppg brine in the well, the well is static with fluid to the surface indicating a downhole pressure at the leak of 1480 psi. We just completed our weekly BOP test yesterday. The scope of this workover is to pull and replace the ESP. The final completion will be identical to the current completion once finished. Attached is a current schematic along with a general plan forward workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~~ ~~~~ Brett Packer Wells Engineer CPAI Drilling and Wells ORIGINAL IJ--135 West Sak Producer General Workover Procedure (Plan Forward) Cement Squeeze Casing Leak, Run ESP Completion 1. Spot 2500# sand on top of RBP set at 9075' MD. 2. Spot a 114 bbl (1500' MD) high-viscosity pill on top of sand plug. 3. RIH with a 95/8" cement retainer on 3%2" IF drillpipe and set at 7390' MD (approximately 50' above the casing leak at 7443'). 4. Close the annular and PT the backside to 1000 psi to verify retainer is set. Move stinger to test position and PT drillpipe to 3000 psi. Move stinger back down. 5. Check leak rates and pressures. 6. Mix and pump 50 bbls 12.0 ppg DeepCRETE cement and perform hesitation squeeze. 7. Leave 3.8 bbls cement in 95/8" casing below retainer (volume down to leak), sting out of cement retainer and dump remaining cement on top of retainer. 8. Pull up one stand, reverse circulate out. at max rate. 9. POOH w/drillpipe and allow sufficient time for cement to cure. 10. RIH w/ mill tooth bit assembly w/ large ports and while reverse circulating, slowly drill out cement and retainer down past casing leak to 7450' MD. 11. Pressure test casing to 1500 psi. 12. Continue to drillout contaminated cement stringers below the casing leak down to within one joint of the RBP. Reverse circulate while slowly rotating drillstring until returns are clean. 13. PT casing again to 1500 psi. 14. POOH and swap over to casing scraper with RBP retrieving head below. 15. RIH to RBP and reverse circulate out remaining sand above RBP. 16. Latch and release RBP, POOH laying down drillpipe. 17. Continue running ESP completion. KRU 1J-135 ConocoPhillips Alaska, Inc. 1J-135 Summary Ops ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Packer, J.Brett [J.Brett.Packer@conocophillips.com] Sent: Monday, March 31, 2008 3:20 PM To: Maunder, Thomas E (DOA) Subject: 1J-135 Summary Ops Attachments: 1J-135 Operations Summary as of 3-31-08.pdf Tom, ~-~~ - ~ ~ S ~p S~~ • e Thy 5~,~~~ v~~.`> .,, Sv~ ~ N1e ~ CcJ°J Ee , As was discussed over the phone, here is an update of the status of 1 J-135. Q~csS~~~' ``~~ ~ V. ~CG~~` Rig Activi 3/18/08 Accepted Rig 3/19!08 Kill Well ~. 3/20/08 BOP test, POOH w/ completion ~~„~~ 3/21/08 Cont. POOH w/ completion, discovered tbg leak, toad pipe shed w/ workstring 3/22!08 RIH w/ test packer 3/23108 Cont. RIH w/ test packer, found leak in 9-5/8" casing between 7442' - 7447' MD. (3234' TVD) 3/24/08 RIH w/ RBP & test packer to verify only the one leak, trouble getting down, POOH. 3/25/08 RIH w/ cleanout asst'., cleanout to top of B-sand hook hanger 3/26/08 RIH w! new RBP, set just above B-Sand hook hanger at 9075' MD. POOH to PU test packer. RIH w/ test packer. 3/27/08 Set test packer below known casing leak, tested 9-5/8" casing to 2500 psi for 30 min. Verified only the one leak. Weekly BOP test. 3/28/08 RIH w/ muleshoe, set sand plug on top of RBP. Place Hi-Vis pill on top of sand plug. POOH. RIH w/ cement retainer, trouble circulating, POOH w/ retainer to inspect. 3/29!08 RIH w/ replacement cement retainer, set 50' above leak. Pump 33 bbl cement squeeze w/ partial success. Need additional cement. 3/30/08 Pump second cement squeeze (22 bbls additional cement behind pipe, achieved squeeze pressure of 2000 psi and held) 3/31/08 RIH w/mill to top of cement. Ream down near retainer. Wait additional time for cement to cure (24 hrs since final squeeze). Getting ready to drill out cement retainer and cement to test casing. Plan Forward: 3/31/08 Drill out cement to below the leak, test the casing to 1500 psi. 4/01/08 Continue to drill/cleanout cement, sand plug to RBP. Test casing again to 1500 psi. POOH. 4/02/08 RIH w/ RBP retrieving head and pull RBP. Lay down DP. 4/03108 Run ESP completion. 4/04/08 RDMO All indications are we got a good cement squeeze, but that will be verified by two 9-5/8" casing tests after we mill out the retainer and cement. Attached is an operations summary. Please contact me with any questions. Thanks, 4/1/2008 r~ Dail O erations Summa Re ort Y P rY P i 1 J-135 ' .. ,• Job: RECOMPLETION Start Date Entl Date Last 24hr Sum _ 3/18/2008 3/19/2008 Move Rig from 3M Pad to 1J Pad. MIRU and set handi berm. RU hard line f/ cellar to well head and to Tiger tank. Lubricate out BPV. 3/19/2008 3/20/2008 PT lines and blow down gas head on IA. Pump 50 bbls down tbg . Reverse dreulate down IA ,attempt to get circulation. Kill well 3/20/2008 3/21/2008 Install BPV and ND Tree and NU BOPE. Test BOPS. Unland hanger and Pooh to 7,016' 3/21/2008 3/22/2008 Continue to Pooh f/ 7,016' and Replace ESP Components. Found hole in 2nd tbg joint above pump or set depth of 7,440'?. Notify Anchorage and wait for decision. Decision was to Rih w/ Test packer to 7,550' on DP. Load pipe shed w! 3 112 DP. 3/2212008 3/23/2008 Continue to Load pipe shed w/ 3 1/2 DP and Test Packer. Rih w/ same PU and Drifting 3 1/2 DP to 7,550' and attempt to test csg. f/ 7,550' to 7,371' Insufficient test. Pooh and add wt pipe and condition KW fluid w/ tubes. Begin circulating and swapping hole volume. 3!23/2008 3/24/2008 Continue to swap hole volume w/ lubricated KW Fluid. Set and Test packer. Continue to Rih to 7,548'. Set and test pkr PT up to 860 psi Q 2 bpm and begin to pump away. Work back to 7,430' in 30 tt increments pumping away Q 2 bpm 700 psi. before recovering a good test Q 2,500 psi. Rih to 7,452. and and work back in 5' increments and estimate hole between 7,442' and 7,44T. Test f! 7,442' to surface to 2,500 psi for 30 minutes and chart. Pooh and w/o test and squeeze equip. Rih w/ RBP and Test packer to 7,393'. 3/24/2008 3/25/2008 Continue to Rih to 8,575' and began taking wt. Pooh to 8,384' and attempt to set RBP with no luck. Rih and RBP set Q 8,608' but would not test. Pull up hole again and attempt to set wi no luck. Pooh and Pu Clean out assy. ~ Rih t/ 3,281'. 3/25/2008 3/26/2008 Continue to RIH w/ Clean out assy. Tag fill Q 8611tt, wash w/ partial returns and dean WB to top Hook Hanger Q 9094tt. Rev Circ well clean Q 4 bpm w! 60°~ returns. POOH LD C/O BHA, S&C Drill Line. 3/26/2008 3/27/2008 Set HOWCO RBP Q 9075'. PU &RIH w/ BOT test packer, set at 7450', TU and start Csg test over interval from 7450' - 9075' to 2500 psi f/ 30 minute. Notified AOGCC inspector of pending BOP test Q 0600 hrs. 3/27/2008 3/28/2008 Tested casing interval from 7450' -9075' to 2500 psi f/ 30 min. OK. Release packer, POOH. Tested BOPS to 250!2500 psi. No failures. AOGCC witness waived by John Crisp. RIH w/ muleshoe on DP to spot sand plug over top of RBP. RU pump van and start pill spotting procedure. 3/28/2008 3/29/2008 Spot 2500# sand over top of RBP. Spot 114 bbls hi-vis pill over top of sand. POOH w/ DP, lay out mule shoe, PU retainer and running tool. RIH on 3 1/2" DP work string to 7400 tt. Attempt to dreulate, unable to obtain decent rate down DP, reverse circulate OK, possible obstruction in tool, diagnose same, decide to POOH w/ retainer to ~ inspect. ~, 3/29/2008 3/30/2008 Wait on replacement retainer, PU &RIH w! same. Establish pump thru parameters, set Q3790', p-test above to verify proper set. Establish injection, batch and displace DeepCRETE cmt system for squeeze. Perform hesitation squeeze, pumped total of 33 bbls DeepCRETE, run out of ant. Pump to clear retainer, unsting, reverse to dean DP & order additional ant. 3/30/2008 3/31/2008 Perform Squeeze #2. Squeezed total 22 bbls 12 ppg DeepCRETE behind csg and left 4 bbls below retainer. POOH, LD running Tool. 3/3112008 4/1/2008 I -- - r -- -- Page 1/1 Report Printed: 3/31/2008 1J-135 (PTD 2060380) Report of Failed ESP Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 21, 2008 1:39 PM To: 'NSK Problem Well Supv'; Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: RE: 1 J-135 (PTD 2070380) Report of Failed ESP Brent, 1 was just filing and noted that the PTD number should be 207-038 rather than 206-038. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, March 21, 2008 1:09 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: iJ-135 (PTD 2060380) Report of Failed ESP Tom & Jim, Page 1 of 2 The plan to gas lift the well has changed. A workover rig is currently on the well to repair the ESP. The well was not brought on line in gas lift service, therefore a 10-404 will not be submitted for a change in service. Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:33 PM To: NSK Problem Well Supv Subject: RE: 1J-135 (PTD 2060380) Report of Failed ESP Martin - Please submit a 10-404 to document the change of artificial lift method from ESP to gas lift. This would be consistent with how paperwork for similar ESP failures has been handled. I understand this is a temporary situation with plans to repair the well with a rig intervention in the near future. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 3/21 /2008 1J-135 (PTD 2060380) Reportailed ESP ~ Page 2 of 2 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, March 03, 2008 9:19 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1J-135 (PTD 2060380) Report of Failed ESP Tom & Jim, West Sak packerless ESP lifted producer 1J-135 (PTD 2060380) experienced an ESP failure on February 28, 2008. The TIO prior to failure was 212/208/432. Our plans include attempting to pull the pump utilizing coiled tubing and producing via gaslift by installing an orifice valve in the mandrel at 2194' MD. We intend to produce using gaslift until the failed ESP can be replaced. Attached is a 90 day TIO plot and a wellbore schematic. Please let me know if you have any questions. «1J-135 Wellbore Schematic.pdf» «1J-135 TIO Plot.jpg» Martin Walters Problem Wells Supervisor ConocoPhitlips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1720 Pager (907) 659-7000 pgr. 909 3/21/2008 1J-135 (PTD 2Qfi93~8~~Report of~led ESP ~ Page 1 of 2 Zc~7v Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, March 03, 2008 2:11 PM ~~~ ~(71~~ To: 'NSK Problem. Well Supv' ~~ Subject: RE: 1J-135 (PTD 2060380) Report of Failed ESP One other thing -PTD # should be 2070380 ~ Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Regg, James B (DOA) Sent: Monday, March 03, 2008 1:33 PM To: 'NSK Problem Well Supv' Subject: RE: 1J-135 (PTD 2060380) Report of Failed ESP Martin - Please submit a 10-404 to document the change of artificial lift method from ESP to gas lift. This would be consistent with how paperwork far similar ESP failures has been handled. I understand this is a temporary situation with plans to repair the well with a rig intervention in the near future. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, March 03, 2008 9:19 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1J-135 (PTD 2060380) Report of Failed ESP Tom & Jim, West Sak packerless ESP lifted producer 1J-135 (PTD 2060380) experienced an ESP failure on February 28, 2008. The TIO prior to failure was 212/208/432. Our plans include attempting to pull the pump utilizing coiled tubing and producing via gaslift by installing an orifice valve in the mandrel at 2194' MD. We intend to produce using gaslift until the failed ESP can be replaced. Attached is a 90 day TIO plot and a wellbore schematic. Please let me know if you have any questions. «1J-135 Wellbore Schematic.pdf» «1J-135 TIO Plot.jpg» Martin Walters 3/3/2008 a ~~- u~~ 1J-135 (PTD 2060380) Report of Failed ESP ~ Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1720 Pager (907) 659-7000 pgr. 909 3/3/2008 KRU 1J-135 PTD 207-038 CHI IAP 600 500 400 ~ X00 200 100 0 FTP OAP TlU{~ Pla# - 'IJ-'1 ~5 02-Dec-07 15-Dec-07 28-Dec-07 10-Jan-08 23-Jan-08 05-Feb-08 Date 1$-Feb-08 ~~~ 150 a E n~ 100 50 0 i'~ ~~. ~'• !<' Conac~oPhll~as Ataska, ln~. .... - ___ ! f J-135 TUBING (aa54s, i OD:4.500, ID:3.958) ` ~ N KRU 1 J-135 HPC ~UUZyZ334yUU Well I e: F'KUU An le o) I5: de ~ SSSV Type: NONE i Orig Com letion: 5/23!2007 Angle @ TD: 91 deg @ 17735 Annular Fluid: Last W/O: _ _ Rev Reason: GLV C/O Reference L : 41.4' RKB Ref Lo Date: Last U date: 1/31/2008 Last Ta TD: 17735 ftKB Last Tag Date: Max Hole Anale~ 93 deg (o7 11921 ___ Casin Strin -ALL STRINGS Descri lion Size T~_ Bottom 1 VD _ Wt Grade ThrEad CONDUCTOR 20.000 0 118 118 94.00 H-40 WELDED _____ SURFACE 13.375 0 3462 _2215 _____ 68.00 L-80 BTC INTERMEDIATE 9.625 0 9819 3604 40.00 L-80 BTCM B-SAND SLOTTED LINER 5.500 9167 1772? 3513 15.50 L-RO BTC'M Tubing String -TUBING Size Top Eottom T JD Wt Gi ode Thread 1 ~n~~ n -1=~ _-,= 1~ ~0 L ,fin IhTPe, Perforations Summary I E:' 1 E: interval TVD Zone Status Ft SPF ! Date T e Comment 9829 - 11845 3605 - 3584 WS B 2016 32 4/30/2007 ;SLOTS 2.5"long X .125"wide, 4 circumferencial rows/ft, 3" centers sta ered 18 de 11847 - 17681 3584 - 3513 WS B 58341 32 i 4/30/2007 SLOTS 2.5"long X .125"wide, 4 ' circumferencial rows/ft, 3" ~ ~ canters sta ered 18 de SEAL r~- '..Gas Lift Mandrels/Valves (7496-7510, ". OD:5.130) ,_1 I St ~MD TVD ~ Man Mfr Man Type V Mfr V Type V UD I Latch Port tRU~Ru ~ ,y-, ~ 1 2194 18701 CAMCO KBMG SOV 1.0 BK-5 0.000 _ 2000 1/30/2.008 r r;~ Ey~ Other (plugs, equip., etc.) -COMPLETION e, GAUGE --- - (7545-7547, i! 1 1 ~,' Other (Dluas. eauio.. etc.) - B-SAND LINER DETAIL XO Bushing (9194-9195, OD:7.630) De th TVD T e Descri lion ID 36 36 HANGER VETCO GRAY TUBING HANGER 4.500 7409 3226 Discharge UNIQUE DISCHARGE SUB 3.950 Sub 7470 3240 PUMP TTC ESP @ 40' SLM. SET 4 1/2 D&D PACKOFF W/ KOBE KNOCK OUT, 0.000 CHECK, AND STINGER ASSEMBLY @ 40' SLM (DISTANCE FROM F.N. TO KOBE KNOCK OUT IS 36'--DISTANCE FROM F.N. TO CHECK VALVE IS 86"--100.5"= OAL OF PACKOFF ASSEMBLY ). TESTED PACKOFF. SET 4 1/2 TBG. STOP ONTOP OF PACKOFF @ 32' SLM. ""DEPTH OF 7470' IS APPROXIMATION"` 7486 3244 XO Intake PERFORATED CROSSOVER INTAKE TTC ESPCP 0.000 7496 3246 SEAL UPPER/LOWER TANDEM SEAL GSB3D6 FER HL SSCV H6 SB/SB i 0.000 PFSA 7510 3249 MOTOR 418 HP KMH 2610 v / 98 am 0.000 7545 3257 GAUGE A-WELL PUMP SENSOR 0.000 7547 3258 Centralizer MOTOR CENTRALIZER ~ 0.000 9094 3528 HANGER D-SAND BAKER MODEL'B-1' HOOK HANGER INSIDE CSG 3.980 9097 3528 D-SAND D-SAND WINDOW 0.000 WINDOW ~~ De th TVD T e Descri Pion ID / - 9167 3539 PACKER B-SAND MLZXP LINER TOP PACKER 7.500 '~ ,~ 9188 3542 HANGER B-SAND FLEXLOCK LINER HANGER 6.090 a• ~- ~, 9194 3542 XO Bushing B-SAND CROSSOVER BUSHING i 4.950 .y -- [ ~ ~' 9195 3542 SBE B-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 F ~, 17721 3513 SHOE B-SAND SILVER BULLET SHOE 4.750 WELL LOG TRANSMITTAL To: State of Alaska July 6, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-135 AK-MW-4957664 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 349-00 PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~. -~ ~ ~ ~~ _ ~ Date: ~ , , ~ ~ ~ ~;,~~ Signed: ~a J ~f~f-63~S ~ rS3~( ~ ~ 12-J u I-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-135 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 41.40' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 17,735.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN -EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~~~ Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 02. D ~ -' O ~C~ l~ LJ ConocoPhillips July 2, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-135, 1 J-135L1 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-135 and 1J-135L1. ,~~ If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1a. Well Status: Oil ^ ~ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: a~ Q 8 Development ^/ Exp~or~tbry ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., a oraband.: May 22, 2007 12. Permit to Drill Number: 207-038 / +~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 12, 2007 ` 13. API Number: 50-029-23349-00 ' 4a. Location of Well (Governmental Section): Surface: 1583' FSL, 2287' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: April 27, 2007 14. Well Name and Number: 1J-135 At Top Productive Horizon: 649' FNL, 829' FWL, Sec. 12, T10N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 121' MSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1954' FSL, 761' FWL, Sec. 13, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17720' MD / 3512' TVD West Sak Oil Poof 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558926 y- 5945397 ~' Zone- 4 10. Total Depth (MD + TVD): 17735' MD / 3512' TVD ( 16. Property Designation: ADL 25661; 25662, 380058 f TPI: x- 562108 y- 5937910 Zone- 4 Total Depth: x- 562110 ~ - 5929954 ~ Zone- 4 11. SSSV Depth (MD + TVD): none 17. Land Use Permit: 2177, 4604 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 15.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1523' TVD (Estimated) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# H-40 41' 121' 41' 121' 42" 280 sx AS 1 13.375" 68# L-80 41' 3463' 41' 2213' 16" 650 sx AS Lite, 220 sx DeepCRETE 9-5/8" 40# L-80 41' 9819' 41' 3604' 12.25" 720 sx DeepCRETE 5.5" 15.5# L-80 9167' 17722.5' 3537' 3512' 8.5" slotted liner 23. Open to production or injection? Yes O No ^ If Yes, list each 24. TUBING RECORD Interval open (MD + TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7549' 9167 slotted liner from 9222' - 9829', 11847'-17680' MD ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production June 10, 2007 Method of Operation (Flowing, gas lift, etc.) shares production with 1J-135L1 Date of Test 6/13/2007 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1222 GAS-MCF 142 WATER-BBL 0 CHOKE SIZE 24% GAS-OIL RATIO 149 Flow Tubing press. 268 p Casing Press: not available Calculated 24-Hour Rate -> OIL-BBL 1981 GAS-MCF 296 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD + 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. ~::~. '~FL NONE ~ . 2,Z,.• O i"'~. ~ ~~~ Form 10-407 Revised 2/2007 ~ ~ ~ /1 ~ ~ ~ ~ ~ C INU~~ E~~ E SIDE x ~~ ~ ~~~~ ~~~~ 1 L 2 3 2007. /V L ~C~~C V ~~ JUL 0 5 2007 ~~i~f~ SIOr V zs. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and Permafrost -Top Surface surface attach detailed supporting data as necessary. If no tests were Permafrost -Bottom 1619' (est.) 1523' (est.) conducted, state "None". T3 n/a n/a K15 n/a n/a Ugnu C 6287' 2940' Ugnu B 7193' 3174' Ugnu A 7557' 3260' K13 8157' 3379' West Sak D 9065' 3524 West Sak C 9535' 3575' N/A West Sak B 9771' 3600' Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Nam Randv-~l~n as Title: GKA Drilling Team Lead _ Si ~~ r~- Z' . ~ `~„C'' , - ~ gnature N~ rt --~. ~i6s ~-r ~.j ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2007 Slotted and Blank B Liner Detail Well: 1J-135 r ~Q~Q~~~~A~~~~ "B" 5 9/2" Slotted Liner Date: 4/3012007 kldska, ins, Rig: Doyon Rig 15 FINAL DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 5" DP to Surface =_> 9156.78 Liner Runnin Tool 5" Does not sta in hole 10.50 9156.78 - - ~ MLZXP Liner Top Packer 9-5/8" (7.50" X 8.32") 21.21 9167.28 _ -- 9188.49 •- - FlexLock Liner Hanger 7" x 9-5/8" (6.09" X 8.30") 5.27 9188.49 - XO Bushing 4.95" ID, 7.63" OD 1.44 9193.76 190-47 Casing Seal Bore Ext. 4.75" ID x 6.28" OD 19.65 9195.20 XO Pup Jt. -Hydril 563 X Hydril 521 3.90 9214.85 Pup Jt. - 5-1/2", 15.5 ppf, L-80, Hydril 521 3.68 9218.75 9222.43 Jts 1s7 to 201 15 Jts 5-1 /2" Hydril 521, L-80, 15.5 ppf-Blank Casing 606.45 9222.43 Jts 137 to 18 50 Jts 5-1/2" Hydril 521, L-80, 15.5 ppf Slotted Casing. 2016.23 9828.88 5-1/2", BTC-Mod x Hydril 521 Crossover 1.58 11845.11 Jts 1 to 136 136 Jts 5-1/2", BTC-Mod, L-80, 15.5 ppf Slotted Casing 5$33.77 11846.69 5-1/2", BTC-Mod, L-80, 15.5_ppf Blank Casin 40.36 17680.46 5-1/2" Silver Bullet Shoe 1.68 17720.82 Bttm of Shoe =_> 17722.50 17722.50 Top Of window planned @ 909T _ 70' above TOL 17722.50 17722.50 NOTE: Snap in is 13' inside Top of liner 17722.50 Top of liner Oriented to 1 Deg Left of high side. 17722.50 17722.50 17722.50 17722.50 17722.50 17722.50 17722.50 TD 8-1/2" hole a~ 17,735.00' MD / 3512' TVD 17722.50 5-1/2" Shoe @ 17,722.50' MD / 3512' TVD 17722.50 (12.5' RatHole) 17722.50 Run 1 Hydro-Form per joint floating on the BTC 17722.50 On jts 1-136 17722.50 1 Hydro-Form perjoint On the Hydril w/stop rings 17722.50 In the center of the jts On jts 137-186 17722.50 65 Jts Hydril 521 (Blanks/Slots) = 2622.68 17722.50 Torque Rings in joints 56-136, 81 total = 3473.48' 17722.50 17722.50 Ran total of 201 jts Csg = 8535.88' Up Wt (RT) 235K Ran Total 186 Hydro-Forms Dn Wf (RT) OK Used Run-N-Seal thread compound on all connections. Block Wt 70K Drifted casing to 4.825" w/ tefion rabbit. Rot Wt 130K Torque Rings Installed in joints ?? Thru 56 = 136 torque rings Supervisors: Fred Herbert /Scott Heim Halliburton Company Survey Report Company: ConoaoPhillips Alaska Inc. Field: Kuparuk River Unit Sitr. Kuparuk 1J Pad Well: 1 J-135 Wellpath: 1J-135 i Field: Kuparuk River Unit North Slope Alaska United States i Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) ~I Sys Datum: Mean Sea Level Date: 6/13/2007 Time: 14:08:41 Page: 1 Co-ordinate(NE}Reference: Well: 1J-135, True North Vertical (TVD) Reference: 1J-135: 122.5 Section (VS) Reference: '' Well (O.OON,O.OOE,180.OOAzi) Survey Caknlation Method: Minimum Curvature Db: Oracle Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: bggm2006 Well: 1 J-135 Slot Name: We11 Position: +N/-S -523.65 ft Northing: 5945397.09 ft Latitude: 70 15 41.108 N +E/-W 132.13 ft Easting : 558926.15 .ft Longitude: 149 31 25.162 W Position Uncertainty: 0.00 ft Wellpath: 1J-135 Drilled From: Well Ref. Point 500292334900 Tie-on Depth: ~ 41.40 ft Current Datum: 1 J-135: Height 122.50 ft " Above System Datum: Mean Sea Level Magnetic Data: 4/7/2007 Declination: 23.56 deg Field Strength: 57621 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft --- ft - - _-- -- -_ -- ft - deg ------ 41.40 0.00 0.00 180.00 ~ Survey Program for Definitive Wellpath j Date: 12/5/2006 Validated: No Version: 1 'i Actual From To Survey Toolcode Tool Name ft ft r 104.00 836.00 1J-135 gyro (104.00-836.00) CB-GYRO-SS Camera based gyro single shot 8 77.39 17706.10 1J-135 (877.39-17706.10) MWD+IFR=AK_CAZ_SC MWD+IFR AK CAZ SCC 1 Survey N[D Incl ft deg 41.40 0.00 104.00 0.15 204.00 0.27 304.00 0.97 404.00 0.48 490.00 0.62 ', 590.00 3.21 I 660.00 6.04 750.00 10.35 836.00 13.54 ~~ 877.39 14.06 'I 972.10 17.03 1066.14 22.67 ~~ 1161.80 24.65 ', 1256.42 27.32 II 1353.43 30.42 1449.50 34.95 1544.36 39.40 1639.12 42.27 j 1731.22 46.22 ~ 1829.23 48.60 1924.09 51.44 ~ 2019.30 56.06 2112.70 63.18 2207.28 66.41 2304.78 71.28 2399.24 73.90 2493.74 73.23 2589.04 73.02 ~zim T~'D Sys TVD N/S E/W de g ft ft ft ft 0 .00 41. 40 ` -81 .10 0 .00 0 .00 49 .37 104. 00 -18 .50 0 .05 0 .06 345 .24 204. 00 81 .50 0 .37 0 .10 8 .61 303. 99 181 .49 1 .43 0 .17 14 .03 403. 98 281 .48 2 .67 0 .40 128 .00 489. 98 367 .48 2 .74 0 .85 167 .67 589. 92 467 .42 -0 .33 1 .87 179 .53 659. 69 537 .19 -5 .93 2 .32 190 .39 748. 75 626 .25 -18 .62 0 .90 192 .07 832. 88 710 .38 -36 .07 -2 .60 186 .38 873. 08 750 .58 -45 .81 -4 .17 178 .69 964. 32 841 .82 -71 .11 -5 .13 174 .48 1052. 74 930 .24 -102 .95 -3 .07 168 .79 1140. 37 1017 .87 -140 .87 2 .58 165 .35 1225. 42 1102 .92 -181 .25 11 .91 156 .52 1310. 40 1187 .90 -225 .34 27 .34 151 .63 1391. 25 1268 .75 -271 .89 50 .12 150 .90 1466. 82 1344 .32 -322 .13 77 .69 149 .15 1538. 51 1416 .01 -375 .78 108 .66 148 .58 1604. 47 1481 .97 -430 .77 141 .89 148 .84 1670. 80 1548 .30 -492 .43 179 .36 149 .71 1731. 74 1609 .24 -554 .91 216 .49 149 .30 1788. 02 1665 .52 -621 .05 255 .45 154 .09 1835. 25 1712 .75 -691 .97 293 .50 156 .23 1875. 53 1753 .03 -769 .62 329 .42 156 .77 1910. 70 1788 .20 -852 .99 365 .66 157 .30 1938. 96 1816 .46 -935 .97 400 .83 157 .95 1965. 70 1843 .20 -1019 .78 435 .33 155 .79 1993. 37 1870 .87 -1103 .64 471 .15 MapN ~1apE Tool ft ft -- 5945397. 09 558926. 15 _ - TIE LINE 5945397. 14 558926. 21 CB-GYRO-SS 5945397. 46 558926. 25 CB-GYRO-SS 5945398. 52 558926. 31 CB-GYRO-SS 5945399. 77 558926. 53 CB-GYRO-SS 5945399. 83 558926. 98 CB-GYRO-SS 5945396. 77 558928. 03 CB-GYRO-SS 5945391. 18 558928. 52 CB-GYRO-SS 5945378. 48 558927. 20 CB-GYRO-SS 5945361. 00 558923. 84 CB-GYRO-SS 5945351. 26 558922. 34 MWD+IFR-AK-CAZ-SC 5945325. 95 558921. 58 MWD+IFR-AK-CAZ-SC 5945294. 13 558923. 89 MWD+IFR-AK-CAZ-SC 5945256. 26 558929. 84 MWD+IFR-AK-CAZ-SC 5945215. 96 558939. 48 MWD+IFR-AK-CAZ-SC 5945171. 99 558955. 25 MWD+IFR-AK-CAZ-SC 5945125. 62 558978. 39 MWD+IFR-AK-CAZ-SC 5945075. 61 559006. 35 MWD+IFR-AK-CAZ-SC 5945022. 21 559037. 74 MWD+IFR-AK-CAZ-SC 5944967. 49 559071. 39 MWD+IFR-AK-CAZ-SC 5944906. 13 559109. 34 MWD+IFR-AK-CAZ-SC 5944843. 94 559146. 95 MWD+IFR-AK-CAZ-SC 5944778. 12 559186. 42 MWD+IFR-AK-CAZ-SC 5944707. 50 559225. 03 MWD+IFR-AK-CAZ-SC 5944630. 14 559261. 55 MWD+IFR-AK-CAZ-SC 5944547. 07 559298. 44 MWD+IFR-AK-CAZ-SC 5944464. 38 559334. 25 MWD+IFR-AK-CAZ-SC 5944380. 84 559369. 40 MWD+IFR-AK-CAZ-SC 5944297. 27 559405. 88 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ _ __- - Company: ConocoPhillips Alaska Inc. Uxte: 6!13!2007 Time: 14:08:41 Page: Z Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-135, True North Site: KuparuklJPad Vertical (TVD)Reference: 1J-135:122.5 Wdl: 1J-135 Section (VS) Keference: Well (O.OON,O.OOE,180.OOAzi} N'ellpxth: 1J-135 Survey Calculation D~Iethod: Minimum Curvature Db: Oracle Sun°ev - - --- i1D Ind Azim TVD Sys TVD ~/S E/yV b4apN blapE Tool ft deg deg ft ft ft ft ft ft '. 2684.10 75.92 154.75 2018.82 1896.32 -1186.82 509.47 5944214.41 559444.84 MWD+IFR-AK-CAZ-SC i i 2779.50 76.26 154.79 2041.75 1919.25 -1270.59 548.94 5944130.96 559484.96 MWD+IFR-AK-CAZ-SC ~ 2874.33 76.89 155.81 2063.77 1941.27 -1354.39 587.48 5944047.47 559524.15 MWD+IFR-AK-CAZ-SC j 2969.94 75.61 153.53 2086.50 1964.00 -1438.32 627.20 5943963.86 559564.53 MWD+IFR-AK-CAZ-SC 3063.12 75.51 152.63 2109.73 1987.23 -1518.78 668.06 5943883.73 559606.01 MWD+IFR-AK-CAZ-SC 3158.23 75.53 152.86 2133.51 2011.01 -1600.65 710.23 5943802.21 559648.81 MWD+IFR-AK-CAZ-SC ', 3253.33 73.01 152.92 2159.29 2036.79 -1682.12 751.94 5943721.07 559691.16 MWD+IFR-AK-CAZ-SC ', 3349.13 75.81 153.50 2185.04 2062.54 -1764.48 793.52 5943639.04 559733.38 MWD+IFR-AK-CAZ-SC 3430.38 73.89 153.16 2206.27 2083.77 -1834.56 828.72 5943569.24 559769.12 MWD+IFR-AK-CAZ-SC 3476.12 73.42 151.99 2219.14 2096.64 -1873.52 848.94 5943530.45 559789.64 MWD+IFR-AK-CAZ-SC 3571.21 76.13 152.53 2244.11 2121.61 -1954.72 891.64 5943449.59 559832.97 MWD+IFR-AK-CAZ-SC 3665.99 74.72 152.44 2267.96 2145.46 -2036.07 934.01 5943368.58 559875.98 MWD+IFR-AK-CAZ-SC I~ 3760.70 74.65 153.47 2292.98 2170.48 -2117.43 975.55 5943287.56 559918.14 MWD+IFR-AK-CAZ-SC i 3854.86 74.28 154.06 2318.20 2195.70 -2198.80 1015.65 5943206.51 559958.88 MWD+IFR-AK-CAZ-SC i 3950.50 75.24 154.47 2343.34 2220.84 -2281.93 1055.72 5943123.71 559999.59 MWD+IFR-AK-CAZ-SC 4045.69 74.27 154.76 2368.37 2245.87 -2364.90 1095.09 5943041.06 560039.61 MWD+IFR-AK-CAZ-SC 4140.32 74.66 156.13 2393.71 2271.21 -2447.82 1132.98 5942958.44 560078.14 MWD+IFR-AK-CAZ-SC 4235.60 75.86 158.41 2417.96 2295.46 -2532.81 1168.57 5942873.75 560114.39 MWD+IFR-AK-CAZ-SC 4330.90 75.22 158.17 2441.75 2319.25 -2618.54 1202.71 5942788.29 560149.19 MWD+IFR-AK-CAZ-SC ~ 4426.87 74.84 157.06 2466.55 2344.05 -2704.27 1238.01 5942702.85 560185.17 MWD+IFR-AK-CAZ-SC 4522.05 74.90 156.35 2491.39 2368.89 -2788.66 1274.35 5942618.76 560222.16 MWD+IFR-AK-CAZ-SC 4615.70 75.87 155.26 2515.02 2392.52 -2871.31 1311.49 5942536.40 560259.94 MWD+IFR-AK-CAZ-SC 4711.45 74.66 153.98 2539.37 2416.87 -2954.97 1351.18 5942453.06 560300.28 MWD+IFR-AK-CAZ-SC 4807.09 75.88 153.98 2563.69 2441.19 -3038.09 1391.75 5942370.27 560341.50 MWD+IFR-AK-CAZ-SC i 4901.25 76.38 153.38 2586.26 2463.76 -3120.03 1432.28 5942288.66 560382.67 MWD+IFR-AK-CAZ-SC 4996.87 76.11 152.76 2609.00 2486.50 -3202.84 1474.35 5942206.20 560425.37 MWD+IFR-AK-CAZ-SC 5092.56 75.67 153.45 2632.33 2509.83 -3285.60 1516.33 5942123.77 560467.99 MWD+IFR-AK-CAZ-SC 5187.78 74.47 153.42 2656.86 2534.36 -3367.89 1557.47 5942041.81 560509.78 MWD+IFR-AK-CAZ-SC 5282.86 74.22 154.26 2682.52 2560.02 -3450.07 1597.84 5941959.96 560550.78 MWD+IFR-AK-CAZ-SC 5377.84 74.34 155.17 2708.25 2585.75 -3532.73 1636.89 5941877.61 560590.47 MWD+IFR-AK-CAZ-SC li 5472.88 74.78 155.11 2733.55 2611.05 -3615.85 1675.40 5941794.80 560629.63 MWD+IFR-AK-CAZ-SC 5568.00 75.81 155.35 2757.70 2635.20 -3699.39 1713.95 5941711.58 560668.83 MWD+IFR-AK-CAZ-SC ~ 5663.14 76.25 154.98 2780.67 2658.17 -3783.18 1752.72 5941628.10 560708.25 MWD+IFR-AK-CAZ-SC 5762.04 75.53 154.23 2804.78 2682.28 -3869.83 1793.86 5941541.79 560750.06 MWD+IFR-AK-CAZ-SC 5853.10 75.16 154.41 2827.81 2705.31 -3949.22 1832.03 5941462.70 560788.85 MWD+IFR-AK-CAZ-SC 5941.89 74.91 154.95 2850.74 2728.24 -4026.76 1868.72 5941385.46 560826.14 MWD+IFR-AK-CAZ-SC I~ 6045.41 75.36 154.21 2877.30 2754.80 -4117.13 1911.67 5941295.44 560869.79 MWD+IFR-AK-CAZ-SC ~i 6139.32 74.98 154.62 2901.34 2778.84 -4199.01 1950.87 5941213.88 560909.63 MWD+IFR-AK-CAZ-SC 6233.85 74.79 154.91 2925.99 2803.49 -4281.56 1989.78 5941131.64 560949.18 MWD+IFR-AK-CAZ-SC 6328.51 74.61 154.62 2950.96 2828.46 -4364.15 2028.71 5941049.37 560988.75 MWD+IFR-AK-CAZ-SC 6422.91 74.79 155.42 2975.87 2853.37 -4446.69 2067.16 5940967.14 561027.84 MWD+IFR-AK-CAZ-SC 6517.50 75.05 155.07 3000.48 2877.98 -4529.62 2105.40 5940884.51 561066.73 MWD+IFR-AK-CAZ-SC I 6613.03 75.24 155.23 3024.97 2902.47 -4613.41 2144.21 5940801.04 561106.18 MWD+IFR-AK-CAZ-SC ~' 6708.50 75.36 156.01 3049.20 2926.70 -4697.52 2182.32 5940717.24 561144.95 MWD+IFR-AK-CAZ-SC 6802.49 75.56 155.28 3072.80 2950.30 -4780.40 2219.84 5940634.66 561183.12 MWD+IFR-AK-CAZ-SC if 6897.56 74.91 154.43 3097.03 2974.53 -4863.62 2258.90 5940551.76 561222.82 MWD+IFR-AK-CAZ-SC i 6992.34 74.54 153.53 3122.00 2999.50 -4945.79 2299.01 5940469.92 561263.57 MWD+IFR-AK-CAZ-SC 7087.72 74.60 154.99 3147.38 3024.88 -5028.60 2338.94 5940387.43 561304.14 MWD+IFR-AK-CAZ-SC 7182.84 75.94 156.22 3171.56 3049.06 -5112.38 2376.93 5940303.96 561342.78 MWD+IFR-AK-CAZ-SC 7278.62 76.05 156.44 3194.74 3072.24 -5197.50 2414.24 5940219.14 561380.75 MWD+IFR-AK-CAZ-SC 7373.83 76.36 155.99 3217.44 3094.94 -5282.11 2451.53 5940134.84 561418.70 MWD+IFR-AK-CAZ-SC 7468.42 76.51 155.66 3239.63 3117.13 -5365.99 2489.19 5940051.25 561457.01 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report (bmpany: ConocoPhillips Alaska Inc. Date: 6/13/2007 Time: 14:08:41 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE}Reference: Well: 1J-135, True North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-135: 122.5 Nell: 1J-135 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi) ~Vellpath: 1J-135 Survey Calculation Mtethod: Minimum Curvature D6i Oracle ___ Su rvc~~ D4D Incl azim TVD Sys TVD NS ElW MapN IVIapE Tool ~ ft deg deg ft ft ft ft ft ft 7563.85 76.83 155.13 3261.63 3139.13 -5450.42 2527.85 5939967.14 561496.33 MWD+IFR-AK-CAZ-SC 7658.87 78.28 152.78 3282.11 3159.61 -5533.77 2568.59 5939884.12 561537.72 MWD+IFR-AK-CAZ-SC 7753.94 76.58 153.44 3302.80 3180.30 -5616.53 2610.56 5939801.70 561580.33 MWD+IFR-AK-CAZ-SC 7848.52 78.54 154.50 3323.18 3200.68 -5699.51 2651.09 5939719.04 561621.50 MWD+IFR-AK-CAZ-SC 7944.52 80.41 155.00 3340.71 3218.21 -5784.88 2691.34 5939634.00 561662.42 MWD+IFR-AK-CAZ-SC 8039.59 79.41 154.78 3357.37 3234.87 -5869.63 2731.06 5939549.57 561702.79 MWD+IFR-AK-CAZ-SC 8135.58 79.22 155.38 3375.16 3252.66 -5955.17 2770.81 5939464.35 561743.20 MWD+IFR-AK-CAZ-SC 8230.04 81.79 156.36 3390.75 3268.25 -6040.19 2808.89 5939379.64 561781.94 MWD+IFR-AK-CAZ-SC 8324.93 81.35 154.46 3404.66 3282.16 -6125.54 2847.94 5939294.61 561821.66 MWD+IFR-AK-CAZ-SC 8420.20 80.91 153.81 3419.35 3296.85 -6210.24 2889.01 5939210.24 561863.39 MWD+IFR-AK-CAZ-SC i ~i 8515.46 80.72 154.49 3434.55 3312.05 -6294.87 2930.01 5939125.95 561905.04 MWD+IFR-AK-CAZ-SC 8610.32 80.96 158.30 3449.66 3327.16 -6380.67 2967.50 5939040.45 561943.20 MWD+IFR-AK-CAZ-SC 8705.63 80.84 161.67 3464.74 3342.24 -6469.08 2999.71 5938952.30 561976.10 MWD+IFR-AK-CAZ-SC ~ 8800.15 80.59 162.91 3479.99 3357.49 -6557.94 3028.09 5938863.68 562005.17 MWD+IFR-AK-CAZ-SC 8895.48 80.79 163.69 3495.41 3372.91 -6648.04 3055.12 5938773.79 562032.90 MWD+IFR-AK-CAZ-SC 8990.86 80.60 164.92 3510.83 3388.33 -6738.66 3080.58 5938683.39 562059.07 MWD+IFR-AK-CAZ-SC 9086.87 80.53 169.44 3526.58 3404.08 -6830.98 3101.59 5938591.24 562080.80 MWD+IFR-AK-CAZ-SC 9180.01 82.16 172.59 3540.60 3418.10 -6921.92 3115.96 5938500.43 562095.88 MWD+IFR-AK-CAZ-SC 9275.14 84.52 175.13 3551.63 3429.13 -7015.85 3126.06 5938406.59 562106.71 MWD+IFR-AK-CAZ-SC 9369.78 84.70 178.37 3560.53 3438.03 -7109.91 3131.40 5938312.59 562112.79 MWD+IFR-AK-CAZ-SC II 9465.21 84.83 181.19 3569.23 3446.73 -7204.93 3131.77 5938217.58 562113.90 MWD+IFR-AK-CAZ-SC 9560.33 84.08 182.61 3578.43 3455.93 -7299.55 3128.63 5938122.95 562111.50 MWD+IFR-AK-CAZ-SC 9655.28 84.02 181.28 3588.27 3465.77 -7393.93 3125.42 5938028.55 562109.03 MWD+IFR-AK-CAZ-SC ~~ 9750.31 84.27 181.06 3597.96 3475.46 -7488.44 3123.49 5937934.03 562107.84 MWD+IFR-AK-CAZ-SC 9800.49 84.93 181.15 3602.69 3480.19 -7538.39 3122.53 5937884.09 562107.27 MWD+IFR-AK-CAZ-SC ' 9830.53 85.79 181.07 3605.12 3482.62 -7568.33 3121.95 5937854.15 562106.92 MWD+IFR-AK-GAZ-SC 9925.73 88.21 181.27 3610.10 3487.60 -7663.37 3120.01 5937759.10 562105.73 MWD+IFR-AK-CAZ-SC ~~ 10021.43 92.42 181.32 3609.57 3487.07 -7759.02 3117.85 5937663.45 562104.31 MWD+IFR-AK-CAZ-SC 10116.67 91.43 180.74 3606.37 3483.87 -7854.19 3116.14 5937568.28 562103.35 MWD+IFR-AK-CAZ-SC 10211.50 91.98 178.96 3603.55 3481.05 -7948.98 3116.38 5937473.51 562104.34 MWD+IFR-AK-CAZ-SC 10307.24 91.81 177.86 3600.38 3477.88 -8044.63 3119.04 5937377.89 562107.74 MWD+IFR-AK-CAZ-SC ' 10402.09 90.63 176.38 3598.37 3475.87 -8139.33 3123.80 5937283.23 562113.25 MWD+IFR-AK-CAZ-SC 10497.17 89.77 176.94 3598.03 3475.53 -8234.25 3129.34 5937188.37 562119.53 MWD+IFR-AK-CAZ-SC 10592.90 90.61 178.97 3597.72 3475.22 -8329.91 3132.76 5937092.75 562123.69 MWD+IFR-AK-CAZ-SC 10687.88 90.14 180.73 3597.09 3474.59 -8424.88 3133.01 5936997.79 562124.68 MWD+IFR-AK-CAZ-SC ', 10782.05 88.66 178.56 3598.08 3475.58 -8519.04 3133.59 5936903.65 562126.00 MWD+IFR-AK-CAZ-SC ~~ 10877.02 89.98 178.83 3599.21 3476.71 -8613.97 3135.75 5936808.74 562128.91 MWD+IFR-AK-CAZ-SC 10971.83 89.40 179.19 3599.72 3477.22 -8708.77 3137.39 5936713.97 562131.29 MWD+IFR-AK-CAZ-SC 11066.27 89.36 179.17 3600.74 3478.24 -8803.19 3138.74 5936619.57 562133.38 MWD+IFR-AK-CAZ-SC 11161.71 91.19 179.67 3600.28 3477.78 -8898.62 3139.71 5936524.16 562135.09 MWD+IFR-AK-CAZ-SC 11256.07 91.11 179.19 3598.39 3475.89 -8992.96 3140.65 5936429.85 562136.77 MWD+IFR-AK-CAZ-SC 11350.90 92.12 179.81 3595.72 3473.22 -9087.75 3141.48 5936335.08 562138.34 MWD+IFR-AK-CAZ-SC 11446.03 91.87 181.57 3592.41 3469.91 -9182.81 3140.33 5936240.02 562137.93 MWD+IFR-AK-CAZ-SC 11541.35 90.94 183.76 3590.07 3467.57 -9277.99 3135.90 5936144.81 562134.25 MWD+IFR-AK-CAZ-SC 11636.21 89.77 183.14 3589.48 3466.98 -9372.67 3130.19 5936050.10 562129.28 MWD+IFR-AK-CAZ-SC ~~ 11731.59 92.11 182.02 3587.92 3465.42 -9467.93 3125.90 5935954.81 562125.74 MWD+IFR-AK-CAZ-SC 11826.76 92.12 180.05 3584.40 3461.90 -9563.02 3124.18 5935859.73 562124.76 MWD+IFR-AK-CAZ-SC 11921.47 92.54 180.63 3580.55 3458.05 -9657.65 3123.62 5935765.11 562124.94 MWD+IFR-AK-CAZ-SC 12014.25 91.43 179.31 3577.34 3454.84 -9750.37 3123.67 5935672.40 562125.72 MWD+IFR-AK-CAZ-SC I 12112.48 92.04 180.32 3574.37 3451.87 -9848.55 3123.99 5935574.23 562126.80 MWD+IFR-AK-CAZ-SC ' 12207.83 90.26 181.25 3572.45 3449.95 -9943.87 3122.68 5935478.91 562126.24 MWD+IFR-AK-CAZ-SC 12302.91 90.57 182.40 3571.76 3449.26 -10038.90 3119.65 5935383.87 562123.96 MWD+IFR-AK-CAZ-SC 12397.58 90.20 182.49 3571.13 3448.63 -10133.48 3115.61 5935289.27 562120.66 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 6/13!2007 "Time: 14:08:41 Yale: 4 Field:. Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-135, True North Sitr. Kuparuk 1J Pad Vertical (TVD) Reference: 1J-135: 122.5 Nell: 1J-135 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-135 Survey Calculation Dlethod: Minimum Curvature Db: Oracle- Survey M11D Inc! azim TVD Sys TVD N/S EIyV A1apN DIapE 'fool ft deg deg ft ft ft ft ft ft 12493.08 90.39 181.56 3570.64 3448.14 -10228.92 3112.24 5935193.82 562118.03 MWD+IFR-AK-CAZ-SC 12588.11 91.41 182.34 3569.14 3446.64 -10323.88 3109.01 5935098.85 562115.54 MWD+IFR-AK-CAZ-SC 12683.42 91.86 183.66 3566.42 3443.92 -10419.02 3104.02 5935003.68 562111.30 MWD+IFR-AK-CAZ-SC 12778.73 91.31 183.32 3563.79 3441.29 -10514.11 3098.22 5934908.55 562106.25 MWD+IFR-AK-CAZ-SC 12873.57 90.88 182.81 3561.97 3439.47 -10608.80 3093.15 5934813.84 562101.92 MWD+IFR-AK-CAZ-SC 12968.22 90.94 182.95 3560.47 3437.97 -10703.32 3088.39 5934719.29 562097.90 MWD+IFR-AK-CAZ-SC 13063.68 91.00 181.89 3558.85 3436.35 -10798.68 3084.36 5934623.91 562094.62 MWD+IFR-AK-CAZ-SC 13158.64 90.63 178.87 3557.50 3435.00 -10893.61 3083.73 5934528.98 562094.73 MWD+IFR-AK-CAZ-SC ~I 13254.11 91.48 177.72 3555.75 3433.25 -10989.02 3086.57 5934433.61 562098.32 MWD+IFR-AK-CAZ-SC 13349.33 90.94 177.96 3553.74 3431.24 -11084.15 3090.16 5934338.52 562102.65 MWD+IFR-AK-CAZ-SC 13444.50 91.84 179.91 3551.43 3428.93 -11179.27 3091.93 5934243.43 562105.16 MWD+IFR-AK-CAZ-SC ~~ 13537.05 90.20 179.87 3549.78 3427.28 -11271.81 3092.11 5934150.91 562106.06 MWD+IFR-AK-CAZ-SC 13634.24 90.33 178.20 3549.33 3426.83 -11368.98 3093.75 5934053.76 562108.46 MWD+IFR-AK-CAZ-SC 13729.85 90.57 178.81 3548.58 3426.08 -11464.55 3096.24 5933958.22 562111.70 MWD+IFR-AK-CAZ-SC 13824.56 89.34 176.52 3548.65 3426.15 -11559.18 3100.10 5933863.64 562116.30 MWD+IFR-AK-CAZ-SC i 13919.39 89.34 177.62 3549.75 3427.25 -11653.87 3104.95 5933768.99 562121.89 MWD+IFR-AK-CAZ-SC 14014.08 91.32 179.19 3549.20 3426.70 -11748.52 3107.58 5933674.38 562125.26 MWD+IFR-AK-CAZ-SC 14109.42 91.00 180.01 3547.27 3424.77 -11843.83 3108.25 5933579.08 562126.68 MWD+IFR-AK-CAZ-SC 14204.75 91.61 180.43 3545.10 3422.60 -11939.14 3107.88 5933483.78 562127.06 MWD+IFR-AK-CAZ-SC 'i 14299.87 91.25 180.61 3542.72 3420.22 -12034.22 3107.02 5933388.70 562126.94 MWD+IFR-AK-CAZ-SC i~ 14394.11 90.82 180.35 3541.02 3418.52 -12128.45 3106.23 5933294.49 562126.89 MWD+IFR-AK-CAZ-SC I i 14489.09 91.06 180.31 3539.46 3416.96 -12223.41 3105.68 5933199.53 562127.08 MWD+IFR-AK-CAZ-SC ~ 14584.72 91.25 180.23 3537.54 3415.04 -12319.02 3105.23 5933103.93 562127.38 MWD+IFR-AK-CAZ-SC ~, it 14679.68 91.00 179.29 3535.67 3413.17 -12413.96 3105.63 5933009.00 562128.52 MWD+IFR-AK-CAZ-SC j 14774.86 88.90 179.01 3535.76 3413.26 -12509.12 3107.04 5932913.86 562130.68 MWD+IFR-AK-CAZ-SC ~, 14870.18 90.46 180.46 3536.29 3413.79 -12604.44 3107.48 5932818.56 562131.86 MWD+IFR-AK-CAZ-SC i 14965.53 91.41 181.99 3534.73 3412.23 -12699.75 3105.44 5932723.25 562130.57 MWD+IFR-AK-CAZ-SC 15060.71 91.07 182.24 3532.67 3410.17 -12794.84 3101.93 5932628.14 562127.80 MWD+IFR-AK-CAZ-SC 15155.82 89.15 180.45 3532.49 3409.99 -12889.92 3099.70 5932533.06 562126.31 MWD+IFR-AK-CAZ-SC I 15250.99 90.53 181.00 3532.76 3410.26 -12985.08 3098.49 5932437.90 562125.86 MWD+IFR-AK-CAZ-SC 15345.86 89.03 180.77 3533.12 3410.62 -13079.93 3097.03 5932343.05 562125.13 MWD+IFR-AK-CAZ-SC 15441.36 89.21 181.93 3534.59 3412.09 -13175.39 3094.78 5932247.58 562123.63 MWD+IFR-AK-CAZ-SC 15535.53 90.12 182.18 3535.14 3412.64 -13269.50 3091.40 5932153.46 562120.99 MWD+IFR-AK-CAZ-SC I'~ 15631.46 90.98 181.52 3534.22 3411.72 -13365.37 3088.31 5932057.58 562118.64 MWD+IFR-AK-CAZ-SC i 15726.11 90.76 180.76 3532.78 3410.28 -13459.99 3086.42 5931962.95 562117.50 MWD+IFR-AK-CAZ-SC 15821.20 90.26 179.52 3531.93 3409.43 -13555.08 3086.19 5931867.88 562118.01 MWD+IFR-AK-CAZ-SC '~ 15916.24 90.14 178.94 3531.60 3409.10 -13650.11 3087.47 5931772.87 562120.03 MWD+IFR-AK-CAZ-SC 16011.46 90.74 178.24 3530.87 3408.37 -13745.29 3089.81 5931677.71 562123.12 MWD+IFR-AK-CAZ-SC 16106.38 90.45 178.49 3529.88 3407.38 -13840.17 3092.52 5931582.87 562126.57 MWD+IFR-AK-CAZ-SC 16201.51 90.33 179.26 3529.24 3406.74 -13935.28 3094.39 5931487.79 562129.18 MWD+IFR-AK-CAZ-SC 16296.94 90.20 180.05 3528.79 3406.29 -14030.70 3094.96 5931392.38 562130.50 MWD+IFR-AK-CAZ-SC 16390.92 89.40 180.41 3529.12 3406.62 -14124.68 3094.58 5931298.41 562130.86 MWD+IFR-AK-CAZ-SC 16486.01 89.64 180.64 3529.92 3407.42 -14219.76 3093.71 5931203.33 562130.74 MWD+IFR-AK-CAZ-SC 16581.96 89.95 181.38 3530.26 3407.76 -14315.70 3092.02 5931107.40 562129.80 MWD+IFR-AK-CAZ-SC 16677.17 90.92 183.23 3529.54 3407.04 -14410.82 3088.19 5931012.26 562126.71 MWD+IFR-AK-CAZ-SC 16772.20 90.39 184.53 3528.45 3405.95 -14505.63 3081.76 5930917.41 562121.02 MWD+IFR-AK-CAZ-SC II 16867.27 89.71 184.28 3528.37 3405.87 -14600.42 3074.46 5930822.58 562114.46 MWD+IFR-AK-CAZ-SC 16962.44 91.56 183.40 3527.32 3404.82 -14695.36 3068.09 5930727.60 562108.84 MWD+IFR-AK-CAZ-SC 17056.94 91.93 182.42 3524.44 3401.94 -14789.69 3063.29 5930633.24 562104.78 MWD+IFR-AK-CAZ-SC 17152.17 90.76 181.50 3522.20 3399.70 -14884.84 3060.04 5930538.08 562102.27 MWD+IFR-AK-CAZ-SC 17246.73 91.66 181.65 3520.21 3397.71 -14979.34 3057.44 5930443.57 562100.41 MWD+IFR-AK-CAZ-SC ~I 17342.11 92.29 181.03 3516.92 3394.42 -15074.64 3055.21 5930348.27 562098.93 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report _____ Company: ConocoPhillips Alaska Inc . Date: 6!13/2007 Time: 14:08:41 Page: 5 Field: Kuparuk River Unit Co-ordinate(NF,} Reference: WeII: 1 J-135, True North Site: Kuparuk 1J Pad Vertical('PVD) Reference: 1J-135: 122.5 WeII: 1J-135 Section (VS) Reference: Well (O.OON,D OOE,180.OOAzi) Wellpath: 1J-135 __ Survey Cakulatim~ Method: Minimum curvature Db: Oracle Sur~c~' --- __ V[D Inc! Azim TVD Sys TVD N/S Ef1Y :11apN MapE Tool ft deg deg ft ft ft ft ft ft 17436.96 89.76 178.38 3515.22 3392.72 -15169.46 3055.70 5930253.47 562100.16 MWD+IFR-AK-CAZ-SC 17532.07 90.25 179.03 3515.21 3392.71 -15264.54 3057.85 5930158.41 562103.05 MWD+IFR-AK-CAZ-SC 17627.49 91.05 178.72 3514.13 3391.63 -15359.94 3059.72 5930063.04 562105.67 MWD+IFR-AK-CAZ-SC 17706.10 90.94 177.91 3512.77 3390.27 -15438.50 3062.03 5929984.51 562108.59 MWD+IFR-AK-CAZ-SC ~! .17735.00 90.94 177.91 3512.29' 3389.79 -15467.38 3063.09 f` 5929955.64 - 562109.87 PROJECTED to TD ConocoPhillips Time Log Summary WelN7pw N7~b Re/wrting L. - -- ------~------ Well Name: 1 J-135 Job Type: DRILLING ORIGINAL --- - Time Loys ~ Date From To Dur S th E. De th Phase Code Subcode T CO(vi 04/10/2007 10:00 21:00 11.00 0 0 MIRU MOVE DMOB P _ __ ______ __ Move Pits. Move sub off of 1J-160 (close fit between 1J-10 and 1J-159). Move to other side of ad. 21:00 22:30 1.50 0 0 MIRU MOVE PSIT P Spot rig sub over hole and set down. (Close well 1J-136 on the driller's side. 22:30 00:00 1.50 0 0 MIRU MOVE PSIT P Move pit/pump module to align with ri . 04/11/2007 00:00 00:30 0.50 0 0 MIRU MOVE OTHR P Finish jacking cantilever feet down, prepare to skid rig floor to the drilling osition. 00:30 01:30 1.00 0 0 MIRU MOVE PSIT P PJSM, then skid rig floor to the drilling osition. Move and set rockwasher. 01:30 04:00 2.50 0 0 MIRU MOVE OTHR P Spot rockwasher in place. Place herculite and install cuttin s tanks. 04:00 06:00 2.00 0 0 MIRU MOVE RURD P Rig up: Hook up water, steam and air. Bermin u around the ri . 06:00 10:00 4.00 0 0 MIRU MOVE RURD P Continue to berm up around rig. Update well sign information. Connect mud lines, flowlines and choke lines. Install blind flange on kill Iine.Hook up communications line. Preparing pits to accept spud mud. Start mixing spud mud in pits. Note: Rig acceptance walkthrough performed. Rig accepted @ 0900 hrs 4/11 /2007. 10:00 10:30 0.50 0 0 MIRU MOVE OTHR P Pressure test lines with air. 10:30 14:45 4.25 0 0 MIRU WELC NUND P PJSM. Nipple up 21-1/4" diverter assembl . 14:45 18:00 3.25 0 0 MIRU CASIN RURD P Rig up Frank's StabRite. Rig down after obtaining measurements for needed modifications for better clearance between top drive. Right now it is 1-1/4" clearance. 18:00 18:30 0.50 0 0 MIRU CASIN RURD P Rig down Frank's stabrite from the derrick. 18:30 00:00 5.50 0 0 MIRU DRILL PULD P PU/MU stad back in the derrick 5"drill pipe. Rabbit pipe to 2 1/2". Total of 32 stands picked up @ midnight. A total of 48 stands in the derrick @ midni ht. P~~L' 1 A~ ~'~ Time Lomas ____ Date From _To_ Dur S. De th E. De th Ph se Code Subcode T COM ~ 04/12/2007 00:00 04:00 4.00 0 0 MIRU DRILL PULD P Finish PU/MU stand back in the derrick 5"drill pipe. Rabbit pipe to 2 1/2". Total of 52 stands picked up. A total of 68 stands in the derrick. PU/MU 3 stands (including jars) of 5" HWDP. 04:00 05:00 1.00 0 0 MIRU WELCT BOPE P Function test 21-1/4" Diverter system. Witness of test waived by AOGCC inspector Jeff Jones. Knife valve opened in 19 sec. Hydril closed in 44 seconds. Accumulator tested. Gas alarms tested on 4/11!2007. 05:00 05:30 0.50 0 0 MIRU DRILL RURD P Rig up Sperry Sun Gyro and wireline. 05:30 06:00 0.50 0 0 MIRU DRILL PULD P Prepare rig tongs and floor to PU/MU BHA #1. 06:00 07:15 1.25 0 0 SURFA DRILL PULD P PU/MU BHA #1. 07:15 08:00 0.75 0 0 SURFA DRILL CIRC P Fill hole w/ water, check for leaks. Pressure test mud lines to 3500 si. 08:00 08:15 0.25 0 0 SURFA DRILL REAM P Clean out inside of conductor f/ 107' to 121'. Swa to s ud mud. 08:15 09:45 1.50 0 193 SURFA DRILL DDRL P Spud. Drill 16" surface hole. 09:45 10:00 0.25 193 99 SURFA DRILL TRIP P Stand back a stand of 5" HWDP. 10:00 10:30 0.50 99 193 SURFA DRILL PULD P Pickup 2 flex drill collar, MU stand of HWDP w/jars. Install corrosion ring in to of first stand of HWDP. 10:30 12:00 1.50 193 314 SURFA DRILL DDRL P Directional drill 16" surface hole. Using S er Sun G ro's. 12:00 18:00 6.00 314 665 SURFA DRILL DDRL P Directional drill 16" surface hole. Using S er Sun G ro's. 1.8:00 00:00 6.00 665 918 SURFA DRILL DDRL P Directional drill 16" surface hole. Using S er Sun G ro's. 04/13/2007 00:00 06:00 6.00 918 1,297 SURFA DRILL DDRL P Directional drill 16" surface hole. Using Sperry Sun Gyro's to 932' then usin S er Sun MWD. 06:00 12:00 6.00 1,297 1,650 SURFA DRILL DDRL P Directional drill 16" surface hole. 12:00 13:45 1.75 1,650 1,774 SURFA DRILL DDRL P Directional drill 16" surface hole. 13:45 15:30 1.75 1,774 1,774 SURFA DRILL CIRC NP Circulate while backreaming f/ 1774' to 1640' to clean hole. Significant increase in cuttings. Rotate 50 rpm, um in u to 850 m w/ 2900 si. 15:30 18:00 2.50 1,774 1,964 SURFA DRILL DDRL P Directional drill 16" surface hole. 18:00 19:15 1.25 1,964 2,020 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 76 units. 19:15 19:30 0.25 2,020 1,966 SURFA DRILL TRIP NP POOH, set back a stand. 19:30 20:00 0.50 1,966 1,871 SURFA DRILL CIRC NP Circulate to clean hole while backreaming w/ 50 rpm and up to 900 gpm w/ 2950 psi. Lots of clay blinding shakers. ~~ ~ 3'age 2 ~t ~~~ / ` Time Logs _______ _ _ _ Da e From To Dur S De th E Depth Phase Code Subcode T COM 04/13/2007 20:00 20:15 0.25 1,871 1,765 SURFA DRILL TRIP NP Stand back a stand. 20:15 20:30 0.25 1,765 1,765 SURFA DRILL OTHR NP Preparing pitslshakers to circ clay to rockwasher. Chan a shaker screens. 20:30 21:15 0.75 1,765 1,765 SURFA DRILL CIRC NP Circulate to clean hole while backreaming w/ 50 rpm and 500 gpm up to 800 gpm w/ 2300 psi. Clay not as bad as earlier. Circ a total of 2+ BU countin the earlier circulation. 21:15 21:30 0.25 1,765 2,020 SURFA DRILL TRIP NP RIH to drill ahead. 21:30 00:00 2.50 2,020 2,105 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 76 units 04/14/2007 00:00 00:45 0.75 2,105 2,154 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 76 units. 00:45 06:00 5.25 2,154 2,154 SURFA DRILL REAM NP Trying to ream out a 9.3 deg dogleg. Circ up to 900 gpm w/ 2880 psi. 57% flow. Rotate 50 rpm w/ 3-5k ft Ib torque. Rotating weight 120k. Final do le 8.8 de . 06:00 12:00 6.00 2,154 2,535 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 86 units. 12:00 18:00 6.00 2,535 2,987 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 126 units 18:00 00:00 6.00 2,987 3,408 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 51 units. 04/15/2007 00:00 01:00 1.00 3,408 3,478 SURFA DRILL DDRL P Directional drill 16" surface hole. Max as 51 units. 01:00 02:00 1.00 3,478 3,200 SURFA DRILL CIRC P Circulate bottoms up while backreaming pulling 3-5'/min. Rotate 60 r m w/ 7k ft Ib for ue. 02:00 03:30 1.50 3,200 2,537 SURFA DRILL REAM P Backream out of the hole pulling 40-45'/min. Rotate 60 rpm w/ 7k ft Ib for ue. 03:30- 04:15 0.75 2,537 2,347 SURFA DRILL REAM P Continue backreaming out .Rotate 60 rpm w/ 7k ft Ib torque. Slow to 6'/min for 2 stands to circ a bottoms u . 04:15 04:45 0.50 2,347 2,156 SURFA DRILL REAM P Continue backreaming out. Rotate 60 rpm w/ 6k ft Ib torque. Pull @ 40-45'/min. 04:45 05:15 0.50 2,156 1,776 SURFA DRILL REAM P Continue backreaming out. Rotate 60 rpm w/ 6k ft Ib torque. Pull @ 40-45'/min. 05:15 05:30 0.25 1,776 1,681 SURFA DRILL REAM P Continue backreaming out. Rotate 60 rpm w/ 6k ft Ib torque. Pull @ 40-45'/min. 05:30 06:00 0.50 1,681 1,491 SURFA DRILL TRIP P Pull 2 stands without pumps. OK. 06:00 06:30 0.50 1,491 1,200 SURFA DRILL REAM P Continue backreaming out. Rotate 60 rpm w/ 6k ft Ib torque. Slow to 10'/min for 3 stands to circ a bottoms u +. 06:30 06:45 0.25 1,200 1,200 SURFA DRILL OWFF P Monitor well. Static. 06:45 07:30 0.75 1,200 444 SURFA DRILL TRIP P POOH on elevators using trip tank for hole fill. 07:30 08:00 0.50 444 161 SURFA DRILL TRIP P Stand back 3 stands of HWDP. Pag€~ 3 of ~1 Time Logs __ Date From To _ Dur __ 5_ _De~th_ E_D~th Phase Code Subcode T_ COM 04!15/2007 08:00 08:15 0.25 161 67 SURFA DRILL TRIP P Stand back 8" flex collars. 08:15 08:45 0.50 67 67 SURFA DRILL OTHR P Download MWD. 08:45 10:00 1.25 67 0 SURFA DRILL PULD P Lay down BHA #1: Remvoe clay f! stabilizers, mtr and bit. Drain mtr, break off bit. UD Pulsar, HCIM, stab and mtr. 10:00 10:30 0.50 0 0 SURFA DRILL OTHR P Clear and clean rig floor. 10:30 12:00 1.50 0 0 SURFA CASIN RURD P RU to run 13-3/8" surface casing. 12:00 12:30 0.50 0 0 SURFA CASINC SFTY P Stabbing board inspection. 12:30 13:00 0.50 0 0 SURFA RIGMN SVRG P Lubricate Rig. 13:00 13:15 0.25 0 0 SURFA CASINC SFTY P PJSM on running 13-3/8" casing. 13:15 15:30 2.25 0 1,635 SURFA CASIN RNCS P Run 13-3/8" 68 ppf L-80 BTC casing per running order. Checked floats, RIH, Worked through bridge @ 811'. Obtain PU and SO wt's every 10 jts. Fill w/ Frank's fillu tool eve 'oint. 15:30 16:45 1.25 1,635 1,680 SURFA CASIN CIRC P Circ 2+ BU (275 bbls) on jt # 40. Start @ 4 bpm w/ 200 psi, stage to 7 bpm w/ 320 si, 31 % . 16:45 18:00 1.25 1,680 2,660 SURFA CASINC RNCS P Run 13-3/8" 68 ppf L-80 BTC casing per running order. Obtain PU and SO wt's every 10 jts. Fill w/ Frank's fillup tool every joint. Circ joint # 60 down, no roblems. 18:00 18:45 0.75 2,660 2,993 SURFA CASINC RNCS P Run 13-3/8" 68 ppf L-80 BTC casing per running order. Obtain PU and SO wt's every 10 jts. Fill w/ Frank's fillup tool every joint. Circ joint # 73 down, no problems while installing 2 turbolizers on the jt #73 in the middle of the 'oint. 18:45 19:30 0.75 2,993 3,410 SURFA CASIN RNCS P Run 13-3/8" 68 ppf L-80 BTC casing per running order. Obtain PU and SO wt's every 10 jts. Fill w/ Frank's fillup tool every joint. Install a bowspring centralizer on the collar of jt # 81 and #82. Circ joint # 83 down, no roblems. Down wt 155k 19:30 20:00 0.50 3,410 3,463 SURFA CASIN RNCS P PU Vetco Gray hanger w/ the short landing joint. MU and remove the short landing joint. PU/MU Long landing joint. RIH and land on the load shoulder 43.64'. 20:00 20:30 0.50 3,463 3,463 SURFA CASIN RURD P Remove Frank's fillup tool. Blow down to drive. 20:30 21:00 0.50 3,463 3,463 SURFA CEME~ RURD P Rig up Dowell's cement head. Hook up 2" circulation hose. -_""." ~ Pasae 4 of ~1 i l ~rJ Time Logs ____ Datz From _ _ To Dur S. De th E. Depth Phase Code Subcod_e__ T COM ___ 04/15/2007 21:00 23:30 2.50 3,463 3,463 SURFA CEME~ CIRC P Circulate prior to cementing. Recip pipe 28-32' stroke @ 6'/min stroke speed. PU wt 265-270k, SO wt 150k. Held pre job safety meeting prior to cement job while circulating. Circulated a total of 915 bbls prior to cementing (BU x 3.5) Mud properties going in the casing prior to cementing were 9.6 ppg, vis 51, PV/YP = 18/16, gels 3, 10 min gels 4. Returns from the well: 9.7 ppg, vis 62, PV/YP 23/19, gels 5, 10 min els 7. 23:30 00:00 0.50 3,463 3,463 SURFA CEME OTHR P Dowell pump 10 bbls CW 100 @ 2.5 bpm w/ 64 psi, pressure test lines to 2500 psi, continue to pump a total of 50.1 bbls of CW 100 @ 6 bpm w/ 233 psi, mix and start pumping 10.5 ppg Mud Push II w/ red dye @ 4 bpm w/ 200 si. 04/16/2007 00:00 02:15 2.25 3,463 3,463 SURFA CEME~ OTHR P Dowell continue pumping 10.5 ppg Mud Push II w! red dye @ 4 bpm w/ 200 psi.(41.9 bbls), drop bottom plug, Mix and pump 650 sx AS1 (530.3 bbls) (yield 4.57 cu ft /sx)(10.7 ppg) , Quit recip casing w/ 12 bbls cement around the shoe. Mix and pump DeepCRETE tail 220 sx (99.4 bbls) (yield 2.49 cu ft/sx) (12.0 ppg) ,drop top plug, follow w/ 20 bbls water throu h the tub. 02:15 03:45 1.50 3,463 3,463 SURFA CEME~ DISP P Rig displace cement w/ 9.6 ppg mud @ 8 bpm w/ 360-770 psi till last 10 bbls (475 bbls mud pumped), slow down to 3 bpm w/ 530 psi. Bump plug w/ 1050 psi (Bumped @ 4872 strokes) hold 5 min. Bleed presssure and check floats. OK. CIP 0334hrs 4/16/2007. 196.5 bbls of really good 10.7 ppg cement returns in the cellar, took 310 bbls to vac trucks. 03:45 04:30 0.75 0 0 SURFA CEME~ RURD P Blow down cement line. Rig down Dowell cement head. 04:30 05:15 0.75 0 0 SURFA CASIN RURD P Back out landing joint, lay down same to i e shed. 05:15 05:30 0.25 0 0 SURFA WELCT SFTY P Pre job safety meeting on nippling down Diverter assembl . 05:30 06:00 0.50 0 0 SURFA WELC OTHR P Clean drip pan. Unload 8 joints of 13-3/8" casing from pipe shed. Flush flowline and work annular to clean out cement. 06:00 10:00 4.00 0 0 SURFA WELCT NUND P Nipple down diverter assembly. 10:00 11:00 1.00 0 0 SURFA WELCT NUND P NU Vetco Gray MB22 A wellhead. Test flange to 250 psi f/ 5 min and 5000 si f/ 10 min. Good test. Fage 5 of ~9 • Time Logs Date From To Dur 5 D~th E. Depth Phase Code Subcode T_ COM ___ - 04/16/2007 11:00 22:45 11.75 0 0 SURFA WELCT NUND , P Nipple up 13-5/8" BOPE. Install riser. Tighten all connections. Rig up flowline, install choke line. Orient flow nipple to flowline and connect same. Install turnbuckles and center BOP stack w/rotary table. Install floor drains to drip pan. Change out saver sub on top drive. UD 20" Riser from the floor. Change bales to drilling bales. UD casin runnin bales. 22:45 23:30 0.75 0 0 SURFA WELCT OTHR P Rig up to test 13-5/8" BOPE. 23:30 00:00 0.50 0 0 SURFA WELCT OTHR P Install 12-3/4" OD lower Vetco/Gray test plug w/ 5" test joint. Fill stack and choke manifold with water. Re tighten Oteco connection on choke line. Tighten flange @ stack and choke line. Monitor well via lower annulus. Witness of test waived by AOGCC ins ector Bob Noble. 04/17/2007 00:00 04:15 4.25 0 0 SURFA WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector Bob Noble. Test 300 psi low and 3000 psi high. Hold each test 5 min. Chart test. Test both HCR and manual valves on kill and choke line, floor safety valve and IBOP. Test top drive manual and IBOP valve. Test lower pipe rams w! 9-5/8" test joint. Test annular and upper variable (3-1 /2" x6") rams w/ 5". Test accumulator. 04:15 04:45 0.50 0 0 SURFA WELC OTHR P Rig down test equipment. Blow down choke, kill line and choke line, drain stack. 04:45 05:15 0.50 0 0 SURFA WELC OTHR P UD test plug, install long Vetco gray wear bushing (13-3/8" OD, 12-5116" ID, 59-1/2" long), run in lockdown screws. 05:15 06:45 1.50 0 0 SURFA DRILL PULD P Rig up to PU/MU and stand back in the derrick, 8 stands of 5"drill pipe f/ the i e shed. Drift to 2-1/2". 06:45 07:00 0.25 0 0 SURFA DRILL SFTY P Pre job safety meeting on picking up 12-1/4" BHA. 07:00 09:00 2.00 0 82 SURFA DRILL PULD P PU/MU BHA #2. 09:00 09:30 0.50 82 82 SURFA DRILL OTHR P Upload Sperry Sun MWD. 09:30 10:00 0.50 82 458 SURFA DRILL TRIP P MU/RIH w/ a stand of 7-5/8" flex collars and 3 stands (w/jars) of 5" HWDP. 10:00 12:00 2.00 458 1,796 SURFA DRILL PULD P Continue picking up and run in the hole w/ 5"drill pipe from the pipe shed. Rabbit to 2-1/2". PU/MU 12-1 /4" host reamer on to of stand #14. P~s~e 6 of 41 l _~ Time Logs _ _ _ Date From 70 Dur S De th E. De th Phase Code Subcode T COM 04/17/2007 12:00 _ 13:15 1.25 _ 1,796 2,177 SURFA DRILL _ PULD __ P Continue picking up and run in the hole w/ 5"drill pipe from the pipe shed. Rabbit to 2-1/2". (18 stands in the hole 13:15 13:45 0.50 2,177 2,177 SURFA DRILL CIRC P Fill pipe. Circulate Rotate 30 rpm w/ 6-71k ft Ib for ue. 13:45 14:45 1.00 2,177 3,319 SURFA DRILL PULD P Blow down top drive. Continue picking up and run in the hole w/ 5" drill pipe from the pipe shed. Rabbit to 2-1/2". 30 stands in the hole 14:45 15:15 0.50 3,319 3,374 SURFA DRILL CIRC P 5' in to tag cement @ 3374'. Circ 250 gpm, rotate 30 rpm w/ 120k rotating wt. 15:15 16:00 0.75 3,374 3,319 SURFA DRILL CIRC P Circulate bottom's up @ 3367'. Rotate 30 rpm w/ 7-9k ft Ib torque. Rot wt 120k. Set back a stand. 16:00 16:15 0.25 3,319 3,319 SURFA DRILL SFTY P PJSM on rigging up to test 13-3/8" casin . 16:15 16:30 0.25 3,319 3,319 SURFA CASIN( DHEQ P Rig up, circ through kill line. Rig up chart recorder. 16:30 18:00 1.50 3,319 3,319 SURFA CASINC DHEQ P Close top set of pipe rams (3-1/2" x6"). Test casing to 3050 psi for 30 min. Lost 25 psi. Good test.Bleed back 4 bbls to the trip tank. Open rams, bleed off pressure. Rig down e ui ment. 18:00 21:30 3.50 3,319 3,478 SURFA CEME COCF P MU top drive connection, tag up on cement @ 3374'. Drill cement, wiper lu s, FC, cement, FS, and rat hole. 21:30 21:45 0.25 3,478 3,498 SURFA DRILL DDRL P Drill 20' of new hole f/ 3478' to 3498'. 21:45 22:15 0.50 3,498 3,493 SURFA DRILL CIRC P Circulate bottoms up. Reciprocate pipe staying up inside of casing mostly. Rotate 60 rpm w/ 6-10k ft Ib for ue. 22:15 23:30 1.25 3,493 3,493 SURFA DRILL CIRC P Displace well to 9.0 ppg new LSND mud. Displace @ 500 gpm w/ 580 psi. Rotate 60 r m w/ 6-10k ft Ib for ue. 23:30 23:45 0.25 3,493 3,493 SURFA DRILL CIRC P Perform PWD baseline test. 700 gpm w/ 100 rpm and 50 rpm. 800 gpm w/ 100 rpm and 50 rpm. Clean hole 9.4 23:45 00:00 0.25 3,493 3,413 SURFA DRILL TRIP P Stand back a stand. Blow down top drive. Pre are to erform LOT. 04/18/2007 00:00 00:15 0.25 3,413 3,413 SURFA DRILL OTHR P RU to perform LOT. 00:15 00:45 0.50 3,413 3,413 SURFA DRILL LOT P Perform LOT w/ 9.0 ppg mud. Casing shoe @ 3462' (2213' TVD). Hole depth 3493' (2224' TVD) (20' new hole). Applied pressure 451 psi= EMW 12.9 ppg. Pump down drill string and annulus, use upper pipe rams (3-1/2" x 6"). Bleed off pressure and 1 bbl of mud to tri tank. 00:45 01:15 0.50 3,413 3,413 SURFA DRILL OTHR P Blow down kilt line. Rig down e ui ment for testin formation. F~~g~ 7 of ~1 :.Time Logs Date From To __ Dur 5 Depth E_De th Phase Code Subcode T COM 04/18/2007 01:15 01:30 0.25 3,413 3,413 INTRM1 RIGMN' SFTY P PJSM for slip and cut drilling line. 01:30 02:45 1.25 3,413 3,413 INTRM1 RIGMN' SVRG P Slip and cut 92' of 1-3/8" drilling line. Ins ect and ad'ust brakes. 02:45 03:30 0.75 3,413 3,413 INTRM1 RIGMN SVRG P Service top drive and traveling e ui ment. 03:30 04:45 1.25 3,413 3,450 INTRMI WELC WOEL T Make top drive connection. Prepare to directional drill intermediate hole. Trouble shoot GeoPilot skid and MWD detection. Thaw out GeoPilot skid. 04:45 06:00 1.25 3,493 3,600 INTRM1 DRILL DDRL P Directional drill intermediate hole. 06:00 12:00 6.00 3,600 4,360 INTRM1 DRILL DDRL P Directional drill intermediate hole. 12:00 18:00 6.00 4,360 5,110 INTRM1 DRILL DDRL P Directional drill intermediate hole. 18:00 00:00 6.00 5,110 5,882 INTRM1 DRILL DDRL P Directional drill intermediate hole. 04/19/2007 00:00 06:00 6.00 5,882 6,706 INTRMI DRILL DDRL P Directional drill intermediate hole. Pumped a 30 bbls hi vis sweep (250-300 vis) while drilling @ 6358'-6452'.. Significant increase in cuttin s. 06:00 12:00 6.00 6,706 7,288 INTRM1 DRILL DDRL P Directional drill intermediate hole. Pump a 40 bbl hi vis sweep (250-300 vis) while drilling @ 6737' to 6835'. si nificant increase in cuttin s. 12:00 18:00 6.00 7,288 7,935 INTRMI DRILL DDRL P Directional drill intermediate hole. Pump a 40 bbl hi vis sweep (250-300 vis) while drilling @ 7212' to 7308'. si nificant increase in cuttin s. 18:00 00:00 6.00 7,935 8,640 INTRM1 DRILL DDRL P Directional drill intermediate hole. Pump a 40 bbl hi vis (250-300 vis) weighted (10.8 ppg) sweep while drilling @ 8069" to 8164'. no increase in cuttin s. 04/20/2007 00:00 06:00 6.00 8,640 9,019 INTRM1 DRILL DDRL P Directional drill intermediate hole. Ghost reamer appeared to be taking torque while drilling @ 8871' to 8898' (27'). Ghost reamer back 1790' f/ bit @ 7081'-7108'. Time was 0145hrs to 0445 hrs, total of 3 hrs f/ 27'. 06:00 12:00 6.00 9,019 9,495 INTRM1 DRILL DDRL P Directional drill intermediate hole. 12:00 14:30 2.50 9,495 9,779 INTRM1 DRILL DDRL P Directional drill intermediate hole. 14:30 16:00 1.50 9,779 9,779 INTRM1 RIGMN RGRP T Repair #2 mud pump. Change out API ring gasket on discharge manifold/ dischar a strainer. 16:00 16:30 0.50 9,779 9,832 INTRMI DRILL DDRL P Directional drill intermediate hole. 16:30 18:00 1.50 9,832 9,688 INTRM1 DRILL CIRC P Pump a 40 bbl weighted (11.1ppg) high vis sweep (280vis). Backream out slow (3'/min) until sweep is out of the hole. Page 8 of 41 Time Logs - -- -_---- -- ------- 1 Date From To Dur S Depth E. De th Phase Code Subcod_e___ T_ COM______ 04/20/2007 18:00 00:00 6.00 9,688 6,170 INTRM1 DRILL REAM P Backream out of the hole (35-40'/min). Record PU and SO wt's every 5 stands. 04/21/2007 00:00 02:30 2.50 6,170 5,215 INTRM1 DRILL REAM P Backream out of the hole (35-40'/min). Record PU and SO wt's every 5 stands. 02:30 04:00 1.50 5,215 5,025 INTRM1 DRILL REAM P Backream out of the hole (3'/min). Record PU and SO wt's every 5 stands. 04:00 04:15 0.25 5,025 4,835 INTRM1 DRILL TRIP P POOH on elevators. Pulling 30k over and swabbin . 04:15 06:00 1.75 4,835 3,700 INTRM1 DRILL REAM P Backream out of the hole (50-60"/min). Record PU and SO wt's every 5 stands. 06:00 06:30 0.50 3,700 3,410 INTRM1 DRILL REAM P Backream out of the hole (50-60"/min). Record PU and SO wt's every 5 stands. 06:30 07:45 1.25 3,410 3,410 INTRM1 DRILL CIRC P Pump a 35 bbls sweep surface to surface. Then follow w/4 BU_ Bring casin a ui ment to the ri floor. 07:45 08:00 025 3,410 3,410 INTRM1 DRILL OWFF P Monitor well 08:00 08:30 0.50 3,410 3,410 INTRM1 DRILL CIRC P Pump a dry job, blow down top drive. Install stri er rubber and air sli s. 08:30 10:00 1.50 3,410 458 INTRM1 DRILL TRIP P POOH to 1800', remove ghost reamer (1/8" under guage)., Continue POOH to the BHA. Hole dis alcement ood. 10:00 12:00 2.00 458 80 INTRM1 DRILL PULD P UD BHA #2: UDjars and (2) singles HWDP, rack back 2 stands of HWDP, UD flex drill collars. 12:00 13:00 1.00 80 80 INTRM1 DRILL OTHR P Download Sperry Sun MWD. 13:00 14:00 1.00 80 0 INTRMI DRILL PULD P Continue to UD BHA #2. 14:00 14:30 0.50 0 0 INTRM1 DRILL OTHR P Pull Vetco/Gray wear bushing. 14:30 14:45 0.25 0 0 INTRM1 CASINC SFTY P PJSM on rigging up to run 9-5/8" 40ppf L-80 BTC-m casin . 14:45 16:30 1.75 0 0 INTRM1 CASINC RURD P Rig up to run 9-5/8" intermediate casing. MU Frank's fillup tool and GBR casin runnin tools. 16:30 16:45 0.25 0 0 INTRM1 CASINC SFTY P PJSM for running 9-5/8" casing. 16:45 17:30 0.75 0 148 INTRM1 CASINC RNCS P Run 4 joints of 9-5/8" 40 ppf L-80 BTC-mod casin . 17:30 18:00 0.50 148 148 INTRM1 CASINC CIRC P Fill shoe joints and circ through float equipment. Pump 30 bbls @ 6bpm w/ 280 si. 29% flow. 18:00 21:30 3.50 148 3,420 INTRM1 CASINC RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's every 10 jts. 90 jts in the hole. t.~...____ ~ _____ ~a€de 9 ~f 4~3 • i Time Logs Date From To Dur_ _ S;Depth__E. Depth Phase Code Subcode T COPvt _ 04/21/2007 21:30 22:45 1.25 3,420 3,420 INTRM1 CASIN( CIRC P Circulate surface to surface. Stage pumps up every 50 bbls f/ 4 bpm to 8 bpm. After 250 bbls pumped continue to pump 8 bpm. Pump last 100 bbls @ 9 bpm. PU wt 178k, SO wt 130k before and after circulating. 4 bpm, 190 psi, 26% flow 5 bpm, 230 psi, 30% flow 6 bpm, 280 psi, 31% flow 7 bpm, 360 psi, 31% flow 8 bpm, 340 psi, 31% flow 9 b m, 580 si, 32% flow 22:45 00:00 1.25 3,420 4,180 INTRM1 CASIN RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's eve 10 'ts. 04/22/2007 00:00 02:15 2.25 4,180 6,660 INTRM1 CASIN RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's eve 10 'ts. 02:15 03:30 1.25 6,660 6,660 INTRM1 CASIN CIRC P Circulate while recip 40' f/ 6660' to 6620'. Circulate 400 bbls. 03:30 04:45 1.25 6,660 7,685 INTRM1 CASIN RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's eve 10 'ts. 04:45 05:30 0.75 7,685 7,720 INTRM1 CASIN RNCS P Circulate while running 2 jts (#202 & # 203 Circulate a total of 162 bbls. 05:30 06:00 0.50 7,720 8,200 INTRM1 CASIN( RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's eve 10 'ts. 06:00 08:00 2.00 8,200 9,826 INTRM1 CASIN RNCS P Run 9-5/8" casing per detail. Record PU and SO wt's every 10 jts. PU wt 310k, SO wt 120k. 08:00 09:15 1.25 9,826 9,826 INTRM1 CEME~ CIRC P Circulate w/ Frank's fillup tool, reciprocate pipe 40' (9826' to 9786'). Circ and conditiion mud and hole @ 4 bpm w/ 220 psi. Stage up to 5 bpm w/ 350 psi. No losses. Circulate a total of 361 bbls. Ri down casin ton s. 09:15 09:30 0.25 9,826 9,836 INTRMI CASIN( RURD P Rig down Frank's fillup tool, blow down to drive. 09:30 10:00 0.50 9,826 9,826 INTRM1 CEMEf` RURD P Rig up dowell's cementing head. 10:00 12:00 2.00 9,826 9,826 INTRM1 CEME~ CIRC P Continue to circulate and condition mud/ hole prior to cementing 9-5/8" casing. Recip pipe 40' (9826' to 9786')Start pumping 4 bpm w/ 220 psi and 28% flow, stage up to 5 bpm w/ 270 psi and 30% flow, then 6 bpm w/ 290 psi and 31 % flow. After circulating and conditioning: PU wt 280k, SO wt 125k. Circulated a total of 980 bbls prior to the cement job (includes the 361 bbls w/Frank's tool. Held two pre job safety meeting w/ circ (Dowell f/ cementing and APC f/fluid swap/haul 0 _ _ _..~..-....._.. _ ~'~ge 14 of 41~ tL J Time Logs ____ _ _ _ __ Date From To Dur S De th E. De th Phase Code Subcode T COM 04/22/2007 12:00 14:30 2.50 9,826 9,819 INTRM1 CEME OTHR _ P Cement 9-5/8" casing w/ Dowell:. Dowell pump 10 bbls CW100 @ 4.8 bpm w/ 180 psi, test lines to 3000 psi, follow w/ 40 more bbls CW100 @ 5.6 bpm w/ 230 psi ,pump 11 ppg Mud Push II @ 5.0 bpm w/ 200 psi.(71 bbls), drop bottom plug, Mix and pump 720 sx DeepCRETE (289.5 bbls) (yield 2.25 cu ft /sx)(12.5 ppg) ,Quit recip casing w/ 82 bbls cement around the shoe, drop top plug, follow w/ 10 bbls water throu h the tub. 14:30 16:15 1.75 9,819 9,819 INTRM1 CEME~ DISP P Rig pumps displaced cement w/ 8.5 ppg MOBM @ 7 bpm w/ 250-500 psi for the first 300 bbls, then slowed from 6.8 bpm w! 500 psi, then down to 6 bpm w/ up to 1500 psi @ 700 bbls pumped. Slowed down after 700 bbls displaced with the rig pump to 3 bpm/1400 psi and bumped the plug with 2000 psi on calculated strokes. Held pressure f/ 5 min. Bleed off pressure, floats held. CIP @ 1530 hrs on 4-22-2007. Note: Reciprocated pipe 40' until 82 bbls of cement around the shoe and could not go down. Shoe is @ 9819' (5' above planned}. Final PU wt 280k, SO wt 125. 16:15 16:30 0.25 9,819 9,819 INTRM1 WELC SFTY P PJSM on picking up BOP stack to set emer enc sli s tanned . 16:30 17:30 1.00 9,819 9,819 INTRM1 WELCT NUND P Break Vetco gray multibowl 222A, PU BOP stack. 17:30 18:45 1.25 9,819 9,819 INTRMI CASIN( OTHR P Pull tension on casing string to 170K on wt indicator (100k tension on 9-5/8" casing). Rig down Dowell cement head. Use rig vac system to evacuate MOBM from inside of the last joint of casin #258 . Set emer enc sli s. 18:45 19:00 0.25 9,819 9,819 INTRM1 WELC OTHR P RU to cut 9-5/8" casing w/ WACHS S lit Frame Machine. 19:00 19:30 0.50 9,819 9,819 INTRMI CASIN OTHR P Cut 9-5/8" casing UD jt # 258 plus the cutoff on # 257. 19:30 20:45 1.25 0 0 INTRM1 WELC OTHR P Install packoff. Set back back down. Tighten Vetco Gray M6222A wellhead. UD casin tools f/ ri floor. 20:45 21:45 1.00 0 0 INTRM1 WELCT OTHR P Test Vetco Gray packoff. Testing seals on 9-5/8" casing and flange break to 300 psi and 2475 psi f/ 5 min. OK. 21:45 22:30 0.75 0 0 INTRM1 WELCT OTHR P RU to test upper pipe rams with a 5-1/2" test jt .Hook up hole fill and flowline. 22:30 23:00 0.50 0 0 INTRM1 WELC BOPE P Test upper pipe rams to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Chart test. Pale 11 af4i C~ Time Logs ___ Date__ From To _ _Dur S. De th E. Depth Phase ___ Code Subcode T_COM __ ~__ 04/22/2007 23:00 23:30 0.50 0 0 INTRM1 WELC OTHR P UD testing equipment. Set short (38") wear bushin 9' ID . RILDS. 23:30 23:45 0.25 0 0 INTRMI DRILL OTHR P RU for injectivity test on 13-3/8" x 9-5/8". 23:45 00:00 0.25 0 0 INTRM1 DRILL LOT P Performing injectivity test. 04/23/2007 00:00 00:45 0.75 0 0 INTRM1 DRILL LOT P Performing injectivity test on 13-3/8" x 9-5/8" casin . 00:45 02:30 .1.75 0 0 INTRMI DRILL OTHR P Flush 13-3/8" x 9-5/8" annulus 110% volume (230 bbls total water) @ 2 bpm. Initial circulating pressure 600 psi, final circulating pressure 590 psi. After 10 minutes the static pressure was 375 psi. Finished 0245 hrs. 02:30 03:30 1.00 0 63 INTRM1 DRILL PULD P PU/MU BHA #3. 03:30 04:15 .0.75 63 63 INTRM1 DRILL OTHR P Upload Sperry Sun MWD. 04:15 05:00 0.75 63 260 INTRMI DRILL PULD P Continue to PU/MU BHA #3. Shallow pulse test MWD. Break in seals on S er Sun GeoPilot. 05:00 06:00 1.00 260 875 INTRMI DRILL PULD P Blow down top drive. PU/MU/RIH w/ 17 jts of 5" drill pipe on top of BHA #3. Drift i e w/ 2-1/2" rabbit. 06:00 07:15 1.25 875 2,252 INTRMI DRILL PULD P Continue to PU/MU/RIH 5"drill pipe on top of BHA #3. Drift pipe w/ 2-1/2" rabbit. 07:15 07:45 0.50 2,252 2,252 INTRM1 DRILL CIRC P Fill pipe. Break in GeoPilot and test MWD. Rot wt 115k. 07:45 09:30 1.75 2,252 4,154 INTRM1 DRILL PULD P Continue to PU/MU/RIH 5"drill pipe on top of BHA #3. Drift pipe w/ 2-1/2" rabbit. 09:30 10:00 0.50 4,154 4,154 INTRM1 DRILL CIRC P Fill pipe. Break in GeoPilot and test MWD. Rot wt 120k. rotate 20 rpm w/ 3-4k ft Ib for ue. Blow down to drive. 10:00 12:00 2.00 4,154 6,056 INTRM1 DRILL PULD P Continue to PU/MU/RIH 5" drill pipe on top of BHA #3. Drift pipe w/ 2-1/2" rabbit. 12:00 12:30 0.50 6,056 6,056 INTRMI DRILL CIRC P Fill pipe. Break in GeoPilot and test MWD. Rot wt 120k. rotate 20 rpm w! 3-4k ft Ib for ue. Blow down to drive. 12:30 13:45 1.25 6,056 7,953 INTRMI DRILL PULD P Continue to PU/MU/RIH 5"drill pipe on top of BHA #3. Drift pipe w/ 2-1/2" rabbit. 13:45 14:00 0.25 7,953 7,953 INTRM1 DRILL CIRC P Fill pipe. Break in GeoPilot and test MWD. 14:00 15:00 1.00 7,953 9,670 INTRM1 DRILL TRIP P Trip in the hole from the derrick. Tag wiper plugs on the float collar @ 9745'. Pumping 4 bpm w/ 480 psi, set 10k wt on plugs. PU 190k, So 110, Rot wt 140k. Rack back a stand. Fill i e. 15:00 15:15 0.25 9,670 9,670 INTRM1 RIGMN SFTY P PJSM on slip and cut drilling line. 15:15 16:30 1.25 9,670 9,670 INTRMI RIGMN SVRG P Slip and cut 86' of 1-3/8"drilling line. Inspect draw works. Circulating @ 25 s m w/ 340 si. ~ ~ f~age I~ cif ~9 Time_Logs _ Date From To Dur 5. De th E. De th Phase Code Subcode TCOM 04/23/2007 16:30 18:00 1.50 9,670 9,670 INTRM1 RIGMN' SVRG P _ ___ __ _ ___ Service rig. Change oil filters on top drive. Change scraper pad on driller's side brake band. Inspect draw works chains. Grease wash pipe. Continue to circ @ 25 spm wl 340 psi for total of 7497 strokes. 18:00 19:00 1.00 9,670 9,670 INTRM1 RIGMN SVRG P Blow down top drive. Install covers on drawworks. 19:00 20:00 1.00 9,670 9,670 INTRM1 CASIN( OTHR P Rig up to test 9-5/8" casing. 20:00 21:00 1.00 9,670 9,670 INTRM1 CASIN DHEQ P Test 9-5/8" casing to 3000 psi f/ 30 min. Chart test. 21:00 21:30 0.50 9,670 9,670 INTRM1 CASINC OTHR P Rig down testing equipment. 21:30 22:00 0.50 9,670 9,743 INTRM1 DRILL CIRC P Make a top drive connection. Circulate and establish baseline data for MWD. 22:00 00:00 2.00 9,743 9,745 INTRM1 CEME~ COCF P Drill wiper plugs above the float collar and drillin float collar 9745' 04/24/2007 00:00 00:30 0.50 9,745 9,752 INTRM1 CEME COCF P Drilling the 9-5/8" float collar @ 9745' 00:30 01:30 1.00 9,752 9,752 INTRM1 RIGMN RGRP T Shut down and attempt to identify a oil leak on the to drive. 01:30 02:00 0.50 9,752 9,762 INTRM1 CEME~ COCF P Continue to clean out cement in the shoe track. 02:00 06:00 4.00 9,762 9,762 INTRM1 RIGMN RGRP T Continue to trouble shoot top drive gear oil leak. Remove gear oil filter assembly and replace a 1-1/2" nipple. Tighten assembly and reinstall on the to drive. Crew Chan e 06:00 07:15 1.25 9,762 9,832 INTRM1 CEME~ COCF P Continue to clean out cement in the shoe track from 9762' - 9832'. 07:15 07:30 0.25 9,832 9,852 INTRM1 DRILL DRLG P Continue drill open hole from 9832' - 9852'. TVD = 3607'. ADT = .11 HRS 07:30 08:30 1.00 9,852 9,815 INTRM1 DRILL CIRC P BROOH from 9852' - 9815' while circulate & condition mud for LOT @ 600 GPM's - 2710 PSI. Reciprocate & rotate drill strin . ECD = 10.1 PPG 08:30 09:30 1.00 9,815 9,815 INTRM1 DRILL LOT P Rig up equipment & lines. Perform LOT to calculated 13.8 PPG EMW. 2.4 BBLS bled back. Bleed all pressures. Rig down equipment & blow down same. 09:30 09:45 0.25 9,815 9,852 PROD1 DRILL TRIP P Make Top Drive connection & TIH to 9852' MD. 09:45 12:00 2.25 9,852 10,005 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 9852' - 10005' MD. TVD = 3610'. ADT = 1.44 HRS. 12:00 18:00 6.00 10,005 10,672 PROD1 DRILL DDRL P Continue directional drill 8 1!2" hole in the B lateral from 10005' -10672' MD. TVD = 3596'. ADT = 4.30 HRS. Crew than e. 18:00 00:00 6.00 10,672 10,775 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 10672' - 10775 MD. TVD = 3597'. ADT = 4.33 HRS. Total concretions drilled = 84' for 8.9% of total hole drilled. Page 13 oaf ~'I • • Time Logs __ ____ __ __ _ I Date From 7o Dur S. De tkt E. De th Phase Code Subcode T COM 04/25/2007 00:00 06:00 6.00 10,775 11,189 PROD1 DRILL DDRL P _ _ Continue directional drill 8 1/2" hole in the B lateral from 10775' - 11189' MD. ND = 3602'. ADT = 3.83 HRS. Crew than e 06:00 12:00 6.00 11,189 12,029 PROD1 DRILL DDRL P Continue directional drill 8 1!2" hole in the B lateral from 11189' - 12029' MD. ND = 3574'. ADT = 3.56 HRS. 12:00 18:00 6.00 12,029 12,711 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 12029' - 12711' MD. ND = 3564'. ADT = 3.89 HRS. Crew Chan e 18:00 00:00 6.00 12,711 13,376 PROD1 DRILL DDRL P Continue directional drill 8 112" hole in the B lateral from 12711' - 13376' MD. ND = 3351'. ADT = 3.83 HRS. Total concretions for the day = 131' for 5% of hole drilled. 04/26/2007 00:00 06:00 6.00 13,376 14,326 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 13376' - 14326' MD. ND = 3540'. ADT = 3.44 HRS. Crew Chan e 06:00 12:00 6.00 14,326 15,183 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 14326' - 15183'MD. ND = 3530'. ADT = 3.68 HRS. 12:00 18:00 6.00 15,183 16,418 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 15183' - 16418' MD. ND = 3528'. ADT = 3.64 HRS. Crew Chan e 18:00 00:00 6.00 16,418 17,019 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 16418' - 17019' MD. ND = 3525'. ADT = 4.14 HRS. 04/27/2007 00:00 06:00 6.00 17,019 17,678 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 17019' - 17678' MD. ND = 3513'. ADT = 4.30 HRS. Crew Chan e 06:00 10:45 4.75 17,678 17,735 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole in the B lateral from 17678' - 17735' MD. ND = 3512'. ADT = 1.41 HRS. Observed bit stopped drilling. pump 40 BBLS Hi Visc sweep ,allow to clear bit & bottoms u . 10:45 12:15 1.50 17,735 17,559 PROD1 DRILL REAM P BROOH from 17735' - 17559' @ 3 ft/min to allow sweep to return to surface. Observed ECD drop to 11.15 PPG, and little increase in cutting across shakers. 12:15 18:00 5.75 17,559 14,234 PROD1 DRILL REAM P Monitor well -static. Continue BROOH at 40-50 ft/min from 17559' - 14234'. Observed hole in good condition. Obtain T&D parameters as per rig engineer. Pump 1 stand slow every 15 stands to observed ECD parameters. Crew Chan e Page 14 of 4~ ~' • i Time Logs _ Date From To Dur S De th E. De th Phase CodeSubcode T COM _ 04/27/2007 18:00 00:00 6.00 14,234 9,976 PROD1 DRILL REAM P Continue BROOH at 40-50 ft/min from 14234' - 9976'. Observed hole in good condition. Obtain T&D parameters as per rig engineer. Pump 1 stand slow every 15 stands to observed ECD arameters. 04/28/2007 00:00 00:15 0.25 9,976 9,819 PROD1 DRILL REAM P Pull air slips from rotary table, and stri in rubbers. Monitor well -static. 00:15 02:30 2.25 9,819 9,819 PROD1 DRILL CIRC P Pump Hi visc sweep at the shoe while reciprocate & roptate drill string. Pump 3 bottoms up until clean. Observed little increase in cuttings when sweep returned. 02:30 02:45 0.25 9,819 9,819 PROD1 DRILL OWFF P Monitor well -static. Install air slips. 02:45 05:00 2.25 9,819 13,700 PROD1 DRILL TRIP P Trip back in hole from 9819' - 13700' on elevators. Ran out of down wei ht. 05:00 06:00 1.00 13,700 14,520 PROD1 DRILL REAM P Make Top drive connection, fill drill string. Wash & ream into hole from 13700' - 14520'. Crew Chan e 06:00 09:00 3.00 14,520 17,735 PROD1 DRILL REAM P Continue wash & ream from 14520' - 17735' TD. 09:00 10:45 1.75 17,735 17,735 PROD1 DRILL CIRC P Reciprocate & rotate drill string while circulate 30 BBLS sweep around at 600 GPM's 3680 PSI. Spot trucks for displacement. Held PJSM. Discuss dis lacement rocedure of SFMOBM. 10:45 12:45 2.00 17,735 17,735 PROD1 DRILL CIRC P Displace well with SFMOBM @ 600 GPM's - 3600 PSI. Continue reci rocate & rotate drill strin . 12:45 18:00 5.25. 17,735 10,241 PROD1 DRILL TRIP P Monitor well -static. Attempt to POOH on elevators. Observed swabbing. Pump out of hole from 17371' - 16421'. Monitor well -static. Continue POOH on elevators from 16421' - 10241'. Observed proper hole fill. No swabbing issues. Drop 1 7/8" drift in Drill string on TOH. Obtain SLM. Obtain T&D parameters as per ri en ineer. Crew Chan e 18:00 18:15 0.25 10,241 9,763 PROD1 DRILL TRIP P Continue POOH on elevators from 10241' - 9763'. Monitor well -static. BHA inside shoe. 18:15 19:45 1.50 9,763 9,763 PROD1 RIGMN SVRG P Held PJSM. Discuss safety & hazard recognition issues. Change out saver sub on To drive. 19:45 00:00 4.25 9,763 919 PROD1 DRILL TRIP P Continue POOH on elevators from 9763' - 919'. Observed proper hole fill. Obtain SLM, & T&D parameters as er ri en ineer. 04/29!2007 00:00 00:30 0.50 919 348 PROD1 DRILL TRIP P Continue POOH on elevators from 919' - 348'. BHA. Observed proper hole fill. No correction on SLM. 00:30 01:30 1.00 348 92 PROD1 DRILL PULD P Rack back HWDP & DC's. Breakout & lay down BHA as per DD. & MWD re s. Pag~~9 ~f ~~ • Time Logs _______ _ __ Date From To Dur S. De th E. De th f?h~e Code Subcode_ TCOM 04%30/2007 04:30 05:00 0.50 17,722 17,722 COMPZ CASIN CIRC P Work torque out of drill string to observe oriented Liner hanger to 1 degree left. Pumps @ 3 BPM - 650 PSI. UP WT = 235K, SO wt = O. ROT WT = 130K. 05:00 06:00 1.00 17,722 17,722 COMPZ CASIN CIRC P Break connection & drop 1 3/4" ball down drill string. Pump down at 3 BPM - 650 PSI. Crew Chan e 06:00 07:30 1.50 17,722 8,830 COMPZ CASIN CIRC P Continue pump 1 3/4" Ball down drill string to observe ball landed in 1270 stks. Slack off weoight to 72K. Pressure to 3000 PSI. Pressure to 3430 PSI observing pressure fall off suddenly with flow in the stack. Close pipe rams. Pump down kill line to obtain a test on the MLZXP to 2500 PSI for 5 minutes. NOTE. Pump strokes indicated pressuring the DP also through the setting tools. Blled pressures. open rams. Pull up to attempt to pull free. No Go. Pull up to 100K over reated times. Work left hand torque down to tool to safety off of assembly. Pull 5 stands. Monitor well -static. 07:30 07:45 0.25 8,830 8,830 COMPZ RIGMN SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss rocedure for sli & cut drillin line. 07:45 09:15 1.50 8,830 8,830 COMPZ RIGMN SVRG P Slip & cut 131' of drilling line. Inspect & adjust brakes on draw works. Service auto driller & crown o matic. 09:15 10:15 1.00 8,830 8,830 COMPZ RIGMN SVRG P Inspect & service Top Drive & travelling equipment. SIMOPS: Pump 160 BBLS of Freeze protect diesel down OA with Littfe Red services @ 2 BPM - 775 PSI. Final shut in pressure = 320 PSI. 10:15 10:30 0.25 8,830 8,830 COMPZ RIGMN SVRG P Replace 1 1/4" Oil hose on Top drive for the oil um . 10:30 12:00 1.50 8,830 5,597 COMPZ CASIN RUNL P POOH on elevators from 8830' - 5597'. Observed correct hole fill. 12:00 14:30 2.50 5,597 0 COMPZ CASIN RUNL P Continue POOH on elevators from 5597' -running & setting tools. Observed correct hole fill. 14:30 15:15 0.75 0 0 COMPZ CASIN RURD P Inspect, breakout & lay down setting & runnin tools. 15:15 16:00 0.75 0 0 COMPZ CASINC OTHR P Clear & clean floor area from tools & OBM. Change out air boot in Bell ni le for SPCC control. 16:00 16:15 0.25 0 0 PROD2 STK OTHR P Held PJSM with crew, BOT & Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure to make up & run New whipstock assembly with ML Anchor assembly & orientation of same to MWD. ~~~_______~.r._.~.~. F~age '17 of ~1 ~ ~ Time Logs __ ___ __ _ ____ Date From To Dur S. De th E. De th Phase Code Subco_d_e T _ COM_ _ 04/30/2007 16:15 18:00 1.75 0 0 PROD2 STK PULD P Make up ML Whipstock assembly with new ML anchor & seals. Orient whipstock face with ML anchor latch. Crew Chan e 18:00 20:30 2.50 0 0 PROD2 STK PULD P Continue make up whipstock assembly as per BOT reps. Make up mills with a 8 1/2" Pathmaker starting mill. orient MWD to whipstock slide as er S er Sun re s. 20:30 21:00 0.50 0 0 PROD2 STK PULD P Plug in and upload MWD assembly. 21:00 21:45 0.75 0 290 PROD2 STK PULD P Continue make up remaining BHA with bumperjar, and drill collars. Total BHA len th = 290.39'. 21:45 22:00 0.25 290 290 PROD2 STK TRIP P TIH with 1 stand of DP. perform shallow pulse test on MWD tools with 490 GPM"S - 850 PSI. Good test. 22:00 00:00 2.00 290 3,621 PROD2 STK TRIP P Trip in hole with whipstock assembly from 290' - 3621' at 90 seconds / stand as per BOT rep. Observe proper hole fill. Fill drill string every 25 stands. 05/01/2007 00:00 03:00 3.00 3,621 8,039 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 3621' - 8039 at 90 seconds /stand as per BOT rep. Observe proper hole fill. Fill drill string eve 25 stands. 03:00 04:15 1.25 8,039 8,164 PROD2 STK OTHR P Perform MAD PASS from 8039' - 8164' DPM @ 180 ft/min. Perform test on tools with circulation rates, obsrerving low rate at 440 GPMs- 1530 PSI. 04:15 04:30 0.25 8,164 8,661 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8164' - 8661 at 90 seconds /stand as per BOT rep. Observe ro er hole fill. 04:30 05:30 1.00 8,661 9,120 PROD2 STK WPST P Single in hole with 15 joints of 5" HWDP for extra down weight as per BOT re from 8661' - 9120'. 05:30 06:00 0.50 9,120 9,180 PROD2 STK WPST P Pick up 1 more stand of DP & circulate @ 9120' to observe orientation of whipstock face to 44 deg right of high side. Slack off to tag & latch up into MLZXP packer @ 9180' DPM.Pumps @ 430 GPM's - 1650 PSI. UP WT = 220K, SO WT = 108K. Attempt to latch up into profile, and pick up several times to verify latch. Observed seals "hydraulically" preventing a good latch up. Crew Chan e Pa~~ 11~ z~f ~1 r ~ Time Logs _ _ _ _ Date From To Dur 5 Depth E De th Phase Code Subcode T COM ___ 05/01/2007 06:00 07:00 1.00 9,180 9,180 PROD2 STK WPST P Continue attempt to snap into profile, setting up to 28K downweight to observe snapped in and MWD orientation moving from 44 deg Right back to 33 Deg left. Pull up to 20K over to verify good latch up & orientation of whipstock. SIMOPS: Held PJSM with crew for OBM dis lacement. 07:00 08:00 1.00 9,180 9,180 PROD2 STK CIRC P Displace well with 8.5 PPG OBM at 600 GPM's - 2000 PSI. NO movement in drill string as we are still bolted up to whi stock. 08:00 08:30 0.50 9,180 9,180 PROD2 STK WPST P Shear 45K bolt with 3 attempts "slapping" the bolt with the bumperjar. Up movement indicated sheared off and free movement. UP WT = 205K, SO WT = 105, ROT WT = 155K with 10K for ue. 08:30 12:00 3.50 9,097 9,104 PROD2 STK MILL P MITI window in 9 5/8" casing from 9097' - 9104'. WOB = 4K, RPM's = 120, Pum sat 450 GPM's - 1700 PSI. 12:00 15:15 3.25 9,104 9,137 PROD2 STK MILL P Continue mlll window in 9 5/8" casing from 9104' - 9113'. Mill in open hole from 9113' - 9137'.Total milling time = 6.12 HRS. WOB = 4K, RPM's = 120, Pum sat 450 GPM's - 1700 PSI. 15:15 16:00 0.75 9,137 9,137 PROD2 STK CIRC P Circulate out sweep in hole, while reciprocate & rotate drill string with mills to clean u window area. 16:00 16:45 0.75 9,137 8,947 PROD2 STK TRIP P Pull & rack back 1 stand of DP. Lay down sin le to shed. 16:45 18:00 1.25 8,947 8,947 PROD2 WELCT OTHR P Make up BOT 9 518" storm packer. RIH to set packer @ 68'. Release from packer. POOH. Close blind rams. Test packer to 500 PSI - 5 minutes. Good test. Crew chan e 18:00 19:45 1.75 8,947 8,947 PROD2 WELCT OTHR P Rig up tools & BOLDS to pull wear bushing. Make up stack washing tool. RIH, flush BOP stack & lines of iron cuttin s. 19:45 00:00 4.25 8,947 8,947 PROD2 WELC BOPE P Install test plug. Rig up test equipment & lines. Test BOP's & choke manifold. perform Koomey draw down test. 200 PSI increase in 54 seconds, with full pressure in 3 min, 18 seconds. 5 Nitrogen bottles with avg PSI of 2300 PSI. 05/02/2007 00:00 00:45 0.75 8,947 8,947 PROD2 WELCT BOPE P Pull test plug. Install wear bushing - RILDS. Blow down Choke & kill lines, and manifold. Witness of BOP test waived b AOGCC re -Jeff Jones. €~~~~~ page ~9 of 41 ! ~ .Time Logs _ ___ ___ __ _ __ __ _ .Date From To Dur S. Depth E_ Depth Phase Code Subcode T COM _ 05/02/2007 00:45 02:00 1.25 8,947 8,930 PROD2 WELCT OTHR P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to retrieve storm packer & well control issues. Make up retrieving tool. RIH to 66', and screw into storm packer. Pull bypass open to verify no pressure. Release packe with 1 RH turn, pull to rig floor. Breakout & lay down storm packer assembl . 02:00 02:45 0.75 8,930 8,930 PROD2 STK OTHR P Make top drive connection. Pump down drill string to verify minimal flow test for MWD. pumps at 300 GPM's indicated too much noise & little detection. Pumps at 325 GPM's - indicated good pulses & detection but questionable. MWD rep recomends minimal rate @ 350 GPM's with good ulses & detection. 02:45 03:15 0.50 8,930 8,930 PROD2 STK OWFF P Monitor well -static. Pump dry job. 03:15 06:00 2.75 8,930 207 PROD2 STK TRIP P Trip out of hole with milling assembly from 8930' - 207'. Observed proper hole fill. Crew Chan e 06:00 08:30 2.50 207 0 PROD2 STK TRIP P Continue trip out of hole .Breakout, inspect & lay down milling assembly.Grade pathmaker mill to 0/0/NOlA/X/I/NO/TD. Send tools outside. 08:30 11:00 2.50 0 0 PROD2 RPCOh OTHR P Make up Baker FJD tool with tailpipe to the MWD. Perform test on FJD tool with 2 x 18's & 1 x 16"jets. pumps @ 350 GPM's - 850 PSI Good MWD Signal. Observed partial actuation of FJD tool @ 425 GPM @ 1240 PSI and Full actuation of tool w/ 450 GPM's - 1400 PSI. Shut down, Change out jets to 2 x 20's & 1 x 16. partial actuation @ 400 GPM @ 1100 PSI and Full actuation w/ 450 GPM's -1400 PSI. Test questionalble. Breakout & lay down FJD tools & tail i e. 11:00 11:45 0.75 0 0 PROD2 STK PULD P Plug in and download MWD assembl . 11:45 12:45 1.00 0 0 PROD2 DRILL PULD P Lay down DM asseembly from MWD. Make up new DM assembly. Make up GeoPilot & bit. Breakout & lay down Pulsar. Install new Pulsar assembly, and make u to BHA. 12:45 13:30 0.75 0 0 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 13:30 14:00 0.50 0 0 PROD2 DRILL PULD P Make up ARD resisitivity & float sub to BHA. 14:00 14:45 0.75 0 0 PROD2 DRILL PULD P Plug in and Upload ARD assembly. E~~t~~ 27 e~f ~1 ! ~ Time Logs I Dat_~ From To Dur S. Depth E_Depth Phase Code Subcode T COM 05/02/2007 14:45 15:00 0.25 0 398 PROD2 DRILL PULD P Perform shallow [pulse test on MWD assembly. Good test. Total BHA = 398.28' 15:00 18:00 3.00 398 5,155 PROD2 DRILL TRIP P Trip in hole from 398' - 5155'. Fill drill string every 25 stands. Observed ro er hole fill. Crew Chan e 18:00 19:45 1.75 5,155 8,559 PROD2 DRILL TRIP P Continue trip in hole from 5155' - 8559'. Observed proper hole fill. Fill DP eve 25 stands. 19:45 20:15 0.50 8,559 8,559 PROD2 RIGMN SVRG P Service Top Drive, Blocks & draw works. 20:15 21:00 0.75 8,559 9,137 PROD2 DRILL TRIP P Continue trip in hole from 8559' - 9137'. observed no issues with assembly through the whipstock. Pumps on at 2 BBLS minute. Pull back above window. Pumps @ 600 GPM's - 2650 PSI. Slack off through window verifying ABI inclination readin s. 21:00 21:30 0.50 9,137 9,137 PROD2 DRILL CIRC T Trouble shoot MWD problems. Observed poor detection. Gained detection b mode switchin . 21:30 22:00 0.50 9,137 9,165 PROD2 DRILL DDRL P Directional drill in the D lateral from 9137' - 9165'. ADT = .33 HRS. Observed poor detection again. Lost ABI surve s. 22:00 00:00 2.00 9,165 9,165 PROD2 DRILL CIRC T Pull drill string back into casing above window. Trouble shoot MWD and ABI problems. Continue with mode switching. Observed good ABI surveysand good detection. Decision to continue drillin . 05/03/2007 00:00 00:45 0.75 9,165 9,165 PROD2 DRILL CIRC T Continue trouble shoot MWD assembl . 00:45 02:30 1.75 9,165 9,240 PROD2 DRILL DDRL P Continue directional drilling from 9165' - 9240'. observed questionable detection. ADT = .33 HRS. 02:30 03:15 0.75 9,240 9,054 PROD2 DRILL TRIP T POOH from 9240' - 9054'. Trouble shoot MWD. Lost ABI, gained it back, then bad detection. Got it back. 03:15 04:15 1.00 9,054 9,054 PROD2 DRILL OTHR T Check all surface equipment. Pull screens on pumps, check valves & seats. Check all manifold valves and perform a 3000 PSI surface test on all lines & e ui ment. 04:15 04:30 0.25 9,054 9,240 PROD2 DRILL TRIP T Trip in hole from 9054' - 9240'. 04:30 05:00 0.50 9,240 9,432 PROD2 DRILL DDRL P Continue drilling D lateral from 9240' - 9432'. Total ADT = 1.27 HRS. ECD = 9.78 PPG. Detection roblems a ain. 05:00 06:00 1.00 9,432 9,179 PROD2 DRILL TRIP T POOH from 9432' - 9179'. Take checkshots at 9336', 9241' and 9179'. Obtained ood surve s. Crew chan e 06:00 06:15 0.25 9,179 9,432 PROD2 DRILL TRIP T TIH once again with good detection to 9432'. ~_._._.._-....~-_ Page 21 ~s' ~1~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/03/2007 06:15 06:45 0.50 9,432 9,539 PROD2 DRILL DDRL P Continue driectional drill in the D lateral from 9432' - 9539'. ADT = .34 HRS. Observed trouble with detection. Decision to POOH. 06:45 07:30 0.75 9,539 9,539 PROD2 DRILL CIRC T Retake check shot surveys for verification. Obtain survey @ 9527'. MD. 07:30 08:00 0.50 9,539 9,539 PROD2 DRILL OWFF T Monitor well -static. pump dry job. POOH from 9539' - 9097'. 08:00 08:15 0.25 9,539 9,539 PROD2 DRILL TRIP T Blow down Top drive & lines. Install stri in rubbers & air sli s. 08:15 11:00 2.75 9,539 410 PROD2 DRILL TRIP T POOH from 9097' - 410'. Observed correct hole fill. 11:00 11:30 0.50 410 398 PROD2 DRILL PULD T Breakout & fay down BHA to MWD. 11:30 12:00 0.50 398 398 PROD2 DRILL PULD T Plug in and download MWD &ARD tools. 12:00 13:00 1.00 398 398 PROD2 DRILL PULD T Breakout & lay down pulsar. Change out internal components, and make up same. 13:00 14:15 1.25 398 398 PROD2 DRILL PULD T Plug in and Upload MWD and ARD assemblies. Pull to-bit. Inspect & rade same to 1/1/WT/GTIX/I/NO/DTF 14:15 14:45 0.50 398 398 PROD2 DRILL PULD T Make Top Drive connection. Perform shallow ulse test. Good test. 14:45 15:00 0.25 398 398 PROD2 DRILL PULD T Make up remaining BHA.FIex DC's & 'ars. 15:00 18:00 3.00 398 8,007 PROD2 DRILL TRIP T Trip in hole from 398' - 8007'. Observed correct hole fill, and fill dril- string every 25 stands. Crew Chan e 18:00 18:45 0.75 8,007 9,539 PROD2 DRILL TRIP T Continue trip in hole from 8007' - 9539'. Observed clean hole and no issues when assembly going through whi stock area. 18:45 19:00 0.25 9,539 9,539 PROD2 DRILL CIRC T Obtain drilling parameters as per DD. Get ood PWD baseline readin s. 19:00 00:00 5.00 9,539 10,222 PROD2 DRILL DDRL P Continue driectional drill 8 1/2" hole in the D lateral from 9539' - 10222' MD. TVD = 3537'. ADT = 2.81 HRS. ECD = 10.28 PPG. 05/04/2007 00:00 04:30 4.50 10,222 10,825 PROD2 DRILL DDRL P Continue directional drill 8 1!2" hole in the D lateral from 10222' - 10825' MD. ADT = 2.58 HRS. ECD = 10.40 PPG. 04:30 06:00 1.50 10,825 11,050 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 10825' - 11050' MD. TVD = 3506'. ADT = 1.25 HRS. ECD = 10.40 PPG. Page 22 of 41 ~~ Time Lo Date From To Dur S. De th E. De th Phase Code Subcade T COM 05/04/2007 06:00 07:15 1.25 11,050 11,190 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 11050' - 11190' MD. TVD = 3497'. ADT = .63 HRS. ECD = 10.14 PPG. Geologists observed formation change & out of zone. NOTE: Geologists confrimed we drilled through a fault @ 9200' MD. This is 87' below bottom of window. The fault indicated a 13' down throw. Upon further review, the fault was recognized in the intermediate section as well. 07:15 07:45 0.50 11,190 10,825 PROD2 DRILL TRIP NP POOH with 5 stands from 11190' - 10825'. 07:45 08:30 0.75 10,825 10,825 PROD2 STK KOST NP Obtain surveys & set parameters. Ream from 10800' - 10825'. Widen bend for kick off as er DD. 08:30 11:00 2.50 10,825 11,190 PROD2 STK KOST NP Perform open hole kick off sidetrack 10825', continue drilling to 11190' MD. TVD = 3514' ADT = 1.47 HRS. 11:00 12:00 1.00 11,190 11,334 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 11190' - 11334' MD. TVD = 3510'. ADT = .54 HRS. ECD = 10.12 PPG. 12:00 18:00 6.00 11,334 12,265 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 11334' - 12265' MD. TVD = 3504'. ADT = 3.57 HRS. ECD = 10.80 PPG. 18:00 00:00 6.00 12,265 13,110 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 12265' - 13110' MD. TVD = 3491'. ADT = 3.81 HRS. ECD = 10.80 PPG. 05/05!2007 00:00 06:00 6.00 13,110 13,369 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 13110' - 13369' MD. TVD = 3477'. ADT = 4.49 HRS. ECD = 10.68 PPG. Drilled total of 54' of concretions for 1.6% of hole drilled with an avers a thickness of 6'. 06:00 12:00 6.00 13,369 14,377 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 13369' - 14377' MD. TVD = 3455'. ADT = 3.79 HRS. ECD = 10.86 PPG. 12:00 18:00 6.00 14,377 15,443 PROD2 DRILL DDRL P Continue directional drill $ 1/2" hole in the D lateral from 14377' - 15443' MD. TVD = 3445'. ADT = 3.38 HRS. ECD = 11.22 PPG. 18:00 00:00 6.00 15,443 16,503 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 15443' - 16503' MD. TVD = 3436'. ADT = 3.84 HRS. ECD = 11.32 PPG. 05/06/2007 00:00 06:00 6.00 16,503 17,406 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 16503' - 17406' MD. TVD = 3426'. ADT = 3.61 HRS. ECD = 11.41 PPG. Crew Chan e Page 23 gif 41 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/06/2007 06:00 07:45 1.75 17,406 17,609 PROD2 DRILL DDRL P Continue directional drill 8 112" hole in the D lateral from 17406' - 17609' MD. TVD = 3423'. ADT = .89 HRS. ECD = 11.26 PPG. 07:45 09:00 1.25 17,609 17,609 PROD2 DRILL CIRC T Circulate & reciprocate drill string while repair Mud Pump # 2. Washed out liner seal. 09:00 12:00 3.00 17,609 17,935 PROD2 DRILL DDRL P Continue directional drill 8 1/2" hole in the D lateral from 17609' - 17935' MD. TVD = 3420'. ADT = 1.86 HRS. ECD = 11.27 PPG. 12:00 16:30 4.50 17,935 17,935 PROD2 DRILL CIRC P Circulate Hi Visc sweep + 4 bottoms up. Reciprocate & rotate drill string while circulating. Pumps @ 620 GPM's - 3850 PSI. 16:30 17:15 0.75 17,935 17,470 PROD2 DRILL TRIP P POOH on elevators form 17935' - 17470'. Hole fill not correct. 17:15 18:00 0.75 17,470 16,912 PROD2 DRILL TRIP P Continue pump out of hole from 17470' - 16912'. Crew Chan e 18:00 00:00 6.00 16,912 12,858 PROD2 DRILL REAM P Attempt to POOH on elevators. Observed improper hole fill, and fluid running over DP in stump, and as we pulled. Continue BROOH to 12858'. Observed good hole conditions with increased cuttings, slowing speed to allow cuttin s to clean u . 05/07/2007 00:00 03:00 3.00 12,858 10,577 PROD2 DRILL REAM P Continue BROOH from 12858' - 10577'. Observed good hole conditions. 03:00 06:00 3.00 10,577 10,577 PROD2 RIGMN RGRP T While lowering Top drive to rig floor, the bales were being floated to center position, driller observed bales continued to extend in reverse sending drill pipe elevators and bales out the back side of the derrick- Rig team notified. No injuries, or spills. Invetigation underway. Pull Top drive up and retract bales and elevators into center "float" position. Remove damaged parts. Send for inspection & repair. Prepare Top drive to use without link tilt. Inspect derrick. Inspect switch on Top drive panel. Crew Chan e 06:00 09:45 3.75 10,577 9,054 PROD2 DRILL REAM P Continue BROOH slow from 10577' - 9054'. Observed ood hole conditions. 09:45 10:15 0.50 9,054 9,054 PROD2 DRILL CIRC P Circulate and reciprocate drill string from 9054' - 8961'. Clean & clear rig floor area. 10:15 11:00 0.75 9,054 9,054 PROD2 RIGMN SVRG P Blow down & service Top Drive. grease crown section & sheaves. Service travelling block. Inspect derrick. Continue work on #2 mud pump dischar a screen flan es. 11:00 12:30 1.50 9,054 9,054 PROD2 RIGMN SVRG P Siip & cut 119' of drilling tine. Install Floor safe valve. Page 74 of 41 ~~ ~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/07/2007 12:30 15:30 3.00 9,054 9,054 PROD2 DRILL OTHR P Rig up handling equipment. pick up and rack back 9 stands of 5" HWDP planned for future run, while waiting on To drive arts. 15:30 18:00 2.50 9,054 9,054 PROD2 RIGMN SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss and change out 4 1/2" IF saver sub on Top Drive. Crew than e 18:00 21:30 3.50 9,054 9,054 PROD2 RIGMN SVRG P Continue change out saver sub with new crew. Complete repair of discharge screen flanges on mud pump #2. 21:30 23:30 2.00 9,054 9,054 PROD2 DRILL CIRC P Test mud pump & lines. Establish circulation. Pump 35 BBL Hi Visc sweep @ 620 GPM - 2950 PSI. Reciprocate & rotate drill string @ 120 RPM's. Observe minimal increase in cuttings when sweep returned. Continue pump 1 more bottoms up to veri hole clean. 23:30 00:00 0.50 9,054 9,054 PROD2 RIGMN RGRP T Install floor safety valve. Continue assemble parts on Top Drive. Monitor well through trip tank. Observed 4 BBL loss. 05/08/2007 00:00 04:00 4.00 9,054 9,054 PROD2 RIGMN RGRP T Continue assemble parts on Top Drive. Attach hydraulic lines and adjust link tilt assembly. Test run link tilt assembly. Continue Monitor well throu h tri tank. 04:00 06:00 2.00 9,054 10,930 PROD2 DRILL TRIP P Trip back in hole Fill every 20 stands. PU wt 205k, SO wt 80k. 06:00 07:45 1.75 10,930 12,383 PROD2 DRILL TRIP P Continue trip back in hole. Fill every 10 stands. Obtain PU and SO wt's. 07:45 14:15 6.50 12,383 17,935 PROD2 DRILL REAM P Ream in the hole (no down wt). 14:15 17:00 2.75 17,935 17,935 PROD2 DRILL CIRC P Circ and condition hole. Circulated 2211 bbls and 45 bbl weighted sweep (10.2 ppg, 185 vis). Total of 2256 bbls pumped. Slight increase in cuttings from sweep. Rotate 150 rpm w/ 18-20k ft Ibs for ue. 17:00 19:15 2.25 17,935 17,935 PROD2 DRILL CIRC P Displace well to Solids free oit base mud. Rotate 150 rpm w/ 20-21 k ft Ibs for ue. 19:15 19:30 0.25 17,935 17,935 PROD2 DRILL OWFF P Monitor well. 19:30 21:15 1.75 17,935 16,566 PROD2 DRILL TRIP P POOH on the trip tank. Hole not taking proper fill. Record PU and SO wt's eve 10 stands. SLM. 21:15 00:00 2.75 16,566 14,665 PROD2 DRILL TRIP P Pump out of the hole. Pulling 45'/min. pumping 180 gpm. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 05/09/2007 00:00 01:00 1.00 14,665 14,189 PROD2 DRILL TRIP P Pump out of the hole. Pulling 45'/min. pumping 180 gpm, 500 psi. PU wt 270k, no down wt. record PU and So wt's eve 10 stands. SLM. Page 25 of 41 r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/09/2007 01:00 03:30 2.50 14,189 11,716 PROD2 DRILL TRIP P Pump out of the hole every other one. Pulling 45'/min. pumping 180 gpm, 460 psi.. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 03:30 06:00 2.50 11,716 10,101 PROD2 DRILL TRIP P Pump out of the hole every 3rd one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 06:00 07:30 1.50 10,101 9,054 PROD2 DRILL TRIP P Pump out of the hole every 4th one. Pulling 45'/min. pumping i80 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 07:30 08:15 0.75 9,054 9,054 PROD2 DRILL CIRC P Circulate bottom's up. Rotate 120 rpm w/ 13k ft Ibs torque. 08:15 08:30 0.25 9,054 9,054 PROD2 DRILL CIRC P Perform minimal flow test w/ Sperry MWD. 300 gpm was determined with ood detection. 08:30 08:45 0.25 9,054 9,054 PROD2 DRILL OWFF P Monitor well. Static. 08:45 09:15 0.50 9,054 8,198 PROD2 DRILL TRIP P Pull out of the hole. Hole not taking ro er fill. 09:15 09:45 0.50 8,198 8,388 PROD2 DRILL TRIP P RIH 09:45 10:30 0.75 8,388 8,388 PROD2 DRILL CIRC P Circulate bottom's up. Rotate 120 rpm w/ 13k ft Ibs for ue. 10:30 12:00 1.50 8,388 7,057 PROD2 DRILL TRIP P Pump out of the hole every 3rd one. Pulling 45'/min. pumping 180 gpm, 460 psi. PU wt 270k, no down wt. record PU and So wt's every 10 stands. SLM. 12:00 13:00 1.00 7,057 6,201 PROD2 DRILL TRIP P POOH. Hole started taking proper fill. 13:00 13:15 0.25 6,201 6,201 PROD2 DRILL OWFF P Monitor well. Static. 13:15 13:30 0.25 6,201 6,201 PROD2 DRILL CIRC P Pump dry job. Blow down top drive. 13:30 17:45 4.25 6,201 398 PROD2 DRILL PULD P Insert Haggard ID mud wiper. Pull out and la down drill i e. 17:45 18:30 0.75 398 247 PROD2 DRILL TRIP P Stand back HWDP, lay down jars, PU a sin le HWDP. 18:30 18:45 0.25 247 247 PROD2 DRILL OTHR P Clear and clean rig floor. 18:45 19:00 0.25 247 247 PROD2 DRILL SFTY P PJSM on laying down BHA # 6 19:00 19:30 0.50 247 125 PROD2 DRILL PULD P UD 3 jts of NM flex collars. 19:30 20:00 0.50 125 125 PROD2 DRILL OTHR P Download Sperry Sun MWD. 20:00 20:30 0.50 125 77 PROD2 DRILL PULD P UD MWD 20:30 21:00 0.50 77 77 PROD2 DRILL OTHR P Download Sperry Sun MWD. Page 26 0€ 41 ~~ • Time Lo s Date From To Dur S, De th E. De th Phase Code Subcode T COM 05/09/2007 21:00 23:00 2.00 77 0 PROD2 DRILL TRIP P PU single dp, stand back MWD. Break bit, lay down geopilot. Note: Calculated fill for trip 160 bbls, actual 213 bbls. Total of 53 bbls over calculated. 23:00 23:15 0.25 0 0 COMPZ FISH SFTY P PJSM on PU BHA #7. 23:15 00:00 0.75 0 63 COMPZ FISH PULD P PU/MU BHA # 7 to retrive whipstock assembl 05/10/2007 00:00 00:30 0.50 63 154 COMPZ FISH PULD P Continue to PU/MU BHA # 7 to retrive whi stock assembl 00:30 01:30 1.00 154 2,532 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 115, SO wt 108k. 01:30 01:45 0.25 2,532 2,532 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 01:45 02:45 1.00 2,532 4,909 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 140, SO wt 108k. 02:45 03:00 0.25 4,909 4,909 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 03:00 04:00 1.00 4,909 7,285 COMPZ FISH TRIP P RIH w/ whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 180, SO wt 95k. 04:00 04:15 025 7,285 7,285 COMPZ FISH CIRC P Fill pipe, circ 50 bbls. 04:15 05:15 1.00 7,285 9,061 COMPZ FISH TRIP P RIH w! whipstock retrieval assembly (BHA #7). Fill every 25 stands. Record PU and SO wt's every 5 stands. PU wt 220, SO wt 110k. 05:15 05:30 0.25 9,061 9,061 COMPZ FISH SFTY P PJSM on displacing well to MOBM. 05:30 06:45 1.25 9,061 9,061 COMPZ FISH CIRC P Displace from SFOBM to MOBM.PU wt prior to displacement =220k, SO 110k. 06:45 09:00 2.25 9,061 9,061 COMPZ FISH CIRC P Circulate 5 BU at a high rate to clean casing.PU wt after circuiting and displacement = 210k, SO wt 140k. Gained 30k down wt. 09:00 09:30 0.50 9,061 9,101 COMPZ FISH FISH P Make up stand 96, RIH, engage hook into whipstock. Pull 25k over. Jar, then pull to 285k. Unlatched anchor and ulled u 30'. 09:30 10:00 0.50 9,071 9,071 COMPZ FISH CIRC P Circulate bottom's up. 10:00 10:15 0.25 9,071 9,071 COMPZ FISH OTHR P Observe well for flow. Static. 10:15 10:30 0.25 9,071 9,071 COMPZ FISH CIRC P Pump dry job. Blow down top drive. 10:30 14:45 4.25 9,071 154 COMPZ FISH TRIP P POOH with whipstock assembly. Hole took ro er dis lacment. 14:45 16:30 1.75 154 0 COMPZ FISH PULD P Stand back a stand of HWDP. Lay down whipstock retrieval assembly and whi stock assembl . Page 27 of 41 l Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/10/2007 16:30 17:00 0.50 0 0 COMPZ FISH PULD P Clean tools. UD Baker tools from the floor. 17:00 17:30 0.50 0 0 COMPZ FISH OTHR P Clean and clear rig floor. 17:30 17:45 0.25 0 0 COMPZ RPCO(V SFTY P PJSM on picking up Baker RAM diverter assembl . 17:45 20:15 2.50 0 125 COMPZ RPCOh PULD P PU/MU RAM diverter assembly, orient same to index opening with window and lu . 20:15 21:00 0.75 125 174 COMPZ RPCOh PULD P PU/MU Sperry MWD and make top drive connection. U load MWD. 21:00 21:30 0.50 174 174 COMPZ RPCOh OTHR P Set Seal bore diverter in the rotary table. Manually release FJD running tool. PU and disengage the running tool. Test volume and pressure for release. Results: @ 275 gpm w/ 550 psi- detection but not real good, 300 gpm w/ 640 psi- good detection w/ MWD, 325 gpm w/ 740 psi- tool still not released, 350 psi w/ 850 psi- still not releassed, 375 gpm w! 980 psi, @ 400 pm w/ 1100 psi tool released. 21:30 00:00 2.50 174 4,240 COMPZ RPCOh TRIP P PJSM, RIH w/diverter assembly on 5" drill pipe. Good hole displacement. Runnin speed 80-90' er min. 05/11/2007 00:00 03:00 3.00 4,240 9,173 COMPZ RPCOh TRIP P Continue to RIH w/diverter assembly on 5" drill pipe. Good hole displacement. Running speed 80-90' per min. PU wt 210k, SO wt 130k @ 9173'. 03:00 03:30 0.50 9,173 9,205 COMPZ RPCOh OTHR P MU top drive on stand 96, break circulation, establish circulation and good detection w/ 275 gpm w/ 830 psi. PU wt 210k, SO wt 135k. Initial survey w/ MWD showed 130 right. Work pipe to a final of 83 Right and torque worked down hole. Slack off until) latched in w/ mule shoe @ 9205.43'. Surve indicatin 8 de left. 03:30 04:00 0.50 9,205 9,205 COMPZ RPC06 OTHR P Pull testing to see required overpull to snap out. Snapped out w/ weight indicator reading 320k (110k overpull). Confirm PU wt 210k and SO 130k. 04:00 04:15 0.25 9,205 9,075 COMPZ RPCOh OTHR P Set back down to weight indicator reading of 80k. Increase pumps f/ 275 gpm w/ 830 psi to 500 gpm w/ 2380 psi. Pickup and free of diverter assembl . PU wt is now 205k. 04:15 04:30 0.25 9,075 9,075 COMPZ RPCO(V SFTY P PJSM on displacing well f/ 8.4 ppg MOBM to NEW 8.5 ppg Solids free oil base mud. 04:30 06:00 1.50 9,075 8,999 COMPZ RPCO CIRC P Set back stand #96. Displace well from 8.4 ppg MOBM to 8.5 ppg Solids free Oil Base mud, pumping 570 gpm w/ 3280 psi. Reciprocate pipe 65' stroke. Take SPR's. Record PU and SO wt. PU 220k, 135k SO wt. Page 28 of 41 s Time L s Date From To Dur S. De th E De th Phase Code Subcode T COM 05/11/2007 06:00 06:15 0.25 8,999 8,999 COMPZ RPCOh OTHR P Monitor well. Static. 06:15 06:30 0.25 8,999 8,999 COMPZ RPCOti OTHR P Blow down top drive. 06:30 11:30 5.00 8,999 50 COMPZ RPCOh TRIP P POOH w/diverter running tools. 11:30 12:00 0.50 50 50 COMPZ RPCOti OTHR P Download MWD. 12:00 12:45 0.75 50 0 COMPZ RPCOh PULD P Lay down BHA: MWD and Baker runnin tools. 12:45 13:15 0.50 0 0 COMPZ RPCOh OTHR P Clean and clear rig floor. Function pipe rams, blind rams, kill and choke HCR valves and the annular. 13:15 13:45 0.50 0 0 COMPZ CASINC RURD P Rig up GBR equipment to run "D" lateral 4-1/2" 11.6 f 13:45 14;00 0.25 0 0 COMPZ CASINC SFTY P Pre job safety meeting on running "D" lateral slot balnk 4-1/2" liner w/ Baker RAM liner han er. 14:00 18:00 4.00 0 6,240 COMPZ CASINC PUTB P Run 4-1/2", 11.6 ppf, slotted liner fJ "D" lateral. 18:00 20:30 2.50 6,240 8,763 COMPZ CASINC PUTB P Continue to run 4-1/2", 11.6 ppf, slotted liner f! "D" lateral. Record PU and SO wt's every 10 jts. PU wt 120k, SO wt 95k. Calculated displacement 37 bbls, actual displacement 29 bbls. 20:30 21:00 0.50 8,763 8,763 COMPZ CASINC PUTB P PUlMU crossover to 7" Hydril 563. Monitor well on tri tank. 21:00 22:15 1.25 8,763 8,763 COMPZ CASINC WOEQ NP Load pipe shed w/ 96 joints of 4-1/2" 12.6 ppf L-80 IBT-m tubing for the completion run, while trying to locate a ~t of 3-1 /2" STL for the inner strin . 22:15 00:00 1.75 8,763 8,763 COMPZ DRILL PULD P Lay down 5" extra drill pipe from driller's side of derrick while waiting on a joint of 3-1/2" STL inner string for the liner run. 05/12/2007 00:00 00:15 0.25 8,763 8,763 COMPZ DRILL PULD P Lay down 5" extra drill pipe from driller's side of derrick while waiting on a joint of 3-1/2" STL inner string for the liner run. Layed down total of 7 stands esterda and toda . 00:15 00:45 0.50 8,763 8,828 COMPZ CASINC PUTB P PU Ram hanger, MU inner string, MU to liner. PU wt 100k, SO wt 125k. 00:45 01:30 0.75 8,828 9,200 COMPZ CASINC RUNL P Run 4-1/2" "D" lateral liner on 5" drill pipe. Note: with stand # 2 picked up(prior to exit diverter): PU wt 130k, SO wt 100k, rot @ 35 rpm w/ 4000 ft Ib torque, rot @ 45 rpm w/ 4000 ft Ib torque, 110k rot wt. Note: with stand # 4 picked up(in open hole 9200'}: PU wt 130k, SO wt t00k, rot @ 35 rpm w/ 4000 ft Ib torque, rot @ 45 rpm w/ 4000 ft Ib torque, 112k rot wt. Page 29 of 44 • Time Lo s Date Fram To Dur S: De th E. De th Phase Gode Subcode T COM 05/12/2007 01:30 06:00 4.50 9,200 14,058 COMPZ CASINC RUNL P Continue to run in hole w/ 4-1/2" slotted liner on 5"drill pipe. Record PU and SO wt's every 5 stands, record torque every 10 stands.. Fill pipe every 25 stands or 10 stands to maintain weight. @ 14058': PU wt 180k, So wt 80K, rot wt 125k. No rotation required to this point, with 55 stands of 5"drill i e. 06:00 11:00 5.00 14,058 17,868 COMPZ CASINC RUNL P Rotate 4-1/2" slot/blank "D" lateral liner in the hole. Record PU and SO wt's every 10 stands. Record torque. Ran in hole stand # 95 and 41' in on #96. Note: Torque was 17k prior to reaching this oint, for ued u to 23k ft lbs. 11:00 12:00 1.00 17,868 17,868 COMPZ CASINC OTHR P Obtain PU and SO wt's prior to attempting to run through diverter and land. PU wt 242k, SO wt 85k, Rot wt 169k. Rotating up 195k, Rotating down 165k. Made several attempts to land. Decision made to POOH and look at tool for any indications why it would not. Suspicion of 7" x 4.5" crossover assembly hanging up on diverter. 12:00 14:15 2.25 17,868 17,868 COMPZ CASINC CIRC T Circulate bottom's up. (top slot @ 9202'). After CBU a small amount of gas back to surface. Circulated until well was static before tripping out of hole. Could not get liner hanger to final osition sh b 38.32' . 14:15 14:30 0.25 17,868 17,868 COMPZ CASINC OTHR T Monitor well. Static. 14:30 18:00 3.50 17,868 13,963 COMPZ CASIN OTHR T POOH w/ 4-1/2" slotted/ blank 11.6 ppf liner with Baker RAM liner hanger. Hole took ro er dis lacment. 18:00 20:15 2.25 13,963 8,828 COMPZ CASINC OTHR T Continue to POOH w/ 4-1 /2" slotted/ blank 11.6 ppf liner with Baker RAM liner hanger. Calculated displacment 86.4, actual 92.5 bbls. 20:15 20:45 0.50 8,828 8,765 COMPZ CASIN OTHR T Look at Baker RAM hanger and crossover under same. Analyze scarrin and re-veri dimensions. 20:45 22:45 2.00 8,765 8,765 COMPZ CASINC WOOR T Waiting on decision. While waiting: service top drive, crown, and drawworks. Clean out drip pan under drawworks and rig floor. Check h draulic lines under ri floor for leaks. 22:45 23:45 1.00 8,765 8,827 COMPZ CASINC OTHR T Lay down and change 7" Hydril pup and 7" x 4-1/2" hydril crossover under hanger. Install 7" crossover to 5-1/2" hydril, then 5-1/2" Hydril pup, then crossover to 4-1/2" h dril. Page 30 of 41 C~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/12!2007 23:45 00:00 0.25 8,827 9,018 COMPZ CASINC RUNL T RIH w/ liner on 2 stands of 5" drill pipe. Obtain PU, SO wt's. PU 135k, SO 90k, Rotate @ 30 rpm w/ 5000 ft Ib torque (Torque limit set at 5000 ft Ib), with rotatin wei ht of 112k. 05/13/2007 00:00 00:30 0.50 9,018 9,102 COMPZ CASIN RUNL T Trip in hole w/ "D"lateral finer on 5" dp. Tag up on diverter of seal bore diverter @ 9102'. Set down 10k f/ 90k to 80k, PU w/ 5k overpull f/ 135k to 140k. RiH and tag again with same 10k down wei ht loss and 5k over ull. 00:30 00:45 0.25 9,102 9,018 COMPZ CASINC OTHR T POOH one stand of 5" drill pipe. Decision made to POOH w/ 4-1/2" "D" lateral liner assembly, then more than likely run the plop and drop liner s stem. 00:45 02:15 1.50 9,018 9,018 COMPZ RIGMN SVRG T Slip and cut 119' of 1-3/8" drilling line. 02:15 02:30 0.25 9,018 8,827 COMPZ CASINC OTHR T POOH 5"drill pipe to Baker RAM liner han er f! the "D" lateral. 02:30 03:45 1.25 8,827 8,780 COMPZ CASINC OTHR T Lay down Baker RAM liner hanger. La down 4-1/2" inner strip . 03:45 04:30 0.75 8,780 8,780 COMPZ CASINC RURD T Change out GBR tongs, rig up to lay down 4-1/2" 11.6 ppf slot and blank, h dril 521 and BTC liner f/ "D"lateral. 04:30 04:45 0.25 8,780 8,780 COMPZ CASINC SFTY T Pre job safety meeting on laying down 4-1/2" liner. 04:45 06:00 1.25 8,780 8,320 COMPZ CASINC OTHR T Rig up to lay down and lay down 10 jts of 4-1/2" 11.6 ppf L-80 Hydril 521" liner to the pi a shed. 06:00 18:00 12.00 8,320 0 COMPZ CASINC OTHR T Continue to lay down 4-1/2" 11.6 ppf L-80 Hydril 521" liner to the pipe shed. Note: A total of 7 stop rings for the 4-1 /2" were not accounted for while ullin out of the hole with the liner. 18:00 18:30 0.50 0 0 COMPZ CASINC OTHR T Clear and clean rig floor. 18:30 19:00 0.50 0 0 COMPZ CASIN< OTHR T Continue to clean rig floor. Retrieve Haggard ID wiper f/ inside of 4-1/2" liner shoe 'oint. 19:00 19:15 0.25 0 0 COMPZ FISH SFTY T Pre job safety meeting on running in the hole w/ Baker retrieving tool for the seal bore diverter. 19:15 19:45 0.50 0 22 COMPZ FISH PULD T PU/MU Baker FJD running tool for the seal bore diverter, instal( float sub on to w/ orted float. 19:45 00:00 4.25 22 7,819 COMPZ FISH TRIP T RIH w/ Baker running tool on 5"drill pipe. Record PU and SO wt's every 10 stands. Fill i e eve 25 stands. 05/14/2007 00:00 01:00 1.00 7,819 9,020 COMPZ FISH TRIP T Continue RIH w/ FJD diverter running tool to pull the diverter. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. PU wt 235k, SO wt 100k. 01:00 01:45 0.75 9,020 9,020 COMPZ FISH CIRC T CBU while reciprocate 65'. Circulate total of 475 Page 31 of 41 • Tme Logs Date From To Dur S. De th E. De tft Phase Code Subcode T COM 05/14/2007 01:45 02:30 0.75 9,020 9,088 COMPZ FISH CIRC T Continue circ while 5' in to 9088'. Circ another 250 bbls.Recip pipe 65' to just above the diverter to . 02:30 04:45 2.25 9,088 9,103 COMPZ FISH FISH T PU wt 235k, SO wt 110k. Attempt to latch into the top of the diverter assembly with the running tool. Slack off 40k to 70k, Pull up to 235 and over pull to 280-290k and weight dropped off to 235-150k. Wash slot with up to 500 m w/ 2070 si pum ressure. 04:45 06:00 1.25 9,103 7,914 COMPZ FISH TRIP T POOH with running toot. 06:00 08:45 2.75 7,914 0 COMPZ FISH TRIP T Continue to POOH w/ Baker runnin /retievin tool for the diverter. 08:45 09:15 0.50 0 0 COMPZ FISH OTHR T Clean and inspect running tool. Found (1) stop ring wedged in the retieving tool fin er. UD retrievin tool. 09:15 09:45 0.50 0 0 COMPZ FISH OTHR T Clean and clear rig floor. 09:45 10:15 0.50 0 0 COMPZ RIGMN SVRG T Service rig. 10:15 10:45 0.50 0 0 COMPZ FISH PULD T Bring Baker oil tools fishing tools to the rig floor. Stap and obtain OD,ID len the and fishin neck of tools. 10:45 11:30 0.75 0 0 COMPZ FISH PULD T MU fishing tools (magnets) per Baker Oil Tools rep. 11:30 17:00 5.50 0 9,032 COMPZ FISH TRIP T Trip in the hole w/ the magnets. Fill pipe every 25 stands, record PU and SO wt's every 10 stands. Depth 9032': PU wt 150k, SO wt 95k. 17:00 18:00 1.00 9,032 9,082 COMPZ FISH CIRC T Establish circulation then 5 foot in the hole. Circulate bottom's up+ (503 bbls). Rotate 110 rpm w/ 11-13k ft Ib for ue. Rot wt 160k. 18:00 19:30 1.50 9,082 9,082 COMPZ FISH CIRC T Continue to rotate and recip 60' the magnets, while pumping a 50 bbl sweep (9.5 ppg, 100 vis) around and to surface. Pumping 600 gpm w/ 2170 psi. No increase in cutttings. Rotate 110 rpm w/ 9-10k ft Ib torque. With um son: PU wt 205k, SO wt 120k. 19:30 20:30 1.00 9,102 9,116 COMPZ FISH OTHR T PU wt 218k, SO wt 130k, Rot wt 170k rotating 30 rpm w/ 10k ft Ibs of torque. Work down 70' in on stand # 96 to 9102' (Ramp of diverter) without pumps on. Took weight. Rotate 30 rpm w/ torque limit set @ 12k ft Ib (normal torque 10k). Worked down to 9105', then free @ 9105'. Shut off rotary. Continue to slack off to 9116', (83' in on stand # 96) (2' below bottom of the window @ 9114'). PU with no restriction or extra dra . Page 32 of d1 • ~~ Time Lo s Date From To ©ur S. De th E. De th Phase Code Subcode T COM 05/14/2007 20:30 00:00 3.50 9,116 4,310 COMPZ FISH TRIP T PU to 9032'. POOH with magnet assembly. Perform ROPE test of choke manifold while POOH. Witness of BOPE test waived by AOGCC ins ector John Crisp. 05/1512007 00:00 02:30 2.50 4,310 76 COMPZ FISH TRIP T PU to 9032'. POOH with magnet assembly. Perform BOPE test of choke manifold while POOH. Witness of BOPE test waived by AOGCC inspector John Crisp. 02:30 03:30 1.00 76 0 COMPZ FISH PULD T Pull magnets to the floor. Clean magnets. Recovered 4 halves of stop rin s. La down ma nets. 03:30 04:00 0.50 0 0 COMPZ WELCT OTHR P Clean and clear rig floor.. Rig up to pull wear bushin .Pull wear bushin . 04:00 04:30 0.50 0 0 COMPZ WELCT OTHR P Rig up to test BOPE. 04:30 07:45 3.25 0 0 COMPZ WELC BOPE P Two week BOPE test (witness of test waived by AOGCC inspector John Crisp). Test upper pipe rams (variable 3-1 /2" x 6") and annular to 250 psi and 3000 psi with a 4-1/2" test joint. Test upper rams w/ 5" test joint. Test floor safety valves and top drive valves, kill and choke. Accumulator test. 07:45 08:45 1.00 0 0 COMPZ WELCT OTHR P Rig down test equipment. Blow down choke and kill lines and top drive. Install Vetco Gray Wear bushing 3.17' long, 9" ID, 13-3/8" OD. Hold wear bushin w/ 2 lockdown screws. 08:45 09:15 0.50 0 0 COMPZ RIGMN SVRG P Service drawworks ,top drive and crown 09:15 09:45 0.50 0 0 COMPZ FISH PULD T Clear rig floor of fishing tools not needed. 09:45 10:30 0.75 0 138 COMPZ FISH PULD T PU/MU Baker FJD runninglretrieving tool, make up float sub, 1 joint of 5" drill pipe. Make up top drive and pump. Tool released @ 450 gpm w/ 102 psi. PU/MU Bum er sub and 'ars. 10:30 16:00 5.50 138 9,072 COMPZ FISH TRIP T RIH w/ retrieving tool on 5"drill pipe. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands.PU wt 200k, SO wt 110k. Calculated displacement 86.3 bbls, actual dis lacement 79 bbls. 16:00 17:15 1.25 9,072 9,072 COMPZ FISH CIRC T Circulate bottom's up. Reciprocate 30'. Monitor well, bubbling, continue to circualte. Circulate a total of 735 bb1s. 17:15 17:30 0.25 9,072 9,102 COMPZ FISH FISH T Five foot in the hole. Attempt to engage diverter running/retieving tool into the diverter. PU wt 218k, SO wt 138k. Slack off and set down to 100k, PU to 340k (120k overpu-I to pull diverter free). Gained string pu wt now 225k 7k wei ht increase . 17:30 18:00 0.50 9,072 9,072 COMPZ WELC OWFF T Monitor well, static. Page 33 of ~1 l J ~~ Time Logs Date From To Dur S. De `th E. De th Phase Code Subcode T COM 05/15/2007 18:00 00:00 6.00 9,072 123 COMPZ FISH TRIP T POOH w/diverter retrieving tool and diverter assembly. Last stand of drill i e out of the hole midni ht. 05/16/2007 00:00 00:30 0.50 123 123 COMPZ FISH RURD T RU GBR to break and lay down Baker RAM assembl . 00:30 02:15 1.75 123 0 COMPZ FISH PULD T Break and lay down messed up Baker RAM diverter and running tool. Retrieved a total of 2 stop rings in pieces. Also recovered some formation in the diverter below the opening. Note: Two stop rings still unaccounted for. 02:15 02:45 0.50 0 0 COMPZ FISH OTHR T Rig down GBR tongs. Clear and clean ri floor. 02:45 03:15 0.50 0 0 COMPZ FISH PULD T PU tools for cleanout run to the rig floor. 03:15 04:30 1.25 0 50 COMPZ FISH PULD T MU BHA for reverse circ basket and magnets and junk baskets to clean out to packer f/ the "B" lateral. Packer 9167.28'. 04:30 08:45 4.25 50 9,090 COMPZ FISH TRIP T Trip in the hole w/ 5"drill pipe and BHA to clean out to the top of the "B" lateral packer. Calculated siplacment 85 bbls, actual 78.5 bbls. Aty 9090' PU wt 215k, So wt 135k 08:45 10:00 1.25 9,090 9,090 COMPZ FISH CIRC T Circulate bottom's up (the window is @ 9097'-9114') while recip 90' .Pump total of 704 bbls. 10:00 11:45 1.75 9,090 9,090 COMPZ FISH CIRC T Drop a 1"ball and pump bpm w/ 630 psi. Ball on seat @ 1250 strokes. Now with reverse cirulation @ the basket, pump with 2700 psi. Five foot in to final depth of 9175' with this tally (Liner tally depth is 9167.28'). Set down 5k on liner top. Continue to reverse circ at the basket and POOH to 9090'. Shut down um s. 11:45 12:00 0.25 9,090 9,090 COMPZ FISH OTHR T Monitor well. Static. 12:00 16:30 4.50 9,090 50 COMPZ FISH TRIP T Pull out of the hole to Baker fishing assembly. Calculated fill 86 bbls, actual fill 97 bbls. 16:30 16:45 0.25 50 50 COMPZ FISH OTHR T Inspect reverse junk basket and the junk baskets for recovery. Found 2 halves and a hinge of stop rings, also pieces (large) of formation. Reverse basket was full. Emptied contents into a halve of a 5 gal bucket. Pictures were taken. Note: All except one 4-1I2" stop ring. has been recovered and accounted for from the initial RAM liner run. 16:45 18:00 1.25 50 0 COMPZ FISH PULD T Lay down BHA and clear floor of Baker fishin tools. 18:00 18:30 0.50 0 0 COMPZ CASIN( RURD T Lay Baker frshing tools off the floor. Page 3A of 41 ~ i Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T COM 05/16/2007 18:30 19:00 0.50 0 0 COMPZ RIGMN SVRG T Service rig and grease crown. Lay Baker fishin tools off the floor. 19:00 20:45 1.75 0 0 COMPZ CASINC RURD T Rig up to run "D" lateral 4-1l2" slotted liner Plo and Dro 20:45 21:00 0.25 0 0 COMPZ CASINC SFTY T PJSM on running "D" lateral 4-1/2" slotted liner Pto and Dro 21:00 00:00 3.00 0 4,798 COMPZ CASINC RNCS T PU/MU/RIH w/ "D" lateral 4-1/2" slotted liner (Plop and Drop). Install 4-1/2" x 6 1/8" Hydraoform centralizers on all slots. Start taking PU and SO wt's @ jt # 60, then every 10 'ts. 05/17/2007 00:00 03:45 3.75 4,798 8,620 COMPZ CASINC RNCS T MU/RIH w/ "D" lateral 4-1/2" slotted liner (Plop and Drop). Install 4-1/2" x 6 1/8" Hydraoform centralizers on all slots. Start taking PU and SO wt's @ 't # 60, then eve 10 ~ts. 03:45 04:15 0.50 8,620 8,620 COMPZ CASINC RURD T Rig down GBR tongs and tools. 04:15 04:45 0.50 8,620 8,700 COMPZ CASINC RUNL T PU/MU first stand of 5" Drill pipe. Obtain PU (123k) and SO (95k) wt's. Rotating wt 107k. Rotate @ 35 rpm w/ 4700 ft Ib torque. Rotate @ 45 rpm w/ 5000 ft Ib torque. While rotating: PU wt 112k, SO 102k. 04:45 05:30 0.75 8,700 9,220 COMPZ CASINC RUNL T Continue RIH w/4-1/2" Plop and Drop liner f/the "D" lateral on 5"drill pipe. Record PU and SO wt's per Rig engineer. Record PU and SO above the window on stand # 5: PU 130k, SO 98k. Continue in the hole exiting the window and going into the "D" lateral. 05:30 06:00 0.50 9,220 10,237 COMPZ CASINC RUNL T Continue RIH w/ 4-1 /2" Plop and Drop liner f/ the "D" lateral on 5"drill pipe. Record PU and SO wt's per Rig en ineer. 06:00 07:00 1.00 10,237 11,198 COMPZ CASINC RUNL T Continue RIH w/4-1/2" Plop and Drop liner f/the "D" lateral on 5" drill pipe. Fill pipe @ 10500', 50 spm (210 gpm w/ 380 psi. Tag up @ 11198' 1J-135L1 PB1 f/ 11825' to 11190') Record PU and SO wt's per Rig en ineer. 07:00 08:00 1.00 11,198 11,380 COMPZ CASINC RUNL T POOH f/ 11198' to 10710'. Work 180 deg of torque into string, work 60' down and up, twice. Then RIH w/ liner on 5" drill pipe. Went into the right hole. 08:00 12:00 4.00 11,380 14,146 COMPZ CASINC RUNL T Continue RIH w/ 4-1 /2" Plop and Drop liner f/ the "D" lateral on 5" drill pipe. Fill pipe every 20 stands pumping 210 gpm w/ 450 psi. Lost all down weight @ 14146'.Record PU and SO wt's per Rig engineer. Rotating 45 rpm w/ 10-11 k ft Ib torque. Rotatin wt 130k, PU wt 190k. Page 35 of 41 n • ~ Time Logs Date From fio Dur S. De th E. De th Phase Code Subcode T COM 05/17/2007 12:00 16:30 4.50 14,146 17,906 COMPZ CASINC RUNL T Continue RIH by rotating 4-1/2" Plop and Drop liner on 5"drill pipe. Fill pipe every 20 stands pumping 210 gpm w/ 450 psi. Record PU and SO wt's every 5 stands. Rotating 45 rpm w! 10-11k ft Ib torque to final torque on bottom of 19k. . Rotating wt 130k to final of 152k, PU wt 190k to final of 250k. 16:30 18:00 1.50 17,906 17,923 COMPZ CASINC RUNL T Continue RIH by rotating 4-1/2" Plop and Drop liner on 5" drill pipe. Pumping 210 gpm w/ 450 psi. Rotating 45 rpm w/ 19k ft Ib torque. Rotating wt 152k, PU wt 250k. Five foot in to tag bottom @ 17935', PU to set liner top @ 9308'. Drop and pump 29/32" ball @ 4bpm w/ 480 psi. Ball on seat w/ 1825 strokes. Pressure to 3500 psi, then slack off to 100k, PU to 235k (3 times) running tool is free from liner. PU 5' and pressure to 4000 spi to blow ball seat. OK. Monitor well. 18:00 18:45 0.75 17,923 8,900 COMPZ CASINC OTHR T POOH to 8900' 18:45 20:30 1.75 8,900 8,900 COMPZ CASINC CIRC T Circulate bottom's up. Pumping 370 gpm w/ 870 psi. Circulate a total of 722 bbls. 20:30 21:00 0.50 8,900 8,900 COMPZ CASINC OTHR T Monitor well. OK. Blow down top drive. 21:00 00:00 3.00 8,900 3,518 COMPZ CASIN OTHR T Pull out of the hole with Baker liner running tool f/ the Plop and drop "D" lateral liner. 05/18/2007 00:00 01:45 1.75 3,518 30 COMPZ CASINC OTHR T Continue to pull out of the hole with Baker liner running tool f/ the Plop and drop "D" lateral liner. 01:45 02:00 0.25 30 0 COMPZ CASINC OTHR T Lay down Baker running tools. 02:00 02:15 0.25 0 0 COMPZ CASINC OTHR T Clear and clean rig floor. 02:15 03:30 1.25 0 0 COMPZ CASINC OTHR T Rig up to run Hook Hanger assembly (tri #2). 03:30 04:30 1.00 0 226 COMPZ CASINC OTHR T MU Hook hanger assembly till ready for the inner strip 04:30 06:30 2.00 226 226 COMPZ CASIN OTHR T PU/Run inside of Hook Hanger assembly the Sperry Sun MWD, make up cup and 2-3/8" 4.6 ppf, hydril 511, L-80 s aceout tubin 06:30 06:45 0.25 226 226 COMPZ CASINC OTHR T PU Baker B-1 Hook Hanger, MU inner strip to the hook han er. 06:45 07:00 0.25 226 226 COMPZ CASINC OTHR T Make hook hanger up to assembly below. Check MWD orientation to the Baker hook han er. 07:00 08:00 1.00 226 360 COMPZ CASIN RUNL T Run in the hole one stand, make a top drive connection. Record PU wt of 85k, SO wt 85k. Page 36 of 41 • Time Los Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/18/2007 08:00 08:30 0.50 360 360 COMPZ CASINC CIRC T Pump to shallow test Sperry MWD. Pumping 130 gpm w/ 660 psi. Good detection. 08:30 14:00 5.50 360 9,267 COMPZ CASIN( RUNL T RIH w/ Baker Hook hanger (Trip #2) assembl on 5" drill ipe. 14:00 16:15 2.25 9,267 9,352 COMPZ CASINC RUNL T Five foot in to 9352. Pickup 10'. Break circulation to see what Sperry MWD indicates. Hook Baker B-1 9-5/8" x 7" hook hanger on the bottom of the window (hooked @ 9114.84')with the mule shoe 9352.43'. 16:15 18:30 2.25 9,352 9,352 COMPZ CASIN OTHR T Drop the 29/32" ball, circ @ 3bpm w/ 920 psi, after 120 bbls stow to 2bpm w/ 490 psi. Ball was on seat after pumping 198 bbls. Increase pressure f/ 1000 psi in stages to 1500, 2000, 2200, 2400, 2600 psi. No Shear @ 2600 psi. Increase to 2700 psi, shear valve and inflate ECP w/ 2 strokes, pressure bled back to 2300 psi. Pressure back up to 2700 psi w/ 2 strokes, bled back to 1500 psi, increase to 2600 psi w/ 3 strokes. Pressure bled backto 1500 psi. Pressure back up to 2600 psi w/ 3 strokes and not hoding pressure after pumping a total of 10 strokes (1 bbl). Attempt to blow ball seat w/ 4200 psi. Stop pumping, bleed off all pressure with the tool released from the hook hanger. PU wt 230k, no drag or indication of moving the hook assembl . SO wt 115k. 18:30 23:15 4.75 9,352 174 COMPZ CASIN OTHR T POOH with the Hook Hanger running tools and inner strip . 23:15 23:45 0.50 174 174 COMPZ CASINC OTHR T Rig up and lay down running tools and inner strip . 23:45 00:00 0.25 174 60 COMPZ CASINC OTHR T Lay down running tools f/ the hook han er. 05/19/2007 00:00 00:45 0.75 60 0 COMPZ CASINC OTHR T Finish laying down running tools for the hook han er. 00:45 01:15 0.50 0 0 COMPZ CASINC OTHR T Remove hook hanger handling tools and inner strip tools from the floor. 01:15 02:30 1.25 0 7 COMPZ DRILL PULD T Rig up floor to MU BHA. MU 8-1l2" reverse circulating basket, bit sub with a float. 02:30 06:45 4.25 7 9,093 COMPZ DRILL TRIP T Trip in the hole with the BHA on 5"drill pipe. Fill pipe every 20 stands. Tag the top of the hook hanger @ 9093', set 12k on the to . 06:45 08:45 2.00 9,092 9,063 COMPZ DRILL CIRC T Pick up, make a top drive connection, PU 30' above hook hanger top and circulate. Circulate a total of 730 bbls. 08:45 09:00 0.25 9,063 9,063 COMPZ DRILL OWFF P Monitor well. Install stripping rubbers. Page 37 of 41 • Time Los Date From To Dur S. De th E. De th Phase Code Subcode T COM 05!19/2007 09:00 09:30 0.50 9,063 9,063 COMPZ DRILL CIRC P Pump a ZO bbls dry job (9.5 ppg), break connection and drop the Haggard ID wiper (Mud dog). Blow down the to drive. 09:30 12:00 2.50 9,063 6,940 COMPZ DRILL PULD P Pull out of the hole laying down 5"drill pipe. A total of 33 joints of 5" HWDP and 33 joints of 5"drill pipe. Monitor well on the trip tank. 12:00 13:15 1.25 6,940 5,135 COMPZ DRILL PULD P Pull out of the hole laying down 5"drill pipe. A total of 57 joints of 5" drill pipe altogether. Monitor well on the trip tank. 13:15 14:15 1.00 5,135 8,082 COMPZ DRILL TRIP P Run in hole with 31 stands of 5" drill i e from the derrick. 14:15 17:00 2.75 8,082 5,023 COMPZ DRILL PULD P Pull out of the hole laying down 5" drill pipe. A total of 195 joints of 5" drill pipe altogether. Monitor well on the tri tank. 17:00 18:30 1.50 5,023 5,023 COMPZ RIGMN SVRG P Slip and cut 18 wraps of 1-3/8" drilling line. 18:30 19:30 1.00 5,023 5,023 COMPZ RIGMN SVRG P Service drawworks, topdrive and blocks. 19:30 22:00 2.50 5,023 5,023 COMPZ RIGMN RGRP T Locate and repair a Glycol leak on the d rawworks. 22:00 22:30 0.50 5,023 5,023 COMPZ DRILL SFTY P Pre job safety meeting on pulling out of the hole and laying down the 5" drill i e. 22:30 00:00 1.50 5,023 3,225 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5" drill i e. 05/20/2007 00:00 03:00 3.00 3,225 682 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5"drill pi e. 03:00 04:15 1.25 682 682 COMPZ RIGMN RGRP T Repair link tilt "U" bolt clamp attatched to the bales. 04:15 06:30 2.25 682 682 COMPZ DRILL OTHR P Remove 41 joints of 4-1/2" completion tubing from the pipe shed. Re strap 168 joints on bottom row. Monitor well on tri tank. 06:30 08:30 2.00 682 7 COMPZ DRILL PULD P Continue pulling out of the hole laying down 5" drill pi e. 08:30 08:45 0.25 7 0 COMPZ DRILL PULD P Lay down BHA. Clear floor of BHA Reverse basket w/ 8-1/2" OD shoe. 08:45 09:15 0.50 0 0 COMPZ DRILL OTHR P C-ear floor of BHA (Reverse basket w/ 8-1/2" OD shoe. 09:15 09:45 0.50 0 0 COMPZ RPCOh RURD P Rig up 4-1/2" Tubing equipment. 09:45 10:15 0.50 0 0 COMPZ RPCO SFTY P Pre job safety meeting on Picking up/making up/ RIH w/ 4-1 /2" 12.6 ppf, L80, IBT-m tubin . 10:15 18:00 7.75 0 7,200 COMPZ RPCOh PULD P PU/MU/RIH w/ 4-1/2" completion tubing wi mule shoe on the bottom to 7200'. Total of 234 ~ts 18:00 23:00 5.00 7,200 0 COMPZ RPCOh TRIP P Pull out and stand back the 4-1/2" completion tubing. Install new seal rin sin the boxes of 'oints broke out. Page 38 of ~1 C~ ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/20/2007 23:00 23:30 0.50 0 0 COMPZ RPCOh OTHR P UD mule shoe, clean and clear rig floor. Shut blind rams. Calculated fill 33 bbls, actual 42 bbls. 23:30 00:00 0.50 0 0 COMPZ RPCOfi OTHR P Drain stack, pull Vetco Gray wear bushin . 05/21/2007 00:00 00:30 0.50 0 0 COMPZ RPCOA RURD P Rig up tools f/ completion. 00:30 00:45 0.25 0 0 COMPZ RPCOA SFTY P Pre job safety meeting on Picking up perforated pump intake w/ pup, 2 joints of 4-1/2" 12.6 ppf IBT tubing, 4-1/2" pup jt, discharge sub, 4-1/2" pup jt. Picking up and installing pump w/wireline. Testin . 00:45 01:30 0.75 0 91 COMPZ RPCOh PULD P Pick up perforated pump intake w/ pup, MU 2 joints of 4-1/2" 12.6 ppf IBT tubing, 4-1 /2" pup jt, discharge sub, 4-1/2" pu 't. 01:30 01:45 0.25 91 91 COMPZ RPCOh PULD P Set Pump eye, gas seperator and FC 6000 um inside of tubin . 01:45 03:30 1.75 91 91 COMPZ RPCOh SLKL P RU HOWCO slickline. MU crossover, 2-7/8" spacer pup, bow spring and hanger receptical to lower section, RIH and set. POOH, RIH w/ D & D packoff, Kobe knockout, and check valve. Distance f/ FN to Kobe knock out is 36", Distance f/ FN to check valve is 86". Overall of packoff is 100.5". Set on top of ump. POOH. 03:30 03:45 0.25 91 91 COMPZ RPCOh RURD P RU to test with water and rig test ump. 03:45 04:15 0.50 91 91 COMPZ RPCOh DHEO P Test to 1000 psi. lost 100 psi in 15 min. Decision to make test tool run. Ri down test equi ment. 04:15 05:00 0.75 91 91 COMPZ RPCOti SLKL P HOWCO slickline RIH w/ D&D test tool. POOH. RU test equipment. test to 1000 psi fl 15 min. Lost 50 psi. Rig down test a ui ment. 05:00 05:15 0.25 91 91 COMPZ RPCOti SLKL P HOWCO slickline RIH w/ 4-1/2 GS, latch tool, POOH. RIH w/tubing slip sto and set. POOH wireline. 05:15 05:30 0.25 91 91 COMPZ RPCOh RURD P Rig down HOWCO slickline. 05:30 05:45 0.25 91 0 COMPZ RPCOh TRIP P POOH w/ stand, check rotation of um . OK. 05:45 08:00 2.25 0 0 COMPZ RPCOh RURD P RU ESP sheave, stage tools and clam s on ri floor. 08:00 08:30 0.50 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on running com letion. 08:30 11:00 2.50 0 51 COMPZ RPCOh PULD P PU motor, fill with oil, install capillary tube f/ A-well senost ti dischar a sub. 11:00 11:30 0.50 51 51 COMPZ RPCO OTHR P Test ESP cable at the reel in spooling unit. Good. 11:30 13:45 2.25 51 143 COMPZ RPCOh PULD P MU pump assembly to motor. Install bands and clam s. I Page 39 of 41 l~ Time Logs Date Fram To Dur S. De th E. De th Phase Cade Subcode T COM 05/21/2007 13:45 18:00 4.25 143 3,563 COMPZ RPCOh RCST P MU/RIH with 4-1/2" completion, installing clamps. Test cable every 10 stands. 18:00 23:15 5.25 3,563 7,508 COMPZ RPCOh RCST P MU/RIH with 4-1/2" completion, installing clamps. Test cable ever 10 stands. 23:15 00:00 0.75 7,508 7,508 COMPZ RPCOh PULD P PU Vetco Gray hanger and landing ~oint. 05/22/2007 00:00 01:00 1.00 7,508 7,508 COMPZ RPCOh PULD P MU Vetco Gray hanger and orient to wellhead. Install penetrator, Check ESP cable @ reel. Install pigtail on pentetrator. Cut ESP cable. Rig up to s lice cable to pi tail. 01:00 04:30 3.50 7,508 7,508 COMPZ RPCOh OTHR P Splice ESP round cable (1.39" OD to flat i tail. 04:30 05:30 1.00 7,508 7,508 COMPZ RPCOh OTHR P Plug pigtail into penetrator. Make electrical checks. Install band above and below splice. Note: Total of 12 1-1 /4" stainlesss steel bands applied on the ESP completion. 212 Canon across the collar clamps, 3 protectorlizer guards (1 mtr and 2 pum uard , 2 flat uards. 05:30 06:00 0.50 7,508 7,549 COMPZ RPCOh HOSO P Run in hole and land. PU wt 140k, SO wt 95k, Blocks 70k. Crew Chan e 06:00 07:15 1.25 0 0 COMPZ RPCOh NUND P Blow down all lines. Put! and lay down landing joint. Rig up and install BPV as er Vetco Gra re . 07:15 11:15 4.00 0 0 COMPZ RPCOh NUND P ND flowline, flow nipple, and all Iines.Remove Koomey lines and nipple down SOP stack. remove a!I tubing runnin a ui ment from ri floor. 11:15 11:45 0.50 0 0 COMPZ RPCOh OTHR P perform continuity test on ESP pigtail and penetrator as per centrilift rep. SIMOPS: Cleanin its. 17:45 13:15 1.50 0 0 COMPZ RPCOh NUND P Niupple up vetco Gray 5k tree. Instal! TWC. Test tree to 250 / 5000 PSI - 15 minutes. Pull TWC. Continue cleaning its. 13:15 13:45 0.50 0 0 COMPZ RPCOI~ FRZP P Rig up Little Red services for freeze rotectin well. 13:45 14:00 0.25 0 0 COMPZ RPCOR SFTY P Held PJSM with crew & Little red. Discuss safety & hazard recognition issues. Desi Hates ill cham ion. 14:00 18:00 4.00 0 0 COMPZ RPCOh FRZP P Pump freeze protect diesel down annulus with returns through choke and poorboy degasser. Initially pump at rates of up to 2 BPM with 100% losses. Slow pump to 1 BPM for 100% returns @ 500 PSI. Continue pumping displacing out SFMOBM. Crew Chan e Page 40 of 41 l ~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/22/2007 18:00 23:15 5.25 0 0 COMPZ RPCOh FRZP P Continue displace well with freeze protect diesel at 1 BPM - 550 PSI. Increase rate gradually up to 2 BPM - 575 PSI when diesel in the tubing, with 100% returns. Total pumped = 600 BBLS with FCP @ 510 PSI. Total losses while pumping = 25 BBLS. Shut in valves on tree. 23:15 00:00 0.75 0 0 COMPZ RPCOh FRZP P Vac out all lines and rig down Little Red services. Blow down all lines including choke manifold and degasser. Rig down all lines including choke line. 05!23/2007 00:00 02:30 2.50 0 0 COMPZ MOVE DMOB P Continue cleaning pits. Demob rig for move. Move change house. Remove Rockwasher. Rig Released @ 0400 HRS 02:30 04:00 1.50 0 0 COMPZ RPCOh OTHR P Continue install BPV with Lubricator as per Vetco Gray reps. Rig down Lubricator. Shut in pressures = OA - 250PS1, IA - 490 PSI, Tubing - 490 PSI. Page 41 a€ 41 ~~TT~+ g~ ~~t~gB~AT ~®Y ~e ~D+~+rl$r ~T 1~-7~~~~iY®li i~®~~~-7-71®1` Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ~AR61ff PALIId, GO!/ERIdOR 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, 1J-135 ConocoPhillips Alaska, Inc. Permit No: 207-038 Surface Location: 1583' FSL, 2287' FEL, SEC. 35, T 11 N, R 1 OE, UM Bottomhole Location: 1759' FSL, 766' FWL, SEC. 13, T10N, R10E, 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 an~ required test, contact the Commission's petroleum field inspector at (907)' %~-3607 (pager). T7 x~. DATED this ~P day of March, 2007 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 Email: Randy.L.Thomas@conocophillips.com March 14, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, i1-135, iJ-135 L1 Dear Commissioners: ~~~ i~ ~® MAt2 ~ 4 2007 Alaska Oii ~. Gas Cons. Commission _ knchorage ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producing well, a dual lateral horizontal well in the West Sak °B"and °D" sands. The main bore of the well will be designated 1J-135, and the lateral bore of the well will be designated 1J-135L1. 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 iJ-135 is April 5th, 2007. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, { Randy Thomas Greater Kuparuk Area Drilling Team Leader RE~EiO/ED STATE OF ALASKA ~ ~'~j M~~ g ~ 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.oos Anchoarage 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-135 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: i MD: 17907' TVD: 3532' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1583' FSL, 2287' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ,~~` ZSL4 / 8C ADL 25662& 380058 D ,(6 °~ West Sak Oil Pool Top of Productive Horizon: 1152' FNL, 824' FWL, Sec. 12, T10N, R10E, UM ~ 8. Land Use Permit: ALK 2177 & 4604 13. Approximate Spud Date: 4/5/2007 Total Depth: 1759' FSL, 766' FWL, Sec. 13, T10N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: > 1 mile '' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558926 ' y- 5945397 ' Zone- 4 10. KB Elevation ~,..q~ fMSG b,p? (Height above GL): 28' RKB feet 15. Distance to Nearest ~ Well within Pool: 1J-103L2 , 14T @ 1381 16. Deviated wells: Kickoff depth: 400 ~ ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) Downhole: 1565 psig '" Surface: 1165 psig ' 1 S. Casing Program ecification S Setting Depth Quantity of Cement Size p s Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3511' 28' 28' 3511' - 2221' - 670 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10200' 28' 28' 10200' ~ 3639' 840 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 8481' 9428' • 3570' - 17907' slotted liner 3 ~~ ~bbi•/v-~~ 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ' 1 ~`~~ J Phone w3 G ~ 3~ Date 3 ~('~ Per 7 h n All D k MJ Commission Use Only Permit to Drill Number: ~~ 7- ~ ~ API Number: /^~ 50- ~ G+~ ` 2331' '~fJ Permit Approval Date: ~ _ "~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedrm~ethane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No U Mud log req'd: Yes ^ No [/]~ Other: ~~ ,` ~~~ ~s~~ H2S measures: Yes ^ N ~ cti nal svy req'd: Yes [/]~ No ^ 1 ~ ~ APPROVED BY THE COMMISSION DATE:3~! ~~ ,COMMISSIONER Form 10-401 Revised 12/2005 v ( / Submit in Duplicate v ~~f ~, a, ~~.07 tion for Permit to Drill, Well 1 J-135 Revision No.O Saved: 14-Mar-07 Permit It -West Sak Well #1J-135 .., Application for Permit to Drill Document ~'~ ,~,,,i x m i II W~_II V41~/4 Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ............................................................................................................. 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 .................................................. 3 Requirements of 20 AAC 25.005 (c)(5) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI YersaPro Mineral Oid Base) B, D sand laterals .................................................... 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)(I1) ...................................................................................................... 5 1J-135 PERMIT IT Page 1 of 7 Printed: 14-Mar-07 Aation for Permit to Drill, Well 1 J-135 Revision No.O Saved: 14-Mar-07 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 q .f ()( ) ...................................................................................................... Re uirements o 20 AAC 25.005 c 13 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 2 Directional Plan .................................................................................................................. 7 Attachment 3 Drilling Hazards Summary ................................................................................................... 7 Attachment 4 CemCADE Summary ............................................................................................................. 7 Attachment S Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (fJ Each well must be identified by a ~unigue name designated by the operator mid a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unigue name and API number by adding a suffix to the ~uime designated for the well by the operator and to the number assigned to the well 6y the commission. The well for which this Application is submitted will be designated as 1J-135. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (2) a plat ident~ing the property and the property's owners and shoi~~ing (A)the coordinates of the proposed location of the well at the surface, at die top of each objective fonnadon, and at total 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 in 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 1,584' FSL, 2,287' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,397 Eastings: 558,926 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 1,152' FNL, 824' FWL, Section 12, T10N, R10E Sak "B" Sandl ASP Zone 4 NAD 27 Coordinates Northings: 5,937,407 Eastings: 562,107 Measured De th, RKB: 10,25 ; Total Vertical De th, RKB: 3,634 Total Vertical Depth, SS: 3,513 Location at Total Depth 1,759' FSL, 766' FWL, Section 13, T10N, R10E ' Measured De th, RKB: 17,907 ASP Zone 4 NAD 27 Coordinates 116 62 Total Vertical De th, RKB: 3,532 , Northings: 5,929,759 Eastings: 5 Total Vertical Depth, SS: 3,411 and (D) ether i~~ormation required by 20 AAC 25.050(b), 1J-135 PERMIT IT Page 2 of 7 Printed: 14-Mar-07 • ~ation for Permit to Drill, Well 1J-135 Revision No.O Saved: 14-Mar-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Forrn 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, mid show that each named operator has been fi~naished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application 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 ident0ed in the application: (3) a diagram and description of the blowoutprevention equipment (BOPS) as required by 20 AAC 2.035, 20 AAC 25.036, or 20 AAC 2.1.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-135. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident0ed in the application: (4) information on drilling ha_ards, including (A) the nuzximum downhole pressure that may be encountered, criteria used to determine it, and maa;imum potential surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-135 area is 0.43 psi/ft, or 8.3 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,165 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,640'. The MPSP is: MPSP = (3,640 ft)(0.43 - 0.11 psi/ft) =1,165 psi (B) data on potential gas =ones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation =ones, and pones that have a propensity for differential sticking; Please see Attachment 2: 1J-135 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the follown~g items, exceptfor m2 item already on file with the commission and identified in the application: (~) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; 1J-135 will be completed with 9-5/8" casing landed at the top of the West Sak "B" 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. 1J-135 PERMIT IT Page 3 of 7 Printed: 14-Mar-07 • ation for Permit to Drill, Well 1 J-135 Revision No.O Saved: 14-Mar-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An application for a Permit to Drill must be accompanied by each of the fodlrnving items, except for an item already on file with the commission and identtfted in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of arty slotted liner, pre perforated liner, or screen to be installed,• ~.--~°`""~ Casing and Cementing Program See also Attachment 3: Cement Summary i , ~ `~ Hole Top Btm Size Weight Length MD/TVD MD/TVD in) (lb/ t Grade Connection t t) t Cement Pro am 40" 62 5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf . ArcticCRETE Cemented to Surface with 16" 68 L-80 BTC 3,511 28' / 28' 3,511' / 2,221' 670 sx AxcticSet Lite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 5,496' 12-1/4" 40 L-80 BTCM 10,200 28' / 28' 10,200' / 3,639' MD / 2,736' TVD. Cemented w/ 840 sx Dee CRETE 8-1/2" B Sand Lateral 15.5 L-80 BTCM 481 8 9,428' / 3,570' 17,909' / 3,532' Slotted- no cement (1J-180) , -3/4" D Sand Lateral 11.6 L-80 BTCM 8 578 9,328' / 3,564' 17,906' / 3,469' Slotted- no cement slotted (1J-180 Ll) , 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 already on file with the commission and ident~ed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 2~. 03~ (h) (2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 135. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 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 fide with the commission and ident~ed in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid svstem, as reguired by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (pp~ 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 (cP Plastic Viscostty 20-45 20-45 15-20 15-20 (rb/IOO s~ pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 (cc / 30 min)) *9.6 ppg if hydrates aze encountered 1J-135 PERMIT IT Page 4 of 7 Printed: 14-Mar-07 Intermediate Hole Mud Program (LSND) 13-3/8"Casing Shoe to Intermediate Casing Point Initial Value Densi ( ~ 9.0-9.4 Funnel Viscosity 45-60 (seconds) Plastic Viscostty 12-18 (Ib/100 s~ Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/l) <500 pH 9.0-9.5 MBT <20.0 ~ation for Permit to Drill, Well 1J-135 Revision No.O Saved: 14-Mar-07 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Density ( ~ 8.4 - 8.6 Plastic Viscostty 15-25 (lb/1 DO s~ Yield Point 18.28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical >600 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 application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.033(fl; 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 accompmaied by each of the following items, except for an item already ora file with the conunission acrd identfied in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(I1) An application for a Permit to Drill must be accompanied by each of the follrnving items, except for an item already on f le with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom fou~rded structure, jack-up rig, or floaiing drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except forma item already on file i+~ith the commission and identfied in the application: (12) evidence showing that the reguirernents of 20 AAC 25.02) {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for ar, item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. iJ-135 PERMIT IT Page 5 of 7 Printed: 14-Mar-07 ~ation for Permit to Drill, Well 1J-135 Revision No.O Saved: 14-Mar-07 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,511' MD / 2,221' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, 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). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 10,200' MD / 3,639 TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 5,496' MD / 2,736' TVD (500' above Ugnu formation). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 6-3/4" 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 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation ~`~ ~~ integrity test to leak off, recording results. ~~' 14. Directionally dri118-1/2" hole to TD at +/- 17,909' MD / 3,532' TVD as per directional plan. II ~~~ 15. POOH, back reaming out of lateral. POOH. 16. PU and run 5-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 9,428' MD / 3,570' TVD. POOH. Note: Remaining operations are covered under the 1J--135 Ll Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 9,328' MD / 3,564' TVD, the top of the "D" sand. 19. Mi118-1/2" window. POOH. 20. Pick up 4-3/4" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 17,906' MD / 3,469' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool, POOH, laying down drill pipe as required. 27. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 28. Nipple down BOPE, nipple up tree and test. Pull BPV. 1J-135 PERMIT IT Page 6 of 7 Printed: 14-Mar-07 ~ation for Permit to Drill, Well 1 J-135 Revision No.O Saved: 14-Mar-07 29. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 30. Set BPV and move rig off. 31. Rig up wire line unit. Pull BPV. 32. Set gas lift valves in mandrels. Use ESP to clean up well. 33. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on ftle with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud mid cuttings and a statement of whedzer the operator intends to request azAthori_ation under 20 AAC 2.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-135 PERMIT IT Page 7 of 7 Printed: 14-Mar-07 • ConocoPhillips Alaska • Plan: 1J-135 (wp07) Sperry Drilling Services Proposal Report -Geographic 13 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-135 D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) N s True API - US Survey Feet HAL~..tE3lJR't"O Sperry Drftling Ssrvlcss HALLIBURTON Drilling Sarvieea FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1523.45 1402.35 1619.42 Pfrost 2 1663.46 1542.36 1811.35 T3 3 1989.78 1868.68 2615.87 K15 4 2207.16 2086.06 3455.76 Casing Pt 5 2869.53 2748.43 6014.96 Ugnu C 6 3129.13 3008.03 7017.98 Ugnu B 7 3193.59 3072.49 7267.03 Ugnu A 8 3374.78 3253.68 8210.15 K 13 9 3544.80 3423.70 9322.72 W Sak D 10 3585.52 3464.42 9677.55 W Sak C 11 3619.05 3497.95 9974.79 W Sak B ~~'/ g J• -500 ~_ 1500 2000 a 2500 N 3000 U ~ 3500 N 4000 5500 ~ CASING DETAILS No MD TVD TVDss Name Sir I 3455.76 2207.16 2086.06 l3 3/8" I ~-. 2 10256.73 3634.38 3513.28 95/8" 9-Si8 3 17904.79 3532.65 3411.55 41/2" 4-IQ SHL - 1584' FSL, 2287' FEL - Sec35-T11 N-R10E ~ 0° 13 3/8" Csg @ 3456' MD, 2207' ND - 293' FNL, 1432' FEL - Sec02-T10N-R10E 500 1000 '500 o Top Pump Tangent 7285' MD, 3198' ND g 5/8" Csg. @ 10257' MD, 3640' ND - 1152' FNL, 824' FWL - Sec12-T10N-R10E - T3•ost- -- ryp0 t° ~ N oo° O ~ ~~ BHL - 17908' MD, 3533' TVD - 1759' FSL, 766' FWL - Sec13-T10N-R10E - ~ ,~ , ~ o ~ End Pump Tangent 7485' MD, 3250' ND -K15 ----?+s-g--o---------------~- -- ----- --------------------------- o O ~ -Casing Pt------- --`~- a -0--6- -~------- ----- -- ------- -------------------------------------- h h O h ~ O i O O ~ co h ~ ' -UgnuC-------- --------- -- co--~~~ :o°- o ------- -~------- --- ----~- o ----- --'FJ-935L1~wpQ7 - U nu 8 - - - - - - - - - - - - - - - - - - - - - - - - / ^~ -~ - ~- O O ~- - - - 1 ~ - - - . C C C - _ - C C - _ _ - = C C ~ - o- - C C - - - - - r - C C - g -UgnuA~----------------------- --- -eu--$--~- ° --~---------- --- -- -- --------- ------ -K13_--WSakD_-------------------------------- - - - -- ___- -- -- - =____ W Sak B 1 J-135 Top D (wp06) _ _ - - ~ ~ , ,°o ~ 0 0 1J-135 MB_B CP1 (01/31/2007) ' 1J-135 MB_B CP2 (01/31/2007) , 1J-135 MB_B CP3 (01/31/2007) 1J-135 MB B CP4 (01/31!2007) ~ 1J-135 MB_B CP6 0 0 0 0 ,' o o ' 9 ~ o o '0 0 0~~ , o o ,'o ~ i 1 J-135 (wp07) i , ~~ ~ ~ ' 4 1/2" ~ i i i '~ ~ , ~ i ~ i ~ i ~ i 1J-135 MB_B CP5 (01/31/2007) 1J-135 WELL DETAILS: Plan U-135 Ground Level. S1.I0 +N/-S +E/-W Nonhing P.asling Latittude Longitude Slot 0.00 0-00 594539709 558926.15 70°IS'41.IOSN 149°31'25.162W 07) ,' 1J-135 MB_B CP8 (01/31/206) 1J-135 MB_B Toe (01/31/2007) CP7 (01/31/2007) 1J-135 MB_8 CP9 (01/31/2007) -500 0 500 1000 1500 2000 2500 3000 3500 4000 1500 5000 5500 6000 6500 .000 7500 &000 8500 9000 9500 10000 10500 11000 11500 1200012500 13000 13500 14000 14500 15000 15500 16000 16500 Vertical Section at 180.00° (1750 ff/in) ~ ConocoPhillips Aiaska HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: Plan IJ-135 Site: Kuparuk 1J Pad Ground Level: 81.10 Sperry Drilling Services Well: Plan 1J-135 +N/-s +E/-w Northing Fasting Lati[tnae Longitude slot Wellbore: Plan 1 J-135 0.00 0.00 5945397.09 558926.15 70°15'41.108N 149°31'25.162W Plan: 1 J-135 (wp07) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-135, True North Vertical (rVD) Reference: D16 (40+61.1) ~ 121.1 Ofl (D15 (40+81.1)) 1000 Measured Depth Reference: D15 (40+61.1) @ 121.tOfl (D16 (40+61.1)) Calculation Methotl: Minimum Curvature 500 SHL-1584'FSL, 2287 FEL-Sec35-TlIN-RlOE 0 25~ ~'~ CASING DETAILS No MD TVD TVDss Name Size -500 ~'15~ 1 3455.76 2207.16 2086.06 13 3/8" 13-3/8 2 10256.73 363438 3513.28 9 5/8" 9-5/8 3 17904.79 3532.65 3411.55 41/2" 4-1/2 -1000 Qpo 'L 13 3/8" Csg @ 3456' MD, '_20T Tb'D - 293' FNL, 1432' FEL - Sec02-TI ON-Rl OE -1500 ___---~ \ ,~ ~ -2000 ~ ti'SU ~Q( -2500 S+ - 1~~~ -3000 X55 -3500 ,~2go -4000 -4500 .SDO~ Top Pump Tangent 7285' MD, 3198' TVD -5000 , Sp _ _ _ End Pump Tangent 7485' MD, 3250' TVD "~'---- -5500 Aga -6000 ~.5° ~ -6500 3500 O -7000 11-I?5 Top D (wp06 _ _ _ _ _ _ 80° O OV -7500 I I-135 MB_B CPI (O1i31/?007 ~ - - - - - 180° ~ -8000 IJ-135 MB B CP2 (01/3 U2007 _ _ _ _ _ _ ~ - - - 9 5/8" Csg. ~ 10257 MD, 3640' TVD - 1152' FNL, 824' FWL - Sec12-TI ON-Rl OE O - ~ -8soo 180° ,~ 1J-135 MB_B CP3 (01:31/2007 _ _ _ _ _ _ o -9000 180° -9500 IJ-1;5'`.1[3 B CP4 (OP31C00', _ _ _ _ _ _ -10000 180° -10500 I1-135 V1B B CP5101 31 ^_007 _ _ _ _ _ _ -11000 -11500 180° I1-125 A11313 CPC 10131."007______ -12000 -12500 180° -13000 IJ-135 MB_B CP7 (01/31/'007 _ _ _ _ _ -13500 180° -14000 n-135 >a3 B crs (ol 31 cool _ _ _ _ _ -14500 180° T M Azimuths to True North -15000 Magnetic North: 24.54° I]-135 ~16_B CI'9 (0131,'_007 _ _ _ _ _ _ 4 I/2" Magnetic Field -15500 IJ-135'vf6_B Toe (Ol i1i3007 _ _ _ _ _ ~ _ " Strength: 57578.OnT ~ ~ - - - - _ _ _ Dip Angle: 80.72° -16000 r BHL - 17908' MD, 3533' TVD - 1759' FSL, 766' FWL-Sec] 3-TlON-RIOE Date: 11/18/2004 • Model: BGGM2004 I]-135 (wp07) -16500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 1100011500 West(-)/East(+) (2000 ft/in) ~ Conocol'hillips Alaska • COttOC{?~'il~~lp5 Alaska Halliburton Company Planning Report -Geographic • Sperry Qrilliir~g ServCcea Database: Compass 2003.11 Local Co-ordinate Reference: -Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: K.uparuk 1J Pad North Reference: .True - Well: Plan 1J-135 Survey Calculation Method: 'Minimum Curvature - Wellbore: Flan 1J-135 Design: 1J-135 (~~,1~07) Project Kupanik P.iver Unit, North Slope Alaska. U nited States Map System: Geo Datum: US State Plane 1927 (Exact solution) - NAD 1927 (NADCON CONUS) System Datum: Mean Sea Level ~ Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-135 Well Position +N/-S 0.00 ft Northing: 5,945,397.09 ft Latitude: 70° 15' 41.108" N +E/-W 0.00 ft Easting: 558,926.15 ft ' Longitude: 149° 31' 25.162" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.10ft ~ Wellbore P!an 1J-135 Magnetics Model Name Samplo Date bggm2004 t 1I12i2004 Declination f°1 24.54 Dip Angle Field Strength (°) (nT) ft0. ~ 2 57.5 ~ 3 Design 1J-135,wp0+~ Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +NI-S"''' +E!-W Direction (ft) (n) (n) l°1 40.00 0.00 0.00 180.00 3/13/2007 7:21:39PM Page 2 of 11 COMPASS 2003.11 Build 48 '~-'' Halliburton Company H~-L~IBtJRTt~I'V ~~~~~~ Planning Report -Geographic ~~~.~ oritti~g g~ervie~s Database: Compass 2003.11 Local Co-ordinate Reference: ~"Jell Plan 1J-135 Company: ConocoPhillips Alaska, Inc. TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: `'-' Minimum Curvature Wellbore: Plan 1J-135 Design: iJ-135 (wp07) Plan Summary l Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_S +E/-W Rate Rate Rate TFO (ft) (~) (~) (ft) (ft) (ft) (°1100ft) (°/100ft) (°I100ft) (~) 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 i 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 790.00 11.00 175.00 787.30 -41.95 3.67 2.50 2.50 0.00 175.00 1,040.00 20.92 170.16 1,027.38 -109.85 13.40 4.00 3.97 -1.94 -10.00 1,240.00 28.56 164.44 1,208.91 -191.23 32.36 4.00 3.82 -2.86 -20.00 1,564.20 38.10 148.27 1,480.00 -351.64 106.08 4.00 2.94 -4.99 -50.00 1,614.20 38.10 148.27 1,519.35 -377.88 122.30 0.00 0.00 0.00 0.00 2,359.61 75.00 154.83 1,923.46 -918.48 406.49 5.00 4.95 0.88 10.50 7,484.98 75.00 154.83 3,250.00 -5,398.99 2,512.39 0.00 0.00 0.00 0.00 7,684.30 80.90 153.82 3,291.60 -5,574.57 2,596.82 3.00 2.96 -0.50 -9.57 8,459.18 80.90 153.82 3,414.17 -6,261.21 2,934.38 0.00 0.00 0.00 0.00 9,322.72 82.00 180.00 3,544.80 -7,085.47 3,125.74 3.00 0.13 3.03 89.59 9,375.23 83.52 180.41 3,551.42 -7,137.56 3,125.56 3.00 2.90 0.77 14.83 10,005.50 83.52 180.41 3,622.51 -7,763.79 3,121.12 0.00 0.00 0.00 0.00 10,256.73 91.06 180.41 3,634.38 -8,014.56 3,119.33 3.00 3.00 0.00 0.03 10,444.73 91.06 180.41 3,630.90 -8,202.52 3,117.99 0.00 0.00 0.00 0.00 10,595.28 89.56 180.45 3,630.09 -8,353.06 3,116.86 1.00 -1.00 0.03 178.35 11,085.80 89.56 180.45 3,633.90 -8,843.55 3,112.97 0.00 0.00 0.00 0.00 11,225.84 90.96 180.44 3,633.28 -8,983.57 3,111.88 1.00 1.00 -0.01 -0.48 11,985.97 90.96 180.44 3,620.60 -9,743.58 3,106.02 0.00 0.00 0.00 0.00 12,121.65 92.31 180.40 3,616.73 -9,879.19 3,105.03 1.00 1.00 -0.03 -1.90 13,143.94 92.31 180.40 3,575.50 -10,900.63 3,097.96 0.00 0.00 0.00 0.00 13,211.04 91.64 180.40 3,573.19 -10,967.69 3,097.49 1.00 -1.00 0.00 179.99 14,244.48 91.64 180.40 3,543.60 -12,000.68 3,090.34 0.00 0.00 0.00 0.00 14,388.06 90.21 180.35 3,541.29 -12,144.23 3,089.40 1.00 -1.00 -0.03 -178.15 15,443.59 90.21 180.35 3,537.50 -13,199.74 3,082.94 0.00 0.00 0.00 0.00 15,467.91 89.96 180.39 3,537.46 -13,224.05 3,082.79 1.00 -0.99 0.14 171.80 16,343.66 89.96 180.39 3,538.00 -14,099.79 3,076.90 0.00 0.00 0.00 0.00 16,352.39 90.00 180.31 3,538.00 -14,108.52 3,076.85 1.00 0.40 -0.92 -66.21 17,543.74 90.00 180.31 3,538.00 -15,299.85 3,070.50 0.00 0.00 0.00 0.00 17,641.98 90.98 180.29 3,537.16 -15,398.09 3,069.99 1.00 1.00 -0.02 -0.97 17,907.81 90.98 180.29 3,532.60 -15,663.88 3,068.65 0.00 0.00 0.00 0.00 3/13/2007 7:21:39PM Page 3 of 11 COMPASS 2003.11 Build 48 • Ccxx~c©illips pdaska Halliburton Company Planning Report -Geographic • HALt_~ Bl.~RT01V Sperry Drilling Servlcea Database: Compass 2003.11 Local Co-ordinate Reference: 'Well Plan 1J-135 Company: ~;onocoPhillips Alaska, Inc. TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+g1.1)) Site: Kuparuk 1J Pad North Reference: 'True Well: Plan 1J-135 Survey Calculation Method: 'Minimum Curvature Wellbore: flan 1J-135 Design: 1J-135 (wp07) Planned Survey 1J-135 (vdp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) Iftl lft) lft) (ft) (ft) (°/100ft) (ft) 40.00 0.00 0.00 40.00 -81.10 0.00 0.00 5,945,397.09' 558,926.15 0.00 0.00 SHL -1584' FSL, 2287' FEL - Sec35-T11 N-R10E 100.00 0.00 0.00 100.00 -21.10 0.00 0.00 5,945,397.09 558,926.15 0.00 0.00 200.00 0.00 0.00 200.00 78.90 0.00 0.00 5,945,397.09 558,926.15 0.00 0.00 300.00 0.00 0.00 300.00 178.90 0.00 0.00 5,945,397.09 558,926.15 0.00 0.00 350.00 0.00 0.00 350.00 228.90 0.00 0.00 5,945,397.09 558,926.15 0.00 0.00 ~ 400.00 1.25 175.00 400.00 278.90 -0.54 0.05 5,945,396.55 558,926.20 2.50 0.54 500.00 3.75 175.00 499.89 378.79 -4.89 0.43 5,945,392.21 558,926.62 2.50 4.89 600.00 6.25 175.00 599.50 478.40 -13.57 1.19 5,945,383.53 558,927.44 2.50 13.57 700.00 8.75 175.00 698.64 577.54 -26.57 2.32 5,945,370.54 558,928.68 2.50 26.57 790.00 11.00 175.00 787.30 666.20 -41.95 3.67 5,945,355.18 558,930.15 2.50 41.95 800.00 11.39 174.65 797.11 676.01 -43.88 3.85 5,945,353.24 558,930.34 4.00 43.88 900.00 15.35 172.12 894.38 773.28 -66.84 6.58 5,945,330.31 558,933.26 4.00 66.84 1,000.00 19.33 170.60 989.82 868.72 -96.29 11.10 5,945,300.90 558,938.00 4.00 96.29 1,040.00 20.92 170.16 1,027.38 906.28 -109.85 13.40 5,945,287.35 558,940.41 4.00 109.85 1,100.00 23.19 168.07 1,082.98 961.88 -131.97 17.68 5,945,265.28 558,944.86 4.00 131.97 1,200.00 27.02 165.34 1,173.52 1,052.42 -173.22 27.50 5,945,224.10 558,955.00 4.00 173.22 1,240.00 28.56 164.44 1,208.91 1,087.81 -191.23 32.36 5,945,206.14 558,960.01 4.00 191.23 1,300.00 30.16 160.78 1,261.21 1,140.11 -219.28 41.17 5,945,178.16 558,969.03 4.00 219.28 1,400.00 33.01 155.42 1,346.40 1,225.30 -267.79 60.78 5,945,129.81 558,989.02 4.00 267.79 1,500.00 36.06 150.85 1,428.78 1,307.68 -318.29 86.45 5,945,079.52 559,015.08 4.00 318.29 1,564.20 38.10 148.27 1,480.00 1,358.90 -351.64 106.08 5,945,046.32 559,034.96 4.00 351.64 1,600.00 38.10 148.27 1,508.17 1,387.07 -370.43 117.69 5,945,027.63 559,046.73 0.00 370.43 1,614.20 38.10 148.27 1,519.35 1,398.25 -377.88 122.30 5,945,020.22 559,051.39 0.00 377.88 1,619.42 38.36 148.34 1,523.45 1,402.35 -380.63 124.00 5,945,017.48 559,053.11 5.00 380.63 Pfrost 1,700.00 42.32 149.43 1,584.86 1,463.76 -425.29 150.93 5,944,973.04 559,080.39 5.00 425.29 1,800.00 47.26 150.56 1,655.80 1,534.70 -486.29 186.13 5,944,912.32 559,116.06 5.00 486.29 1,811.35 47.82 150.68 1,663.46 1,542.36 -493.58 190.24 5,944,905.06 559,120.22 5.00 493.58 T3 1,900.00 52.21 151.53 1,720.42 1,599.32 -553.05 223.04 5,944,845.86 559,153.49 5.00 553.05 2,000.00 57.16 152.37 1,778.21 1,657.11 -625.04 261.38 5,944,774.17 559,192.38 5.00 625.04 2,100.00 62.12 153.13 1,828.75 1,707.65 -701.73 300.85 5,944,697.80 559,232.46 5.00 701.73 2,200.00 67.08 153.82 1,871.63 1,750.53 -782.54 341.17 5,944,617.32 559,273.40 5.00 782.54 2,300.00 72.04 154.46 1,906.55 1,785.45 -866.83 382.02 5,944,533.36 559,314.90 5.00 866.83 2,359.61 75.00 154.83 1,923.46 1,802.36 -918.48 406.49 5,944,481.90 559,339.78 5.00 918.48 2,400.00 75.00 154.83 1,933.91 1,812.81 -953.79 423.09 5,944,446.73 559,356.65 0.00 953.79 2,500.00 75.00 154.83 1,959.79 1,838.69 -1,041.21 464.18 5,944,359.65 559,398.41 0.00 1,041.21 2,600.00 75.00 154.83 1,985.67 1,864..57 -1,128.63 505.26 5,944,272.56 559,440.18 0.00 1,128.63 2,615.87 75.00 154.83 1,989.78 1,868.68 -1,142.50 511.78 5,944,258.75 559,446.81 0.00 1,142.50 K15 2,700.00 75.00 154.83 2,011.56 1,890.46 -1,216.04 546.35 5,944,185.48 559,481.95 0.00 1,216.04 2,800.00 75.00 154.83 2,037.44 1,916.34 -1,303.46 587.44 5,944,098.39 559,523.71 0.00 1,303.46 2,900.00 75.00 154.83 2,063.32 1,942.22 -1,390.88 628.53 5,944,011.31 559,565.48 0.00 1,390.88 3,000.00 75.00 154.83 2,089.20 1,968.10 -1,478.30 669.61 5,943,924.22 559,607.25 0.00 1,478.30 3,100.00 75.00 154.83 2,115.08 1,993.98 -1,565.72 710.70 5,943,837.13 559,649.01 0.00 1,565.72 3/13x1007 7:21:39PM Page 4 of 11 COMPASS 2003.11 Build 48 • Conc~coPhitlips Alaska Halliburton Company Planning Report -Geographic • Sp®rry OMllir~g Servio~ Database: Compass 2003.11 Local Co-ordinate Reference: \'Jell Plan 1J-135 Company: ConocoPhillips Alaska, Inc. TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 ' Survey Calculation Method: f:^inimum Curvature Wellbore: Plan 1J-135 Design: 1J-135 (vrp07) Planned Survey 1J-1?5 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft1 (ftl 3,200.00 75.00 154.83 2,140.97 2,019.87 -1,653.14 751.79 5,943,750.05 559,690.78 0.00 1,653.14 3,300.00 75.00 154.83 2,166.85 2,045.75 -1,740.55 792.88 5,943,662.96 559,732.54 0.00 1,740.55 3,400.00 75.00 154.83 2,192.73 2,071.63 -1,827.97 833.96 5,943,575.88 559,774.31 0.00 1,827.97 3,455.76 75.00 154.83 2,207.16 2,086.06 -1,876.71 856.87 5,943,527.32 559,797.60 0.00 1,876.71 13 318" Csg @ 3456' MD, 2207' TVD - 293' FNL, 1432' FEL - Sec02-T10N -R10E -Casi ng Pt -13 318" 3,500.00 75.00 154.83 2,218.61 2,097.51 -1,915.39 875.05 5,943,488.79 559,816.08 0.00 1,915.39 3,600.00 75.00 154.83 2,244.49 2,123.39 -2,002.81 916.14 5,943,401.71 559,857.84 0.00 2,002.81 3,700.00 75.00 154.83 2,270.37 2,149.27 -2,090.23 957.23 5,943,314.62 559,899.61 0.00 2,090.23 3,800.00 75.00 154.83 2,296.26 2,175.16 -2,177.64 998.32 5,943,227.54 559,941.38 0.00 2,177.64 3,900.00 75.00 154.83 2,322.14 2,201.04 -2,265.06 1,039.40 5,943,140.45 559,983.14 0.00 2,265.06 4,000.00 75.00 154.83 2,348.02 2,226.92 -2,352.48 1,080.49 5,943,053.37 560,024.91 0.00 2,352.48 4,100.00 75.00 154.83 2,373.90 2,252.80 -2,439.90 1,121.58 5,942,966.28 560,066.68 0.00 2,439.90 4,200.00 75.00 154.83 2,399.78 2,278.68 -2,527.32 1,162.67 5,942,879.20 560,108.44 0.00 2,527.32 4,300.00 75.00 154.83 2,425.67 2,304.57 -2,614.74 1,203.75 5,942,792.11 560,150.21 0.00 2,614.74 4,400.00 75.00 154.83 2,451.55 2,330.45 -2,702.15 1,244.84 5,942,705.02 560,191.97 0.00 2,702.15 4,500.00 75.00 154.83 2,477.43 2,356.33 -2,789.57 1,285.93 5,942,617.94 560,233.74 0.00 2,789.57 4,600.00 75.00 154.83 2,503.31 2,382.21 -2,876.99 1,327.02 5,942,530.85 560,275.51 0.00 2,876.99 4,700.00 75.00 154.83 2,529.19 2,408.09 -2,964.41 1,368.10 5,942,443.77 560,317.27 0.00 2,964.41 4,800.00 75.00 154.83 2,555.08 2,433.98 -3,051.83 1,409.19 5,942,356.68 560,359.04 0.00 3,051.83 4,900.00 75.00 154.83 2,580.96 2,459.86 -3,139.24 1,450.28 5,942,269.60 560,400.81 0.00 3,139.24 5,000.00 75.00 154.83 2,606.84 2,485.74 -3,226.66 1,491.37 5,942,182.51 560,442.57 0.00 3,226.66 5,100.00 75.00 154.83 2,632.72 2,511.62 -3,314.08 1,532.45 5,942,095.43 560,484.34 0.00 3,314.08 5,200.00 75.00 154.83 2,658.60 2,537.50 -3,401.50 1,573.54 5,942,008.34 560,526.10 0.00 3,401.50 5,300.00 75.00 154.83 2,684.49 2,563.39 -3,488.92 1,614.63 5,941,921.26 560,567.87 0.00 3,488.92 5,400.00 75.00 154.83 2,710.37 2,589.27 -3,576.34 1,655.72 5,941,834.17 560,609.64 0.00 3,576.34 5,500.00 75.00 154.83 2,736.25 2,615.15 -3,663.75 1,696.80 5,941,747.08 560,651.40 0.00 3,663.75 5,600.00 75.00 154.83 2,762.13 2,641.03 -3,751.17 1,737.89 5,941,660.00 560,693.17 0.00 3,751.17 5,700.00 75.00 154.83 2,788.01 2,666.91 -3,838.59 1,778.98 5,941,572.91 560,734.94 0.00 3,838.59 5,800.00 75.00 154.83 2,813.89 2,692.79 -3,926.01 1,820.07 5,941,485.83 560,776.70 0.00 3,926.01 5,900.00 75.00 154.83 2,839.78 2,718.68 -4,013.43 1,861.15 5,941,398.74 560,818.47 0.00 4,013.43 6,000.00 75.00 154.83 2,865.66 2,744.56 -4,100.84 1,902.24 5,941,311.66 560,860.23 0.00 4,100.84 6,014.96 75.00 154.83 2,869.53 2,748.43 -4,113.92 1,908.39 5,941,298.63 560,866.48 0.00 4,113.92 Ugnu C 6,100.00 75.00 154.83 2,891.54 2,770.44 -4,188.26 1,943.33 5,941,224.57 560,902.00 0.00 4,188.26 6,200.00 75.00 154.83 2,917.42 2,796.32 -4,275.68 1,984.42 5,941,137.49 560,943.77 0.00 4,275.68 6,300.00 75.00 154.83 2,943.30 2,822.20 -4,363.10 2,025.51 5,941,050.40 560,985.53 0.00 4,363.10 6,400.00 75.00 154.83 2,969.19 2,848.09 -4,450.52 2,066.59 5,940,963.32 561,027.30 0.00 4,450.52 6,500.00 75.00 154.83 2,995.07 2,873.97 -4,537.94 2,107.68 5,940,876.23 561,069.07 0.00 4,537.94 6,600.00 75.00 154.83 3,020.95 2,899.85 -4,625.35 2,148.77 5,940,789.14 561,110.83 0.00 4,625.35 6,700.00 75.00 154.83 3,046.83 2,925.73 -4,712:77 2,189.86 5,940,702.06 561,152.60 0.00 4,712.77 6,800.00 75.00 154.83 3,072.71 2,951.61 -4,800.19 2,230.94 5,940,614.97 561,194.37 0.00 4,800.19 6,900.00 75.00 154.83 3,098.60 2,977.50 -4,887.61 2,272.03 5,940,527.89 561,236.13 0.00 4,887.61 7,000.00 75.00 154.83 3,124.48 3,003.38 -4,975,03 2,313.12 5,940,440.80 561,277.90 0.00 4,975.03 7,017.98 75.00 154.83 3,129.13 3,008.03 -4,990.74 2,320.50 5,940,425.15 561,285.41 0.00 4,990.74 Ugnu B 7,100.00 75.00 154.83 3,150.36 3,029.26 -5,062.44 2,354.21 5,940,353.72 561,319.66 0.00 5,062.44 7,200.00 75.00 154.83 3,176:24 3,055.14 -5,149.86 2,395.29 5,940,266.63 561,361.43 0.00 5,149.86 3/132007 7:21:39PM Page 5 of 1 t COMPASS 2003.11 Build 48 Canoc ~,illips Kaska • Halliburton Company Planning Report -Geographic ~A~~~e~R,~o 8per~ry Drilling Ssrvic+u~s Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: ' D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: K:uparuk 1J Pad North Reference: True Well: Flan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 Design: 1J-135 (wp07) Planned Survey 1J-135(wp07) ~~ ~, Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) C°) Ift) (ft) lft) (ft) (ft) (ft) f°I100ft) (ft) 7,267.03 75.00 154.83 3,193.59 3,072.49 -5,208.46 2,422.83 5,940,208.26 561,389.43 0.00 5,208.46 Ugnu A 7,284.98 75.00 154.83 3,198.24 3,077.14 -5,224.15 2,430.21 5,940,192.63 561,396.92 0.00 5,224.15 Top Pump Tangent 7285' MD, 3198' TVD 7,300.00 75.00 154.83 3,202.12 3,081.02 -5,237.28 2,436.38 5,940,179.55 561,403.20 0.00 5,237.28 7,400.00 75.00 154.83 3,228.01 3,106.91 -5,324.70 2,477.47 5,940,092.46 561,444.96 0.00 5,324.70 7,484.98 75.00 154.83 3,250.00 3,128.90 -5,398.99 2,512.39 5,940,018.45 561,480.46 0.00 5,398.99 End Pump Tangent 7485' MD, 3250' TVD 7,500.00 75.44 154.75 3,253.83 3,132.73 -5,412.13 2,518.57 5,940,005.37 561,486.74 3.00 5,412.13 7,600.00 78.40 154.24 3,276.45 3,155.35 -5,500.03 2,560.51 5,939,917.80 561,529.37 3.00 5,500.03 7,684.30 80.90 153.82 3,291.60 3,170.50 -5,574.57 2,596.82 5,939,843.55 561,566.26 3.00 5,574.57 7,700.00 80.90 153.82 3,294.08 3,172.98 -5,588.49 2,603.66 5,939,829.69 561,573.21 0.00 5,588.49 7,800.00 80.90 153.82 3,309.90 3,188.80 -5,677.10 2,647.23 5,939,741.43 561,617.46 0.00 5,677.10 7,900.00 80.90 153.82 3,325.72 3,204.62 -5,765.71 2,690.79 5,939,653.17 561,661.71 0.00 5,765.71 8,000.00 80.90 153.82 3,341.54 3,220.44 -5,854.33 2,734.35 5,939,564.91 561,705.96 0.00 5,854.33 8,100.00 80.90 153.82 3,357.36 3,236.26 -5,942.94 2,777.91 5,939,476.65 561,750.21 0.00 5,942.94 8,200.00 80.90 153.82 3,373.18 3,252.08 -6,031.55 2,821.48 5,939,388.39 561,794.46 0.00 6,031.55 8,210.15 80.90 153.82 3,374.78 3,253.68 -6,040.54 2,825.90 5,939,379.44 561,798.95 0.00 6,040.54 K13 8,300.00 80.90 153.82 3,388.99 3,267.89 -6,120.16 2,865.04 5,939,300.13 561,838.71 0.00 6,120.16 8,400.00 80.90 153.82 3,404.81 3,283.71 -6,208.77 2,908.60 5,939,211.87 561,882.96 0.00 6,208.77 8,459.18 80.90 153.82 3,414.17 3,293.07 -6,261.21 2,934.38 5,939,159.64 561,909.14 0.00 6,261.21 8,500.00 80.91 155.06 3,420.63 3,299.53 -6,297.58 2,951.77 5,939,123.42 561,926.82 3.00 6,297.58 8,600.00 80.95 158.10 3,436.39 3,315.29 -6,388.18 2,991.02 5,939,033.14 561,966.77 3.00 6,388.18 8,700.00 81.02 161.14 3,452.06 3,330.96 -6,480.75 3,025.41 5,938,940.85 562,001.88 3.00 6,480.75 8,800.00 81.12 164.17 3,467.59 3,346.49 -6,575.03 3,054.86 5,938,846.81 562,032.07 3.00 6,575.03 8,900.00 81.24 167.20 3,482.93 3,361.83 -6,670.77 3,079.29 5,938,751.27 562,057.24 3.00 6,670.77. 9,000.00 81.38 170.24 3,498.05 3,376.95 -6,767.70 3,098.62 5,938,654.51 562,077.33 3.00 6,767.70 9,100.00 81.55 173.26 3,512.89 3,391.79 -6,865.56 3,112.81 5,938,556.77 562,092.28 3.00 6,865.56 9,200.00 81.74 176.29 3,527.44 3,406.34 -6,964.07 3,121.81 5,938,458.34 562,102.05 3.00 6,964.07 9,300.00 81.95 179.31 3,541.63 3,420.53 -7,062.97 3,125.61 5,938,359.48 562,106.62 3.00 7,062.97 9,322.72 82.00 180.00 3,544.80 3,423.70 -7,085.47 3,125.74 5,938,336.99 562,106.93 3.00 7,085.47 W Sak D - 1J-135 Top D (wp06) 9,375.23 83.52 180.41 3,551.42 3,430.32 -7,137.56 3,125.56 5,938,284.91 562,107.15 3.00 7,137.56 9,400.00 83.52 180.41 3,554.21 3,433.11 -7,162.17 3,125.38 5,938,260.29 562,107.17 0.00 7,162.17 9,500.00 83.52 180.41 3,565.49 3,444.39 -7,261.53 3,124.68 5,938,160.94 562,107.24 0.00 7,261.53 9,600.00 83.52 180.41 3,576.77 3,455.67 -7,360.89 3,123.97 5,938,061.59 562,107.32 0.00 7,360.89 9,677.55 83.52 180.41 3,585.52 3,464.42 -7,437.95 3,123.43 5,937,984.54 562,107.38 0.00 7,437.95 W Sak C 9,700.00 83.52 180.41 3,588.05 3,466.95 -7,460.25 3,123.27 5,937,962.24 562,107.39 0.00 7,460.25 9,800.00 83.52 180.41 3,599.33 3,478.23 -7,559.61 3,122.57 5,937,862.89 562,107.47 0.00 7,559.61 9,900.00 83.52 180.41 3,610.61 3,489.51 -7,658.97 3,121.86 5,937,763.53 562,107.54 0.00 7,658.97 9,974.79 83.52 180.41 3,619.05 3,497.95 -7,733.28 3,121.34 5,937,689.23 562,107.59 0.00 7,733.28 W Sak B 10,000.00 83.52 180.41 3,62.1.89 3,500.79 -7,758.33 3,121.16 5,937,664.18 562,107.61 0.00 7,758.33 3/13/2007 7:21:39PM Page 6 of 11 COMPASS 2003.11 Build 48 ~-~'' Halliburton Company ~~~~~`~ Planning Report -Geographic HALt,~B~RTt~N 8~'rY Drilling. 8srviaa~s Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ~-onocoPhillips Alaska, Inc. TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: k:uparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 Design: 1J-135 (wp07) Planned Survey 1J-135(\~;p~~) MD Inclination Azimuth TVD SSTVD +N/-S +E!-W (ftl (°) (°) (ftj {ftl (ft) (ft) 10,005.50 83.52 180.41 3,622.51 3,501.41 -7,763.79 3,121.12 10,063.73 85.27 180.41 3,628.20 3,507.10 -7,821.74 3,120.71 1J-135 MB_B Heei (01 /31/2007) 10,081.73 85.81 180.41 3,629.60 3,508.50 -7,839.69 3,120.58 1J-135 MB_B CP1 {01!31/2007) 10,100.00 86.36 180.41 3,630.85 3,509.75 -7,857.91 3,120.45 10,200.00 89.36 180.41 3,634.58 3,513.48 -7,957.83 3,119.74 10,256.73 91.06 180.41 3,634.38 3,513.28 -8,014.56 3,119.33 9 5/8" 10,257.34 91.06 180.41 3,634.37 3,513.27 -8,015.16 3,119.33 9 518" Csg. @ 10257' MD, 3640' TVD -1152' FNL, 824' FWL - Sec12-T10N-R10E 10,300.00 91.06 180.41 3,633.58 3,512.48 -8,057.82 3,119.03 10,400.00 91.06 180.41 3,631.73 3,510.63 -8,157.80 3,118.31 10,444.73 91.06 180.41 3,630.90 3,509.80 -8,202.52 3,117.99 1J-135 MB_B CP2 (01131!2007) 10,500.00 90.51 180.43 3,630.14 3,509.04 -8,257.78 3,117.59 10,595.28 89.56 180.45 3,630.09 3,508.99 -8,353.06 3,116.86 10,600.00 89.56 180.45 3,630.13 3,509.03 -8,357.78 3,116.82 10,700.00 89.56 180.45 3,630.90 3,509.80 -8,457.77 3,116.03 10,800.00 89.56 180.45 3,631.68 3,510.58 -8,557.76 3,115.24 10,900.00 89.56 180.45 3,632.46 3,511.36 -8,657.76 3,114.44 11,000.00 89.56 180.45 3,633.23 3,512.13 -8,757.75 3,113.65 11,085.80 89.56 180.45 3,633.90 3,512.80 -8,843.55 3,112.97 1J-135 MB_B CP3 (01 /3112007) 11,100.00 89.70 180.45 3,633.99 3,512.89 -8,857.75 3,112.86 11,200.00 90.70 180.44 3,633.65 3,512.55 -8,957.74 3,112.08 11,225.84 90.96 180.44 3,633.28 3,512.18 -8,983.57 3,111.88 11,300.00 90.96 180.44 3,632.04 3,510.94 -9,057.73 3,111.31 11,400.00 90.96 180.44 3,630.37 3,509.27 -9,157.71 3,110.54 11,500.00 90.96 180.44 3,628.70 3,507.60 -9,257.69 3,109.77 11,600.00 90.96 180.44 3,627.04 3,505.94 -9,357.67 3,109.00 11,700.00 90.96 180.44 3,625.37 3,504.27 -9,457.66 3,108.22 11,800.00 90.96 180.44 3,623.70 3,502.60 -9,557.64 3,107.45 11,900.00 90.96 180.44 3,622.03 3,500.93 -9,657.62 3,106.68 11,985.97 90.96 180.44 3,620.60 3,499.50 -9,743.58 3,106.02 1J-135 MB_B CP4 (01 /3112007) 12,000.00 91.10 180.44 3,620.35 3,499.25 -9,757.61 3,105.91 12,100.00 92.10 180.40 3,617.56 3,496.46 -9,857.56 3,105.18 12,121.65 92.31 180.40 3,616.73 3,495.63 -9,879.19 3,105.03 12,200.00 92.31 180.40 3,613.57 3,492.47 -9,957.48 3,104.49 12,300.00 92.31 180.40 3,609.54 3,488.44 -10,057.40 3,103.79 12,400.00 92.31 180.40 3,605.51 3,484.41 -10,157.31 3,103.10 12,500.00 92.31 180.40 3,601.47 3,480.37 -10,257.23 3,102.41 12,600.00 92.31 180.40 3,597.44 3,476.34 -10,357.15 3,101.72 12,700.00 92.31 180.40 3,593.41 3,472.31 -10,457.06 3,101.03 Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°I100ft) (ft) 5,937,658.72 562,107.62 0.00 7,763.79 5,937,600.77 562,107.66 3.00 7,821.74 5,937,582.83 562,107.67 3.00 7,839.69 5,937,564.60 562,107.69 3.00 7,857.91 5,937,464.70 562,107.76 3.00 7,957.83 5,937,407.97 562,107.79 3.00 8,014.56 5,937,407.36 562,107.79 0.00 8,015.16 5,937,364.72 562,107.82 0.00 8,057.82 5,937,264.74 562,107.89 0.00 8,157.80 5,937,220.02 562,107.92 0.00 8,202.52 5,937,164.77 562,107.95 1.00 8,257.78 5,937,069.50 562,107.96 1.00 8,353.06 5,937,064.78 562,107.96 0.00 8,357.78 5,936,964.79 562,107.95 0.00 8,457.77 5,936,864.80 562,107.95 0.00 8,557.76 5,936,764.81 562,107.94 0.00 8,657.76 5,936,664.83 562,107.93 0.00 8,757.75 5,936,579.04 562,107.92 0.00 8,843.55 5,936,564.84 562,107.92 1.00 8,857.75 5,936,464.85 562,107.92 1.00 8,957.74 5,936,439.02 562,107.92 1.00 8,983.57 5,936,364.87 562,107.93 0.00 9,057.73 5,936,264.90 562,107.94 0.00 9,157.71 5,936,164.92 562,107.95 0.00 9,257.69 5,936,064.95 562,107.97 0.00 9,357.67 5,935,964.97 562,107.98 0.00 9,457.66 5,935,864.99 562,107.99 0.00 9,557.64 5,935,765.02 562,108.00 0.00 9,657.62 5,935,679.07 562,108.01 0.00 9,743.58 5,935,665.04 562,108.01 1.00 9,757.61 5,935,565.09 562,108.06 1.00 9,857.56 5,935,543.46 562,108.08 1.00 9,879.19 5,935,465.18 562,108.15 0.00 9,957.48 5,935,365.27 562,108.24 0.00 10,057.40 5,935,265.36 562,108.33 0.00 10,157.31 5,935,165.45 562,108.42 0.00 10,257.23 5,935,065.55 562,108.51 0.00 10,357.15 5,934,965.64 562,108.60 0.00 10,457.06 3/13/2007 7:21:39PM Page 7 of 11 COMPASS 2003.11 Build 48 Halliburton Company C0110CQ~11~ Planning Report -Geographic HAl.l..1BURTQIV Sperry OriEling Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Flan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 Design: 1J-135 (wp07) Planned Survey 1J-135 (evp0?) Map Map MD Inclination Azimuth ND SSND +N/-S +EI-W Northing Easting DLSEV Vert Section (ft) l°) (') (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) Iftl 12,800.00 92.31 180.40 3,589.37 3,468.27 -10,556.98 3,100.33 5,934,865.73 562,108.69 0.00 10,556.98 12,900.00 92.31 180.40 3,585.34 3,464.24 -10,656.90 3,099.64 5,934,765.82 562,108.78 0.00 10,656.90 13,000.00 92.31 180.40 3,581.31 3,460.21 -10,756.81 3,098.95 5,934,665.91 562,108.87 0.00 10,756.81 13,100.00 92.31 180.40 3,577.27 3,456.17 -10,856.73 3,098.26 5,934,566.00 562,108.96 0.00 10,856.73 13,143.94 92.31 180.40 3,575.50 3,454.40 -10,900.63 3,097.96 5,934,522.10 562,109.00 0.00 10,900.63 1J-135 MB_B CP5 (01131/2007) 13,200.00 91.75 180.40 3,573.51 3,452.41 -10,956.65 3,097.57 5,934,466.08 562,109.05 1.00 10,956.65 13,211.04 91.64 180.40 3,573.19 3,452.09 -10,967.69 3,097.49 5,934,455.05 562,109.06 1.00 10,967.69 13,300.00 91.64 180.40 3,570.64 3,449.54 -11,056.61 3,096.88 5,934,366.13 562,109.14 0.00 11,056.61 13,400.00 91.64 180.40 3,567.78 3,446.68 -11,156.57 3,096.18 5,934,266.18 562,109.23 0.00 11,156.57 13,500.00 91.64 180.40 3,564.91 3,443.81 -11,256.52 3,095.49 5,934,166.24 562,109.32 0.00 11,256.52 13,600.00 91.64 180.40 3,562.05 3,440.95 -11,356.48 3,094.80 5,934,066.29 562,109.41 0.00 11,356.48 13,700.00 91.64 180.40 3,559.19 3,438.09 -11,456.44 3,094.11 5,933,966.34 562,109.50 0.00 11,456.44 13,800.00 91.64 180.40 3,556.32 3,435.22 -11,556.39 3,093.41 5,933,866.39 562,109.59 0.00 11,556.39 13,900.00 91.64 180.40 3,553.46 3,432.36 -11,656.35 3,092.72 5,933,766.44 562,109.68 0.00 11,656.35 14,000.00 91.64 180.40 3,550.60 3,429.50 -11,756.31 3,092.03 5,933,666.49 562,109.77 0.00 11,756.31 14,100.00 91.64 180.40 3,547.74 3,426.64 -11,856.26 3,091.34 5,933,566.54 562,109.86 0.00 11,856.26 14,200.00 91.64 180.40 3,544.87 3,423.77 -11,956.22 3,090.65 5,933,466.59 562,109.95 0.00 11,956.22 14,244.48 91.64 180.40 3,543.60 3,422.50 -12,000.68 3,090.34 5,933,422.13 562,109.99 0.00 12,000.68 1J-135 MB_B CP6 (01131/2007) 14,300.00 91.09 180.38 3,542.28 3,421.18 -12,056.18 3,089.96 5,933,366.64 562,110.05 1.00 12,056.18 14,388.06 90.21 180.35 3,541.29 3,420.19 -12,144.23 3,089.40 5,933,278.60 562,110.18 1.00 12,144.23 14,400.00 90.21 180.35 3,541.24 3,420.14 -12,156.18 3,089.33 5,933,266.65 562,110.20 0.00 12,156.18 14,500.00 90.21 180.35 3,540.89 3,419.79 -12,256.17 3,088.72 5,933,166.66 562,110.37 0.00 12,256.17 14,600.00 90.21 180.35 3,540.53 3,419.43 -12,356.17 3,088.10 5,933,066.67 562,110.54 0.00 12,356.17 14,700.00 90.21 180.35 3,540.17 3,419.07 -12,456.17 3,087.49 5,932,966.68 562,110.71 0.00 12,456.17 14,800.00 90.21 180.35 3,539.81 3,418.71 -12,556.17 3,086.88 5,932,866.69 562,110.88 0.00 12,556.17 14,900.00 90.21 180.35 3,539.45 3,418.35 -12,656.16 3,086.27 5,932,766.70 562,111.05 0.00 12,656.16 15,000.00 90.21 180.35 3,539.09 3,417.99 -12,756.16 3,085.66 5,932,666.72 562,11.1.22 0.00 12,756.16 15,100.00 90.21 180.35 3,538.73 3,417.63 -12,856.16 3,085.05 5,932,566.73 562,111.39 0.00 12,856.16 15,200.00 90.21 180.35 3,538.37 3,417.27 -12,956.16 3,084.43 5,932,466.74 562,111.56 0.00 12,956.16 15,300.00 90.21 180.35 3,538.01 3,416.91 -13,056.15 3,083.82 5,932,366.75 562,111.73 0.00 13,056.15 15,400.00 90.21 180.35 3,537.66 3,416.56 -13,156.15 3,083.21 5,932,266.76 562,111.91 0.00 13,156.15 15,443.59 90.21 180.35 3,537.50 3,416.40 -13,199.74 3,082.94 5,932,223.17 562,111.98 0.00 13,199.74 1J-135 MB_B CP7 (01 131!2007) 15,467.91 89.96 180.39 3,537.46 3,416.36 -13,224.05 3,082.79 5,932,198.86 562,112.01 1.00 13,224.05 15,500.00 89.96 180.39 3,537.48 3,416.38 -13,256.15 3,082.57 5,932,166.77 562,112.05 0.00 13,256.15 15,600.00 89.96 180.39 3,537.54 3,416.44 -13,356.15 3,081.90 5,932,066.78 562,112.16 0.00 13,356.15 15,700.00 89.96 180.39 3,537.61 3,416.51 -13,456.14 3,081.23 5,931,966.79 562,112.27 0.00 13,456.14 15,800.00 89.96 180.39 3,537.67 3,416.57 -13,556.14 3,080.56 5,931,866.80 562,112.38 0.00 13,556.14 15,900.00 89.96 180.39 3,537.73 3,416.63 -13,656.14 3,079.88 5,931,766.81 562,112.49 0.00 13,656.14 16,000.00 89.96 180.39 3,537.79 3,416.69 -13,756.14 3,079.21 5,931,666.82 562,112.60 0.00 13,756.14 16,100.00 89.96 180.39 3,537.85 3,416.75 -13,856.13 3,078.54 5,931,566.83 562,112.71. 0.00 13,856.13 16,200.00 89.96 180.39 3,537.91 3,416.81 -13,956.13 3,077.87 5,931,466.84 562,112.82 0.00 13,956.13 16,300.00 89.96 180.39 3,537.97 3,416.87 -14,056.13 3,077.19 5,931,366.85 562,112.93 0.00 14,056.13 3/13/2007 7:21:39PM Page 8 of 11 COMPASS 2003.11 Build 48 • ~ ~ " Halliburton Company HAI-LIBtJ~Tt?iV ~ ~ Planning Report -Geographic Sper~t Dritth~g 8,ervEc~s Database: Compass 2003.11 Local Co-ordinate Reference: b^Jell Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D 15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: I<uparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: t,linimum Curvature Wellbore: flan 1J-135 Design: 1J-1~5 (wp071 Planned Survey 1J-135 (wp07) ~~ Map Map MD Inclination Azimuth ND SSND +N/-S +E!-W Northing Easting DLSEV Vert Section (ft1 (°) (°) (ftl (ft) (ft) (ft) lft) (ft) (°/100ft) (ft) 16,343.66 89.96 180.39 3,538.00 3,416.90 -14,099.79 3,076.90 5,931,323.19 562,112.98 0.00 14,099.79 1J-135 MB_B CP8 (01/31/2007) 16,352.39 90.00 180.31 3,538.00 3,416.90 -14,108.52 3,076.85 5,931,314.46 562,113.00 1.00 14,108.52 16,400.00 90.00 180.31 3,538.00 3,416.90 -14,156.13 3,076.59 5,931,266.86 562,113.11 0.00 14,156.13 16,500.00 90.00 180.31 3,538.00 3,416.90 -14,256.13 3,076.06 5,931,166.87 562,113.36 0.00 14,256.13 16,600.00 90.00 180.31 3,538.00 3,416.90 -14,356.12 3,075.53 5,931,066.88 562,113.61 0.00 14,356.12 16,700.00 90.00 180.31 3,538.00 3,416.90 -14,456.12 3,075.00 5,930,966.89 562,113.86 0.00 14,456.12 16,800.00 90.00 180.31 3,538.00 3,416.90 -14,556.12 3,074.46 5,930,866.90 562,114.11 0.00 14,556.12 16,900.00 90.00 180.31 3,538.00 3,416.90 -14,656.12 3,073.93 5,930,766.91 562,114.36 0.00 14,656.12 17,000.00 90.00 180.31 3,538.00 3,416.90 -14,756.12 3,073.40 5,930,666.92 562,114.61 0.00 14,756.12 17,100.00 90.00 180.31 3,538.00 3,416.90 -14,856.12 3,072.86 5,930,566.93 562,114.86 0.00 14,856.12 17,200.00 90.00 180.31 3,538.00 3,416.90 -14,956.12 3,072.33 5,930,466.94 562,115.11 0.00 14,956.12 17,300.00 90.00 180.31 3,538.00 3,416.90 -15,056.11 3,071.80 5,930,366.95 562,115.36 0.00 15,056.11 17,400.00 90.00 180.31 3,538.00 3,416.90 -15,156.11 3,071.27 5,930,266.96 562,115.61 0.00 15,156.11 17,500.00 90.00 180.31 3,538.00 3,416.90 -15,256.11 3,070.73 5,930,166.97 562,115.86 0.00 15,256.11 17,543.74 90.00 180.31 3,538.00 3,416.90 -15,299.85 3,070.50 5,930,123.23 562,115.97 0.00 15,299.85 1J-135 MB_B CP9 {01/31/2007) 17,600.00 90.56 180.30 3,537.72 3,416.62 -15,356.11 3,070.20 5,930,066.98 562,116.12 1.00 15,356.11 17,641.98 90.98 180.29 3,537.16 3,416.06 -15,398.09 3,069.99 5,930,025.00 562,116.23 1.00 15,398.09 17,700.00 90.98 180.29 3,536.16 3,415.06 -15,456.10 3,069.70 5,929,967.00 562,116.39 0.00 15,456.10 17,800.00 90.98 180.29 3,534.45 3,413.35 -15,556.08 3,069.19 5,929,867.03 562,116.67 0.00 15,556.08 17,900.00 90.98 180.29 3,532.73 3,411.63 -15,656.06 3,068.69 5,929,767.05 562,116.95 0.00 15,656.06 17,904.79 90.98 180.29 3,532.65 3,411.55 -15,660.85 3,068.67 5,929,762.26 562,116.96 0.00 15,660.85 4 112" ~ 17,907.81 90.98 180.29 3,532.60 ~ 3,411.50 -15,663.88 3,068.65 5,929,759.24 562,116.97 0.00 15,663.88 BHL -17908' MD, 3533' ND - 1759' FSL, 766' FWL - Sec13-T10N-R10E - 1J-135 MB_B Toe (01/31/2007) 3/13/2007 7:21:39PM Page 9 of 11 COMPASS 2003.11 Build 48 ~-' Halliburton Company ~-[~.LI~-3l.JC~TQR1 ~~~~'~ Planning Report -Geographic g {terry Dritlir,rg Smrvic~s Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: Kuparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Flan 1J-135 Design: 1J-1 s5 (wp07) Geologic Targets Pla~~ 1J-135 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,543.60 1J-135 MB_B CP6 (01/3112007) -12,000.68 3,090.34 5,933,422.13 562,109.99 - Polygon Point 1 0.00 0.00 5,933,422.13 562,109.99 Point2 -1,199.47 -7.40 5,932,223.17 562,111.98 3,620.60 1J-135 MB_B CP4 (01/31/2007) -9,743.58 3,106.02 5,935,679.07 562,108.01 - Polygon Point 1 0.00 0.00 5,935,679.07 562,108.01 Point2 -1,157.28 -8.07 5,934,522.13 562,109.00 3,538.00 1J-135 MB_B CP9 (01/31/2007) -15,299.85 3,070.50 5,930,123.23 562,115.97 - Polygon Point 1 0.00 0.00 5,930,123.23 562,115.97 Point 2 -364.15 -1.85 5,929,759.24 562,116.97 3,544.80 1J-135 Top D (wp06) -7,085.47 3,125.74 5,938,336.99 562,106.93 - Point 3,628.20 1J-135 MB_B Heel (01/31/2007) -7,085.47 3,125.74 5,938,336.99 562,106.93 - Polygon Point 1 0.00 0.00 5,938,336.99 562,106.93 Point 2 -217.02 -1.70 5,938,120.00 562,106.93 3,532.60 1J-135 MB_B Toe (01/31/2007) -15,663.88 3,068.65 5,929,759.24 562,116.97 - Point 3,538.00 1J-135 MB_B CP8 (0113112007) -14,099.79 3,076.90 5,931,323.19 562,112.98 - Polygon Point 1 0.00 0.00 5,931,323.19 562,112.98 Point 2 -1,200.48 -6.40 5,930,123.23 562,115.97 3,575.50 1J-135 MB_B CP5 (01131/2007) -10,900.63 3,097.96 5,934,522.10 562,109.00 - Polygon Point 1 0.00 0.00 5,934,522.10 562,109.00 Point 2 -1,101.02 -7.63 5,933,422.13 562,109.99 3,537.50 1J-135 MB_B CP7 (01131/2007) -13,199.74 3,082.94 5,932,223.17 562,111.98 - Polygon Point 1 0.00 0.00 5,932,223.17 562,111.98 Point2 -900.36 -6.05 5,931,323.19 562,112.98 3,630.90 1J-135 MB_B CP2 (01/31/2007) -8,202.52 3,117.99 5,937,220.02 562,107.92 - Polygon Point 1 0.00 0.00 5,937,220.02 562,107.92 Point 2 -641.11 -5.02 5,936,579.00 562,107.92 3,629.60 1J-135 MB_B CP1 (01131/2007) -7,302.47 3,124.04 5,938,120.00 562,106.93 - Polygon Point 1 0.00 0.00 5,938,120.00 562,106.93 Point 2 -900.20 -6.05 5,937,220.02 562,107.92 3,633.90 1J-135 MB_B CP3 (01/31/2007) -8,843.55 3,112.97 5,936,579.04 562,107.92 - Polygon Point 1 0.00 0.00 5,936,579.04 562,107.92 Point 2 -900.13 -6.95 5,935,679.07 562,108.01 3/13/2007 7:21:39PM Page 10 of 11 COMPASS 2003.11 Build 48 ~' Halliburton Company Ct~OCQPhtll Planning Report -Geographic ~"'~/QL~..~~~RT~N Sperry ~riiiing Ssrvia~ Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-135 Company: ConocoPhillips Alaska, Inc. TVD Reference: `' D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Project: H:uparuk River Unit MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-135 Design: 1J-135 (wp07) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 3,455.76 2,207.16 13-318 16 10,256.73 3,634.38 9-5l8 12-114 17,904.79 3,532.65 4-1i2 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N!-E +E/-W (ft) (°) (°) (ft) (ftl Ift) Namc 1,619.42 313.36 148.34 1,523.45 -380.63 124.00 Pfrost 1,811.35 47.82 150.68 1,663.46 -493.58 190.24 T3 2,615.87 75.00 154.83 1,989.78 -1,142.50 511.78 K15 3,455.76 75.00 154.83 2,207.16 -1,876.71 856.87 Casing Pt 6,014.96 75.00 154.83 2,869.53 -4,113.92 1,908.39 Ugnu C 7,017.98 75.00 154.83 3,129.13 -4,990.74 2,320.50 Ugnu B 7,267.03 75.00 154.83 3,193.59 -5,208.46 2,422.83 Ugnu A 8,210.15 80.90 153.82 3,374.78 -6,040.54 2,825.90 K 13 9,322.72 82.00 180.00 3,544.80 -7,085.47 3,125.74 W Sak D 9,677.55 83.52 180.41 3,585.52 -7,437.95 3,123.43 W Sak C 9,974.79 83.52 180.41 3,619.05 -7,733.28 3,121.34 W Sak B Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W Comment (n) lft) (ft) (ft) 40.00 40.00 0.00 0.00 SHL - 1584' FSL, 2287' FEL - Sec35-T11 N-R10E 3,455.76 2,207.16 -1,876.71 856.87 13 3/8" Csg @ 3456' MD, 2207' TVD - 293' FNL, 1432' FEL - Sec02-T10N-R1 ~ 7,284.98 3,198.24 -5,224.15 2,430.21 Top Pump Tangent 7285' MD, 3198' TVD 7,484.98 3,250.00 -5,398.99 2,512.38 End Pump Tangent 7485' MD, 3250' TVD 10,257.34 3,634.37 -8,015.16 3,119.33 9 5/8" Csg. (c~ 10257' MD, 3640' TVD - 1152' FNL, 824' FWL - Sec12-T10N-R 17,907.80 3,532.60 -15,663.86 3,068.65 BHL - 17908' MD, 3533' TVD - 1759' FSL, 766' FWL - Sec13-T10N-R10E 3/13/2007 7:21:39PM Page 19 of 11 COMPASS 2003.11 Build 48 r ConocoPhillips • Plan: 1J-135 (wp07) Sperry Drilling Services Anticollision Summary 13 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1 J-135 D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) N True API - US Survey Feet Sperry Drilling B®rvirs®s SUKVEY PROGILllII ConocoPhillips Alaska, Inc. ANTI-COLLISION SETTINGS Date: 2007-U2-UTfUU:00:UU Validated: Yes Version: Depth FromDepth To Surrey/Plan Tool 40.00 1400.10 1J-135 (wp07) CB-Gl'RaSS 1400.1010257.34 1J-135 (wp07) MWD+IFR-AK-CAZSC 10257.34 17907.81 1J-135 (wp07) MWD+IFR-AK-C.~LC ~ ~J WSP-OS 1 J-14 WSP-O7 ~~ 0 , iJ-122 (wp04) ~. 1 1J-23 Pilot (wp01) ~ ~ ~ ~ ~~ ' ~~ ~ ~ ~ ~~ _ _~ >, WSP-14 WSP-12 ---- f.. ~ r ~' '.~ ~° ` 330 r~ f ~ ~-! ~~ 30 _,_ 1)•173 Pilot (wp06) - - - - - ~~ '"°- S>~ '~ r .l..t' "Jti ~~-. _ x761: ~\\ 1J-174 (wp05) ~soo 1J-176 (wp02) 1J-178 (wp02)` 1J-180 (wp10) 270 -- 1J-180 - - 1J-184 zao 1J-137 Rig ' '180 Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 1J-130 (wp02) 1J-1331ntermediate 60 i~ -.. .Ft ~~ i ~~ }~ -~-r 90 \ 1 J-103 L2 Travelling Cylinder Azimuth (TFO+AZ-) ~°~ vs Centre to Centre Separation X150 ft/ink NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-135 Ground Level: 81.10 +NI-S+EI-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5945397.09 558926.15 70°15'41.108N 149°31'25.162W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-135, True North Vertical (TVD) Reference: D15 (40+81.1) ~ 121.10ft (D15 (40+81.1)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: D15 (40+g1.1) ~ 121.10tt (D15 (40+81.1)) Calculation Method: Minimum Curvature Colour To 40 250 250 500 soo 7so 750 1000 1000 1250 1250 1500 1500 1750 1750 -- 2000 2000 --- 2250 2250 - 2500 2500 2750 2750 3000 3000 - 3250 3250 3500 3500 3750 3750 4000 4000 4250 4250 4500 4500 4750 4750 _ 5000 5000 5250 5250 5500 5500 --v 5750 5750 - 6000 6000 6250 6250 6500 6500 6750 6750 7000 7000 7250 7250 7500 7500 7750 7750 8000 8000 9000 9000 - 10000 10000 11000 11000 12000 12000 13000 13000 17000 17000 18000 Interpolation Method: MD Interval: 50Stations Depth Range From: 40.00 To 17908.40 Maximum Range:1986.83977072957 Reference: Plan: 1J-135 (wp07) WSP-14 4 ,~ WSP-12 3 ' ~ ~ 3 ' ~ _ SECTION DETFILS Sec MD Inc Nzl ND IWS iE/-W DLp ]Face VSac Target 4o.aD D.% D.oo 40.x0 o.% o.DO z 35D.w D.aD am 350.x0 0.00 o.DO o.oo o.oD o.Do o.oo o.aD o.ao 3 790.00 11.00 1]5.% ]8].30 -41.% 3.87 4 1ao.DO 20.92 pals mv.3e ao9.es 13.40 2.50 175.00 41.95 4.ao -m.aD 109x5 s 1240.00 28.56 164.44 12%.91 -191.2) 32.3a 6 15fid.20 )9.10 149.2] 1480.00 -351.69 106.% 4.% -20.00 191.23 4.% L0.% 351.64 I 1814.20 Ja.10 148.3] 1519.35 -J]I.BB 122.30 9 2359.61 ]5.00 154.93 192J.4fi -918.49 4%.49 0.00 0.00 3]].98 5.00 10.`A 918.da 9 ]461.% ]5.00 154.83 3250.00 -53%.% 2512.39 10 7684.30 80.% 153.82 3291.60 -SS74.57 25%.82 0.00 0.00 SJ%.% 3.00 9.5] 55]4.5] 1 8459.18 %.% 153.82 3111.1] -6261.21 2%1.38 12 %22.]2 82.00 180.% 3544.90 -J%5.4] 3125.]1 0.00 0.00 6261.21 3.00 89.59 ]095.1] 1J-135 TOp D(44p%1 13 93]5.23 83.52 180.41 3551 d2 -)13]56 3125.56 3.00 14.83 IIJ7.% 1d looos.w 93.52 1eo.41 3s22.s1 ->Tw.]9 3121.1x 15 10256.73 91.% 190.41 363x.39 -0p14.% 3119x3 t6 10441.]] 91.% 18041 3630.% -0202.52 ]11 T.% o.% o.oo ns3.]s 3.% 0.03 6014.% 0.00 0.% 8202.52 1}135 MB_B CP2 (012112007) 1] 105%.28 89.Sfi 180.15 3630.09 -035J.% )116.% 18 11%5.90 89.% 180.45 3633.% -0913.55 It 12.9] 1.00 1)8.35 8353.% 0.00 0.00 8x43.55 1}135 MB_B CPS (01/3112%7) 19 11225.84 90.% 180.41 3633.29 -0983.57 3111.98 2011985.9] %% 180.44 3630.60 -9743.% 31%.03 1.00 -0.4a 8983.5] 0.00 0.00 9)43.58 1}135 MB_B CP4 (01/3112007) 21 12121.fi5 92.31 180.40 3816.]3 -%79.19 J105.D3 x213143.94 92.)1 180.40 JS]5.50-10900.6) 3x97.% 1.00 -1.% %]9.19 0.00 0.0010900.63 1}135 MB_B CPS (01131 2 0 0 7) 2J 13211.09 91.64 190.4° 3573.19-1096)69 31197.49 24 14244.49 91.61 190.10 354).60-12000.% 3090.31 2514)89.% 90.21 190.35 3511.29-12140.2) 3099.40 1.00 179.% 10967.69 0.00 0.00 1200°.% 1}1~MB BCP6 (0113112007) 1.00 -179.15 121 M.23 2615443.59 90.21 180.35 )53].50-13199.71 3%2.91 2] 15467.91 89.% 1%.39 353146-13224.05 3%2.N 28 1634).% 89.% 180.39 %38.00-14099.]9 3078.% 0.% 0.00 13199.]4 1}135 MB_B GPT (Ot/312007) 1.00 171.% 13224.05 0.00 0.% 14099.]9 1}135 MB BCP6 (01/3112007) 29 16352.39 %.00 190.31 3.53800-141%.52 3078.% 301754).71 %.00 1x0.31 3538.00-tsz%.85 3070.50 100 41631 141%52 0.00 0.0015z99.as 1}135 MB_B GP9101I3120071 31 1]641.% %.% 180.29 353].16-153%.% 3099.% 32 17%741 90.% 18039 %32.60-1NL3.% JII68.% 1.00 -0.9] 15)%.09 o.ao om 15663.88 1}135 MB_B Tce (011312 0 0 7) C C 90 Travelling Cylinder Azimuth (TFO+ALI) (°( vs Centre to Centre Separation (50 ft/in~ 1J-103 L2 1J-137 Rig ConocoPhillips Alaska Halliburton Company Anticollision Report Bperry Driliin® ®~raicas Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: /Vell Plan 1J-135 Project: Kuparuk River Unit TVD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Reference Site: 'Kuparuk 1J Pad MD Reference: D15 (40+81.1) @ 12t10ft (D15 (40+81.1)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-135 Database: Compass 2003.11 Reference Design: 1J-135 (wp07) Offset TVD Reference: Offset Datum ~ Reference 1J-133(wp07) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,986.84ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3/13/ZUU/ From To (ft) (ft) Survey (Wellbore) 40.00 1,400.10 1J-135 (wp07) (Plan 1J-135) 1,400.10 10,257.34 1J-135 (wp07) (Plan 1J-135) 10,257.34 17,907.81 1J-135 (wp07) (Plan 1J-135) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-LC MWD+IFR AK CAZ LC Sperry CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/13/2007 12:10:17PM Page 2 of 5 COMPASS 2003.11 Buitd 48 ~-' Halliburton Company HALL~BU~TQ1~ ~~~~~ Anticollision Report ~~,,~,~ Drilitng srl~~ Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-135 Project: K,~paruk River Unit ND Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Reference Site: Kuparuk 1J Pad MD Reference: D15 (40+81.1) @ 121.10ft (D15 (40+81.1)) Site Error: O OOft North Reference: True Reference Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Well Error: O OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-135 Database: Compass 2003.11 Reference Design: 1J-135 (wp07) Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 9J Pad 1J-102 - 1J-102 - 1J-102 249.79 250.00 681.27 4.97 676.30 Pass -Major Risk 1J-102 - 1J-102 L1 - 1J-102 L1 6,571.01 9,800.00 728.69 162.97 565.72 Pass -Major Risk 1J-102 - 1J-102 L2 - 1J-102 L2 6,343.44 9,575.00 684.20 150.97 533.23 Pass -Major Risk 1J-102 - 1J-102 l2 PB2 - 1J-102 L2 PB2 6,333.24 9,564.52 680.56 151.13 529.43 Pass -Major Risk 1J-102 - 1J-102 PB3 - 1J-102 PB3 6,582.74 9,846.02 821.05 154.00 667.05 Pass -Major Risk 1J-127 - 1J-127 - 1J-127 396.84 400.00 160.97 8.53 152.44 Pass -Major Risk 1J-127 - 1J-127 L1 - 1J-127 L1 Rig Surveys 396.84 400.00 160.97 8.53 152.44 Pass -Major Risk 1J-127 - 1J-127 L1 PB1 - 1J-127 L1 PB1 Rig Sun 396.84 400.00 160.97 8.53 152.44 Pass -Major Risk 1J-127 - 1J-127 L2 - 1J-127 L2 Rig Surveys 40.10 40.10 160.24 1.23 159.02 Pass -Major Risk 1J-127 - 1J-127 PB1 - 1J-127 PB1 Rig Surveys 396.84 400.00 160.97 8.64 152.33 Pass -Major Risk 1J-127 - 1J-127 PB2 - 1J-127 PB2 Rig Surveys 396.84 400.00 160.97 8.64 152.33 Pass -Major Risk 1J-14 - 1J-14 - 1J-14 1,597.80 1,575.00 60.96 33.74 27.22 Pass -Major Risk 1J-182 - 1J-182 - 1J-182 475.46 475.00 147.17 10.37 136.80 Pass -Major Risk 1J-182 - 1J-182 L1 - 1J-182 L1 475.46 475.00 147.17 10.21 136.96 Pass -Major Risk 1J-182 - 1J-182 L1 P61 - 1J-182 L1 PB1 475.46 475.00 147.17 10.37 136.80 Pass -Major Risk 1J-184 - 1J-184 - 1J-184 489.61 475.00 148.77 10.60 138.16 Pass -Major Risk 1J-184 - iJ-184 L1 - 1J-184 L1 489.61 475.00 148.77 10.60 138.16 Pass -Major Risk Plan 1J-122 - 1J-122 L1 - 1J-122 L1 (wp03) 500.00 500.00 259.46 10.90 248.56 Pass -Major Risk Plan 1J-122 - 1J-122 L2 - 1J-122 L2 (wp03) 500.00 500.00 259.46 10.90 248.56 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp04) 500.00 500.00 259.46 10.90 248.56 Pass -Major Risk Plan 1 J-123 Kuparuk Prelim - 1 J-23 E Lat - 1 J-23 394.49 400.00 240.41 8.48 231.92 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 f 394.49 400.00 240.41 8.48 231.92 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-2< 394.49 400.00 240.41 8.48 231.92 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp02) 500.00 500.00 218.94 10.90 208.04 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) 445.85 450.00 100.21 9.71 90.50 Pass -Major Risk Plan 1J-133 - 1J-133 - 1J-133 Intermediate 582.55 575.00 33.17 12.84 20.33 Pass -Major Risk Plan 1J-135 -Plan 1J-135 L1 - 1J-135 L1 (wp07) 9,325.00 9,325.00 0.01 0.70 -0.69 FAIL - No Errors - Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 419.71 425.00 248.54 9.04 239.50 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W L 419.71 425.00 248.54 9.04 239.50 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (~ 419.71 425.00 248.54 9.04 239.50 Pass -Major Risk Plan 1J-174 (01 Phase 2) - 1J-174 - 1J-174 (wp0: 408.13 400.00 232.63 8.74 223.89 Pass -Major Risk Plan 1J-174 (Q1 Phase 2) - 1J-174 L1 - 1J-174 L1 408.13 400.00 232.63 8.74 223.89 Pass -Major Risk Plan 1J-176 (02 Phase 2) - 1J-176 - 1J-176 (wp0: 409.08 400.00 203.13 8.87 194.27 Pass -Major Risk Plan 1J-176 (02 Phase 2) - 1J-176 L1 - 1J-176 L1 409.08 400.00 203.13 8.87 194.27 Pass -Major Risk Plan 1J-178 (Q3 Phase 2) - 1J-178 - 1J-178 (wp0: 398.46 400.00 177.69 8.66 169.03 Pass -Major Risk Plan 1J-178 (03 Phase 2) - 1J-178 L1 - 1J-178 L1 398.46 400.00 177.69 8.66 169.03 Pass -Major Risk Rig: 1J-103 - 1J-103 - 1J-103 337.09 325.00 661.20 7.32 653.88 Pass -Major Risk Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 8,033.84 12,444.02 447.10 191.44 255.66 Pass -Major Risk Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 8,957.33 13,475.00 115.25 - 216.39 -101.14 FAIL -Major Risk -° Rig: 1J-136 - 1J-136 - 1J-136 300.00 300.00 20.45 6.46 13.99 Pass -Major Risk Rig: 1J-136 - 1J-136 L1 - 1J-136 L1 300.00 300.00 20.45 6.46 13.99 Pass -Major Risk Rig: 1J-136 - 1J-136 L1 PB1 - 1J-136 L1 PB1 300.00 300.00 20.45 6.46 13.99 Pass -Major Risk Rig: 1J-136 - 1J-136 L1 P62 - 1J-136 L1 P62 300.00 300.00 20.45 6.46 13.99 Pass -Major Risk Rig: 1J-136 - 1J-136 PB1 - 1J-136 PB1 300.00 300.00 20.45 6.46 13.99 Pass -Major Risk Rig: 1J-137 - 1J-137 - 1J-137 Rig 312.09 300.00 41.05 6.73 34.32 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 - 1J-137 L1 312.09 300.00 41.05 6.73 34.32 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 P61 - 1J-137 L1 P61 312.09 300.00 41.05 6.73 34.32 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 P62 - 1J-137 L1 P62 312.09 300.00 41.05 6.73 34.32 Pass -Major Risk Rig: 1J-180 - 1J-180 - 1J-180 324.63 325.00 159.03 7.11 151.92 Pass -Major Risk Rig: 1J-180 - 1J-180 - 1J-180 (wp10) 399.29 400.00 158.53 8.68 149.85 Pass -Major Risk Ri : 1 J-180 - 1J-180 L1 - 1J-180 L1 324.63 325.00 159.03 7.11 151.92 Pass - Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/13J2007 12:10:17PM Page 4 of 5 COMPASS 2003.11 Buitd 48 Halliburton Company Ha1..~..1BURTC3~'V ~~~~~'~' Anticollision Report Sperry Drifting Serviaeir~ Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-135 Project: Kuparuk River Unit TVD Reference: D15 (40+g1.1) @ 121.10ft (D15 (40+81.1)) Reference Site: Kuparuk 1J Pad MD Reference: D15 (40+g1.1) @ 121.10ft (D15 (40+81.1)) Site Error. O OOft North Reference: True Reference Well: Plan 1J-135 Survey Calculation Method: Minimum Curvature Well Error: O OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-135 Database: Compass 2003.11 Reference Design: 1J-1?5 (wp07) Offset TVD Reference: Offset Datum ~ Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad Rig: 1J-180 - 1J-180 L1 PB1 - 1J-180 L1 (wp10t 399.29 400.00 158.53 8.68 149.85 Pass -Major Risk Rig: 1J-180 - 1J-180 L1 PB1 - 1J-180 L1 PB1 324.63 325.00 159.03 7.11 151.92 Pass -Major Risk Rig: 1J-180 - 1J-180 P61 - 1J-180PB1 324.63 325.00 158.87 7.00 151.88 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 418.06 425.00 203.72 12.09 191.62 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 410.27 400.00 146.33 11.95 134.38 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 421.46 425.00 87.92 10.60 77.33 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 390.60 375.00 41.92 9.31 32.61 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 775.64 775.00 39.76 18.47 21.29 Pass -Major Risk WSP-12 -WSP-12 -WSP-12 1,009.30 1,000.00 49.05 25.98 23.07 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 1,163.94 1,125.00 45.62 25.07 20.56 Pass -Major Risk WSP-14 -WSP-14 -WSP-14 1,339.71 1,300.00 47.55 30.25 17.31 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/13/2007 12:10:17PM Page 5 of 5 COMPASS 2003.11 Build 48 Cc~nocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad ® ~ 3 (' `~) 1/4 Mile Pool Scan per~~°y I~rilli~ ~~~r~ice~ March 13, 2007 \; :r'' -.•__ s _~ L~ -..'i~i,i~e _ =:~~ .ate-~~__: ,.u;_ ..;:-::.,a„~i:,~-.,a~..sz~.e® - - - - -.:.~.:~~W~~,,:~ Yfi --_ • 61~~,~~E-~ li° ~--t !ice Drilling and Formation Evaluation Cic~sest in POOL Closest A roach: Reference Well: 1J-135 L1 w 07 Plan Offset Vllell: 1J-'i03 L2 Coords. - cooras. - ASP ASP 3-D ctr-ctr . Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Dist Mi De ih An le Incl TRUE Azi. TVD E + /W . 180° Comments De th Incl. An le TRUE Azi. TVD E +)/W - 180 Comments . n. . P OL Min Distance POOL Min Distance (146.63 ft) in POOL (146.63 ft) in POOL (9323 - 17903.09 MD) (9323- 17903.09 MD) to 1J-135 L1 (wp07) to 1J-103 L2 (5990 - Plan (5990 - 13866 746.63 9325 82.31 180 3424.057 5938334 562107.1 7087.672 13866 MD) 13811.75 70.99 176.08 3535.26 5938367 562017.5 7695.89 MD) Closest A roach: Reference Well: 1J-135 L1 wp07 Plan ®ffset V 19e11: 1J-136 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)IS(-) View VS Meas. Subsea N(+)/S(-) View VS Min Dist De th Angle Incl TRUE Azi. TVD E + /W -) 180°) Comments De th Incl. Angle TRUE Azi. TVD E + /W - (180°) Comments . . . POOL Min Distance POOL Min Distance (982.64 ft) in POOL (982.64 ft) in POOL (9323 - 17903.09 (9323 - 17903.09 MD) to 1 J-135 L1 (wp to 1J-136 L1 (9081 - Plan (9061 - 982.64 Ski"; i - "~ 16075 89.86 180.39 3352.014 5931585.7 562112.9 13836 17233.03 MD) 15698.15 91.19 180.6 3312.45 5931580.9 561131.1 13813.6 17233.03 MD) Closest A roach: Reference Well: 1J-135 L1 w 07 Plan ®ffset Well: 1J-133 Int. Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E(+)/W(_ 180°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W -) 180`) Comments POOL Min Distance POOL Min Distance (1386.88 ft) in POOL (1386.88 ft) in POOL (9323 - 17903.09 MD) (9323 - 17903.09 MD) to 1 J-135 L1 (wp07) to 1 J-133 Int. (9880 - Plan (9880 - 1386.88 9325 82.31 180 3424.057 5938334 562107.1 7087.872 10878,02 MD) 9802.42 78.89 167.86 3486.69 5938518.4 563480.3 6953.12 10878.02 MD) Closes t A roach: Reference Well: 1J-13 5 L1 (w 07 Plan Offset WeIB: 1J-102 LL Coords. - Coords. - ASP ASP 3-D ctr-ctr ? Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. 7VD E{+ /W - 180° Comments De th Incl. Angle TRUE Azi. TVD E(+ /W(- 180°) Comments POOL Min Distance POOL Min Distance (1494.54 ft) in PO (1494.54 ft) in POOL (9323 - 17903.0 (9323 - 17903.09 MD ) to 1 J-135 L1 (wp to 1 J-102 L2 (4730 - Plan (4730 - '1494.54 -1«STi'4 - 9325 82.31 180 3424.057 5938334 562107.1 7087.872 12060.83 MD) 12060.83 90.9 178.05 3380.307 5938522.2 560625.1 6888.013 12060.83 MD) i POOL Summary Template.xls 3/13/2007 7:53 PM 1~-135 drilling Hazar~ Ammar (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. 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 Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-135 Drilling Hazards Summary 3/1/2007 2:39 PM CemCADE Preliminar Job Design Schlumberger Y 13 3/8" Surface Preliminary Job Design based on limited input data. For esfimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 2/21/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 94.# casing at 80' MD < Base of Permafrost at 1,616' MD (1,520' TVD) < Top of Tail at 2,711' MD < 13 3/8", 68.0# casing in 16" OH TD at 3,511' MD (2,209' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,711' MD. Lead Slurry Minimum pump time: 320 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1616' - 80') x 3.50 (250% excess) = 2261.1 ft3 0.4206 ft3/ft x (2711' - 1616') x 1.35 (35% excess) = 621.8 ft3 81.5 ft3 + 2261.1 ft3+ 621.8 ft3 = 2964.4 ft3 2964.4 ft3 / 4.45 ft3/sk = 666.2 sks Round up to 670 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3511' - 2711') x 1.35 (35% excess) = 454.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 ft3 454.2 ft3 + 67.3 ft3 = 521.5 ft3 521.5 ft3/ 2.47 ft3/sk = 211.1 sks Round up to 220 sks BHST = 48~, Estimated BHCT = 64`F. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 6 531 88.5 121.8 Tail Slurry 6 97 16.2 138.0 Drop Top Plug 8.0 146.0 Water 5 20 4.0 150.0 Switch to Rig Pum s 5.0 155.0 Displacement 7 474 67.7 222.7 Slow Rate 3 20 6.7 229.4 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Mark of Schlumberger CemCADE Preliminary Job Design Schlumberger 9.625" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 2/21/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 13 3/8", 68.0# casing at 3,511' MD < Top of Tail at 5,496' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,200' MD (3,640' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 5971' MD, TOC at 5471' MD, 4704' MD annular length). Tail Slurry Minimum thickening time: min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 4704' x 1.25 (25% excess) = 1841.6 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1841.6 ft3 + 34.1 ft3 = 1875.7 ft3 1875.7 ft3/ 2.25 ft3/sk = 833.6 sks Round up to 840 sks BHST = 85~, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.6`l=/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 10.0 20.0 MudPUSH II 6 75 12.5 32.5 Tail Slurry 6 337 56.2 88.7 Drop Top Plug 10.0 98.7 Water 5 20 4.0 102.7 Switch to Rig Pum s 5.0 107.7 Displacement 7 727 103.9 211.6 Slow Rate 3 20 6.7 218.3 MUD REMOVAL Recommended Mud Properties: 9.3 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Wellhead /Tubing Head /Tree, 13-3/8" x 4-%", 5,000 ksi ('~ = - -- WPO6 Directional Plan /~ ~ /~ Insulated Conductor Tubing String: 4-I/2", 12.6 d, L-80, IBTM, ail/ Casing, 20", 94#, K55 x 510" OD Connections O ~ 34", 0312" WT @ . +/- 80' MD ~~ (1) 3.875" DB nipple set+/- 500' ~• , 13-3/8", 68#, L-80, BTC 3,511' biD / 2,209' TVD ~~ L 75 degrees TD 16" hole Top of Uguu C (a 5,928' MD / 2,847' TVD ~ rP F ~ ~ S 'tr c n ^, rn c o S o m .. m A n 4 w \\ 1 Top of West Sak D C~ 9,326' NID / 3,564' TVD ,~ (I) Gas Lift Mandrel, CAMCO 4-I/2" x 1" Model KB~IG ~ 67 degrees +/- 2100' MD (1) Gas Lift Mandrel, CM1CO 4-1/2" x l" Model KMBG w/ dummy valve, @ < 72 deg Electric Submersible Purnp, Cenlrilift 4I8 HP motor, with FC6000 wireline deployed pump. Bottom at 8,800' MD, 3,190' TVD 180 LI "D" Sand Window 9,328' MD / 3,Sti4' TVD i degrees ~~ "D" Liner, 4-1/2", 11.6N, L80, BTCM r$ 3 a ,q ~ g F 0 C y ,, (~y ~~ B Sand Liner, 5.1/2", I5.5# Top of West Sak B @ ` ~/ 10,050' MD / 3,632' TVD ~ `~\ Seal bore and ZXP packer for B linet~~ a 9,428' MD, 3,577 TVD 9-5/8", 40N, L-80, BTCM, Csg @ 10,200' MD / 3,640' TVD ~ ~ 89 degrees TD l2-l/4" hole iS - ~~~ IJ-135 Ll 6-3/4" °D" sand lateral TD 17,906' bID / 3,469' TVD Angle 91 degrees I1-135: _^-___ 8-%" B sand lateraF~'~'~ TD C7,'909'MD/3,532'f"VD~ ~~~ -- Angle 91 degrees Re: 1 J-135 • • Subject: Re: 1J-135 From: Thomas Maunder <tommaunder~~admin.state.ak.us> Date: F~-i, 16 Mar 2007 15:01:40 -0800 ~ ~~ - C~ ~ ~` To: "Hart~~~'i~~_ Dennis D" - L)rnnis.l).I lart~~~i'=~icot~~~c~~phillips.cot~~ . Thanks Dennis, As I got to reviewing 1J-135L1, I was able to look at the plan and 3D views of the trajectories. Was it intended to include similar plots in 1J-135. It does not appear that any were included. Those plots make the complicated geometries much easier to understand. I will plan to make additional copies so both applications have this information. My question is answered. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/16/2007 2:47 PM: Tom, You are correct, the Anti-collision violation occurs while the 1J-135 is drilling the 12 1/4" hole with the toe (6 3/4") of 1J-103. The 1J-103, over the interval in question, is in the D-Sand while the 1J-135 is in the K-13 shale. The risk is null because of geologic control as we drill the interval. In essence the error ellipses of both wells overlap but because of geologic control we know that one well is in the D-sand while the other is in the K-13. The issue is highlighted to the rig-site team for heightened awareness. as 4ve drill over the interval in question. Regards...Dennis Dennis Hartwig Drilling Engineer ConoccPhillips Alaska, Inc. Office 907-265-6862 Cell 907-980-1433 Fax 907-265-1535 -----Original Message From: Thomas Maunder [mai.l`::c:>:t:cm ma~_rnder~:~adEr.in.st:a'::e.ak._zs_] Sent: Friday, March 16, 2007 2:18 PM To: Hartwig, Dennis D Cc: Greener, Mike R. Subject: 1J-135 Dennis, ', I am reviewing the 1J-135 permit application. All appears to be in order. ', I have 1 question regarding the anticollision report. It is indicated that proximity with 1J-103 fails the major risk criteria at 13475'. Could you provide ', a little more information on this? It appears from the relative depths/lengths that 1J-135 is still drilling in the 12-1/4" hole and iJ-103 is "in the laterals". I look forward to your reply. Tom Maunder, PE AOGCC 1 of 1 3/16/2007 3:02 PM • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS AT0,1530 700 G ST. ANCHORAGE AK 99501 ° PAY TO THE S~~Q ~~ OF ~ a ORDER OF ~ / /~-1~5~ Y,~ JPMorganCha /~ • 1176 GATE Q~/~L /T ~U g_7551/441 r /4aC7CC $ /~. UO ~- ~ ~~/ ~. DOLLARS ~,,,,~,~,~, Se ~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH MEMO ~ ~- • -------- ~---__C~y\J~~ ~+115511~.528747L907927n~1L76 • • ~'~tA~ISl0~I1"i'AL. LEI'~'Ela CI~~CKLIS~' WELL NAME ,~i~LC /gT=/3S PTn~ 2D 7 - D 3 8 ®evelopment Service Exploratory Stratigraphic Vest Yon-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK I ADD-ONS ! TEXT FOR APPROVAL LETTER w'HAT ~ (OPTIONS) ~ ' APPLIES NiTJLTI LATERAL ~ The permit is for a new wellbore segment of existing i i ~ well ~ (If last two digits in I Permit No. API No. ~0- - - API number , are ,' between 60-69) Production should continue to be reported as a function of the i original API number stated above. PLOT HOLE U accordance with 20 AAC 25.005(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both j well name ( PH) and API number ' (50- - -_) from records, data and lots ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.0». Approval to perforate and produce /inject is contingent. upon issuance of a conservation order approving a spacing j exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. f t G ;DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in i SA!~iPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following, special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Fell ;for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data I j ,' on water quality and quantity. SCom~any Name) must contact the ~ ~ Commission to obtain advance approval of such water well testing program. ~ Rev: ['2~i06 C:` jody`transmittal_checklist • ~ N ' 0 0 , ~ a~ a N .N , a~ ~ o ~ Q ~ ~ , ~ , ' o ~ 3' ~; m' v c O o. ~ ~°~ m~ ~ ~ ~ vi ~ ~ ~ ~ ~ ~o ~ i ° N. ~ ~ ~ ~ ~ ~ yr ~~ i s E' ~ ao M J ~ Q rn c u a N •° ~ ~ ~ i , N. c a N N L ~ ~ m ~ ~ ~~ N ~ L, ~ Ts ~ ~ ~ N• m O ~ L t o, a o- '~ ~ ai ~ ~ ~ ~ E O m. ~ o. o, ao y a, m ~ m C ~ m. o- o; ~ m o T C9 v. ~ a d; ~; -o o ~, o' ~ ~: ~ oo ~ ~ , o 3. ' o ~ ~ Q' U ; Q 0- 3 ~ U' ~ ~~ ~ 0- m ~ m' s o o ~ ~~ ~ M ° ~ ~ ~ ~ ~ v ~ ~ ~ ~ ~ ~ ~ ~ ~ Q. m' ~ ~: ~ L 3 m' Z. C, O C. T ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~ ~ d~ ~ C. ~ ~ N, N. ~~ m. ~ > o, m ~ ~ ~ ~ N. a~, ~I ~ ' , ~ ~ o j 4 ° ° = s, ' Yi ~ _ ~0 3 a3i ~ ~~ ~ Z ~ ~ ~ c ~ w ~ ° o' ~ ~ O~ O. ~ ~ J ! N' ~ ° N rn C N ~' U ~ 3, , a' Y ~ 7 ~~ fl. V. ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~, ~ ~ °~ m. ~ ~ ~~ m, W. ~~ ' ~, oa o. ~ C~ ~ ~ ~ ~ m 'C p. N: a~ m. ~ ~ j ~ ~~ v ~ ~ ° Z ~ J ~°, ~ N ~ N. Y. ~ ~ to ~, 01 a oS ~ ~~ ~ ~ ~ d O ~ E~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ , ~ F-, ~ fl! ~ M. ~ ~~ ~ Q; d ~ O m U o m ~ ~ ' ~, o0 0 Y ~ N. . ~ . Y. Vl: ~~ N ~ ~ ~ i O U Q _4 ~ m o. a N N p 7 ~ ~ J. ~ m ~ N w~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~'~ . ~ ~ ~ N• ~ ~~ ~ .~~ f . ~ . ~ ~ O. N. ~~ ~: ~ ~ ~ ~ ~ 4 C p. ~ ~ a, T N. N' ~ N N Q C. ~ E ~ o. °r o ~ m' m a . m. a~ ° ~ m: ~ m C7 Y. m O E: ~ ` C. s T ~ m' N i L -O' O) ~ ~ ,~~ tt, C~ ~ fl ~ T N N, .E x, ~ L ° N U _ Z 7 . ~ ~ ~ O ~ m. N, ~ ~ m L - O, 01 O, X m• Q. tn N: ~ a O X' O W ~ ~~ Y. ~~ ~~ ~~ ~ ~ ~ ~ Q• ~ Q. ~. ~ ~, ~, ~. ~ ~~ ~ ~ Z. Z. W. ~~ a ; W , ~ ~ ~ ~ ~ ~ -o c m N m L ^ 0 ^ ^ ^ 3 C N fl. 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U C v~ ~: (n ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ C ~ ~ ~~ ~ ~ m. ~ ~ . a' Q' 'I ~ ~ ~ ~ 7 N 3 ~ C ~: ~~ .N C ~~ O ~ N• O. ~, O. ~ ~ ~ C y. ~ m C ~ ~ >, ~ N: N, W ~ ~ ~ ~ O) '~~ ~ O ?~ O ~ M. ~~ U ~ ,N. fl'. ~ C O - ~ ~ ~: fl. ~ d', -O, N. ~ i ~ ~ ~ C ~~ 3, ~ N N ~ T r' ~ 'O O O o2S E N~ ~ '~ M a ~ O N N ~ ~ ~ V~ ~ ~ ~ ~ = L• v 0) ~ ~ Z (n' m a N tf)~ ~ O' 3 O m a f/Y C' O9 L, , m C' N' O a O M' 7 Q N N N ~ Y ~ Z - ~ ~ ~ ~ ~ o ~ c. ~: o m :~ C : .~ _~ ' ~~ • ~ ~ N ~ >: . ~ ~ , O, 'a, o: rn ~ N. o~ : ~ ~ ~ ~ ~ O~ °. : ~ ~~ Q c N ~.. ~ ~ E E o o - 'O, v o E C o ~' ~ ~, N O M °' to i C 3' O o • ~ ~ ~ . m' d ~ v c ~ o ~ ~ 3 ~ o a~' N N Q a ~ ~ w o ~ ~ ° -o ~ m ~ ~ o N o o' Q I o c m ~ o -o U 4 o s m ~ c m o. ~ ' ~ d d m , ~ ur a ~ o. m rn o ~ g Q O N N ~ ~ T a~ O ~ 7 _0 0 o a~ '6 m ~p O c, m II Y _ (6 O O O Z, o O ~ ~ (6 ° (6 3 m 4 a~ s ~ 3_ Y Q ~, 'c -p ~° : ° ~ a a m ~ ~ ~ i°' m -o E i a-°i m ~ c c a> N' M w ~ 'N t ~ o N o n 3' Q '~ °' y; ' ~ . m~~ ~ a m 3 3 m m m ~ ~o N '~ ~ 3 m ~ o ~ m ~ ~ ~ .~ N o, 3 ~i m m ° ~ ° m •a a a m' o ' ° ' °- ~ ~' o ~ •~ o c ~ o~ ~ o o c ~ o o' ~' ~' E' ° ' `~° E ~ rn o ', ~. a N. ~, d. "'~ v N p- ~° Q O ~ N ~ = , I Q U G : O ~ Y, a N ~ N; ~ ~ a i E' ~ O :.-% I N 7' C' O N: ds I cLi~~ O , m. N, . : E. m 0. o N °? a~' ~ /1~ 4 N t a ~+ ~? Q m . ~ N. of N ~~ ~- 'c ` a ~ m ca m; ~4' rn m o ~ ' oS T ._ 3 -. ~°' 2 ~ °' ,n o a- p ~° m E. o o. ~ N m ~ ~ . N , , ° ~ a' rn c ~ ~ ` c m _ ~ ° f6 0 : o > i a m 4 . . 'D a 'O U. ~ C, , m, .Q. ~~ .O , -O. L : N. .~ N~ i •N, N. N. a > >. . ,O? c' , : t ' N ~ a y' ~ ' i N '~~ U• > ; o c ~ I ar Q: ~' C• ' a ~p~ C• LL ` U ~~ ~, ~: a~~ a;~ a~~ m~ .a~ o L, c~ c _ ~~ ~. ~ o 3 m, -o `°' -o m' o c~ ~n ~ -, 3, ~ -° ~ o~ -° N ° o m ~' m~ i c. c~ a~~ N C~ a m ~. Z m c 3, u cm~ m ar ~ a~ o ~ m o ~ ~ E ~ , -a: ~ i m o 'n o o ~ o ~. o o '3 ~ ~ ~: _ v, ~: ~, r m vi ~ - 4 ~ •3 ~ N, ~ ~i m ~ Q c~. •° ~: ~ O E a~, -° -° -° io ' >~ m; ~~ '~~ a ~ a~, °~ -o' m' ~ c~ ~~ >~ ~ d d L '~~ ~ J U a ~ .a; ~ ~ ~ ~ ~ a ~ m m ~ 3' o o ~` 1- I- ' I- • m ~ ~ ~° . . , p. o: i ~ a c ~ ~ m. m ~ ~. .~ Y ~ ~ a a~ ~ c, ~ ~', ~', ~', ~ <n, w O ; a~ a~ o a' O U ; ; ~~, Q; a' z U ~ ~; U ~ , U ~; U ; U ~: Q m _ -o, _ Q o' O. m O L, m U ~ ~'' ~' I a~ a' , o a~ a~, cn cn w a. , , , E O ~ _ N _. __. M ~t tp M __- ~ M O _..____-_. O ~ N ~ ~ ~ M ~- tt ~ (O f~ ~ W a- ~_ ~ ~ -__ _.__ ~ ~ __- O N __ N _ N N _ - N _ N _ N N - N _ N ~ N M M M _ M V M M~ -__- M M O M _- E M M M (~ i _ __ - _.__- - - i O N C m O I O I ~ O M w ~ (O ~l ~ ~,. M 0 M ~ O ~ M I~ L M M J N y II y rn D E a ~ a W ~ ' a O W a s a ~ ~ ~ ~' w ¢ ~ < ~, ° ~ Q~ ~ , w m o ^ m` a~ y (1 m 11a' rn° c ~ 0 .~ N •~ _N ~~ W U ai N U C O O N O U 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 inforTnation, 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. 1J135o04272007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Fri Jun 29 15:52:48 2007 Reel Header Service name .............LISTPE Date . ...................07/06/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/06/29 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing 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 MWD RUN 2 JOB NUMBER: w-0004957664 LOGGING ENGINEER: 6. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical Services Library. Scientific Technical services 1J-135 500292334900 ConocoPhillips Alaska Inc. Sperry Drilling Services 29-JUN-07 MWD RUN 3 w-0004957664 B. HENNINGSE F. HERBERT 35 11N l0E 1583 2287 122.50 81.00 Page 1 ~~_~~~ ~ t 53 l 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 171350042720075SN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3462.0 8.500 9.625 9819.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 3 ALSO INCLUDED AT-BIT GAMMA (ABG). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 17-135 WITH API#: 50-029-23349-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17735'MD/3512'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). File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 • 1713500427200755N.txt FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3438.5 17700.5 RPD 3450.0 17693.0 FET 3450.0 17693.0 RPS 3450.0 17693.0 RPM 3450.0 17693.0 RPx 3450.0 17693.0 ROP 3473.5 17735.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3438.5 9832.0 3 9832.0 17735.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 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 HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 17735 10586.8 28594 3438.5 17735 RPD MWD OHMM 3.26 2000 40.4217 28487 3450 17693 RPM MWD OHMM 0.44 2000 37.2563 28487 3450 17693 RPS MWD OHMM 2.37 2000 32.4786 28487 3450 17693 RPx MWD OHMM 3.43 2000 31.1087 28487 3450 17693 FET MWD HOUR 0.11 170.44 0.979901 28487 3450 17693 GR MWD API 9.8 117.18 65.7676 28525 3438.5 17700.5 ROP MWD FT/H 0.03 966.37 260.817 28524 3473.5 17735 First" Reading For Entire File..........3438.5 Page 3 • • 17135004272007SSN.txt Last Reading For Entire File...........17735 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3438.5 9796.5 FET 3450.0 9788.5 RPX 3450.0 9788.5 RPS 3450.0 9788.5 RPM 3450.0 9788.5 RPD 3450.0 9788.5 ROP 3473.5 9832.0 LOG HEADER DATA DATE LOGGED: 20-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9832.0 TOP LOG INTERVAL (FT): 3473.0 BOTTOM LOG INTERVAL (FT): 9832.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.4 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 230192 Page 4 • 1~135004272007SSN.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 12.250 3462.0 Fresh water Gel 9.20 56.0 9.3 800 4.4 2.400 92.0 1.930 116.0 2.300 85.0 2.800 85.0 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 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3438.5 9832 6635.25 12788 3438.5 9832 RPD MWD020 OHMM 3.34 2000 14.1335 12678 3450 9788.5 RPM MWD020 OHMM 0.44 1554.71 13.3743 12678 3450 9788.5 RPS MWD020 OHMM 2.37 63.84 12.4329 12678 3450 9788.5 RPX MWD020 OHMM 3.43 46.35 10.3977 12678 3450 9788.5 FET MwD020 HOUR 0.13 170.44 1.11044 12678 3450 9788.5 GR MWD020 API 9.8 117.18 67.6814 12717 3438.5 9796.5 ROP MWD020 FT/H 2.85 912 237.991 12718 3473.5 9832 Page 5 171350042720075SN.txt First Reading For Entire File..........3438.5 Last Reading For Entire File...........9832 File Trailer Service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER • FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9789.0 17693.0 RPD 9789.0 17693.0 RPM 9789.0 17693.0 FET 9789.0 17693.0 RPS 9789.0 17693.0 GR 9797.0 17700.5 oP 9832.5 17735.0 $ LOG HEADER DATA DATE LOGGED: 27-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17735.0 TOP LOG INTERVAL (FT): 9832.0 BOTTOM LOG INTERVAL (FT): 17735.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.2 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 6 1713500427200755N.txt DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 145654 ABG AT-BIT GAMMA 143793 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9819.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .. .......0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Mineral 8.50 61.0 .0 21000 .0 .000 .000 .000 .000 Name service order units size Nsam Rep code offset channel • oil Base .0 127.0 .0 .0 DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9789 17735 13762 15893 RPD MwD030 OHMM 3.26 2000 61.5035 15809 RPM MWD030 OHMM 11.72 2000 56.4085 15809 RPS MWD030 OHMM 9.02 2000 48.5542 15809 Page 7 First Reading 9789 9789 9789 9789 Last Reading 17735 17693 17693 17693 17135004272007SSN.txt RPX MWD030 OHMM 4.01 2000 47.7179 15809 9789 17693 FET MWD030 HOUR 0.11 90.16 0.875219 15809 9789 17693 GR MWD030 API 32.74 94.98 64.228 15808 9797 17700.5 RoP MWD030 FT/H 0.03 966.37 279.183 15806 9832.5 17735 First Reading For Entire File..........9789 Last Reading For Entire File...........17735 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/29 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ....................07/06/29 Ori 9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EoF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 8
