The URL can be used to link to this page

Home My WebLink About205-0071. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Treatment Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13529'feet None feet true vertical 3479' feet None feet Effective Depth measured 13018'feet 7191'feet true vertical 3478' feet 3512' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 7229' MD 3521' TVD Packers and SSSV (type, measured and true vertical depth) 7212' MD 7191' MD N/A 3517' TVD 3512' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3905' 2286' Burst Collapse Production L1 Liner 8265' 5987' Casing 3713' 2-3/8" 8290' 13516' 6534' 3875' 108'Conductor Surface Intermediate 20" 13-3/8" 77' measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-007 50-029-23243-60-00 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: ADL0025651, ADL0025660 Kuparuk River Field/ West Sak Oil Pool KRU 1E-105L1 Plugs Junk measured 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 108' ~~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RPPG pumped down 1E-105L1 (Injector) (see details in Well events.) Packer: SBE Seal Assembly Packer: ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 465-6471Staff Well interventions Engineer Alternating Slotted Liner: 7622-13249', Perfs: 8745-8755', 8945-8950', 9945-9955' Alternating Slotted Liner: 3595-3478', Perfs: 3556-3555', 3549-3549', 3525-3525' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:13 am, Aug 25, 2025 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: 2025.08.25 08:14:49-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne By Grace Christianson at 11:13 am, Aug 25, 2025 By Grace Christianson at 11:15 am, Aug 25, 2025 RBDMS JSB 082825 DSR/9/11/25J.Lau 11/4/25 DTTMSTART JOBTYP SUMMARYOPS 7/27/2025 REPAIR WELL MOVE CONTAINERS OF RPPG FROM 1J TO 1E, LAY LINER AND SPOT EQUIPMENT, SPOT TANK, RIG UP HARDLINE . FUNCTION TEST EQUIPMENT/CHECK COMMS 7/29/2025 REPAIR WELL STANDBY FOR OPS TO GET 1E-126 PRODUCER PAIR ONLINE (ICE PLUG) TO PUMP RPPG JOB ON 1E-105 7/30/2025 REPAIR WELL PUMP FULL BORE RPPG TO MBE IN THE B SAND LATERAL AT 9950'. PUMPED 6393.4 LBS OF DAQING RPPG PRODUCT AT .85 PPG FOR 183 BBL'S. STEADY INCREASE TO TARGET PSI OF 1252 PSI. CALLED FLUSH AT 345 JSV, AVG PSI 1102, AVG RATE 2.8 BPM. TOTAL JSV 471 BBL. WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1E-105/ 1E-126 RPPG Pumping Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:13,018.0 1E-105 6/21/2006 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DB plug, diverter, and iso sleeve 1E-105 11/19/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: PROFILE MOD. - PUMPED 2310 LBS (4MM) CRYSTAL SEAL IN B LATERAL MBE@8750 9/4/2011 pproven NOTE: MBE repair w/9 bbls of 1G1-2289E, 105 degree meltpoint wax @ 8750' 9/11/2010 lmosbor NOTE: TRI LATERAL WELL: A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) 6/18/2006 lmosbor NOTE: B-SAND LEM CONTAINS CAMCO 'DB' NIPPLE w/3.562" PROFILE @ 7578' 6/18/2006 famaj 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 20 19.12 31.0 170.0 170.0 94.00 K-55 WELDED SURFACE 13 3/8 12.41 30.0 3,905.3 2,285.7 68.00 L-80 BTC INTERMEDIATE 9 5/8 8.83 25.1 8,290.0 3,713.1 40.00 L-80 BTCM A-SAND LINER 5 1/2 4.95 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM D-SAND LINER LEM 4 1/2 3.96 7,190.5 7,492.5 3,577.2 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 7,229.2 Set Depth … 3,521.0 String Max No… 4 1/2 Tubing Description TUBING 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) 22.6 22.6 0.00 HANGER 13.375 VETCO GRAY TUBING HANGER 4.500 503.2 502.8 4.42 NIPPLE 4.500 'DB-6' NIPPLE w/NO GO 3.875" PROFILE Camco 3.875 4,217.0 2,399.1 69.08 GAS LIFT 5.984 Camco KBG-2- 1R 3.938 6,712.9 3,383.2 68.69 GAS LIFT 5.984 Camco KBG-2- 1R 3.938 7,163.9 3,505.3 76.00 SLEEVE 5.210 CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE (CLOSED 6/27/05) 3.810 7,211.1 3,516.7 76.09 LOCATOR 4.500 LOCATOR Baker 3.880 7,211.8 3,516.8 76.09 SEAL ASSY 4.500 SBE SEAL ASSEMBLY Baker 3.880 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) 7,258.0 3,528.0 76.03 ISO-SLEEVE TYPE 2 - D-LAT ISO SLEEVE. OAL 19' 11/18/2023 2.500 7,524.0 3,583.0 79.06 DIVERTER TYPE 1 DIVERTER. OAL 19' 11/18/2023 7,578.0 3,593.5 78.94 PLUG A SAND DB PLUG OAL 5.05' 11/18/2023 0.000 8,000.0 3,666.5 81.06 FISH LOST IPROF CENTRALIZER ARM IN HOLE. DID NOT SEE ON SUBSEQUENT RUNS. ~0.75" X ~6" 11/18/2023 0.000 13,320.0 3,626.6 91.41 FISH DEFLATED IBP (4/20/2020) AND PUSHED TO BOTTOM IN D-LATERAL 11/27/2019 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) 4,217.0 2,399.1 69.08 1 GAS LIFT DMY BK 1 0.0 8/8/2010 0.000 6,712.9 3,383.2 68.69 2 GAS LIFT DMY BK 1 0.0 8/8/2010 0.000 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) 7,190.5 3,511.7 76.12 PACKER 8.940 ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7,213.4 3,517.2 76.09 SBR 6.260 190-47 CASING SEAL BORE RECEPTACLE 4.750 7,232.6 3,521.8 76.06 XO BUSHING 6.030 CROSSOVER BUSHING 3.940 7,619.1 3,601.2 79.40 PACKER 7.000 HRD ZXP LINER TOP PACKER 4.970 7,637.6 3,604.6 79.61 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.875 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,312.0 8,774.0 3,716.9 3,726.6 WS A2, 1E-105 5/18/2005 0.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 9,030.0 9,498.0 3,702.2 3,694.9 WS A2, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 9,710.0 10,473.0 3,703.6 3,685.1 WS A2, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 1E-105, 8/11/2025 2:31:13 PM Vertical schematic (actual) A-SAND LINER; 7,619.1- 13,519.0 FISH; 13,320.0 SLOTS; 12,902.0-13,455.0 SLOTS; 12,348.0-12,603.0 SLOTS; 11,584.0-12,090.0 SLOTS; 10,731.0-11,114.0 SLOTS; 9,710.0-10,473.0 SLOTS; 9,030.0-9,498.0 SLOTS; 8,312.0-8,774.0 INTERMEDIATE; 25.1-8,290.0 FISH; 8,000.0 PLUG; 7,578.0 DIVERTER; 7,524.0 B-SAND LINER; 7,523.0- 13,509.9 B-SAND LINER LEM; 7,461.5- 7,661.8 D-SAND LINER LEM; 7,190.6- 7,492.5 ISO-SLEEVE; 7,258.0 GAS LIFT; 6,712.9 Cement Casing; 3,600.0 ftKB GAS LIFT; 4,217.0 SURFACE; 30.0-3,905.3 Cement Casing; 0.0 ftKB CONDUCTOR; 31.0-170.0 KUP INJ KB-Grd (ft) 30.59 RR Date 6/20/2005 Other Elev… 1E-105 ... TD Act Btm (ftKB) 13,539.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292324300 Wellbore Status INJ Max Angle & MD Incl (°) 96.20 MD (ftKB) 8,942.81 WELLNAME WELLBORE1E-105 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,731.0 11,114.0 3,669.7 3,658.2 WS A2, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 11,584.0 12,090.0 3,665.2 3,659.9 WS A3, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 12,348.0 12,603.0 3,649.4 3,631.0 WS A3, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft 12,902.0 13,455.0 3,624.7 3,624.7 WS A3, WS A2, 1E-105 5/18/2005 40.0 SLOTS Slotted Liner, alternating jts of blank/slotted liner for all A- Sand slots 2.5 x .125 holes, 4 rows/ft Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 0.0 3,905.0 0.0 2,285.5 Cement Casing Cement Found Between Shoe and Collar (Y/N): YCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): NPressure before cementing (psi): 450Hours circulated between stages: 5.5Bbls cmt to surf: 291Method used to measure density: microReturns (pct): 100 %Time cementing mixing started: 12:40 5/4/2005 3,600.0 8,290.0 2,173.5 3,713.1 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 45Drag up (lbs): 275Time started reciprocating: 01:00Time stopped reciprocating: 08:30Annular flow after cement job (Y/N): NPressure before cementing (psi): 500Hours circulated between stages: 4Bbls cmt to surf: 0Method used to measure density: MicromotioMethod used for mixing cement in this stage: FlyReturns (pct): 100Time cementing mixing started: 06:00 5/11/2005 1E-105, 8/11/2025 2:31:14 PM Vertical schematic (actual) A-SAND LINER; 7,619.1- 13,519.0 FISH; 13,320.0 SLOTS; 12,902.0-13,455.0 SLOTS; 12,348.0-12,603.0 SLOTS; 11,584.0-12,090.0 SLOTS; 10,731.0-11,114.0 SLOTS; 9,710.0-10,473.0 SLOTS; 9,030.0-9,498.0 SLOTS; 8,312.0-8,774.0 INTERMEDIATE; 25.1-8,290.0 FISH; 8,000.0 PLUG; 7,578.0 DIVERTER; 7,524.0 B-SAND LINER; 7,523.0- 13,509.9 B-SAND LINER LEM; 7,461.5- 7,661.8 D-SAND LINER LEM; 7,190.6- 7,492.5 ISO-SLEEVE; 7,258.0 GAS LIFT; 6,712.9 Cement Casing; 3,600.0 ftKB GAS LIFT; 4,217.0 SURFACE; 30.0-3,905.3 Cement Casing; 0.0 ftKB CONDUCTOR; 31.0-170.0 KUP INJ 1E-105 ... WELLNAME WELLBORE1E-105 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:13,018.0 1E-105L1 6/21/2006 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PERF 1E-105L1 7/3/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: Coil Tubing RPPG Treatment 4190 Lbs to B MBE in 1E-105L1 5/1/2017 pproven NOTE: PROFILE MODIFICATION - PUMPED 2310 LBS (4MM) CRYSTAL SEAL IN B LATERAL MBE@8750 9/4/2011 haggea NOTE: MBE repair w/9 bbls of 1G1-2289E, 105 degree meltpoint wax @ 8750' 9/11/2010 lmosbor NOTE: B-SAND LEM CONTAINS CAMCO 'DB' NIPPLE w/3.562" PROFILE @ 7578' 6/18/2006 famaj NOTE: TRI LATERAL WELL: A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) 6/18/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 5 1/2 4.95 7,523.0 13,509.9 3,479.4 15.50 L-80 BTCM B-SAND LINER LEM 4 1/2 3.96 7,461.5 7,661.8 3,598.5 12.60 L-80 IBTM 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) 7,461.5 3,571.6 79.84 PACKER 8.260 ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7,480.2 3,574.9 79.60 XO 7.680 CROSSOVER 4.950 7,481.9 3,575.2 79.58 SBR 6.260 190-47 CASING SEAL BORE RECEPTACLE 4.750 7,501.3 3,578.8 79.34 XO BUSHING 6.040 XO BUSHING 3.940 7,502.7 3,579.0 79.32 SWIVEL 5.750 CASING SWIVEL 3.960 7,578.0 3,591.0 83.95 NIPPLE 5.210 CAMCO 'DB' NIPPLE w/ 3.563" PROFILE 3.562 7,550.3 3,587.5 81.44 XO BUSHING 7.000 XO BUSHING 5.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B, 1E-105L1 5/29/2005 40.0 SLOTS Slotted Liner, alternating joints of blank/slotted liner for all B-Sand slots 2.5 x .125 holes, 4 rows/ft 8,140.0 8,472.0 3,597.3 3,566.4 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 8,733.0 9,029.0 3,555.9 3,548.6 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 8,745.0 8,750.0 3,555.5 3,555.4 WS B, 1E-105L1 9/4/2011 6.0 IPERF 60 DEG PHASING w/ 0.43" HOLES 8,750.0 8,755.0 3,555.4 3,555.2 WS B, 1E-105L1 8/27/2006 6.0 RPERF 2.5" HSD Guns-.26" ENT hole, 60 deg phase 8,945.0 8,950.0 3,549.1 3,549.1 WS B, 1E-105L1 8/20/2015 6.0 APERF 2" Powerflow HSD guns (2006 FP, 6 SPF, 60 Deg, EDH 0.45", 4.5" PEN 9,328.0 9,623.0 3,543.4 3,531.7 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 9,926.0 10,385.0 3,525.4 3,517.2 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 9,945.0 9,950.0 3,525.2 3,525.2 WS B, 1E-105L1 4/25/2017 6.0 APERF 6 SPF, 60 DEG PHASE (SLB 2.0" POWERFLOW PERF GUNS) 9,950.0 9,955.0 3,525.2 3,525.1 WS B, 1E-105L1 7/3/2018 6.0 APERF SLB 2.00" POWER FLOW, 6 SPF, 60 DEG PH, HMX 10,644.0 11,023.0 3,513.7 3,516.6 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 11,669.0 11,881.0 3,529.9 3,510.5 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 12,269.0 12,437.0 3,502.6 3,502.4 WS B, 1E-105L1 5/29/2005 40.0 SLOTS 12,738.0 13,249.0 3,491.4 3,477.5 WS B, 1E-105L1 5/29/2005 40.0 SLOTS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ Profile Modification - Pumped Crystal Seal, 2310 LBS of 4MM product in a 2% KCL Solution 9/4/2011 1E-105L1, 8/11/2025 2:31:15 PM Vertical schematic (actual) B-SAND LINER; 7,523.0- 13,509.9 SLOTS; 12,738.0-13,249.0 SLOTS; 12,269.0-12,437.0 SLOTS; 11,669.0-11,881.0 SLOTS; 10,644.0-11,023.0 SLOTS; 9,926.0-10,385.0 APERF; 9,950.0-9,955.0 APERF; 9,945.0-9,950.0 SLOTS; 9,328.0-9,623.0 APERF; 8,945.0-8,950.0 SLOTS; 8,733.0-9,029.0 RPERF; 8,750.0-8,755.0 IPERF; 8,745.0-8,750.0 GEL SQZ; 8,745.0 ftKB SLOTS; 8,140.0-8,472.0 SLOTS; 7,622.0-7,750.1 B-SAND LINER LEM; 7,461.5- 7,661.8 INTERMEDIATE; 25.1-8,290.0 D-SAND LINER LEM; 7,190.6- 7,492.5 ISO-SLEEVE; 7,258.0 GAS LIFT; 6,712.9 Cement Casing; 3,600.0 ftKB GAS LIFT; 4,217.0 SURFACE; 30.0-3,905.3 Cement Casing; 0.0 ftKB CONDUCTOR; 31.0-170.0 KUP INJ KB-Grd (ft) 30.59 RR Date 6/20/2005 Other Elev… 1E-105L1 ... TD Act Btm (ftKB) 13,529.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292324360 Wellbore Status INJ Max Angle & MD Incl (°) 98.07 MD (ftKB) 8,166.01 WELLNAME WELLBORE1E-105 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:13,018.0 1E-105L2 6/21/2006 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PERFORATE L2 HOOK HANGER (D-LATERAL) 1E-105L2 12/2/2019 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: Deflated IBP in D-Lateral and pushed to bottom 4/20/2020 rwocoman NOTE: PROFILE MODIFICATION - PUMPED 2310 LBS (4MM) CRYSTAL SEAL IN B LATERAL MBE@8750 9/4/2011 haggea NOTE: MBE repair w/9 bbls of 1G1-2289E, 105 degree meltpoint wax @ 8750' 9/11/2010 lmosbor NOTE: B-SAND LEM CONTAINS CAMCO 'DB' NIPPLE w/3.562" PROFILE @ 7578' 6/18/2006 famaj NOTE: TRI-LATERAL WELL: A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) 6/18/2005 WV5.3 Conversio n NOTE: 8.5" OPEN HOLE BEHIND SLOTTED LINER 6/18/2005 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 HH 5 1/2 4.95 7,260.4 7,416.3 3,558.2 15.50 L-80 BTCM D-SAND LINER 5 1/2 4.95 7,370.9 13,536.7 15.50 L-80 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) 7,287.8 3,534.6 78.03 XO BUSHING 6.030 CROSS OVER BUSHING 3.940 7,306.9 3,538.4 78.69 PACKER 6.000 BAKER PAYZONE EXTERNAL CASING PACKER 5.500 7,370.9 3,550.5 79.61 SLEEVE 7.000 BAKER 'HR' LINER SETTING SLEEVE 5.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,293.0 7,298.0 3,535.7 3,536.7 WS D, 1E-105L2 12/2/2019 6.0 APERF PERFORATE HOOK HANGER FOR RPPG JOB 8,024.0 8,399.0 3,533.0 3,511.7 WS D, 1E-105L2 6/16/2005 40.0 SLOTS Slotted Liner, alternating joints of blank/slotted liner for all D-Sand slots 2.5 x .125 holes, 4 rows/ft 8,612.0 9,120.0 3,505.5 3,489.8 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 9,331.0 9,794.0 3,485.8 3,486.4 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 10,181.0 10,602.0 3,475.6 3,468.9 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 10,587.0 11,070.0 3,468.9 3,461.4 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 11,415.0 11,457.0 3,468.8 3,471.2 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 11,885.0 12,387.0 3,460.6 3,430.6 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 12,688.0 12,773.0 3,419.9 3,415.8 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 12,860.0 12,945.0 3,412.3 3,410.0 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 12,988.0 13,074.0 3,408.9 3,407.6 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 13,118.0 13,201.0 3,406.4 3,403.6 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 13,244.0 13,329.0 3,402.7 3,400.2 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 13,366.0 13,492.0 3,399.0 3,396.5 WS D, 1E-105L2 6/16/2005 40.0 SLOTS 1E-105L2, 8/11/2025 2:31:15 PM Vertical schematic (actual) D-SAND LINER; 7,370.9- 13,536.7 SLOTS; 13,366.0-13,492.0 SLOTS; 13,244.0-13,329.0 SLOTS; 13,118.0-13,201.0 SLOTS; 12,988.0-13,074.0 SLOTS; 12,860.0-12,945.0 SLOTS; 12,688.0-12,773.0 SLOTS; 11,885.0-12,387.0 SLOTS; 11,415.0-11,457.0 SLOTS; 10,587.0-11,070.0 SLOTS; 10,181.0-10,602.0 SLOTS; 9,331.0-9,794.0 SLOTS; 8,612.0-9,120.0 SLOTS; 8,024.0-8,399.0 D-SAND LINER HH; 7,260.4- 7,416.3 APERF; 7,293.0-7,298.0 INTERMEDIATE; 25.1-8,290.0 D-SAND LINER LEM; 7,190.6- 7,492.5 ISO-SLEEVE; 7,258.0 GAS LIFT; 6,712.9 Cement Casing; 3,600.0 ftKB GAS LIFT; 4,217.0 SURFACE; 30.0-3,905.3 Cement Casing; 0.0 ftKB CONDUCTOR; 31.0-170.0 KUP INJ KB-Grd (ft) 30.59 RR Date 6/20/2005 Other Elev… 1E-105L2 ... TD Act Btm (ftKB) 13,530.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292324361 Wellbore Status INJ Max Angle & MD Incl (°) 98.63 MD (ftKB) 11,930.87 WELLNAME WELLBORE1E-105 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-19_22138_KRU_1E-105L1_InjectionProfile.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22138 KRU 1E-105L1 50-029-23243-60 Injection Profile 19-Nov-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 205-007 T38146 11/22/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.22 12:47:15 -09'00' OF Tb Iyyy' A THE STATE Alaska Oil and Gas o111c ji Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF .m Main: 907.279.1433 ALA44'P' Fax: 907.276.7542 www.aogcc.alaska.gov John Pierce 5t Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1E-105L1 Permit to Drill Number: 205-007 Sundry Number: 318-148 Dear Mr. Pierce: 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, tOQ Hollis S. French Chair DATED this day of April,2018. BDMSV APR 0 5 20/8 • • �} E CEIVED STATE OF ALASKA P c 3/N,3 i ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS kelPGCC 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations LI Fracture Stimulate LJ Repair Well LJ Operations shutdown LJ Suspend ❑ Perforate ❑, • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Gel TrtmnL ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: f<PP(./ ConocoPhilliDs Alaska, Inc. Exploratory ❑ Development ❑ 205-007 3.Address: Stratigraphic ❑ Service Q 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 500292324360 , 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 0No D KRU 1E-105L1 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 • Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): • 13,529' . 3,479' • 8209' . 3599' 1400 psi NONE NONE Casing Length Size MD ND Burst Collapse Conductor 139' 20" 170' 170' Surface 3,875' 13-3/8" 3,905' 2586' Intermediate 7,499' 9-5/8" 8,290' 3713' Production Liner 5987' 5-1/2" 13,510' 3,479' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner at 7622'-13249' • Slotted Liner at 3595'-3477' Perfs at 8746-8755', Perfs at 3556-3555', 4.500" L-80 7229' 8946-8950',and 9945'-9950' 3549'-3549',and 3525'-3525' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): ZXP LINER TOP PACKER w/HRD PROFILE 7461'MD and 3572'ND ` SSSV:NIPPLE 503'MD and 503'ND • 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., r 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/1/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr., Wells Engineer Contact Email: John.W.Peirce@cop.com Authorized Signature: j"y,., •-e. Date: 4/2 I Ve) Contact Phone: (907)265-6471 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 g.... /14 I , Plug Integrity ❑ BOP Test El Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Ilf Subsequent Form Required: 1 t — 0 '. APPROVED BY (I /S I Approved by: �t— 1j COMMISSIONER THE COMMISSION Date: ilk 'INN vrL 41 57/1 V� � RBDMS.A- APR 0 5 2018,ubmit Form and y Form 10-403 Revised 4/2017 Approved apppt;R5IBINALfm the date of approval. Attachments in Duplicate • ! Proposed 1E-105L1 to 1E-126L1 B Sand MBE Retreatment with RPPG 1E-105 Tri-Lateral injector was drilled and completed in 2005 with West Sak A, B, & D Sand laterals. The 1E-105L1 B Lat has a 5.5", L-80 slotted liner. 3 MBE's (Matrix Bypass Event) have occurred in 1 E-105L1. The first was on 12/28/05 from 1 E-105 to 1E-126 producer. A 6/20/06 (PROF found a B MBE at 8750' RKB taking all PWI. On 9/4/11 a Crystal Seal job sealed this MBE, and the treatment lasted —2 years until 1 E-126 rising WC% indicated a new MBE existed from 1E-105. An IPROF of 1/28/14 in 1E-105L1 showed a new MBE at 8950 - 9150' area. The MBE at 8950 - 9150' RKB was sealed by Crystal Seal job on 9/23/15 and lasted —1 year until the 1 E-126 WC% spiked again. An (PROF ran 1/29/17, found a new MBE in 1E-105L1 at 9950' RKB, but the two previously treated MBE's were not taking fluid. A 1E-105L1 B MBE RPPG job was pumped 5/1/17. Post-RPPG FCO, the 'B Lat only' was BOI for 1 month with 1 E-126 showing lower WC% and rising BOPD, so the A Lat Plug & D Iso-Sly were pulled to get all Lats on injection, but this caused a spike in 1 E-126 WC%. On 6/18/17, a mainbore IPROF saw 73% D, 26% B, 1% A (suggests a new D MBE). On 9/18/17, a D IPROF found all injection exiting the D Lat at —7260' RKB near the D LEM junction, and then injection was flowing down backside of D Liner to top of the first slotted liner —764' below the D LEM. The D MBE location is unknown, but the log suggests an MBE (or high perm thief) most likely exists behind 764' of blank liner section up hole of the first slots. The D MBE will be treated with MARCIT (per 2/26/18 AOGCC approval #318-068), but in the meantime, a Plug was set 2/2/18 at 7578' RKB to isolate A Lat, and a B Diverter was set, and a D Iso-Sly was set to reconfigure 1E-105 for a B (PROF. The B Lat IPROF on 3/10/18 confirmed that the B MBE at —9950' RKB reopened again and requires a retreatment. 1E-105 is currently configured for the B MBE retreatment. Thus, it is proposed (below) that the B MBE be retreated with RPPG and evaluated before reconfiguring for a D MBE MARCIT job. The D MBE treatment with MARCIT would be performed after a successful B MBE treatment. Proposed Procedure Coil Tubing: 1) RIH to shoot 5' of 'big hole' add perforations at 9950 - 9955' RKB near the B MBE at —9950' RKB. These perfs are intended to double the number of perfs located near the B MBE to provide better passage of RPPG through the slotted liner to the MBE. 2) Verify 1E-126 producer is online and put 1E-105 BOI at —1500 BWPD at 12 - 24 hrs before CTU RU on 1E-105. Flow 1E-126 to 1E test separator to avoid CPF1 upset. This reestablishes flow through the MBE between wells to ensure MBE is open for RPPG, and pushes away the 'gas head' from 1E-105 to the MBE. Ideally, we want the tubing `liquid packed' for pumping the RPPG treatment. RU CT with 2" CT on 1E-105. Request that 1E-126 be SI when CT is ready to RIH, but keep 1E-105 on PWI —1500 BWPD. RIH with a large single 'down port' Nozzle while displacing Diesel FP from CT by pumping —50 bbls of 2% KCL Water down CT at —0.5 bpm while warm 130°F PWI continues down CT x Tbg annulus. • • Park the Nozzle at `safety' (above all liner slots) at 7620' RKB, and then halt pumping down CT while checking the WHIP on CT x Tbg. Record starting WHIP on tubing. Any 'gas head' that may have been in the tubing earlier should have been fully displaced away from the tubing to the MBE, so expected WHIP on tubing should be less than 100 psi to start the RPPG treatment. SI PWI to 1 E-105 CT x Tbg annulus, and swap over to pumping warm 2% KCL Water from a full 290 bbl transport down CT x Tbg annulus at minimum rate (target 0.4 bpm), to keep well warm and keep CT x Tbg annulus flushed of any potential RPPG coming up CT backside during RPPG pumping as precaution to prevent stuck CT. More importantly, the 2% KCL Water pumped down CT backside from this point forward displaces away all PWI to MBE to eliminate presence of any residual hydrocarbons (which exist in PWI) that can negatively affect proper hydration and swell of RPPG in the MBE during treatment which might impact treatment success. Pump a short Step Rate Injection Test (SRIT) down CT with 2% KCL Water at 1 bpm, 1.5 bpm, and 2 bpm to record a stable CT treating pressure at each rate. Pick a steady treating rate between 1 to 2 bpm that yields a good starting CT treating pressure somewhere in range of 1000 - 2000 psi. After a steady pump rate is determined, start mixing 2% KCL Water from a transport with 1 - 4 mm mesh RPPG at 0.75 ppg concentration (31.5 lbs/bbl) in mixing van to make RPPG slurry on-the-fly while pumping it down CT at established steady rate. Pump 0.75 ppg RPPG slurry in 2% KCL Water until WHP on CT x Tbg annulus reaches -800 psi, then swap from RPPG slurry to pumping 1 CT volume of 2% KCL Water Spacer (-50 bbls) while maintaining the steady established rate down CT, followed by 47 bbls Diesel FP, followed by another full CT volume (-50 bbls for CT Diesel FP), followed by SD. During the treatment pumping schedule (above), CT will start POOH from 'safety' to surface when the first Diesel FP starts entering CT. The 2% KCL Water pumping down CT x Tbg annulus will be halted when the nozzle reaches 7000' in 4.5" tubing, which should slow rate of WHP pressure rise as WHP climbs toward target Frac pressure of -1200 psi WHP. Pump rate down CT can be reduced to keep WHP < 1200 psi, if needed. However, a short duration of WHP > 1200 psi, if needed, to get all Diesel FP away is not considered to be detrimental to the RPPG MBE treatment. RD CTU. Wait 2 days for RPPG particles to fully crosslink in MBE before returning 1E-105L1 to PWI. Coil Tubing - FCO RPPG (optional, if needed): 3) RIH with jet swirl nozzle to tag RPPG in 1 E-105L1. Jet down through RPPG with Diesel to as deep as possible while injecting away RPPG and Diesel to MBE &/or formation. POOH. RD CTU. Place 1 E-105L1 on injection to evaluate results of B MBE treatment. Evaluate `B only' PWI performance and monitor offset producer 1 E-126 performance to verify that the B MBE has been isolated. If B MBE treatment is evaluated as successful, then the previously approvedl E-105L2 D MBE treatment with MARCIT Gel will be executed, as per AOGCC Approval # 318-068 of 2/26/18. •UP INJ 1E-105 A 1 Well Attributes ax Angle&MD TD ConocoPhillips (Wellbore API/UWI Field Name Wellbore Status !Inc! MD(ftKB) Act BM(ftKB) Alaska,Inc. 500292324300 WEST SAK INJ In 96.20 8,942.81 13,539.0 --morOprealps Comment H2S(ppm) Date Annotation End Dale KB-Grd(ft) Rig Release Date """ SSSV:NIPPLE Last WO: 30.59 6/20/2005 1E-105,2/5/2018 1:3923 PM Last Tag Vertlul schematic(actual) Annotation Depth(ftKB) End Date Last Mod By ......................................................................._....................................._.Last Tag: 13,018.0 6/21/2006 Imosbor HANGER;22.6 /1-Li°5x11 Last Rev Reason Annotation End Date Last Mod By t, Pim Rev Reason:PULL DIVERTER/TYPE II ISO SLEEVE,SET DB PLUG w/PRONG,DIVERTOR 2/5/2018 pproven CONDUCTOR;31.0-170.0 in D LAT LEM NIPPLE;5032 _ Casing Strings Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread II CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;30.0-3.905.3 SURFACE 133/8 12.415 30.0 3,905.3 2,285.7 68.00 L-80 BTC GAS LIFT;4,217.0III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT;8,712.9 ` INTERMEDIATE 95/8 8.835 25.1 8,290.0 3,713.1 40.00 L-80 BTCM SLEEVE;7,183.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread A-SAND LINER 5 1/2 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM sF' Liner Details LOCATOR;7,211.1 . M". Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) SEAL ASSY;7.211.8 = 7,619.1 3,601.2 79.40 PACKER HRDZXP LINER TOP PACKER 4.970 7,637.6 3,604.6 79.61 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 ISO SLEEVE;7,240.0 til I(( 7,640.4 3,605.1 79.64 HANGER FLEX-LOCK LINER HANGER 4.853 I! i• 7,649.4 3,606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 1Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - - D-SAND LINER LEM 4 1/2 3.958 7,190.5 7,492.5 3,5772 12.60 L-80 IBTM Liner Details I Nominal ID MI 7 Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (in) D-SAND LINER LEM:7,190.6- 7,190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKERw/HRD PROFILE 7.500 7,492.5 7,213.4 3,517.2 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 DIVERTER;7,520.0 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 B-SAND LINER LEM;7,461.5- •t2 r!: 7,240.3 3,523.7 76.05 HANGER LEM ABOVE HOOK HANGER 3.980 7,881.8 B-SAND LINER;7,523.0- ;1t- 1: 7,254.4 3,527.1 76.03 HANGER LEM INSIDE HOOK HANGER 3.688 13,509.9 7,489.2 3,576.6 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 PLUG;7,558.0 7 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection -- =- TUBING 41/2 3.958 22.6 7,229.2 3,521.0 12.60 L-80 IBTM Completion Details Top(TVD) Top Incl Nominal Top(ftKB) (ftKB) 7) Item Das Com ID(in) I I 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 INTERMEDIATE;25.1-0,290.0 _ _ 503.2 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE ' 3.875 ` 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE(CLOSED 3.810 6/27/05) SLOTS;8,312.0-8,774.0--4 _ _ 7,211.1 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 ` 7,211.8 3,516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) -4 P- Top(TVD) Top Incl Top(ft)(B) (MKB) (') Des Com Run Date ID(in) '- 7,240.0 3,523.6 76.05 ISO SLEEVE TYPE 2 ISOSLEEVE(2.59"ID) 2/2/2018 2.590 SLOTS;9,030.0-9,498.0 7,520.0 3,582.3 79.11 DIVERTER TYPE 1 DIVERTER 2/2/2018 0.000 r 7,558.0 3,589.6 78.72 PLUG DB PLUG BODY(OAL=25.5")WITH PRONG 2/1/2018 0.000 (OAL=7.71')SET IN PLUG BODY Perforations&Slots n- Shot Dens Top(TVD) BM(TVD) (shots/ft APERF;9,815.0.9,850.0 o.- Top(ftKB) BM(ftKB) (ftKB) (ftKB) Zone Date I Type Com 8,312.0 8,774.0 3,716.9 3,726.6 WS A2,1E-105 5/18/2005 0.0 SLOTS Slotted Liner,altemating jts -. _- ofblank/slottedlinerforallA- SLOTS;9,710.0-10.473.0 Sand slots 2.5 x.125 holes, 4 rows/ft 9,030.0 9,498.0 3,702.2 3,694.9 WS A2,1E-105 5/18/2005 40.0 SLOTS Slotted Liner,alternating jts of blank/slotted liner for all A- - .- Sand slots 2.5 x.125 holes, ` 4 rows/ft --, .- 9,710.0 10,473.0 3,703.6 3,685.1 WS A2,1E-105 5/18/2005 40.0 SLOTS Slotted Liner,alternating jts I,- of blank/slotted liner for all A- Sand slots 2.5 x.125 holes, SLOTS;1S,731.0-11,114.0---------. r 4 rows/ft • 5 r y r 9,945.0 9,950.0 3,708.3 3,708.4 WS D,1E- 4/25/2017 6.0 APERF 6 SPF,60 DEG PHASE •• ..- 105L2 (SLB 2.0"POWERFLOW -. • PERF GUNS) -1 r 10,731.0 11,114.0 3,669.7 3,658.2 WS A2,1E-105 5/18/2005 40.0 SLOTS Slotted Liner,altemating jts of blank/slotted liner for all A- Sand slots 2.5 x.125 holes, SLOTS;11,584.0-12,090.0 - 4 rows/ft .-- 11,584.0 12,090.0 3,665.2 3,659.9 WS A3,1E-105 5/18/2005 40.0 SLOTS Slotted Liner,alternating jts .- ofblank/slottedlinerforallA- Sand slots 2.5 x.125 holes, 4 rows/ft - °-- 12,348.0 12,603.0 3,649.4 3,631.0 WS A3,1E-105 5/18/2005 40.0 SLOTS Slotted Liner,alternating jts SLOTS;12,348.0-12,503.0 of blank/slotted liner for all A- Sand slots 2.5 x.125 holes, ._ 4 rows/ft --. 12,902.0 13,455.0 3,624.7 3,624.7 WS A3,WS A2, 5/18/2005 40.0 SLOTS Slotted Liner,alternating jts 1 E-105 of blank/slotted liner for all A- -7 ~ Sand slots 2.5 x.125 holes, 4 rows/ft SLOTS:12.902.0-13,455.0 r A-SAND LINER;7,819.1- 13,519.01 SUP INJ 1E-105 ConocoPhillips Pa �, Alaska,Inc. •inocoPtvatpc 1E-105,2/5/2018 1:39:25 PM Vertical schematic(actual) HANGER;22.6 CONDUCTOR; 11 I 31.0-770.0 NIPPLE;5032 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run SURFACE;30.0-3,905.3 • N Top(9KB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT;4,217.0 1 4,217.0 2,399.1 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 111 1R GAS LIFT;6,712.9 2 6,712.9 3,383.2 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 SLEEVE;7,163.9 1R ' Notes:General&Safety LOCATOR;7,211.1 End Date Annotation SEAL ASSY;7,211.6 f 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' � 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) ISO SLEEVE;7.240.o �� , 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 �ki i 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 !1h D-SAND LINER LEM;7,190.6- _ 7,492.5 ANN DIVERTER;7,520.0 B-SAND LINER LEM;7,461.5- •1��. 7,661.8 I B-SAND LINER;7,523.0- 13,509.9 PLUG;7,558.0 - G. ..E11 1 I I INTERMEDIATE;25.1-8,290.0 SLOTS;8,312.0-8,774.0 SLOTS;9,030.0-9,498.0 APERF;9,945.0-9,950.0 SLOTS;9,710.0-10,473.0 SLOTS;10,731.0-11,114.0 SLOTS;11,584.0-12,090.0- SLOTS; 15840-12,090.0SLOTS',12,348.0-12,6030 SLOTS;12,902.0-13,455.0 A-SAND LINER;7,619.1- ' 13,519.0 r. ~\ KUP INJ 1E-105L1 r • ��nO��rl 1��nS \1 Well Attributes Max Angle&MD TD f I Wellbore API/UWI Field Name Wellbore Status not(") MD(ftKB) Act Btm(ftKB) Alaska,Inc. 500292324360 WEST SAK INJ 98.07 8,166.01 13,529.0 oao%vups cm . Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date .°° SSSV:NIPPLE Last WO: 30.59 6/20/2005 1E-105L1,40/2018 10:02:43 AM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By ..........._..._.........._...........................__._ Last Tag: 13,018.0 6/21/2006 ninam HANGER;22.8-4 ` 1 Last Rev Reason Annotation End Data Loot Mod By IIRev Reason:Correct pert data from 4/25/2017 jennalt • II Casing Strings ,r-.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR;31.0.170.0 B-SAND LINER 51/2 4.950 7,523.0 13,509.9 3,479.4 15.50 L-80 BTCM NIPPLE;5032 Liner Details • Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID (in) 7,523.0 3,582.9 79.07 HANGER BA 7,550.3 3,587.5 81.44 XO BUSHING XOKER BUSHINGMODEL B-1 HOOK HANGER FOR LEM 7.000 5.500 SURFACE;30.0-3,905.3 ♦ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B-SAND LINER LEM 4 1/2_ 3.958 7.461.5 7,661.8 3,598.5 12.60 L-80 IBTM GAS LIFT;4,217.0 S Liner Details MN GAS LIFT;8,712.9 411. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SLEEVE;7,183.9 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 • 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 ' .a -..s 4 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 LOCATOR;7,211.1 -r 1.11r r 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 1 n f 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 3.960 SEPI ASSY;7,211.8 7,509.1 3,580.2 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 Ink 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 _ 7,578.0 3,591.0 83.95 NIPPLE CAMCO'DB'NIPPLE w/3.563"PROFILE 3.958 ISO SLEEVE;7,240.0 !Vi I1'411 Perforat7,658.6Ions&Slots 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Shot Dens Top(TVD) Bbn(TVD) (shots/ft Top(ftKB) Btm(ftKB) MKS) (MB) Zone Date I Type Corn 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating 105L1 joints of blank/slotted liner for all B-Sand slots 2.5 x.125 holes,4 rows/ft Mr 8,140.0 8,472.0 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 SLOTS D-SAND LINER LEM;7,190.& 105L1 7,492.5 0 8,733.0 9,029.0 3,555.9 3,548.6 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 I 8,745.0 8,750.0 3,555.5 3,555.4 9/4/2011 6.0 (PERF 60 DEC PHASING w10.43" HOLES ,;:1rfr 8,750.0 8,755.0 3,555.4 3,555.2 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26"ENT DIVERTER;7.520.0 - ,. 105L1 hole,60 deg phase l r. I, 8,945.0 8,950.0 3,549.1 3,549.1 WS B,1E- 8/20/2015 6.0 APERF 2"Powertlow HSD guns INTERMEDIATE;25.1-8,290.0 I'i rr4 105L1 (2006 FP,6 SPF,60 Deg, 't1 IJ I EDH 0.45",4.5"PEN 9,328.0 9,623.0 3,543.4 3,531.7 WS B.1E- 5/29/2005 40,0 SLOTS 9,926.0 10,385.0 3,525.4 3,517.2 VVS WS B,B,1E- 5/29/2005 40.0 SLOTS 105L1 9,945.0 9,950.0 3,525.2 3,525.2 WS B,1E- 4/25/2017 6.0 APERF 6 SPF,60 DEG PHASE 1 105L1 (SLB 2.0"POWERFLOW PERF GUNS) 10,644.0 11,023.0 3,513.7 3,516.6 WS B,1E- 5/29/2005 40.0 SLOTS B-SAND LINER LEM;7,481.5- -I - 105L1 7 _ - 11,669.0 11,881.0 3,529.9 3,510.5 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;7022.0-7,750.1,7S0,i-- - _ 105L1 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;8,140.0-8,472.0 _ _ 105L1 12,738.0 13,249.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS - - 105L1 GEL SOZ;8,745.01918 (PERF;8,745.0-8,750.0 - Cement Squeezes RPERF;8,750.0-8,755.0 - Top(ND) Btm(ND) SLOTS;8,733.0-9,029.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com APERF;8,945.0-8,950.0- 8,745 0 8,750.0 3,555.5 3,555.4 GEL SQZ 9/4/2011 - - Notes:General&Safety -. _ End Date Annotation 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),DSAND(1E-105L2) SLOTS;9,328.0-9,623.0 - 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 _ _ 9/11/2010 NOTE:MBE repairw/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' APERF;9,945.0-8,950.0 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS4MM CRYSTAL SEAL IN B LATERAL8750 SLOTS;9.928.0-10,385.0- ( ) MBE@8750 _ 5/1/2017 NOTE:Coil Tubing RPPG Treatment 4190 Lbs to B MBE in 1E-105L1 SLOTS:10,844.0-11,023.0-. SLOTS;11,889.0-11,881.0-•-• - SLOTS;12,289.0-12,437.0 - SLOTS;12,738.0-13,249.0 - B-SAND LINER;7,523.0- 13,509.9 STATE OF ALASKA ALASIIIL AND GAS CONSERVATION COMMISSION") REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE GEL JOB 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 205-007 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic Service❑, 6.API Number: 99510 50-029-23243-60 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-105L1 ADL 25651,ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 13,529 feet Plugs measured None feet true vertical 3,479 feet Junk measured None feet Effective Depth measured 8,209 feet Packer measured 7190, 7462, 7619 feet true vertical 3,599 feet true vertical 3512, 3572,3601 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 139 feet 20 " 170'MD 170 SURFACE 3,875 feet 13 3/8" 3,905'MD 2286 INTERMEDIATE 7,499 feet 9 5/8" 8,290'MD 3713 B-SAND LINER 5,987 feet 5 1/2" 13,510'MD 3598 RECEIVED MAY 192017 Perforation Depth Measured depth 7622-13249 feet AOGCC True Vertical depth 3533-3396 feet Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,229'MD 3,521'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,190'MD 3,512'TVD PACKER= HRD ZXP Liner Top Packer 7,462'MD 3,572'TVD PACKER=HRD ZXP Liner Top Packer 7,619'MD 3,601'TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED JUN N 3 r 0 Treatment descriptions including volumes used and final pressure: tai I Y zT 11 17, 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: - - 447 - 3 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ ExploratoryD Development❑ Servid Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPLE Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-079 Contact Name: John Peirce Authorized Name: John Peirce Contact Email:John.W.Peirce@conocophillips.com Authorized Title: Sr.Wells Engineer lT. ,f /a c7 Contact Phone: (907)265-6471 Authorized Signature: Date: 5/1$ / Form 10-404 Revised 4/2017I` ?/l, 4/3 RBDMS L'V MAY 1 9 2017 Submit Original Only • • 1E- 105L1 DTTMS'JOBTYP SUMMARYOPS 2/13/17 MECH ZONE RIH AND RETRIEVE TYPE-1 ISO-SLEEVE AT 7500' CTMD, RIH AND SET TYPE-1 DIVERTER IN B LEM AT 7520', RIH AND SET TYPE-2 ISO-SLEEVE ACROSS D LEM AT 7234'. ***JOB COMPLETE*** 4/24/17 NRWO PERFORM PASSING MIT-IA, RIH WITH 3.5" NOZZLE, TAG ISO SLEEVE AT 7234' CTMD, FLAG PIPE, JOB IN PROGRESS. 4/25/17 NRWO RIH WITH SLB 2.0" POWERFLOW PERF GUNS, 6 SPF, 60 DEG PHASE, CORRECT DEPTH AT FLAG, FIRE GUNS FROM TOP SHOT AT 9945' RKB TO BOTTOM SHOT AT 9950' RKB, PUMP 40 BBLS DIESEL F/P WHILE POOH, READY FOR OPS TO BOL AT 1000 BWPD, JOB IN PROGRESS. 5/1/17 NRWO RIH TO 8740' RKB, PUMP 4190 LBS OF REFORMED PARTICLE POLYMER GEL (RPPG) INTO THE B LATERAL MBE, AVERAGE CONCENTRATION OF .68 PPG, FOLLOW WITH 220 LBS OF MI POLYSWELL WITH AVERAGE CONCENTRATION OF .24 PPG, F/P TBG WHILE POOH, READY FOR FCO IN 48 HRS, JOB IN PROGRESS. 5/4/17 NRWO RIH WITH XRV, DJN. FLUFF-N-STUFFED DOWN TO LOCK UP AT 13224.6' CTMD, LRS PUMPING DOWN THE BACKSIDE AND COIL PUMPING DOWN THE COIL. DID NOT GET RETURNS, TURNED WELL OVER TO DSO. (JOB COMPLETE) KUP I 1E-105L1 _ConocoPhillips 4 Well Attribu Max Angl TD Alaska.Inc. WellboreAPI/UWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) Conocatigips 500292324360 WEST SAK INJ 98.07 8166.01 13,529.0 A.... �, Comment H2S(ppm) Date Annotation End Date KB.Grd(ft) Rig Release Date 1E-1VSL1,5/16201711;5533 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 VerSoal schemayc:(achol) Annotation Depth(ftKB) End Date Annotation Last Mai By End Date Last Tag: 13,018.0 6/21/2006 Rev Reason:PERFORATIONS hipshkf 8/20/2015 HANGER;22.6 it �`- Casing Strings �. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread € f; ii B- SAND LINER 51/2 4.950 7,523.0 13,509.9 3,479.4 15.50 L-80 BTCM Liner Details CONDUCTOR;31.5-170.0 Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com Nominal ID (in) NIPPLE;503.2 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 7,550.3 3,587.5 81.44 XO BUSHING XO BUSHING 5.500 l':- Casing Description OD(in) ID(in) "Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread B-SAND LINER LEM 4 1/2 3.958 7,461.5 7,661.8 3,598.5 12.60 L-80 IBTM Liner Details • SURFACE;30.0.3,905.3-• A Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;4,217.0 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 GAS LIFT;6,712.9 r 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 SLEEVE;7,163.9 I/M1 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 + 1jr_r 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 3.960 LOCATOR;7,211.1r• 7,509.1 3,580.2 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 _ 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 SEAL ASSY;7,211.6 ;w_ 7,578.0 3,591.0 83.95 NIPPLE CAMCO DB'NIPPLE w/3.563"PROFILE 3.958 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 1 s Top(ND) Top Incl -3';' Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ISO SLEEVE.7,258.0 e Ii' 7,541.0 3,586.0 80.60 DIVERTER TYPE 1-B-LAT DIVERTER 2/23/2017 0.000 1f iii I 11 Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating a,-a . 105L1 joints of blank/slotted liner for all B-Sand slots 2.5 x.125 holes,4 rows/ft DSAND LINER LEM;7,190.6- 8,140.0 8,472.0 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 SLOTS 7,492.5 105L1 8,733.0 9,029.0 3,555.9 3,548.6 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 It 8,745.0 8,750.0 3,555.5 3,555.4 9/4/2011 6.0 IPERF 60 DEG PHASING w/ 0.43"HOLES INTERMEDIATE;25.1-8,280.0 .111 8,750.0 8,755.0 3,555.4 3,555.2 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26"ENT DIVERTER;7,541.0 t) _� 105L1 hole,60 deg phase it _8,945.0 8,950.0 3,549.1 3,549.1 WS B,1E- 8/20/2015 6.0 APERF 2"Powerflow HSD guns 105L1 (2006 FP,6 SPF,60 a- -ri.m Deg,EDH 0.45",4.5" I PEN 9,328.0 9,623.0 3,543.4 3,531.7 WS 8,1E- 5/29/2005 40.0 SLOTS 105L1 I 9,926.0 10,385.0 3,525.4 3,517.2 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 10,644.0 11,023.0 3,513.7 3,516.6 WS B,1E- 5/29/2005 40.0 SLOTS B-SAND LINER LEM;7.461.5- 105L1 SLOTS;7.6zz.a7,70o.1 7,801 -- 11,669.0 11,881.0 3,529.9 3,510.5 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;8,140.k8,472.0-. _ 105L1 - 12,738.0 13,249.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS (PERF;8,745.0-8,750.0 105L7 GEL SW;8,745.0ftKB .._ Cement Squeezes RPERF;8,750.08,755.0 Top(TVD) Btm(ND) SLOTS;8,733.09,029.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com APERF;8,945.0-8,950.0-. - 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ 9/4/2011 Notes:General&Safety End Date Annotation 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),DSAND(1E-105L2) SLOTS:9,328 0-9,623.0 -- 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;9,926.0-10,385.0 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 SLOTS;10,644.0-11,023.0 SLOTS;11,669.0-11,881.0 SLOTS;12,288.o-12,437.0 SLOTS;12,738.0-13,249.0 B-SAND LINER',7,523.0- 13,509.9 . KUP 1E-105 ConocoPhiliip5 .• Well Attribu Max Angl D TD Alaskainc. . : Wellbore APIIUWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) CoonUOPh,Il iG 500292324300 WEST SAK INJ 96.20 8,942.81 13,539.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-105,5/1820179:03:23 AM '-'SSSV:NIPPLE Last WO: 30.59 6/20/2005 Val-haat schamahc(actual). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date �.. � Last Tag: 13,018.0 6/21/2006 Rev Reason:PULL ISO-SLEEVE's,SET ISO- pproven 4/5/2017 HANGER;22.6 s,__;•-"® SLEEVE,SET TYPE 1 DIVERTER Casing Strings O' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;31.0-170.0 CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED NIPPLE;503.2 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 133/8 12.415 30.0 3,905.3 2,285.7 68.00 L-80 BTC II II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread 1 ipl INTERMEDIATE 95/8 8.835 25.1 8,290.0 3,713.1 40.00 L-80 BTCM SURFACE;30.0-3,905.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I GAS LIFT;4,217.0 A-SAND LINER 5 1/2 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM rdiptili GAS LIFT;6,712.9 f AK Liner Details NOM SLEEVE;7,183.9 Nominal ID `'ir. Top(kKB( Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 7,619.1 3,601.2 79.40 PACKER HRD ZXP LINER TOP PACKER 4.970 LOCATOR;7,211.1 7,637.6 3,604.6 79.61 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 - r SEAL ASSY.7,211.8 i 7,640.4 3,605.1 79.64 HANGER FLEX-LOCK LINER HANGER 4.853 7,649.4 3,606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 �tl rt Casing Description IOD(in) IID( in) !Top(ftKB) ISet Depth(kKB) 'Set Depth(ND)...I WVLen(I...Gratle Top Thread Ir: LI D-SAND LINER LEM 41/2 3.958 7,190.5 7,492.5 3,577.211 12.60 L-80 IBTM ISO SLEEVE;7,258.0 Si Pt k 51 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl p) Item Des Com (in) 7,190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7,213.4 3,517.2 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 D-SAND LINER LEM;7,190.6- 7,492.5 Si... 7,240.3' 3,523.7 76.05 HANGER LEM ABOVE HOOK HANGER 3.980 7,254.4 3,527.1 76.03 HANGER LEM INSIDE HOOK HANGER 3.688 B-SAND LINER;7,523.0. 13,509.9 7,489.2 3,576.6 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880' B-SAND LINER LEM;7,481.5- ti 4 !.11: 7,661.6 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 22.6 7,229.2 3,521.0 12.60 L-80 IBTM PLUG;7,578.0 Completion Details Nominal ID /Ill Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 5032 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE 3.875 1 I 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE 3.810 INTERMEDIATE;25.1-8,290.0 (CLOSED 6/27/05) 7,211.1 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 7,211.8 3,516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 SLOTS;8,312.0-6,774.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) - - 7,578.0 3,593.5 78.94 PLUG A SAND DB PLUG W/PRONG 7/24/2015 0.000 Perforations&Slots Shot Dens SLOTS;8,030.0-9498.0 Top(TVD) Btm(ND) (shots/ 1- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date to Type Com 8.312.0 8,774.0 3,716.9 3,726.6 WS A2,1E- 5/18/2005 0.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots -) 2.5 x.125 holes,4 rows/ft 9,030.0 9,498.0 3,702.2 3,694.9 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots SLOTS;9,710.0-10,473.0-.12.5 x.125 holes,4 -1 rows/ft 9,710.0 10,473.0 3,703.6 3,685.1 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted -� liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 10,731.0 11,114.0 3,669.7 3,658.2 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating sLo7s;1n,731.o-11,tu.o 105 joints of blank/slotted - liner for all A-Sand slots 2.5 x.125 holes,4 -1 rows/ft - -- 11,584.0 12,090.0 3,665.2 3,659.9 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 -- rows/ft SLOTS,11,584.012,090.0 _ _ 12,348.0 12,603.0 3,649.4 3,631.0 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted -" liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 12,902.0 13,455.0 3,624.7 3,624.7 WS A3,WS 5/18/2005 40.0 SLOTS Slotted Liner,alternating SLOTS;12,348.0-12,923.0 _ A2,1E-105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft Mandrel Inserts -" - St ati SLOTS;12902.0-19455.0 _ on Top(ND) Valve Latch Port Size TRO Run 1 = N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,217.0 2,399.1 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 1R A-SAND LINER;7,619.1- 1 I 13,519.0 1 l KUP 1E-105 ConocoPhillips Alaska,Inc, Can**:Mn ... 1E-105,5/18/2017 9:03:23 AM Verbal..0.0140(oytrr 0 HANGER.22 i,ant Mandrel Inserts ". 1 S ati CONDUCTOR;31.0-170.0 on NIPPLE,503.2 N Top(TVD) Valve Latch Port Size TRO Run Top(tKB) (tKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 2 6,712.9 3,383.2 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 1R SURFACE;30.0-33.905.3 Notes:General&Safety GAS LIFT;4,217.0 End Date Annotation GAS LIFT;6,712.9 F' 6/18/2006 NOTE.B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' SLEEVE;7,163.9PSI 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;7,211.1 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' SEAL ASSY;7,211.8 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 ISO SLEEVE;7,258.0 ` JI D-SAND LINER LEM;7,190.6- 7,492 5 7,492.5 0-SAND LINER;7.523.0- 13,509.9 8-SAND LINER LEM;7,461.5- 0114° J, 7,861.8 PLUG;7,578.0 INTERMEDIATE;25.18.290.0 SLOTS;8,312.0-8,774.0 SLOTS,9.030.0-9 498.0 r SLOTS;9,710.0-10,473.0.-----.1 SLOTS;10,731.0-11,114.0 SLOTS; SLOTS;12,348.0-12,603.0 1 SLOTS;12,902.0-13,455.0 A-SAND LINER;7,619.1- 13,519.01 - • 8o2-..P WELL LOG TRANSMITTAL PROACTIVE DIAq,NOSTIC SERVICES, INC. RECEIVED DAT /A LO/2C1 EE(D �/ wl K. BENDER MAR 0 1 2017 To: AOGCC AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED MAY 1) Injectiion Profile 29-Jan-17 1E-105 L1 Color Log/CD 50-029-23234-60 2) Signed : M/agossza.j"/) ..es tA�RJt Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D AAchives\MasterTemplateFi les\Templates\Distribution\Transmittals heels\ConocoPhillips_Transmit.docx SOF Tit IP I72 THE STATE Alaska Oil and Gas fAo LASKA Conservation Commission t£t 333 West Seventh Avenue ‘ 7. GOVERNOR BILL WALKER ,�..... Anchorage, Alaska 99501-3572 4 � Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells EngineerMAR 2 `.i,�1/, ConocoPhillips Alaska, Inc. SCAN dIED P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-105L1 Permit to Drill Number: 205-007 Sundry Number: 317-079 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, 1� Daniel T. Seamount, Jr. Commissioner DATED this e3 day of February, 2017. RB®ISS AV FEB 2 7 2017 • • • RECEIVED STATE OF ALASKA �� X017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS G CC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate E Repair Well E Operations Shutdown E Suspend E Perforate rOther Stimulate r Pull Tubing r Change Approved Program E Plug for Redrill E Perforate New Pool E Re-enter Susp Well E Alter Casing r Other: MBE GEL JOB i✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory E Development r 205-007. 3.Address: 6.API Number: Stratigraphic r Service F P.O.Box 100360,Anchorage,Alaska 99510 50-029-23243-60 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1E-105L1 • Will planned perforations require a spacing exception? Yes r No v 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 • Kuparuk River Field/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): 13,529'• 3,479' • - 8209 • 3599 1400 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 139' 20" 170' 170' Surface 3,875' 13 3/8 3,905' 2,286' Intermediate 7,499' 9 5/8 8,290' 3,713' Liner 5,987' 5 1/2 13,510' 3,479' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner 7622-13249• 3595-3477 4.500" L-80 7,229' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=PACKER ZXP LINER TOP PACKER MD 7815 TVD=5822 PACKER=PACKER ZXP LINER TOP PACKER MD 8130 TVD=6095 SSSV: =NONE N/A 12.Attachments: Proposal Summary E Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory r Stratigraphic r Development E Service F 14.Estimated Date for 3/14/2017 15.Well Status after proposed work: Commencing Operations: OIL r WINJ F ' WDSPL E Suspended E 16.Verbal Approval: Date: GAS r WAG E GSTOR E SPLUG r Commission Representative: GINJ E Op Shutdown — Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer 2 114 /17 Signature Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3V/ .-- 07 1 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 1 4C f. 241:q11 J i �11 Other: J -� 4 � �i1 �� o�E•�fb. 4� � �,�J ty Post Initial Injection MIT Req'd? Yes ❑ NoV p� r 7 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: ` U 4 / RBDMS l r �o�r APPROVED BY /2 2 Approved by: y� ie4N, .10COMMISSIONER THE COMMISSION Date: Z 3 17 , L2 2It Submit Form and PFor 10-4gi yi� 11/27ill I' . is valid for 12 months from the date of approval. Attachments in Duplicate 2Fr (( l KUP 10 1E-105L1 rConoroPhillips a Well Attributes Max Angle D TD Alaska ir1e. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,i9tp, 500292324360 WEST SAK INJ 98.07 8,166.01 13,529.0 A- ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-105L1,2/13/20178:52:35 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vortcal>schemabo(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 13,018.0 6/21/2006 Rev Reason:PERFORATIONS hipshkf 8/20/2015 HANGER;22.6 4 1 I Casing Strings Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 5 1/2 4.950 7,523.0 13,509.9 3,479 4 15.50 L-80 BTCM Liner Details Nominal ID CONDUCTOR,31.0-170.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE,5032 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 7550.3 3,587.5 81.44 XO BUSHING XO BUSHING 5.500 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread B-SAND LINER LEM 4 1/2 3.958 7,461.5 7,661.8 3,598.5 12.60 L-80 IBTM Liner Details Nominal ID SURFACE;30.63,905.3I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Cam (in) GAS LIFT;4,217.0 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 IIM 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 GAS LIFT;6,712.9 ik 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 IN SLEEVE;7,163.9 Ot"l- 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 3.960 1 1 p r rMO 7,509.1 3,580.2 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 LOCATOR;7,211.1 111 t 1 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 _ 7,578.0 3,591.0 83.95 NIPPLE CAMCO'DB'NIPPLE w/3.563"PROFILE 3.958 SEAL ASSY;7,211.5 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Perforations&Slots g Shot 11 If Dens Top(TVD) Otto(ND) (shots) It Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating 105L1 joints of blank/slotted liner for all B-Sand slots 2.5 x.125 holes,4 rows/ft .:ra tom, 8,140.0 8,472.0 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 SLOTS ;,xu-,n ' 105L1 M_. 8,733.0 9,029.0 3,555.9 3,548.6 WS B,1E- 5/29/2005 40.0 SLOTS •4®1 105L1 I D-SAND LINER LEM;7,190.6 I 7,492.5 -IMF 8,745.0 8,750.0 3,555.5 3,555.4 9/4/2011 6.0 IPERF 60 DEG PHASING w/ 0.43"HOLES 8,750.0 8,755.0 3,555.4 3,555.2 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26"ENT 105L1 hole,60 deg phase 1i i� 8,945.0 8.950.0 3,549.1 3,549.1 WS B,1E- 8/20/2015 6.0 APERF 2"Powertlow HSD guns INTERMEDIATE,25.1-62900 ` J 105L1 (2006 FP,6 SPF,60 II I i PDeg, EN EDH 0.45",4.5" �'---- 9,328.0 9,623.0 3,543.4 3,531.7 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 9,926.0 10,385.0 3,525.4 3,517.2 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 10,644.0 11,023.0 3,513.7 3,516.6 WS 6,1E- 5/29/2005 40.0 SLOTS 105L1 11,669.0 11,881.0 3,529.9 3,510.5 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 B-SAND LINER LEM;7,461.5- 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS 7,661.8\__. _ 105L1 SLOTS;7,622.0-7,750.1 12,738.0 13,249.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 SLOTS;8,140.08,472.0 Cement Squeezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn GEL F;8,74.0-8,ftKB, _ _ 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ 9/4/2011 (PERF;8,745.08,750.0 RPERF;8,750.08.755.0 Notes:General&Safety SLOTS;8,733.0-9,029.0 End Date Annotation APERF,8,945.0A,850.0 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) - - 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID 0 7578' _ _ 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;8,328.69,823.0 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 SLOTS;9,928.610,365.0 SLOTS;10,844.611,023.0 SLOTS;11,66.611,881.0 SLOTS;12,269.0-12,437.0 SLOTS;12,738.613,249.0 B-SAND LINER;7,523.0- 13,509.9"...--- • • Proposal for 1E-105L1 to 1E-126L1 B Sand MBE Treatment with RPPG 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B lateral has 5.5", L-80 slotted liner. Three MBE's have occurred in 1E-105L1. The first happened 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 (PROF found a B MBE in 105L1 at 8750' RKB taking all PWI. On 9/4/11, a Crystal Seal job in 105L1 sealed this MBE. The treatment lasted -2 years, then rising WC% at 1E-126 indicated another MBE from 1E-105. An (PROF 1/28/14 in 105L1 showed a new MBE at 8950 - 9150' RKB area. This MBE was sealed by another Crystal Seal job 9/23/15, and lasted -1 year, until WC% again spiked at 1 E-126. A new IPROF ran 1/29/17, found a new MBE in 1E-105L1 at 9950' RKB, but saw no evidence that the two earlier MBE's treated were taking any fluid. On 1/30 & 1/31/17, the D Iso-Sly was pulled and the B Diverter was replaced with an Iso-Sly to isolate the B MBE and configure 1 E-105 for injection to D sand only until we are ready to seal the B MBE. The A lateral was isolated by a Plug set in the DB Nipple at 7578' RKB on 7/24/15, and this plug is still set. The following procedure is proposed to seal off the new B MBE at 9950' RKB with RPPG (aka: Reformed Polymer Particle Gel) to return 1 E-105L1 to PWI service. RPPG is a newly developed synthetic dehydrated crystalline particle polymer gel product that hydrates and swells in water. RPPG is like Crystal Seal in appearance and swellability. However, unlike Crystal Seal, RPPG has a delayed crosslinking feature that tightly bonds individual swollen particle polymer grains together into an amalgamated mass of gel after placement to the MBE. This crosslinking feature should give RPPG MBE treatments much better resilience to disaggregation and breakdown vs. Crystal Seal when the treatment in the MBE is being subjected to drawdown pressure from flowing the producer. Unlike all previous Crystal Seal MBE treatments that we have performed to date in West Sak MBE's, we also propose that we inject the initial 37 to 50 bbls of gel slurry at maximum concentration from CT to the MBE while drawdown is being applied on the MBE by flowing the 1 E-126 offset producer. Coil Tubing Procedure: 1) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 2) RIH to set a Diverter in the B LEM at 7524' RKB. 3) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. 4) RIH to shoot 5' of 'big hole' perforations at 9945 - 9950' RKB across the new B MBE located at 9950' RKB, per 1/29/17 (PROF. 5) Put both 1E-126 producer and 1E-105 injector BOL 12 - 24 hrs before CTU RU on 1E-105. Have 1 E-126 flowing to 1 E test separator. This will reestablish flow through the B MBE between the wells. RU CTU with 2" CT on 1E-105. RIH with a down port nozzle on CT. Park nozzle at 9940' RKB just above the open MBE in 1E-105L1. Blend Seawater from transports with 1 - 4 mm mesh RPPG at 0.30 - 0.35 ppg slurry concentration `on-the-fly' in a mixing van and then pump it down CT at a steady established rate of 1.7 - 2.2 bpm while producing 1E-126 and injecting 1000 BPD PWI down CT x Tbg to keep CT back side flushed of any RPPG slurry. Pump the first 37 to 50 bbls of slurry out of the nozzle parked at MBE at -9940. After -37 bbls of slurry exits the nozzle, shut-in 1E-126 (to avoid any significant placement of RPPG into the producer), while continuing slurry pumping to 1E-105L1 and starting POOH at 40 fpm. Continue pumping steady • • rate and slurry concentration until nozzle is POOH and parked at `safety' above all liner slots at 7620' RKB. POOH to safety mitigates development of very heavy PU weight that often develops while pumping heavy gel concentrations into slotted liners with crossflow. Continue pumping slurry at steady rate and 0.30 — 035 ppg concentration until WHIP reaches -800 psi, then SI all 1E-105 injection to CT x Tbg annulus, and swap from RPPG slurry to pumping to 10 bbls of Seawater spacer down CT, followed by -34 bbls Diesel FP followed by 1 CT volume of CT Diesel FP. When Diesel starts going down CT, start POOH from safety while maintaining steady rate down CT. RD CTU. Wait 2 days for RPPG particles fully crosslink in MBE before returning 1E-105L1 to PWI. If step 5 is executed as planned, 1E-126 producer will be allowed to flow back to the plant with low odds that it creates a plant upset due to gel production. 6) RIH with jet swirl nozzle and tag top of RPPG in well, then jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner. POOH w/CT. PU & RIH with 2.5" OD CT Tractor with nozzle to jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner at deeper depths to open more lateral to PWI. POOH w/CT Tractor. Place 1 E-105L1 on PWI to evaluate the results of the MBE treatment. 7) RIH with IPROF BHA. Memory log down & up passes to verify all the MBE's are sealed off. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1E-105L1 to PWI service. Leave 1E-105L1 on `B sand only' injection long enough to evaluate that the B MBE's remain sealed. When deemed appropriate, proceed to steps 8 -10 to normal up well. 8) RIH to pull the Iso-Sly across the D LEM at 7258' RKB to open the D lateral to injection. 9) RIH to pull the Diverter in the B LEM at 7524' RKB and leave B lateral open to injection. 10) RIH to pull the Plug from the DB Nipple at 7578' RKB to open the a lateral to injection. Return 1E-105 to PWI service to all 3 laterals. STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Aker Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatment l7 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-007 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-23243-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-105L1 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 13529 feet Plugs(measured) none true vertical 3479 feet Junk(measured) none Effective Depth measured 8209 feet Packer(measured) 7462 true vertical 3599 feet (true vertical) 3572 Casing Length Size MD ND Burst Collapse CONDUCTOR 139 20 170 108 SURFACE 3875 13.375 3905 2285 INTERMEDIATE 7499 9.625 7524 3712 B-SAND LINER 5987 5.5 13510 ` cA'®LB9®F Nov 0 34 2015 A®L� RECEIVED Perforation depth: Measured depth: slotted liner from 7622-13249, perfs from 8745-8755, 8945-8950 L r Z01 5 True Vertical Depth: slotted liner from 3595-3478, perfs from 3555-3555, 3549-3549 AOGGC Tubing(size,grade,MD,and ND) 4.5, L-80, 7229 MD, 3517 TVD Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 7462 MD,3572 TVD NIPPLE-CAMCO'DB-6'NIPPLE @ 503 MD, 503 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: see attached summary 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 r Development rY4i Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ I WAG r GINJ r SUSP r SPLUG r 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: 315-362 Contact John Peirce @ 265-6471 Email John.W.Peirce(a�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature / Phone:265-6471 Date 1.4' /1-5115 ATL tb/2I`l5— , /6/(// RBDMS' OCT 212015 Form 10-404 Revised 5/2015 Submit Original Only 1E-105L1 Crystal Seal Treatment • DATE SUMMARY 5/24/2015 PULLED 5/16" CHOKE ON DB LOCK @ 503' RKB. BRUSHED AND FLUSHED TBG TO 7164' RKB. SET 1/4" CHOKE ON 3.81" DB LOCK @ 7164' RKB. COMPLETE. 7/13/2015 GAUGED TBG TO 3.86"TO 503' RKB; 3.79"TO CMU @ 7164' RKB. PULLED CHOKE @ 7164' RKB. READY FOR CTU. 7/14/2015 Pumped 25 bbls diesel down Tbg. Job complete. 7/21/2015 B&C CTU#1: RETREIVE TYPE 1 ISO-SLEEVE FROM B LEM AT 7524'WITH BAKER G- FORCE JARS. WHILE GOING TO WELL FOR SECOND RUN, UNABLE TO COME UP ON TROLLEY WINCH. MECHANIC CALLED OUT, WILL RESTART IN THE MORNING. 7/24/2015 B&C CTU #1: SET A SAND ISOLATION PLUG & PRONG IN DB NIPPLE AT 7578'WITH BAKER SI-DI HIPP TRIPPER, TWO RUNS. SET TYPE 1 DIVERTER IN B LEM AT 7524'. WILL RETURN IN THE MORNING TO SET A TYPE 2 ISO SLEEVE ACROSS D LEM. 7/25/2015 B&C CTU #1: SET A TYPE 2 ISO SLEEVE ACROSS D LEM AT 7258'WITH BAKER SI-DI HIPP TRIPPER. READY FOR ELINE TRACTOR PERF. 8/7/2015 UNABLE TO TRACTOR PAST 8225'. MADE MULTIPLE ATTEMPS AND TRIED TO USE A PUMP ASSIST BUT WERE UNABLE. DECISION MADE TO RDMO AND GO TO NEXT JOB 8/13/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOG IN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 11226' CTMD (PERF DEPTH FROM 8945'-8950'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 8900'AND 9000' CTMD. WILL RETURN THE MORNING TO PERFORATE. 8/20/2015 B&C CTU#1: PERFORATE MBE INTERVAL IN B LATERAL FROM 8945'-8950' RKB WITH SLB 2-IN POWERFLOW HSD GUNS (2006FP -6SPF, EHD 0.45", 4.5" PEN). DEPTH CORRECTED TO TAG FROM LAST MEMORY LOG, REFERENCED TO (PROF DATED 6-MAR- 06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/22/2015 INJECTIVITY TEST. PUMPED 2OBBLS DIESEL @ 1BPM DOWN THE TUBING @ 200PSI. JOB COMPLETE. 9/23/2015 Perform MBE treatment with 2,805 lbs (51 sacks) of 4 millimeter CrystalSeal per design. Well freeze protected and to be left shut-in. ***Job in Progress with more steps in Procedure to follow.*** 9/27/2015 Injectivity test,pump 20 bbls dsl down tbg at 1 bbl/min @ 625 psi,job complete KUP INJ • 1E-105L1 • •COt1000PI1•IIIip$ ' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status rax (°) MD(ftKB) Act Btm(ftKB) [o....J1a8pe 500292324360 WEST SAK INJ 98.07 8,166.01 13,529.0 °.. Comment 825(ppm) Date Annotation End Date KB-Grd(ft) --Rig Release Date 1E-105L1,8/25/20157:54:29 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ................... HANGER;22.6 111..9M1- _. Last Tag: 13,018.0 6/21/2006 Rev Reason:PERFORATIONS hipshkf 8/20/2015 11.1 "� Casing Strings , ,...........,..Casing Description I OD(in) I ID(in) Top(ftKB) Set Depth(ftKB) ISet Depth(ND).79.4.1 WtlLen15.50(I...I L-80 Grade I Top ThreadBTCM B-SAND LINER 5 1/21 4.950 7,523 0 13509 9 3,4 IILinerDetails ' 7� Nominal ID CONDUCTOR;31.0-170.0-1Top(ftKB) Top(ND)(ftKB) Top Incl 1°) Item Des Com (in) NIPPLE;503.2 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 7,550.3 3,587.5 81.44 XO BUSHING XO BUSHING 5.500 Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)... Wt/Len(I...Grade Top Thread B-SAND LINER LEM I 4 1/21 3.958 7,461.511 7,661.81 3,598.51 12.601 L-80 I IBTM SURFACE;30.03,905.3 _ Ljrler Details GAS LIFT,4,217.0 _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top!not(°) Item Des Corn (in) GAS LIFT;6,712.9 1B 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 - ''` - 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 SLEEVE;7,163.91M4 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 e r <fhlf 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 all LOCATOR;7,211.1 ;. ;,__. 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 1960 7,509.1 3,580.2 7924 HANGER LEM ABOVE HOOK HANGER 3.980 SEAL ASSY;7,211.8 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 7,578.0 3,591.0 83.95 NIPPLE CAMCO'DB'NIPPLE w/3.563"PROFILE 3.958 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 9 Perforations&Slots 4 i snot ' Dens ISO SLEEVE;7,258.0 I -1E, Top(TVD) Btm(ND) (shotstt #, 1. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating 105L1 joints of blank/slotted liner for all B-Sand slots 2.5 x.125 holes,4 rows/ft 8,140.0 8,472.0 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 1 8,733.0 9,029.0 3,555.9 3,548.6 WS B,1E- 5/29:'2005 40.0 SLOTS a 105L1 D-SAND LINER LEM;7,190.6 7,492.5 I 8,745.0 8,750.0 3,555.5 3,555.4 9/4/2011 6.0 IPERF 60 DEG PHASING w/ 0.43"HOLES 8,750.0 8,755.0 3,555.4 3,555.2 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26" 105L1 ENT hole,60 deg phase 1 8,945.0 8,950.0 3,549.1 3,549.1 WS B,1E- 8/20/2015 6.0 APERF 2"Powerflow HSD guns INTERMEDIATE;25.1-8,290.0 '�� 105L1 (2006 FP,6 SPF,60 I Deg,EDH 0.45",4.5" { PEN 9,328.0 9,623.03,543.4 3,531.7 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 I 9,926.0 10,385.0 3,525.4 3,517.2 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 10,644.0 11,023.0 3,513.7 3,516.6 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 - 11,669.0 11,881.0 3,529.9 3,510.5 WS B,1E- 5/29/2005 40.0 SLOTS - 105L1 B-SAND LINER LEM;7.461.6 -I I-- 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS 7,661.81 - - 105L1 SLOTS;7,622.0.7,750.1- 12,738.0 13149.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;8,140.0.8,472.0 I 105L1 Cement Squeezes _ ..- Top(ND) Btm(NO) Top(ftKB) BIm(ftKB) (ftKB) (ftKB) Des Start Date Corn IPERF;8,745.0-8.750.0 - 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ 9/4/2011 RPERF;8,750.0.8,755.0 Notes:General&Safety SLOTS;8.733.0.9,029.0- `� End Date Annotation APERF;8,945.0.8,950.0 r-- 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) - - 6/18/2006 'NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;9,328.0-9,623.0----;-" - 9/11/2010 NOTE:MBE repair w/9 bb)s of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 SLOTS;9,926.0-10.385.0 SLOTS;10.644.0-11,023.0 , SLOTS;11,669.0.11,881.0 SLOTS;12,269.0-12.437.0- SLOTS;12.738.613,249.0 ' B-SAND LINER,7,523,509.9. 130. • • (e_________50. 5 WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 DATA LOGGED Anchorage, Alaska 99501 `6 BENDER (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. REIVED Attn: Robert A. Richey 130 West International Airport Road �uG 0 2iii Suite C Anchorage, AK 99518 Fax: (907) 245-8952 A Sr r, 1) Coil Flag 13-Aug-15 1E-105 L1 CD 2-05-001 50-029-23243-60 2r..4,12-1 5 2) Jewelry Log 14-Aug-15 1E-102 CD z , k-23 \ 50-029-23236-00 ZCo k24Ca mxtizaSigned : i7) ��/`�`�� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE4MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx (...(:0F r�• ��7�,s� THE STATL Alaska Oil and Gas ��M ofA LAsKA Conservation Commission M =z1-;,-- 333 West Seventh Avenue - rR=' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'- Fax: 907 276 7542 Ea 3\i\-- 11 ` V.1 www aogcc.alaska.gov satJohn Peirce s _ 00 7 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-105L1 Sundry Number: 315-362 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, 4/4---, Daniel T. Seamount, Jr. Commissioner DATED this to day of June, 2015 Encl. RECEIVED STATE OF ALASKA • •1 i ;KA OIL AND GAS CONSERVATION COM. SION J U Nl 12 2015 tv,► ` APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate T Alter Casing r Change Approved Program r Rug for Redrill E Perforate New Pool '1$= r Repair Well r Re-enter Susp Well r Other•Crystal SealAreatment IV, 2.Operator Name. 4.Current Well Class. 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 205-007 3.Address: Stratigraphic r Service 6 API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23243-60 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 KRU 1 E-105L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,25660 . Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft). Total Depth TVD(ft). Effective Depth MD(ft) Effective Dept `�+ TVD(ft),% Plugs(measured): Junk(measured). 13529 3479 8209' 3 99' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108' 108' SURFACE 3875 13.375 3905' 2285' INTERMEDIATE 8262 9.625 8290' 3712' B-SAND LINER 5987 5 5" 13510' 3479' Perforation Depth MD(ft) Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): slotted liner from 7622-13249 - 3595-3478 4.5 L-80 7229 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=7462 TVD=3572• NIPPLE-CAMCO'DB-6'NIPPLE MD=503 TVD=503 . 12.Attachments: Description Summary of Proposal pl. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r• 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work. 7/8/2015 OIL r VVINJ r • WDSPL r Suspended r 16 Verbal Approval. Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. John Peirce @ 265-6471 Email: John W Peirce@conocophillips.com Printed Name John Peirce Title: Sr. Wells Engineer Signature — Phone:265-6471 Date 61s IlSc Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315- 3 Lo 2 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required' ` 0 _ 4 O// APPROVED BY Approved by: /.... .. .e. COMMISSIONER THE COMMISSION Date: LI/L 1 ) 1.7-1,_ o,s/e 5 Appigvp�appiKalgl�Isle for 12 ent c tr oln�he date of approval. Submit Form and Form 10-403 Revised 5/2015 U K I I�,'J I\VI L I Attach in Duplicate 6�4 RBDMS` JUN 2 5 2015 KUP INJ 1E-105L1 Conoc Phdhps $ Well Attributes Max Angle&MD TD Alaska,IncWellbore API/U1/61 Field Name Wellbore Status ncl(°l MD(ftKB) Act Btm(ftKB) ty,,,,yM 500292324360 WEST SAK INJ 98.07 8,166.01 13,529.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1E-105L1,3/4/20142.55.00 PM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vertical schematic aaua - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------------------------- Last Tag: 13,018.0 6/21/2006 Rev Reason:SET CHOKE Iehallf 3/4/2014 HANGER;22.6-`L± IIIasing rings Casing Description OD(in) ID(in) Top(MKB) Set Depth(ftKB) Set Depth(WD),.. WtlLen(I...Grade TopThread I' ��i.B-SAND LINER 512 4.950 7,523.0 13,509.9 3,479.4 15.50 L80 BTCM Liner DetailsCONDUCTOR;31.0.170.0 Top(ftKB) Top(IVO)(ftKB) Top Incl("I Item Des Com No(in)IID CHOKE;5030 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 NIPPLE;503.2 t 7,550.3 3,587.5 81.44 XO BUSHING XO BUSHING 5.500 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread B-SAND LINER LEM 4 1/2 3.958 7,461.5 7,661.8 3,598.5 12.60 L-80 IBTM Liner Details SURFACE;30.0-3,905.3 Nominal ID GAS LIFT;4,217.0 1. 7,461.5 Top(ftKB) Top(ND)(ftKB) Top teal(1 Item Des Com (in) 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 pm GAS LIFT;6,712.9L lit 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 SLEEVE;7,163.9 I 0 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 _1;1 Eli=E 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 3.960 7,509.1 3,580.2 7924 HANGER LEM ABOVE HOOK HANGER 3.980 LOCATOR;7,211.1 v-lit t=t ` 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 LTV f 7,578.0 3,591.0 83.95 NIPPLE CAMCO'DB'NIPPLE w/3.563"PROFILE 3.958 SEAL ASSY;7,211,8 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 a Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotslf Top(565) Btm(ftKB) (ftKB) (ftKB) Zone Date 0 Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating 105L1 joints of blank/slotted liner for all B-Sand slots 2.5x.125 holes,4 rows/ft 8,140.0 8,472.0 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 1 8,733.0 9,029.0 3,555.9 3,548.6 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 D-SAND LINER LEM;7.190.6- 8,745.0 8,750.0 3,555.5 3,555.4 9/4/2011 6.0 IPERF 60 DEG PHASING w/ 7.492.5 0.43"HOLES 8,750.0 8,755.0 3,555.4 3,555.2 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26" 105L1 ENT hole,60 deg phase 9,328.0 9,623.0• 3,543.4 3,531.7 WSB,1E- 5/29/2005 40.0 SLOTS INTERMEDIATE;25.1-8,290.0 105L1 9,926.0 10,385.0 3,525.4 3,517.2 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 -_ 10,644.0 11,023.0 3,513.7 3,516.6 WSB,1E- 5/29/2005 40.0 SLOTS -I- 105L1 11,669.0 11,881.0 3,529.9 3,510.5 WSB,1E- 5/29/2005 40.0 SLOTS 105L1 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 12,738.0 13,249.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 B-SAND LINER LEM;7,481.5- - - Cement Squeezes 7,661.8=" _ Top(TVD) Btm(TVD) SLOTS;7,622.0-7,750.1- Top(ftKB) Ben IftKB) (ftKB) (ftKB) Des Start Date Corn 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ 9/4/2011 SLOTS;8,140.0-6,472.0-_ _ Notes:General&Safety End Date Annotation 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) (PERF;9.746.0.8.750.0 _ 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' RPERF;8,750.0.8,755.0 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS,8.733.0-9,029.0- _ 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 SLOTS;9.328,0.9.623.0 SLOTS;9,926.0.10,385.0 ' SLOTS.10.644.6 11.023.0 SLOTS;11,669.0-11.881.0-- SLOTS;12.269612.437.0 SLOTS;12,738.0-13,249.0 B-SAND LINER;7.523.0- 13.509.9-*-- Treatment Proposal for 1E-105L1 to 1E-126L1 B Sand MBE's 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B Sand lateral has 5.5", L-80 slotted liner._Two MBE's occurred in 1E-105L1. The first occurred 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 IPROF found a B MBE in 105L1 at 8750' RKB taking all PWI at 2711 BWPD. On 9/4/11, a Crystal Seal job pumped in 105L1 to seal this MBE. The treatment lasted -2 years before rising WC% at 1E-126 indicated another MBE occurred from 1E-105. An IPROF 1/28/14 in 1E-105L1 shows the B MBE at 8750' RKB again taking some PWI, plus a new MBE now at 8950 - 9150' RKB area. 1E-105 lost PWI May 2014 due to 1E PWI line SI for repairs, then PWI resumed April 2015 to 1 E-105L2 only (105L1 is 'so-Skid off due to B MBE's). A job procedure is now proposed to seal off the B MBE's to return 1 E-105L1 lateral to PWI service: Slickline: 1) A 0.25" choke was set on 5/24/15 on a 3.81" DB Lock at 7164' RKB in a Camco Sliding Sleeve. RIH & pull this choke to enable CT access to 1E-105L1 B Sand lateral. RD SL. Coil Tubing: 2) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 3) RIH to set a Diverter in the B LEM at 7524' RKB. 4) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. E-line: 5) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 8945 - 8950' RKB. This perfs 5.5" slotted liner at the lower new MBE at -8950' to allow CrystalSeal entry through slotted liner to the MBE. Fire gun. POOH. RD. Perfs were shot in 2011 at the upper MBE at-8750'RKB. Coil Tubing: 6) RIH with a large down port nozzle on CT. Park nozzle at 8700' RKB above both MBE's, and then pump a Step Rate Injection Test (SRIT) followed by a Crystal Seal treatment as follows: a) Pump SRIT with Seawater down CT to MBE's. Select a steady treatment rate (likely to be in the 1.5 - 2 bpm range) to be held constant during the treatment (steps b through e) to Flush (step f) to monitor MBE response to treatment and to watch Crystal Seal screenout develop during the slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater of adequate salinity), then pump: b) 2% KCL Water with 0.05 ppg Crystal Seal (using 4 mm mesh all stages b through e) down CT. Each stage volume TBD during pumping based on treating pressure seen during stage. Then pump, c) 2% KCL Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if screen out develops. d) 2% KCL Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. Once Crystal Seal concentrations > 0.10 ppg starts exiting the nozzle, begin POOH with nozzle continuously at 5 - 10 fpm while pumping away all the remaining slurry to be pumped until the nozzle reaches a safe parking point just above the B LEM (7524' RKB). This practice is used now to help mitigate development of very sudden heavy PU weights that have been experienced during previous Crystal Seal treatments where the nozzle stayed parked at the MBE while pumping away all the Crystal Seal stages with only periodic weight checks. Continuously POOH allows for continuous monitoring of PU weight development to provide early warning re: rising PU weight issues. Once the nozzle reaches final parking location at the B LEM, Crystal Seal stacking behind CT cannot occur, since only CT x Tbg dead leg exists above the B LEM and pumping of at least 0.3 bpm will be kept down the CT backside. f) If screen out occurs, pump 1 CT volume Seawater Flush to displace Crystal Seal from CT to well while POOH and pumping 0.5 bpm 2% KCL down CT backside to mitigate Crystal Seal stacking behind CT (that can lead to excessive PU weight). Even if screen out is not seen prior to Flush, keep a minimum of 0.3 bpm of 2% KCL down the CT backside at all times to help keep Crystal Seal flushed away from CT backside to mitigate elevated PU weights. Pump 1 full CT volume of 2% KCL to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let the Crystal Seal particles fully hydrate and swell in the MBE's before returning 1E-105L1 to PWI. 7) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet down through Crystal Seal to as deep as possible to shear & mechanically break all Crystal Seal remaining in the liner. POOH w/CT. Place 1 E-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with IPROF BHA. Memory log down & up passes to verify if the MBE's are sealed off or still taking PWI. Wait 2 hours, then log a cool back pass. POOH with CT. RD CTU. Return 1E-105L1 to PWI service. Leave 1E-105L1 on PWI to `B sand only' for a few months to ensure that the B MBE's continue to appear to be sealed off. Depending on surveillance, evaluate retreatment options for the MBE's, if needed. If several months have passed without obvious indications of treatment failure, proceed to normal up the well to resume unobstructed PWI to the A sand and D sand laterals as follows: Coil Tubing: 9) RIH to pull the Iso-Sly across the D LEM at 7258' RKB. 10) RIH to pull the Diverter in the B LEM at 7524' RKB. Return 1 E-105 to PWI service to all 3 laterals. · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d Q5 - 00 7 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: J D.3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY ~ Date7/:JD/07 Stage 1 If NO in stage 1, page(s} discrepancies were found: YES Organizing (done) tø1'wo-sided 11111111I11 ""1111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No.à.. o Other, Norrype: o Poor Quality Originals: o Other: NOTES: BY: ~ Date7/ao/07 I I Date7Ja.fJ) 07 I I 3 x 30 =3..!¿ + Project Proofing BY: ~ Scanning Preparation BY: Date: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: rnP 11111111111111 "'II /5/ /5/ (Vlf I J- = TOTAL PAGES I ()a- P (Count does not include cover sheet) /5/ III 11111111111 ,,11/ NO /5/ W1 P NO /5/ 11111111/1111111111 ReScanned BY: Date: /5/ Maria Comments about this file: 11111111111111" III Quality Checked III II 111111I II 1111I 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Plug Perforations r Stimulate r Other gr, MBE Sealing P Tubing P New Pool Waiv Treatment Alter Casing C"" 9 1� r 1 Time Exte j'°"` 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 r Exploratory f — 205 -007 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic j "` Service r 50- 029 - 23243 -60— QQ 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25660 + 1 E -105L1 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13529 feet Plugs (measured) 7578 true vertical 3479 feet Junk (measured) None Effective Depth measured 8209 feet Packer (measured) 7462 true vertical 3699 feet (true vertucal) 3572 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108' SURFACE 3875 13.375 3905 2285 INTERMEDIATE 8262 9.625 8290 3712 B -SAND LINER 5987 5.5 13510 3479 RECEIVED" Perforation depth: Measured depth: slotted liner 7622' - 13249' CEP 2 8 2(111 True Vertical Depth: 3595' - 3478' ,� k , -p ,j,l i Alaska Oil & Gas Cons. Commission Tubing (size, grade, MD, and TVD) 4.5, L -80, 7229 MD, 3521 TVD :` c oragO Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 7262 MD and 3572 TVD NIPPLE IN MAIN WELLBORE 11. Stimulation or cement squeeze summary: t t S4rN iD 4A M � T Intervals treated (measured): T C=A-11- 1 tel. [f Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 560 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service . Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ f 7 WAG r GINJ r SUSP r SPLUG E 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: 311 -199 Contact John Peirce (a, 265 -6471 Printed Name John Peirce Title Wells Engineer Signature / 7:1/..., Phone: 265 -6471 Date 9 /20/1. i. ZIT " RBDMS SEP 8 201 7,4_ ' .1. Form 10 -404 Revised 10/2010 ,f / / 2 . 7 / 7 Submit Original Only 1E-105 and 1E-105L1 Well Work Summary DATE SUMMARY 9/4/11 .PERF FROM 8745' - 8750 CTMD IN E B SANDS LATERAL, PERF INTERVAL. PROVIDED 6 SPF @ 60 PHASING W/ 0.43" HOLES, PUMP CRYSTAL SEAL, 2310 LBS OF 4 MM PRODUCT WAS PUMPED IN A 2% KCL SOLUTION ACROSS THE PERFS IN THE B SAND LATERAL. WH FP, COMPLETE , `''s • KUP 1E -105L1 4 " ConocoPhilips L Well Attributes Angle & MD TD ` " 20$ " 5 1 Wel!bore API/UWI Field N me 'Well State Inel ( °) I MD (ftKB) Act Btm (ft06) 500292324360 IWESI SAK IINJ 9807 I 8,16601 13,526.0 N nr. _ _ - Comment H2S (ppm) Date Annotation 'End Date KB Grd (ft) Rig Release Date - SSSV. NIPPLE 1Last WO I I_ 3059 6/20/2005 0 T 1-4. 9� 195.1 p u ., Annotation ,Trs 3822AM _ .-- - - _ _ - _- Depth (ftKB) End Date Annotation Last Mod .. End Date Last Tags � 621/2006 R ev Reason ADD PERFS l nlnam 9/7/2011 � - -- , Casing Strings HANGER, 23 Casing Description (String 0 String ID.. -'Top (ftKB) 'Set Depth (f...'Set Depth (TVD) . String Wt... String ...'String Top Thrd - 13-SAND LINER 1 51'2 4.950 7,523.0 13,5099 3479.4 15.50 L-80 1 BTCM Liner Details CONDUCTOR i u - Top 7,523 Top �8)g Top Intl Nomi... (°) Item Description Comment ID (in) 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 NIPPLE, 503 - 7,550.3 3,588.8 85.19 XO BUSHING XO BUSHING 5.500 « ; Casing Description String 0... String ID ... BSAND LINER LEM I 4 12 3.958 Top (ftKB) Set D pth (f -.. Set Depth ( ... String Wt... String ... String Top Thrd 958 L7,461. ]_ 7 661 3,59 12.60 L-80 IBTM i Liner D Details , Top Depth _.. _.. (TVD) Top Intl Nomi... SURFACE,_ ToP(ftKB) ( MB) (°) Item Description Comment .___. ID On) 30 - 3,905 7,461.5 3,571.6 79 - 84 PACKER ZXP LINER TOP PACKER w /HRD PROFILE 7.500 GAS LIFT. _ - ._ - 4,217 .I,. 7,480 -2 3,575.0 79.60 XO CROSSOVER 4.950 GAS LIFT. _ __.. . _ . 7,481.9 3,575.3 79.58 SBR 190 -47 CASING SEAL BORE RECEPTACLE 4.750 6,713 !; 7,501 -3 3,578.8 79.34 XO BUSHING X0 BUSHING 3.940 SLEEVE, 7,164 -- 7,502.7 3,579.1 79.32 SWIVEL CASING SWIVEL 3.960 ( - 7,509.1 3,580.3 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 LocATOR, yr 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 7,211 - - '' ., , ., 7,578.0 3,591.1 85 -10 NIPPLE CAMCO 'DB' NIPPE w/ 3. 563" PROFILE 3.958 - =_-, 7,658.6 3,5982 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 SEAL ASSY, 7.212 _ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) .. • , y.e . Top Depth (TVD) Top Intl Top(rtKB) ( (') Description Comment Run Date ID(in) 7,578 3,591.1 85.10 PLUG 3.562" DBP PLUG BODY w 19.4 "889" LONG P -PRONG IN 6/9/2010 0.000 PLUG BODY Perforations & Slots Top (TVD) Btm (TVD) Dens Shot Top (ttK8) Ben (flKe) (ftKB) (ftKB) Zone Date (sh.-. Type Comment 7,622 7,750 3,595.0 3,605.8 WS B, 1E -105L1 5/29/2005 40.0 SLOTS Slotted Liner, alternating joints of blank/slotted liner for all BSand slots , ` � 2.5 x .125 holes, 4 rows/ft 8,140 8,472 3,597.6 3,566.3 WS B, 1E -105L1 5/29/2005 40.0 SLOTS D - SAND LINER 8,733 9,029 3,555.9 3,548.6 WS B, 1E -105L1 5/29/2005 40.0 SLOTS LE 7,191 M, 8,750 8,755 3,555.4 3,555.2 WS B, 1E -105L1 8/27/2006 6.0 RPERF 2.5" HSD Guns -.26" ENT hole, 60 : <... deg phase PLUG, 7,578 6- SAND LINER LEM, 9,328 9,623 3,542.1 3,531.6 WS B, 1E - 105L1 5/29/2005 40.0 SLOTS 7,4 SLOTS, _ L LINER 9,926 10,385 3,525.4 3,517.0 WS B, 1E - 105L1 5/29/2005 40.0 SLOTS 7,622 VTERMEDIATE, 10,644 11,023 3,513.7 3,516.2 WS B, 1E -105L1 5/29/2005 40.0 SLOTS 25 11,669 11,881 3,529.8 3,510.8 WS B, 1E -105L1 5/29/2005 40.0 SLOTS / r ) 12,269 12,437 3,502.4 3,501 7 WS B, 1E -105L1 5/29/2005 40.0 SLOTS 12,738 13,249 3,492.5 34775 WS B, 1E -105L1 5/29/2005 40.0 SLOTS Notes: General & Safety End Date Annotation M 6/18/2005 NOTE: TRI LATERAL WELD A -SAND (15-105), 8 -SAND (1E- 105L1), D -SAND (1E- 105L2) 6/18/2006 NOTE: B-SAND LEM CONTAINS CAMCO'DB' NIPPLE w/3.92" ID @ 7578' 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 9/11/2010 NOTE: MBE repair w/9 Obis of 1G1- 2289E, 105 degree meltpotnt wax @ 8750' SLOTS, .1...., N °IC 8,140 -8,472 T y- - -- /� //� y � . / .f� -�/ ( G (Q� /7L/,f�'- 7 1TJ RPERF, Ijr � f •- 7 Y 1 E �/ ✓ l _ 1 �� ( f X 8,750 -8,755 SLOTS, 8,733-9,029 2- 7Z ' T V D 8,733 -9,029 `ir SLOTS,__ 1 9,328-9,623 kI H 44 .m SLOTS. - ^'.? 9,926-10,385 Mandrel Details SLOTS -. Top Depth Top Port 10,644- 11,023 - "- (TVD) Intl OD Valve Latch Size TRO Run Stn Top MKS) (4468) 7) Make Model (in) Sere Type Type (in) (psi) Run Date Can... 1 4,217.1 2,399.5 68. CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 8/82010 SLOTS.__ 2 6,712.9 3,383.2 68.69 CAMCO KBG -2 -1R 1 GAS LIFT OMY BK 0.000 0 -0 8/8/2010 11,66311,861 • - -- "' 1 SLOTS,__ 1 12,269- 12,437 i STS, - _.. 12,738- 13,2 BSAND LINER, - 7,523- 13,510 TD (1E-1051.1), 13,529 • • slam olF D D fl SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMl►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. J,7 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -105L1 Sundry Number: 311 -199 Dear Mr. Peirce: 783 JUN 4 201'i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 e) 11 Daniel T. Seamount, Jr. Chair DATED this 13 day of June, 2011. Encl. . STATE OF ALASKA , IE! \J ALASK. AND GAS CONSERVATION COMMISSI � APPLICATION FOR SUNDRY APPROVALS '= .ii -11\i (;) A lir 20 AAC 25.280 IF, t 3 ti r 1. Type of Request: Abandon l Rug for Redrill r Perforate New Pool f Repair w ell l pl +'ralto- r Suspend r Rug Perforations r Perforate r Pull Tubing r- t+Eigiion r Operational Shutdow n r Re -enter Susp. Well r Stimulate [ Alter casing r Other: MBE Sealing Treatment J 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205 -007 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23243 -60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: >4- where ownership or landownership changes: Spacing Exception Required? Yes E No IV 1E -105L1 • B s -,444 0. 1-4rcAc.' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651, 25660 • Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13529 - 3479 • 8209' 3699' 7578' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 108' 108' SURFACE 3875 13.375 3905' 2285' INTERMEDIATE 8262 9.625 8290' 3712' B -SAND LINER 5987 5.5" 13510` 3479' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 7622' 13249' 3595 4.5 L - 7229 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) ZXP LINER TOP PACKER w /HRD PROFILE MD= 7462 TVD= 3572 NIPPLE IN MAIN WELLBORE 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development (" Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/10/2011 Oil E Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ f✓' GINJ r WAG r Abandoned E Commission Representative: GSTOR fl SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer /// Signature (N `--- Phone: 265 -6471 Date `�/ 1 Commission Use Only / Sundry Number: 5\ 1 ) Conditions of approval: Notify Commission so that a representative may witness Plug Integrity f BOP Test f Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / :) � t( Q ,0 APPROVED BY / l "} e / l Approved by COMMISSIONER THE COMMISSION Date: t7 ` 3 Form 10 -403 Re43 MAY 14 J 4 Submit in u uplicate RBDMS JUN 14 2011 R G N A L ,, • • 1E-105L1 to 1E-126L1 MBE Treatment A matrix bypass event (MBE) occurred Dec. 2005 in 1E-105L1 with breakthrough to 1E-126L1 7 producer. A 6/20/06 IPROF in 105L1 found a heel MBE at 8750' RKB taking all PWI. 1E-105 currently has an Iso -Slv set over 1 E -105L2 (D lat) and Diverter set in the 1 E -105L1 (B lat) LEM. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal swells to 400 times original size by hydrating and absorbing water. Due to swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate acceptance of injection. Procedure: Coil Tubing: 1) Pull old style 2.50" min ID Iso - Sleeve from the 1E-105L2 (D lateral) LEM at 7258' MD. 2) Run 2.75" OD perf gun to shoot 10' of big hole perfs in 5.5" slotted liner at 8740 - 8750' RKB in 1 E -105L1 to enable CrystalSeal entry through slotted liner to the MBE. POOH with perf gun. 3) Set a 'new style' 2.75" min ID Iso- Sleeve across 1E-105L2 before Crystal Seal job. 1E-126 producer will be shut -in to limit drawdown on the MBE during the 1E-105L1 CrystalSeal job. 4) RIH w /Active -Coil until large side port only ('wax nozzle') is at the perf interval at 8740 - 8750' MD, then pump 40 bbls 2% KCI Pad down coil at initial rate of 0.7 bpm. Work rate to max allowable rate just below frac gradient while taking any returns from the CT x Tbg annulus, followed by 5 bbls 2% KCI with 0.1 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.25 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 20 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) while ramping rate down to 0.7 bpm and taking returns from CT x Tbg, followed by shut -in of CT x Tubing annulus, followed by 60 bbls (target) 2% KCI with 0.4 ppg CrystalSeal (4 mm size) down coil at steady max allowable rate to stay just below frac gradient while squeezing slurry to MBE and monitoring treating pressure at nozzle. Cycle the nozzle occasionally over the perf interval to mitigate screen out, and to remove bridging of CrystalSeal across the perforated interval. If screen out (pressure spike) is seen during pumping, stop mixing slurry and open CT x Tbg annulus to take returns to surface to halt the squeeze, followed by a swap to displacement to push remaining CrystalSeal from coil to liner. If pumping proceeds OK to target of 60 bbls, open CT x Tbq at completion of this stage and take returns, if any, to surface to halt the squeeze on the MBE, then swap to pumping displacement of 50 bbls 2% KCI down coil at 0.5 bpm to push all CrystalSeal from the coil to the liner while POOH with nozzle to B LEM at 7524' MD, followed by POOH with coil pumping xx bbls Diesel for FP, followed by 1 more CT volume of Diesel to fully displace all Diesel FP into the tubing. RD CTU. Wait at least 6 hours to let the CrystalSeal fully hydrate before returning 1 E -105L1 to PWI to evaluate effectiveness of treatment in sealing the MBE. Return 1E-105L1 to PWI slowly in step rate fashion (ie: 0.25 bpm, 0.4 bpm, 0.6 bpm) to observe post- treatment PWI rate vs. WHIP, and to evaluate how injectivity has changed as a result of the treatment. e KUP • 1E -105L1 ,,,,,,, „0...,,IY.4.s,„ 0 ConoaPhillips ''' 3 Well Attributes : Max Angle & MD TD pe WellboreAPIUWI I Field Name Well Status Ind ( °) IMD (RKB) Act Btm (RKB) rs�rxe�P • ; 500292324360 1 WEST SAK INJ 98 07 8,166 01 13 529 0 _ Comment H25 (ppml D 'Last End Date KB (ft) Rig Release Date To., a1 z SSSV: NIPPLE Last WO. 30.59 6/20/2005 _ 4162;12.55 PM _ __ _ _ ey p, al A ot D epth (RKB) End Date Annotation Last Mod By End Date Last Tag:_ 621/2006 Rev Reason MBE Repairw /Melted WAX 1 - Imosbor 10/2/2010 Casing Strings 'Casin Description I String O . String ID ' Top (R 'Set 'Set Depth (f .'Set Depth (ND) .. !String Wt_.. I Str ng String Top Thrd HANGER, 23 a' I B -SAND LINER 5 1/2 4 950 7,523.0 13,509 9 3,479.4 I 15.50 L-80 I BTCM Liner Details Top Top Depth Nomi... (ND) Top IInd (11KB) (RKB) (°) Item Description Comment ID (in) CONDUCTOR, 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B HOOK HANGER FOR LEM 7.000 31 -170 .... NIPPLE, 503 7,550.3 3,588.8 85.19 XO BUSHING XO BUSHING 5.500 Casing Description 151ring 0... String ID _fop (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt... Str g String Top Thrd BAND LINER LEM 4 12 3.958 7 5 7 661 8 1 3, 12 60 I L 80 - _ IBTM ner Details f' • Top Depth e (ND) Top Ind Nomi... SURFACE, Top (ftKB) (RKB) (°) Rem Description Comment ID (in) 30 - 3 . 905 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 GAS LIFT, -- l 4,217 7,480.2 3,575.0 79.60 XO CROSSOVER 4.950 GAS LIFT,_ 7,481.9 3,575.3 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 6,7 13 7,501.3 3,578.8 79,34 XO BUSHING XO BUSHING 3.940 SLEEVE, 7,164 7,502.7 3,579.1 79.32 SWIVEL CASING SWIVEL 3 -960 • - 7,509.1 3,580.3 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 LOCATOR, _ 1.r 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 7.211^ ` -- -- 7,578.0 3,591.1 85.10 NIPPLE CAMCO'DB' NIPPE w/ 3.563" PROFILE 3.958 ±-1 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 SEAL A7.22 C 11t--q I. ( irelin valves, fish, �eKe) ( C) a retrievable plugs, v pumps, h, etc.) Other ' Hole Depth eWlTelln T (RKB) Description PLUG - - Comment Run Date ID�n) 7 ,578.0 3,591.1 85 10 3 -562" DBP PLUG BODY w 19.4 "x89 "' LONG P -PRONG IN 6/92010 0.000 PLUG BODY Perforations & Slots Shot Top (ND) Btm (ND) Dens Top ()NK6) elm (RKB) MB) !Reset Zone Date (R0.. Type Comment _,__ -_ 7,622.0 7,750.1 3,595.0 3,605.8 WS B, 1E -105L1 5/29/2005 40.0 Slot Slotted Liner, attemating joints of blanWslotted liner for all B-Sand slots ' F. x .125 holes, 4 rows /ft 8,140.0 8,472.0 3,597.6 3,566.3 WS B, 1E -105L1 5/29/2005 40.0 Slot D - SAND LINER 8,733.0 9,029.0 3,555.9 3,548.6 WS B, 1E -105L1 5/29/2005 40.0 Slot LEM, 7,191 - 7,493 4111111M 8,750.0 8,755.0 3,555.4 3,555.2 WS B, 1E -105L1 8/27/2006 6.0 RPERF 2.5" HSD Guns-.26" ENT hole, 60 deg phase PLUG, 7,57 - B -SAND LINER LEM, - 9,328.0 9,623.0 3,542.1 3,531.6 WS B, 1E - 105L1 5/29/2005 40.0 Slot 7,462 - 7.662 Slat, 9,926.0 10,385.0 3,525.4 3,517.0 WS B, 1E - 105L1 5/29/2005 40.0 Slot 7,622 NTE Rb1EDO,750 10,644.0 11,023.0 3,513.7 3,516.2 WS B, 1E -105L1 5/29/2005 40.0 Slot 25 11,669.0 11,881.0 3,529.8 3,510.8 WS B, 1E -105L1 5/29/2005 40.0 Slot )■ 8 , rl 12,269.0 12,437.0 3,502.4 3,501.7 WS B, 1E -105L1 5/29/2005 40.0 Slot 12 738.0 13,249.0 3,492.5 3 477 S WS B, 1E-105L1 5!292005 40.0 Slot ili Notes: General & Safety g �' M End Date Annotat 6/18/2005 NOTE: TRI LATERAL WELL: A -SAND (1E -105), B -SAND (1E- 105L1), D-SAND (1E- 105L2) • - 6/18/2006 NOTE: B-SAND LEM CONTAINS CAMCO 'DB' NIPPLE w/3.92" ID • 7578' 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1.7 9/11/2010 NOTE: MBE repair w/9 bbls of 1G1- 2289E, 105 degree me(tpoint wax @ 8750' sloe. i `1 . 8,140 - 8,472 Imo"^ 5 RPERF, °°^ 8,750 -$755 in 2 9 8.733 -9.029 ° pp 9,328 -9,623 - Slot. I 4 7 9,926- 10,385 tom Sot, 1 1.� 10,64411,023 Sot, I I 11,669- 11,881 ., .. ' Slot, 12,269 - 12,437 '" ' I { Mandrel Details Slot, -. , 12,738-13,249 -- Top Depth Top Port (TVD) Inc! OD VaNe Latch Size TRO Run Stn Top (RKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Data Com.,. ...] BSAND 1 4,217.1 2,399.5 68.74 CAMCO KBG - 2 - 1R 1 GAS LIFT DMY BK 0.000 0.0 8/82010 LINER, 7,523-13,510 TD(1E 105L1), 2 6,712.9 3,383.2 68.69 CAMCO KBG - 2 - 1R 1 GAS LIFT DMY BK 0.000 0.0 8/82010 � - ______ 13,529 WE DT� ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W, 7th AVENUE, SUITE 100 CONSE RVATION COMMSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John W. Peirce AOAO Noy 11 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 E - 105L1 Sundry Number: 310 -370 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair 4t 7" C DATED this day of November, 2010. Encl. STATE OF ALASKA I ALASOIL AND GAS CONSERVATION COMMISSO APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool Repair w ell Change Approved Program Suspend r Plug Perforations Perforate Pull Tubing Time Extension Operational Shutdown Re -enter Susp. Well r Stimulate F Alter casing Other: Wax Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 205 -007 3. Address: 6. API Number: Stratgraphic "" Serve .° . P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23243 -60 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 Required? Yes No 1E -105L1 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651, 25660 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fty Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13529 3479 13018' 3478' 7578' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 3811 13.375 3905' 2285' INTERMEDIATE 8196 9.625 8290' 3712' B -SAND LINER 5987 5.5 13509' 3479' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 7622'- 13249' 3595' -3478' 4.5 L -80 7229 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NIPPLE - CAMCO 'DB -6' NIPPLE W /NO GO 3.875" PROFILE MD= 503 TVD= 503 PACKER - ZXP LINER TOP PACKER MD =7462 TVD =3572 12. Attachments: Description Sunrrnry of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ]" Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2010 Oil Gas WDSPL r Suspended r 16. Verbal Approval: Date: WINJ j' GINJ WAG r ' Abandoned Commission Representative: GSTOR SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John W. Peirce @ 265 -6471 Printed Name John W. J Peirce Title: Wells Engineer Signature � W Phone: 265 -6471 Date Commission nl Sundry Number:��J��J �I� .�"�c\ Conditions of approval: Notify Commission so that a representative may witness v Plug Integrity r BOPTest Mechanical Integrity Test Location Clearance` r r W Other: ' 0 3 2010 Subsequent Form Required: U ^ Masks OM Jas Cons. Gajr'jj Ion Anchrag@ APPROVED BY 1 l 1 Approved by: COMMISSIONER THE COMMISSION Date: C, ` �" Q n ,.•,I'r5 � i''3 icy Form 10 -4 �(J1?�21'1 0 � 11 3.1d Submit in Du licate RIGINAL in 1 E -1051-1 Seal B Sand MBE with Wax Proposal / Objective: 1E-105L1 is a B sand lateral with 5.5" slotted liner. A Matrix Bypass Event (MBE) occurred in 1051-1 in 2005 to 1 E -126 offset producer. A 6/20/06 (PROF in 1051_1 detected an MBE at 8750' MD near the heel of 1051-1. A Crete job was attempted on 9/4/06 to seal the MBE, but it failed. 1 E -1 05L1 MBE isolation was attempted 9/11/10 with molten wax pumped down coil. This initial wax job failed to seal the MBE. The wax pumped to the MBE was probably too hot to solidify in the MBE before it flowed to 1 E -126 which was on production to exert drawdown on the MBE. Active -Coil will be used to reattempt sealing the 1E-105L1 MBE using 105 - 115 F melt point wax heated to 180 ° F at surface. A total of 20 bbls of wax will be pumped down coil to the MBE at 8750' MD. For this attempt, the offset 1 E -126 producer will be shut -in and the wax will be placed in the MBE with the wax temperature in phase change range (melting point range) to help limit the wax solidification time in the MBE. Procedure: 1) Preheat 1 E -105 for wax job by pumping 180 F Seawater down tubing at 1 bpm for —72 hrs. 2) RIH with Active -Coil to MBE at 8750' RKB and pump 20 bbls of molten wax down coil to the MBE. Displace wax out of coil with hot Seawater at 0.5 - 1.5 bpm to the MBE, followed by shutdown. Monitor temperature cool down at MBE. POOH with CT. RD. 3 Wait on wax 5 - 7 days to harden and cure. 4) Return 1 E -1051-1 to injection to test wax job and determine if wax plug has sealed the MBE. Determine the future well work plans for 1 E -105 and1 E -126 following evaluation of the wax job. ' 1 E -105L1 `, � KU P G+f�CKfCtD�'4i� W ell At tu. %y es _ Max Angle & MD TD � Wellbore APW WI F Itl N Well Status MD (ftKB) Act Btm (ftKB) 500292324360 WEST SAK INJ 9807 I 8,166.01 13,529.0 Comment H25 (pp D. Annotation Entl Date KB Grtl (ft) Rig Release Date NIPPLE l Last WO: -l 3059 6/2012005 (ftKB) End Dste Annotation Last Mod By End Date Last Tag: 6/21/2006 Rev Reason: MBE Repair w /Melted WAX Imoshor 10/2/2010 - Casin Strin s HANGER, 23 C sing Des iption ,String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TV ... String ... St g ... String Top Third — B SAND LINER 1 51/2 14 950 7,523.0 13,5099 3 479A 15 50 L - BTCM Line D etails__ _ 1 I Top Depth (ND) Top Inc! I Top(ftKB)I (ftKB) (% Item Descripgon Commend CONDUCTOR, J 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B -1 HOOK HANGER FOR LEM 7.000 31 - 170 [, NIPPLE, 563 -- i. 7,550.3 3,588.8 85.19 XO BUSHING XO BUSHING 5.500 Cee g D Stn g O . String ID ... Top (ftKB) Set Depth (f Set Depth (ND) Str g Wl Str g String T p Thrd BAND LINER LEM 4 112 3.958 7,461.5 7661 8 3 598 5 12 60 L 80 IBTM Top Depth , l (ND) Top Inc! Noml... SURFACE, To KB (ttKBl (') Near Desan n Comment 34 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 GAS LIFT. — _ 4,217 7,480.2 3,575.0 79.60 XO CROSSOVER 4.950 GAS UFT,_ _.. _ 7,4819 3,575.3 79.58 SBR 19037 CASING SEAL BORE RECEPTACLE 4.750 6,713 7,501.3 3,578.8 7934 XO BUSHING XO BUSHING 3.940 SLEEVE, 7,164 7,502.7 3,579.1 79.32 SWIVEL CASING SWIVEL 3.960 7,509.1 3,580.3 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 LOCATOR, 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 7,211 _ ( 7,578.0 3,591.1 85.10 NIPPLE CAMCO'DB' NIPPE w/ 3.563" PROFILE 3.958 7,658.6 3,598.2 84 EA .84 SEAL ASSY BAKER SL ASSEMBLY 3.880 SEAL ASSY, 7 , 212 - -- Other In Hole_(Wireline retrievable plugs, valves, pumps, fish, etc.).a- 6 <. Top Depth (ND) Top Inc! T -K6 - I T (°) Deseriptio Comment Run Date ID in) 7,578.0 3,591.1 85.10 PLUG 3.562" DBP PLUG BODY w 19.4 "x89" LONG P -PRONG IN 6/9/2010 0.000 PLUG BODY Perforations & Slots Shot Top (ND) Stm (ND) Dens T ftKB 8 81 _(ftKB) (ftKB) ,.Zone Date (ah° TVp. Comment _ 7,622.0 7,750.1 3,595.0 3,605.8 WS B, 1E -105L1 5/29/2005 40.0 Slot Slotted Liner, alternating joints of blank;slotted liner for all "and slots 2.5 X. 125 holes, 4 rows/ft ,140.0 C 3,597.6 3,566.3 WS B, 1E-10 LL7 5/29;2005 40.0 Slot D -SAND LINER - =_ — 8,733.0 3,555.9 3,548.6 WS B, 1E -10511 5/29/2005 40.0 Slot LEM, 7,111 - 7,493 8,750.0 3,555.4 3,555.2 WS B, 1E - 10517 8/27/2006 6.0 RPERF 2.5" HSD Guns ENT hole, 60 PLUG, 7,578 deg phase BSAND LINER , 9,328.0 3,542.1 3,531.6 WSB.1E - 105L7 5129;2005 40.0 Slot LEM, 7,462 - 7.662 9,926.0 3,525.4 3,517.0 WS B, 1E - 1051-1 5/29/2005 40.0 Slot SIO1 7,622 10,644.0 3,573.7 3,5162 WS B, tE - 105L1 5129;2005 40.0 Slot TERMEDKTE, _ - -_ 216'296 11,669.0 11,881.0 3,529.8 3,510.8 WS B, 1E -105L7 5/29/2005 40.0 Slot 72,269.0 72,437.0 3,502 4 3,501.7 WS B, 1E -105L7 5129/2005 40.0 Slot _ _ 12,738.0 13,249.0 3,492.5 3,477.5 WS B, 1E -1051-1 5/29/2005 40.0 Slot a Notes: General_ &Safety_ - y w - _ E nd Date Annotatio 6/18/2005 NOTE: TRI LATERAL WELL A -SAND (1E -105), BSAND (1E -1 10517), D -SAND (1E- 10512) 6/18/2006 NOTE: BSAND LEM CON I AINS CAMCO'DB' NIPPLE w/3.92" ID @ 7578' 1/29/2009 NOTE: VIEW SCHEMATIC ./Alaska SchematiC9.0 9/11/2010 NOTE: MBE repair w19 bbls of 1G1- 2289E, 105 degree mehpoim wax @ 8750' Slot.— - --- 8,140- 8,472 - ----y. y: -d RPERF, 8,]54 Sot, 8,133- 9,0294 9,328 -8,623 SIOL 9,926 - 10,385 Si x, 10,64611,023 23 �.. 11,669 - 11,081 12,269 - 12,437 •- Mandrel Details Top Depth Top 12,738 - 13,24 Size 9' (TVD) Intl OD vale Latch TRO Run - �1 T 4,2176 2,399 5 C>8 74 CAMCO Model (in) Senr Type Ty pe (i ^) 1pa9 Run Date Com... ftKB) ( °) Make B SAND KBG -2 1 H - 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 LINER - 2 6,712.9 3,383 2 68 69 CAMCO KBG -2 1 R 1 GAS LIFT DMY BK 0.000 0.0 8;812010 TO (1 E- 1 13,529 ~~at~~ 0~ Q~~~~Q /.E..%~..~~~~ John Peirce Wells Engineer t' ConocoPhillips Alaska, Inc.~~~ 1i~~~4w ~~ ~ ~ ~~ ~ ~ ~~ ~ ~~ 1 P.O. Box 100360 ~,~ Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 E-105L 1 Sundry Number: 310-108 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 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. Q~ Chair DATED this L7 day of April, 2010. Encl. V+' ' ~~~~ STATE OF ALASitA ~~,~ ~LASI~IL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVALSAPR ~ ~ 2010 20 AAC 25.280 ~- y~`~'~" . wAx TRF4TM£r~ 1. Type of Request: Abandon """ Plug for Redrill j- Perforate New Pool Repair ~~ogram J"°` Suspend ~ Rug Perforations f- Perforate ~ Pull Tubing ~"°` ~~~O~F Time Extension ~'""` Operational Shutdown ~"`, Re-enter Susp. Well ~ Stimulate Aker casin g ~eirw:.r Other: Matnx Bypass Event 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 205-007 3. Address: Stratigraphic ~" Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23243-60 ' 7. If pertorating, 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 Required? Yes No )/ 1E-105L1 . 9. Property Designation: 10. Field/Pool(s): ADL 25651, 25660 Kuparuk River Field /West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effeaive Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13529 3479 13018' 3478' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20 108' 108' SURFACE 3811' 13.375 3905' 2285' INTERMEDIATE 8196' 9.625 8280' 3712' B-SAND LINER 5986' 5.5" 13509' 3479' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 7622'-13249' 3595'-3478' 4.5 L-80 7229. Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO'DB-6' NIPPLE W/NO GO 3.875" PROFILE MD= 503 ND= 503 12. Attachments: Description Surrrrnry of Proposal ;~ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ F~loratory Development " Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2010 Oil Gas WDSPL Suspended ~° 16. Verbal Approval: Date: WINJ ~ GINJ WAG ~ Abandoned J" Commission Representative: ~ GSTOR ~ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer Signature ~ ~ Phone: 265-6471 Date 7~~0 mi i n nl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l ~ ,~,~ ~~ vvvvvv Plug Integrity ~"" BOP Test Mechanical Integrity Test J""' Location Clearance ~'~" Other: Subsequent Form Required: ~6. 5/~c~l APPROVED BY /~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10d 1~ 4 ~'a ~ `1'• g•!~ Submit in Duplic~e ORIGINAL k~~.~~~ • 1 E-105L1 Proposal to Wax Fill the B Sand MBE Proposal & Objective: 1 E-105L1 is a B sand lateral with 5.5" slotted liner. A matrix bypass event (MBE) occurred in 105L1 in 2005 to 1E-126 offset producer. A 1/28/06 IPROF of 1/28/06 in 105 showed all PWI entering the B sand. A 6/20/06 IPROF in 105L1 saw a robust MBE at 8750' MD near the heel of 105L1. A Crete job was attempted on 9/4/06 to seal the MBE, but the job failed. On 10/7/06 an Iso-Slv was set in the B LEM. 1 E-105 has since been on just `D & A only' PWI. IPROF data shows 1 E-105 A sand lateral does not take any appreciable PWI. The Iso-Slv will be pulled from the 105 B LEM and replaced with a diverter, then an Iso-Slv will be set to isolate the D sand. In 1 E-126, the Iso-Slv will be pulled from the B LEM to allow inflow from the MBE, then an Iso-Slv will be set in the D LEM. A Step Rate Infectivity Test (BRIT) will then be pumped in 105L1 to determine fluid temperature pumped through an Active-Coil (I-Coil) nozzle at MBE depth vs. various pump rates. This will provide a temperature vs. rate plot at the nozzle to determine pump rates needed for placing liquid wax into the MBE. An Active-Coil job will be performed to seal the 105L1 MBE using 125 F melting point wax heated to 180°F at surface. Hot wax will be pumped down coil to the MBE at 8750' MD as liquid and will be displaced by warm diesel to the MBE, followed by shutdown to let the wax solidify in the MBE to West Sak reservoir temperature (~72 F). Work Sequence: 1 E-105 Infector Work 1 E-126 Producer Work CT Pull 'B' Iso-Sleeve CT Set'B' Diverter CT Set'D' Iso-Sleeve halt X-Flow Pull 'B' Iso-Sleeve o en MBE Set'D' Iso-Sleeve halt X-Flow Pump BRIT using Active-Coil with Distributed Temperature Survey (DTS), with 180°F Seawater pumped in 1 coil volume stages at various rates ranging from 1.5 bpm to 0.5 bpm. Verify an open MBE with DTS across trunk of MBE, and by WHIP vs. In' Rate indicators. Pump Wax Job using Active-Coil with Distributed Temperature Survey (DTS). Pump 100 bbls 180°F Seawater at 1.5 bpm to ensure open 8~ preheated MBE, followed by 10 bbls 180°F Wax at 1.5 bpm, followed by 1 Coil volume of warm Diesel displacement at 1.5 bpm gradually slowed to decreasing rates to put the tail of the wax slug into the MBE just a few degrees above cloud point, followed by shutdown to let wax solidify in MBE. Wait on Wax 4 da s to `cure'. Return to `B' sand onl PWI Flow as `B' sand onl to evaluate Wax Job Pull 'D' Iso-Sleeve Pull D lso-Sleeve Restore PWI to A, B, and D laterals Restore roduction from A, B, and D laterals C~CiC1GC?P~llI~Ip5 t~~~~n~t N n . s w~ YV ellt ~iA Co. ni SSS _N(ellC ng ,tE-tU5S1, 2/t/ 20053,56.15fM _,. - ,., Stltematc Ac Wal Annc Last Caa Cas HANGER. 23 - B-Sf - Lin CONDUCTOR, 0-170 ~ Top NIPPLE. 503- - .,~~ 7 ~ 7' ',Las . : ': i6S/ SURFACE. O•t 't 30-3,905 GAS LIFT, _. 4.21] -"i'` Top - /.: - GAS LIFT, 6.713 Pet SLEEVE, 7,166 Top - ~ 7 LOCATOR, ] 2't S_AL ASSY. 7.rz r 8, 8, D SAND WINDOW. ].258-7,275 a 9.926-0 70,644.0 71.669.0 12.269-0 SLEEVE.7.530 B-SAND V29/2009 (NOTE: VIEW Slot, 8,160-8,672 __ _ 7- RPERF, - 8.750-8.755 ... '"-' Slot 8.733-9,025 . . ~ 1 Slot, ' ~p+' ^~ - ~ ~ ""'w,+: 9,328-9,623 -. 1.o•r I tI }~~w. Slot, __ '° ~ 9.926-10.385 Slot, 18.644-11,023 _. _ Slot, ~~''"77I1 I ~" ~ - - - -_-- 11,66&11,881 _ ,~ ~ ~.m Slot, _ 12,269-12,437 61oL 12,738-13,245 6-SAND LINER ],52~t3,510 \ 13,525 KUP ',Max Angle D (f 8 B-G g WI 50 (°) Item Description Comment 3 79.07 HANGER BAKER MODEL B-7 HOOK HANGER FOR LEM 3 85.19 XO BUSHING XO BUSHING String O._ String ID ... Top (ftK8) Sel Depth (f... Set Depth (ND) ... String WI 41/2 3.958 7.461.5 7.661.8 I 3.598.5 12.60 ~ield Name WBII Status Prod/lnj Type Incl (°) M NEST SAK INJ PWI 98.07 H25 (ppm) Data Annotation ,End Date ~K 40 9/1/2009 Last WO: ', tpth (ftK6) End Date Annotation 6/21/2006 (Rev Reason' FORMAT UPDATE to Schematic9 0 s String O. _ _ String ID . __ .. Top (ftK8) Set Depth (i.. Set Depth (ND) Strin 51/2 4.950 7,523.0 ~ 13,509.9 3,479.4 15 ~' ToP Incl 85.261 SLEEVE Top (TV D) Btm n (ftK8) (ftKl 1 3,595.0 3,61 D 3,597.6 3,51 0; 3,555.9 3,S 3,471.5 1 E-105L1 ActDBtm (ftK8) 13.529.0 -Rig Release Da I 6/20/2005 61CM ID (in) 7.000 5 500 Top Thrd IBl M 0e ID (in) )6 2.500 Zona Data Ish°~ Type Comment tE-706L1 5/2912005 40.0 Slot Slotted Liner, alternating joints of blank slotted liner for all B-Sand slots 2.5 x .125 holes, 4 rows/tt 1 E-t O5L1 5/29/2005 1 ~ 40 0' Slot 1E-105L1 5/29/2005 40.0 Slot 1E-105L1 8/27/2006 6.0 RPERF 2.5" HSD Guns-.26" ENT hole, 60 deg phase tE-105L1 • MICROFILMED 03/01 /2008 DO NOT PLACE • ,., ~~a;_ ~^~ .~-. ~,. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFic~\CvrPgs_Inserts\Microfilm Mazker.~c } q J~~ DATA SUBMITTAL COMP"lIANCE REPORT 7/2/2007 Permit to Drill 2050070 Well Name/No. KUPARUK RIV U WSAK 1 E-1 05L 1 Operator CONOCOPHILLlPS ALASKA INC API No~I?:or/;-23~f?6f1;t ~.¡- MD 13529""'-- TVD 3479 " Completion Date 6/19/2005·? Completion Status 1-01L Current Status 1WINJ ~ --~_.,--~-- -~~--- REQUIRED INFORMATION Interval Start Stop Sent Directional S~ Yes) (data taken from Logs Portion of Master Well Data Maint - Interval OH/ Start Stop CH Received Comments 7458 13529 Open 7/29/2005 IIFR I 7458 13529 Open 7/29/2005 MWD 3862 13494 Open 1/31/2006 GR/EWR4/ABI/CNP/SLD/R I OP/ACALlPWD/GEOPI LOT 3862 13494 Open 1/31/2006 GR/EWR4/ABI/CNP/SLD/R ' OP/ACALlPWD/GEOPILOT 7350 12333 Case 3/24/2006 PresslTemp/Spin 06-Mar- 2006 7650 12500 Case 7/25/2006 Injection Profile PRES, TEMP, SPIN 20-Jun-2006 3862 13486 Open 7/14/2007 LIS Veri, GR, FET, ROP, NPHI, FCNT, NCNT, RHOB, DRHO w/Graphics CGM, EMF, PDF a Sample Set Number Comments Mud Log No Samples No -~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ D Asc Directional Survey ~: Asc Directional Survey Lis 13427 Induction/Resistivity f5 13427 LIS Verification r Injection Profile Injection Profile Lis 15033 Induction/Resistivity L__ Well Cores/Samples Information: Name Log Log Run Scale Media No 15 Blu 5 Blu ~--_.- Received ADDITIONAL INFORMATION Well Cored? yG) Chips Received? ~ Formation Tops @N 0N Daily History Received? Analysis ~ Received? - --~- ---_.----- Comments: Permit to Drill 2050070 MD 13529 TVD 3479 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Well Name/No. KUPARUK RIV U WSAK 1E-105L1 Operator CONOCOPHILLlPS ALASKA INC Completion Date 6/19/2005 Completion Status 1-01L Current Status 1WINJ UIC Y Date: API No. 50-029-23243-60-00 /D-;)~ ~, - e e e \VELL LOG TR\NSMITT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 16. 2007 RE: MWD Formation Evaluation Logs: IE-105, Ll, L2 & PB2, AK-MW -3677560 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 IE-105, Lt, L2 & PB2: LIS & Digital Log Images: 50-029-23243-00,60,61, 71. 1 CD Rom E F ~~ c. ADD 'I i'J .'1",. .'.'p. .' ~..{ r\} j\ .J.. J '~_'-'-TJ~ A::'-¡J'" ~:I ')."".. ~ " , ~ Vb ;Jt'~ WiS, tiC«~fù .'~,.i. p,I¡;.,;fiCmge U.I C- (;) os-- Cö~ it Jf)Ö3d U:L~ 9-05- 00+ 'íf l~o33 u:r. c...- e 6")- - 00 '?f t-Þ J5Ô3 '-{ ~ 15D35 1-1 ~ ,L-VL-I V L-LI STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . . OCT 0 3 20Ub REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission Anchorage 1. Operations Performed: Abandon D Repair Well D Plug Perforations [2] . Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate [2] . Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 205-007 / . 3. Address: Stratigraphic D Service [2] 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23243-60 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1E-105l1 . 8. Property Designatio.n: 10. Field/Pool(s): ADL 25651,25660 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13529' . feet true vertical 3479' feet Plugs (measured) Effective Depth measured 13018' feet Junk (measured) true vertical 3478' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3811' 13-318" 3905' 2285' INTERMEDIATE 8196' 9-518" 8290' 3712' LINER B-SAND 5986' 5-1/2" 13509' 3479' Perforation depth: Measured depth: 7622'-7750', 8140'-8472', 8733'-9029', 9328'-9623', 9926'-10385', 10644'-11023', 11669'-11881', 12269'-12437', 12738'-13249' true vertical depth: 3595'-3606',3597'-3566',3556'-3549', 3543'-3532', 3525'-3517', 3514'-3517', 3530'-3511', 3502'-3502', 3491'-3478' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7229' MD. Packers & SSSV (type & measured depth) ZXP liner packer @ 7462' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) attempt to shut-off injection thief zone with sized CaC03 ,/ I reatment deSCriptions Including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation na na SI Subsequent to operation na na SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service [2] Daily Report of Well Operations _X 16. Well Status after proposed work: OiID GasD WAGD GINJD WINJ[2] WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: n/a Contact Guy Schwartz @ 265-6958 Printed Name Guy SChwarz Title Wells Group Engineer Signature G t.c.c.¡ s: ~,c: ~ Phone Date ló -Z-óc. 7' Pre"ared b" Sharon AI/sun-Drake 263-4612 Form 1 0-40¿evised 04/2004 '...( RBDMS BFt OCT 0 ,4 2006 /P /0'"1 .o(p 0 Submit Ori inal Only ORIGINAL t, {<-j ~(~Æ;16 . 1 E-1 05 Well Events Summary . DATE Summary 8/27/06 Perforated slotted liner in BLat (1 E-1 05 L 1) @ 8750'- 8755' with 2.25" HSD GUNS- .27" v ENT hole wI 60 deg phase. Used reference log, (Schlumberger IPROF tractor log dated June, 20, 2006) for tie in. 9/3/06 PERFORMED WATER SHUT-OFF DIAGNOSTICS USING CCL TO VERIFY B LATERAL ENTRY AND TIED INTO B LEM WITH A22' CORRECTION, WHILE 1E-105 WAS STILL ON INJECTIONS @ 1780 BWPD. PUMP FOUR DIFFERENT 10 BBLS STAGES OF 60# OF HEC WITH 50 Iblbbl OF SC40/SC250/SC500/SC10 9/4106 Pumped two Crete treatments to attempt sealing off BEAST event to neighboring producer. During final stages of "fluff & stuff" to 9000' post treatments, the well showed a down hole pressure increase of 100 psi while injecting @ approx 1 bpm. Logged from 9000' to 6600' Uust above GLM #2) for jewelry log. conOCOPhilliAlaSka, Inc. . KRU 1 E-105L 1 ~ 1E-105L 1 API: 500292324360 Well Tvpe: INJ Anale @ TS: dea@ SSSV Type: NIPPLE Oria Completion: 6/20/2005 Ana Ie @ TD: 90 dea @ 13529 Annular Fluid: Last W/O: Rev Reason: PERFS in slotted liner Reference Loa: 28' RKB Ref Log Date: Last Update: 9/29/2006 Last Tag: 13018' w/Tractor TD: 13537 ftKB L1 8166 TVD Wt Grade Thread Description Size Top Bottom CONDUCTOR 20.000 0 170 170 94.00 K-55 WELDED SURFACE 13.375 0 3905 2286 68.00 L-80 BTC INTERMEDIATE 9.625 0 8290 3579 40.00 L-80 BTCM LINER B-SAND 5.500 7523 13509 3479 15.50 L-80 BTCM Tubing String - TUBING Size I Top I Bottom , TVD I Wt I Grade I Thread 4.500 0 I 7229 I 3521 I 2.00 I L-80 I IBTM Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 7622 - 7750 3595 - 3606 WSB 128 40 5/29/2005 IPERF Slotted Liner, alternating joints of blank/slotted liner for all B-Sand perfs, 2.5" x .125" holes, 4 rows/ft 8140 - 8472 3597 - 3566 WSB 332 40 5/29/2005 IPERF Q 8733 - 8750 3556 - 3555 WSB 17 40 5/29/2005 IPERF 8750 - 8755 3555 - 3555 WSB 5 46 8/27/2006 RPERF 2.5" HSD Guns-.26" ENT hole, 60 deg phase 8755 - 9029 3555 - 3549 WSB 274 40 5/29/2005 IPERF 9328 - 9623 3543 - 3532 WSB 295 40 5/29/2005 IPERF 9926 - 10385 3525 - 3517 WSB 459 40 5/29/2005 IPERF 10644 - 11023 3514-3517 WSB 379 40 5/29/2005 ¡PERF 11669 - 11881 3530 - 3511 WSB 212 40 5/29/2005 IPERF 12269 - 12437 3502 - 3502 WSB 168 40 5/29/2005 IPERF 12738 - 13249 3491 - 3478 WSB 511 40 5/29/2005 IPERF Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 4217 2399 CAMCO KBG-2-1R DMY 1.0 BK 0.000 0 8/19/2005 2 6713 3383 CAMCO KBG-2-1 R DMY 1.0 BK 0.000 0 8/19/2005 other pluQs, equip., etc. - COMMON JEWELRY Depth TVD Type Description ID 23 23 HANGER VET CO GRAY MCA TOP CONNECTION HANGER 4.500 503 503 NIP CAMCO 'DB-6' LANDING NIPPLE 3.875 7164 3505 SLEEVE-C BAKER CMU 'DB-6' SLIDING SLEEVE - CLOSED 6/27/05 3.810 7211 3517 SEAL BAKER SBE SEAL ASSEMBLY w/GBH-22 LOCATOR 3.880 = = Other plugs, equip., etc.) - B-SAND LEM (DIVERTER w/3.0" ID set 2/10/2006) = = Perf = = Depth TVD Type Description ID = = (7622-7750) = = 7462 3572 PACKER ZXP LINER TOP PACKER 7.500 = = 7482 3575 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 = = 7509 3580 B-SAND B-SAND LEM w/HOOK HANGERS 3.688 LEM 7578 3590 NIP CAMCO 'DB' NIPPLE 3.563 7659 3598 SEAL BAKER SEAL ASSEMBLY 3.880 Perf Other plugs, equip., etc.) - D-SAND LEM (ISOLATION SLEEVE w/2.5" ID - set 2/10/2006 (8733-9029) Depth TVD Type Description ID 7191 3512 PACKER ZXP 7" LINER TOP PACKER w/HRD PROFILE 7.500 7213 3517 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 7240 3524 D-SAND D-SAND LEM w/HOOK HANGERS 3.688 LEM General Notes Date Note 6/18/2005 TRI LATERAL WELL w/A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) LEGS 6/18/2005 8.5" OPEN HOLE BEHIND SLOTTED LINERS 6/18/2005 TREE: VET CO GRAY / Horz /4-1/16" 5M TREE CAP CONNECTION: 9" OTIS --- . 07/24/06 Sc~"bepger NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 "05- ~ V\ -COT C) xC- Field: Kuparuk Well Job# BL Color CD Log Description Date ,''0 ,:) 1 E-1 Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E·1iJ5L 1 11213766 INJECTION PROFILE 06/20/06 1 1B·18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-2a 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-13- 11249930 LDL 07111/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & rvD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West ih Avenue, Suite 100 Anchorage, Alaska November 14, 2005 RE: MWD Formation Evaluation Logs J 34 (11 1E-105 L1, é)C6 ~ D22MW-3677560 1 LDWG formatted Disc with verification listing. API#: 50-029-23243-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:Jd:/ï I DG Si~~ ) · - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 94' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 205-00 6. API Number: 50-029-23243-60 9. Well Name and Number: 1 E-105L1 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool Total Depth measured 13529' 3479' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE INTERMEDIATE PROD. CASING Length Size MD TVD Burst Collapse 170' 3811' 8196' 5986' 20" 13-3/8" 9-5/8" 5.5" 170' 3905' 8290' 13509' 170' 2285' 3712' 3479' Perforation depth: Measured depth: 7622'-13249' true vertical depth: 3595'-3478' RBDMS BFl SEP .1 /) Z005 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7229' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 503' Form 10-404 Revised 04/2004 Submit Original Only - . 1 E-10SL 1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/6/200slCommenced WINJ e ~1J~1JŒ LID~ ~~~~~~ e A",A~1iA. OIL AlO) GAS CONSERVATION COMMISSION J ! FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 ilnchorage,Alaska ;lø6- 007 Re: Kuparuk lE-105Ll Sundry Number: 305-254 Dear Mr. Christensen: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 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 23r following the date of this letter, or the next working day if the 23rd day falls 0 hor ay or weekend. A person may not appeal a Commission decision er" r Co unless rehearing has been requested. DATED this 4 day of September, 2005 Encl. , Waiv,er: ,:q. ' , ,: ·'·oinß~,Œ:¡: ,J7,IM~e~lan:!l¡O(l 0 , ,', " . "~, ~Fr(løto,wINJ ' ~e-êntør:SµIi!~ndediNell ,. ,0' .: ~ 5. Permit to Orin Number: , 50-029-23243-60 g, V ',,,II Name and Number: E-105L1 10. : leld/PQol(s); Kup I,ruk River Field / Welõt Sak Oil PoOl PRESENT WELL CONDITION Sl iMMARY Effective Depth TVD (fI): P1ug51 measured): Junk (measured): d--~ ; \.K) 1\ \ c. \La ~ L ~ - , e C¡1) 1- ~ -&. "'1. TyP.9fRe¡;¡~ei~: ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMJ: ,SION APPLICATION FOR SUNDRY APF'ROVAL 20 AAC 25.280 Oper;¡tion SnutdownD F>lu!; PerfO!;;}!iQn~ 0 '.::Ii1ÜII!,'n.ibiI'lQ;,',DParforøteNeWPOOJ ' 0 'Co' 4. Current Well Class: ; , '0'·' .0' D., .. . . ..I' , Su¡¡.pend/ ~~¡¡.mPQr{ P~~or¡ ;I!i, [] , ' . ,.', ,:.".,,¡. "!:. ",',:. , , Alt~r c~lI!n¡¡ ." \ ,'. R~~eirwêll o SlljTit~!; It¡! ,,0 , " ,:¡¡::I\!!"¡~!M~[Qweg Pro9~0iI" 2, Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7, KB ElevatJon (ft); RKB 94' Delleloplnc!tnt 'Sll¡jtigr~phiç o o ExpJ~r. '~Iy 0 ~~ plOD' a. Property Designation: K:\.lp¡irl;!k~¡¥lI:\r Ur¡it 11. Total depth MD (ft); 13529' Casing Total Depth TVD (ft): Effective Depth MD ('It): 3479' Length Size MD TVD 170' 170 3905' 2285 8290' 3712 13509' 3479 , CONDUCTOR SURFACE INTERMEDIATE LINER B·SAND 170' 20" 3811' 8196' 5986' 13-3/8" 9-5/8" 5-112" Perforation Depth MD (ft); 7622'·13249' Packers and SSSV Type: ZXP liner tQP pkr w/HRD SSSV= NIP 12. Attiilchments: '1:!~~!:;llptQii~ummáry of prQpO$al ,D¡¡'ta,I~ØOp~ratioI1S PrpQr'un 0 BPP ,Ska!éh 0 14, es~matødD~tefo¡' '." C:ommencill9 OP~ratjqns; 06129/05 16, Verþ~1 AppÌ'ov¡¡¡l: Date:Oaa6/05, , ,Comroi!l~i0I1R.þf$5imb¡tive: 'Tl;!mMaund,er 17, I h.eni\by;cer1ifythat.~he fQ~$J.oir;Jgistrueand correct to the best of my knowledge. P~il1tld Niilrr:¡¢ Rbert D,.c:rn~i:$tensen Perforation Depth "¡VD (ft); 3595'·347:'8' Tubing :3i~e: w1/2" oJ Packers õlnd SSSV MD (ft) F'KR" 7191'; 7462' 7619' SSSV" 503' 13. Well Class after proPQ$ed wor : Exploratory ODe 'e1opmerit 0 15, Well'$latu$ after proposed,iNo :.; Oil 0 a,a.s , [ :J WAG 0 GINj 0 , ,.', C0nt~t: Title: Phon ! e5Se 7224 Signature Commission Use Onl Conditions of approval; Notify Commission so that a representative may witnes~ Plug Integrity 0 BOP Test Other: .l~~ct....c....4(),,- o Me"',,',,""''''';'' T.., 'ri rcá-"a ~ \ I/'-.- CAeca,\:) ~ ( Þ\ \.0 Locatiol Clearance 0 ~L<b 205-007 6. Ar>1 Number: au rst Collapse :', . Tubing Grade: L-80 iubing MD (ft): 7229' $ervi¡;;e 0, Plugged 0 w,¡;ú 121 , Abandoned, 0 WDSPL 0, MJ LO\tèlmdlMarleMc:Conriel , Problem Well Supetvi$or Date:, Sundry Number; __7'0<)- <XC::; APPRO lED ßY THE CC IßMISSION Date: 6121 39\ï'd v (}?;;¡;f~ -D I V(.~~ ~3M ~SN ÞIEL5S9LI2I5 I2IS:5121 SI2I12I6/8121/5121 A>¡ e e tr~ I~ ~~. .. .0-.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AUG :i 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 94' 8. Property Designation: 11. Total depth MD (ft): 13529' Casing CONDUCTOR -"SURFACE INTERMEDIATE LINER B-SAND Total Depth TVD (ft): 3479' Length 17Q' 3811' 8196' 5986' 20" 13-3/8" 9-518" 5-1/2" Commission Use Only mission so that a representative may witness Sundry Number: 306--¿;( Plug Integrity 0 BOP est 0 Mechanical Integrity Test ~ Location Clearance . "'" U\ ()~\Ü\-\()f'-',. 'xl'- Û.LLO~ 'OJ IÀ' 0 ';J ~. ~OL\ o '^" ~\t: Q. 0 \.JL '\ Other: n L\L \.... ¡ BY ORDER OF COMMISSIONER THE COMMISSION Date: INSTRUCTIONS ON REVERSE Submit in Duplicate e ( "" e .. 1- . '"' 1E-105L 1 DESCRIPTION SUMMARY OF PROPSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Well 1 E-1 05L 1. This well was pre-produced for a 30 day period. Well 1 E-1 05L 1 is the multi- lateral wellbore which will provide pressure support for the West Sak B sand. The 13-3/8" Surface casing (3905' tvd 12286' tvd) was cemented with 798 sx AS Lite followed by219 sx DeepCrete. The 9-5/8" Intermediate casing (8290' md 13713' tvd) was cemented with 650 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 7" x 9-5/8" Liner Top Packer w/HRD located @ 7191' md 13512' tvd. The B sand lateral injection tubing/casing annulus is isolated via upper ZXP 7" x 9-5/8" Liner Top Packer w/HRD located @ 7462' md 13572' tvd and a lower ZXP 7" x 9-5/8" Liner Top Packer w/H RD located @ 7619' md I 35360 l' tvd. The top of West Sak B sand is located at 7516'md 13582' tvd. The top of West Sak A sand is located at 7688' md 13616' tvd. An MITrA was performed on 08/20105; MITIA3000 psi, 30 minutes, Passed b' g ~( ~~ .~= iii"a .~. (Ã ~ 1: ... {IJ ""," "'~~ =- t.H c;;,. 1~a. .... So õ' <0 " = ;::~:à ~æ. " - .... \"1 .... o <1\ 'f!" n ~fh :8..: ~ ~ ""It... .... Wellhead I Tub iug He~d I Tree, 13-5/8" x r 4-1>",5,000ksi Insulated Conductor Casing, 20", 94#, IC55 x 34",0.312"WT@ \ +1-8(1MD . .. .~ IE-I 05 FINAL: ASP NAD Z7Eastings: .5.50,300 ASPNAD 27Nonhings: 5,959,980 PadElevatioR: 66.1' AMSL Tubing String: 4-J/2", 12.6 #, L-80, IBTM Doyon Rig 141 Rig Floor (RF)@O' Elevation: 94.1' AMSL 13-3/8",68#, L-80. BTC, R3 X @ 3,905' MD I 2,285' TVD ---- . @ 71.86 degre.. TD 16" h~le ~i~~II~I.I~~II.~ Lateral Entry Module #2 (LEM), Baker, willi seal bore and ZXP packer above. i¡.f.i.I;t.I~~11 ~¡~1111~~~11~ Tubing, 4-1h" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A21iner +/- 90' below UB" window (I) 3.875" DB nipple set@ 500' (I)GasLiftMandreJ, CAMCO 4-1/2" x I" ModelKBG- 2, one (I) set at 67 deg, 4,217' MD, 2,415' TVD. (I) Gas Lift MandreJ, CAMCO 4-1/2" x I" ModeIKBG- 2, one (I) set at 68 deg, 6,712' MD, 3,380' TVD. (I) Sliding Sleeve, willi 3.812" nipple, one (I) joint above packer. 7,164' MD, 3,508' TVD - 105 L2 "D" Sand Window ¡; @7,258'MD/3,527'TVD 76 degrees "D"Liner, 5-1/2", 15.5#. LSO, BTCM, R3 73 slotted and 71 blank, (0 125" x 2.5" ,Iou, 32 per fooJ, 5 9% open area), ECP packer 16 constrictors@ 12,655',12,405',11,860',11,480', 11,400', 11,090', r@7'300'MD 13,536' TV~ 10,848',10,630',10,150'.9.790',9,305',9,110', 8,601', 8,400', 8,000', 23 66' long, 78.5 degre.. 7,420' ~~-;::: . ." ", IE-105 L2: 8-1/2" D sandlateraJ TD 13,53(1 MD 13,396' TVD 7 Angle 98.63 degrees - - ".' ~- ... .~ - ---.----" -- u"..____.. ..._. ...n._.___ 105LJ "B"SandWindow "B"Liner 5-1/2" 155# L80 BTCM R3 r @ 7,524 MD I 3,583' TVD 65ju slort.d, 63 ju!dank. (0: 125" x 2.5" slou, 32 per fooJ, 5.9% open 79 degrees r area), 18 con,trictors @ 13,260'. 12,710', 12.450', 12,245',11,890', JI.641'. JI,045', 10,641', 10,400',9,910',9,650',9,30(1,9,050',8,700'.8,500', 8,134',7,780',7,610' $~!f$~~ ." IJ!..105L1: 8-1/2" '13" ,and laternl TD 13.529' MD I 3,479' TVD 1 Angle 98.07 degrees -- - --- e 9-5/8",40#, L-80, BTCM, R3 Csg ~ @ 8,295' MD I 3,713' TVD ~ @ 81.54 degrees TD 12- 1/4" hole ,II( ~, e e . .' ConocoPhUUp$ AI$sk3, Inc. KRU TUBING (0-7229, OD:4.500, ID:3.958) Perf (7622-7750) '. 0.:,0: % ~ ~¡~¡li¡¡¡¡¡I¡¡~¡¡li~~ ... J"~ y~A ¡[~i~:iiii:iiiiiiiiiii~i¡ii~ iii fa :·::!:i,:·¡li¡¡:.!.'¡:: :)::r:rri:::: Ii :::::~:::::::::::::::;;~:::: ··············1·············· '::~rft j~j~~rt: = ~ = ::::: = = ::::: = :::,F:,:,:,:,:,"",::: = .no··f·n.n ~.'~':~',:::'::::~.:: ~ ·¡:~·:::.¡~':.¡:I~¡:,c- ........................"....... = nnln.nþ ~:;lI¡:t:i!:i[;:Ë . wI"""'" ~.;~:;:;;:::;;::;...- .............................. ~~¡·¡:::!~;:I:¡I[:~ ~ ~Jî:i;::i~::::::l:: ~ API~ SSSV Type: NIPPLE .' Well Type: PROD Orig Completion: Annular Fluid: Last W/O: Reference Log: 28' RKB Ref Log Date: Last Tag: TO: 13537 ftKB Last T aa Date: Max Hole Angle: 98 dea (àJ 8166 Ci;I$iiÙ1SfrirtóyqOMMQNS1R1NQS>·""':':>"""""··· Description Size Top CONDUCTOR 20.000 0 SURFACE 13.375 0 INTERMEDIATE 9.625 0 LINER B-SAND 5.500 7523 Bottom 170 3905 8290 13509 1E-105L 1 Anale (àJ TS: deg @ Angle @ TO: 90 deg @ 13529 Rev Reason: GLV desian Last Update: 7/1012005 TVD 170 2286 3579 3479 Wt 94.00 68.00 40.00 15.50 I I Size 4.500 I Top I Bottom I TVD I I Grade I I 0 I 7229 I 3521 I 2.00 I L-80 I Grade K-55 L-80 L-80 L-80 Thread WELDED BTC BTCM BTCM Thread IBTM I I Zone Status Ft SPF Date Type Comment WS B 128 40 5/29/2005 IPERF Slotted Liner, alternating joints of blank/slotted liner for all B-Sand perfs, 2.5" x .125" holes, 4 rows/ft 8140 - 8472 3597 - 3566 WS B 8733 - 9029 3556 - 3549 WS B 9328 - 9623 3543 - 3532 WS B 9926 - 10385 3525 - 3517 WS B 10644-11023 3514-3517 WSB 11669-11881 3530-3511 WSB 12269 - 12437 3502 - 3502 WS B 12738 - 13249 3491 - 3478 WS B '~ášt.îftMártëf..e:I$J.Má""Ëlš.>,·""""""'·'·'· . St MD TVD Man Man Type V Mfr V Type V OD Latch Port Mfr 1 4217 2399 CAMCO KBG-2-1R GL V 1.0 2 6713 3383 CAMCO KBG-2-1 R OV 1.0 ·QtbËit·'·:p¡ki$,Ëlq¡j¡P.,.:Ëi~¢.)8CQMMON.1ewet..RY·.·'·':.>"",.,."....,................... Depth TVD Type DescriPtion 23 23 HANGER VETCO GRAY MCA TOP CONNECTION HANGER 503 503 NIP CAMCO 'DB-6' LANDING NIPPLE 7164 3505 SLEEVE-C BAKER CMU 'DB-6' SLIDING SLEEVE - CLOSED 6/27/05 7211 3517 SEAL BAKERSBESEALASSEMBLYw/GBH-22LOCATOR Interval TVD 7622 - 7750 3595 - 3606 332 40 296 40 295 40 459 40 379 40 212 40 168 40 511 40 5/29/2005 5/29/2005 5/29/2005 5/29/2005 5/29/2005 5/29/2005 5/29/2005 5/29/2005 ~ Ë 1= C:::::: = t= == Depth TVD Type Description 7191 3512 PACKER ZXP 7" LINER TOP PACKER w/HRD PROFILE 7213 3517 SBR 190-47 CASING SEAL BORE RECEPTACLE 7240 3524 D-SAND D-SAND LEM w/HOOK HANGERS LEM 7489 3577 SEAL BAKER SEAL ASSEMBLY Depth TVD Type Description 7462 3572 PACKER ZXP LINER TOP PACKER 7482 3575 SBR 190-47 CASING SEAL BORE RECEPTACLE 7509 3580 B-SAND B-SAND LEM w/HOOK HANGERS LEM 7578 3590 NIP CAMCO 'DB' NIPPLE 7659 3598 SEAL BAKER SEAL ASSEMBLY IPERF IPERF IPERF IPERF IPERF IPERF IPERF IPERF BK BK TRO Date Run 0.188 1495 6/29/2005 0.313 0 6/29/2005 Vlv Cmnt Date Note 6/18/2005 TRI LATERAL WELL w/A-SAND (1 E-1 05), B-SAND (1E-105L2), D-SAND (1E-105L2) LEGS 6/18/2005 8.5" OPEN HOLE BEHIND SLOTTED LINERS 6/18/2005 TREE: VETCO GRAY / Harz /4-1/16" 5M TREE CAP CONNECTION: 9" OTIS ID 4.500 3.875 3.810 3.880 ID 7.500 4.750 3.688 3.880 ID 7.500 4.750 3.688 3.563 3.880 OPER & FIELD ,~05 -ct:)(Q ò(:lS-OtJf' ·.)Û5-00.~ "c- \7 C\ -c \L Q.. \) - \J..:)t?-\- ~ \- \E - \.as ) - \o>~1. t- \0 S-L~ e e HECRANICAL INTEGRITY REPORT· '... :-?UD DA!:::: : --c ~~'!-,,....- :..~" r....:..:.....:.i"...: ~: ' 'W"ELL NUMB ER ~~LL DATA 1Ì:>: r3S\~ .HI>. 3~)~ TVD: :?ETD: MD TVD Ca.s iDg: 9.5f« Shoe: <6;M.D HD ~~ \ J. TVD j DV: \-.J~ HI> \-.:J{\:. ·!'Vu _:.:-¡e=:-: Shoe: HD T~TD i :CP: HD :::VD _'JD~:;g: 4Y.~·t Packe:!:' ~\Io \ till TVD j S e c. ê. t: '\ dd'9 ::ole Size and Per£3 to I O\,X-~, ~ \<c. Ss·Š \ d'- '~'-\~'i \¡.)\~,~~ L 1. e. "5;}3 L.,) ~ '\\ "\ \ :--SC?.ÞJEG·.l., INTEGRITY - PART /1 Annulus Press Test: ~p 15 min ; 30 mi.n Com:oents: /"'"" :-Œ:CH.tL1\1ICÞ.L INTEGRITY- PART 12 , ~ )5'-\ ~~\~ Cement: Volumes:' Þ-..mt. Liner Csg ~ ·S\)*>~ : DV \oec ""-t\ ~'t;'.>J t' C': \ ~ C üi t -.¡ 0 1 to c ov et!: per £ s ,:) ~ ~ C'.,. ~ <::. -...) ~'L~\i'~ ~ c.a...:Jc..'\ ._\ 'J.,.),\~C~ <..\...~\ ~soot Q S\)(a ~~ , Theoretical Toe c: ~o1.~ '" ~ '--i <0$.50 ú..L\...O~\.~'\O \c~\ù" Qt 505J.·=-) "-\S'lc ~ S . Cement Bo~d Logg or No) 'Slls-c.s:~ '\'n' AOGCC ~íle '(((~. ..\ .. _. . TK~ c.CA1C:o..,",~ ~1'..Ç\~~~4"1.V\.. ~\~ CEL .:.valuat~on, zone ë.DOVe perfs \~e' \ \_ " '\ \.~. "~..,'~~ \~. \ .. '---.', . h....."-~ . -4 \ \ . .... ,f....'~"\ It '-\. ,~'" '\ ~'0Q'I'> Produ~tion Log: Type Evaluation CONCLUSIONS: . ? ar t . il , Ç. ?f\"1: <.c ~~~ I ¡" I<~\" '\:.<\ S fxso<;;. '-N; \..Ü~ V\ \\ f't.~ , ?ar~ ¡Z: M"'L\~\~\<.L.\'t0 ~~ ~\\\~~",,~~~.~~c;. ... -\'{j C£.>'''''",,- '\'"eA~,,,, ¡!f£~ ~{" -0 ç- ~: west ;:,aK It-IV;) on 1I1J1;;I,;LlOU WlLU ucac_ L> > e Tom, \t:>--\QÇ è)DS--C)CJ~ -\OS \.-1.. J05-()tJ~ - \05 L~ a-OS-O£)~ There has been no injection into this well prior to today. Thanks, Peter Nezaticky / HaL Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 ("', Q.5''( c0~(,_~;'''''~\î'~ N\..tlli"\\Ù",-<.,.J \.:, -~k Sit ,,~<> S~~ <> 0..,(,;. '\ V"\. \ t:-l a s- ~~ ~ \.. ç-~ \.Q: áQ ?¡v( 't(")"Ò ~ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, September 06, 200S 4:21 PM To: NSK West Sak Prod Engr Subject: Re: West Sak 1E-10S on injection with defeated LPP Thanks Pete. Had there been any injection into the well?? Since this is a baseline, likely not. I will look forward to seeing the follow-up. Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 9/6/20053:58 PM: Tom, This email is to notify the AOGCC that 1 E-1 05, a West Sak pre-produced injector, has been placed on injection 9/6/05. Per your request a base line temperature log has be run and is attached and a second temperature log is planned in 1-2 weeks to confirm isolation. «1E-105 Combined Press_Temp .zip» This email is also notifying the AOGCC that the LPP was defeated in accordance with AOGCC Rule Amendment No. C0406B.001 dated 6/14/05. The LPP has been tagged and recorded in the facility safety defeat log. The well is injecting 1600 bwpd at 300 psi. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 9/7/2005 8:32 AM Kb: i~-4U.:j ~unary AppUCaUons; Wl:U U:,-.lVJLl, IVJL..:. e Tom, I'll put it on our schedule. Thank you! MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin,state.ak.us] Sent: Friday, August 26, 20053:15 PM To: Spenceley, Neil Cc: NSK Problem Well Supv Subject: Re: 10-403 Sundry Applications; WeIl1E-105, 105L1, 105L2 Neil, I got the report and that is the information I needed. The well appears to have been pressure tested satisfactorily. MJ, After the temperatures get equilibrated, please contact the Inspectors for a witnessed MIT. Torn Maunder, PE AOGCC Spenceley, Neil wrote, On 8/26/2005 2:38 PM: Tom, I just faxed you a drilling report detailing a test of the top ZXP packer and a service report detailing an MITIA on the well. Let me know if you need anything else. Thanks. Neil -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, August 26, 2005 1 :53 PM To: Spence ley, Neil Cc: NSK Prod Engr Tech; Redman, R.Scott; Hunt, Hai L; Schwartz, Guy L Subject: Re: 10-403 Sundry Applications; WeIl1E-105, 105L1, 105L2 Neil, I have received the faxed cementing information. On the pressure test information, what I need is the testing done at the end of the well when the tubing was run and packer set. That 10f3 9/7/2005 8:32 AM ,Kh: lU:4~j :->unary AppUCaUums; VVt:1l ID-l.VJLl, lVJL... e would have occurred on the end of"L2". Based on the information in the operations report and my review of the USIT log, I concur with the plans you have proposed. I will look for the hard copies of the sundries. Please be aware that I will be out of the office next week. If that doesn't present a problem, I will address the sundries when I return. Please advise if this is acceptable. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 8/26/2005 10:39 AM: Tom, As per our discussion today mine and Guy Schwartz's opinion of the USIT log is that we have good cement from 7006'-7022' with excellent cement from 7008'-7015'. As a result it is likely that there is good isolation between the West Sak 0 sand and the UGNU. In order to confirm this our recommendation is as follows;- 1. Run a baseline temperature log prior to injection 2. Place the well in water injection service 3. Run a temperature log and RST log 1-2 weeks following injection to confirm isolation or identify any channeling that may exist Guy Schwartz is tracking down the 407 completion report, the cement report for the 9 5/8" casing and the pressure test information. Please give me a call at 263-4906 if you have any questions. Thanks. Neil -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Friday, August 26, 200S 9:S1 AM To: NSK Prod Engr Tech Cc: Redman, R.Scott; Spenceley, Neil; Hunt, Hai L Subject: Re: 10-403 Sundry Applications; WelllE-l0S, 10SL1, 10SL2 Thanks Bob. I have included my message back to MJ yesterday. Did it get forwarded to Neil or Hai?? Tom Maunder -----Original Message----- From: Thomas Maunder rmailto:tom maunder(Q}admin.state.ak.us] Sent: Thursday, August 25, 2005 3:20 PM To: NSK Problem Well Supv Subject: IE-II4, et al MJ, I have pulled the file on IE-I05. I don't have the 407 in my hands yet. I do have the 200 9/7/2005 8:32 AM · J:{b: 1O;4"U3 Sundry ApplICatiOnS; well Ib-.!U;)Ll, W;)Lk e USIT. If you all are sending in some information, I need the 9-5/8 cementing information and the pressure tests conducted when the packer was set. Also, if Neil or Hai could look at the USIT and let me know their thoughts on the "fluid channel" around where the L2 junction was planned. Thanks, Tom Maunder, PE AOGCC NSK Prod Engr Tech wrote, On 8/26/2005 9:45 AM: Here are the sundry applications (10-403) and schematics for Wsak 1 E-1 05, 1 05L 1, and 105L2. «1 E-1 05%20FINAL %20Schematic.pdf» «1E-10510-403 OB-25-05.xls» «1E-105 Schematic.pdf» «1E-105L110-403 OB-25-05.xls» «1E-105L1 Schematic.pdf» «1E-105L2 10-403 OB-25-05.xls» «1E-105L2 Schematic.pdf» Hardcopies are in the mail. Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 30f3 917/20058:32 AM .~ 1 a. Well Status: Oil 0 Gas U Plugged D Abandoned D Suspended D WAG D 1t5:'W~I¡š* 0\ mJð~. 20AAC 25.105 20AAC 25.110 Development ~nChOr.loratory D GINJ D WINJ D WDSPL D No. of Completions Other XXX Pre-produced Injector Service D Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., 1'1 Il~, z .l>Ç" 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: June jZ:2005 205-007 3. Address: 6. Date SPudde~b ·z¿£1Ç; uS: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 . ,oob .g .z.' j,Þ 50-029-23243-60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 391' FSL, 224' FEL, Sec. 16, T11N, R10E, UM May 27, 2005 .- 1E-105L1 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 958' FSL, 327' FEL, Sec. 22, T11 N, R10E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1338' FNL, 349' FEL, Sec. 27, T11N, R10E, UM 8209' MD / 3699' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 550300 , y- 5959981 ' Zone- 4 ' 13529' MD /3479' TVD , ALK 25651 / 25660 TPI: x- 555519 y- 5955305 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 555516 ,. V- 5953009 " Zone- 4 n/a ADL 469/470 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 4195' MD 21. Logs Run: ---rfiJ<-weø-.,.j 7'5' z. c..f ,. /YJ Þ / 3~('$;7/-n1> ......- GRlRes .Jtb g. 7.~CP 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE wr. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 62.58# H-40 28' 108' 28' 108' 30" 225 sx AS I 13.375" 68# L-80 28' 3905' 28' 2285' 16" xx sx AS Lite, xx sx DeepCrete 9.625" 40# L-80 28' 8290' 28' 3712' 12.25" 650 sx DeepCrete 5.5" 15.5# L-80 7523' 13509' 3582' 3479' 8.5" slotted liner 4.5" 12.6# L-80 7461' 7662' 3572' 3599' 8.5" LEM 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 7229' 7461' slots in liner from 7622'-13249' ,. 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 40 slots/ft DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift. etc.) July 12, 2005 Pre-produced Injector - shares production with 1 E-1 05 Dat~~t Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1"\ 7/ 005 14 hours Test Period --> 561 631 6 53Bean 1191 I F10w Tu"ing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 464 psi 1204 24-Hour Rate -> 927 1104 11 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rëëi~c~ >;,:r~~f1nrr~"! RBDMs 8FL AUG 03 2D05 D;\TE _ ¡ NONE , _þ.~.L1~ ~-=-I ~1 --:- ". -..---.. ~ c.,t k ..., .........,----.- . STATE OF ALASKA I RECEIVËÐ ALAS~ Oil AND GAS CONSERVATION COMM ION AUG 0.2 2005 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Revised 12/2003 Ç_Q!'JT.INY_ÉD,o~ REV~RSE '. ;\ t ' 1;\ f ff'\ I "::.. ~ (-~) ~ i ';\~ ,;fJ, ~ ~ 1\ """^-~,, ~ ~ 'tij \~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-105L 1 West Sak B 11230' 3532' N/A 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: Mike Greener @ 263-4820 Date 7 /5//aji Signature Title: Phone KUDaruk Drillina Team Leader 4. R. íl(7'/,<ç 5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared by Sharon Allsup-Drake 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 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: I i Disconnected boiler, motor, pump and pit complex's and prepared same for move 9.00 MOVE MOVE MOVE Moved rig off Kokoda 5 and began moving boiler, motor, pump and pit complex's to 2M pad, as of 24:00 hrs were at Alpine turn-off, worked on other complex's on Kokoda 5 preparing them for move 4/26/2005 00:00 - 08:00 8.00 MOVE MOVE MOVE Peak continue moving boiler, motors, pumps and pit modules to 2M pad. Arrived 2M @ 0500 hrs. Peak sows return to Kokoda for next I group. Preparing modules on Kokoda #5 location f/ move to 1 E-1 05. 'Check and fuel. Prep pad f/ move. 08:00 - 12:00 4.00 MOVE MOVE MOVE Load counter weights on two Peak Sows f/ moving subbase. Load rockwasher on peak trailer. Hook two sows to subbase and move off I well @ 1100 hrs. Clean up well area. Load two pipe shed halves. 12:00 - 00:00 12.00. MOVE MOVE MOVE Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5 ! I towards Kuparuk. At midnight leaving midway camp which is 26 miles f/ . Kokoda #5. 4/27/2005 00:00 - 12:30 12.50 MOVE MOVE MOVE I Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5 towards Kuparuk. At midnight leaving midway camp which is 26 miles f/ Kokoda #5. Arrived @ Alpine cutoff @ 0500 hrs. Arrive 2L pad @ 0830 hrs. Change up some loads @ 2m pad. Continue to 1 E pad. Arrived @ pad @ 1230 hrs. 12:30 - 00:00 11.501 MOVE POSN MOVE Spot sub over 1 E-1 05. Spot Pits, pumps, motors. Return with Sows to I 2M pad. Leave 2M pad @ 1800 hrs w/ 2 pipe sheds, rock washer and 'boiler module. Sows leaving 1 E pad to return to Kokoda 5 @ 2100 hrs. Estimated to arrive @ 0100 hrs 4/28/05 to get camp modules. APC Crane set Sperry Sun shack on top of pit module @ 1800 hrs. Vetco gray work w/ crew on change out of upper and lower "0" ring seal on diverter adapter @ 1800 hrs test to 300 psi f/10 min.,. Crew rigging I up modules, unloading trucks. 4/28/2005 00:00 - 12:00 12.00 MOVE RURD RIGUP I Change out saver sub, tighten grabbers, service top drive. Slip and cut I I 38' of drilling line, adjust brakes, rig up interconnects. Prep pits, start taking on water @ 0800 hrs and start mixing spud mud. NU Diverter @ 0900 hrs. Unloading trucks. Prep f/ camp placement on 1 E pad. Rig on I highline @ 09:00 hrs. 12:00 - 00:00 12.00 MOVE RURD RIGUP Accept rig @ 12:00 hrs. Continue mixing spud mud. Camp arrived @ 1600 hrs. Camp and shop set by 18:00 hrs. Camp on highline @ 18:00 hrs. Set pipe sheds and rock washer, berm up around rockwasher. 5.75 DRill rUlD Loading dp into pipe shed. PU mousehole. Prep f/ PU of pipe and BHA. 4/29/2005 100:00 - 05:45 SURFAC PUlMU 5" drill pipe, stand back in derrick 37 stands. . 05:45 - 06:30 0.75' WELCT BOPE SURFAC Function test diverter system. Witness of test waived by AOGCC inspector Chuck Scheve. Initial pressure 2950 psi, after closing 1800 psi. Nitrogen bottles (5) avg 2325 psi. 200 psi buildup req 37 second, ! full charge 3 min 1 sec. (25 seconds to close annular.) 06:30 - 08:30 ! 2.00 DRILL ¡PULD SURFAC Continue PU/MU 5" drill pipe, stand back in derrick 9 stands. Total of 46 I ! stands of 5" dp. PU/MU 10 stands 5" HWDP w/ jars. I i 08:30 - 09:30 1.00 DRILL SFTY SURFAC PRE spud meeting w/ Rig Engineer Mike Greener, both crews attended, and third party team members. 09:30 - 11 :30 2.00 DRILL PULD SURFAC MU 16" BHA #1 to drill out conductor and drill to 263'. 11:30-12:00 ' 0.50 DRILL OTHR SURFAC Fill conductor, check f/leaks. Pressure test mud line to 3000 psi. No leaks. 12:00 - 13:30 1.50 I DRILL REAM SURFAC Ream and clean out 20" conductor f/31' to 97'. 450 gpm @ 275 psi. 13:30-14:15 0.75' DRILL CIRC SURFAC í Circ to shear mud. 14:15 - 16:00 1.75 DRILL REAM SURFAC ! Ream and clean out conductor f/ 97' to 170'. 450 gpm @ 275 psi. PU wt 47K, SO wt 54K, Rot wt 49k Printed: 716/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 16:00 - 18:30 I I 4/29/2005 2.50 DRILL IDRLG SURFAC Drlg 16" hole f/ base of conductor @ 170' to 263'. PU wt 51 k, SO wt 54k, Rot wt 54K, ADT 1.77 hrs 18:30 - 19:00 0.50 DRILL SURV SURFAC Halliburton wireline gyro. Gyro @ 100' and 200'. 19:00 - 21 :30 2.50 DRILL TRIP SURFAC POOH to change BHA. 21 :30 - 00:00 2.50 DRILL PULD SURFAC Pickup/MU BHA #2. 4/30/2005 00:00 - 00:30 0.50 DRILL RIRD SURFAC RU Halliburton WL in derrick f/ gyro. 00:30 - 00:45 0.25 DRILL TRIP SURFAC RIH w/ BHA to 263' 00:45 - 01 :00 0.25 DRILL SURV SURFAC Run gyro @ 260' 01 :00 - 02:30 1.50 DRILL DRLG SURFAC Drilled 16" hole from 263' to 351' MD/351' TVD (88') ART .77 hrs, AST .32 hrs, 0-2K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1025 psi, rot wt 59K, up wt 56K, dn wt 6OK. 02:30 - 03:15 0.75 DRILL SURV SURFAC Run gyro @ 351'. Ran survey twice. 03:15 - 04:30 1.25 DRILL DRLG SURFAC Drilled 16" hole from 351' to 441' MD/440' TVD (90') ART .6 hrs, AST .58 hrs, 2-5K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1200 psi, on bottom torque 1-2k ftIlb, rot wt 60K, up wt 60K, dn wt 62K. 04:30 - 05:00 0.50 DRILL SURV SURFAC Run gyro @ 441'. 05:00 - 06:15 1.25 DRILL DRLG SURFAC Drilled 16" hole from 441' to 531' MD/530' TVD (90') ART .43 hrs, AST ! .48 hrs, 2-8K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure i 1225 psi, on bottom torque 1-2k ftIlb, rot wt 65K, up wt 66K, dn wt 67K. 06: 15 - 06:30 0.25 DRILL SURV . SURFAC Run gyro @ 531'. 06:30 - 07:45 1.25 DRILL DRLG SURFAC Drilled 16" hole from 531' to 626' MD/625' TVD (95') ART .45 hrs, AST .56 hrs, 8-10K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1225 psi, on bottom torque 2k ftIlb, rot wt 69K, up wt 69K, dn wt 70K. 07:45 - 08:30 0.75 DRILL SURV SURFAC Run gyro @ 626'. Ran survey twice. Still no picture. 08:30 - 10:00 1.50 DRILL DRLG SURFAC Drilled 16" hole from 626' to 718' MD/715' TVD (92') ART .36 hrs, AST I I ¡ .85 hrs, 8-12K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure I i 1300 psi, on bottom torque 2-4k ftIlb, rot wt 74K, up wt 73K, dn wt 75K. i 10:00 - 10:45 0.75 DRILL SURV SURFAC Run gyro @ 718', and 626'. 110:45 - 12:00 1.25 DRILL DRLG SURFAC Drilled 16" hole from 718' to 781' MD/776' TVD (63') ART .0 hrs, AST i 1.01 hrs, 23K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1400 psi, on bottom torque 2-4k ftIlb, rot wt 82K, up wt 82K, dn wt 81 K. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 781' to 1553' MD/1411.56' TVD (772') ART .41 hrs, AST 8.82 hrs, 10-40K wob, 60 rpm's, 500 gpm, 9.0-9.2ppg mw, on btm pressure 1400-1600 psi, on bottom torque 2-6k ftIlb, rot wt 82-88K, up wt 82-93K, dn wt 81-85K. 5/1/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC . Drilled 16" hole from 1553' to 2328' MD/1734.99' TVD (775') ART 2.19 ! hrs, AST 6.28 hrs, 10-40K wob, 60 rpm's, 500-554 gpm, 9.2-9.3ppg mw, on btm pressure 1600-1900 psi, on bottom torque 5-11k ftIlb, off I bottom torque 4-9k ftIlb, rot wt 80-87K, up wt 93-102K, dn wt 84-70K. 112:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 2328' to 3174' MD/2024.2' TVD (846') ART 4.71 hrs, AST 3.63 hrs, 10-40K wob, 60 rpm's, 554-613 gpm, 9.3-9.4ppg mw, on btm pressure 1900-2250 psi, on bottom torque 5-11 k ftIlb, off bottom torque 4-9k ftIlb, rot wt 80-83K, up wt 95-1 OOK, dn wt 68-70K. 5/2/2005 00:00 - 07:00 7.00 DRILL DRLG SURFAC i Drilled 16" hole from 3174' to 3607' MD/2176' TVD (433') ART 2.86 I hrs, AST 2.44 hrs, 1 0-25K wob, 60 rpm's,613 gpm, 9.3-9.4ppg mw, on i ' btm pressure 2300 psi, on bottom torque 7-11 k ftIlb, off bottom torque , I 5-9k ftIlb, rot wt 83-79K, up wt 100-115K, dn wt 70-62K. 07:00 - 08:00 i 1.00 DRILL CIRC SURFAC Circ at reduced rate (70 spm/900 psi), change shaker screens on all three shakers f/140's to 11 O's. 08:00 - 08:45 0.75 DRILL DRLG SURFAC Drilled 16" hole from 3607' to 3631' MD/2184.95' TVD (24') ART .38 hrs, AST 0.0 hrs, 10-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm pressure 2350 psi, on bottom torque 10k ftIlb, off bottom torque 9k ftIlb, rot wt 79K, up wt 115K, dn wt 62K. Printed: 7/6/2005 3:50:05 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRilLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Circ at reduced rate (75 spm/950 psi), change shaker screens on all three shakers f/11 O's to 84's. 2.75 DRILL DRLG SURFAC Drilled 16" hole from 3631' to 3748' MD/2228.7' TVD (117') ART .88 hrs, AST 0.0 hrs, 1 0-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm pressure 2300 psi, on bottom torque 10k ftIlb, off bottom torque 5-9k ftIlb, rot wt 85K, up wt 112-115K, dn wt 74-70K. 11.00 DRILL DRLG SURFAC Drilled 16" hole from 3748' to 4,395' MD/2,458.09' TVD (647') ART 3.99 hrs, AST 3.41 hrs, 0-28K wob, 60 rpm's, 613 gpm, 9.3-9.4ppg mw, on btm pressure 2300-2325 psi, on bottom torque 9-10k ftIlb, off bottom torque 8-10k ftIlb, rot wt 85-91 K, up wt 112-131 K, dn wt 70-64K. While drilling at 4,365' MD / 2,447' TVD encounted gas. Gas was 249 units max. Monitored well. Took final surveys. Circulate to POOH. POOH and prepare to backream. Circulate bottoms up @ 4368' w/613 gpm /2300 psi. Rotate and recip. PU wt 132K, SO wt 65k, torque 9-12k. Max gas 70 units. Monitor well. OK. MU stand in derrick. RIH 27' to tag bottom @ 4395' with out pumps. Pump out to 4368'. Backream out of hole f/4368' to 2574'. Lots of clay and sand while reaming @ 2574' @ shakers. Reduce pump rate f/613gpm/2250 psi to ,338 gpm/1000psi. 60 rpm. Continue back reaming, pulling slow to 12296' I . Change out shaker screens on # 2 shaker. Continue to backream f/2296' to 1493' w/338 pgm /1000 psi, 60 rpm. Change out shaker screens on #1 and #2 shaker. Backream out f/1493' to 1089' w/338 gpm /1000 psi, 60 rpm. Monitor well. Static. Attempt to pull out of hole on elevators. Hole swabbing. Backream out f/1 089' to 734' w/ 338gpm/1000 psi, 60 rpm. Pump out f/ 734' to 170' w/ 296 gpm/600 psi. UD BHA #2. Clear rig floor. RU to run 13 3/8" 68 Ib/ft, L-80, BTC. PJSM on running casing. Run 13 3/8" casing. Weatherford float shoe, 2 jts 13 3/8" 68#/ft L-80 BTC, weatherford float collar, check floats on jt #3, continue to run casing. First 3 joints have weatherford bow spring centralizers over stops 10' f/ pin end. First 3 joints were bakerlocked. Next 14 joints have centralizers over box. Total of 17 centralizers. Running out of down wt @ 2565'. Wash casing in hole w/ Frank's fillup tool. Wash f/2565' to 2804'. 5bpm w/ 350 psi. 6 bpm w/ 400 psi. PU wt 185k, SO wt 65K. 21.5 bbls behind calc displacement @ 2804' Wash casing in hole w/ Frank's fillup tool. Wash f/2804' to 3905'. 210bpm w/350 psi. 6 bpm w/400 psi. PU wt 185k, SO wt 65K. 133/8" 68 #/ft L-80 BTC casing stuck @ 3905', Attempt to free casing while circulating w/ Frank's fillup tool w/ 360 gpm /680 psi. Pull max 450k. Toolpusher attempted to push with a little top drive weight. No go. Circ and condition mud. UD jt # 93. UD Frank's fillup tool. Blow down top drie. Clear rig floor. PU/MU 10' pup jt, 13 3/8" 68#/ft L-80 BTC. MU Dowell cement head, and rig up equipment. 09:15 - 12:00 12:00 - 23:00 23:00 - 23:15 0.25 DRILL CIRC SURFAC 23: 15 - 00:00 0.75 DRILL TRIP SURFAC 5/3/2005 00:00 - 01:15 1.25 DRILL CIRC SURFAC 01: 15 - 01 :30 0.25 DRILL OBSV SURFAC 01 :30 - 01 :45 0.25 DRILL TRIP SURFAC 01 :45 - 06:00 4.25 DRILL REAM SURFAC 1 I 106:00 - 06:15 0.25 DRILL OTHR ! SURFAC 06:15 - 08:00 1.75 DRILL REAM SURFAC 08:00 - 08:30 0.50 DRILL I REAM SURFAC 08:30 - 08:45 0.25 DRILL 'OBSV SURFAC 08:45 - 09:00 0.25 DRILL TRIP SURFAC 09:00 - 10:30 1.50 DRILL REAM SURFAC 110:30 - 12:45 2.25 DRILL PULD SURFAC 112:45 - 13:45 1.00 DRILL OTHR SURFAC 113:45 -15:15 1.50 CASE RURD SURFAC 15:15 - 15:45 0.50 CASE SFTY SURFAC 15:45 - 21 :45 6.00 CASE RUNC SURFAC 21:45 - 00:00 2.25 CASE RUNC SURFAC 5/4/2005 00:00 - 02:45 2.75 CASE RUNC SURFAC 02:45 - 09:30 6.75 CASE OTHR SURFAC 09:30 - 10:45 1.25 CASE 10THR SURFAC 10:45 - 12:00 1.25 CEMEN~ PULD SURFAC , Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 12:45 - 15:00 I 2.25 CEMENlpUMP I 1.50 CEMElDISP I I 0.50 CEME~OTHR 1.50 CASE I NUND 3.00 CASE OTHR I 1.50 WELC10THR I 1.00 WELCT OTHR 2.00 WELCT NUND 15:00 - 16:30 16:30 - 17:00 17:00 - 18:30 18:30 - 21 :30 21 :30 - 23:00 5/5/2005 23:00 - 00:00 00:00 - 02:00 Continue circ and condition mud and hole @ 315 gpm w/450 psi. Final MW 9.3+, PV 20, YP 15, 10 see gel 2, 10 min gel 3. PJSM w/ crew w/ continuing to circ. SURFAC Turn over to Dowell. Dowell pump 5 bbls water, test lines to 3500 psi. pump 50 bbls CW1 00 @ 8.34 ppg, follow w/ 50 bbls Mudpush w/ red dye @ 10.5 ppg, drop bottom plug, mix and pump 604 bbls (762sx) lead cement ASlite 10.7ppg @ 7bpm, mix and pump 94 bbls (214sx) tail cement DeepCrete 12.0 ppg @ 7bpm, drop top plug, follow w/20 bbls 'water. Turn over to rig to finish displacement. SURFAC Rig displace cement w/9.3+ ppg mud @ 7 bpm. Mudpush w/ red dye observed @ shakers w/1270 stokes pumped, 10.8 ppg lead cement observed @ shakers w/ 2600 stokes pumped, slow pumps to 3 bpm @ 5300 strokes pumped, bump plug @ 5449 strokes (calculated 5512 strokes). Final pumping pressure 720 psi, bumped plug w/1300 psi. CIP 1635 hrs 5/4/2005. Hold f/5 min., bleed off to check floats. Floats holding. Calculated 291 bbls 10.8 ppg cement circ to surface. SURFAC Flush stack, RID Dowell cement head. SURFAC Nipple down 16" diverter line. PU 21 1/4" diverter. SURFAC PU 133/8" casing to 305 k on weight indicator. Install Vetco Gray emergency slips. Slack off to block weight of 35 K. Calculated weight of casing in mud 226k. SURFAC Make hole in casing at +1' above starting head to drain jt #92. Make 'rough cut @ 1.04' above starting head. Pull remainder of jt # 92 out of hole, removed 31 .1 0'. SURFAC Set diverter down. N/D 21 1/4" diverter. SURFAC Continue NID 21 1/4" diverter. Welder making final cut @ 71/4" above casing slips. Welder start welding on Vetco/Gray Socket weld x Threaded flange adapter. PIN H109976-3 Rev N/C \ H/N C8278 Bore 12.56" UD 13 3/8" casing equipment f/ rig floor. Change out bales, service top drive. Welder continue welding on head. PJSM on PU 5" dp f/ pipe shed. RU mouse hole and iron roughneck I track. Welder continue welding on head. i PU 5" dp f/ pipe shed, stand back in derrick. Welder finished welding head @ 0445 hrs. Continue PU 5" dp f/ pipe shed, rabbit to 2.90", stand back in derrick. Wrap head w/ insulation, let cool slowly. PU total of 39 stands f/ pipe shed. Clear rig floor. PU smaller pieces of BHA #3 to rig floor. Test welds on Vetco/Gray Socket weld x threaded flange adapter to 1800 psi. Found 3 leaks in welds. Welder reweld on Vetco/Gray Socket weld x threaded flange adapter. ,Pressure test weld to 1800 psi f/1 0 min. OK. I Screw on flange to Vetco Gray adapter, NU Vetco/Gray Multibowl. NU 13 5/8" BOPE. Test BOPE. Witness of test by AOGCC inspector John Crisp. Test annular to 250 psi low f/ 5 min., test to 3500 psi high f/5 min. Test all other componets including choke manifold and floor safety valves and dart valve to 250 psi low f/ 5 min and 5000 psi high f/ 5 min. Test . accumulator. 02:00 - 03:45 1.75 CASE 10THR SURFAC 03:45 - 04:15 DRILL SFTY SURFAC 04:15 - 04:45 0.50 DRILL ,PULD SURFAC 04:45 - 08:30 3.75 DRILL IpULD ! SURFAC 08:30 - 10:30 2.00 DRILL OTHR SURFAC I 10:30 - 11 :00 0.50 WELCTY OTHR SURFAC 11:00-12:15 1.25 WELCT~ OTHR SURFAC 12:15 - 12:30 0.25 WELCT OTHR I SURFAC 12:30 - 16:00 350 WELCl NUND SURFAC I 16:00 - 20:451 4.75 WELCT BOPE SURFAC i , Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Rig down test equipment. Install wear bushing (12 5/16"). I MU BHA #3 (12 1/4" bit). upload MWD. 5/6/2005 Note: During pre tour meeting 22:30 hrs 5/4/2005, crew discussed . picking up more drill pipe f/ pipe shed to stand back in derrick and to still to keep track of Doyon 15's 5" dp( stands which avg's about 2' longer than Doyon 14). By the dicscussion it was determined that we had not drilled to the total depth of 4422' (2474' TVD). After adjusting pipe tally, TD drilled too was 4395' (2458'TVD). All previous DIMS I reports f/ 4/29/2005 through 5/5/2005 have been corrected, surveys OTHR I SURFAC have been corrected. 00:00 - 00:30 0.50 DRILL I RIH one stand of flex collars and one stand of 5" HWDP to 260'. Strapping dp in hole. 00:30 - 00:45 0.25 DRILL OTHR SURFAC ,Shallow test MWD. Too much pump noise. Not a good test. 00:45 - 01 :30 0.75 DRILL TRIP SURFAC RIH to 910'. SLM on dp. 01 :30 - 01 :45 0.25 DRILL OTHR SURFAC Shallow test MWD. 132 strokes per minute (558 gpm), 1150 psi. All is good. 01:45 - 03:15 1.50 DRILL TRIP SURFAC RIH f/910' to 3786'. SLM on DP. No correction. 03:15 - 03:30 0.25 DRILL REAM SURFAC Break circ @ 5bpm (210 gpm) w/500 psi. Wash f/3786' to 3814'. Tag float collar. PU wt 120k, SO wt 60k. 03:30 - 04:30 1.00 DRILL CIRC SURFAC Circulate bottoms up after tagging plugs on top of float collar. Circ @ 65 spm (275 gpm) w/ 600 psi. 04:30 - 05:30 1.00 DRILL CIRC SURFAC Pull and set back a stand. RU testing equipment. Continue circ and condition mud @ 65 spm (275 gpm) w/ 600 psi. Circulating through 2" high pressure line. Circ total of 732 bbls. MW 9.1 +, 10 min gel 40, YP 21. 05:30 - 07:00 1.50 CASE DEQT SURFAC Test 13 3/8" 68#/ft, L-80, BTC casing. FC @ 3818' MD/2254' TVD. Test w/9.1 + ppg MW. Apply 3025 psi, hold f/30 min, chart test. No bleed off. Good test. 07:00 - 07:15 0.25 DRILL OTHR SURFAC Rig down test equipment. 07:15 - 08:45 1.50 DRILL REAM SURFAC [Drill out (2) cement wiper plugs, Float collar @ 3818', cement, Float I shoe @ 3905'. ¡REAM 08:45 - 10:45 2.00 DRILL SURFAC I Ream 16" hole below shoe f/ 3905' to 4072' MD. Appears to have sidetracked 16" hole @ 4027' MD/ 2332.07' TVD. 10:45 - 12:00 1.25 DRILL ICIRC SURFAC i Circulate bottoms up @ 4072'. Pumping 600 gpm w/1800 psi. 12:00 - 12:45 0.75 DRILL LOT SURFAC I POOH 2 stands f/4072' to 3886' inside of 13 3/8" casing shoe. RUt ITRIP Perform LOT using 9.1 ppg mud. RID testing equipment. 12:45 - 13:00 0.25 DRILL INTRM1 'RIH f/3886' to 4072'. 13:00 -19:15 6.25 DRILL iDRLG INTRM1 I Drilled 12 1/4" hole from 4072' to 4,722' MD/2591' TVD (650') ART I .1.73 hrs, AST 2.96 hrs, 2-22K wob, 60-80 rpm's, 550-655 gpm, 9.1 ppg I mw, on btm pressure 1600-2100 psi, on bottom torque 6-9k ftllb, off bottom torque 8-9k ftllb, rot wt 89-95K, up wt 11 0-127K, dn wt 64-75K, IINTRM1 I max gas units of 350 while drilling @ 4280' 19:15 -19:30 0.25 DRILL CIRC I Circ prior to short trip. Circulate @ 600 gpm w/1800 psi. 19:30 - 21 :00 1.50 DRILL TRIP i INTRM1 Pump out of hole 7 stands f/4722' to 3885' (13 3/8" shoe @ 3905' MD/ i 2285' TVD). Orient to high side prior to pulling out. Pumping 600 gpm [TRIP w/1800 psi. PU wt 105k. 21 :00 - 21 :45 0.75 DRILL INTRM1 RIH f/3885' to 4630'. MU top drive. Fill pipe, wash f/4630' to TD @ 4722'. SO wt 75K. :45 - 00:00 2.25 DRILL IDRLG INTRM1 Drilled 12 1/4" hole from 4722' to 4,908' MD/2656' TVD (186') ART .63 I hrs, AST .23 hrs, 10-15K wob, 80 rpm's, 634-651 gpm, 9.1ppg mw, on btm pressure 1600-2000 psi, on bottom torque 6-1 Ok ftllb, off bottom torque 8-9k ftllb, up wt 119-115K, dn wt 75-80K, rot wt 93-96K. 51712005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4908' to 5836' MD/3019' TVD (928') ART 2.9 Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: I hrs, AST 3.75 hrs, 5-25K wob, 80-90 rpm's, 550-668 gpm, 9.1 ppg mw, on btm pressure 1900-2250 psi, off bottom pressure 1400-2000, on bottom torque 6-12k ftIlb, off bottom torque 6-12k ftIlb, up wt 115-128K, dn wt 80-86K, rot wt 95-1 03K. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 5836 to 6597' MD/ 3341' TVD (761 ') ART 1.3 hrs, AST 4.16 hrs, 0-30K wob, 95 rpm's, 672 gpm, 9.1 ppg mw, on btm pressure 2150-2300 psi, off bottom pressure 2050-2200, on bottom torque 10-13k ftIlb, off bottom torque 10-16k ftIlb, up wt 127-155K, dn i wt 86-83K, rot wt 104-1 07K. 5/8/2005 i 00:00 - 00:30 0.50 DRILL iDRLG INTRM1 I Drilled 12 1/4" hole from 6597' to 6679' MD/3370' TVD (82') ART 0.0 I I hrs, AST .56 hrs, 10-15K wob, 95 rpm's, 672 gpm, 9.1ppg mw, on btm pressure 2300 psi, off bottom pressure 2200, on bottom torque 13-20k ftIlb, off bottom torque 20-23k ftIlb, up wt 155K, dn wt 84K, rot wt 112K. 00:30 - 04:45 4.25 DRILL REAM IINTRM1 Backream out of hole f/ 6679' to 5468' @ 700 gpm w/2300 psi, 95 rpm. Pulling 3'- 6'/min first 5 stands, then 10'-12'/min. 04:45 - 06:30 1.75 DRILL CIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2300 psi, 95 rpm, pulling real I slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 15%. 06:30 - 07:30 I 1.00 I DRILL REAM INTRM1 I Backream out of hole f/ 5282' to 4725' @ 700 gpm w/2175 psi, 95 rpm. I i I 1 Pulling 10-12'/min. 07:30 - 08:45 1.25 DRILL ICIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2100 psi, 95 rpm, pulling real slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 10-15%. 08:45 - 09:45 1.00 DRILL TRIP INTRM1 RIH f/4597' to 6584'. 09:45 - 10:00 0.25 DRILL REAM INTRM1 Fill pipe. Wash f/6584' to 6679'. 10:00 - 12:00 2.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6679' to 6773' MD/3406' TVD (94') ART 0.0 hrs, AST .85 hrs, 10-15K wob, 95 rpm's, 672 gpm, 9.1ppg mw, on btm I pressure 2300 psi, off bottom pressure 2200, on bottom torque 15-18k I I ftIlb, off bottom torque 15k ftIlb, up wt 157K, dn wt 80K, rot wt 11 OK. 112:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6773' to 7442' MD/3568' TVD (669') ART 3.32 I hrs, AST 3.81 hrs, 1 0-25K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm pressure 2300-2400 psi, off bottom pressure 2200, on bottom torque i 14-15k ftIlb, off bottom torque 14-17k ftIlb, up wt 157-151K, dn wt 76-80K, rot wt 107-11 OK. 5/9/2005 00:00 - 10:30 10.501 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 7442' to 8295' MD/3713' TVD (853') ART 5.31 I I hrs, AST 1.24 hrs, 1 0-35K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm i pressure 2400-2500 psi, off bottom pressure 2200-2300, on bottom torque 13-15k ftIlb, off bottom torque 14-18k ftIlb, up wt 151-154K, dn I wt 76-80K, rot wt 109-11 OK. 10:30 - 12:00 1.50 DRILL CIRC INTRM1 i Pump 60 bbls weighted hi vis sweep @ 680 gpm w/ 2500 psi, rotating I 95 rpm. 12:00 - 12:45 0.751 DRILL 10BSV INTRM1 Monitor well. i 12:45 - 18:45 i 6.00 DRILL ¡REAM INTRM1 Backream out of hole f/ 8295' to 3850' w/ 680 gpm/2500- 1975 psi, ! I rotating 95 rpm. 133/8" shoe is @ 3905'. Mud weight is 9.2+. i 18:45 - 21:15 2.50 DRILL CIRC INTRM1 Circulate, pump 60 bbls hi vis sweep, continue pumping to total of 2 1/2 i BU after sweep to surf, and hole is clean. No increase in cuttings. Pumping @ 680 gpm w/1975 psi. 21:15-22:15 1.00 DRILL TRIP INTRM1 Monitor well. Pull 5 stands on elevators f/3905' to 3440'. Proper fill. RIH !CIRC 5 stands f/ 3440' to 3905'. 22:15 - 22:45 0.50 i DRILL INTRM1 Circ, spot lube pill EMI 920 (f/ metal to metal). Pump 226 bbls, follow w/ 41 bbls mud, 20 bbls dry job, 10 bbls to chase dry job. Pumping @ 680 ,gpm w/1975 psi. Mud weight is 9.4 ppg. 22:45 - 00:00 1.25 DRILL TRIP INTRM1 I Blow down top drive. POOH on elevators f/ 3850' to 3150' @ midnight to run 9 5/8" casing. 5/10/2005 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 POOH from 3,150' to 177', stood back HWDP and jars, LD ghost Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 06:00 - 07:45 07:45 - 08:00 08:00 - 13:45 1.75 CASE 0.25 CASE 5.75 CASE RURD INTRM1 SFTY INTRM1 RUNC INTRM1 13:45 - 15:00 1.25 CASE CIRC INTRM1 15:00 - 16:30 1.50 CASE RUNC INTRM1 16:30 - 17:30 1.00 CASE CIRC INTRM1 17:30 - 20:00 2.50 CASE RUNC INTRM1 20:00 - 21 :30 1.50 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE ¡RUNC INTRM1 5/11/2005 00:00 - 01 :00 1.00 CASE IRUNC INTRM1 I ì 01 :00 - 03:00 2.00 CEMEN~CIRC INTRM1 03:00 - 03:30 03:30 - 05:30 0.50 CEMEN RURD INTRM1 2.00 CEMEN CIRC INTRM1 05:30 - 07: 15 1.75 CEMEN PUMP INTRM1 07:15 - 08:45 I 1.50 CEMENl!DISP INTRM1 I I I I I i 08:45 - 13:00 4.25 WELCT EQRP INTRM1 I reamer Downloaded MWD and LD BHA #3, LD NM flee DC's, MWD and motor Pulled wear bushing and installed test plug Changed out top set of 3 1/2" x 6" VBR's to 9 5/8" csg rams and tested same to 250 psi low and 3,000 psi high RU Doyon's 9 5/8" csg equipment and Franks fill up tool I Held PJSM with rig crew and tong operator on running of 9 5/8" csg RIH with 9 5/8",40#, L-80, BTC-M csg to 2,891', MU 9 5/8" Float shoe, 2 jts csg and float collar, thread locked btm 3 conn's and circ thru float equip and ck ok, RIH with 72 add. jts along with pup jts for spacing out to 2,891' Circ btms up at 2,891', staged pump rate up to 6 bpm at 300 psi, st wt up 120K, dn wt 62K RIH with 95/8" csg from 2,891' to 3,894', (Csg Shoe at 3,905') RIH with 26 add. jts, 100 total jts of csg in hole Circ a csg cap at 3,894' (300 bbls), staged pump rate up to 6 bpm at 400 psi, st wt up 144K, dn wt 63K RIH with an add 50 jts of 9 5/8" csg from 3,894' to 5,800' with no problems, 150 total jts in the hole Circ 200 bbls of mud to cond mud in open hole, staged pump rate up to 5 bpm at 380 psi, st wt up 207K, dn wt 70K RIH with an add 45 jts of 95/8" csg from 5,800' to 7,520',195 jts of 215 in the hole, no problems RIH, st wt up 247K, dn wt 79K Fin RIH with 9 5/8" csg from 7,520' to 8,290' with no problems, ran a total of 215 jts of 9 5/8", 40#, L-80, BTCM csg with 2 pup jts for space out, total ran including float equipment 8,264.87' Began circ and conditioning mud thru Franks fill up tool for cementing, I circ 1.5X btms up, staged pump rate from 3.5 bpm at 500 psi to 7 bpm I at 625 psi, st wt up 245K, dn wt 83K, reciprocated pipe with no problems and full returns LD Franks fill up tool and MU Dowells cement head Fin circ and cond mud for cementing, circ at 7 bpm at 500 psi, st wt up 255K, dn wt 82K, initial MW out, 9.2+ ppg, 69 vis, PV 15, YP 30, Conditioned mud to final MW of 9.2 ppg, 48 vis, 15 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 30 add. bbls of CW 100, Pumped 38 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 260.5 bbls, (650 sxs) of DeepCrete cmt at 12.4 ppg, 2.26 yield with additives, ave 3.7 bpm at 450 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped top plug. Rig displaced cement with 9.0 ppg MOBM, Bumped plug on calc displacement after pumping 621 bbls (96% pump eft.) ave 8 bpm while I displacing cmt, Max pressure 1,230 psi, Slowed pump rate to 3 bpm I (700 psi) with 20 bbls left to pump and bumped plug to 1,200 psi, ck !floats and held, CIP at 08:42 hrs, Reciprocated pipe until 190 bbls cmt I was around shoe when hole began getting tight and stopped reciprocating, Stopped reciprocating with csg with Shoe at 8,290' and I Float Collar at 8,208', Calc TOC @ 5,035', Had full returns thru out job ND stack and RD cement head, PU on stack and installed 9 5/8" Vetco Gray MB 222 (C-21) csg slips per well plan, PU and set slips with 75K st wt, cut oft csg and LD same, Installed 9 5/8" packoft, NU stack and Printed: 71612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/11/2005 08:45 - 13:00 13:00 - 13:45 13:45 - 15:45 15:45 - 16:45 116:45 - 18:00 118:00 - 18:30 18:30 - 20:00 20:00 - 20:15 20:15 - 21:15 5/12/2005 21:15 - 00:00 00:00 - 08:00 I 08:00 - 11 :00 11:00 -11:15 '11:15 -12:00 12:00 - 16:45 16:45 - 18:00 18:00 -18:15 I 18:15 - 19:45 19:45 - 20:00 20:00 - 00:00 5/13/2005 100:00 - 01 :45 I I 01 :45 - 02:30 i 02:30 _ 03:15 03:15 - 06:30 06:30 - 07: 15 07:15 -12:00 I I 4.251 WELCl EaRP INTRM1 0.75 DRILL LOT INTRM1 2.00 DRILL OTHR INTRM1 I , 1.00 WELCT~ BOPE INTRM1 1.25 DRILL RIRD INTRM1 0.50. RIGMNT RSRV INTRM1 1.50 DRILL PULD INTRM1 0.25 DRILL SFTY INTRM1 1.00 DRILL IPULD I INTRM1 I 2.75 DRILL PULD INTRM1 8.00 DRILL PULD INTRM1 3.001 DRILL iPULD ! INTRM1 0.25 DRILL SFTY INTRM1 0.75 DRILL PULD INTRM1 ¡ 4.75 DRILL TRIP INTRM1 1.25 RIGMNT RSRV INTRM1 I 0.25 DRILL TRIP INTRM1 1.50 CASE , DEQT INTRM1 0.25 DRILL ~TRIP IINTRM1 4.00 CEMEN I DSHO INTRM1 I I 1.75 CEMEl DSHO I'NTRM1 0.75¡ DRILL CIRC INTRM1 0.75 DRILL LOT INTRM1 I 3.25 DRILL DRLG 'PROD 0.75 DRILL CIRC PROD 4.75 DRILL DRLG PROD tested packoff to 2,400 psi (80% of collapse) for 10 min and ck ok RU and performed LOT on 133/8" x 95/8" annulus to 16.1 ppg EMW, 801 psi at 2,285' TVD with 9.4 ppg MW, Flushed 13 3/8" x 9 5/8" annulus with 275 bbls water, initial rate 1.5 bpm at 850 psi, final rate 3 bpm at 960 psi, Sim-Ops, changed out top set of pipe rams from 9 5/8" csg rams back to 3 1/2" x 6" VBR's RU and tested 3 1/2" x 6" VBR's and 133/8" 5M flange to 250 psi low I and 3,500 psi high RD 9 5/8" csg equipment and RU to PU 5" DP, installed wear bushing Inspected 5" saver sub and ck ok, RU Little Red on 133/8" x 9 5/8" annulus I PU 30-5" Lo-Tads to rig floor while Little Red freeze protected 133/8" x 9 5/8" annulus with 130 bbls diesel, ave 3 bpm at 1,100 psi Held PJSM on PU 5" DP with Lo-Tads and PU Sperry Suns Geo Span by-pass unit PU and spotted Sperry Suns Geo Span by-pass unit on the off drillers , side of rig floor PU and stood back 14 stds of 5" Dp with Lo-Tads Fin PU and standing back 5" Dp with Lo-Tads, (PU an add. 46 stds, 60 stds total with Lo-Tads) MU 8 1/2" BHA #4 and RIH to 85', MU bit #3, Geo-pilot rotary system ! with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and shallow tested tool Held PJSM on loading of radioactive sources Fin MU BHA #4 and RIH to 385', loaded radioactive sources, PU 3-6 3/4" NM flex Dc's and RIH with HWDP and jars to 385' RIH from 385' to 8,100' Slip and cut 104' of drlg line, circ btms up while cutting drlg line at 175 gpm at 500 psi, rot wt 102K, up wt 162K, dn wt 79K, 9.0 ppg MOBM in , and out RIH from 8,100' and tagged up at 8,196', LD 1 single PU to 8,165' (Fit Collar at 8,208') RU and tested 9 5/8" csg to 3,000 psi for 30 min PU single and RIH from 8,165' to 8,196', est circ and took SPR's Cleaned out cement on top of plugs from 8,196' and began drilling out plugs, drilling out plugs at 8,206' with 5-17 wob, 70 rpm's, 550 gpm at 2,750 psi, on btm torque 12-15K ft-Ibs, rot wt 110K, up wt 155K, dn wt 80K (fit Collar at 8,208') Fin drilling out plugs, fit collar at 8,208', shoe track, fit shoe at 8,290' and drill 20' of new formation from 8,295' to 8,315' MD/3,718' TVD, drilled out at 5-17K wob, 70 rpm's, 550 gpm at 2,750 psi, rot wt 11 OK, up wt 155K, dn wt 80K, ADT .18 hrs I Circ btms up for LOT, CÎrc at 550 gpm at 2,750 psi with 8.9 ppg MOBM in and out, stood back 1 std RU and performed LOT to 12.3 ppg EMW, 650 psi at 3,712' TVD with 8.9 ppg MOBM Drilled 8 1/2" hole in A2 lateral from 8,315' to 8,683' (368') ADT 2.19 hrs Circ btms up and est. PWD baseline, at 120 rpm's and 600 gpm, clean hole ECD was 10.6 ppg Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary i steerable system from 8,683' to 9,169' MD/3,692' TVD (486') ADT 3.41 hrs, 5-15K wob, 120 rpm's, 150 spm, 636 gpm, off btm pressure 3,500 psi, on btm pressure 3,570 psi, off btm torque 10K ft-Ibs, on btm 12K Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 12:00 - 00:00 5/14/2005 00:00 - 12:00 i 12:00 - 20:00 ,20:00 - 22:30 , I 22:30 - 23:00 23:00 - 00:00 5/15/2005 00:00 - 02:00 02:00 - 12:00 12:00 - 16:00 16:00 -17:00 17:00 - 17:45 17:45 - 18:45 18:45 - 00:00 i i 12.00 DRILL PROD 12.00 DRILL I DRLG PROD 8.00 DRILL DRLG PROD 2.50, DRILL ¡REAM! PROD 0.50 DRILL CIRC PROD 1.00 DRILL ¡REAM PROD , , I I 2.00 DRILL DRLG PROD 10.00 DRILL ,DRLG PROD I I 4.00 DRILL I DRLG PROD I 1.00 DRILL CIRC PROD 0.75 DRILL PROD ft-Ibs, rot wt 112K, up wt 165K, dn wt 78K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 150 units, max gas 430 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary isteerable system from 9,169' to 10,232' MD/3,703' TVD (1,063') ADT '7.03 hrs, 5-20K wob, 120 rpm's, 150 spm, 636 gpm, off btm pressure 3,600 psi, on btm pressure 3,625 psi, off btm torque 14-18K ft-Ibs, on btm 13-20K ft-Ibs, rot wt 11 OK, up wt 193K, dn wt 72K, 9.0 ppg MOBM, ave ECD 11.1 ppg, ave BGG 150 units, max gas 229 units, drilled thru several concretions and using Sperry Sun's Stratasteering tool to aid in geosteering Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 10,232' to 11,474' MD/3,648' TVD (1,242') ADT 7.21 hrs, 6-14K wob, 120 rpm's, 150 spm, 636 gpm, 3,625 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 11 OK, up wt 195K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 150 units, max gas 220 units, drilled thru several concretions and using Sperry Sun's Stratasteering tool to aid in geosteering Drilled 81/2" hole in A2 sand lateral from 11,474' to 12,208' MD/3,717' TVD (734') ADT 4.26 hrs, 5-15K wob, 120 rpm's, 141 spm, 600 gpm, 3,600 psi, off btm torque 16-19K ft-Ibs, on btm 16-20K ft-Ibs, rot wt 111 K, up wt 220K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave BGG 120 units, max gas 230 units, crossed fault at 11,420' MD/ 3,650' TVD as predicted and drilled thru btm lobe of A2 sand to determine formation dip, btm of lower A2 sand at 12,125' MD/3,691' TVD, to POOH and open hole sidetrack well per directional plan and geologist . Backreamed out of hole for open hole sidetrack from 12,208' to 11,297', backreamed out at 100 rpm's, 445 gpm at 2,200 psi with 15-17K torque. Note: Began changing out 6" liners in mud pumps over to 5 1/2" liners while backreaming out Circ hole at 11,297' while fin. changing out liners on mud pumps to 5 1/2" I Began cutting trough for open hole sidetrack from 11,297' to 11,332' MD/3,653' TVD, cutting trough at 120 rpm's, 176 spm, 625 gpm at 3,650 psi, rot wt 11 OK, up wt 195K, dn wt 60K, off btm torque 15-16K ft-Ibs Time drilled to sidetrack well from 11,332' to 11,341', sidetracked well at 11,332' MD/3,653' TVD, (9') ADT 1.93 hrs ,Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 11,341' to 12,245' MD/ 3,654' TVD (904') ADT 6.58 hrs, 8-20K wob, 120 rpm's, 176 spm, 625 gpm, 3,800 psi, off btm torque 15-18K ft-Ibs, on btm 15-17K ft-Ibs, rot wt 108K, up wt 207K, dn wt 57K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 100 units, max gas 228 units, using Sperry Sun's Stratasteering tool to aid in geosteering I Drilled 8 1/2" hole from 12,245' to 12,627' MD/3,629' TVD (382') ADT 2.46 hrs, max gas 723 units Stood back 1 std and circ hole while trouble shoot MWD computer problem, re-booted computers, circ and worked pipe from 12,622' to 12,595', circ at 500 gpm, 2,700 psi with 80 rpm's and 17K ft-Ibs torque Drilled 8 1/2" hole from 12,627' to 12,723' MD/3,625' TVD (96') ADT i .89 hrs, max gas 412 units Circ hole while geologist evaluated logs Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/16/2005 00:00 - 00:45 I 0.75 i DRILL IDRLG PROD I I I 00:45 - 01 :30 0.75 DRILL OTHR PROD 01 :30 - 04:30 3.00 DRILL DRLG PROD I ! 04:30 - 04:45 04:45 - 06:30 0.25 DRILL CIRC PROD 1.75 DRILL REAM PROD ! 3.00 DRILL REAM PROD 06:30 - 09:30 09:30 - 11 :30 2.00 DRILL REAM PROD i ! 11 :30 - 12:00 0.50 I DRILL REAM PROD I 12:00 -14:00 2.00 DRILL REAM ,PROD I 114:00 - 15:15 1.25 DRILL ¡REAM PROD I I i i I 15:15-16:00 0.75 DRILL REAM I PROD 16:00 - 16:30 0.50 DRILL TRIP PROD 16:30 - 17:15 0.75 DRILL iTRIP PROD , , I I 17:15 - 19:30 I 2.25 DRILL 'REAM PROD 19:30 - 20:00 0.50 DRILL REAM PROD 20:00 - 20:45 0.75, DRILL ¡REAM PROD I I steerable system from 12,723' to 13,184' MD/3,631' TVD (461 '} ADT 2.8 hrs, 1 D-20K wob, 120 rpm's, 176 spm, 625 gpm, 4,050 psi, off btm torque 18-19K ft-Ibs, on btm 16-17K ft-Ibs, rot wt 112K, up wt 217K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 100 units, max gas 219 units, began using 5" HWDP at 12,820'. NOTE: at 13,000' taking several attempts to get survey and get Geo-pilot to cycle, slowed MWD data rate to improve survey signal, changed out jet on Geo span unit and clean screens on mud pumps and saw improvement in surveys and down linking Geo span unit Drilled 8 1/2" Hole in A2 sand lateral from 13,184' to 13,252' MD/ 3,628' (68') ADT .34 hrs when rig and camp lost highline power Started rig generators and re-established circ and rotation with no I problem, NOTE: rig off highline from 00:45 to 04:45 hrs Drilled 8 1/2" hole in A2 sand lateral from 13,252' to 13,539' MD/3,623' TVD, A2 sand TD, (287') ADT 1.57 hrs, 8-12K wob, 120 rpm's, 625 gpm at 4,100 psi, off btm torque 18-20K ft-Ibs, on btm 17 -18K ft-Ibs, rot wt 115K, up wt 220K, dn wt 68K with 60 stds of 5" DP with Lo-Tads and 8 stds of 5" HWDP in the hole, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave , BGG 80 units, max gas 580 units, Circ hole to clear BHA, circ at 625 gpm at 4,000 psi Backreamd out of hole from 13,539' to 12,911' and started packing off at 12,911', back reamed out at 120 rpm's, 625 gpm at 4,100 psi Backreamed out slow due to packing off from 12,911' to 12,725', backreamed out at 600 gpm, 4,100 psi and 120 rpm's, pumped 30 bbl I wt'd hi vis sweep at 12,800' with slight increase in cuttings back from ì sweep Backkreamed out of hole (BROOH) from 12,725' to 11,488' and started pulling tight and packing off at 11,488', would loose partial returns when packing off then would slow pump rate Worked thru tight spot from 11,488' to 11,393', RIH 1 std to 11,550', I Note: as of 12:00 hrs had lost 50 bbls of MOBM to formation while I backreaming out BROOH from 11,550' to 10,500', no problems thru spot at 11,488', I began pulling tight and packing off at 10,500', backreamed out at 120 rpm's, 15K ft-Ibs torque, 595 gpm at 3,500 psi ¡Worked thru tight spot from 10,500' to 10,492', slowed pump rate due to , circ with only 50% returns, shut down pump and pulled 45K thru tight spot, then RIH to 10,500' and backreamed thru spot with no problems BROOH from 10,492' to 9,945' with no problems, backreamed at 120 rpm's, 15K ft-Ibs torque, 595 gpm at 3,200 psi RIH from 9,945' to 10,615' with no problems . Pumped out of hole from 10,615' to 9,945' at 595 gpm, 3,200 psi with i no problems BROOH from 9,945' to 8,709' and began to pull tight and packing off, backreamed at 120 rpm's, 595 gpm 3,200 psi Worked thru tight spot at 8,709' to 8,689', pulled 45-50K over and pulled thru spot, RIH past spot and backreamed out thru spot with no problems , BROOH from 8,689' to 8,285' with no problems (9 5/8" csg shoe at 8,290') NOTE: While backreaming out of hole found 3 small pin hole wash outs, found 1 in middle of std # 102 and 1 between std #112-#113 and between #120-#121, lost an add 112 bbls of MOBM while Backreaming out, total lost 162 bbls Printed. 716/2005 3.50.05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 0.25 DRILL OBSV PROD Monitored well at shoe, well-static 1.25 DRILL CIRC PROD Pumped 35 bbl wt'd hi vis sweep at shoe and circ 2 complete circ and was clean at shakers, had a slight increase in cuttings back from sweep, circ at 625 gpm, 3,150 psi, 120 rpm's, 12-18K ft-Ibs torque, rot wt 105K, up wt 180K, dn wt 76K Swapped out 6 jts of 5" DP found to be washed out while BROOH RIH from 8,285' to 8,496' RIH from 8,496' to 13,539', had 20K drag at 11,356' and no other problems RIH Pumped 30 bbl wt'd hi vis sweep and circ hole clean, circ at 570 gpm at 4,100 psi, had no increase in cuttings back from sweep Displaced hole over from 9.1 ppg MOBM to 9.0 ppg SFMOBM, circ hole at 535 gpm at 3,450 psi, rot wt 110K, up wt 245K, dn wt 65K Monitored well-static POOH on elevators from 13,539' to 8,206', (95/8" Shoe at 8,290') no problems POOH Monitored well inside csg shoe, well-static Removed shot pin hydraulic assembly on top drive for repair due to leak, (shot pin is locking pin for pipe handler) Slip and cut 57' of drlg line Changed out 4 1/2" IF saver sub on top drive Re-installed shot pin assembly on top drive, Note: hole took 4 bbls of mud in 4 1/2 hrs Dropped 2 3/8" rabbit on a wire and POOH from 8,206' to BHA #4 at 385', LD ghost reamer Stood back 2 stds NM flex Dc's, held PJSM and removed radioactive 'sources, LD a NM flex Dc and downloaded MWD, LD remaining BHA #4 with Geo-pilot and cleared rig floor, calc fill on trip out 117.6 bbls, actual fill 146.7 bbls Held PJSm with SWS and rig crew on RU of wireline and USIT logging tool with WELL TEC tractor tool RU SWS wireline and MU US IT logging tools with tractor tool Fin RU SWS wireline, hydraulic unit on winch failed ,Attempted to repair hydraulic switch on winch with no success, W.O. back up logging truck to arrive rig, RD sheaves, back up unit arrived at 04:30 hrs, RU sheaves and re-head wireline RIH with US IT logging tool and tool stopped at 7,200', cont RIH using tractor tool to 8,160', ran bond log from 8,160' to 4,792' and POOH with , wireline LD USIT and tractor tool & RD SWS wireline RU Doyons 5 1/2" liner running equipment Held PJSM with rig crew on running of liner (crew change) 'PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner per well program to 5,856' (137Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 92 jts (3,944') of 51/2" 15.5#, L-80, BTCM blank liner, ran 45 jts (1,881') of 5 1/2", 15.5# L-80 BTCM liner, ran 121 - 5 '1/2" x 81/2" spiralglide centralizers 1/jt #3 thru # 123, ran 15 constrictor packers placed on blank liner to cover shale sections. MU Baker 190-47 seal bore ext, 9 5/8" x 7" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,909", st wt up 95K, dn wt 67K, , RIH with liner on 5" DP to 8,283' (95/8" csg shoe at 8,290') , Circ a DP capacity at the 9 5/8" csg shoe, circ at 3 bpm at 150 psi, st wt 5/16/2005 '20:45 - 21 :00 21:00-22:15 22:15 - 23:30 1.25 DRILL ,PULD PROD 23:30 - 00:00 0.50 DRILL ITRIP PROD 5/17/2005 00:00 - 03:00 3.00 DRILL TRIP PROD '03:00 - 05:15 2.25 DRILL CIRC PROD 05:15 - 06:45 1.50 DRILL CIRC PROD ,06:45 - 07:00 0.25 DRILL OBSV PROD i 07:00 - 11 :30 4.50 DRILL TRIP PROD 11:30-11:45 0.25 DRILL OBSV PROD 11 :45 - 12:45 1.00 RIGMNT RGRP PROD 12:45 - 13:45 1.00 RIGMNT RSRV PROD 13:45 - 15:45 2.00 RIGMNT RSRV PROD 15:45 -16:15 0.50 RIGMNT RGRP PROD '16:15 - 19:30 3.25 DRILL TRIP PROD 19:30 - 22:45 I 3.25 DRILL PULD 'PROD 22:45 - 23:00 , 0.25 LOG SFTY PROD 123:00 - 00:00 1.00 LOG RURD PROD 5/18/2005 00:00 - 00:30 0.50 LOG RURD ,PROD 00:30 - 05:30 5.00 WAlTON EQIP PROD I 05:30 -10:15 4.75 LOG ELOG PROD 110:15 - 10:45 0.50 LOG RURD PROD 10:45 - 11 :30 0.75 CASE RURD CMPL TN 11:30 -12:00 , 0.50 CASE SFTY 'CMPL TN 12:00 - 16:00 4.00 CASE PULR CMPL TN 16:00 - 16:45 0.75 CASE PULR CMPL TN 16:45 - 18:00 1.25 CASE CMPL TN 118:00 -18:30 0.50 CASE CMPL TN Printed: 7/612005 3:50:05 PM Legal Well Name: 1E-105 Common Well Name: 1 E-1 05 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 5/18/2005 18:00 - 18:30 0.50 I CASE CIRC CMPL TN 118:30 - 21 :45 3.25 CASE RUNL CMPL TN 21 :45 - 22:30 0.75 CASE ¡RUNL CMPL TN I I I 22:30 - 22:45 0.25 CASE DEQT CMPL TN 22:45 - 23:45 1.00 CASE CIRC CMPL TN 23:45 - 00:00 0.25 I CASE OTHR CMPL TN 5/19/2005 100:00 - 04:30 4.50 I DRILL TRIP CMPL TN 104.30 - 05.15 0.75 DRILL PULD CMPL TN 05:15 - 05:45 0.50 DRILL PULD CMPL TN 05:45 - 08:45 3.00 WELCT OTHR PROD2 08:45 - 13:00 4.25 WELCT PROD2 13:00 -13:15 ULD PROD2 13:15 - 16:45 ULD PROD2 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: I 116'45 - 21'00 12ÙO-21;30 I PROD2 PROD2 21 :30 - 22:00 i 22:00 - 23:00 I 0.50 WINDOWTRIP PROD2 1.00 WINDOWsETW I PROD2 1.00 WINDllRC PROD2 15.25 WINDO TWP PROD2 23:00 - 00:00 5/20/2005 00:00 -15:15 15:15 - 16:00 0.75 WINDO IRC PROD2 up 127K, dn wt 75, set torque limiter on top drive to 4,500 ft-Ibs torque, pipe would not rotate unless pipe was moving, would rotate at 4 rpm's at 4,500 ft-Ibs torque I Cont to RIH with 5 1/2" liner on 5" DP from 8,283' and tagged btm at : 13,539' with no problems RIH, PU liner to setting depth, ran liner with 11 stds of 5" DP slick, 60 stds of 5" DP w/Lo-Tads, 8 stds HWDP and 1 std of slick 5" DP , st wt up 200K, dn wt 75K Dropped 1 3/4" ball and pumped down to seat, pumped at 5 bpm at 590 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, slacked off 25K, cont to set packer, pressured up to 4,000 psi and set ZXP packer and release HR running tool, no problems setting hanger/ packer, set "A2" sand liner with TOL @ 7,619' MD/3,601' TVD and ¡shoe at 13,519' MD/3,624' TVD I Tested ZXP packer to 1,000 psi for 5 min & checked ok PU and sat back down to reconfirmed TOL at 7,619', PU from 7,619' to 7,555' and circ btms up, circ at 336 gpm at 800 psi, no gas at btms up, st wt up after setting liner 170K, 100K dn Monitored well-static, preparing to POOH POOH wet with liner running tool from 7,555' to 50', SLM out no corr. 'I LD Baker running tool and cleaned rig floor Pulled wear bushing RU & attempted to set test plug, had trouble setting same, flushed out wellhead and changed out seal ring and finally got to hold pressure Tested rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, NOTE: Jeff Jones with AOGCC waived witnessing of test ! Installed wear bushing Held PJSM, PU & MU Baker 9 5/8" whipstock assembly BHA #5 and RIH to 205', MU seal assembly, locator sub, unloader sub, then PU 2-DP pup jts & 1 jt of 5" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH to 205' I RIH with whipstock assembly on 5" DP from 205' to 6,767' 'Made MADD pass from 6,767' to 6,817 (sensor depth 6,610'-6,660')' and correlated MWD to K-13, no corr. circ at 450 gpm's at 1,425 psi, st wt up 147K, dn wt 80K Cont to RIH from 6,817' , oriented whipstock and tagged TOL at 7,619' Oriented whipstock 12 deg left of high side, tagged TOL at 7,619', set ,whipstock and sheared off from same, top of whipstock at 7,524' : MD/3,583' TVD, st wt up 160K, dn wt 92K, RIH with whipstock milling assembly with 11 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 8 stds and 1 single of 5" HWDP Displaced out 9.0 ppg SFMOBM with re-conditioned 9.0 ppg MOBM, circ at 535 gpm at 2,200 psi I Milled 8 1/2" window in "B" sand lateral from 7,524' to 7,540', cont to I mill to 7,5550' when P-rate slowed to less than 1 '/hr, possibly due to concretion, ADT 14.91 hrs, milled at 2-40K wob, 65-80 rpm's, 437 gpm at 1,625 psi, off btm torque 1 OK ft-Ibs, on btm 7 -16K ft-Ibs, rot wt 120K, up wt 162K, dn wt 92K, pumped several wt'd hi vis sweep while milling window with no increase in cuttings back from sweeps, took 4 hrs to mill window, 10.91 hrs drilling formation below window I Circ btms up while working mills thru window, circ at 437 gpm at 1,625 psi Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 16:00 - 16:15 16:15 -19:30 19:30 - 20:00 I 20:00 - 21 :00 5/21/2005 21 :00 - 00:00 00:00 - 00:30 00:30 - 01 :15 01:15 - 02:00 02:00 - 02:45 02:45 - 03:00 103:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 12:30 12:30 - 15:15 , ì 115:15 - 16:15 16:15 - 17:00 , 17:00 - 00:00 I 5/22/2005 00:00 - 12:00 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 PROD2 PROD2 PROD2 PROD2 IRC PROD2 PROD2 PROD2 PROD2 PROD2 ¡ , 3.50 DRILL PULD PROD2 2.75 DRILL ¡TRIP PROD2 1.00 RIGMNT RSRV PROD2 0.75 DRILL CIRC PROD2 , i 7.00 DRILL DRLG PROD2 12.00 DRILL DRLG i PROD2 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Monitored well-static, pumped dry job POOH from 7,550' to whipstock milling BHA #5 at 106' POOH and LD MWD and mills, gauged mills and lower 8" mill and upper 8 1/2" mill was in gauge, starting mill went in at 8" and came out at 7 1/2" and worn on btm due to possibly drilling on concretion, calc fill on trip out 67 bbls, actual fill 76.5 bbls MU BHA #7 with 8 1/2" bit #5 and lower and upper mills with flex jt, 1-jt HWDP, bumper and oil jars RIH to 76' RIH from 76' to 6,888' RIH with BHA #6, 8 1/2" bit with lower and upper whipstock mills from 6,888' to 7,501' Est circ and rotation, rotated down thru whipstock and window with no problems, TOW at 7,524', BOW at 7,540', tagged gauge hole at 7,541' and cleaned out to 7,550', rot wt 116K, up wt 145K, dn wt 100K, 80 rpm's, 9K ft-Ibs torque, circ at 455 gpm at 1,500 psi Drilled 8 1/2" hole from 7,550' to 7565' MD/3,589' ADT .8 hrs, drilled with 25-28K wob, 90 rpm's, 1 OK ft-Ibs torque, 455 gpm at 1,500 psi, drilled 3' of concretions from 7,550' to 7,553 before being able to drill to 7,565'. drilled a total of 25' of gauge hole from BOW for Geo-Pilot BHA Circ btms up while working mills thru window, circ at 455 gpm at 1,500 ¡psi 1 Monitored well-static, pumped dry job POOH from 7,565' to BHA #6 at 76' POOH LD BHA #6, 8 1/2" bit and upper mill in gauge, LD mills, jars, flex jt and jt of HWDP, cleared rig floor Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing MU 8 1/2" BHA #7 and RIH to 384', MU bit #6, Geo-pilot rotary system ,with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and I shallow tested tool, held PJSM and loaded radioactive sources and RIH with HWDP and jars to 384' RIH with BHA #7 from 384' to 7,424', PU 2-8 1/2" ghost reamers while RIH, 1 reamer is 1,008' back from the bit and the 2nd one is 2,499' back Slip and cut 62' of drlg line and serviced top drive and drawworks Est circ and rotation, circ at 125 gpm at 550 psi and 10 rpm's, rotated down thru whipstock and window with no problems then washed to btm ¡at 7,565', rot wt 110K, up wt 145K, dn wt 90K i Drilled 8 1/2" hole in "B" sand lateral with Geo-Pilot assembly from 17,565' to 7,659' MD/3,598" rvD (94') ADT 6.35 hrs, 5-17K wob, 30-100 rpm's, 182 spm, 650 gpm, 3,100 psi, off btm torque 10K, on btm torque 11 K ft-Ibs, rot wt 11 OK, up wt 145K, dn wt 90K, 9.0 ppg MOBM, ave ECD 10.2 ppg, ave BGG 50 units, Drilled thru concretions from 7,568' to 7,570' and from 7,590' to 7,598' Directionally drilled 8 1/2" hole in "B" sand lateral with Geo pilot rotary steerable system from 7,659' to 8,446' MD/3,567' TVD (787') ADT 8.54 I hrs, 5-15K wob, 100 rpm's, 173 spm, 615 gpm, 3,000 psi, off btm I torque 11-14K ft-Ibs, on btm 11-15K ft-Ibs, rot wt 104K, up wt 157K, dn ¡wt 75K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 100 units, max I gas 303 units. NOTE: While Drlg at 8,030' light on Geo-pilot panel came on showing out of oil, decision was made by Sperry Sun to drill ahead till tool quits, back up tool was delivered to location. Drilled out of zone from 7,800' MD/3,610' rvD to 8,122' MD/3,600' TVD (322') Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: I Directionally drilled 8 1/2" hole in "B" sand lateral from 8,446' to 9,657' MD/3,530' TVD (1,211') ADT 8.94 hrs, 5-15K wob, 120 rpm's, 186 spm, 660 gpm, 3,550 psi, off btm torque 14.5K ft-Ibs, on btm 13K ft-Ibs, rot wt 104K, up wt 163K, dn wt 70K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 170 units, max gas 376 units. Drilled thru several concretions last 24 hrs 12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral with Geo pilot rotary steerable system from 9,657' to 10,388' MD/3,518' TVD (731') ADT ,10.14 hrs, 5-15K wob, 120 rpm's, 186 spm, 660 gpm, 3,600 psi, off btm I torque 12-16K ft-Ibs, on btm 11-15K ft-Ibs, rot wt 104K, up wt 170K, dn 'wt 63K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max I gas 183 units. NOTE: Rig and Camp went off highline at 08:00 hrs to add additional breakers to system for Doyon 15 12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 10,388' to 11,287' MD/ 3,536' TVD (899') ADT 9.53 hrs, 5-25K wob, 120 rpm's, 186 spm, 660 gpm, 3,800 psi, off btm torque 15.5K ft-Ibs, on btm 12-18K ft-Ibs, rot wt 105K, up wt 186K, dn wt 52K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 175 units, max gas 368 units. Cont to Drill thru concretions in "B" Lat 10.50 DRILL ' DRLG PROD2 I Directionally drilled 8 1/2" hole in "B" sand lateral from 11287' to 11,976' MD/3,504' TVD (689') ADT 8.28 hrs, 4-25K wob, 120 rpm's, 173-186 spm, 615- 660 gpm, 3450-3950 psi, off btm torque 16K ft-Ibs, on btm 14-18K ft-Ibs, rot wt 105K, up wt 194K, dn wt 53K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 260 units, max gas 321 units. Cont to Drill thru concretions in "B" Lat Trouble shoot geo-pilot failure. Pump 30 bbl weighted Hi-vis sweep surf -surf @ 660 gpm w/ 3900 psi and 120 rpm rotation. PU wt 180k, SO wt 53k, Rot wt 104k, torque 17k. I Backream out of hole f/11 ,976' to 11,194' @ 40'/min., 11,194' to '10,700' @ 20'/min due to packing off POOH on elevators f/10,700' to 7409'. No problems. Monitor well- static. Pump dry job. POOH f/ 7409' to 108'. PJSM on removing RA sources. Remove RA sources. , Download MWD/LWD tools. UD Geopilot and bit #6, FSF2565 ser # 110684400 PU/MU new geo-pilot and rebuilt bit. Bit # 7, FSF2565 ser # 10676838. Upload MWD/LWD tools. Upload MWD/LWD tools. PJSM on loading nuke sources. PU NMflex drill collar. Break in seals on Geo-pilot. Shallow test MWD. Load nuke sources. RIH, fill pipe every 25 stands. Test MWD, OK. RIH to 7426'. ! Service top drive and drawworks. I Repair hyd fitting on top drive. Continue RIH f/7426' to 11,230'. Fill pipe every 25 stands. Tag up @ 11,230'. Rotated w/1 0 rpm and 3 bpm pump to go through window @ 7524'. Wash and ream in hole f/11 ,230' to 11,480'. Pump @ 462 gpm w/ 2300 psi. Rot wt 95k, torque 15-17k. Continue RIH f/11 ,480' to 11,866'. I Precautionary ream f/11 ,866' to TD @ 11,976'. PU wt 180k, SO wt 60k, i , 5/23/2005 00:00 - 12:00 12:00 - 00:00 5/24/2005 00:00 - 10:30 I 10:30 -11:00 0.50 DRILL OTHR PROD2 11:00-12:15 1.25 DRILL CIRC i PROD2 I I 12:15 -14:30 2.25 DRILL I REAM PROD2 14:30 - 16:45 2.25 DRILL TRIP PROD2 16:45 - 17:00 0.25 I DRILL OBSV PROD2 17:00 - 19:30 i 2.50 DRILL TRIP PROD2 19:30 - 20:00 I 0.50 DRILL SFTY PROD2 20:00 - 20:15 0.25 DRILL OTHR I PROD2 20: 15 - 22:45 2.50 DRILL TRIP I PROD2 I 22:45 - 00:00 1.25 DRILL ITRIP PROD2 ! 5/25/2005 00:00 - 00:30 0.50 I DRILL TRIP PROD2 00:30 - 01 :00 I 0.50 DRILL OTHR PROD2 01 :00 - 01: 15 i 0.25 DRILL OTHR PROD2 01:15-04:30 i 3.25 DRILL TRIP I PROD2 04:30 - 05:00 0.50 RIGMNT RSRV PROD2 05:00 - 06: 15 1.25 RIGMNTi RGRP PROD2 06:15 - 09:00 2.75 DRILL TRIP PROD2 09:00 - 09:45 0.75 DRILL REAM PROD2 I I 09:45 - 10:15 I 0.50 DRILL TRIP PROD2 10: 15 - 10:30 I 0.25 DRILL REAM PROD2 Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/25/2005 10:15 - 10:30 0.25 DRILL I REAM PROD2 Rot wt 109k, torque 15k, no pumps. 10:30 - 12:00 1.50 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 11976' to 12056' MD/3,501' TVD (80') ADT .51 hrs, 7K wob, 120 rpm's, 185 spm, 657 gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot wt 104K, up wt 183K, dn wt 53K, 9.1 ppg MOBM, ave ECD 11.5 ppg, max gas 180 units. Cont to Drill thru concretions in "8" Lat 12:00 - 13:45 1.75 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 12,056' to 12170' MD/3,501' TVD (114') ADT 1.17 hrs, 7-15K wOb, 120 rpm's, 185 spm, 657 gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot wt I 104K, up wt 183K, dn wt 53K, 9.1 ppg MOBM, ave ECD 11.5 ppg, max I I gas 202 units. Cont to Drill thru concretions in "B" Lat I 13:45 - 14:15 0.50 DRILL OTHR PROD2 Reboot MWD computer, trouble shoot geo-pilot. Stand back 1 stand. 14:15 -15:30 1.25 DRILL CIRC PROD2 Circ two bottoms @ 660 gpm wI 4050 psi. Rotate @ 120 rpm. torque I i ' 15k. Set deflection to zero on geo-pilot. 15:30 - 17:30 2.00 DRILL TRIP PROD2 Monitor well - static. POOH on elevators f/12, 156' to 10,595'. Pump dry job. 17:30 - 21 :00 3.50 DRILL TRIP PROD2 POOH on elevators f/10595' to 384'. No problems. 21 :00 - 00:00 3.00 DRILL TRIP PROD2 , Rack back HWDP and jars. Rack back NM flex DC's. PJSM on removing sources. remove sources. Download MWD. Change out I Neutron density tool. I ITRIP Calc displ 96 bbls, actual 125.75 bbls. 5/26/2005 00:00 - 00:15 0.25 DRILL PROD2 Break biU UD geo-pilot. Change one of the 16/32 jets to a 18/32. 00:15 - 00:30 0.25 DRILL OTHR PROD2 Clean rig floor. 00:30 - 01 :00 0.50 DRILL 'PULD PROD2 PUIMU BHA #9. PU/MU geopilot, bit and MWD. 01 :00 - 02:00 I 1.00 DRILL OTHR PROD2 Upload MWD/LWD. 02:00 - 02:45 0.75 DRILL OTHR PROD2 Shallow test MWD, PU 1 NM flex DC, PJSM on loading nuke sources, "load sources. 02:45 - 06:00 3.25 DRILL TRIP PROD2 RIH wI BHA #9/bit7rr1, fill pipe every 25 stands. 06:00 - 07:00 1.00 RIGMNT' RSRV PROD2 Slip and cut 64', 1 1/4" drilling line. 07:00 - 09:15 2.25 DRILL TRIP PROD2 Con't RIH f/7427' to 12060', filling pipe every 25 stands. PU wt 167k, I i SO wt 75k. 09:15 - 09:45 0.50 DRILL REAM PROD2 I Precautionary wash and ream f/12060' to 12170'. Pumping 636 gpm wI 4000 psi, rotating 120 rpm w/15k torque. 09:45 - 12:00 i 2.25 DRILL DRLG PROD2 I Directionally drilled 8 1/2" hole in "B" sand lateral from 12,170' to 12324' ¡ MD/3,505' TVD (154') ADT 1.65 hrs, 5-15K wob, 90-120 rpm's, 179-185 spm, 636-657 gpm, 3700-4100 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt 105K, up wt 183-188K, dn wt 55-45K, 9.0 ppg MOBM, ave ECD 11.5 ppg, max gas 133 units. Cont to Drill thru I concretions in "B" Lat 12:00 - 00:00 12.00 DRILL DRLG "PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 12,324' to 13004' MD/3,479' TVD (680') ADT 7.6 hrs, 5-25K wob, 120 rpm's, 185 spm, 657 gpm, 4000-4100 psi, off btm torque 16-17K ft-Ibs, on btm 15-19K ft-Ibs, rot wt 103-105K, up wt 188-190K, dn wt 35-51 K, 9.0 ppg MOBM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat 5/27/2005 100:00 - 02:00 2.00 DRILL iDRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 13004' to 13105' MD/3,478' TVD (101') ADT 1.12 hrs, 7-17K wob, 120 rpm's, 185 spm, 657 gpm, 4000 psi, off btm torque 16K ft-Ibs, on btm 15-19K ft-Ibs, rot wt 102-103K, up wt 190K, dn wt 35-45K, 9.0 ppg MOBM, ave ECD 11.6 ! 02:00 - 04:00 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat 2.00 DRILL OTHR PROD2 ,Trouble shoot MWD. Tools not working. 04:00 - 06:45 2.75 DRILL DRLG I PROD2 ! Directionally drilled 81/2" hole in "B" sand lateral from 13105' to 13304' MD/3,476' TVD (199') ADT 1.85 hrs, 5-17K wob, 120 rpm's, 185 spm, Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 1657 gpm, 4000-4150 psi, off btm torque 16K ft-Ibs, on btm 16K ft-Ibs, rot wt 1 03-1 05K, up wt 190K, dn wt 35-45K, 9.0 ppg MOBM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat 0.75 DRILL OTHR PROD2 Confirm wI town on loss of survey's, as to how far to drill. 2.50 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 13304' to 13529' MD/3,479' TVD (225') ADT 1.62 hrs, 5-14K wob, 120 rpm's, 185 spm, 657 gpm, 4150-4300 psi, off btm torque 16-17K ft-Ibs, on btm 15K ft-Ibs, rot wt 1 05-1 09K, up wt 190-200K, dn wt 35-53K, 9.0 ppg MOBM, lave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in I"B" Lat i Circ 15 min, attempt to get survey, no luck. SPR's, monitor well. Backream out of hole f/13529' to 12422'. Rotate 120 rpm, circ @ 620 gpm. POOH on elevators f/12422' to 11866'. Hole fill ok. RIH f/11866' to 13482', fill pipe, wash f/13482' to TD @ 13529'. Circ weighted 35 bbl hi-vis sweep, follow wI 3 BU @ 660 gpm wI 3850 psi. PU wt 220k, So wt 47k, torque 20k. Rotate @ 120rpm. I Monitor well- static. Displace wI 947 bbls SFOBM @ 420 gpm wI 21 00 I psi. Stand back 1 stand while circ. Over disp by 60 bbl, returns were 80% SFOBM/20% MOBM SPR's, monitor well-OK. Blow down top drive. POOH f/13479' to 7925'. No problems. Calc displacement 43.6 bbls, actual 60.1 Madd pass fl 7925' bit depth to 7810' bit depth (115'). Logging tool fl 17840' to 7725' (115'). Good SFOBM by 75 bbls pumped. Pumping @ ! 500 gpm wI 2050 psi, 40 rpm. Hole started packing off. Working tight spot @ 7810-7818', hole packing off, increase rotary to 120 rpm, pumping 500 gpm. MU stand, work down to 7900' w/ good circ. Circ 1 1/2 BU while working up to 7810'. Working tight spot @ 7810-7818', hole packing off, rotary @ 120 rpm, pumping 500 gpm. Work down to 7900' wI good circ. Circ while working up to 7810'. Hole still packing off@ 7818'. RIH to below where started circulating. RIH to 9194', no problems.. POOH on elevators f/8194'-7500', to inside 9 5/8" casing. No problems. Monitor well. POOH f/7500' to 381'. Rack back stand of HWDP wI jars, PU a jt of dp- rack back 2NM flex drill collars, PJSM, remove nuke sources. ¡Attempt to download MWD. No luck. UD MWD to download in pipe 'shed. Continue to work - LD BHA. Clean rig floor. PU whipstock retrieving tools fl beaver slide. MU BHA to retrieve whipstock. RIH, fill pipe every 25 stands. RIH to 6318'. PU 15 jts 5" HWDP, RIH to 7529'. PU wt 190k, SO wt 103k. I Hook and pull free whipstock assembly. Stand back 1 stand. I CBU @ 515 gpm wI 2950 psi. Monitor well- static. POOH wI whipstock assembly. Rabbit 75 stands dp wI 2.4" rabbit. UD Whipstock retrieving assembly. No whipstock assembly recovered. calc fill 68 bbls, actual 83 bbls Clean rig floor. Functioned blind rams. I Service rig and top drive. I 06:45 - 07:30 107:30 - 10:00 I 10:00 - 10:30 0.50 I DRILL CIRC PROD2 10:30 - 12:00 1.50 DRILL REAM PROD2 112:00 - 12:30 0.50 DRILL WIPR PROD2 112:30 - 13:45 1.25 DRILL WIPR PROD2 113:45 - 15:45 2.00 DRILL CIRC PROD2 I 15:45 - 17:45 2.00 I DRILL CIRC I PROD2 , I 17:45 - 18:00 0.25 DRILL OBSV PROD2 18:00 - 21 :30 3.50 DRILL TRIP PROD2 21 :30 - 22:30 1.00 DRILL OTHR PROD2 22:30 - 00:00 I 1.50 DRILL CIRC PROD2 5/28/2005 00:00 - 00:45 0.75 DRILL ¡CIRC PROD2 I , ì I 00:45 - 02:00 1.25 DRILL TRIP PROD2 02:00 - 05:45 3.75 DRILL ¡TRIP PROD2 05:45 - 06:30 0.75 DRILL ,TRIP PROD2 ! 06:30 - 07:00 I 0.50 DRILL PULD PROD2 I I 07:00 - 08:00 1.00 DRILL PULD PROD2 08:00 - 08:30 I 0.50 DRILL PULD CMPL T2 08:30 - 09:00 I 0.50 FISH ¡PULD CMPL T2 09:00 - 12:00 3.00 FISH ¡TRIP CMPL T2 12:00 - 12:30 0.50 FISH ITRIP I CMPL T2 ,12:30 - 13:45 1.25 FISH FISH I CMPL T2 113:45 - 14:30 0.75 FISH CIRC CMPL T2 14:30 - 18:45 4.25! FISH TRIP CMPL T2 I 18:45 -19:30 I 0.75 FISH PULD CMPL T2 I 19:30 - 20:00 0.50 FISH 'OTHR CMPL T2 20:00 - 20:45 0.75 RIGMNT RSRV I CMPL T2 Printed: 716/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Note: While picking 6 1/4" Bowen jars back up from ground to floor via I beaver slide, Derrickman Jon Larson hurt left arm tailing jars through to floorhands on rig floor. i 20:45 - 21 :15 0.50 FISH PULD CMPL T2 PUlMU BHA to retrieve whipstock assembly. 21 :45 - 00:00 2.25 FISH TRIP CMPL T2 RIH wI whipstock retrieving BHA #2, fill pipe every 25 stands. RIH to 6319'. 5/29/2005 00:00 - 00:30 0,50 FISH TRIP CMPL T2 Con't RIH wI whipstock retrieving BHA #2 f/6319' to 7510', PU single I dp. PU wt 185k, SO wt 105k 00:30 - 00:45 0.251 FISH FISH CMPL T2 !Attempt to engage key slot in whipstock. Rotate 1/4 turn each time, I,a,oh" '0 00 3'" attempt 00:45 - 01 :00 0.25 FISH JAR CMPL T2 Pull to 225k on weight indicator, allow jars to hit, pull to 275k on indicator. Re-cock jars, PU and jar wI 300k on indicator, pull to 325k on i indicator. Re-cock jars, PU and jar wI 300k on indicator, pulled I whipstock free w/318k on indicator. Continue PU to break off single. Dragging to as much as 235k fl first 20'. UD single dp. ,01 :00 - 01: 15 0.25 FISH TRIP I CMPL T2 Pull one stand HWDP-slow. Check fl swabbing, OK. 01:15-02:15 1.00 FISH CIRC CMPL T2 j Circ one and a half BU (561 bbls) @ 420 gpm wI 1450 psi. Lost 22.2 I bbls mud while circ. 02:15 - 02:30 I 0.25 FISH OTHR CMPL T2 Monitor well. 02:30 - 07:00 4.50 FISH TRIP CMPL T2 POOH slow wI whipstock retrieval assembly #2. Cal fill 65.04 bbls, i actual 75.2 bbls. 07:00 - 09:00 2.00 I FISH PULD CMPL T2 UD whipstock assembly (98.5') consisting of: 95/8" whipstock slide, debris barrier sub wI cup, ported drain sub, shear disconnect, bottom trip anchor, blanking sub, 1 jt 5" dp, 2- 5" dp pup jts, unloader sub, crossover, locator sub, seal assembly. 09:00 - 09:45 0.75 CASE RURD CMPL T2 Clean rig floor, RU casing equip to run 5.5" Blat liner. 09:45 - 10:00 0.25 CASE SFTY CMPL T2 PJSM wI all team members in running 5.5" liner. 10:00 - 12:00 2.00 CASE RUNC CMPL T2 PUIMUIRIH wI 5.5" L-80 BTCM slotted and blank liner per detail. Baker 5.5" guide shoe(no float), 5.5" 15.5 #/ft L-80 BTCM blank bent joint, 5 jts 5.5" blank, 1 jt slotted wI insert bushing @ pin end, 11jts 5.5" slotted, 7 jts 5.5" blank, 4 jts 5.5" slotted, 9 jts 5.5" blank, 5 jts 5.5" slotted, 15 jts 5.5" blank, 9 jts 5.5" slotted, 6 jts 5.5"blank, 11 jts 5.5" slotted, 7 jts 5.5" blank, 7 jts, 5.5" slotted, 7 jts, 5.5" blank, 7 jts 5.5" slotted, 6 jts 5.5" blank, 8 jts 5.5" slotted, 9 jts 5.5" blank, 3 jts 5.5" slotted, 21' blank 5.5" marker jt, 1 jt 5.5" blank, 3.77' blank 5.5" pup jt, 5.5" casing swivel, 5.5" x 7" crossover bushing, Baker Model B-1 hook hanger 9 5/8" x 7". Total length 5986.74'. Total of 18 constrictor packers were run to be placed @ 13260', 12710', 12450', 12245', 11890', 11641', 11045', .10641',10400',9910',9650',9300',9050',8700', 8500', 8134', 7780', I a"" 7610' Roo total of 53 jts '0 ho~ @ 0000. 12:00 - 13:45 1.75 CASE RUNC CMPL T2 Continue running 5.5" L-80 BTCM 15.5 ppf L-80 slottted and blank "B" 0.75' CASE lateral liner. Total of 137+ insert + bent jt+ marker jt. 13:45 - 14:30 RURD CMPL T2 i RID Doyon casing tools. RU to PU Baker model B-1 Hook Hanger on 5" I dp. PUlMU hook hanger. PU 93k, SO wt 63k 14:30 - 15:45 1.25 CASE RUNL CMPL T2 Run liner on 5" dp f/5994' to 7530'. 15:45 - 18:00 2.25 CASE OTHR CMPL T2 ,Orient bent joint to exit window. 18:00 - 23:15 5.25 CASE RUNL CMPL T2 I Run 5.5"liner on open hole on 5" dp f/7530' to 13512'. PU wt 205k, SO wt 65k. Calc displacement 108 bbls, actual 119 bbls. 23:15 - 00:00 0.75 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl '13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to hook window. 5/30/2005 100:00 - 01 :30 1.50 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl ,13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to I I Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 01 :30 - 02:00 i 0.50 CASE 'CIRC CMPL T2 I 02:00 - 02:30 i 0.50 CASE OTHR I CMPL T2 02:30 - 02:45 0.251 CASE OTHR CMPL T2 02:45 - 03:30 0.75 CASE CIRC CMPL T2 03:30 - 03:45 0.25 CASE OTHR CMPL T2 03:45 - 07:00 3.25 CASE OTHR CMPL T2 07:00 - 07:30 0.50 CASE OTHR CMPL T2 07:30 - 07:45 0.25 CASE 10THR CMPL T2 107:45 - 08:30 0.75 CMPLTN RURD CMPL T2 08:30 - 08:45 0.25 CMPL TN SFTY CMPL T2 08:45 - 10:30 1.75 CMPL TN PULD CMPL T2 10:30 - 12:00 12:00 - 12:30 12:30 - 13:00 I I í 1.50 CMPL TNI PULD CMPL T2 0.50 CMPL T~ OTHR CMPL T2 0.50 WELCT BOPE CMPL T2 0.75 WELCT BOPE I CMPL T2 40751 WELC1BOPE CMPLT2 0.50 I WELCTU OTHR CMPL T2 0.50 CMPL TN SFTY CMPL T2 1.00 CMPL TN PULD CMPL T2 13:00 - 13:45 13:45 - 18:30 18:30 -19:00 19:00 - 19:30 19:30 - 20:30 I hook window. PU wt 205-225k, SO wt 75-55k. Hooked window wI 61 ' in (4.23' low shows btm of window @ 7544.23') on stand 79. Hole taking weight on first 3 attempts to hook hanger and giving false hooks. !Turned pipe 14 times until good confirmed hook. Hooked 3 times in the 'only place that would hook w/61' in. Top of Baker hook hanger @ 7523.18', Baker guide shoe @ 13509.92'. Set all available weight to verify down-35k on indicator). Break off top drive. Drop Baker's ball. Circ ball down @ 2bpm wI 225 psi, increase to 4bpm wI 625 psi. Slow down to 3bpm @ 1000 strokes I wI 400 psi, con't pumping @ 3 bpm, ball reached seat @ 1540 strokes, increasing presure, ball seat blew @ 1725 psi. Work left hand torque in pipe to release hook hanger running tool. Work pipe f/35k to 200k. Once finally released, PU wt 190-195k wlo liner. Set 1 back down. Tag top with all DP wt available. Top in same spot--7523' (61.3' in on stand 79 w/35k on wt indicator) Pull stand 79 and set back (Pulled 61' out of hole+ 3' above floor in slips= 64'). Bottom of hook hanger ball seat, circ sub orifice BPV and guide assembly @ 7501'. PU wt 185k to 190k , Circulate bottoms up @ 444 gpm wI 1500 psi. Circ total of 440 bbls. Monitor well. POOH wI Baker B-1 hook hanger running assembly. Service breaks and lay down liner running tools and ball sear, circ sub orifice BPV, and guide assemble. I Clean rig floor. RU Doyon casing tools to run 4 1/2" LEM. PJSM on running LEM. PUlMU LEM assembly: Baker Seal assembly, 41/2" 12.6 ppf IBT box X STL pin x-o jt, (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing, Cameo 4 1/2" 'DB nipple wI 3.563" ID profile, (1) jt 4 1/2" 12.6 ppf L-80 IBT tubing, LEM,4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563 box x 51/2" hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker Hydraulic setting I tool, Baker running tool. While making up and lowering seals into top of X-O below ZXP, seals hung up; ZXP sheared, slips moved to set position. RUlLO LEM BHA. I Clean rig floor. RU to test BOPE. Witness of BOP test waived by AOGCC inspector John Crisp. Pull riser to check annular preventor, visual inspection. 114 day BOPE test. Tested annular to 250 psi low and 2800 psi high. ¡Tested rams and valves to 250 psi low and 3500 psi high. Held each I test 5 min. Tested accumulator. Tested IBOP valves and floor safety valves 250/3500, held each test 5 min. I Rig down test equipment. I PJSM on running LEM. PUIMU LEM assembly: Baker Seal assembly, 4 1/2" 12.6 ppf IBT box X STL pin x-o jt, (2) joints 41/2" 12.6 ppf L-80 IBT tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 4 1/2" 12.6 ppf L-80 IBT tubing, LEM,4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf, IBT casing swivel, X-O bushing 5 1/2" hydril563 box x 41/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563 box x 51/2" Printed: 71612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 119:30 - 20:30 I 20:30 - 21 :00 0.50 CMPL TN RURD CMPL T2 21 :00 - 00:00 3.00 CMPL TN TRIP CMPL T2 5/31/2005 00:00 - 01 :30 1.50 CMPL TN TRIP CMPL T2 01 :30 - 04:30 3.00 CMPL TN OTHR CMPL T2 04:30 - 05:00 0.50 CMPL TN TRIP CMPL T2 I ,05:00 - 07:15 2.25 CMPL TN OTHR CMPL T2 07:15 - 12:00 4.75 CMPL TN TRIP CMPL T2 12:00 - 13:30 1.50 CMPL TN PULD I CMPL T2 13:30 - 13:45 0.25 CMPL TN OTHR CMPL T2 13:45 -15:00 I 1.25 CMPL TN PULD CMPL T2 15:00 - 20:00 5.00 CMPL TN TRIP CMPL T2 20:00 - 21 :15 1.25 CMPL TN OTHR CMPL T2 ! 21:15-22:30 1.25 RIGMNT RSRV CMPL T2 22:30 - 00:00 I 1.50 RIGMNTIRSRV CMPL T2 1 1 6/1/2005 ,00:00 - 01:00 1.00 CMPL TN OTHR CMPL T2 i i CMPL T2 01 :00 - 02:30 1.50 CMPL TNI CIRC I I 02:30 - 02:45 I 0.25 CMPL TN OTHR CMPL T2 02:45 - 07:00 4.25 CMPL TN TRIP CMPL T2 07:00 - 08:30 1.50 CMPL TN PULD CMPL T2 08:30 - 09:30 1.00 FISH OTHR CMPL T2 09:30 - 11 :30 2.00 FISH IPULD CMPL T2 , 11 :30 - 14:30 3.00 FISH TRIP CMPL T2 114:30 - 15:00 0.50 FISH CIRC I CMPL T2 15:00 - 16:45 I 1.75 FISH MILL CMPL T2 I I i 16:45 - 18:30 1.75 FISH OTHR CMPL T2 18:30 - 19:45 1.25 FISH CIRC CMPL T2 19:45 - 20:00 0.25 FISH OTHR I CMPL T2 '20:00 - 21 :00 1.00 FISH TRIP CMPL T2 21 :00 - 21:45 0.75 FISH TRIP CMPL T2 21 :45 - 00:00 2.25 FISH MILL CMPL T2 í 6/2/2005 00:00 - 00:45 0.75 FISH MILL I CMPL T2 00:45-01:15 0.50 FISH MILL CMPL T2 hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker Hydraulic setting tool, Baker running tools. RID casing tools. I RIH wI LEM to 5016' I RIH wI LEM f/5016' to 7545'. PU wt 180K, SO wt 101K I Tag up @ 7545'. Orient and work through hook hanger. Con't RIH wI LEM assembly f/7545' to 7619'. Tag up @ 7619'. Attempt to work through- no luck. PU wt 195k, SO wt 105k. Tag up @ 7619'. Attempt to work through- no luck. PU wt 195k, SO wt 105k. i Monitor well, POOH f/7619' to 216'. I RU and UD LEM assembly. Clean Rig Floor. PU seal assembly wI a bent joint 4 1/2" tbg, + rest of LEM assembly. RU to RIH wI LEM assembly, RIH wI LEM assembly to 7619'. Tag up @ 7619'. Try to work by top of liner hanger- no luck. PU wt ¡185K, SO wt 107K, Rot wt 130k. Pull partial stand and 10' pup jt. Stand 77 in hole. Slip and cut 65' drilling line. Service top drive, inspect saver sub, clean rig floor. Prepare to take Oil base mud into pits. Prepare to remove solids free oil base mud fl pits and store into uprights. ,Prepare to take 9.0 ppg MOBM into Pits, remove 9.0 ppgSolids free oil base mud fl pits. Transfer to upright storage. Displace solids free 9.0 ppg to Mineral oil base mud 9.0 ppg @ 89 spm (7.5 bpm) wI 900 psi. 35 bbls interface put in MOBM. SPR, monitor well. POOH with LEM assembly f/7566' to 207'. I RU and UD LEM assembly. i Clean Rig Floor. PU Baker tools to floor to handle 2 7/8" equiptment. MU Cleanout BHA: 4 11/16" x 3 518" Junk basket mill shoe, 3 5/8" Junk basket extension, 35/8" rev circ jet bushing, x-o , 14 jts 2 7/8" PAC drill pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o (6.25" OD). RIH f/465' to 7615' wI cleanout assembly on 5" DP. Tag up @ 7615'. ì PU wt 156k, SO wt 106k, Rot wt 130k. Drop ball. Circ @ 210 gpm wI 900 psi ball to activate rev circ junk basket Milling f/7615' to 7619' w/210 gpm @ 1050 psi. Rotate wI 50 rpm, torque 10-12k. Mill to 7649'. i RIH wI mill-no rotation f/7649' to 8071'. Circ @ 210 gpm wI 1000 psi. Pump Hi-vis sweep @ 320 gpm wI 2000 psi. SPR, Monitor well POOH slow f/8071' to 7503'. RIH f/7503', took wt @ 7617', push to 7627', PU to 7580', RIH tag @ 7627' , Rotate @ 50 rpm, 284 gpm wI 1650 psi. Milling f/7627' to 7635, slide fl 7635' to 7644', taking wt @ 7644', Rotate 7643' to 7646'. Torquing up @ 7646'. Pull f/7646' to 7500' (up above hook hanger), RIH f/7500' to 7645', taking wt @ 7645'. I Pull up above 7645', start pumping 80 spm wI 1650 psi, rotate 50 rpm, Mill on junk f/7644' to 7645', torqued up @ 7645', Pull up to 7640', free rotating, ran 7640' to 7648', taking a little wt @ 7648', PU, ran to 7712' Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 02:30 - 04:30 2.00 FISH CIRC CMPL T2 04:30 - 05: 15 0.75 FISH ¡TRIP CMPL T2 05:15 - 05:45 I 0.50 FISH TRIP CMPL T2 05:45 - 06:45 1.00 FISH TRIP CMPL T2 I 06:45 - 07:45 1.00 I FISH TRIP CMPL T2 07:45 - 09:30 1.75 FISH IC1RC CMPL T2 09:30-10:30 I 1.00 FISH ITRIP CMPL T2 10:30-11:15 0.75 FISH TRIP CMPL T2 11:15-12:00 0.751 FISH TRIP CMPL T2 , 112:00 - 15:45 3.75 FISH TRIP CMPL T2 ,15:45 - 16:15 0.50 FISH OTHR CMPL T2 116:15 - 18:30 2.25 FISH IPULD , CMPL T2 I ! 18:30 - 19:00 0.50 FISH OTHR CMPL T2 119:00 -19:30 0.50 FISH 10THR I CMPL T2 19:30 - 19:45 0.25 CMPL TN SFTY i CMPL T2 19:45 - 21 :00 1.25 CMPL TN PULD CMPL T2 I I 6/3/2005 21 :00 - 00:00 100:00 - 01 :30 3.00 CMPL TN TRIP I CMPL T2 1.50 CMPL TN TRIP . CMPL T2 I I 01 :30 - 02:45 ! 1.25 CMPL TN TRIP CMPL T2 02:45 - 04:15 ! I i 1.50 I CMPL TN TRIP CMPL T2 I I 2.00 CMPL TN TRIP CMPL T2 04:15 - 06:15 I without rotation. I Start rotating @ 7708' to 7729'. Slide fl 7729' wlo rotation to 7837', then took wt. PU and slide to 8010'. PU , slide f/8010; to 8052' taking a little extra wt @ 7977', slide to 8052'. PU, slide f/8052' -8078', Rotate fl 8078' to 8087, torquing @ 8087'. PU wt 165-170K, SO wt 112k. PU f/8087' to 8078'. Pump 30 bbl hi-vis sweep@ 89 spm (316 gpm) wI 2000 psi. Calc surf-surf 6219 strokes (526 bbls). Surf to mill 112 bbls. ¡ Pump total of 9532 strokes (806.4 bbls). Monitor well, POOH f/8087' to 7500'. RIH fl 7500' to 8030' POOH f/8030' to 7500'. Pull tight @ 7973',7-8 k over pull. Con't POOH to above hook hanger. I RIH f/7500' to 8089'. Slight bobble @ 7647'. · Pump hi vis sweep. Pumping @ 90 spm, 320 gpm, wI 2050 psi. POOH f/8060' to 7500'. PU wt 165k. Pull tight @ 7647', 12 k over, work pipe through, OK. RIH f/7500' to 8089'. Tag up @ 7648', work pipe, con't to 8089'. POOH f/8089' to 7823'. No problems. PU wt 170K, SO wt 114k while Ion bottom. Continue POOH wI Cleanout BHA: 4 11/16" x 3 518" Junk basket mill shoe, 35/8" Junk basket extension, 3 5/8" rev CÎrc jet bushing, x-o , 14 jts 2 7/8" PAC drill pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o (6.25" OD). · Clean rig floor. I RU Baker small tongs to lay down small BHA. UD 14 jts 2 7/8" DP, Break junk sub. Recovered over 1 Ib of steel junk fl 5.5" x 8.25" Weatherford spiralglider. Recovered some rubber fl Easy Solutions swell packer and ID metal fl swell packer. i Clear Baker small tools fl rig floor. Clean rig floor. RU and PJSM on running Lateral Entry Module. PUlMU LEM assembly: Baker4 3/4" Seal assembly, 4 1/2" 12.6 ppf IBT box X STL pin x-o jt(bent), (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppf L-80 IBT tubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf pup jt, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril 563 box x 5 1/2" hydril563 pin, Baker ZXP (7" hydril 563 pin), Baker I Hydraulic setting tool, Baker running tools. RIH w/ LEM assembly on 5" DP f/207' to 5499' RIH wI LEM assembly on 5" DP f/5499' to 7619'. Pu wt 170K, SO wt 110K. · RIH wI LEM assembly on 5" DP f/7619' to 7649' w/95k on wt I indicator.:: Took slight amount of wt @ 7635' (RS nipple), worked pipe, Run to 7647' (x-o bushing), set down 15K, worked pipe down to 7649' wI 95k on indicator. Saw some over pull to 195k when picked up (25k over). Work LEM down f/7649' to 7655' w/95k on indicator.:: Taking a little 'weight @ 7652', work down to 7655', then to 7655' w/95k on indicator. Picked up wI 170K. SO wt 111 k. PU f/7655' to 7500', rotate pipe 1/2 round, slack off, tag up @ 7647' (x-o bushing), work, then PU again, rotate 1/4 turn, Tag up again, PU to 7500', turn 1/4, slack off to 7655' wI 95k on indicator. Dragging to Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 08:30 - 12:00 12:00 - 13:30 113:30 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 17:45 ' 17:45 - 19:00 119:00 - 19:15 19:15-19:45 6/4/2005 i 19:45 - 00:00 ! 100:00 - 02:45 02:45 - 03:15 ì 03:15-04:30 ' 04:30 - 04:45 04:45 - 05:15 ! 05:15 - 06:00 06:00 - 06:45 106:45 - 07:30 07:30 - 09: 15 09:15 - 09:30 09:30 - 10:00 10:00 -11:30 11 :30 - 12:00 12:00 - 00:00 6/5/2005 00:00 - 02:45 i i 02:45 - 03:00 3.50 CMPL T] TRIP I CMPL T2 1.50 CMPL TN TRIP CMPL T2 2.00 CMPL TN PULD CMPL T2 0.50 I CMPL TN OTHR CMPL T2 1.00 WELCT EQRP CMPL T2 0.75 WELCTiBOPE CMPLT2 1.25 FISH RURD I CMPL T2 0.25 FISH SFTY CMPL T2 0.50 FISH PULD CMPL T2 4.25 FISH 2.75 FISH TRIP CMPL T2 TRIP CMPL T2 0.50 FISH 1.25 FISH OTHR I CMPL T2 PULD CMPL T2 0.25 I FISH ,TRIP CMPL T2 0.50 FISH CIRC CMPL T2 0.75 FISH TRIP CMPLT2 0.751 FISH TRIP CMPLT2 I ! 0.75 FISH TRIP CMPL T2 1.75 FISH CIRC CMPLT2 0.25 FISH 0.50 FISH OTHR CMPL T2 CIRC CMPL T2 1.50 FISH MILL CMPL T2 0.50 I FISH OTHR CMPL T2 12.00 FISH OTHR CMPL T2 2.75 FISH OTHR CMPL T2 0.25 FISH OTHR CMPL T2 185-190k wI PU, then free. Work pipe while circ @ 56 spm (199 gpm) wI 500 psi. PU wt 170k, SO iwt 106, set down 65k, no extra movement down. 7655' final depth 'reached wI mule shoe and 95k on wt indicator.. Monitor well, POOH fl 7655' to 4307'. PU wt 172k, SO wt 11 OK Continue POOH wI LEM assembly f/4307' to 207'. RU small tools and ready floor, Lay down 41/2" LEM assebly. I Clear and clean rig floor. II Change bottom pipe rams fl 5" to 2 7/8", RU to test rams. Test bottom pipe rams to 250 psi low and 3500 psi high. Chart test. RU to MU small tool string to clean out A2 liner. I PJSM on picking up small string to clean out liner. I MU 4 11/16" x 3 518" JB mill shoe, 3 5/8" junk basket extension, 3 5/8" rev circ jet bushing, x-o, x-o. PU/MU 198 jts 2 7/8" 6.4ppf, L-80, hydril 511 tubing. Con't PUlMU 198 jts 27/8" 6.4ppf, L-80, hydril511 tubing to 5823'. PU wt 57k, SO wt 45k I Drifted 2 7/8" wI 2" rabbit. Rig down tongs fl handling 2 7/8". RU to handle a jt of 31/2" dp. PUIMU Baker tools.:: double pin x-o, (2) boot baskets, bit sub, x-o, I Bowen bumper sub, Bowen super jar, x-o. SO wt 47k ì SLM, RIH 70' of first stand of 5" DP. [' Circ drill string volume plus a little (50 bbls). 61 spm = 1850 psi. Check out torque. 50 rpm 1 k torque. PU wt 60k, SO wt 48k, rot wt 53k. ! RIH wI clean out assembly on 5" dp. Taking a little weight @ 7650'. ¡Taking a little weight @ 7650'. Continue till through CSR (bottom @ 7669'), then again @ 7708'. PU wt 90k, SO wt 69K, slack off to as much as 60K. Screw into 5", establish rotation wI 2000 ftllb torque. Rot wt 79k. Continue RIH wI cleanout assembly on 5" DP f/7708' to 8080'. No problems RU to displace well fl MOBM to solids free oil base mud @ 8080'. Circ @ 55 spm (4.65 bpm) (195 gpm) wI 1800 psi. Check fl flow, OK. Drop 5/8" ball to activate rev basket jet. Pump ball down @ 60 spm (5 bpm) (213 gpm) wI 2050 psi. Mill fl 8093' to 8098'. PU wt 90k, SO wt 65k, Rot wt 83k, torque 2500-3000 ftllb. Pump 60 spm (5 bpm) (213 gpm) w/2100 psi. 50 rpm Continue w/4 11/16" mill and rev basket cleanout assembly f/8098' to 8189'. 8226' Continue wI 4 11/16" mill and rev basket cleanout assembly fl 8189' to 12050'. Tagging collars every +/-42'. PU wt 155k, SO wt 63k. Tag @ 8226', mill @ 8224', then slide to next collar 8268', then slide to 8562' then to 8718', slide 8718'-9028',9072' took wt, work past to '10214', work past, slide to 10345', worked past, slide to 10515', work past to 10645', work past, slide to 11200', hung up @ 11240', worked thru, slide to 11460'. Continue w/4 11/16" mill and rev basket clean out assembly f/12050' to 13155'. Pumping 60 spm (5 bpm) wI 2100-2400 psi. PU wt 190-195k, SO wt 82K Continue w/4 11/16" mill and rev basket clean out assembly f/13155' to 13341'. Pumping 60 spm (5 bpm) wI 2475 psi. PU wt 190-195k, SO wt Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 03:00 - 04:00 04:00 - 06:15 1.00 FISH 2.25 FISH CIRC ,CMPL T2 06:15 - 06:30 0.25 FISH OTHR CMPL T2 06:30 - 12:00 I 5.50 FISH TRIP CMPL T2 12:00 -12:15 ' 0.25 FISH TRIP CMPL T2 12:15 -13:00 0.75 FISH PULD CMPL T2 13:00 - 14:00 1.00 FISH RURD CMPL T2 14:00 -14:15 0.25 FISH SFTY CMPL T2 14:15 - 21 :15 7.00 FISH PULD CMPL T2 21:15-21:45 0.50 FISH PULD CMPL T2 '21 :45 - 22:30 0.75 FISH RURD CMPL T2 , 22:30 - 23:15 0.75 FISH OTHR CMPL T2 23:15 - 00:00 0.75 WELCT EQRP CMPL T2 6/6/2005 00:00 - 01 :30 1.50 WELCT BOPE CMPL T2 01 :30 - 02:00 0.50 WELCT~ BOP. CMPL T2 02:00 - 02: 15 0.25 CMPL TN RURD CMPL T2 02:15 - 02:30 0.25 CMPL TN SFTY CMPL T2 02:30 - 04:30 2.00 CMPL TN RUNT CMPL T2 04:30 - 04:45 04:45 - 10:00 10:00 -11:15 0.25 CMPL TN RURD CMPL T2 5.25 CMPL TN TRIP CMPL T2 1.25 CMPL TN PCKR CMPL T2 , 82K Rot wt 127k, torque 13-14k to rotate. Note: Insert bushing is @ 13247' in "S" lateral. Insert bushing in A2 is @ 13452') I SLM of 78 stands 2.35' longer. No correction I Approaching top of hook hanger wI upper mill (7.4" OD). Slack off 9.5', PU to 205K then free. Slack off while rotating, slight indication of top @ 8' in while rotating (13349.73'), rotate to 10' in (13251.73'). PU, start rotation again and slack off to 11' in (13352.73). PU wI 215k. Free up. Circ Hi-Vis sweep wI 4 11/16" mill @ 13350' (8' in on jt after stand 78). Therfore the 7.4" mill is @ 7521.65'. Calculated surf- surf 641.8 bbls (7586 strokes). Circ @ 60 spm (5 bpm) 213 gpm wI 2500 psi.. ANN velocity in 51/2" x 27/8" = 316 ftImin. 9 5/8" csg x 2 7/8" = 73 ftImin. 9 5/8" x 5" dp = 97 ftImin. PU wt 193k, SO wt 85k. Monitor well. OK. POOH wI clean out assembly f/13350' to 6355' Continue POOH wI cleanout assembly f/6355' to 5889'. UD 3 1/2" dp & Baker tools.:: double pin x-o, (2) boot baskets, bit sub, x-o, Bowen bumper sub, Bowen super jar, x-o. SO wt 47k 'I· RID 3 1/2" handling tools, RU to UD 2 7/8" tubing. PJSM on laying down 2 7/8" tubing. UD 198 jts of 27/8" 6.4 ppf L-BO Hydril511 tubing. ! Break and UD 4 11/16" x 3 518" JB mill shoe, 35/8" junk basket I extension, 3 5/8" rev circ jet bushing, x-o, x-o. Clean out junk basket. Recovered 18 pounds 3 oz of metal f/5 1/2" x 81/4" Weatherford spiralgliders. I RID tools fl handling 2 7/8". RID Doyon double stack tongs. Clean rig floor. Pull wear bushing, set test plug. Prepare to change rams fl 2 7/8" to 5" 'I in lower BOPE. Change lower rams fl 2 7/8" to 5". RU test equip. Test lower rams to ,250 psi I~w and 3500 psi high, 5 min each. Charted test. Called ì AOGCC Inspector Jeff Jones. \ Pull test plug, install Vetco Gray wear bushing, UD tools. RU to run Baker LEM. I PJSM on running Baker LEM assembly. I PUIMU LEM assembly: Baker4 3/4" Seal assembly, 41/2" 12.6 ppf 1ST box X STL pin x-o jt(bent), (2) joints 4 1/2" 12.6 ppf L-80 1ST tubing, I Cameo 4 1/2" DB nipple wI 3.563" ID profile, (1) jt 4 1/2" 12.6 ppf L-80 ·'IIBT tubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf pup jt, IBT casing swivel, X-O bushing 5 1/2" hydril563 box x 4 1/2" IBT pin, ,Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563 box x 5 1/2" hydril563 pin, Baker ZXP (7" hydril 563 pin), Baker Hydraulic setting tool, Baker running tools. RID equip. : RIH wI LEM assembly on 5" DP fl 207' to 7523' ( Fill pipe every 25 stds). Run assy through Hook Hanger to 7544' tag up bttm of window. PU and orient string 1/4 turn. RIH and only saw a few small bobbles on indicator. RIH to top of A2 ZXP @ 7619'. Up wt 189K, DN wt 105K. ¡Work seals and set LEM in place. Had good solid location on depth and showed 20K release from locator ring when PU. Top of LEM @ 7509' MD (end of seals @ 7662' MD) Seals buried 12.57' in CSB 19.48' long. Drop Ball and pump to seat - Set ZXP Packer - Pressure up to 2500 psi . and hold for 3-4 min. Work psi up to 4000 psi in 500 psi steps holding Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/612005 10:00-11:15 1.25 CMPL TN PCKR CMPL T2 each 3-4 min. Had no indication of packer set. Work wt from 50k DN , 205K up 11:15 -13:30 2.25 CMPL TN PCKR CMPL T2 Con't to attempt to set packer with pressure. Worked pressure from 2500 psi to 4000 psi 2 times without any sign of setting. Attempt to pressure up csg ann pumping down back side. Will not pressure up. Pumped 73 stks (6.2 bbls) 425psi. Worked pressure from 2500 psi to 4500 psi 3 times with no indication of packer setting. At this point we tryed to surge drill string. Pressuring up to 1000 psi and then release the pressure swiftly to surge the drill string. Afterword we attempted to I pressure up 2500 psi to 4500 psi again to set packer. No indication. We attempted to pressure up again on the csg ann. Will not test, Pumped ,65 stks (5.5 bbls) During all attempts worked wt from 50K DN wt, 205K IUPwt. 13:30 - 14:45 1.25 CMPL TN PCKR CMPL T2 After discussion with Baker Supv, Well Engineer and Rig Supv it was decided to safety off the ZXP with left had torq. The baker procedure on this tool is to work the wt from neutral point, torq string with left hand from 1/2 to 3/4 turn while working wt from 60K to 210K. 6 1/4 rounds of torque was worked down the string with no indication of a release. The LEM snap out up wt remained 220k and no sign of release was seen. 14:45 - 20:45 6.00 CMPL TN TRIP CMPL T2 Monitor well, POOH wI LEM assembly ( inspecting Lo-Tads on 5" dp, , cahnged out Lo-tad on stand #10, #8 & #6). Drill string started pulling dry @ 896'. Calc displ 71.4 bbls, actual 89.7 bbls. No LEM assembly on end of DP. Running tools only. 20:45 - 21:15 0.50 CMPL TN OTHR CMPL T2 Clean rig floor. 21:15-21:45 0.50 CMPL TN PULD CMPL T2 Break and lay down Baker running tool. 21:45 - 23:15 1.50 RIGMNT RSRV CMPL T2 Slip and cut drilling line. Service top drive. 23:15 - 00:00 0.75 RIGMNT RSRV CMPL T2 Recalibrate block height fl Sperry Sun MWD fl depth tracking. 6/7/2005 00:00 - 02:00 2.00 CMPL TN OTHR CMPL T2 Cleaned rig floor. Change out dies in rig tongs and on iron roughneck while waiting on running tool 02:00 - 02:15 0.25 FISH ,PULD CMPL T2 I MU Baker HRD liner running tool to retrieve LEM assembly. 02:15 - 03:45 1.50 FISH ¡TRIP CMPL T2 RIH wI Baker LEM retrieval tools on 5" DP f/20' to 2415'., fill pipe @ 25 stands (2415', PU wt 75k, SO wt 69K, circ @ 22 spm (78 gpm) wI 100 I psi.) 03:45 - 05:00 1.25 FISH [TRIP CMPL T2 Con't RIH wI Baker LEM retrieval tools on 5" DP f/2415' to 4829'., fill pipe @ 25 stands (4829', PU wt 110k, SO wt 74K, circ @ 22 spm (78 I gpm) wI 180 psi.) 05:00 - 06:30 1.50 FISH [TRIP CMPL T2 Con't RIH wI Baker LEM retrieval tools on 5" DP f/4829' to 6737'., mud started running over the top once started running HWDP (6360'), runs [TRIP over 10' above floor, PU wt 155k, SO wt 92K, 06:30 - 07:45 1.25 FISH CMPL T2 Con't RIH wI Baker LEM retrieval tools on 5" DP f/6737' t07386' and latched onto LEM, mud running over top 10' above floor, PU wt 189k, I I SO wt 105K, - Tag up solid at 7386' ( This point by calulation would be ,the coupling at the top of the seals ( 21' up from mule shoe) tagging out I at the 4.86" ID XO bushing 8.62' below bttm of window "B" Lat. 07:45 - 12:30 4.75 FISH ITRIP CMPL T2 POOH with fish from 7,386' to running tool at 210', st wt up wt 195K- 2.00 I FISH ,Appears to have additional weight to equal LEM assy, Pulling speed I ¡was kept slow to reduce swabbing. Hole took proper fill 12:30 - 14:30 ¡PULL CMPL T2 LD running tool and LEM, at surface it was seen the retreiving tool I ¡WOrked as designed, made full insertion and latched. No damage was I noted on the LEM assy only minor scoring. The seal assy did have . scoring around the packing stem and the seals had to be replaced. All I I I scoring marks were dressed with emery cloth to remove all sharp I edges. Remove all tools and clean OBM from rig floor. Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Remove old tools from shed and load in new ZXP packer, Finished 0.25 CMPL TN' SFTY installing new seals. 15:15 -15:30 CMPL T2 , Held PJSM with Baker rep on MU LEM assembly. 115:30 - 16:45 1.25 CMPL TN PULD CMPL T2 1 PU LEM assembly #2 with ZXP packer and RIH to 210' 16:45 - 21:30 4.75 CMPLTN TRIP CMPL T2 RIH with LEM assembly on 5" DP from 210' to 7,523' to hook hanger, st wt up 195K, dn wt 105K 21 :30 - 22:00 0.50 CMPL TN TRIP CMPL T2 I Oriented LEM and located hook hanger at 7,523' and landed same with ZXP packer top at 7,462', snapped in & out of hanger several times to I verify on depth and latching into hook hanger 22:00 - 23:00 1.00 CMPL TN¡ PCKR ,CMPL T2 I Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down , at 3.5 bpm at 380 psi, pressured up to 2,500 psi to set packer, then pressured up to 4,000 psi to release from setting tool, no problems setting packer 23:00 - 23:15 0.25 CMPL TN DEQT CMPL T2 Pressure tested ZXP packer and annulus to 1,000 psi for 5 min, good 1 test 23:15 - 23:30 0.25 CMPL TN PCKR CMPL T2 PU out of ZXP packer, then rotated DP while setting 75K st wt down on packer, rotated at 15 rpm's with 14K ft-Ibs torque with 128K rot wt 23:30 - 00:00 0.50 CMPL TN TRIP CMPL T2 ! Began POOH with running tool, POOH from 7,462' to 7,382' 6/8/2005 00:00 - 02:45 2.75 CMPLTN TRIP CMPL T2 I POOH with Baker LEM running tool from 7,382' to 20' '02:45 - 03:30 0.75 CMPL TN PULD CMPL T2 Made service breaks on running tool and LD same, cleared rig floor 03:30 - 03:45 0.251 WINDOWSFTY PROD3 ,Held PJSM with Baker Rep, Sperry Sun and crew on PU & MU of 5.25 WINDO+ULD I whipstock assembly 03:45 - 09:00 PROD3 MU Baker 9 5/8" btm trip whipstock assembly BHA #15 and RIH to I 1 ,580', MU seal assembly, locator sub, unloader sub, then PU 1-DP pup I I jt & 5 jts of 5" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD, I PU 9-6 3/4" Dc's and RIH to 580' 09:00 - 13:30 4.501 WINDO PROD3 : RIH with whipstock assembly from 580' to 6,850', RIH with 13 stds of 5" 1 HWDP above 6 3/4" Dc's 13:30 - 13:45 0.25, WINDO IRC PROD3 Made MADD pass from 6,850' to 6,885 (sensor depth 6,600'-6,635') and correlated MWD to K-13, circ at 450 gpm's at 2,100 psi 13:45 - 14:15 0.501 WINDO PROD3 1 RIH 'rom 6,885' to 7,145' 14:15 - 14:45 0.50 WINDO PROD3 Oriented whipstock 15 deg's left of high side and tagged top of LEM at \ 7,462', set whipstock and sheared off from same, top of whipstock at 17'258' MD/3,528' TVD, st wt up 200K, dn wt 83K, RIH with whipstock milling assembly with 3 stds 6 3/4" Dc's, 13 stds of 5" HWDP and 57 stds of 5" DP with Lo-tads 14:45 - 16:00 IRC PROD3 : Displaced hole over from 9.0 ppg SFMOBM to 9.05 ppg MOBM, circ at 568 gpm at 3,000 psi 16:00 - 21 :30 PROD3 Milled 8 1/2" window for "D" sand lateral from 7,258' to 7,274', cont to mill to 7,304' MD/3,539' TVD (46'), ADT 5.5 hrs, milled at 2-10K wob, 190-120 rpm's, 490 gpm at 2,350 psi, off btm torque 13K ft-Ibs, on btm 1.50 WINDol"RC 8-20K ft-Ibs, rot wt 118K, up wt 185K, dn wt 85K, (20' of gauge hole I below window for Geo-Pilot) last 2' took 15K wob to drill due to possible I concretion 21 :30 - 23:00 PROD3 Pumped 30 bbl weighted hi vis sweep and circ hole clean while working 0.25 WINDO~THR mills thru window, circ at 500 gpm at 2,400 psi, worked mills thru 1 window without pumping and window looks good. 23:00 - 23:15 PROD3 Monitored well-static, pumped dry job 23: 15 - 00:00 0.75 WIND!'P PROD3 POOH with whipstock milling assembly from 7,304' to 6,886' 6/9/2005 100:00 - 03:00 3.00 WINDO RIP PROD3 I POOH with whip'tod< mllll,. a""mb~ 'om 6,888' to ,,",', "ood bad< HWDP 03:00 - 03:45 0.75 WINDO ULD PROD3 POOH LD 9-6 3/4" Dc's from 380' to 104' I Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Downloaded MWD and LD same, cont. to POOH and LD Mills, upper 8 1/2" mill in gauge, cleared rig floor, note inspected saver sub while clearing rig floor and sub ck ok Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing I MU 8 1/2" BHA #16 and RIH to 105', MU bit #11 on Geo-pilot rotary system with Stratasteer LWD/MWD/PWD, uploaded MWD and shallow tested tool, held PJSM and loaded radioactive sources RIH to 105' RIH with BHA #16 from 104' to 7,231', RIH with flex Dc's, HWDP, jars and 5" DP, note ran 1 ghost reamer 1,042' back from bit and 2nd ghost reamer 2,533' back from bit. RIH from 7,231' to top of window at 7,258', washed down from 7,258' to 7,304', no problems going thru window, washed down at 500 gpm at 2,125 psi, rot wt 106K, up wt 150K, dn wt 80K Directionally drilled 8 1/2" hole in "D" sand lateral with Geo pilot rotary ¡steerable system from 7,304' to 8,235' MD/3,514' TVD (931') ADT 6.88 I hrs, from 7,304' to 7,808' drilled at 10-20K wob, 60-120 rpm's, 500 gpm, off btm pressure 2,200 psi, on btm 2,300 psi, from 7,808' drilled at 1 0-20K wob, 130 rpm's, 165 spm, 585 gpm, 2,900 psi, off btm torque 13K ft-Ibs, on btm 11 K ft-Ibs, rot wt 101 K, up wt 165K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 130 units, max gas 265 units. Drilled out of zone from 7,450' MD/3,563' TVD to 7,884' MD/3,549' TVD (434') 12.00 DRILL DRLG PROD3 Directionally drilled 8 1/2" hole in "D" sand lateral with Geo pilot rotary steerable system from 8,235' to 9,200' MD/3,486' TVD (965') ADT 7.75 I hrs, 5-20K wob, 130 rpm's, 170 spm, 600 gpm, 3,100 psi, off btm torque 14-15K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up wt 185K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 175 units, max gas 669 units. 12.00 I DRILL DRLG' PROD3 Directionally drilled 8 1/2" hole in "D" sand lateral from 9,200' to 9,625 MD/3,490' TVD (425') ADT 6.41 hrs, while drilling concretions would drill with 25-35K wob, 90 rpm's, 510 gpm at 2,300 psi, while drilling sand would drill at 5-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175 psi, off btm torque 15-17K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up Iwt 173K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120 'I units, max gas 487 units. 3.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral from 9,625' to 9,736 MDI 3487' TVD (111 ') ADT 2.36 hrs, while drilling concretions would ¡ drill with 20-35K wob, 80-90 rpm's, 510 gpm at 2,300 psi, while drilling ! sand would drill at 1 0-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175 psi, off btm torque 14-17K ft-Ibs, on btm 14K ftllbs, rot wt 105K, up wt 175K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120 units, max gas 345 units. After drlg thru concretion attempted to build I angle by adjusting rpm's and pump rates and was unable to get acceptable build rate, no oil light came on the Geo-Pilot tool at 00:35 hrs Monitored well-static, backreamed out of hole from 9,736' to 8,674' MD. 90 rpm's 90, 600 gpm at 3,000 psi and 14k ft-Ibs torque POOH on elevators from 8,674' to 7,518', had small tight spot @ 7615, pulled 20K over pull and wipe clean, hole taking proper fill, pulled 25-30K over at 7,518' and swabbed and packed off slightly Pumped out of hole from 7,518' to 7,231' and clean up balled stab's at i window, pumped out at 318 gpm at 1,100 psi. Assembly clean and 105:30 - 06:30 PROD3 I 06:30 - 10:15 3.75 DRILL PULD PROD3 10:15 - 13:45 3.50 DRILL TRIP PROD3 I I ¡ I I 13:45 - 14:15 0.50 DRILL REAM PROD3 , 14:15 - 00:00 ! 9.75 DRILL DRLG PROD3 i I 6/10/2005 00:00 - 12:00 I 12:00 - 00:00 ' 6/11/2005 i 00:00 - 03:00 I I ! 03:00 - 05:30 2.50 DRILL TRIP PROD3 05:30 - 07:15 1.75 DRILL TRIP PROD3 07:15 - 08:30 1.25 DRILL TRIP PROD3 Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 08:45 - 12:30 12:30 - 15:15 I 15:15 -15:30 15:30 - 21 :30 21 :30 - 21 :45 21 :45 - 00:00 6/12/2005 00:00 - 00: 15 00:15 - 03:45 i 03:45 - 05:00 05:00 - 05:15 05:15 - 07:00 07:00 - 08:45 08:45 - 12:00 12:00 - 00:00 I 6/13/2005 I i 00:00 - 02:45 02:45 - 04:00 3.75 DRILL TRIP PROD3 2.75' DRILL PULD PROD3 pulling good, hole taking proper fill. Monitored well above window and well was static, pumped dry job and I blow down Top drive. POOH from 7,231' to 381' Stood back HWDP, jars and flex Dc's, held PJSM and removed radioactive sources, downloaded MWD and LD BHA #16 and cleared rig floor, found seals to have gone out of Geo-Pilot tool. Calc hole fill 163.5 bbls, Actual fill 72.25 bbls i Pulled Wear bushing RU and tested valves, rams and manifold to 250 psi high, 3,500 psi low, tested annular to 250 psi low and 2,800 psi high, tested LEL & H2S alarms along with high flow and trip tank alarms, Note: Chuck Scheve with AOGCC waived witnessing of test Installed wear bushing MU 8 1/2" BHA #17 and RIH to 123', MU bit #12 on Geo-pilot rotary system with Stratasteer LWD/MWD/PWD, uploaded MWD and shallow tested tool breaking in bearings on Geo-pilot Held PJSM and loaded radioactive sources RIH with flex Dc's, HWDP and jars with BHA #17 from 123' to 7,039', While RIH began to take 10-15K dn weight at 7,060', PU to 7,039' I Slip and cut 71' of drlg line Washed down from 7,039' to 7,138', washed down at 500 gpm, 2,200 psi, st up wt 165K, dn wt 80K RIH from 7,138' to 9,260', no problems going thru window, while RIH at 19,260' string dn wt was down to 50K Precautionary washed and reamed down from 9,260' to btm at 9,736', initial circ rate 200 gpm at 700 psi and staged circ rate up to 500 gpm at 2,500 psi and 100 rpm's, no problems washing to btm Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 9,736' to 10,082' MD/3,483' TVD (346') ADT 1.9 hrs, 12-15K wob, 120 rpm's, 130 spm, 460 gpm, 2,250 psi, off btm torque 13K ft-Ibs, on btm 11-12K ft-Ibs, rot wt 103K, up wt 185K, dn wt 55K, 9.1 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max gas 285 units Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 10,082' to 11,435' MD/3,470' TVD (1,353') ADT 7.93 hrs, varied drilling perimeters in attempt to get Geo-pilot to steer due to soft sands and concretions, 1 0-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at 2,350 psi to 170 spm, 600 gpm at 3,550 psi, off btm torque 14-16K ft-Ibs, on btm 14-15K ft-Ibs, rot wt 104K, up wt 205K, dn wt 40K, 9.05 I ppg MOBM, ave ECD 11.5 ppg, ave BGG 150 units, max gas 1008 units, NOTE: Re-positioned camp on 1 E pad for Doyon 15 to move onto pad, camp off highline from 10:00 to 17:00 hrs Drilled 8 1/2" hole in "D" sand Lateral from 11,435' to 11,672' MDI 3,480' TVD (237') ADT 2.33 hrs, crossed fault at 11,334' MD/3,465' I TVD, anticipated throw 30', actual 20', while attempting to built angle I with no succes drilled down into "C" shale, Drilled into "C" shale at 11,625' MDI 3,488' TVD and drilled out of "C" back into "D" at 11,753' MD/3,477' TVD Backreamed out of hole slow while geologist evaluated log, began backreaming out at 600 gpm and at 11,650', #1 mud pump had a valve problem, cont to backream out to 11,358' at 355 gpm, 1,500 psi at 130 rpm's, circ a calc btms up, repaired valve on pump, found a piece of camlock rubber in valve I i 0.25 DRILL f PULD PROD3 6.00 I WELCl BOPE PR003 0.25 DRILL i PULD PROD3 2.25 DRILL PULD PROD3 I 0.251 DRILL PULD PROD3 3.50 DRILL TRIP i PROD3 I I 1.25 RIGMNTf RSRV PROD3 0.25 DRILL REAM PROD3 1.75 DRILL 1.75 DRILL I TRIP I PROD3 I REAM PROD3 I I 3.25' DRILL DRLG PROD3 I I 12.00 DRILL DRLG PROD3 2.75 DRILL DRLG PROD3 1.251 DRILL REAM I PROD3 Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/13/2005 04:00 - 04:45 0.75 DRILL REAM PROD3 Washed down from 11,385' to 11,672', washed down at 142 gpm at 500 psi due to little down wt and drag 04:45 - 12:00 7.25 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 11,672' to 12,094' MD/3,435' TVD (422') ADT 4.27 hrs, varied drilling perimeters in attempt to get Geo-pilot to build angle, while drilling in "C" shale was able to get adequate build rate, drilled with 10-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at 2,500 psi to 170 spm, 600 gpm at 3,600 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt 104K, up wt 180K, dn wt 50K, 9.0 ppg MOBM, ave ECD 11.6 ppg, ave BGG 150 units, max gas 670 units, 12:00 - 00:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 12,094' to 12,688' MD/3,420' TVD (416') ADT 5.77 hrs, drilled with 9-25K wob, 130 rpm's, 146 spm, 520 gpm at 2,800 psi to 170 spm, 600 gpm at 3,700 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt 109K, up wt 195K, dn wt 35K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 200 units, max gas 895 units, began PU 5" HWDP at 12,343' 6/14/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 12,688' to 13,530' MD/3,396' TVD (842') (T.D.) ADT 6.79 hrs, drilled with 10-25K wob, 90-130 rpm's, 166 spm, 590 gpm at 3,850 psi, off btm torque 18-20K ft-Ibs, on btm 20-22K ft-Ibs, rot wt 125K, up wt 230K, dn wt 35K, (Blk Wt) 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 200 units, max gas 1,065 units, Cont to PU HWDP to TD well, drilled thru numerous concretions, lost approx 73 bbls MOBM while drlg 12:00 - 12:15 0.25 DRILL OBSV PROD3 Monitored well-static 12:15 - 00:00 11.75 DRILL REAM PROD3 Backreamed out of hole from 13,530' to 7,775', BROOH at drlg rate at 130 rpm's, 586 gpm, ICP 3,900 psi, FCP 2,750 psi, rot wt 100K, up wt 180K, dn wt 78K, packed of while BROOH at 11,783', 11,575', 11,216', I 10,690' and 7,858', lost approx 88 bbls of 9.0 ppg MOBM while BROOH 6/15/2005 00:00 - 00:30 0.50 I DRILL REAM PROD3 Pumped 35 bbl weighted hi vis sweep and BROOH from 7,775' to 7,718', BROOH at 500gpm, 2,400 psi and 100 rpm's, had 30% increase in cuttings back from sweep rot wt 100K, up wt 180K, dn wt I 78K 00:30 - 04:00 3.50 LOG DLOG I PROD3 MADD pass for caliper log from 7,718' to 7,250', logged at 400 gpm, 1,400 psi and 50 rpm's, packed off at 7,560', 7,480' and 7,425' while logging out, POOH thru window to 7,138' with no problems in window 04:00 - 06:00 2.00 DRILL CIRC PROD3 Circ hole clean above window at 7,138', circ at 620 gpm, 2,800 psi, 130 rpm's with 1 0-12K ft-Ibs torque, circ 4X btms up and clean at shakers, had a large amount of shale back at btms up 06:00 - 07:00 1.00 RIGMNT RGRP PROD3 Repaired hyd. leak on filter housing on top drive 07:00 - 07:30 0.50 RIGMNT RSRV PROD3 Serviced top drive and drawworks 07:30 - 11 :30 4.00 DRILL TRIP PROD3 RIH from 7,138' to 13,530', no problems RIH and going thru window, I PROD3 changed out 3 Lo-tads while RIH 11 :30 - 13:30 2.00 DRILL CIRC Pumped 35 bbl weighted hi vis sweep and circ 2 1/2X btms up and was i clean at shakers, saw no increase in cuttings back from sweep, circ at 160 spm, 568 gpm, 3,925 psi, 100 rpms with 17-18K ft-Ibs torque 13:30 - 14:45 1.25 DRILL CIRC PROD3 Displace hole over from 9.0 ppg MOBM to 9.1 ppg SFMOBM, initial circ rate 568 gpm at 3,925 psi, final circ rate 547 gpm at 3,925 psi at 130 rpm's, rot wt 125K, up wt 225K, dn wt 55K 14:45 - 15:00 0.25 DRILL OBSV PROD3 Monitored well-static, obtained SPR's 15:00 -19:15 4.25 DRILL TRIP PROD3 POOH on elevators from 13,530' to 7,230', no problems in open hole or pulling thru window 19:15 - 19:30 0.25 DRILL OBSV PROD3 Monitored well at window, well-static, dropped 2" rabbit 19:30 - 22:15 2.75¡ DRILL TRIP PROD3 POOH from 7,230' to BHA at 385' Printed: 7/6/2005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/15/2005 22:15 - 00:00 1.75 DRILL PULD PROD3 POOH LD 5 jts HWDP and jars, LD 2-NM Flex Dc's, held PJSM and removed radioactive sources, plugged into MWD and began downloading MWD, POOH to 139', calc fill on trip out 114 bbls, actual fill 140 bbls 6/16/2005 00:00 - 02:15 2.25 DRILL PULD PROD3 Fin downloading MWD and LD remaining BHA #17, MWD and I I RURD CMPL T3 Geo-pilot, cleared rig floor 02:15 - 02:45 0.50 CASE I RU Doyon's liner running equipment and held PJSM with rig crew and I i i tong operator 02:45 - 07:15 I 4.50 I CASE PULR CMPL T3 PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner with torque rings per I well program to 6,068' (144 Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 71 jts (3,034') of 5 1/2" 15.5#, L-80, BTCM blank liner, ran 73 jts (3,075') of 5 1/2", 15.5# L-80 BTCM slotted liner, ran 141 - 51/2" x7 5/8" x 8" aluminum solid body centralizers 1/jt #2 thru #143, ran 16 constrictor packers placed on blank liner to cover ,shale sections. 107:15 - 07:45 0.50 CASE PULR CMPL T3 i PU 1jt of 7" 26#, L-80 BTC liner then MU Baker 7" HR liner setting I I I i sleeve, RIH to 6,178', liner up wt 95K, dn wt 65K 07:45 - 08:151 0.50 I CASE RURD CMPL T3 RD Doyon's liner running equipment 08:15 - 13:15 5.00 CASE RUNL CMPL T3 RIH with 5 1/2" liner on 5" DP from 6,178' and tagged btm at 13,536' DP measurement, no problems RIH, took liner weights & torque readings at 6,640' and above window at 7,223'. At 6,640' liner wt up 103K, dn wt 68K, rot wt 82k, at 10 rpm's had 4K ft-Ibs torque and at 20 rpm's had 4,500 ft-Ibs torque. At 7,223' liner up wt 115K, dn wt 75K, rot wt 89K, at 10 rpm's had 5K ft-Ibs torque and at 20 rpm's had 4-6K ft-Ibs torque. Liner wt on btm, up wt 215K, dn wt 70K, with torque limiter set at 14,500 ft-Ibs was unable to rotate liner, calc liner displacement 87 bbls, actual 64 bbls, Ran liner with 5 stds slick 5" DP, 60 stds 5" DP : with Lo-tads and 10 stds of HWDP 13:15 - 15:00 1.75 CASE IRUNL CMPL T3 ¡Dropped 1 1/2" ball and pumped down to seat, pumped down at 4 bpm at 600 psi then slowed to 1 bpm, with ball on seat pressured up to 3,000 psi to release running tool, then pressured up to 3,900 psi and blew ball seat, PU and st wt up was 175K, dn wt 105K, stood back 1 std with setting tool at 7,268', top of HR setting tool landed at 7,370.87' 15:00-16:15 1.25 CASE CIRC I CMPL T3 1 Circ btms up at 7,268', circ across whipstock face while circ btms up, I ! circ at 70 spm, 250 gpm at 500 psi, 9.15 ppg SFMOBM in and out 16:15 -16:30 0.25 CASE OTHR CMPL T3 ' Monitored well-static 16:30 - 20:00 ! 3.50, DRILL TRIP CMPL T3 POOH from 7,268' and LD Baker running tool, cleared rig floor, calc fill I on trip out 69 bbls, actual 75 bbls 20:00-21:15 1.25 RIGMNT RSRV CMPL T3 Slip and cut 79' of drlg line and serviced top drive 21:15 - 21:45 0.50 FISH PULD I CMPL T3 i Held PJSM and MU fishing BHA #18, MU Baker retrieving hook, 1 jt 5" i HWDP, float sub, bumper and oil jars RIH to 61' 21 :45 - 00:00 2.25 FISH TRIP CMPL T3 iRIH with fishing BHA#18 from 61' to 4,466' 6/17/2005 00:00 - 00:45 0.75 FISH TRIP CMPL T3 RIH with whipstock retrieving BHA #18 from 4,496' to 7,237' st up wt I 175K, dn wt 105K 00:45 - 01 :30 0.751 FISH FISH CMPL T3 Hooked whipstock at 7,263 on 3rd attempt. Worked whipstock pulling 1 OOK over with no movement, Pulled to 125k over st wt and hit jars, after 2nd hit pulled 330K st wt and whipstock came free, PU and stood ! back std, had 222K drag up wt, after standing back std string wt dropped to 179K 01 :30 - 02:30 ! 1.00 I FISH CIRC CMPL T3 Circ btms up at 7,230', circ at 420 gpm, 1,375 psi, max gas 60 units at I btms up 02:30 _ 07:30 i 5.00 I FISH TRIP CMPL T3 POOH slow with whipstock from 7,263' to BHA at 60' 107:30 - 09:30 2.00 FISH PULD CMPL T3 POOH and LD bumper jars, oil jars, whipstock, 1-5', 5 jts 5" DP and I Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 107:30 - 09:30 109:30 - 10:00 I 0.50 CASE RURD CMPL T3 10:00 - 10:15 0.25 CASE SFTY CMPL T3 I 10:15-11:30 1.25 CASE PULR i CMPL T3 11 :30 - 17:00 5.50 CASE RUNL CMPL T3 17:00 - 18:45 1.75 CASE OTHR CMPL T3 18:45 - 20:00 1 .25 CASE OTHR CMPL T3 I i I 20:00 - 21:15 1.25 CASE CIRC CMPL T3 i i 21:15 - 22:30 1.25 CASE 'OTHR CMPL T3 22:30 - 23:15 6/18/2005 23: 15 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 03:00 103:00 - 03:30 103:30 - 03:45 03:45 - 05:00 05:00 - 10:00 10:00 - 10:15 10:15-11:00 11:00 -11:15 11:15 -12:15 0.75 CASE CIRC CMPL T3 I I 0.25 CASE 'OTHR CMPL T3 0.50 CASE RUNL CMPL T3 2.00 CASE RUNL CMPL T3 1.00 CASE OTHR CMPL T3 0.50 CMPL TN RURD i CMPL T3 0.25 CMPL TN SFTY i CMPL T3 1.25 CMPL TN, PULD CMPL T3 5.00 CMPL TNi TRIP CMPL T3 I 0.25 CMPL TN TRIP CMPL T3 I , I 1 0.75 CMPLTN CIRC 'CMPLT3 I 0.25 CMPL TN' DEOT CMPL T3 1.00 CMPL TN CIRC CMPL T3 seal assembly, cleared rig floor, calc fill on trip out 64 bbls, actual 77 bbls RU Doyon's liner running equipment Held PJSM with rig crew and tong operator on running of PU and running of hook hanger with ECP pkr MU "D" lateral hook hanger assembly with ECP Pkr RIH to 162', MU 5 1/2" bent jt, 1-6' pup jt, 1-jt of 5 1/2" 15.5#, L-80 IBTM blank liner, ECP, 11-6' pup jt and hook hanger assembly i RIH with hook hanger assembly from 162' to top of window at 7,258', st ¡wt up 175K, dn wt 106K ¡WOrked bent jt thru window after 4th attempt, RIH and tagged XO in HR setting sleeve at 7,425', did not see ECP Pkr go thru window, st wt up 185K, dn wt 104K Oriented hanger to btm of window, after 6 attempts hooked hanger. PU and unhooked hanger, worked hanger by turning pipe 1/4 turn, rehooked and unhooked hanger 6 times while turning hanger to verify btm of window, btm of window @ 7,275.31. Top of Baker hook hanger @ 7,254.41' with 5 1/2" bentjt at 7,416', spaced out 9' above 7" x 51/2" XO at 7, 425', Set 30K wt down on hook Dropped 29/32" ball and pumped down to seat, pumped at 4 bpm, 525 i psi and slowed to 1 bpm at 200 psi, with ball on seat at calc strokes, I pressured up to 500 psi then bled off Turned over to Dowell, pressure tested lines to 3,500 psi, then pressured up on ECP Pkr to 2,200 psi, bled off, pressured back up to 2,500 psi and didn't see valve shear, cont to slowly increase pressure up to 3,800 psi, bled off, pressured up to 4,300 psi and blew ball seat. PU out of assembly to 7,144'. NOTE: Looking at Dowell chart it appears valve may have opened at 1,555 psi and closed at 2,000 psi taking 0.8 bbls to pressure up and set packer Circ btms up at 7,144', circ at 295 gpm at 650 psi, no gas at btms up, st wt up 170K, dn wt 102K Monitored well-static POOH with hook hanger running tool from 7,144' to 6,328' POOH with hook hanger assembly running tool from 6,328' to 70' POOH LD running tool and cleared rig floor, calc fill on trip out 65 bbls, actual fill 73 bbls RU Doyon's tubing handling equipment Held PJSM with rig crew on running of LEM MU "D" sand LEM assembly with ZXP packer and RIH to 312' RIH with LEM from 312' to 7,250' to above hook hanger, st wt up 173K, dn wt 103K Oriented LEM and located hook hanger at 7,254' and landed same with ZXP packer top at 7,191' and end of seals at 7,493', snapped in & out of hanger 1 time to verify on depth and latching into hook hanger, Rehook and pull test 10K over to verify possitive hook, Set down 30K wt. on hook assembly. Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down at 4 bpm at 350 psi, pressured up to 2,500 psi to set packer, then pressured up to 3,900 psi to release from setting tool, no problems setting packer Tested ZXP packer and annulus to 1,000 psi for 5 min, good test PU out of ZXP packer and set back down with dog sub to verify packer setting depth and circ btms up, circ at 285 gpm at 675 psi Printed: 7/612005 3:50:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/18/2005 12:15 - 12:30 0.25 CMPL TN OBSV CMPL T3 Monitored well-static 12:30 - 15:00 2.50 CMPL TN TRIP CMPL T3 POOH with LEM running tool from 7,191' to 45' 15:00 - 15:45 0.75 CMPLTN PULD ¡CMPLT3 I POOH LD LEM running tool 15:45 - 16:00 0.25 CMPL TN PULL CMPL T3 I Pulled wear bushing 16:00 - 16:30 0.50 CMPL TN RURD CMPL T3 RU Doyon's tbg handling equipment and held PJSM 16:30 - 22:00 5.50 CMPL TN RUNT CMPL T3 I Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,217', RIH and tagged no-go at 7,217' tbg measurement, ran a total of 230 jts, 1.00 I CMPL TN¡ RUNT 7,106' of 41/2" tbg 22:00 - 23:00 CMPL T3 I Spaced out completion string, MU Vetco Gray tbg hanger and landed tbg at 7,229', RILDS, landed tbg with open CMU sliding sleeve at 17,164" btm GLM at 6,713', upper GLM at 4,217' and DB-6 nipple at 504', st wt up 95K, down wt 57K, tested hanger seals to 5,000 psi for 15 I min, good test, installed TWC 23:00 - 00:00 1.00 CMPL TN RURD CMPL T3 RD Doyon's tbg handling equipment and landing jt, cleared rig floor 6/19/2005 00:00 - 02:30 2.50 WELCT NUND CMPL T3 I ND BOP's, began to set back when one of the bridge crane's wouldn't ¡work 02:30 - 06:30 4.00 DRILL PULD CMPL T3 LD 144 jts of 5" DP from derrick while repairing bridge crane 06:30 - 08:30 2.00 WELCT NUND I CMPL T3 I Set back BOP's and NU Vetco Gray 13 5/8" x 4 1/8" 5M Tree 08:30 - 09:30 1.00 WELCT OTHR . CMPL T3 Tested tree to 500 psi low then to 5,000 psi high for 15 min, good test, ",. I pulled TWC 109:30 - 16:45 7.25 DRILL PULD CMPL T3 Cont to LD DP from the derrick, LD 132 jts of 5" DP, 39 jts of 5" HWDP [and 44 Lo-Tads, Sim-Ops: held PJSM and RU little Red, displaced hole over from 9.1 ppg SFMOBM to diesel thru choke manifold and open I CMU sliding sleeve at 7,164', RU scaffolding over well 16:45 - 18:00 1.25 WELCT EQRP CMPL T3 RU lubricator and installed BPV, RD lubricator and secured well, RD I scaffolding and began cleaning out SFMOBM in pits, SITP 400 psi, IA 400 psi, OA 160 psi 18:00 - 22:15 4.25 DRILL PULD CMPL T3 ! Fin LD DP from the derrick, LD 123 jts of 5" DP and 16 Lo- Tads, LD a total of 408 jts of 5" DP, 39 jts HWDP and 60 Lo-Tads, RD mousehole [22:15 - 00:00 1.75 DRILL OTHR CMPL T3 Cont to clean mud pits, Sim-Op: Slip and cut 52' of drlg line, rig off highline at 22:15 hrs 6/20/2005 ·00:00 - 01 :30 1.50 DRILL OTHR CMPL T3 Fin. cleaning mud pits and rock washer, Sim-Ops: changed out 4 1/2" IF saver sub on top drive. RELEASED RIG @ 01 :30 Hrs 6/20105 Printed: 7/6/2005 3:50:05 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1E-105L1 . Job No. AK-ZZ-0003677560, Surveyed: 27 May, 2005 Survey Report 30 June, 2005 " Your Ref: API 500292324360 Surface Coordinates: 5959980.60 N, 550300.48 E (700 18' 05.1619" N, 149035' 33.3322" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 959980.60 N, 50300.48 E (Grid) Surface Coordinates relative to Structure: 217.60 N, 412.44 E (True) Kelly Bushing Elevation: 93.58ft above Mean Sea Level Kelly Bushing Elevation: 93.58ft above Project V Reference Kelly Bushing Elevation: 93. 58ft above Structure 5pe..........y-&ul! DRILLING seRVices A Hallibut1Øn Company Survey Ref: svy2150 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105L 1 Your Ref: API 500292324360 Job No. AK-ZZ-0003677560, Surveyed: 27 May, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 7458.74 79.870 175.720 3477.52 3571.10 947.20 S 5154.19E 5959067.93 N 555460.90 E 947.20 Tie-On Point ,.. 7524.00 79.060 175.280 3489.45 3583.03 .. 1011.16 S 5159.22 E 5959004.00 N 555466.36 E 1.407 1011.16 Window Point 7590.21 85.060 176.970 3498.59 3592.17 1076.55 S 5163.65 E 5958938.64 N 555471.22 E 9.408 1076.55 7685.15 84.750 179.400 3507.03 3600.61 1171.06 S 5166.64 E 5958844.15 N 555474.84 E 2.570 1171.06 7780.29 85.500 181.830 3515.11 3608.69 1265.84 S 5165.62 E 5958749.37 N 555474.46 E 2.664 1265.84 7876.84 88.730 181.740 3519.97 3613.55 1362.21 S 5162.62 E 5958652.98 N 555472.10 E 3.347 1362.21 . 7973.47 92.690 181.310 3518.77 3612.35 1458.78 S 5160.05 E 5958556.40 N 555470.18 E 4.122 1458.78 8072.31 95.770 181.260 3511.48 3605.06 1557.31 S 5157.84 E 5958457.85 N 555468.63 E 3.117 1557.31 8166.01 98.070 180.880 3500.20 3593.78 1650.31 S 5156.10E 5958364.85 N 555467.51 E 2.487 1650.31 8260.50 97.000 179.070 3487.80 3581.38 1743.98 S 5156.14 E 5958271.18 N 555468.18 E 2.211 1743.98 8356.44 94.140 179.170 3478.49 3572.07 1839.44 S 5157.61 E 5958175.73 N 555470.29 E 2.983 1839.44 8451.43 91.850 179.170 3473.53 3567.11 1934.29 S 5158.98 E 5958080.89 N 555472.30 E 2.411 1934.29 8548.70 92.300 178.260 3470.01 3563.59 2031.47 S 5161.16 E 5957983.73 N 555475.13 E 1.043 2031.47 8646.90 92.670 176.890 3465.75 3559.33 2129.49 S 5165.31 E 5957885.74 N 555479.93 E 1.444 2129.49 8743.33 91.800 175.940 3461.99 3555.57 2225.65 S 5171.34 E 5957789.62 N 555486.60 E 1.335 2225.65 8837.18 92.610 176.990 3458.38 3551.96 2319.25 S 5177.12 E 5957696.06 N 555493.01 E 1.412 2319.25 8936.93 90.560 176.460 3455.62 3549.20 2418.79 S 5182.82 E 5957596.56 N 555499.37 E 2.123 2418.79 9034.17 90.130 176.540 3455.03 3548.61 2515.85 S 5188.75 E 5957499.54 N 555505.96 E 0.450 2515.85 9127.48 89.820 177.470 3455.07 3548.65 2609.03 S 5193.63 E 5957406.39 N 555511.46 E 1.051 2609.03 9225.71 91.190 179.260 3454.21 3547.79 2707.21 S 5196.43 E 5957308.24 N 555514.92 E 2.295 2707.21 9322.15 93.610 179.990 3450.17 3543.75 2803.56 S 5197.06 E 5957211.90 N 555516.19 E 2.621 2803.56 9419.61 92.170 180.090 3445.26 3538.84 2900.89 S 5197.00 E 5957114.56 N 555516.78 E 1.481 2900.89 . 9514.61 92.300 180.200 3441.55 3535.13 2995.82 S 5196.75 E 5957019.64 N 555517.17 E 0.179 2995.82 9611.02 91.430 179.840 3438.41 3531.99 3092.18 S 5196.72 E 5956923.28 N 555517.79 E 0.977 3092.18 9708.07 91.310 179.680 3436.09 3529.67 3189.20 S 5197.13 E 5956826.27 N 555518.84 E 0.206 3189.20 9804.53 91.320 180.000 3433.88 3527.46 3285.63 S 5197.40 E 5956729.84 N 555519.76 E 0.332 3285.63 9901.54 90.750 179.620 3432.13 3525.71 3382.63 S 5197.72 E 5956632.85 N 555520.73 E 0.706 3382.63 10000.77 90.260 180.170 3431.25 3524.83 3481.85 S 5197.90 E 5956533.62 N 555521.57 E 0.742 3481.85 10094.78 90.200 179.730 3430.88 3524.46 3575.86 S 5197.98 E 5956439.62 N 555522.28 E 0.472 3575.86 10191.19 91.440 181.070 3429.50 3523.08 3672.25 S 5197.31 E 5956343.22 N 555522.26 E 1.894 3672.25 10287.77 92.050 180.980 3426.56 3520.14 3768.77 S 5195.58 E 5956246.69 N 555521.18 E 0.638 3768.77 10383.95 91.370 180.030 3423.69 3517.27 3864.90 S 5194.74 E 5956150.56 N 555520.97 E 1.214 3864.90 10480.50 90.750 180.130 3421.90 3515.48 3961.44 S 5194.60 E 5956054.03 N 555521.48 E 0.650 3961.44 10579.28 90.570 180.300 3420.76 3514.34 4060.21 S 5194.23 E 5955955.25 N 555521.77 E 0.251 4060.21 10674.11 90.690 179.880 3419.72 3513.30 4155.03 S 5194.08 E 5955860.43 N 555522.26 E 0.461 4155.03 30 June, 2005 - 14:37 Page 2 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E -1E-105L1 Your Ref: API 500292324360 Job No. AK-ZZ-0003677560, Surveyed: 27 May, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 DDft) 10771.47 90.690 180.190 3418.55 3512.13 4252.39 S 5194.02 E 5955763.08 N 555522.85 E 0.318 4252.39 10869.69 90.630 180.630 3417.41 3510.99 4350.60 S 5193.32 E 5955664.87 N 555522.81 E 0.452 4350.60 10964.12 87.030 180.540 3419.34 3512.92 4444.99 S 5192.36 E 5955570.47 N 555522.48 E 3.814 4444.99 11060.11 84.930 181.550 3426.07 3519.65 4540.72 S 5190.61 E 5955474.73 N 555521.37 E 2.426 4540.72 11159.33 85.750 181.590 3434.13 3527.71 4639.57 S 5187.90 E 5955375.86 N 555519.32 E 0.827 4639.57 11254.44 86.810 180.870 3440.30 3533.88 4734.46 S 5185.86 E 5955280.96 N 555517.92 E 1.346 4734.46 . 11347.83 88.040 181.220 3444.50 3538.08 4827.74 S 5184.16E 5955187.68 N 555516.84 E 1.369 4827.74 11448.89 89.710 181.890 3446.48 3540.06 4928.74 S 5181.42E 5955086.66 N 555514.78 E 1.780 4928.74 11543.79 92.430 182.360 3444.71 3538.29 5023.54 S 5177.90 E 5954991.83 N 555511.90 E 2.909 5023.54 11640.72 94.660 182.480 3438.72 3532.30 5120.20 S 5173.82 E 5954895.15 N 555508.46 E 2.304 5120.20 11738.76 95.950 181.070 3429.65 3523.23 5217.77 S 5170.79 E 5954797.57 N 555506.09 E 1.945 5217.77 11834.17 94.890 180.370 3420.64 3514.22 5312.74 S 5169.60 E 5954702.59 N 555505.53 E 1.330 5312.74 11929.69 93.400 179.690 3413.74 3507.32 5408.01 S 5169.55 E 5954607.32 N 555506.12 E 1.714 5408.01 12028.57 91.850 180.260 3409.21 3502.79 5506.78 S 5169.59 E 5954508.55 N 555506.82 E 1.670 5506.78 12124.79 90.240 179.710 3407.45 3501.03 5602.98 S 5169.62 E 5954412.35 N 555507.49 E 1.768 5602.98 12219.99 88.780 179.460 3408.27 3501.85 5698.17 S 5170.31 E 5954317.17 N 555508.82 E 1.556 5698.17 12316.13 90.030 180.040 3409.27 3502.85 5794.30 S 5170.73 E 5954221.04 N 555509.88 E 1.433 5794.30 12410.47 90.330 178.610 3408.97 3502.55 5888.63 S 5171.84 E 5954126.72 N 555511.62 E 1.549 5888.63 12503.58 90.930 179.140 3407.95 3501.53 5981.72 S 5173.67 E 5954033.65 N 555514.08 E 0.860 5981.72 12603.25 92.120 180.040 3405.29 3498.87 6081.35 S 5174.38 E 5953934.03 N 555515.46 E 1.497 6081.35 12696.26 93.670 180.780 3400.60 3494.18 6174.23 S 5173.72 E 5953841.14 N 555515.41 E 1.846 6174.23 12790.21 94.280 181.110 3394.08 3487.66 6267.94 S 5172.17 E 5953747.42 N 555514.49 E 0.738 6267.94 . 12885.14 92.410 179.760 3388.54 3482.12 6362.70 S 5171.45E 5953652.66 N 555514.41 E 2.428 6362.70 12979.85 91.250 180.240 3385.52 3479.10 6457.36 S 5171.45E 5953558.00 N 555515.04 E 1.325 6457.36 Inc & Trend 13076.83 89.870 180.240 3384.57 3478.15 6554.33 S 5171.05E 5953461.03 N 555515.29 E 1.423 6554.33 13172.72 90.310 180.240 3384.42 3478.00 6650.22 S 5170.64 E 5953365.14 N 555515.53 E 0.459 6650.22 13262.81 90.400 180.240 3383.86 3477.44 6740.31 S 5170.27 E 5953275.05 N 555515.75 E 0.100 6740.31 13342.76 89.080 180.240 3384.23 3477.81 6820.26 S 5169.93 E 5953195.10 N 555515.95 E 1.651 6820.26 13424.51 89.260 180.240 3385.41 3478.99 6902.00 S 5169.59 E 5953113.36 N 555516.16 E 0.220 6902.00 13497.12 90.050 180.240 3385.85 3479.43 6974.61 S 5169.28 E 5953040.76 N 555516.34 E 1.088 6974.61 ~ 13529.00 90.050 180.240 3385.82 3479.40 - 7006.49 S 5169.15 E 5953008.88 N - 555516.42 E ~ 0.000 7006.49 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). 30 June, 2005 - 14:37 Page 3 of4 DrillQuest 3.03.06.008 Western North Slope Halliburton Sperry-Sun Survey Report for Kuparuk 1E -1E-105L1 Your Ref: API 500292324360 Job No. AK-ZZ-0003677560, Surveyed: 27 May, 2005 ConocoPhillips Vertical Section is from Well and calculated along an Azimuth of 180.000· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13529.00ft., The Bottom Hole Displacement is 8706.95ft., in the Direction of 143.581· (True). Comments Measured Depth (ft) 7458.74 7524.00 13529.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 3571.10 3583.03 3479.40 947.20 S 1011.16 S 7006.49 S 5154.19E 5159.22 E 5169.15 E Tie-On Point Window Point Projected Survey Survev tool øroaram for 1 E-1 05L 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 722.00 12979.85 0.00 719.95 3479.10 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 722.00 12979.85 13529.00 CB-SS-Gyro (1E-105PB1) MWD+IIFR+MS+SAG (1E-105PB1) Inc & Trend (1 E-105L 1) 719.95 3479.10 3479.40 . 30 June, 2005 - 14:37 Page 4 of4 DrillQuest 3.03.06.008 . . 15-Jul-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-1 05 L 1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,458.74' MD 7,524.00' MD 13,529.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date '2(:, ~Ui1 Signed 1JwJ.. CJIlJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) J. O>'~ O~ ì pl . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well 1 E-1 05 L 1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,458.74' MD 7,524.00' MD 13,529.00' MD (if applicable) 15-Jul-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /?j I /1// Date :> () ~~ r Signed jjttmvJ... udvJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ D J - 0 ~ 7 F:/-t.. ~_.....,.. ( . . FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL AlVD GAS CONSERVATION COMMISSION 333 W. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IE-105LI ConocoPhillips Alaska, Inc. Permit No: 205-007 Surface Location: 391' FSL, 224' FEL, SEC. 16, TIIN, RlOE, UM Bottomhole Location: 1338' FNL, 345' FEL, SEC. 27, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU lE-105, Permit No. 205-006, API 50-029-23243-00. Production should continue to be reported as a function of the original API number stated above. In your application it was stated that the original wellbore and the subsequent multi-lateral well bores would be pre-produced and then converted to injection service after a minimum of 30 days production. Regulation 20 AAC 25.402(c)(l5) requires determination of the mechanical condition of any well penetrating the injection zone within a one-quarter mile radius of a proposed injection well. In the case of IE-I05, there are a number of West Sak wells and at least one Kuparuk well within one-quarter mile ofthe proposed trajectory. As currently planned, lE-105 and the subsequent multi-lateral wellbores are designed to meet the requirements for injection wells as specified in 20 AAC 25.412. However, prior to converting lE-105 and the multi-laterals to injection service CPAI must provide information sufficient for the Commission to determine that all of the surrounding wells were satisfactorily cemented to confine any fluids within the West Sak sands. This permit to drill does not exempt you from obtaining additional permits or approvals 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. PI e provide at least twenty-four (24) hours notice for a representative of the Commission wit ess any required test. Contact the Commission's petroleum field inspector a 59 601 ager). I BY ORDER ~THE COMMISSION DATED this£ day of February, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Revision to lE-105 Pennit to Drill package. . . Hi Tom - Please find attached a revision to the proposed drilling program for lE-105. The revision includes the steps to be done after the intermediate hole section is cased and cemented, so that the rig can be released for the exploration work in mid-February. As I mentioned on the phone our plan is to case and cement the intermediate hole section of lE-105, move Rig 141 to NPRA for exploration work, move back to IE pad in late April, drill and complete lE-117, and then move back onto lE-105 to complete the remaining drilling operations. Additionally I have include the steps we will take with regard to lE-105PBl, a well bore we will drill and abandon in order to gain geologic information in order to better geo-steer the lE-105 well bore. With regard to the Area of Review for the nearby wells, we will complete this review and send the AOGCC the required information in the near future. My conclusion from our recent conversation is that the AOGCC will issue Permits to Drill for lE-105, lE-105Ll, and lE-105L2 (assuming all other issues have been adequately addressed and resolved) without the Area of Review being completed. However such Permits to Drill would have a stipulation that the well could not be operated as an injector until the integrity of nearby wells was verified. If my conclusion is incorrect and we need to provide some more information before the Permits to Drill can be issued, please let me know ASAP. «1E-105 Drilling Program Revision.pdf» Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve.mckeever@conocophillps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "The short fortune-teller who escaped from prison was a small medium at large." C t t D . t· . lE-105 Drilling Program on en - escnp IOn. R .. df eVlSlOn.p lE-105 Drilling Program Revision.pdf C t t T 1· t" n/ t t t on en - ype: app lca 10 oc e -s ream Content-Encoding: base64 20f2 1/27/20058:06 PM lE-105. -105L1, -105L2 . . Subject: IE-lOS, -105LI, -105L2 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 24 Jan 200509:38:40 -0900 To: Mike.R. Greener@conocophillips.com CC: Gary Targac <Gary.Targac@conocophillips.com>, Randy Thomas <Randy.L. Thomas@conocophillips.com> Mike and Gary, With regard to these wells, is there a plan to pre-produce?? since the wells will ultimately be injectors, the Area of Review task must be done. AOR means that the cementing record of any penetration that falls within 1/4 mile distance of the planned wellbore track must be examined to assure that such penetrations do not provide a potential conduit out of the intended zone. The pertinent beginning "point" is where the motherbore penetrates the top of the West Sak and the ending "point" is the furthest extent of the toe of any of the laterals. Based on our preliminary review of the trajectory, the WS wells you potentially need to examine are: 1E-114 and laterals, ID-123, ID-126, ID-127, lE-126 and laterals, lE-168 and laterals. The potential Kuparuk wells are lE-33, 1E-33PBl, IJ-09, lE-34 and lE-22. lE-03 or lE-103 may also need to be checked. I can't determine the name on the plot I am looking at. My source of the information is a plan view of the proposed well trajectories. A few of the wells, lE-34, IJ-09 and lE-22 will likely fallout since their WS penetrations are probably outside the 1/4 mile distance. The only "wild card" that you also need to consider are any "lost" hole sections that may have been drilled. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 1/24/2005 10:38 AM ., ConocóPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.LThomas@conocophillips.com RECEIVED JAN 1 1 2005 January ih, 2005 Alaska Oil & Gas COliS, Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Pennit to Drill, West Sak Injector, lE-105, lE-105 L1, lE-I05 L2 Dear Commissioners: ¡ ConocoPhillips Alaska, Inc. hereby applies for Pennits to Drill for a pre-produced onshore injection well, a Tri- lateral horizontal well in the West Sak "Al", "B" and "D" sands. The main bore of the well will be designated lE- 105, the "B" sand lateral will be designated lE-I05 Ll, and the "D" sand lateral will be designated lE-105 L2. Please find attached for the review of the Commission fonns 10-401 and the infonnation required by 20 ACC 25.005 for each of these well bores. The expected spud date oflE-105 is February 5th, 2005. If you have any questions or require any further infonnation, please contact Mike Greener at 263-4820. Sincerely, ~\~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25 005 . 1a. Type of Work: Drill ~ Redrill U Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1b. Current Well Class: Stratigraphic Test ] P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 391' FSL, 224' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 464' FNL, 378' FEL, Sec. 22, T11N, R10E, UM Total Depth: 1338' FNL, 345' FEL, Sec. 27, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300' 16. Deviated wells: Kickoff depth: 7477 ft. 18. Casing Program Size , , Hole 30" 16" , y- 5959981 Zone- 4 Maximum Hole Angle: 95· Specifications Weight Grade Coupling Length 62.5# H-40 Welded 80' 68# L-80 BTC 4537' 40# L-80 BTCM 8180' 15.5# L-80 BTCM 6168' Casing 20" 12.25" 13.325" 9-5/8 " 8.5" 5.5" 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size t(p) \1 BOP Sketch ~ Diverter Sketch 0 Drilling Program[] Seabed Report 0 20. Attachments: Filing Fee Property Plat [j 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Randy Thomas \~~ ~ . - I , Commission Use Only Permit Approval See cover letter for other requirements API Number: 50- D2. c¡ ~ 2. 8 zt/3 - to 0 Samples required 0 Yes gNo Mud log required 0 Yes g No ~ sulfide measures . Rf Yes 0 No Directional survey required N Yes 0 No Other: ?r~'.L'L \O~~~,~\~}.ß~ ~~t'&)~~. ~~~-\'\~~\ ~\'-\~ú.y) l! 1J BY ORDER OF '^ ¿ / ,,-- Approved ~ A / COMMISSIONER THE COMMISSION Date: CT-f ~ () ~ Form ~ReV~03 . 0 RIG I N A L I SU~it in duplicate Permit to Drill Number: 205-~7 Conditions of approval: . Rl:Cl:IVl:J¡ JAN I 1 2005 ~, & )Haske Commission #. Exploratory U Development Oil U ~Mù'Mp~'Zone 0 Service [] Development Gas 0 Single Zone [] 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-1 05L 1 6. Proposed Depth: 12. Field/Pool(s): MD: 13640" TVD: 3453' ' Kuparuk River Field -- 6 If F ~ .' I 7. Property Designation: .........~ ALK 25651/25660 West Sak Pool .,4þ ,. i"z·¿S; 8. Land Use Permit: 13. Approximate Spud Date: 2/5/2005 ADL 469/470 9. Acres in Property: 2560 14. Distance to Nearest Property: 10182' 10. KB Elevation 15. Distance to Nea",st . £.v?.1· .4Þ ¡ b- ¡ '2.(, - .c.><-> Well within Pool: '"'I.E 114, 16~·@ðM'eI.{¿.,,> (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 1599 psig I Max. Surface Pressure: 1208 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 225 sx AS I 2474' 870 sx AS Lite, 210 sx DeepCrete 3675' 630 sx DeepCrete 3453' slotted liner Top MD 28' 28' 28' 7472' I TVD 28' 28' 28' 3552' MD 108' 4537' 8180' 13640' , (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot 0 Drilling Fluid Program [] Date: Shallow Hazard Analysis Q 20 MC 25.050 requirements [] - Contact Mike Greener @ 263-4820 Title Kuparuk Drilling Team Leader Phone '2-G;...r (;.g 1 0 Date l ("7 (0 S amn AII.</ln-nlakF! Date: · A.tion for Permit to Drill, Well 1 E-105 L 1 Revision No.O Saved: 10-Jan-05 Permit It - West Sak Well #lE-IOSLl Application for Permit to Drill Document Moximize We-II I/alue Table of Contents 1. Well Name........... ........ ...... ... ... ................. ................ ...... ............... .............. ......... ...... ... ........... 2 Requirements of 20 MC 25.005 (f) ........................................................................................................................2 2. Location Summary... ......... ..... ... ......... .......... ....... ....... .... ....... ..... ... ........... ....... .......... ... ...... ..... 2 Requirements of 20 M C 25. 005( e)(2)............ ........ ...... ..................................... ........ ........ ......... .......... ...... ............2 Requirements of 20 MC 25.050(b) ........................................................................................................................2 3. Blowout Prevention Equipment Information ....................................................................... 3 Requirements of 20 MC 25.005( e)( 3 )....................................................................................................................3 4. Drilling Hazards Information ...................... ............... ... ... ............ ... ...... ....... ......... ....... ... ...... 3 Requirements of 20 MC 25.005 (e)( 4 )...................................................................................................................3 5. Procedure for Conducting Formation Integrity Tests......................................................... 3 Requirements of 20 MC 25.005 (e)( 5 )...................................................................................................................3 6. Casing and Cementing Program............................................................................................ 3 Requirements of 20 MC 25. 005( e)( 6)... ..... ...... ............................ .......... ...................... ...... .... ......... ...... ..... ............3 7. Diverter System Information .................................................................................................4 Requirements of 20 M C 25. 005( e )(7) ..... ........ ... '" ............ .... ...... ........ ... ......... ... ..... .... .,. .... .... .... .... ................... .....4 8. Drilling Fluid Program.... ... ..... ..... ................ ....... .... ......... ....... ..................... ..... ...... ............... 4 Requirements of 20 MC 25. 005( e)( 8)..... ........ ........ .......... .......... .................... .................. ........... .......... ...... ..........4 Lateral Mud Program (M/ VersaPro Mineral Oil Base)........................................................................................4 9. Abnormally Pressured Formation Information ...................................................................5 Requirements of 20 MC 25.005 (e)(9 )...................................................................................................................5 10. Seismic Analysis.... ..... ........... ..... .................... .... .... ....... ............. ....... ......... ..................... ......... 5 Requirements of 20 MC 25.005 (e)( / 0 ).................................................................................................................5 11. Sea bed Condition Analysis .... ..... ............ .... .......... .... ...... ....... ..... ..... ............. ..... ...... ...... ......... 5 Requirements of20 MC 25.005 (e)( / / ).................................................................................................................5 12. E vi den ce of Do nding . ............. ....... ...... .......... ....... .... ... ............. ..... ..... ...... ..... ...... .... ...... .......... 5 Requirements of20 MC 25.005 (e)( /2).................................................................................................................5 IE-105 L1 PERM/T /T.doc Page 1 of 6 Printed: 10-Jan-05 ORiGINAL · AP.ion for Permit to Drill, Well 1 E-105 L 1 Revision No.O Saved: 10-Jan-05 13. Proposed Drilling Program .. ... ... ......... ... .......... ........ ....... ...... ... .............. ......... ................. ...... 5 Requirements of20 AAC 25.005 (c)( 13 ).................................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal...................................... 6 Requirements of 20 AAC 25.005 (c)( 14 ).................................................................................................................6 15. A ttachmen ts ... ........ .... ........ ...... ..................... ... ......... ............. ...... ... ... ....... ... ......... .............. ..... 6 Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) ........................................................6 Attachment 2 Directional Plan (6 pages) ..............................................................................................................6 Attachment 3 Drilling Hazards Summary (1 page)................................................................................................6 Attachment 4 Well Schematic (1 page) ..................................................................................................................6 1. Well Name Requirements of20 AAC 25.005 if) Each well must he identified by a unique name designated hv the operator and a unique API number assigned hy the commission under 20 ¡t.1C 25.040(b). For a .vell with muitiple well branches. each branch IIIUSt similarly he identified by a unique name and APi number by adding a suffix to the nallle designated JÌJr the well by the operator and to the lJumber assigned to the well by the commission. The well for which this Application is submitted will be designated as lE-105 Ll. 2. Location Summary Requirements of20 AAC 25.005(c)(2) An appiication /Ór a Permit to Drill rnust be accompanied by t'ach of the following items, exceptjÒr an Ílem already onme .,..,.ith the commission and identified in the application: (2) a plat identi/ving the property and the property's owners and showing (A)the coordinates of the propo.~ed location (ilthe well at the sUlj{/(;e. at the tup ofeacl¡ u/~iectlvejÒrmatio/l. and at total depth, referenced to govenuuental section lines, (B) the coordinates uttlie proposed locatÙm of [he well at [he surfiiCt', referenced to the state p!ane coordinate system jilr this state as maintained by the Nationa! Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) [he proposed depth o/the well at the top of each objective formation ,md at total depth: Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,959,981 / Eastings: 550,300 ' 4,889' FNL, 224' PEL, Section 16, TllN, RlOE I RKB Elevation I 94.1' AMSL I Pad Elevation I 66.1' AMSL Location at Top of Productive Interval (West 464' FNL, 378' PEL, Section 22, TlIN, RlOE Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7,477 Northings: 5,959,162 Eastings: 555,434 Total Vertical Depth, RKB: 3,553 Total Vertical Depth, SS: 3,458 ~ Location at Total Depth I 1,338' FNL, 345' FEL, Section 27, TlIN, RlOE ASP Zone 4 NAD 27 Coordinates Measured DePth, RKB: 13,639 Northings: 5,953,009 Eastings: 555,521 Total Vertical Depth, RKB: 3,453 Total Vertical Depth, SS: 3,359 and (D) other infÓrrnation required by 20AAC 25.050(b): Requirements of20 AAC 25.050(b) If a well is to be in ten/ion ally deviated. the appìicatì011 for a Permit to Drill (Form i D-40l ) must (1) include a plat. drawn to a suitable scale. showing the path of the proposed ,rellbon, including all adjacent wellbores within 200feet of any portion of the proposed well: Please see Attachment I: Directional Plan 1E-105 L1 PERMIT IT. doc Page 2 of 6 Printed: 10-Jan-05 ORIGINAL · AP.ion for Permit to Drill, Well 1 E-105 L 1 Revision No.O Saved: 10-Jan-05 and (2) for all wells within 2(Xj feet of the proposed wel/bore (A) list the names (1/he operators of those wells, 10 the extent that those names are known or discoverable in public records, and show that each named operator has beenfumished a copy (if the application by certi,fied mail: or (fJ) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each l!f the fallowing items, except for an item already on fUe with the commission and identified in the application: (3) a diagram and description of the b!OYVOII/ prevention equipment (HOPE) as required by 20 /lAC 25.1ì35, 20 AAC 25.036. or 20 AAC 25.037, a5 applical>le; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete wel1IE-105. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AA C 25.005 (c)( 4) An application /Òr a Permit /(> Drill must be accompanied by each of thefoilowing items, é'xceptjiJr au iten¡ already onfile with the commission and identified in the application: (4) infÒrmation on drilling hazards, including (A) the fi'!iuimum downhole pressure that nulY be encountered, criteria used to determine it, and nuuimum potential surface pressure based on a methane gradient: The expected reservoir pressures in the West Sak sands in the 1E-105 L1 area vary from 0.43 to 0.45 psi/ft, or 8.3 to I 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,250 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 3,553' . The MPSP is calculated thusly: MPSP = (3,553 ft)(0.45 - 0.11 psi/ft) = 1 ,208 psi / (B) data on potential gas zones.: The well bore is not expected to penetrate any gas zones. And IC) data concerning potential causes «f hole problems such as abnorrru:dly gal-pressured strata. lost circulation zones, and zones that have a propensity for differential sticking: Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AA C 25.005 (c)( 5) An application for a Permit to Drill must be aCCOl1lf)(mied by each of the jÓllowing items. except for an item already on file with the commission and identified in the application: (5) a de.H:ription (i(The pmcedure jÌJr conducting./ìmnation integrity Tests. as required under 20 AA.C 25.030(/): No formation integrity test will be performed in the drilling of lE-105 Ll 6. Casing and Cementing Program Requirements of20 AAC 25.005(c)(6) A.n application.fÓr a Permit to Drill must be accompanied by each olrhe./Ói!owing Ìlems. exceptIor an item alread)' onjïle with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.1)30, and a descriptiolllif any slotted liner. pre-peljÓrated liner, or scrc£:'n to be installed,; 1E-105 L 1 PERMIT IT. doc Page 3 of 6 Printed: 10-Jan-05 ORIGJNAL · AP.ion for Permit to Drill, Well 1 E-105 L 1 Revision No.O Saved: 10-Jan-05 I Casing and Cementing Program I See also Attachment 3: Cement Summary Hole Top Btm CsgíFbg Size Weight Length MDflVD MDflVD aD (in) (in) (lb/ft) Grade Connection (fì) (ft) (ft) Cement PrOf!ram 20" 40" 62.5 H-40 Welded 80 28' /28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 4,537 28' /28' 4,537' /2,474' 870 sx ArcticSet Lite Lead, 210 sx DeeDCRETE Tail Cement Top planned @ 5,033' 9-5/8" 12-114" 40 L-80 BTCM 8,180 28' /28' 8,180' /3,675' MD 12,655' TVD. Cemented wI 630 sx DeeDCRETE 5-1/2 8-112" A2 Sand 15.5 L-80 BTCM 5,473 7,562' /3,560' 13,653' /3,625' Slotted- no cement slotted Lateral (1 E-I 05) 5-112 8-112" B Sand Lateral 15.5 L-80 BTCM 6,168 7,472' /3,552' 13,640' /3,453' Slotted- no cement slotted (IE-105 Ll) 5-112 8-112" D Sand Lateral 15.5 L-80 BTCM 6,392 7,242' /3,499' 13,634' /3,399' Slotted- no cement slotted (IE-105 L2) 7. Diverter System Information Requirements of20 AAC 25.005(c)(7) An applicatìonflJr a Permit to l)rill must be acconrpanied by each ofthef(Jllo~ving itCfU.S. e.xceptfor an ¡tern a/read)' onfile ·with the commission and identified in the application: (7) a diagram and description of the divertu system as {'{''luired by 20 AAC 25.035, unless this requirement is waived bv the commission under 20AAC 25.035(h)(2); No diverter system will be used during operations on lE-105 Ll 8. Drilling Fluid Program Requirements of 20 AA C 25. 005( c)( 8) An applicationjìJra Permit to Drill must be accompanied by each ofthef(¡llowing item.s. except for an item already onflle with the commission and identified in the application: (8) /I drilling .fluid program, induding a diagram and description of the drilling .fluid system, as required by 20 AAC 25.033: Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Densi ( ) Plastic Viscostiy (lb/IOO s Yield Point (cP) Value 9.0 15-25 / 18-28 HTHP Fluid loss (ml/30 min @ 200 si & 1500 Dill Water Ratio Electrical 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 141. <4.0 80:20 >600 1E-105 L1 PERMIT IT. doc Page 4 of 6 Printed: 10-Jan-05 ORiGiNAL · AP.on for Permit to Drill, Well 1 E-1 05 L 1 Revision No.O Saved: 10-Jan-05 9. Abnormally Pressured Formation Information Requirements of20 AAC 25.005 (c)(9) An application JÒr a Permit to Drill must be accompanied by each of the foilowing items. except jÒr an item already ontHe with the commission and identified in the application: (9) fÒY an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnorm.ally geopressured strata as required by 20 AAC 25JI33(j); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AA C 25.005 (c)( 10) An application for a Permii to Drill must be accompanied by each of the jÓllowing items. (~xcept for an item alrmdr on jilewith the commission and idnltijied Ù¡ the application: (10) for an exploratory or strati,graphic test well. a seismic retraction or reflection analysis as required by 20 AAC 25.06l(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AA C 25.005 (c)( 11 ) An application .!Ór a Permit to Drill must be accom.panied by each (1' the following iternl'. except for an item already onfile I';;ith the commission and identified in the application: (1] Jjór a well drilledfrom an !dt'shore platfarm, mobile boftom:fÓullded structure, jack-up rig, orfloating drilling vessel. an analysis oJ'seahed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AA C 25.005 (c)( 12) All applicatioll fàr a Permit to Drill must be IIccOlfqHlltied by each of the .fÓllowing iiems. except for an item already Oil .file with the commission and identijied Ù¡ the application: (12 ì evidence showing that the requirements ol20 AAC 25.025 [Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AA C 25.005 (c)( 13) An application jÒr a PermÍl to Drill must be accompanied by each (1' ¡hefÓl!owing íter'LS. except for an Ìlem already onfile with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. revious operations are covered under the lE-105 Application for Permit to Drill. r WindowMaster whipstock system, at window point of 7,562' MD /3,560' TVD, the top of the 1. \( d". 2. 3. 4. 5. Mill 8-112" window. ~ ~ I S"~è>e.cJ Pick up 8-112" drilling assemb ith L WD and MWD and PWD. RIH. ,/ Drill to TD of "B" sand lateral at 13, , , MD / 3,453' TVD, as per directional plan. POOH, back reaming out of lateral. POOH. ERMIT IT.doc Page 5 of 6 Printed: 10-Jan-05 6. RIH with whipstock retrieval tool. Retrieve whipsto 7. PU and run 4-112" slotted liner. 8. RIH, until liner hanger is just above window. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) packer atop assembly and release from assembly. POOH. 11. Run and set Baker WindowMaster whipstock system, at window point of 7,562' MD /3,5 "D" sand. ORIGINAL . . Application for Permit to Drill, Well 1 E-1 05 Revision No.O Saved: 27-Jan-05 ++'25. PU and run 5-112" slotted liner. +&26. Land liner, set liner hanger @ +1- 7,650' MD 13,582'. POOH. Note: Remaining operations are covered under the 1£-105 Ll and 1£-105 L2 Applicationfor Permit to Drill, and are provided here for information only. ~27. Run and set Baker WindowMaster whipstock system, at window point Of7~D 13~VD, the top of the "B" sand. ~28. ;¿+..29. Mill 8-112" window. POOH. Pick up 8-112" drilling assembly with L WD and MWD and PWD. RlH. .,. r Drill to TD of"B" sand lateral at 13,640' MD 13,453' TVD, as per directional plan. '\~~d 35$-q ~'\~ ~,W\.\ ~ doS-aa,\ 22·,3 O. 2;h31 . POOH, back reaming out of lateral. POOH. L"ð :24:32. RlH with whipstock retrieval tool. Retrieve whipstock and POOH. ~5.:,II:.......YU and run 5-112" slotted liner. ;M.;34. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. n35. Release hanger running tool. POOH. 28-,36. Make up junction isolation I re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. ~9..JZ:'m....Run an set Baker WindowMaster whipstock system, at window point of 7 ~D I 3~ TVD, the top of the "D" sand. '"\ W-:.38. Mill 8-112" window. POOH. J'i\ ~ L;~~ }·'}'·:39. Pick up 8-112" drilling assembly with L WD and M~ and PWD. RlH. Drill to TD of"D" sand lateral at 13,6* MD 13,399' TVD, as per directional plan. POOH, back reaming out oflateral. POOH. 32-,40. }';'41. ;;4-;42. RlH with whipstock retrieval tool. Retrieve whipstock and POOH. 35·,43. PU and run 5-112" slotted liner. 3Ð-A4. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 17.15,.__Release hanger running tool. POOH. 38,46. Make up junction isolation I re-entry assembly (Lateral Entry Module or LEM) and RlH to depth. Orient and set packer atop assembly and release trom assembly. POOH. 1:5.b.11'.m..POOH, laying down drill pipe as required. 4448. PU injection as required and RlH to depth. Land tubing. Set BPV. 4-1-:.49. Nipple down BOPE, nipple up tree and test. Pull BPV. ~50. Freeze protect well with diesel by pumping into 4-112" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. ±},-~.L...__.Set BPV and move rig off. 44:52. Rig up wire line unit. Pull BPV. #-:53. Set gas lift valves in mandrels. Operate well on gas lift for +1- +&9 30 days. Shut well in. 44-54. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 1E-105 PERMIT IT Revised with suspensiondoc1E 105 PERMIT/TOOc Page 70f8 Printed: 27-Jan-05 . APan for Permit to Drill, We1l1E-105 L1 Revision No.O Saved: 10-Jan-05 18. 19. ">Ùflè~~ \ ( ;).'ì 12. Mill 8-1/2" window. POOH. 13. Pick up 8-112" drilling assembly with LWD and MWD and PWD. R 14. Drill to TD of "D" sand lateral at 13,634' MD 13,399' TVD, a 15. POOH, back reaming out of lateral. POOH. 16. RIH with whipstock retrieval tool. Retrieve whipsto 17. PU and run 5-1/2" slotted liner. . Orient hanger to window and land hanger. 20. Make up junction isolation I re-e y assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and reI se from assembly. POOH. ," 21. POOH, laying down dril/lpe as required. 22. PU injection as requ' d and RIH to depth. Land tubing. Set BPV. 23. Nipple down BO , nipple up tree and test. Pull BPV. 24. Freeze prote . well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 25. 26. P wire line unit. Pull BPV. et gas lift valves in mandrels. Operate well on gas lift for +1- 180 days. Shut well in. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AA C 25.005 (c)( 14) An application jÒr a Permit to Drill mustc be accompanied by each or the foí!owing items, except jÒr all item already on file with the commÜsion and identified in the application: (14) a general description of how ¡he operator plans to dispose of'dríl!ing mud and cuuings and a statemenf of'whether the operator imends to request attthoríz.ationunder 20 A.AC 2.5. 080 for an annular disposal operation in tht' well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on IE 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 IE 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 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) Attachment 2 Directional Plan (6 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Well Schematic (1 page) 1E-105 L1 PERMIT IT.doc Page 6 of 6 Printed: 10-Jan-05 ORIGINAL IE·IOS. Drillio2 HazardAummar'.: (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8-1/2" Open Hole /5-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Miti ation Strate Stripping drills, shut-in drills, increased mud wei ht. Good hole cleaning, PWD tools, hole opener runs, decreased mud wei ht Reduced urn rates, mud rheolo , LCM Trip speeds, proper hole filling (use of trip sheets), urn in out, backreamin Lost Circulation Hole Swabbing on Trips Low Moderate ORIGINAL 1 E-1 05 L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 1/4/2005 10:18 AM lE-105 L2: D sand lateral 3,634' MD j 3..199' TVD TD 'D" Liner. , 15.5#, L80. BTCM, R3 I,·"i slotted and )/2 blank. (0.125":x 2,)" slot 32 per fOOL 5.9% open area) 13-5/8' 2.6 #, L-80_ IBTM Model sera TVD. [, with 3.812" nipple., one (1) joint above 10S L2 "f)" Sand Window 7 .24]' MD ! 3.499' TVD degree 500' mpple seJ DB 4-1/2' ,875' \Vemwad I Tubing Head ¡ Tree r 5,000 hi ---+ Lateral Entry Module #2 (LEf\J), Baker, with sea! bore and ZXP packer above. Insulated Conductor 20", 94#.. K55 x .0.312" WT@ +/·80'MD ~ ~ s.. :IE ..... !!!.. ..... Ii' ..... "" '" lE-J05 Ll: 8-1/2" "B" sand lateral 13,640' MD / 3,453' TVD Window / 3,552' TVD "'B" Sand 7,472' MD degree' 05 80 Module #1 (LEM), seal bore and ZXP pa-cke.r above. Lateral Bake! TD "8" Liner; 5-1/2", LBO, BTCM, R3 and ~,; blank. (0.125" x 2.5" slotsj 5.9% open are.a) --^'í(" Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ..vv- 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial ~ installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-}'2" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. <II( Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~ To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ~ 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly Conoc~hillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration 13-5 BOP 3K diagram.vsd Sheet 1 of 1 prepared by Steve McKeever 8/11/2004 Uf\.u f~AL . . ConocóPhillipS Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 05 Plan 1E-105 L 1 Plan: 1 E-1 05 L 1 (wp02) Proposal Report 04 January, 2005 ~l'P.... ..... ·..,-.rt' I·.un ::I . ifnJJLt;:]Jí" .... .. "''''~vIf:~$i A Halliburton Company OR'GINJ~l- -600 0 -3000 -2400 -1800 -1200 ·600 0 A '2 :i§ 600 0 0 ~ 1200 ~ 'f: '" > '" 1800 ;:J f=. 2400 3000 3600 4200 4800 600 2400 Vertical Section at 180,00' (1200 ftlin) 3600 4200 4800 5400 6000 7200 7800 8400 9000 9600 10200 -3000 Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1E.105 -2400 Wellbore: Plan 1E·105 L1 Plan: 1 E·105 L 1 (wp02) 7800 8400 9600 3000 6600 1200 1800 Sail @ 91.7' -Begin GeoSteering In B-Lateral (8273'md,3S33'tvd) -1800 -1200 -600 . 0 -i 600 2 CD ~ a ~ 1200 0 CD " S' ~ 8 1800 ~ 2: 2400 3000 . Estimated Intersection Fault #1 (11338'md,3S17'tvd) ./ BHL: 1338'FNL & 34S'FEL: SEC27-T11N-R10E (13639'md,34S3'tvd) 1E-105 L1 (wp02) 1E-i05 PSi (wp05) conocóPhill~ Ai~ iE-i05 (wp05) ~ Ø"'lt:'¡;;;.~..· ..;"V'l~__ ........~ 3600 4200 4800 -600 10200 o 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 Vertical Section at 180,00' (1200 ftlin) 9000 . . ...¥ ConocoPhiUips ÞJåSka Project: Kuparuk River Unit Site: Kuparok 1E Pad Well: Plan 1E-105 Wellbore: Plan 1E-105 L 1 Plan: 1E-105 L1 (wp02) .~ ~"~~ç;'... ~."".c... jI",~~ West(-)/East(+) (1000 ftlin) -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 500 133/8"C 500 .... ...... 0 0 Top of Window - Assume 13.6" DLS off whipstock: 464'FNL & 378'FEL SEC 22-T11N-R10E: (7477'md,3553'tvd) -500 -500 Bottom of Whipstock - (7494'md,3556'tvd) Begin Build @ 5"/100ft (7514'md,3558'tvd) -1000 -1000 Continue Build @ 3"/100ft (7712'md,3568'tvd) -1500 Sail @ 93.8" ( 7767'md,3565'tvd) -1500 Begin Dir@3"/10OO(8203'md,3537'tvd) -2000 -2000 Sail @ 91.7' (8273'md,3533'tvd) -2500 Begin Dir@3'/100ft(9073'md,3509'tvd) -2500 c (/) 0 ~ Sail @ 90.6' (9198'md,3507'tvd) c 0 ~ 0 ~ -3000 Begin Dir@ 3"/1000 (10898'md,3490'tvd) -3000 ~ 0 +' ;:\. ::r :c ~ t:: Sail @ 85.6' (11063'md.3496'tvd) 0 -3500 -:;: ~ -3500 0 0 :c 0 :; Estimated Intersection Fault #1 (11338'md,3517'tvd) ~ 0 -4000 2: (/)-4000 Begin Dir@ 3'/1000 (11474'md,3527'tvd) -4500 -4500 Sail @ 95' (11788'md.3525'tvd) -5000 Begin Dir@ 3'/1000 (12075'md,35OO'tvd) -5000 Sail @ 91" (12210'md,3493'tvd) -5500 -5500 Begin Dir @ 3"/1000 (12375'md,3490'tvd) Sail @ 92' (12407'md,3489'tvd) -6000 -6000 Begin Dir@ 3'/1000 (12676'md.3480'tvd) -6500 Sail @ 924' (12691'md,3480'tvd) -6500 Begin Dir @ 3'/1000 (13200'md,3458'tvd) -7000 Sail @ 90.5' (13262'md,3456'tvd) -7000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 West(-)/East(+) (1000 ftlin) . . ConocóPhillips Alaska Halliburton Company Planning Report - Geographic sp""""'y-SiUl1 CAlL-LING S.AVICIIS A Halliburton Company Site Kuparuk 1 E Pad 66.1 GL + 28 KB @ 94. 100ft (66.1 GL + 28 KB) 66.1 GL + 28 KB @ 94.1000 (66.1 GL + 28 KB) True Minimum Curvature Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Position +N/-S +E/-W 217.648 ft 412.464 ft O.OOOft Northing: Easting: Wellhead Elevation: 5,959,980.600 ft 550,300.480 ft ft Latitude: Longitude: Ground Level: 70' 18' 05.162" N 149' 35' 33.332" W 66.100ft Position Uncertainty 1/412005 6:23:58PM Page 2 of 6 COMPASS 2003.11 Build 48 nr) ¡ ¡ } r\¡ '\:.~# \" . , . . Conoc6P'hillips Alaska Halliburton Company Planning Report - Geographic !iiplilr"'l'"'Y-SUI! aRILLING IU!!RVII:IIS A Halliburton Company 7,477.206 80.000 177.901 3,553.000 3,458.90 -635.368 5,540.815 5,959,161.734 555,433.883 0.00 853.02 Top of Window - Assume 13.6' DLS off whipstock: 464'FNL & 378'FEL : SEC 22-T11N-R10E : (7477'md,3553'tvd) 7,493.706 82.244 177.901 3,555.546 3,461.45 -651.658 5,541.412 5,959,145.449 555,434.588 13.60 869.31 Bottom of Whipstock - (7494'md,3556'tvd) 7,500.000 82.244 177.901 3,556.396 3,462.30 -657.891 5,541.641 5,959,139.219 555,434.858 0.00 875.54 7,513.706 82.244 177.901 3.558.245 3,464.15 -671.462 5,542.138 5.959,125.653 555,435.445 0.00 889.11 Begin Build @ 5'/100ft (7514'md,3558'tvd) 7,600.000 86.557 177.901 3.566.662 3,472.56 -757.266 5,545.283 5,959,039.879 555,439.159 5.00 974.91 7,700.000 91.557 177.901 3,568.305 3,474.20 -857.154 5,548.944 5,958,940.027 555,443.483 5.00 1,074.80 7,712.426 92.180 177.901 3,567.899 3,473.80 -869.565 5,549.399 5,958,927.621 555,444.020 5.01 1,087.21 Continue Build @ 3'/1000 (7712'md,3568'tvd) 7,766.010 93.722 177 .448 3,565.140 3,471.04 -923.032 5,551.570 5,958,874.175 555,446.546 3.00 1,140.68 Sail @ 93.8' (7767'md,3565'tvd) 7,767.010 93.751 177.439 3,565.075 3,470.98 -924.030 5,551.614 5,958,873.178 555,446.597 3.00 1,141.68 7,800.000 93.751 177.439 3,562.917 3,468.82 -956.916 5,553.085 5,958,840.305 555,448.286 0.00 1,174.56 7,900.000 93.751 177.439 3,556.374 3,462.27 -1,056.602 5,557.544 5,958,740.661 555,453.406 0.00 1.274.25 8.000.000 93.751 177.439 3,549.832 3,455.73 -1,156.288 5,562.002 5,958,641.016 555,458.526 0.00 1,373.94 8,100.000 93.751 177.439 3.543.289 3,449.19 -1,255.974 5.566.461 5,958,541.372 555,463.645 0.00 1,473.62 8,200.000 93.751 177.439 3,536.747 3,442.65 -1,355.660 5,570.919 5,958,441.727 555,468.765 0.00 1,573.31 8,203.219 93.751 177.439 3,536.536 3,442.44 -1,358.869 5,571.062 5,958,438.520 555,468.930 0.00 1,576.52 8,203.431 93.751 177.439 3,536.523 3,442.42 -1,359.080 5,571.072 5,958,438.308 555,468.941 0.00 1,576.73 Begin Dir@3'/10OO (8203'md,353Ttvd) 8,272.832 91.727 176.925 3,533.210 3,439.11 -1,428.314 5,574.481 5,958,369.105 555,472.809 3.01 1,645.96 Sail @91.7' (8273'md,3533'tvd) 8,300.000 91.727 176.925 3,532.391 3,438.29 -1,455.431 5,575.938 5,958,342.001 555,474.446 0.00 1,673.08 8,400.000 91.727 176.925 3,529.377 3,435.28 -1,555.242 5,581.300 5,958,242.238 555,480.469 0.00 1,772.89 8,500.000 91.727 176.925 3,526.364 3,432.26 -1,655.052 5,586.661 5,958,142.475 555,486.493 0.00 1,872.70 8,600.000 91.727 176.925 3,523.350 3,429.25 -1,754.863 5,592.023 5,958,042.712 555,492.517 0.00 1,972.51 8,700.000 91.727 176.925 3,520.336 3,426.24 -1,854.674 5,597.385 5,957,942.949 555,498.541 0.00 2,072.32 8,800.000 91.727 176.925 3,517.322 3,423.22 -1,954.484 5,602.747 5,957,843.185 555,504.565 0.00 2,172.13 8,900.000 91.727 176.925 3.514.309 3,420.21 -2,054.295 5,608.109 5,957,743.422 555,510.589 0.00 2,271.94 9,000.000 91.727 176.925 3,511.295 3,417.19 -2,154.106 5,613.471 5,957,643.659 555,516.613 0.00 2,371.75 9,072.832 91.727 176.925 3,509.100 3,415.00 -2,226.799 5,617.376 5,957,571.000 555,521.000 0.00 2,444.45 Begin Dlr @ 3'/1000 (9073'md,3509'tvd) -Œ-105 L 1 T2 9,100.000 91.474 177.699 3,508.341 3,414.24 -2,253.927 5,618.649 5,957,543.884 555,522.453 3.00 2,471.57 9,198.308 90.556 180.503 3,506.599 3,412.50 -2,352.197 5,620.190 5,957,445.636 555,524.646 3.00 2,569.84 Sail @ 90.6' (9198'md,3507'tvd) 9,200.000 90.556 180.503 3,506.583 3,412.48 -2.353.888 5,620.175 5,957,443.945 555,524.642 0.00 2,571.54 9,300.000 90.556 180.503 3,505.612 3,411.51 -2,453.880 5,619.296 5,957,343.959 555,524.428 0.00 2,671.53 9,400.000 90.556 180.503 3,504.642 3,410.54 -2,553.871 5,618.418 5,957,243.974 555,524.213 0.00 2,771.52 1/4/2005 6:23:58PM Page 3 of 6 COMPASS 2003.11 Build 48 ORIGtN,AL . . Conoc~hillips Alaska Halliburton Company Planning Report - Geographic spBr"1""Y-SUI1 DRILLING SI!"VICIIS A Halliburton Company EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(K1Jparuk) Kuparuk River Unit Kuparuk 1 E Pad Ian 1E-105 Ian 1E-1{J5 L 1 E-105 L 1 (wp02) 9,500.000 90.556 180.503 3,503.671 3,409.57 -2,653.863 5.617.540 5,957,143.988 555,523.999 0.00 2,871.51 9,600.000 90.556 180.503 3,502.700 3,408.60 -2,753.854 5,616.661 5,957,044.003 555,523.784 0.00 2,971.50 9,700.000 90.556 180.503 3,501.730 3,407.63 -2,853.846 5,615.783 5,956.944.018 555,523.570 0.00 3,071.49 9,800.000 90.556 180.503 3,500.759 3,406.66 -2,953.837 5.614.904 5,956,844.032 555,523.355 0.00 3,171.48 9,900.000 90.556 180.503 3,499.789 3,405.69 -3,053.829 5,614.026 5,956,744.047 555,523.141 0.00 3,271.48 10,000.000 90.556 180.503 3,498.818 3,404.72 -3,153.820 5,613.147 5,956,644.062 555,522.927 0.00 3,371.47 10,100.000 90.556 180.503 3,497.847 3,403.75 -3,253.811 5,612.269 5,956,544.076 555,522.712 0.00 3,471.46 10,200.000 90.556 180.503 3,496.877 3,402.78 -3,353.803 5,611.391 5.956,444.091 555,522.498 0.00 3,571.45 10,300.000 90.556 180.503 3,495.906 3,401.81 -3,453.794 5.610.512 5,956,344.106 555,522.283 0.00 3.671.44 10,400.000 90.556 180.503 3,494.936 3,400.84 -3,553.786 5,609.634 5,956,244.120 555,522.069 0.00 3,771.43 10,500.000 90.556 180.503 3,493.965 3,399.86 -3,653.777 5,608.755 5,956,144.135 555,521.854 0.00 3,871.42 10,600.000 90.556 180.503 3,492.994 3,398.89 -3,753.769 5.607.877 5,956,044.150 555,521.640 0.00 3,971.42 10,700.000 90.556 180.503 3,492.024 3,397.92 -3,853.760 5,606.998 5,955,944.164 555,521.425 0.00 4,071.41 10,800.000 90.556 180.503 3,491.053 3,396.95 -3,953.751 5,606.120 5,955,844.179 555,521.211 0.00 4.171.40 10,898.193 90.556 180.503 3,490.100 3,396.00 -4,051.936 5,605.257 5,955,746.000 555,521.000 0.00 4,269.58 Begin Dir @ 3°/100ft (10898'md,3490'tvd) - 1E-105 L 1 T3 10,900.000 90.503 180.502 3,490.083 3,395.98 -4,053.743 5,605.242 5,955,744.194 555,520.996 2.93 4,271.39 11,000.000 87.505 180.415 3,491.824 3,397.72 -4,153.713 5,604.442 5,955,644.230 555,520.860 3.00 4,371.36 11,063.437 85.601 180.360 3,495.639 3,401.54 -4,217.031 5,604.014 5,955,580.917 555,520.852 3.00 4,434.68 Sail @ 85.6° (11 063'md,3496'tvd) 11,100.000 85.601 180.360 3,498.443 3,404.34 -4,253.485 5,603.785 5,955,544.465 555,520.866 0.00 4,471.13 11.200.000 85.601 180.360 3.506.114 3,412.01 -4,353.189 5,603.159 5,955,444.770 555,520.902 0.00 4,570.84 11,300.000 85.601 180.360 3,513.784 3,419.68 -4,452.892 5,602.533 5,955,345.074 555,520.938 0.00 4,670.54 11,338.000 85.601 180.360 3,516.699 3,422.60 -4,490.780 5,602.295 5,955,307.189 555,520.951 0.00 4,708.43 Estimated Intersection Fault #1 (11338'md,3S17'tvd) 11,400.000 85.601 180.360 3.521.454 3,427.35 -4,552.596 5,601.907 5,955,245.378 555,520.974 0.00 4,770.24 11,473.602 85.601 180.360 3,527.100 3,433.00 -4,625.980 5,601.446 5,955,172.000 555,521.000 0.00 4,843.63 Begin Dir@ 3°/100ft (11474'md,3S21'tvd) - 1E-10S L 1 T4 11;500.000 86.391 180.362 3;52£.943 3,434.84 -4,652.312 5,601280 5,955,145.669 555;521.009 2;99 4;869;96 11,600.000 89.391 180.371 3,532.619 3,438.52 -4,752.231 5,600.641 5,955,045.758 555,521.033 3.00 4,969.88 11,700.000 92.391 180.380 3,531.061 3,436.96 -4,852.206 5,599.986 5,954,945.791 555,521.042 3.00 5,069.85 11,788.497 95.048 180.388 3,525.320 3,431.22 -4,940.506 5,599.394 5,954,857.497 555,521.037 3.00 5,158.15 Sail @ 9So (11788'md,3S2S'tvd) 11,800.000 95.048 180.388 3,524.308 3,430.21 -4,951.964 5,599.317 5,954,846.040 555,521.035 0.00 5,169.61 11,900.000 95.048 180.388 3,515.509 3,421.41 -5.051.574 5.598.642 5,954,746.437 555,521.022 0.00 5,269.22 12,000.000 95.048 180.388 3,506.711 3,412.61 -5,151.184 5,597.968 5,954,646.835 555,521.010 0.00 5,368.83 12,075.134 95.048 180.388 3,500.100 3,406.00 -5,226.025 5,597.462 5,954,572.000 555,521.000 0.00 5,443.67 Begin Dir @ 3°/10Oft (1207S'md,3S00'tvd) -1E-10S L 1 TS 12,100.000 94.303 180.386 3,498.073 3,403.97 -5,250.808 5,597.294 5,954,547.219 555,520.997 2.99 5,468.46 12,200.000 91.303 180.379 3,493.186 3,399.09 -5,350.674 5,596.628 5,954,447.360 555,520.994 3.00 5,568.32 12,210.076 90.999 180.378 3,492.984 3,398.88 -5,360.748 5,596.561 5,954,437.286 555,520.994 3.01 5,578.40 Sail @ 91° (12210'md,3493'tvd) 12,300.000 90.999 180.378 3,491.415 3,397.32 -5,450.656 5,595.967 5,954,347.385 555,520.997 0.00 5,668.30 1/4/2005 6:23:58PM Page 4 of6 COMPASS 2003.11 Build 48 ORIG1~tAL . . ConocÓÁ,illips Alaska Halliburton Company Planning Report - Geographic SiipIIi''--'Y-SUI1 D.ULLING SERVICE. A Halliburton COmpany EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Plan 1E-105 L 1 1 E-105 L1 (wp02) 12.375.404 90.999 180.378 3,490.100 3.396.00 -5.526.047 5,595.470 5.954,272.000 555.521.000 0.00 5.743.69 Begin Dir@ 3°/10Oft (1237S'md,3490'tvd) - 1E-10S L 1 T6 12.400.000 91.737 180.380 3.489.513 3.395.41 -5.550.636 5,595.307 5,954,247.413 555.521.001 3.00 5.768.28 12,407.430 91.960 180.381 3,489.273 3,395.17 -5,558.062 5.595.258 5.954.239.988 555,521.001 3.00 5,775.71 Sail @ 92" (1240Tmd,3489'tvd) 12.500.000 91.960 180.381 3.486.107 3.392.01 -5,650.575 5.594.643 5.954,147.481 555,521.000 0.00 5.868.22 12.600.000 91.960 180.381 3,482.686 3.388.59 -5.750.515 5,593.979 5,954,047.549 555.521.000 0.00 5.968.16 12,675.601 91.960 180.381 3,480.100 3,386.00 -5,826.070 5.593.477 5.953.972.000 555,521.000 0.00 6,043.72 Begin Dir @ 3"/100ft (12676'md,3480'tvd) -1E-10S L1 T7 12.690.763 92.415 180.380 3,479.521 3,385.42 -5,841.220 5.593.377 5,953,956.850 555.521.000 3.00 6.058.87 Sail @ 92.4° (12691'md,3480'tvd) 12.700.000 92.415 180.380 3.479.132 3.385.03 -5,850.449 5,593.316 5,953,947.623 555,521.000 0.00 6,068.10 12,800.000 92.415 180.380 3,474.918 3,380.82 -5.950.358 5,592.652 5,953,847.721 555,521.000 0.00 6,168.01 12,900.000 92.415 180.380 3,470.704 3,376.60 -6,050.267 5,591.989 5,953,747.820 555,521.000 0.00 6,267.91 13.000.000 92.415 180.380 3,466.490 3,372.39 -6,150.176 5,591.325 5,953,647.918 555,521.000 0.00 6,367.82 13,100.000 92.415 180.380 3,462.277 3,368.18 -6,250.085 5,590.662 5,953.548.017 555,521.000 0.00 6,467.73 13,199.114 92.415 180.380 3,458.100 3,364.00 -6,349.109 5,590.005 5,953,449.000 555,521.000 0.00 6,566.76 Begin Dir@ 3"/10Oft (13200'md,34S8'tvd) -iE-i0S L 1 T8 13,200.000 92.389 180.380 3,458.063 3.363.96 -6,349.994 5,589.999 5,953,448.115 555,521.000 3.00 6,567.64 13,262.4 79 90.514 180.380 3,456.481 3,362.38 -6,412.448 5,589.584 5,953,385.666 555,521.000 3.00 6,630.10 Sail @90.S" (i3262'md,3456'tvd) 13,300.000 90.514 180.380 3,456.144 3,362.04 -6,449.967 5,589.335 5,953,348.149 555.521.000 0.00 6,667.61 13,400.000 90.514 180.380 3,455.246 3.361.15 -6,549.961 5,588.671 5,953,248.163 555,521.000 0.00 6,767.61 13.500.000 90.514 180.380 3,454.349 3,360.25 -6,649.955 5,588.007 5,953,148.177 555,521.000 0.00 6,867.60 13,600.000 90.514 180.380 3,453.452 3,359.35 -6,749.949 5,587.343 5,953,048.191 555,521.000 0.00 6,967.60 ./ 13,639.196 90.514 180.380 3,453.100 ./ 3,359.00 -6.789.142 5,587.083 5,953.009.000 555,521.000 0.00 7,006.79 BHL: 133S'FNL & 34!i'FEL :SEC27-T11N-R10E (13639'md,3453'tvd) -4 1/2" -1E-10S L 1 Toe 1/4/2005 6:23:58PM Page 5 of 6 COMPASS 2003.11 Build 48 ORIGj'~J.AL . . ConocóP'hillips Alaska Halliburton Company Planning Report - Geographic SIp8r""'Y-EiLJl! DRILLING SERViCe. A Halliburton Company 3,500.100 1E-105 L 1 T5 -5,226.025 5,597.462 5,954,572.000 555,521.000 - Point 3,509.100 1E-105 L1 T2 -2,226.799 5,617.376 5,957,571.000 555,521.000 - Point 3,458.100 1E-105 L1 T8 -6,349.109 5,590.005 5,953,449.000 555,521.000 - Point 3,480.100 1E-105 L 1 T7 -5,826.070 5,593.4 77 5,953,972.000 555,521.000 - Point 3,490.100 1E-105 L 1 T3 -4,051.936 5,605.257 5,955,746.000 555.521.000 - Point 3,541.100 1E-105 L1 T1 -1,167.295 5,560.403 5,958,630.000 555,457.000 - Point 3,453.100 1E-105 L 1 Toe -6,789.142 5,587.083 5,953,009.000 555,521.000 - Point 3,527.100 1E-105 L1 T4 -4,625.980 5,601.446 5,955,172.000 555,521.000 - Point 3,490.100 1E-105 L1 T6 -5,526.047 5,595.470 5,954,272.000 555,521.000 - Point 4,537.135 7,477.206 13,639.195 2,474.100 3,553.000 3,453.100 13-3/8 9-518 4-1/2 16 12-1/4 8·112 1/4/2005 6:23:58PM Page 6 of 6 COMPASS 2003.11 Build 48 OR GL~\l.!~f ',' "'...._>f:.~: lanlE-105 From Colour ToMD 7477 10955 10955 11055 11055 11305 11305 11555 11555 11805 0 11805 12305 30.0 12305 12805 12805 13305 0 13305 13805 25.0 20.0 15.0 10.0 5.0 0 27 5.0 10.0 15.0 20.0 25.0 .0.0 WElLDETAILS ANTI~COLUSION SEITINGS lnterpolationMe.tbodMD ln1erval: 25.000 Depth Range,From: 7477.205 To: 13639.475 MaximlUD Range; 10000.000Reference.: Plan: IE-105 Ll (wp02) +N/.S +BI-W 217.648 412.464 Northing 5959980.60 &.ting 55Q300.48 Latitude Longitude Slot 70018'05.162N 149""35'33.332W N/A 56 o o 270 o 18 LEGEND 1D-126 (1[)"126), Major JQsk 1[)..127 (1[)"127), MajOl~k ~~g:H~n:t~i:j~~sk 1&114(l&114L2),MajOlRisk 1&116 (lß.l'26}, Majl.\rRisk 1&126 (1&126L1),Major Risk 1&126 (1&I26LZ), Major Risk - Plan U-l6(i(U~\6(iLl),M:lljcrRisk. - Plan 11-66~J-I66L2J,MajorRisk - P1an11-166 11-166),MajorRisk -- PJan1!-170 JanlJ-14LatA),Maj('>rRisk - PIw.lE-10SLl - 1&105 Ll (wp02) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in] COMPANYDETAJLS ConocoPbiljp.s Alaska IDe.. Engìncering Alpine Calculation M~d: Minimum CUmdure· mar Sys:Im.: rSCWSA Scan MetJ)od: Trsv cylinder North w=:~= ~:~5~Casíng Sl1JI,VEYPROGRAM Dep"fIn>Depf>To~ 741?.2DS 13639.415 !'IaI:mð: JE-J05L) (wp02)VS WEli.PATH DBrAILS Pl=lE-¡O$U ~ hmnWåtpatJ: r~OXIMD, PbmlE-105PBI 7477.205 Rig Rt£IJid¡m; V.S«fioD - 1&10594.100ft ~!':.~ ~ lJ!.C'-OOO" 0.000 0.000 nOM From Colour 7477 10955 11055 11305 11555 11805 12305 12805 13305 ToM 10955 11055 11305 11555 11805 12305 12805 13305 13805 . 90 . Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15ft/in] SECTIONDBTAILS s~ MD "'" Azi TVD +N/-S +Ef-W Dr... "',~ VS~ r_ 7477.205 80.000 177.901 3553.000 ·853.016 5128.351 0.00 0.000 853.016 7493.705 81.244 177.901 3555.546 ·869.306 5128.948 13.60 0.000 869.306 7513.705 81.244 177.901 3558.245 -889.110 5129.674 0.00 0.000 889.110 7712.425 92.180 177.901 3567.899 -1087.213 5136.934 '.00 0.000 1087.213 7766.777 93.749 177.456 3565.088 -ll41.446 5139.133 3.00 ·15.794 1141.446 8203.431 93.749 177.456 3536.538 ~1576.736 5158.471 0.00 0.000 1576.736 8273.110 91.727 176.925 3533.210 -1646.249 5161.882 3.00 -165.28û 1646.249 9073.110 91.727 176.925 3509.100 .2444.734 5204.777 0.00 0.000 2444.734 lE-I05 L1 PtZ (vI) 9 9198.694 90.556 180.507 3506.597 -2570.239 5207.590 3.00 108.065 2570.239 10 10898.47Z 90.556 180.507 3490.100 -4269.870 5192.558 0.00 0.000 4269.871 1E-I05LlPt3(vl) 11 11063.715 85.601 180.363 3495.639 4434.964- 5191.305 3.00 _178.340 4434.964 12 11473.881 85.601 180.363 3527.100 4843.913 5188.715 0.00 0.000 4843.913 lE-l05Ll Pt4 (vi) 13 11788.775 95.048 180.391 3525.320 -5158.439 5186.646 3.00 0.170 5158.439 14 12075.413 95.048 180.391 3500.100 -5443.958 5184.697 0.00 0.000 5443.958 1&105 LlPt5(vl) l' 12210.355 90.999 180.381 3492.984 -5578.681 5183.789 3.00 ·t79.866 5578.681 1612375.683 90.999 180.38] 3490.100 .5743.98} 5182.689 0.00 0.000 5743.981 IE-I05Ll Pf6(vl) 17 12407.709 91.%0 180.384 3489.273 -5775.995 5182.475 3.00 0.134 5775.995 18 12675.880 91.960 180.384 3480.100 -6044.003 5180.680 0.00 0.000 6044.003 IE-I05LlPt7(vl) 19 12691.042 92.415 180.384 3479.521 -6059.154 5180,579 3,00 -0.015 6059.154 20 13199.393 92.415 180.384 3458.100 -6567.042 5177.178 0.00 0.000 6567.042 lE-105L1Pt8(Vl) 21 13262758 90.514 180.384 3456.481 -6630.381 5176.754 3.00 180.000 6630.381 22 13639.475 90.514 1110.384 3453.100 -7007.075 5174.232 0.00 0.000 7007.075 lE-to5 L1 Toe (v1) . . Halliburton Company Anticollision Report 7477.210 3553.001 13639.475 3453.100 9.625 4.500 12.250 8.500 95/8" 4 1/2" Plan: 1 E-1 05 L 1 (wp02) Date Composed: Version: Tied-to: 12112/2004 5 From: Definitive Path Principal: Yes Kuparuk 1 D Pad 10-126 1D-126 V2 9396.384 6325.000 960.273 232.659 727.614 Pass: Major Risk Kuparuk 1 D Pad 10-127 10-127 V2 11260.901 7300.000 812.884 325.045 487.839 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1E-114V1 Out of range Kuparuk 1 E Pad 1 E-114 1E-114L1V1 Out of range Kuparuk 1 E Pad 1 E-114 1 E-114L2 VO Out of range Kuparuk 1 E Pad 1 E-126 1 E-126 V1 8652.065 7175.000 1121.860251.852 870.007 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1 E-126L1 V1 11580.194 10050.000 1177.225 417.752 759.473 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126L2 V1 12366.270 10825.000 1233.007467.227 765.780 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L 1 V1 Plan: 1J- 13635.266 10800.000 1279.228404.066 875.162 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L2 V2 Plan: 1J- 13626.277 10800.000 1276.293408.522 867.771 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 V3 Plan: 1J-166 13628.26610825.000 1288.685411.702 876.983 Pass: Major Risk Kuparuk 1J Pad Plan 1J-170 Plan 1J-L4 LatA VO Out of range Site: Kuparuk 10 Pad Well: 10-126 Rule Assigned: Major Risk Wellpath: 1D-126V2 Inter-8ite Error: 0.000 ft 7890.674 3556.987 1325.000 1122.846 28.536 3.696 115.554 298.098 9.625 5179.391 131.090 5048.301 Pass 7898.579 3556.471 1350.000 1135.003 28.615 3.843 115.534 298.078 9.625 5155.740131.572 5024.169 Pass 7906.490 3555.953 1375.000 1146.724 28.697 3.989 115.520 298.064 9.625 5132.060 132.061 4999.999 Pass 7914.538 3555.427 1400.000 1158.140 28.781 4.131 115.509 298.053 9.625 5108.410132.553 4975.857 Pass 7922.780 3554.888 1425.000 1169.308 28.867 4.274 115.501 298.045 9.625 5084.819133.050 4951.768 Pass 793L214 3554.337 1450.000 1180.228 28.956 4.416 115.496 298.039 9:625 5061.290133.553·4927.737 Pass 7939.830 3553.773 1475.000 1190.920 29.046 4.554 115.492 298.036 9.625 5037.824134.058 4903.766 Pass 7948.563 3553.202 1500.000 1201.566 29.137 4.687 115.489 298.033 9.625 5014.400 134.563 4879.837 Pass 7957.397 3552.625 1525.000 1212.204 29.230 4.820 115.486 298.030 9.625 4991.014135.070 4855.945 Pass 7966.332 3552.041 1550.000 1222.835 29.323 4.953 115.483 298.026 9.625 4967.668 135.579 4832.088 Pass 7975.369 3551.450 1575.000 1233.458 29.418 5.085115.479 298.023 9.625 4944.360 136.091 4808.269 Pass 7984.506 3550.852 1600.000 1244.074 29.513 5.218115.475 298.019 9.625 4921.092136.606 4784.487 Pass 7993.743 3550.248 1625.000 1254.681 29.610 5.351 115.471 298.014 9.625 4897.865137.122 4760.742 Pass 8003.081 3549.638 1650.000 1265.279 29.709 5.484 115.466 298.010 9.625 4874.677137.645 4737.032 Pass 8012.486 3549.023 1675.000 1275.864 29.812 5.628 115.461 298.005 9.625 4851.517138.208 4713.309 Pass 8021.895 3548.408 1700.000 1286.426 29.915 5.775115.457 298.001 9.625 4828.358138.777 4689.581 Pass 8031.308 3547.792 1725.000 1296.965 30.019 5.922 115.453 297.997 9.625 4805.201 139.345 4665.855 Pass 8040.725 3547.176 1750.000 1307.480 30.122 6.069 115.449 297.993 9.625 4782.044139.913 4642.131 Pass 8050.145 3546.561 1775.000 1317.971 30.225 6.215 115.445 297.989 9.625 4758.889 140.481 4618.408 Pass 8059.569 3545.944 1800.000 1328.439 30.328 6.362 115.442 297.986 9.625 4735.735141.048 4594.687 Pass 8068.996 3545.328 1825.000 1338.883 30.431 6.509 115.439 297.983 9.625 4712.581 141.614 4570.967 Pass 8078.423 3544.712 1850.000 1349.306 30.535 6.654 115.436 297.980 9.625 4689.428 142.177 4547.251 Pass 8087.776 3544.100 1875.000 1359.737 30.637 6.794 115.434 297.977 9.625 4666.245142.727 4523.518 Pass ORIGJ~JèAL KRU 1 E..1 05L 1 Proposed Service West Sak nBn Sand 2050070 SFD 1/12/2005 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME )::J2K IE - /05 L ( PTD# Z05--DD7 V' Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUE ". APPLIES (OPTIONS) " MULTI The permit is .for !t... new weJlbore ·segment of t/ LA TERAL existing well K/Z,. . / E -. /0 S ¡, Permit No~~J No. §l;>-ðZ't- ?-324:.. (If API Dumber Production. sbould continue to be reponed as last two (2) digits a function 'of the original API number. stated are between 60-69) above. Pfi.¡OT HOLE ]n accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated "in both name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fun EXCEPTION compliance with 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex cep1ion. (Company Name) assumes the liability of any protest to tbe spacing .~xception that may occur. : DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater 1han 30' .. sample intervals from below tbe permafrost or from where samples are fint caught and ] 0' sample iIiter:vs)s through target zones. .. -Oõ Date: { \ s Geologic Commissioner: Engineering Commissioner: Date ~~~ 35 36 37 38 39 _S!:!abedconditioo survey CQnta_ct namelphone}or we!:!lsly prpgressreports [explor¡ltoryonlyt Appr SFD Date 1/12/2005 (if off-shore) _S!:!tsmic_analysjs_ Qf shaJlow gas_z_olles Geology P!:!rmit _D_ata_preseoted 011 pote_ntial oveJRressuœ _zOnes Meçhanic¡ll_cpoditton of wells wtthio J.\OR verified (Fpr_s_ervjce w!:! can be issued w!Q hYdrogen sulfide measures 31 32 33 34 onJy) Date 1/27/2005 M\ \ ";)., Appr TEM 22 23 24 25 26 27 28 29 30 Js presence Qf H2S gas_ probable test to (puJ psig in_comments) Choke manifold CQnJPJies w/API RF'-53 (May 64) WQrk will PCCur withput 9per¡ltjon _shutdown_ BOPEs,d_o _BQPE_press ratillg appropriate; they meet reguJatipo Jtdiverter required, dQes iLmeet reguJatipns_ Drillillg f]ujdprogram schematic & eCLuipJistadequ¡lte _Mequ<lte Jtare-drilt has_a to-403 fOJ <lbandonment be!:!o apprQved Agequ<lte well bore separ¡ltjon _proppse9 tan_kage or reserye pit _CMT will coyer_aU C_asillg designs ad_equate for Date 12 Permit administratilt'e_apprpvaJ 1/12/2005 13 Can permit be approved before 15-day wait 14 Well JQcated within area and_str¡ltaauthorized by Illjectipll Order # (put 10# 15 AJI we IJs_with in J l4rl1ile_are.a_of review jdelltified (FOr servjc_e well pnly) _ _ , -I;: _16 PJE~-prpduced injector; duration of pr!:!-pr09uctipn less than_ 3 months (For 17 ACMP_ F:ïndjng 9f Con_si$tency_ has been issued_ fpr this project - ~~- Engineering 18 _C_ondu_ctor st(ÌngprQv[ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 119swfaC!:!C¡lSingprotects alLknown USOWs _ 20CMT vol adequate_ to circ_ulate_o_ncpnductpr & surf csg 21 _CMT vol adequate_to tie-tn IQng _string to_surf csg_ Appr SFD C,T, B&permafrost J<oown -Pfo_ductive hQrizon_s - serviçe well onJy) hcommelltsJ-{For NA NA NA NA No Yes Yes NA Yes NA Yes Yes Yes Yes Yes No_ No_ No Yes NA NA NA KRU 10-123, I;xpected _1 D-J 26 and_ tDc 127 Je_ss th<lO r!:!servojr pre_ssuJe is _8.3 11ð, mile to e.ast -_8,6ppg EMW; wHl measured beJween _2 and be drilled wjth 9.0 ppg oilcbased_ mud. 2 ppm H2S in20Q4, Low lelt'el H2S in WS has Þeen Mud sho_uldprec!ude H2S on PœUmillary review pfAOR wells 90es not indicate any proþlems._ CPJ.\Uo prpvide. complete_AOR. report!:!d on E pad, rjg. Rig has sensors_and ¡I¡¡lrm MASP calculate_d at 1208 psi. CPAt plans tQ test_to 3000 psi. pro~imity- an<lly 1:1 BOP stacK will ~h_""'''J 1',_-_", BHP expected between 8.3 ~I"~~""\I -:-.0. :n plê¡;lc_e.. 8.6EMW- Plalll1ed MW 9.0 ppg in West SaK Only _close appro<lch is A_sand_ seçtjon _-j 10: tvd below. Rig js equipped_with steelpjts. No reseJIt'epjtplanlle.d. All w¡lste toan_apprOlt'ed _annu!usor Class well, _U_nique welt loc¡lted Operator _Oper_ator Permit bas_appropriate_ bond inJorce. co_nserva_tion order _S_ufficient Jfdeviated, jsweJlbQre pl¡ltjnclu_ded only- affected party Well Well Well <lcreage_ayail<lble IQc¡lted proper _distance_ located proper _distance_ from driJling unit bound_ary Administration 2 3 4 5 6 7 8 9 10 11 from other wells indrilJillg unjt KRU West SaJ<QjI Pool, governed by _C_onserv:ation Order W!:!IJ is more_ than 500 feet from an exteJnaJ prppe_rty line. No restrictiolls as_ to well in CO 4_06B SP<lCillg in_a define_dppol Lease number _appropri<lte n_ame _and oumb_er KUPARUK RIVER, WEST SAK OIL - 490150 can be issued wjthQut c_an be issued wjthQut Field & Pool ~C Initial ClasslType NA Yes .Yes Yes Yes Yes Yes Yes Yes .Yes Yes Yes Yes Yes Yes Yes NA Con_ductor_setin mptherÞore, tEctO~ M aquifers exempted ð,O cm j 47. tv, Surface castng inst<llJed in 1 E-1 05, . Intermediate. casing installed jn t~ 1 05. SlpttedJinercompleUon ptallne9. Intermediate casi.ng çement pl¡lnned ¡lbo_ve ¡lny!aJlhydrocarbons. J.\rea Injeçtjo_nQrde.r Np..2B E-126_& La_terals,JE:1J4 B<_L¡lterals, '''~(b)(3), 1E-1~8_& Late.r~ls, ~ J E:33, lD.-123,10-126, 0-127 --- SER Well Name: KUPARUJ I &K PEND GeoArea ~ " , Multilat!:!r.at we.ll.segme.nt; J"~ ,', 'J' ,..... .: interval in API.. 025651 TQPprQd_uctive No, 4Q6B 11160 - '",.. '~'?"I"'" Der20 MC .25.005(e) TO in ADL0256_60. E-105L 1 Unit Program SER On/Off Shore On Well bore seg Annular Disposal ~ o . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . Sperry-Sun Drilling Services LIS Scan Utility J 34 r;¿7 $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 14 10:20:08 2005 ;}05- OC-7 Reel Header Service name............ .LISTPE Date.................... .05/11/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .05/11/14 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . ... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-105 L1 500292324360 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-NOV-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 MW0003677560 E. QUAM D. GLADDEN MWD RUN 5 MW0003677560 J. MARTIN M. THORNTON MWDRUN 6 MW0003677560 J. MARTIN M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003677560 J. MARTIN M. THORNTON MWD RUN 8 MW0003677560 J. MARTIN M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 391 224 MSL 0) 93.58 66.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 CASING SIZE (IN) 13.375 9.625 DRILLERS DEPTH (FT) 3905.0 7524.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE . . NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE 1E-105 PB2 WELLBORE AT 7524'MD/3583'TVD, BY MEANS OF A WHIPSTOCK. 4. MWD RUN 1 (COMPRISING 1E-105 PB1) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED 5. MWD RUNS 2,6,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 6 - 8 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) , AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). NO VALID SEXP DATA WERE ACQUIRED DURING MWD RUN 2 DUE TO TOOL PROBLEMS. THE PURPOSE OF MWD RUN 5 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED. MISSING CTN DATA WITHIN THE MWD RUN 8 INTERVAL ARE DUE TO TOOL PROBLEMS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,5-8 REPRESENT WELL 1E-105 L1 WITH API#:50-029-23243-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13529'MD/3479'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) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST LITHOLOGY, VARIABLE HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.0 - 9.15 PPG MUD SALINITY: 35,000 - 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 11,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE . $ . File Header Service name.... ... ..... .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type............. ...LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 7515.0 7515.0 7515.0 7524.0 7524.0 7524.0 7524.5 STOP DEPTH 13494.0 13486.5 13486.5 13486.5 13486.5 13529.0 13440.0 13440.0 13440.0 13454.0 13454.0 13454.0 13486.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 2 5 6 7 8 MERGED MAIN PASS. $ MERGE TOP 3862.0 7524.5 7564.5 11976.0 12170.0 MERGE BASE 7524.0 7564.5 11976.0 12170.0 13529.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record... ......... .Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 . . RHOB MWD DRHO MWD PEF MWD G/CM G/CM BARN 4 4 4 1 68 1 68 1 68 44 48 52 12 13 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 13529 8695.5 19335 3862 13529 ROP MWD FT/H 0.06 708.42 165.947 19003 4028 13529 GR MWD API 23.76 172.01 67.7339 19265 3862 13494 RPX MWD OHMM 4.33 1691.18 34.7143 11899 7524.5 13486.5 RPS MWD OHMM 2.71 2000 27.6779 19214 3880 13486.5 RPM MWD OHMM 4.13 2000 30.3098 19214 3880 13486.5 RPD MWD OHMM 0.13 2000 32.2292 19214 3880 13486.5 FET MWD HOUR 0.18 304.63 2.58645 19214 3880 13486.5 NPHI MWD PU-S -1.03 53.64 37.9839 11063 7515 13440 FCNT MWD CNTS 651 29030 1020.34 11064 7515 13440 NCNT MWD CNTS 117810 210090 138687 11064 7515 13440 RHOB MWD G/CM 0.358 3.084 2.19046 11861 7524 13454 DRHO MWD G/CM -3.812 0.252 0.0352608 11861 7524 13454 PEF MWD BARN 0.96 17.34 2.19379 11861 7524 13454 First Reading For Entire File......... .3862 Last Reading For Entire File......... ..13529 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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...... .05/11/14 Maximum Physical Record. .65535 File Type................ LO Previous File Name... ....STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPM RPD FET ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 STOP DEPTH 7524.0 7524.0 7524.0 7524.0 7524.0 7524.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 09-MAY-05 Insite 66.37 Memory 7524.0 4027.0 . BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units.... ...... .Feet Data Reference Point............. . Undefined Frame Spacing............... ......60 .1IN Max frames per record............ . Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 7524.0 63.4 81. 5 TOOL NUMBER 126027 116184 12.250 3905.0 LSND 9.00 74.0 9.0 350 4.1 3.500 2.420 5.000 6.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPM MWD020 OHMM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 Name DEPT ROP GR RPS RPM RPD FET Service Unit FT MWD020 FT/H MWD020 API MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 HOUR Max 7524 708.42 172.01 2000 2000 2000 93.81 Min 3862 3.04 23.76 2.71 4.49 0.13 0.18 First Reading For Entire File......... .3862 Last Reading For Entire File........ ...7524 Mean 5693 180.935 71.3178 13.0666 14.66 15.2365 4.63009 Nsam 7325 6993 7325 7289 7289 7289 7289 . 68.0 101. 2 68.0 68.0 First Reading 3862 4028 3862 3880 3880 3880 3880 Last Reading 7524 7524 7524 7524 7524 7524 7524 . File Trailer Service name....... ..... .STSLIB.002 service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name... ....... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 . header data for each bit run in separate files. 5 .5000 START DEPTH 7524.5 STOP DEPTH 7564.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 20-MAY-05 Insite 66.37 Memory 7565.0 7524.0 7565.0 .0 81. 5 TOOL NUMBER 124725 8.500 7524.0 Oil Based 9.00 87.0 .0 61500 2.8 .000 .000 .000 .000 .0 105.8 .0 .0 . # HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..............0 Data Specification Block Type.....O Logging Direction........ .........Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value......... ............ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 Name Service Unit DEPT FT ROP MWD050 FT/H Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Min 7524.5 0.06 Max 7564.5 67.54 Mean 7544.5 15.9277 First Reading For Entire File. ....... ..7524.5 Last Reading For Entire File..... ..... .7564.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB FET RPD 4 Nsam 81 81 . First Reading 7524.5 7524.5 Last Reading 7564.5 7564.5 header data for each bit run in separate files. 6 .5000 START DEPTH 7515.0 7515.0 7515.0 7524.0 7524.0 7524.0 7524.5 7524.5 STOP DEPTH 11884.5 11884.5 11884.5 11898.5 11898.5 11898.5 11931.0 11931.0 . RPM RPS RPX GR ROP $ 7524.5 7524.5 7524.5 7524.5 7565.0 11931.0 11931.0 11931.0 11938.5 11976.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point. ............ . Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ . Undefined Absent value............. ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 24-MAY-05 Insite 68.18 Memory 11976.0 7565.0 11976.0 84.8 98.1 TOOL NUMBER 124725 105242 185457 10507555 8.500 7524.0 oil Based 9.00 110.0 .0 32800 3.1 .000 .000 .000 .000 .0 152.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 . . RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7515 11976 9745.5 8923 7515 11976 ROP MWD060 FT/H 0.32 248.97 154.104 8823 7565 11976 GR MWD060 API 39.27 106.23 66.2216 8829 7524.5 11938.5 RPX MWD060 OHMM 4.33 1691.18 34.4305 8814 7524.5 11931 RPS MWD060 OHMM 4.28 1932.37 36.3663 8814 7524.5 11931 RPM MWD060 OHMM 4.13 1757.86 39.8303 8814 7524.5 11931 RPD MWD060 OHMM 4.35 1726.16 42.8007 8814 7524.5 11931 FET MWD060 HOUR 0.21 304.63 1.08897 8814 7524.5 11931 NPHI MWD060 PU-S 7.48 50.28 37.8802 8740 7515 11884.5 FCNT MWD060 CNTS 651 4601 989.268 8740 7515 11884.5 NCNT MWD060 CNTS 117810 210090 138264 8740 7515 11884.5 RHOB MWD060 G/CM 0.358 3.084 2.18269 8750 7524 11898.5 DRHO MWD060 G/CM -3.812 0.251 0.0296942 8750 7524 11898.5 PEF MWD060 BARN 1. 44 17.34 2.21518 8750 7524 11898.5 First Reading For Entire File... ..... ..7515 Last Reading For Entire File.. ........ .11976 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/11/14 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name....... ... .STSLIB.005 physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .....05/11/14 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name.. .... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF DRHO RHOB RPD RPX RPS RPM FET 5 header data for each bit run in separate files. 7 .5000 START DEPTH 11885.0 11885.0 11885.0 11899.0 11899.0 11899.0 11931.5 11931.5 11931.5 11931.5 11931.5 STOP DEPTH 12082.0 12082.0 12082.0 12095.5 12095.5 12095.5 12128.0 12128.0 12128.0 12128.0 12128.0 . GR ROP $ 11939.0 11976.5 12135.5 12170.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 24-MAY-05 Insite 68.18 Memory 12170.0 11976.0 12170.0 90.2 91. 9 TOOL NUMBER 124725 105242 185457 10507555 8.500 7524.0 oil Based 9.00 98.0 .0 34500 3.6 .000 .000 .000 .000 .0 132.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 NPHI MWD070 PU-S 4 1 68 32 9 . FCNT NCNT RHOB DRHO PEF CNTS CNTS G/CM G/CM BARN 4 4 4 4 4 MWD070 MWD070 MWD070 MWD070 MWD070 . 1 1 1 1 1 36 40 44 48 52 10 11 12 13 14 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11885 12170 12027.5 571 11885 12170 ROP MWD070 FT/H 6.45 238.01 167.599 388 11976.5 12170 GR MWD070 API 42.08 68.42 55.9339 394 11939 12135.5 RPX MWD070 OHMM 48.05 88.73 63.9035 394 11931.5 12128 RPS MWD070 OHMM 49.81 85.03 67.4564 394 11931.5 12128 RPM MWD070 OHMM 51. 39 83.1 71.1114 394 11931. 5 12128 RPD MWD070 OHMM 52.21 85.35 71.4469 394 11931.5 12128 FET MWD070 HOUR 0.22 24.98 6.46601 394 11931.5 12128 NPHI MWD070 PU-S 23.88 45.33 41.0295 395 11885 12082 FCNT MWD070 CNTS 773 1488 901.749 395 11885 12082 NCNT MWD070 CNTS 127462 147788 134820 395 11885 12082 RHOB MWD070 G/CM 2.049 2.625 2.11308 394 11899 12095.5 DRHO MWD070 G/CM 0.007 0.22 0.0416218 394 11899 12095.5 PEF MWD070 BARN 1. 61 3.47 2.03294 394 11899 12095.5 First Reading For Entire File......... .11885 Last Reading For Entire File......... ..12170 File Trailer Service name...... .......STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name........ .....STSLIB.006 service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF RHOB DRHO FCNT NCNT NPHI RPM RPS RPD FET RPX GR ROP $ 6 header data for each bit run in separate files. 8 .5000 START DEPTH 12096.0 12096.0 12096.0 12127.5 12127.5 12128.0 12128.5 12128.5 12128.5 12128.5 12128.5 12136.0 12170.5 STOP DEPTH 13454.0 13454.0 13454.0 13440.0 13440.0 13440.0 13486.5 13486.5 13486.5 13486.5 13486.5 13494.0 13529.0 . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value...... ............... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 27-MAY-05 Insite 68.18 Memory 13529.0 12170.0 13529.0 88.8 94.3 TOOL NUMBER 124725 105242 179954 10640599 8.500 7524.0 oil Based 9.00 98.0 .0 34500 3.6 .000 .000 .000 .000 .0 149.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWD080 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 . . DRHO MWD080 G/CM 4 1 68 48 13 PEF MWD080 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12096 13529 12812.5 2867 12096 13529 ROP MWD080 FT/H 0.72 284.95 170.066 2718 12170.5 13529 GR MWD080 API 41.56 88.72 64.6969 2717 12136 13494 RPX MWD080 OHMM 10.93 84.95 31.3704 2691 12128.5 13486.5 RPS MWD080 OHMM 11.91 136.96 32.9223 2717 12128.5 13486.5 RPM MWD080 OHMM 12.93 370.31 35.4927 2717 12128.5 13486.5 RPD MWD080 OHMM 13.79 152.07 37.835 2717 12128.5 13486.5 FET MWD080 HOUR 0.18 20.71 1.39918 2717 12128.5 13486.5 NPHI MWD080 PU-S -1.03 53.64 37.8299 1928 12128 13440 FCNT MWD080 CNTS 738 29030 1185.44 1929 12127.5 13440 NCNT MWD080 CNTS 130187 206462 141395 1929 12127.5 13440 RHOB MWD080 G/CM 2.032 2.721 2.22668 2717 12096 13454 DRHO MWD080 G/CM -0.113 0.252 0.0522654 2717 12096 13454 PEF MWD080 BARN 0.96 6.39 2.14823 2717 12096 13454 First Reading For Entire File......... .12096 Last Reading For Entire File. ... .......13529 File Trailer Service name........... ..STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/11/14 Origin..... ............. .STS Tape Name......... ...... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date........ ............ .05/11/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File