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205-145
1. 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 11472'feet 9200'feet true vertical 3613' feet None feet Effective Depth measured 9200'feet 4185' feet true vertical 3577' feet 3424' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3435' TVD Packers and SSSV (type, measured and true vertical depth) 4185' MD 4187' MD 4703' MD N/A 3424' TVD 3424' TVD 3533' TVD N/A 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: 2333' 2204' Burst Collapse B Liner LEM Liner 5331' 403' Casing 3656' 3543' 5358' 4748' 2303' 108'Conductor Surface Intermediate 20" 10-3/4" 78' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 50-029-23278-60-00 205-145 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: ADL0025650, ADL0025661 Kuparuk River Oil Field/ West Sak Oil Pool KRU 1J-164L1 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. 12. Stimulation or cement squeeze summary: Intervals treated (measured): RPPG pumped down Injector 1J-164 L1, see details in events. Treatment descriptions including volumes used and final pressure: Packer: Baker SBE Seal Assembly Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com 265-6471Staff Well Interventions Engineer Alternating Slotted pipe: 4661-11389', Perfs 5097-5102', 9132-9137' Alternating Slotted Pipe: 3520-3610', Perfs 3525-3525', 3581-3581' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 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: 2025.08.20 11:26:58-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne By Grace Christianson at 3:14 pm, Aug 20, 2025 J.Lau 11/4/25 RBDMS JSB 082525 DSR-9/11/25 DTTMSTART JOBTYP SUMMARYOPS 7/25/2025 REPAIR WELL RIH WITH MOTOR AND 3.8" JUNK MILL. TAG ICE AT 22'. BREAK THROUGH ICE AT 60'. FREEZE PROTECT WELL WITH 45 BBL DIESEL AND DRIFT TO 4000'. PERFORM WEEKLY BOP TEST. 7/26/2025 REPAIR WELL PUMP FULL BORE RRPG TO MBE IN B SAND LATERAL AT 7320' RKB. PUMPED 27161 LBS OF DAQING RPPG PRODUCT AT 1.375 PPG FOR 132 BBL, PSI FLAT LINE INCREASE TO 1.5 PPG FOR 116 BBL PSI INCREASE SLIGHTLY, INCREASE TO 1.8 PPG FOR 118 BBLS STEADY PSI INCREASE, FLUSH CALLED AT 1195 PSI, 656 JSV. STEADY INCREASE TO MAX PSI 1300. TOTAL JSV 734 BBL. WELL TO REMAIN SHUT FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1J-164/ 1J-166 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-164 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164 10/17/2023 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND(1J-164), B-SAND (1J-164-L1), D-SAND (1J-164-L2) 12/7/2005 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 CONDUCTOR Insulated 20 19.12 30.0 108.0 108.0 91.50 H-40 WELDED SURFACE 10 3/4 9.95 29.6 2,332.8 2,204.1 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.88 27.3 5,358.0 3,656.4 29.70 L-80 BTC-M D-SAND WINDOW 7 5.63 4,248.0 4,258.0 3,445.4 12.60 L-80 IBTM B-SAND WINDOW 7 5.63 4,594.0 4,604.0 3,513.2 12.60 L-80 IBTM B LINER LEM 4 1/2 3.96 4,345.8 4,748.5 3,543.0 12.60 L-80 A-SAND LINER 4 1/2 3.96 4,702.9 11,400.0 3,745.4 12.60 L-80 IBT D LINER LEM 4 1/2 3.96 4,187.1 4,375.0 3,474.9 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.2 Set Depth … 4,221.8 Set Depth … 3,434.7 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) 22.2 22.2 0.00 HANGER 11.000 VETCO GRAY TUBING HANGER 4.500 474.9 474.9 0.86 NIPPLE 5.210 CAMCO 'DB-6' NO GO NIPPLE w/3.875" PROFILE 3.875 2,336.4 2,207.3 26.03 GAS LIFT 5.984 9:00 Mandrel Orientation CAMCO KBG-2 3.938 3,902.6 3,335.7 69.45 GAS LIFT 5.984 1:00 Mandrel Orientation CAMCO KBG-2 3.938 4,137.9 3,409.4 72.21 SLEEVE-C 5.480 CMU SLIDING SLEEVE w/3.81" PROFILE (CLSD 12/23/2005) Baker 3.812 4,183.2 3,423.2 72.46 LOCATOR 5.520 BAKER LOCATOR 3.875 4,184.9 3,423.7 72.46 SEAL ASSY 4.740 BAKER SBE SEAL ASSEMBLY 3.875 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) 4,240.0 3,440.1 72.81 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM (OAL=18.5 FT) 10/16/2023 2.590 4,580.0 3,509.1 80.28 DIVERTER TYPE-I DIVERTER SET IN B- SAND LEM (OAL=18.5 FT) 10/16/2023 3.100 4,667.0 3,525.1 78.10 DB PLUG 3" GS PROFILE DB PLUG/PRONG (PRONG 2.72" OD X 8.20', TOP OF = 4662' MD) SET IN DB-6 NIPPLE 8/5/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,336.4 2,207.3 26.03 1 GAS LIFT DMY BK-5 1 3/24/2006 9:00 CAMCO KBG-2 0.000 3,902.6 3,335.7 69.45 2 GAS LIFT DMY BK-5 1 3/24/2006 1:00 CAMCO KBG-2 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) 4,187.1 3,424.3 72.48 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,206.0 3,430.0 72.58 SBR 6.280 190-47 CASING SEAL BORE RECEPTACLE 4.750 4,225.7 3,435.9 72.68 XO BUSHING 6.020 CROSSOVER BUSHING 3.930 4,229.1 3,436.9 72.70 SWIVEL 5.750 CASING SWIVEL 3.920 4,345.8 3,468.4 76.44 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,364.7 3,472.7 77.43 SBR 6.260 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,384.3 3,476.8 78.45 XO BUSHING 6.040 XO BUSHING 3.880 4,670.1 3,525.8 78.00 NIPPLE 5.000 CAMCO 'DB-6' NIPPLE 3.563 4,702.9 3,532.9 76.96 PACKER 6.550 'HRD' ZXP LINER TOP PACKER 4.960 4,722.0 3,537.2 77.11 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.880 4,754.4 3,544.3 77.40 XO BUSHING 6.020 XO BUSHING 3.920 8,555.6 3,695.3 88.94 SWELL PKR 6.300 3.960 9,072.3 3,706.6 94.07 SWELL PKR 6.300 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,399.0 5,430.0 3,662.4 3,666.7 WS A2, 1J-164 11/12/2005 32.0 SLOTS ALL A-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,586.0 5,710.0 3,687.9 3,697.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 8/11/2025 2:26:01 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164 ... TD Act Btm (ftKB) 11,400.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327800 Wellbore Status INJ Max Angle & MD Incl (°) 94.67 MD (ftKB) 9,091.14 WELLNAME WELLBORE1J-164 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 5,802.0 6,049.0 3,697.2 3,687.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 6,384.0 6,846.0 3,671.9 3,673.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 7,524.0 7,774.0 3,697.9 3,696.5 WS A2, 1J-164 11/12/2005 32.0 SLOTS 8,144.0 8,545.0 3,685.7 3,695.1 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,087.0 9,427.0 3,705.5 3,685.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,705.0 9,766.0 3,676.6 3,673.6 WS A2, 1J-164 11/12/2005 32.0 SLOTS 10,286.0 10,592.0 3,692.2 3,706.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 11,179.0 11,365.0 3,730.7 3,743.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 8/11/2025 2:26:02 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ 1J-164 ... WELLNAME WELLBORE1J-164 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:8,189.0 1J-164L1 4/19/2018 raffep Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L1 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-164L2) 12/4/2005 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 4 1/2 3.96 4,587.4 11,452.0 3,612.0 12.60 L-80 IBT 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) 8,226.0 3,553.1 88.48 CMT Retainer BAKER INFLATABLE CEMENT RETAINER - MID ELEMENT 8231' 11/2/2010 0.000 9,000.0 3,585.9 89.63 CMT Retainer BAKER INFLATABLE CEMENT RETAINER SET IN L1 LINER (OAL=2.5"x9.4') 8/6/2009 0.000 9,200.0 3,576.9 93.95 PLUG B-SAND BAKER IBP (2.125" x 10.53) 1/26/2008 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) 4,612.3 3,514.4 81.67 SWIVEL 5.750 Baker Casing Swivel 3.960 8,803.4 3,576.0 87.05 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 9,462.5 3,555.3 94.72 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 11,420.1 3,611.1 88.35 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,661.0 5,127.0 3,519.8 3,526.0 WS B, 1J-164L1 11/19/2005 32.0 SLOTS ALL B-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,097.0 5,102.0 3,524.7 3,524.9 WS B, 1J-164L1 7/6/2021 6.0 APERF ADDED PERFORATION FOR RPPG MBE TREATMENT. 5,399.0 5,862.0 3,531.3 3,526.6 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,140.0 6,605.0 3,529.1 3,528.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,884.0 7,283.0 3,528.1 3,531.2 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 7,562.0 8,148.0 3,538.0 3,551.9 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,300.0 8,794.0 3,555.9 3,575.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,550.0 9,555.0 3,565.9 3,548.4 WS B, 1J-164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG PERFS, BH CHARGES, 31 CHARGES 9,132.0 9,137.0 3,581.4 3,581.1 WS B, 1J-164L1 8/4/2009 6.0 PERF CT Perfs, 60 degree phase pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,035.0 10,591.0 3,548.2 3,578.7 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,927.0 11,389.0 3,593.5 3,610.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,200.0 9,400.0 3,552.5 3,560.8 CMT SQZ 28 BBLS Ultra Lite Crete pumped below retainer & .75 BBLS on top of ICR 1J-164L1, 8/11/2025 2:26:02 PM Vertical schematic (actual) B-SAND LINER; 4,587.4- 11,452.0 SLOTS; 10,927.0-11,389.0 SLOTS; 10,035.0-10,591.0 SLOTS; 9,477.0-9,786.0 PLUG; 9,200.0 PERF; 9,132.0-9,137.0 SQZ; 8,550.0-9,555.0 CMT Retainer; 9,000.0 SLOTS; 8,300.0-8,794.0 CMT Retainer; 8,226.0 CMT SQZ; 8,200.0 ftKB SLOTS; 7,562.0-8,148.0 SLOTS; 6,884.0-7,283.0 SLOTS; 6,140.0-6,605.0 SLOTS; 5,399.0-5,862.0 APERF; 5,097.0-5,102.0 SLOTS; 4,661.0-5,127.0 B LINER LEM; 4,345.8-4,748.5 INTERMEDIATE; 27.3-5,358.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164L1 ... TD Act Btm (ftKB) 11,472.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327860 Wellbore Status INJ Max Angle & MD Incl (°) 95.29 MD (ftKB) 9,395.80 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-164L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L2 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-154L2) 12/4/2005 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 D-SAND LINER 4 1/2 3.96 4,246.5 11,502.6 3,561.2 12.60 L-80 IBT 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) 4,271.4 3,449.0 74.58 SWIVEL 5.750 BAKER CASING SWIVEL 3.950 8,638.1 3,502.2 94.30 SWELL PKR 6.300 SWELL PACKER 3.960 9,158.4 3,476.8 92.53 SWELL PKR 6.300 SWELL PACKER 3.960 11,470.9 3,560.6 88.96 XO 4.500 4-1/2" X 3-1/2" XO sub 3.450 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,285.0 4,408.0 3,452.5 3,476.0 WS D, 1J-164L2 12/4/2005 32.0 SLOTS ALL D-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,719.0 5,306.0 3,479.9 3,471.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 5,582.0 6,133.0 3,466.3 3,473.7 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 6,412.0 6,964.0 3,470.6 3,466.8 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 7,244.0 7,824.0 3,476.3 3,495.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 8,103.0 8,629.0 3,499.5 3,502.9 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 9,183.0 9,739.0 3,475.8 3,488.1 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,018.0 10,606.0 3,499.6 3,521.3 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,883.0 11,470.0 3,532.8 3,560.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 1J-164L2, 8/11/2025 2:26:03 PM Vertical schematic (actual) D-SAND LINER; 4,246.6- 11,502.6 SLOTS; 10,883.0-11,470.0 SLOTS; 10,018.0-10,606.0 SLOTS; 9,183.0-9,739.0 SLOTS; 8,103.0-8,629.0 SLOTS; 7,244.0-7,824.0 SLOTS; 6,412.0-6,964.0 SLOTS; 5,582.0-6,133.0 SLOTS; 4,719.0-5,306.0 SLOTS; 4,285.0-4,408.0 INTERMEDIATE; 27.3-5,358.0 D LINER LEM; 4,187.1-4,375.0 ISO SLEEVE; 4,240.0 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164L2 ... TD Act Btm (ftKB) 11,524.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327861 Wellbore Status INJ Max Angle & MD Incl (°) 94.86 MD (ftKB) 4,717.59 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1. 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 11472'feet 9200'feet true vertical 3613' feet None feet Effective Depth measured 9200'feet 4185' feet true vertical 3577' feet 3424' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3435' TVD Packers and SSSV (type, measured and true vertical depth) 4185' MD 4187' MD 4703' MD N/A 3424' TVD 3424' TVD 3533' TVD 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: 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. Packer: Baker SBE Seal Assembly Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com 265-6471Staff Well Interventions Engineer Alternating Slotted pipe: 4661-11389', Perfs 5097-5102', 9132-9137' Alternating Slotted Pipe: 3520-3610', Perfs 3525-3525', 3581-3581' 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 ~~ ~ measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 50-029-23278-60-00 205-145 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: ADL0025650, ADL0025661 Kuparuk River Oil Field/ West Sak Oil Pool KRU 1J-164L1 Plugs Junk measured Length B Liner LEM Liner 5331' 403' Casing 3656' 3543' 5358' 4748' 2303' 108'Conductor Surface Intermediate 20" 10-3/4" 78' 2333' 2204' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 6864 lbs RPPG pumped into the B lateral 12. Stimulation or cement squeeze summary: Intervals treated (measured):MBE @ 7320' in the B lateral Treatment descriptions including volumes used and final pressure: By Grace Christianson at 12:35 pm, Dec 23, 2024 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.12.23 12:06:48-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DSR-1/8/25 RBDMS JSB 122624 VTL 9/8/2025 DTTMSTART JOBTYP SUMMARYOPS 11/27/2024 REPAIR WELL RIG UP TO PUMP RPPG TREATMENT. DELAYS FROM TROUBLESHOOTING SUPPORT EQUIPMENT, PRODUCT QUALITY CONCERNS, LEAKY TREE VALVES AND ICE PLUGS RESULTED IN CREW HOURING OUT. WILL RETURN IN THE AM. JOB IN PROGRESS. 11/28/2024 REPAIR WELL PUMPED FULLBORE RPPG TREATMENT TO MBE @7320' RKB IN THE B LATERAL. PUMPED 6864 LBS OF RPPG. CALLED FLUSH AT 676 PSI. STEADY PRESSURE INCREASE WHILE PUMPING. FINAL WHP=900 PSI, TARGET WAS ~1000 PSI. WELL TO REMAIN SHUT IN FOR 48 HRS. 1J-164L1 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-164 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164 10/17/2023 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND(1J-164), B-SAND (1J-164-L1), D-SAND (1J-164-L2) 12/7/2005 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 CONDUCTOR Insulated 20 19.12 30.0 108.0 108.0 91.50 H-40 WELDED SURFACE 10 3/4 9.95 29.6 2,332.8 2,204.1 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.88 27.3 5,358.0 3,656.4 29.70 L-80 BTC-M D-SAND WINDOW 7 5.63 4,248.0 4,258.0 3,445.4 12.60 L-80 IBTM B-SAND WINDOW 7 5.63 4,594.0 4,604.0 3,513.2 12.60 L-80 IBTM B LINER LEM 4 1/2 3.96 4,345.8 4,748.5 3,543.0 12.60 L-80 A-SAND LINER 4 1/2 3.96 4,702.9 11,400.0 3,745.4 12.60 L-80 IBT D LINER LEM 4 1/2 3.96 4,187.1 4,375.0 3,474.9 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.2 Set Depth … 4,221.8 Set Depth … 3,434.7 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) 22.2 22.2 0.00 HANGER 11.000 VETCO GRAY TUBING HANGER 4.500 474.9 474.9 0.86 NIPPLE 5.210 CAMCO 'DB-6' NO GO NIPPLE w/3.875" PROFILE 3.875 2,336.4 2,207.3 26.03 GAS LIFT 5.984 9:00 Mandrel Orientation CAMCO KBG-2 3.938 3,902.6 3,335.7 69.45 GAS LIFT 5.984 1:00 Mandrel Orientation CAMCO KBG-2 3.938 4,137.9 3,409.4 72.21 SLEEVE-C 5.480 CMU SLIDING SLEEVE w/3.81" PROFILE (CLSD 12/23/2005) Baker 3.812 4,183.2 3,423.2 72.46 LOCATOR 5.520 BAKER LOCATOR 3.875 4,184.9 3,423.7 72.46 SEAL ASSY 4.740 BAKER SBE SEAL ASSEMBLY 3.875 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) 4,240.0 3,440.1 72.81 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM (OAL=18.5 FT) 10/16/2023 2.590 4,580.0 3,509.1 80.28 DIVERTER TYPE-I DIVERTER SET IN B- SAND LEM (OAL=18.5 FT) 10/16/2023 3.100 4,667.0 3,525.1 78.10 DB PLUG 3" GS PROFILE DB PLUG/PRONG (PRONG 2.72" OD X 8.20', TOP OF = 4662' MD) SET IN DB-6 NIPPLE 8/5/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,336.4 2,207.3 26.03 1 GAS LIFT DMY BK-5 1 3/24/2006 9:00 CAMCO KBG-2 0.000 3,902.6 3,335.7 69.45 2 GAS LIFT DMY BK-5 1 3/24/2006 1:00 CAMCO KBG-2 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) 4,187.1 3,424.3 72.48 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,206.0 3,430.0 72.58 SBR 6.280 190-47 CASING SEAL BORE RECEPTACLE 4.750 4,225.7 3,435.9 72.68 XO BUSHING 6.020 CROSSOVER BUSHING 3.930 4,229.1 3,436.9 72.70 SWIVEL 5.750 CASING SWIVEL 3.920 4,345.8 3,468.4 76.44 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,364.7 3,472.7 77.43 SBR 6.260 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,384.3 3,476.8 78.45 XO BUSHING 6.040 XO BUSHING 3.880 4,670.1 3,525.8 78.00 NIPPLE 5.000 CAMCO 'DB-6' NIPPLE 3.563 4,702.9 3,532.9 76.96 PACKER 6.550 'HRD' ZXP LINER TOP PACKER 4.960 4,722.0 3,537.2 77.11 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.880 4,754.4 3,544.3 77.40 XO BUSHING 6.020 XO BUSHING 3.920 8,555.6 3,695.3 88.94 SWELL PKR 6.300 3.960 9,072.3 3,706.6 94.07 SWELL PKR 6.300 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,399.0 5,430.0 3,662.4 3,666.7 WS A2, 1J-164 11/12/2005 32.0 SLOTS ALL A-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,586.0 5,710.0 3,687.9 3,697.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 12/19/2024 2:58:51 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164 ... TD Act Btm (ftKB) 11,400.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327800 Wellbore Status INJ Max Angle & MD Incl (°) 94.67 MD (ftKB) 9,091.14 WELLNAME WELLBORE1J-164 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 5,802.0 6,049.0 3,697.2 3,687.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 6,384.0 6,846.0 3,671.9 3,673.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 7,524.0 7,774.0 3,697.9 3,696.5 WS A2, 1J-164 11/12/2005 32.0 SLOTS 8,144.0 8,545.0 3,685.7 3,695.1 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,087.0 9,427.0 3,705.5 3,685.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,705.0 9,766.0 3,676.6 3,673.6 WS A2, 1J-164 11/12/2005 32.0 SLOTS 10,286.0 10,592.0 3,692.2 3,706.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 11,179.0 11,365.0 3,730.7 3,743.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 12/19/2024 2:58:53 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ 1J-164 ... WELLNAME WELLBORE1J-164 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:8,189.0 1J-164L1 4/19/2018 raffep Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L1 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-164L2) 12/4/2005 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 4 1/2 3.96 4,587.4 11,452.0 3,612.0 12.60 L-80 IBT 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) 8,226.0 3,553.1 88.48 CMT Retainer BAKER INFLATABLE CEMENT RETAINER - MID ELEMENT 8231' 11/2/2010 0.000 9,000.0 3,585.9 89.63 CMT Retainer BAKER INFLATABLE CEMENT RETAINER SET IN L1 LINER (OAL=2.5"x9.4') 8/6/2009 0.000 9,200.0 3,576.9 93.95 PLUG B-SAND BAKER IBP (2.125" x 10.53) 1/26/2008 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) 4,612.3 3,514.4 81.67 SWIVEL 5.750 Baker Casing Swivel 3.960 8,803.4 3,576.0 87.05 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 9,462.5 3,555.3 94.72 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 11,420.1 3,611.1 88.35 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,661.0 5,127.0 3,519.8 3,526.0 WS B, 1J-164L1 11/19/2005 32.0 SLOTS ALL B-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,097.0 5,102.0 3,524.7 3,524.9 WS B, 1J-164L1 7/6/2021 6.0 APERF ADDED PERFORATION FOR RPPG MBE TREATMENT. 5,399.0 5,862.0 3,531.3 3,526.6 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,140.0 6,605.0 3,529.1 3,528.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,884.0 7,283.0 3,528.1 3,531.2 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 7,562.0 8,148.0 3,538.0 3,551.9 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,300.0 8,794.0 3,555.9 3,575.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,550.0 9,555.0 3,565.9 3,548.4 WS B, 1J-164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG PERFS, BH CHARGES, 31 CHARGES 9,132.0 9,137.0 3,581.4 3,581.1 WS B, 1J-164L1 8/4/2009 6.0 PERF CT Perfs, 60 degree phase pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,035.0 10,591.0 3,548.2 3,578.7 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,927.0 11,389.0 3,593.5 3,610.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,200.0 9,400.0 3,552.5 3,560.8 CMT SQZ 28 BBLS Ultra Lite Crete pumped below retainer & .75 BBLS on top of ICR 1J-164L1, 12/19/2024 2:58:54 PM Vertical schematic (actual) B-SAND LINER; 4,587.4- 11,452.0 SLOTS; 10,927.0-11,389.0 SLOTS; 10,035.0-10,591.0 SLOTS; 9,477.0-9,786.0 PLUG; 9,200.0 PERF; 9,132.0-9,137.0 SQZ; 8,550.0-9,555.0 CMT Retainer; 9,000.0 SLOTS; 8,300.0-8,794.0 CMT Retainer; 8,226.0 CMT SQZ; 8,200.0 ftKB SLOTS; 7,562.0-8,148.0 SLOTS; 6,884.0-7,283.0 SLOTS; 6,140.0-6,605.0 SLOTS; 5,399.0-5,862.0 APERF; 5,097.0-5,102.0 SLOTS; 4,661.0-5,127.0 B LINER LEM; 4,345.8-4,748.5 INTERMEDIATE; 27.3-5,358.0 DIVERTER; 4,580.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164L1 ... TD Act Btm (ftKB) 11,472.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327860 Wellbore Status INJ Max Angle & MD Incl (°) 95.29 MD (ftKB) 9,395.80 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-164L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L2 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-154L2) 12/4/2005 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 D-SAND LINER 4 1/2 3.96 4,246.5 11,502.6 3,561.2 12.60 L-80 IBT 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) 4,271.4 3,449.0 74.58 SWIVEL 5.750 BAKER CASING SWIVEL 3.950 8,638.1 3,502.2 94.30 SWELL PKR 6.300 SWELL PACKER 3.960 9,158.4 3,476.8 92.53 SWELL PKR 6.300 SWELL PACKER 3.960 11,470.9 3,560.6 88.96 XO 4.500 4-1/2" X 3-1/2" XO sub 3.450 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,285.0 4,408.0 3,452.5 3,476.0 WS D, 1J-164L2 12/4/2005 32.0 SLOTS ALL D-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,719.0 5,306.0 3,479.9 3,471.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 5,582.0 6,133.0 3,466.3 3,473.7 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 6,412.0 6,964.0 3,470.6 3,466.8 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 7,244.0 7,824.0 3,476.3 3,495.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 8,103.0 8,629.0 3,499.5 3,502.9 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 9,183.0 9,739.0 3,475.8 3,488.1 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,018.0 10,606.0 3,499.6 3,521.3 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,883.0 11,470.0 3,532.8 3,560.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 1J-164L2, 12/19/2024 2:58:56 PM Vertical schematic (actual) D-SAND LINER; 4,246.6- 11,502.6 SLOTS; 10,883.0-11,470.0 SLOTS; 10,018.0-10,606.0 SLOTS; 9,183.0-9,739.0 SLOTS; 8,103.0-8,629.0 SLOTS; 7,244.0-7,824.0 SLOTS; 6,412.0-6,964.0 SLOTS; 5,582.0-6,133.0 SLOTS; 4,719.0-5,306.0 SLOTS; 4,285.0-4,408.0 INTERMEDIATE; 27.3-5,358.0 D LINER LEM; 4,187.1-4,375.0 ISO SLEEVE; 4,240.0 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev… 1J-164L2 ... TD Act Btm (ftKB) 11,524.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327861 Wellbore Status INJ Max Angle & MD Incl (°) 94.86 MD (ftKB) 4,717.59 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1. 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 feet 9200'feet true vertical feet None feet Effective Depth measured feet 4187'feet true vertical feet 3424' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3435' TVD Packers and SSSV (type, measured and true vertical depth) 4185' MD 4187' MD N/A 3424' TVD 3424' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: See Summary Details 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 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. See Summary details Packer: Baker SBE Seal Assy Packer: ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Alternating Slotted Liner: 4661-11389', Perfs: 5097-5102', 9132-9137' Alternating Slotted Liner: 3520-3610', Perfs: 3525-3525', 3581-3581' 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 ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-145 50-029-23278-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025650, ADL0025661 Kuparuk River Field/ West Sak Oil Pool KRU 1J-164L1 Plugs Junk measured Length Production Liner 5331' Casing 3656'5358' 2303' 108'Conductor Surface Intermediate 20" 10-3/4" 78' 2333' 2204' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 11472' 3613' 8200' 3553' 6865'4-1/2"11452'3612' By Grace Christianson at 4:23 pm, Dec 01, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2023.11.30 14:40:16-09'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 10/31/2023 REPAIR WELL FULLBORE RPPG PUMP JOB TO MBE @ 7320' RKB IN THE B LATERAL. PUMPED 7656 LBS OF RPPG @ 0.75 PPG. CALLED FLUSH @ 777 PSI / 214 BBLS RPPG SLURRY VOLUME. PRESSURE INCREASE WAS STEADY UNTIL IT REACHED 985 PSI & LEVELED OFF **TARGET FINAL PRESSURE WAS ~1400 PSI**. WELL TO REMAIN SHUT IN FOR 48 HOURS. 1J-164 RPPG Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-164 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164 10/17/2023 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND(1J-164), B-SAND (1J-164-L1), D-SAND (1J-164-L2) 12/7/2005 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 CONDUCTOR Insulated 20 19.12 30.0 108.0 108.0 91.50 H-40 WELDED SURFACE 10 3/4 9.95 29.6 2,332.8 2,204.1 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.88 27.3 5,358.0 3,656.4 29.70 L-80 BTC-M D-SAND WINDOW 7 5.63 4,248.0 4,258.0 3,445.4 12.60 L-80 IBTM B-SAND WINDOW 7 5.63 4,594.0 4,604.0 3,513.2 12.60 L-80 IBTM B LINER LEM 4 1/2 3.96 4,345.8 4,748.5 3,543.0 12.60 L-80 A-SAND LINER 4 1/2 3.96 4,702.9 11,400.0 3,745.4 12.60 L-80 IBT D LINER LEM 4 1/2 3.96 4,187.1 4,375.0 3,474.9 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.2 Set Depth 4,221.8 Set Depth 3,434.7 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) 22.2 22.2 0.00 HANGER 11.000 VETCO GRAY TUBING HANGER 4.500 474.9 474.9 0.86 NIPPLE 5.210 CAMCO 'DB-6' NO GO NIPPLE w/3.875" PROFILE 3.875 2,336.4 2,207.3 26.03 GAS LIFT 5.984 9:00 Mandrel Orientation CAMCO KBG-2 3.938 3,902.6 3,335.7 69.45 GAS LIFT 5.984 1:00 Mandrel Orientation CAMCO KBG-2 3.938 4,137.9 3,409.4 72.21 SLEEVE-C 5.480 CMU SLIDING SLEEVE w/3.81" PROFILE (CLSD 12/23/2005) Baker 3.812 4,183.2 3,423.2 72.46 LOCATOR 5.520 BAKER LOCATOR 3.875 4,184.9 3,423.7 72.46 SEAL ASSY 4.740 BAKER SBE SEAL ASSEMBLY 3.875 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) 4,240.0 3,440.1 72.81 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM (OAL=18.5 FT) 10/16/2023 2.590 4,580.0 3,509.1 80.28 DIVERTER TYPE-I DIVERTER SET IN B- SAND LEM (OAL=18.5 FT) 10/16/2023 3.100 4,667.0 3,525.1 78.10 DB PLUG 3" GS PROFILE DB PLUG/PRONG (PRONG 2.72" OD X 8.20', TOP OF = 4662' MD) SET IN DB-6 NIPPLE 8/5/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,336.4 2,207.3 26.03 1 GAS LIFT DMY BK-5 1 3/24/2006 9:00 CAMCO KBG-2 0.000 3,902.6 3,335.7 69.45 2 GAS LIFT DMY BK-5 1 3/24/2006 1:00 CAMCO KBG-2 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) 4,187.1 3,424.3 72.48 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,206.0 3,430.0 72.58 SBR 6.280 190-47 CASING SEAL BORE RECEPTACLE 4.750 4,225.7 3,435.9 72.68 XO BUSHING 6.020 CROSSOVER BUSHING 3.930 4,229.1 3,436.9 72.70 SWIVEL 5.750 CASING SWIVEL 3.920 4,345.8 3,468.4 76.44 PACKER 6.550 ZXP LINER TOP PACKER 4.960 4,364.7 3,472.7 77.43 SBR 6.260 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,384.3 3,476.8 78.45 XO BUSHING 6.040 XO BUSHING 3.880 4,670.1 3,525.8 78.00 NIPPLE 5.000 CAMCO 'DB-6' NIPPLE 3.563 4,702.9 3,532.9 76.96 PACKER 6.550 'HRD' ZXP LINER TOP PACKER 4.960 4,722.0 3,537.2 77.11 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.880 4,754.4 3,544.3 77.40 XO BUSHING 6.020 XO BUSHING 3.920 8,555.6 3,695.3 88.94 SWELL PKR 6.300 3.960 9,072.3 3,706.6 94.07 SWELL PKR 6.300 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,399.0 5,430.0 3,662.4 3,666.7 WS A2, 1J-164 11/12/2005 32.0 SLOTS ALL A-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,586.0 5,710.0 3,687.9 3,697.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 11/13/2023 4:55:32 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SHOE; 11,398.1-11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SWELL PKR; 9,072.3-9,082.7 SWELL PKR; 8,555.6-8,566.1 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 FLOAT SHOE; 5,356.5-5,358.0 FLOAT COLLAR; 5,268.7- 5,270.0 XO BUSHING; 4,754.4-4,755.8 B LINER LEM; 4,345.8-4,748.5 SEAL ASSY; 4,745.2-4,748.5 SBE; 4,734.7-4,754.4 HANGER; 4,724.9-4,734.7 NIPPLE; 4,722.0-4,724.9 PACKER; 4,702.9-4,722.0 NIPPLE; 4,670.1-4,671.6 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 HANGER; 4,587.4-4,611.3 WINDOW B-SAND; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 HANGER; 4,587.4-4,604.1 DIVERTER; 4,580.0 HANGER; 4,576.7-4,587.4 LINER SWIVEL; 4,385.7-4,388.5 XO BUSHING; 4,384.3-4,385.7 D LINER LEM; 4,187.1-4,375.0 SBR; 4,364.7-4,384.3 SEAL ASSY; 4,371.7-4,375.0 PACKER; 4,345.8-4,364.7 HANGER; 4,246.3-4,270.8 D-SAND WINDOW; 4,248.0- 4,258.0 WINDOW D-SAND; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 HANGER; 4,246.6-4,263.4 HANGER; 4,235.7-4,246.3 SWIVEL; 4,229.1-4,231.9 XO BUSHING; 4,225.7-4,227.1 SBR; 4,206.0-4,225.7 SEAL ASSY; 4,184.9 PACKER; 4,187.1-4,206.0 LOCATOR; 4,183.2 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 FLOAT SHOE; 2,331.0-2,332.8 FLOAT COLLAR; 2,249.1- 2,250.7 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 29.6-33.2 HANGER; 22.2 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev 1J-164 ... TD Act Btm (ftKB) 11,400.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327800 Wellbore Status INJ Max Angle & MD Incl (°) 94.67 MD (ftKB) 9,091.14 WELLNAME WELLBORE1J-164 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 5,802.0 6,049.0 3,697.2 3,687.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 6,384.0 6,846.0 3,671.9 3,673.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 7,524.0 7,774.0 3,697.9 3,696.5 WS A2, 1J-164 11/12/2005 32.0 SLOTS 8,144.0 8,545.0 3,685.7 3,695.1 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,087.0 9,427.0 3,705.5 3,685.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,705.0 9,766.0 3,676.6 3,673.6 WS A2, 1J-164 11/12/2005 32.0 SLOTS 10,286.0 10,592.0 3,692.2 3,706.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 11,179.0 11,365.0 3,730.7 3,743.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 11/13/2023 4:55:33 PM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SHOE; 11,398.1-11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SWELL PKR; 9,072.3-9,082.7 SWELL PKR; 8,555.6-8,566.1 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 FLOAT SHOE; 5,356.5-5,358.0 FLOAT COLLAR; 5,268.7- 5,270.0 XO BUSHING; 4,754.4-4,755.8 B LINER LEM; 4,345.8-4,748.5 SEAL ASSY; 4,745.2-4,748.5 SBE; 4,734.7-4,754.4 HANGER; 4,724.9-4,734.7 NIPPLE; 4,722.0-4,724.9 PACKER; 4,702.9-4,722.0 NIPPLE; 4,670.1-4,671.6 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 HANGER; 4,587.4-4,611.3 WINDOW B-SAND; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 HANGER; 4,587.4-4,604.1 DIVERTER; 4,580.0 HANGER; 4,576.7-4,587.4 LINER SWIVEL; 4,385.7-4,388.5 XO BUSHING; 4,384.3-4,385.7 D LINER LEM; 4,187.1-4,375.0 SBR; 4,364.7-4,384.3 SEAL ASSY; 4,371.7-4,375.0 PACKER; 4,345.8-4,364.7 HANGER; 4,246.3-4,270.8 D-SAND WINDOW; 4,248.0- 4,258.0 WINDOW D-SAND; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 HANGER; 4,246.6-4,263.4 HANGER; 4,235.7-4,246.3 SWIVEL; 4,229.1-4,231.9 XO BUSHING; 4,225.7-4,227.1 SBR; 4,206.0-4,225.7 SEAL ASSY; 4,184.9 PACKER; 4,187.1-4,206.0 LOCATOR; 4,183.2 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 FLOAT SHOE; 2,331.0-2,332.8 FLOAT COLLAR; 2,249.1- 2,250.7 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 29.6-33.2 HANGER; 22.2 KUP INJ 1J-164 ... WELLNAME WELLBORE1J-164 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 8,189.0 1J-164L1 4/19/2018 raffep Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L1 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-164L2) 12/4/2005 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 4 1/2 3.96 4,587.4 11,452.0 3,612.0 12.60 L-80 IBT 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) 8,226.0 3,553.1 88.48 CMT Retainer BAKER INFLATABLE CEMENT RETAINER - MID ELEMENT 8231' 11/2/2010 0.000 9,000.0 3,585.9 89.63 CMT Retainer BAKER INFLATABLE CEMENT RETAINER SET IN L1 LINER (OAL=2.5"x9.4') 8/6/2009 0.000 9,200.0 3,576.9 93.95 PLUG B-SAND BAKER IBP (2.125" x 10.53) 1/26/2008 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) 4,612.3 3,514.4 81.67 SWIVEL 5.750 Baker Casing Swivel 3.960 8,803.4 3,576.0 87.05 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 9,462.5 3,555.3 94.72 SWELL PKR 6.300 4-1/2", Swell Packer, BTC 3.960 11,420.1 3,611.1 88.35 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,661.0 5,127.0 3,519.8 3,526.0 WS B, 1J-164L1 11/19/2005 32.0 SLOTS ALL B-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,097.0 5,102.0 3,524.7 3,524.9 WS B, 1J-164L1 7/6/2021 6.0 APERF ADDED PERFORATION FOR RPPG MBE TREATMENT. 5,399.0 5,862.0 3,531.3 3,526.6 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,140.0 6,605.0 3,529.1 3,528.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,884.0 7,283.0 3,528.1 3,531.2 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 7,562.0 8,148.0 3,538.0 3,551.9 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,300.0 8,794.0 3,555.9 3,575.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,550.0 9,555.0 3,565.9 3,548.4 WS B, 1J-164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG PERFS, BH CHARGES, 31 CHARGES 9,132.0 9,137.0 3,581.4 3,581.1 WS B, 1J-164L1 8/4/2009 6.0 PERF CT Perfs, 60 degree phase pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,035.0 10,591.0 3,548.2 3,578.7 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,927.0 11,389.0 3,593.5 3,610.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,200.0 9,400.0 3,552.5 3,560.8 CMT SQZ 28 BBLS Ultra Lite Crete pumped below retainer & .75 BBLS on top of ICR 1J-164L1, 11/13/2023 4:55:34 PM Vertical schematic (actual) B-SAND LINER; 4,587.4- 11,452.0 SHOE; 11,451.0-11,452.0 SLOTS; 10,927.0-11,389.0 SLOTS; 10,035.0-10,591.0 SLOTS; 9,477.0-9,786.0 SWELL PKR; 9,462.5-9,472.9 PLUG; 9,200.0 PERF; 9,132.0-9,137.0 SQZ; 8,550.0-9,555.0 CMT Retainer; 9,000.0 SWELL PKR; 8,803.4-8,813.9 SLOTS; 8,300.0-8,794.0 CMT Retainer; 8,226.0 CMT SQZ; 8,200.0 ftKB SLOTS; 7,562.0-8,148.0 SLOTS; 6,884.0-7,283.0 SLOTS; 6,140.0-6,605.0 SLOTS; 5,399.0-5,862.0 APERF; 5,097.0-5,102.0 SLOTS; 4,661.0-5,127.0 SWIVEL; 4,612.3-4,615.1 HANGER; 4,604.1-4,610.3 HANGER; 4,587.4-4,604.1 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 HANGER; 4,587.4-4,611.3 DIVERTER; 4,580.0 HANGER; 4,576.7-4,587.4 LINER SWIVEL; 4,385.7-4,388.5 XO BUSHING; 4,384.3-4,385.7 D LINER LEM; 4,187.1-4,375.0 SBR; 4,364.7-4,384.3 SEAL ASSY; 4,371.7-4,375.0 PACKER; 4,345.8-4,364.7 HANGER; 4,246.3-4,270.8 D-SAND WINDOW; 4,248.0- 4,258.0 WINDOW D-SAND; 4,248.0- 4,258.0 ISO SLEEVE; 4,240.0 D-SAND LINER; 4,246.6- 11,502.6 HANGER; 4,246.6-4,263.4 HANGER; 4,235.7-4,246.3 SWIVEL; 4,229.1-4,231.9 XO BUSHING; 4,225.7-4,227.1 SBR; 4,206.0-4,225.7 SEAL ASSY; 4,184.9 PACKER; 4,187.1-4,206.0 LOCATOR; 4,183.2 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 FLOAT SHOE; 2,331.0-2,332.8 FLOAT COLLAR; 2,249.1- 2,250.7 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 29.6-33.2 HANGER; 22.2 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev 1J-164L1 ... TD Act Btm (ftKB) 11,472.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327860 Wellbore Status INJ Max Angle & MD Incl (°) 95.29 MD (ftKB) 9,395.80 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-164L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET ISO AND DIVERTER SLEEVES, IPROF 1J-164L2 10/17/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-154L2) 12/4/2005 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 D-SAND LINER 4 1/2 3.96 4,246.5 11,502.6 3,561.2 12.60 L-80 IBT 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) 4,271.4 3,449.0 74.58 SWIVEL 5.750 BAKER CASING SWIVEL 3.950 8,638.1 3,502.2 94.30 SWELL PKR 6.300 SWELL PACKER 3.960 9,158.4 3,476.8 92.53 SWELL PKR 6.300 SWELL PACKER 3.960 11,470.9 3,560.6 88.96 XO 4.500 4-1/2" X 3-1/2" XO sub 3.450 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,285.0 4,408.0 3,452.5 3,476.0 WS D, 1J-164L2 12/4/2005 32.0 SLOTS ALL D-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,719.0 5,306.0 3,479.9 3,471.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 5,582.0 6,133.0 3,466.3 3,473.7 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 6,412.0 6,964.0 3,470.6 3,466.8 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 7,244.0 7,824.0 3,476.3 3,495.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 8,103.0 8,629.0 3,499.5 3,502.9 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 9,183.0 9,739.0 3,475.8 3,488.1 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,018.0 10,606.0 3,499.6 3,521.3 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 10,883.0 11,470.0 3,532.8 3,560.6 WS D, 1J-164L2 12/4/2005 32.0 SLOTS 1J-164L2, 11/13/2023 4:55:35 PM Vertical schematic (actual) D-SAND LINER; 4,246.6- 11,502.6 SHOE; 11,501.6-11,502.6 SLOTS; 10,883.0-11,470.0 SLOTS; 10,018.0-10,606.0 SLOTS; 9,183.0-9,739.0 SWELL PKR; 9,158.4-9,168.9 SWELL PKR; 8,638.1-8,648.5 SLOTS; 8,103.0-8,629.0 SLOTS; 7,244.0-7,824.0 SLOTS; 6,412.0-6,964.0 SLOTS; 5,582.0-6,133.0 SLOTS; 4,719.0-5,306.0 SLOTS; 4,285.0-4,408.0 SWIVEL; 4,271.4-4,274.2 HANGER; 4,263.4-4,269.4 HANGER; 4,246.6-4,263.4 INTERMEDIATE; 27.3-5,358.0 D LINER LEM; 4,187.1-4,375.0 HANGER; 4,246.3-4,270.8 ISO SLEEVE; 4,240.0 HANGER; 4,235.7-4,246.3 SWIVEL; 4,229.1-4,231.9 XO BUSHING; 4,225.7-4,227.1 SBR; 4,206.0-4,225.7 SEAL ASSY; 4,184.9 PACKER; 4,187.1-4,206.0 LOCATOR; 4,183.2 SLEEVE-C; 4,137.9 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 FLOAT SHOE; 2,331.0-2,332.8 FLOAT COLLAR; 2,249.1- 2,250.7 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 29.6-33.2 HANGER; 22.2 KUP INJ KB-Grd (ft) 31.01 RR Date 12/5/2005 Other Elev 1J-164L2 ... TD Act Btm (ftKB) 11,524.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327861 Wellbore Status INJ Max Angle & MD Incl (°) 94.86 MD (ftKB) 4,717.59 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 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 11472'feet 9200'feet true vertical 3613'feet NONE feet Effective Depth measured 8189'feet 4187', 4346' feet true vertical 3552'feet 3424', 3468'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)4-1/2" L-80 4222' MD 3435' TVD Packers and SSSV (type, measured and true vertical depth)4187' MD 4346' MD N/A 3424' TVD 3468' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): See Summary Details 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title:Senior Well Intervention Engineer Contact Email: Contact Phone: Senior Engineer:Senior Res. Engineer: Collapse 108' BurstTVD 2204' 3656' 78' 2303' 7-5/8" Treatment descriptions including volumes used and final pressure: 1560 psi Casing Structural 20" 10-3/4" 108' 3. Address: Casing Pressure Tubing Pressure measured true vertical Kuparuk River Field/ West Sak Oil Pool Conductor Intermediate KRU 1J-164 L1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 100 psi Production Packer Length N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 BOPD Gas-Mcf measuredPlugs Junk measured Size Surface ConocoPhillips Alaska, Inc. ADL0025650, ADL0025661 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-145 50-029-23278-60-00 5. Permit to Drill Number:2. Operator Name N 1150 psi 0 BOPD Representative Daily Average Production or Injection Data 175 psi975 BWPD P.O. Box 100360 Anchorage, AK 99510 0 MSCFD 5358' 575 BWPD Oil-Bbl 4. Well Class Before Work: 2333' 5331' 0 MSCFD Water-Bbl MD Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: NONE Alternating Slotted Liner @ 4661- 11389' feet, Perfs@ 5097-5102', 9132-9137' Alternating Slotted Liner @ 3520- 3610', Perfs @ 3525-3525', 3581-3581' feet See Summary details Stefan Weingarth stefan.g.weingarth@conocophillips.com (907) 265-6038 Authorized Name: Stefan Weingarth Authorized Signature with date: WINJ WAG t Frac O y 6. API N y G L GIN 25.070, 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:41 pm, Aug 04, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date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ast Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-164 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: INSTALL DB PLUG, TYPE-I DIVERTER AND TYPE-II ISO SLEEVE 4/19/2018 1J-164 raffep Casing Strings Casing Description CONDUCTOR Insulated OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 91.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 29.6 Set Depth (ftKB) 2,332.8 Set Depth (TVD) … 2,204.1 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 27.3 Set Depth (ftKB) 5,358.0 Set Depth (TVD) … 3,656.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-M Casing Description D-SAND WINDOW OD (in) 7 ID (in) 5.63 Top (ftKB) 4,248.0 Set Depth (ftKB) 4,258.0 Set Depth (TVD) … 3,445.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Casing Description B-SAND WINDOW OD (in) 7 ID (in) 5.63 Top (ftKB) 4,594.0 Set Depth (ftKB) 4,604.0 Set Depth (TVD) … 3,513.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,345.8 Set Depth (ftKB) 4,748.5 Set Depth (TVD) … 3,543.0 Wt/Len (l… 12.60 Grade L-80 Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,345.8 3,468.4 76.44 PACKER ZXP LINER TOP PACKER 4.960 4,364.7 3,472.7 77.43 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,384.3 3,476.8 78.45 XO BUSHING XO BUSHING 3.880 4,576.7 3,508.5 80.33 HANGER LEM ABOVE HOOK HANGER 3.930 4,587.4 3,510.3 80.19 HANGER LEM INSIDE HOOK HANGER 3.688 4,670.1 3,525.8 78.00 NIPPLE CAMCO 'DB-6' NIPPLE 3.563 4,745.2 3,542.3 77.32 SEAL ASSY BAKER NON-LOCATING SEAL ASSEMBLY 3.890 Casing Description A-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,702.9 Set Depth (ftKB) 11,400.0 Set Depth (TVD) … 3,745.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,702.9 3,532.9 76.96 PACKER 'HRD' ZXP LINER TOP PACKER 4.960 4,722.0 3,537.2 77.11 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.880 4,724.9 3,537.8 77.13 HANGER FLEX-LOCK LINER HANGER 4.800 4,734.7 3,540.0 77.22 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 4,754.4 3,544.3 77.40 XO BUSHING XO BUSHING 3.920 8,555.6 3,695.3 88.94 SWELL PKR 3.960 9,072.3 3,706.6 94.07 SWELL PKR 3.960 Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,187.1 Set Depth (ftKB) 4,375.0 Set Depth (TVD) … 3,474.9 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,187.1 3,424.3 72.48 PACKER ZXP LINER TOP PACKER 4.960 4,206.0 3,430.0 72.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 4,225.7 3,435.9 72.68 XO BUSHING CROSSOVER BUSHING 3.930 4,229.1 3,436.9 72.70 SWIVEL CASING SWIVEL 3.920 4,235.7 3,438.9 72.74 HANGER LEM ABOVE HOOK HANGER 3.930 4,246.3 3,442.0 73.00 HANGER LEM INSIDE HOOK HANGER 3.688 4,371.8 3,474.2 77.80 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 4,221.8 Set Depth (TVD) (… 3,434.7 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.2 22.2 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 474.9 474.9 0.86 NIPPLE CAMCO 'DB-6' NO GO NIPPLE w/3.875" PROFILE 3.875 4,137.9 3,409.4 72.21 SLEEVE-C BAKER CMU SLIDING SLEEVE w/3.81" PROFILE (CLOSED 12/23/2005) 3.812 4,183.2 3,423.2 72.46 LOCATOR BAKER LOCATOR 3.875 4,184.9 3,423.7 72.46 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,236.0 3,439.0 72.74 DIVERTER TYPE-II DIVERTER SET IN B-SAND LEM 7/6/2021 3.100 4,577.0 3,508.6 80.32 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D- SAND LEM 7/6/2021 2.590 4,667.0 3,525.1 78.10 DB PLUG 3" GS PROFILE DB PLUG/PRONG (PRONG 2.72" OD X 8.20', TOP OF = 4662' MD) SET IN DB-6 NIPPLE 7/4/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,399.0 5,430.0 3,662.4 3,666.7 WS A2, 1J-164 11/12/2005 32.0 SLOTS ALL A-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non- slotted ends 5,586.0 5,710.0 3,687.9 3,697.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS 1J-164, 8/4/2021 11:20:07 AM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 ISO SLEEVE; 4,577.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 D-SAND LINER; 4,246.6- 11,502.6 DIVERTER; 4,236.0 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 Rig Release Date 12/5/2005 1J-164 ... TD Act Btm (ftKB) 11,400.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327800 Wellbore Status INJ Max Angle & MD Incl (°) 94.67 MD (ftKB) 9,091.14 WELLNAME WELLBORE1J-164 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 5,802.0 6,049.0 3,697.2 3,687.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 6,384.0 6,846.0 3,671.9 3,673.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 7,524.0 7,774.0 3,697.9 3,696.5 WS A2, 1J-164 11/12/2005 32.0 SLOTS 8,144.0 8,545.0 3,685.7 3,695.1 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,087.0 9,427.0 3,705.5 3,685.3 WS A2, 1J-164 11/12/2005 32.0 SLOTS 9,705.0 9,766.0 3,676.6 3,673.6 WS A2, 1J-164 11/12/2005 32.0 SLOTS 10,286.0 10,592.0 3,692.2 3,706.9 WS A2, 1J-164 11/12/2005 32.0 SLOTS 11,179.0 11,365.0 3,730.7 3,743.2 WS A2, 1J-164 11/12/2005 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,336.4 2,207.3 26.03 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 3/24/2006 9:00 2 3,902.6 3,335.7 69.45 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 3/24/2006 1:00 Notes: General & Safety End Date Annotation 12/7/2005 NOTE: MULTI-LATERAL WELL: A-SAND(1J-164), B-SAND (1J-164-L1), D-SAND (1J-164-L2) 1J-164, 8/4/2021 11:20:08 AM Vertical schematic (actual) A-SAND LINER; 4,702.9- 11,400.0 SLOTS; 11,179.0-11,365.0 SLOTS; 10,286.0-10,592.0 SLOTS; 9,705.0-9,766.0 SLOTS; 9,087.0-9,427.0 SLOTS; 8,144.0-8,545.0 SLOTS; 7,524.0-7,774.0 SLOTS; 6,384.0-6,846.0 SLOTS; 5,802.0-6,049.0 SLOTS; 5,586.0-5,710.0 SLOTS; 5,399.0-5,430.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 DB PLUG; 4,667.0 B-SAND WINDOW; 4,594.0- 4,604.0 B-SAND LINER; 4,587.4- 11,452.0 ISO SLEEVE; 4,577.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 D-SAND LINER; 4,246.6- 11,502.6 DIVERTER; 4,236.0 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ 1J-164 ... WELLNAME WELLBORE1J-164 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG: 8,189.0 4/19/2018 1J-164L1 raffep Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL TYPE II ISO SLEEVE, PULL TYPE 1 DIVERTER, PULL DB PLUG, INSTALL TYPE 1 ISO SLEEVE 6/6/2020 1J-164L1 famaj Casing Strings Casing Description B-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,587.4 Set Depth (ftKB) 11,452.0 Set Depth (TVD) … 3,612.0 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,587.4 3,510.3 80.19 HANGER Baker Mod B1 FHH ( Inside Casing 16.75' ) 3.930 4,604.1 3,513.1 81.01 HANGER Baker Mod B1 FHH ( Outside Casing 6.19' ) 3.688 4,612.3 3,514.4 81.67 SWIVEL Baker Casing Swivel 3.960 8,803.4 3,576.0 87.05 SWELL PKR 4-1/2", Swell Packer, BTC 3.960 9,462.5 3,555.3 94.72 SWELL PKR 4-1/2", Swell Packer, BTC 3.960 11,420.1 3,611.1 88.35 XO Reducing 4-1/2" X 3-1/2" XO sub 3.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,226.0 3,553.1 88.48 CMT Retainer BAKER INFLATABLE CEMENT RETAINER - MID ELEMENT 8231' 11/2/2010 0.000 9,000.0 3,585.9 89.63 CMT Retainer BAKER INFLATABLE CEMENT RETAINER SET IN L1 LINER (OAL=2.5"x9.4') 8/6/2009 0.000 9,200.0 3,576.9 93.95 PLUG B-SAND BAKER IBP (2.125" x 10.53) 1/26/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 4,661.0 5,127.0 3,519.8 3,526.0 WS B, 1J-164L1 11/19/2005 32.0 SLOTS ALL B-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non- slotted ends 5,097.0 5,102.0 3,524.7 3,524.9 WS B, 1J-164L1 7/6/2021 6.0 APERF ADDED PERFORATION FOR RPPG MBE TREATMENT. 5,399.0 5,862.0 3,531.3 3,526.6 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,140.0 6,605.0 3,529.1 3,528.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 6,884.0 7,283.0 3,528.1 3,531.2 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 7,562.0 8,148.0 3,538.0 3,551.9 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,300.0 8,794.0 3,555.9 3,575.5 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 8,550.0 9,555.0 3,565.9 3,548.4 WS B, 1J-164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG PERFS, BH CHARGES, 31 CHARGES 9,132.0 9,137.0 3,581.4 3,581.1 WS B, 1J-164L1 8/4/2009 6.0 PERF CT Perfs, 60 degree phase pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,035.0 10,591.0 3,548.2 3,578.7 WS B, 1J-164L1 11/19/2005 32.0 SLOTS 10,927.0 11,389.0 3,593.5 3,610.1 WS B, 1J-164L1 11/19/2005 32.0 SLOTS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,200.0 9,400.0 3,552.5 3,560.8 CMT SQZ 28 BBLS Ultra Lite Crete pumped below retainer & .75 BBLS on top of ICR 1J-164L1, 8/4/2021 11:20:09 AM Vertical schematic (actual) B-SAND LINER; 4,587.4- 11,452.0 SLOTS; 10,927.0-11,389.0 SLOTS; 10,035.0-10,591.0 SLOTS; 9,477.0-9,786.0 PLUG; 9,200.0 PERF; 9,132.0-9,137.0 SQZ; 8,550.0-9,555.0 CMT Retainer; 9,000.0 SLOTS; 8,300.0-8,794.0 CMT Retainer; 8,226.0 CMT SQZ; 8,200.0 ftKB SLOTS; 7,562.0-8,148.0 SLOTS; 6,884.0-7,283.0 SLOTS; 6,140.0-6,605.0 SLOTS; 5,399.0-5,862.0 APERF; 5,097.0-5,102.0 SLOTS; 4,661.0-5,127.0 INTERMEDIATE; 27.3-5,358.0 B LINER LEM; 4,345.8-4,748.5 ISO SLEEVE; 4,577.0 D LINER LEM; 4,187.1-4,375.0 D-SAND WINDOW; 4,248.0- 4,258.0 D-SAND LINER; 4,246.6- 11,502.6 DIVERTER; 4,236.0 GAS LIFT; 3,902.6 GAS LIFT; 2,336.4 SURFACE; 29.6-2,332.8 NIPPLE; 474.9 CONDUCTOR Insulated; 30.0- 108.0 KUP INJ KB-Grd (ft) 31.01 Rig Release Date 12/5/2005 1J-164L1 ... TD Act Btm (ftKB) 11,472.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292327860 Wellbore Status INJ Max Angle & MD Incl (°) 95.29 MD (ftKB) 9,395.80 WELLNAME WELLBORE1J-164 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: 1 AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ter+ Anchorage, AK 99501 I• TRANSMITTALDATE TRANSMITTAL# WELL NAME API A SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's Receipt Date return via courier or sign/scan and email a copy to *)iilumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. THE STATE °fALASKA GOVERNOR BILL WALKER John Pierce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -164L1 Permit to Drill Number: 205-145 Sundry Number: 318-462 Dear Mr. Pierce: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www,aogcc.olaska.gov Enclosed is the approved application for the 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, Hollis S. French >r� Chair DATED this ( day of October, 2018. RBDMS �� OCT 19 2918 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate E] Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBEEI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilfl s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 205-145 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-60 —00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU U -164D Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650, ADL 25661 1 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): 11,472' 3,613' 11451 3612 1500psi 9200 NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 2,303' 10 314 2,333' 2,204' Intermediate 5,331' 75/8 5,358' 3,656' Liner 6,697 4112 1 11,452' 3,745' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4661-11389 3520.3610 4.500" L-80 4,222' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER =NIA N/A =N 12. Attachments: Proposal Summary ❑, Wellbore schematic F,, 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 2] 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/4/2018 OIL ❑ WINJ EI WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 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 s Contact Phone: (907) 265-6471 Authorized signature: �W- Date: 0 1�, 261 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑"LJ Other: Post Initial Injection MIT Req'd? Yes ❑ No NJ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 O I-4 el \ /Form 10-903 Revised 4/2017 YQ r7-7-10114 lred ORIGINAkmiz OCT Approved application Is valid for 12 months from the date of approval. lb. t ,b, rol"l�8 Submft Form and Attachments in Duplicate KUP INJ 1J-164 cTPhil I� hnl' f11 AiB61w PC. Well Attributes Max Angle&MD TD Fula Name Wellno�e PPWWI Welmo,e Status ncll°I MD'al Act eM IflKBI WEST SAN' 50029232]800 INJ 6.67 9091.14 11400.0 Comment SSSV NIPPLE I X35(ppml Gan, Annotation I Entl Bale 1 KBGN GO RlB flelease Osla Last WO' 31.01 12/52005 as u-1w.1GA1G191Ds4ox AM Last Tag VaRoalsannesp eopi Annual Last Tag' Entl DaleDaptn Me) U.m By Imgibb" ...._...._._......._................._............................._.....__.. HANGEN. 22.2 eoxoumoF lrwWN: 310- 108.0 NIPPIE:s"ll SORFACE;H SZMA GAS LIR. 2.a]9a GAS LI..Agpi ..EYSg41ng LOCATOR:4,1832 $EALASSY:4,184i ISOSLEEVEazmO D lLINER, 42 all msuz.e D SAND Val 4,]180- 4.25Go D LINER LEM: 4.15714.WSD GREATER: ""i sA e-NDUNER4.5au 1t.. a. Wm0OW, 4.5040- axo oe PING 4.e5r.G B LINER OEM: 4.545.84.749.5 INTERMEDMITE:2r.35.55B.D BLDTs:439$.D54.i0.B 8LO18: S.Y665 ]10.0 SLOTS: S.BRBa.049.8� story e.x4.os.e4ao- smrs:7524n7nao ..L e.twaeaut SLOTS; 9.0870e.47r.0 SLOTS ; 9.."Nato � $LOTS; I0,2SE D-1D.Ml smre: 11.17 11 All asAND USER: ',7re.9 gogL 1 lot L � , I r Last Rev Reason An.Waiun Entl Date Last MaJ By REV REASONPull IBP In B tat 9842018 $IDI Cuing Strings easlnB Deicnplwn o0(in) lB pm Test( eI sx cepin lRl(e) Sea Dsplh Ti wuIn p._ Graae trap TM1,eaa CONDUCTOR Insulated 20 19.12 30.0 108.0 1080 91.50 H40 WELDED Seeing Desc,iplwn DD lin) 10 (In) TAM "81 Sat DepN lMe) Set Depm(Ti W11In (1... Graae Is Thea! SURFACE 103/4 9.95 29fi 2,3328 2,204.1 45.50 L-80 BTC Caging Deecriptwn OD IN) to (in) Tap ME) Set Depen MB) Set Dean nVO)... pal 11... Graae Tap Thai INTERMEDIATE 7518 6.88 273 5,3580 3,358.4 29.70 I BTC -M Deals. Deza6N OD lin) ID(In) Tgp hoot Al pal BEGS) SA Depen IRO)... Wtlon.(I... GfWe The Thai D-SANDWINDOW ] 5.63 4,2480 4,258.0 3,445.4 12.60 LED IBTM Cads; Daeligbn OO 6n) IO (in) Tap Met .M MMM SN BepN I... Wil (I._Guae Top Tnw B-SANDWINDOW 7 563 4,594.0 4,6040 3,513.2 12.60 1 IBTM casing Descril DD (in) IDlim Top(f.B) eel Deem pli Gat neigh (Tg01... WBLen(I... GrWe Top Tnrua BLINER LEM 412 3.96 4,345.8 41768.5 3543.0 1260 L-80 Liner Details Top MKe) TepnVD)MKB) Toelncll') nem Dn cram (in) 4,345.8 3,468.4 7644 PACKER ZXP LINER TOP PACKER 4960 4.3643 ,4723 7743 SBR 1D9<7 CASING SEAL BORE RECEPTACLE 47M 4,384.3 ,4768 78.45 TO BUSHING XO BUSHING 3.880 4,5]6.] 3,508.5 8033 HANGER LEM ABOVE HOOK HANGER BLEW 4,5874 ,510.3 80.19 HANGER LEM INSIDE HOOK HANGER 3.688 4,670.1 3,525.8 7800 NIPPLE CAMCO'DB-6' NIPPLE 3.563 4,7452 3.S,12.3 77.32 SEALASSY BAKER NON -LOCATING SEAL AS EMBLY 3.890 CaelnB DasaNPnon OD(In) ID pm Top MKB) 8el0epIM1 MKB) Set DeplM1 (RDI-. WOLen IL.. Graae Top Tnraaa A -SAND LINER 412 3.96 4,]02.9 11,400.0 3,7454 1200 L-80 TBT Liner Details Nnmmm lD Top DUKE) Toe I1VD)Imlel roPL¢I I•) IumIn coin lin) 4,702.9 3,5329 76.96 PACKER 'HAD' ZXP LINER TOP PACKER 4.960 4,722.0 3,537. 7711 NIPPLE 'IRF PA KOFF SEAL NIPPLE Z880 4,724.9 3.5378 77.13 HANGER FLEXLEOCKLINER HANGER 4.800 4,7 7 3,5400 77, BE 1 IXF47 CASING SEAL BORE EXTENSION 475 4,754.4 3.5443 77.40 70 --BUSHING XO BUSHING 3. 8555.6 3,6953 88.94 SW ELL PKR 3. 9,072.3 3.106.6 111 SWELL PKR 3. CazinB OeacripMn DDlin) ID lin) top Got; Set Dept MKe) eel Orolh ITVOL.. WVLen IL.. Gratle Top TFnaa D LINER LEM 412 3.96 4,187.1 4,3]5.0 3,4]4.9 1260 L-80 IIT Liner Details Nominal l0- Top IXKBI TapjrvOnNKe) Tel Man Des Cam ra 4,187.1 3,4243 7.4 PACKER ZXP LINER TOP PACKER 4,960 4, 0 3,430.0 ]2.59 SBR 19047 CASING EAL BORE RECEPTACLE 4.750 ____4=5 3,4359 72. XO BUSHING CROSSOVER BUSHING 4,229.1 3,436.9 72.70 SWIVEL CASING SWIVEL MIT 4,35.7 3,4389 7 74 HANGER LEM ABOVE HOOK HANGER 4,2463 3,4420 73.M HANGER LEM INSIDE HKHANGER 8 4,371.8 34742 77M BEALASSY BAKER SEAL ASSEMBLY 3.90 Tubing Strings Tubing Ons51nnp Ma.. to in Top IflKBI Set GepIM1 M.Set Depth)TVD) I... WL lOgn Gratle Top Canneclion TIEDNG d 1/2 396 22.2 4,2218 3434) 12.60 L-80 )BTM Completion Details TOP Ti Toe In-, Top PIKE) I 1'1 Ilam Gea coin Nominal )Olin) 222 22,2 000 HANGER VETCO GRAY TUBING HANGER 4500 676.9 4]4.9 0.86 NIPPLE CAMCO'OBE'NOG NIPPLE wl3.8]5"PROFILE 3875 --4,1 7.9 3,409.4 72 21 SLEEVE -C BAKER MU L IN EEVE w13. 1"1` L SEO 22L2005) 3.812 9,183.2 3,423.2 ]246 LOCATOR BAKER LOCATOR ]5 4,184.9 3,9237 1 7246 SEAL ASSV BAKER SBE SEAL ASSEMBLY 3.815 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Toppli Top 110) Top'lncl INGES 11 Des Dom Run Dale 0Lim 4,236.0 3439.0 ]2 74 1505LEEVE TYPE -II ISO SLEEVESET ACROSS DSAND LEM 4/191 2590 4,580.0 3,509.1 8028 DIVERTER TYPE -I DIVERTER SET IN B -SAND LEM 4)18)2018 3.100 4,66]0 3,525.1 7.10 DB PLUG FILE DB --N 72" 0 41]2018 0000 X 820, TOP OF - 4662 MDI SET IN DBE NIPPLE perforauono & Slots T-PMKeI supwin reMD) ("a) unci l (Intel Unkshl 0. .no, Gan (Anotam ) Type Cam 5.399.0 5,4300 3,6624 3,666.7 WS A2, IJI 11112/2005 320 SLOTS ALL ALSAND SLOTS= Altemaft SlolsedBlank Pipe 0.125' x 25" x 32 SpL @ 4 CRogmierential adj SUTAGEm rBw5, 3"Cemers sWWered 18 1 3 8. I s1oDEa ends 5,506.0 5,]10.0 3,6879 3,8972 WS11J-164 1111 005 320 SLOTS 5,802.0 6,0490 3,69]. 3,8878 WS A2, 1J-164 1111 005 32.0 SLOTS 6,384.0 6,8460 3,671.9 3,6]3.9 WSA2,1J-1641111 005 32.0 SLOTS KUP INJ 1J-164 ConoAo illips Amska. Inc. L -DM I.. 10%02M1 ............................................................ HPNGEF', 71.1 -j7j Perforations & Slots CONDUCTOR mwb1: itA smi 1060 Dens NIPPIE.a. Tap DVD) elm 1N01 (snmsX[ Tapfta) 61mmKa) MKIN VRW Linked zone D. 1 Type cam 7,524,0 7,7740 3,697.9 3,696.5 WS Q. U-164 11112/200.5 32.0 SLOTS 8,144.0 8.5450 --3,6W.77-7—N-51 WS A2, 1J-164 1111 5 32.0 SLOTS SURFACE; ma2.0528 9,087c 9,4270 3.705.5 3,685.3 WS A2,1J-164 11112/2065 32.0 SLOTS EAS LIFT: 28364 9,7050 9,)66.0 3,676.6 7873.6 WS A21J-164 11/122005 2.0 SLOTS 102880 10,5920 3,6922 3706.9 WSA2,1J-164 111122005 —377 Mors 11,1]90 11,365.0 3.)30.) 3 74T7 WS 732, 1J-164 11/122005 320 SLOTS W LIFT: 3=6 Mandrel Inserts sl sLE£JE{: 4.I T.9 as N TVD) Top (XRD) (I11(R) Mahe Valve Model DO(inl sery Type TYw Portslxe TRI TYpe (In) (psi) Ru.be. Com 1 233fi.4 2.20]3 CAMCO KBG-2 1 GAS LIFT OM1 BK -5 6600 3242006 9'.00 LOCAioR:a 1872 2 3,902.61 3,3353 ICAMGQ KBU-2 1 1 IGAS LIFT JDMY 5K-5 I U0001 1324r2006 11 00 BEALASII:d. MII Notes: General & Safety End Dae AnnaLalon 12012005 INUIL. MULTI -LATERAL WELL'. A-SANDDJ-164), B -SAND (IJ -164 -LI). D -SAND (1J-1fid-LZ) WIDOW INIHE. VIEW SCHEMATIC WAMW EMem3809.D 180 BLEEVE. sM0 D.ND LINER; d,2M6 11.5028 .D WINDOW:4.2 40 12560 D LINER LED; 4.161.14,3250 ONERTER: 4.Y]0 64L9ND LINER: 4.-26 1520 &6PN0 WINOIXY: 4,5F6 4.111MA Ce RUG 4.66/,0 E LINER LEM; 4.34D.8{.)465 1NTERMEONTE DJ5.3-0 SLOTS: g51GD6.430.0� 1115580.06.>10.0� SLOTS. S802DSAU 0� swis:436aoq.Sn.O�� Swi3; 2524L7.n40 swis;glaoas4s.0— swie:6a .AUDo— Swis; 62m.",,ien.0� S'.. Ig1-.LLIMNM.0— SLOTS 11, 179 LI 1,3R.0� AEAND LINER: 4,M4 11 0- Proposed 1J -164L1 to 1J -166L1 RPPG Treatment of B MBE 1J-1641_1 is a West Sak B Sd horizontal injector Lat. An initial MBE from 1J-164 to 1J-166 offset producer occurred January 2008. On 1/26/08, an IBP was set at 9200' RKB in a 683' blank section of 4.5 liner in 1J-1641_1 to isolate the MBE, but communication resumed 5/24/09 to the B MBE. 6/1/09 IPROF showed all PWI entered 1J -164L1. 6/15/09 IPROF in 1641-1 showed all flow passing a swell packer on 4.5" liner at 8803' RKB to a B MBE toward the toe of the Lat, but no flow was seen past the IBP set at 9200' in the liner. All flow to the B MBE was seen exiting to liner x OH annulus. On 8/4/09, 5' of perfs were shot above the IBP. On 8/6/09, an inflatable Cmt Retainer was set at 9000' RKB above perfs to form a straddle in 4.5" liner, then 24 bbls of 8.5# Cement was pumped into the straddle to Cement 200' in 4.5 liner and 683' of adjacent liner x OH annulus to isolate the B MBE. This MBE isolation lasted 7 months until communication resumed to toe B MBE per 4/6/10 B IPROF. On 10/31/10, 5' of perfs were shot at 8550 - 8555' RKB. On 11/2/10, a Cmt Retainer was set at 8231' RKB and 28 bbls of Ultra -Lite 8.5 ppg Cement was pumped to add more Cement Plug to reisolate the toe B MBE. This successful job allowed 1J -164L1 BOI until 2018, before a new MBE occurred. A 4/7/18 ]PROF saw all flow to B Lat, and 4/24/18 B (PROF saw a new B MBE at 5100' RKB, but the Cement Plug was still effectively isolating the toe B MBE of 2008. On 9/15/18, a fullbore MARCIT Gel job put 80 bbls of Crosslinked MARCIT in the MBE, but the treatment failed —4 days after 1J-136 BOI. It is now proposed that RPPG slurry be fullbore pumped to treat the MBE 5100' RKB. 1J-164 is currently configured with A Lat Plug set, B Diverter set, and D Iso-Slv set. 1J -164L1 appears to be a very robust MBE, but we have had some recent success using RPPG to treat similar large MBE's. Proposed Procedure: 1) Coil Tubing: RIH with 2" pert gun to shoot big holes in 4.5" Slotted Liner 5095 - 5100' RKB at 6 spf, 60 deg ph, near the MBE to enable good RPPG passage through the slotted liner. POOH with gun. RD. 2) Fullbore Pump RPPG (Reformed Polymer Particle Gel) Treatment to B MBE: RU Pumping unit, and Fullbore Pump: a) —150 bbls Pre -Flush of 2% KCL Brine or Seawater at —2 bpm to establish injection to MBE at —5100' RKB and displace hydrocarbons to liquid pack the wellbore, then SI offset 1J-166 producer and continue pumping into 1J-1641-1 with, b) RPPG Slurry at —0.75 ppg (target) in 2% KCL Brine at steady rate of —2 bpm until WHIP reaches —800 psi, then swap to Flush/Displacement with c) 40 bbls 2% KCL Brine Spacer at established steady rate of —2 bpm, followed by d) 37 bbls Diesel FP at steady rate of —2 bpm, followed by e) SD pumping & RD pumping equipment. 3) Coil Tubing: RIH with jetting nozzle to perform RPPG Fluff & Stuff to as deep as possible in the 1J -164L1 lateral. RD CTU. Put 1J -164L1 BOI to evaluate MBE treatment. JWP 10/10/2018 • OFT • THE STATE k � Alaska Oil and Gas -s� �, of LJS1K}\. Conservation Commission '11-11611*- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 (4' M Main: 907.279.1433 F ALAS*I" Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineerum JUN 1 5 'z01?, ConocoPhillips Alaska, Inc. S P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-164L1 Permit to Drill Number: 205-145 Sundry Number: 318-232 I Dear Peirce: Enclosed is the approved application for the 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, Hollis S. French Chair DATED this ( ( day of June, 2018. RBDMS.D JUN 12 2018 3. 0 • f 3;,,,,,C STATE OF ALASKA JUN 01 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS5' G 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE MARCIT GEL TrtmtL - 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 205-145 3.Address: Stratigraphic ❑ Service 0 . 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23278-60 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J-164L1 - Will planned perforations require a spacing exception? Yes ❑ No ID 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650,ADL 25661• 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 TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,472' • 3,613' ' 11451 3612 1500psi 9200 Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 2,303' 10 3/4 2,333' 2,204' Intermediate 5,331' 7 5/8 5,358' 3,656' Liner 6,697' 41/2 11,400' 3,745' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4661-11389 3520-3610 4.500" L-80 4,222' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=N/A N/A SSSV =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 6/16/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 2 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ 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. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com ,/p Contact Phone: (907)265-6471 Authorized Signature: ( _ - Date: sI31/ U _ _ _ COMMISSION USE ONLY Conditions of appro I: Notify Commission so that a representative may witness Sundry Number: o_z52 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No 114;?"'"- Spacing 1 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 — 40* APPROVED BY e e Approved by: ta25---7 COMMISSIONER THE COMMISSION Date: 10�t �I V __yy L 6/<< i$ 1 C1,i$ RBDMb JUN 1/11018 / ' �'r QR LNSAJIJ, Submit Form and �V Form 10-403 Revised 4/2017 Approved applicatido dateof approval. Attachments in Duplicate ) \,,, KUP J 1J-164 ConocoPhithps Well Attr Max Ant MD TD Field Name Wellbore APIIUWI Wellbore Status Incl ft) MD(ftKB) Act Btu,(ftKB) • .Alaska,If1C. WEST SAK 500292327800 INJ 94.67 9,091.14 11,400.0 Cor vOM'9ips Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date .-- SSSV:NIPPLE Last WO: /31.01 12/5/2005 1.1-164,5/302018 6:53:36 AM Last Tag Vertical schematic(actual) Annotation End Date Depth(ftKB) Last Mod By Last Tag: Imosbor HANGER;22.2Last Rev Reason ■ � Annotation End Date Last Mod By ., I I�, REV REASON:INSTALL DB PLUG,TYPE-I DIVERTER AND TYPE-II 4/19/2018 raffep ""i ISO SLEEVE Casing Strings .A CONDUCTOR Insulated;00.-- -��I /�� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE'474.9 1I>!. CONDUCTOR Insulated 20 _19.12 30.0 108.0 108.0 91.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I I SURFACE 103/4 9.95 29.6 2,332.8 2,204.1 45.50 L-80 BTC Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.88 27.3 5,358.0 3,656.4 29.70 L-80 BTC-M SURFACE;29.6-2,332.8 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND WINDOW 7 5.63 4.248.0 4,258.0 3,445.4 12.60 L-80 IBTM GAS LIFT;2,336.4 I!!! Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i B-SAND WINDOW 7 5.63 4,594.0 4,604.0 3,5132 12.60 L-80 IBTM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I... Len Grade Top Thread GAS LIFT;3,902.6 BLINER LEM 41/2 3.96 4,345.8 4,748.5 3,543.0 12.60 L-80 ■ Liner Details Nominal ID SLEEVE-C;4,137.9 I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 4,345.8 3,468.4 76.44 PACKER ZXP LINER TOP PACKER 4.960 LOCATOR;4,183.2 4,364.7 3,472.7 77.43 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 .I I 4,384.3 3,476.8 78.45'XO BUSHING XO BUSHING 3.880 SEAL ASSY.4,164.6 - 4,576.7 3,508.5 80.33 HANGER LEM ABOVE HOOK HANGER 3.930 7. 4,587.4 3,510.3 80.19 HANGER LEM INSIDE HOOK HANGER 3.688 _ 4,670.1 3,525.8 78.00 NIPPLE CAMCO'DB-6'NIPPLE 3.563 - 4,745.2 3,542.3 77.32 SEAL ASSY -BAKER NON-LOCATING SEAL ASSEMBLY 3.890 i j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade [Top Thread ISO SLEEVE;4,238.0 kl i A-SAND LINER 41/2 3.96 4,7029 11,400.0 3,745.4 12.60 L-80 IBT 8- D-SAND LINER;4,246. 11,502.6 IpI U� Liner Details D-SAND WINDOW;4,248.0- Nominal ID 4,258'0 '(�( it, Top(ftKB) Top(TVD)(ftKB) Top Incl ft) Item Des Corn (in) 4,702.9 3,532.9 76.96 PACKER 'HRD'ZXP LINER TOP PACKER 4.960 4,722.0 3,537.2 77.11 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.880 I_S 4,724.9 3,537.8 77.13 HANGER FLEX-LOCK LINER HANGER 4.800 aD LINER LEM;4,167.14,375.0 4,734.7 3,540.0 77.22 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 _ 4,754.4 3,5443 77.40 XO BUSHING XO BUSHING 3.920 8,555.6 3,695.3 88.94 SWELL PKR 3.960 9,072.3 3,706.6 94.07 SWELL PKR 3.960 ' .III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread .'=1.1 D LINER LEM 4 1/2 3.96 4,187.1 4,375.0 3,474.9 12.60 L-80 [Top 1 DIVERTER;4,580.0 'I1 a I' Liner Details B-SAND LINER;4,587.4, a'IIIII! Nominal ID 11,452.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(.) Item Des Com (in) 13-SAND WINDOW;4,594.0.4,804.0 I• 4,187.1 3,424.3 72.48 PACKER ZXP LINER TOP PACKER 4.960 4206.0 3,430.0' 72.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 DB PLUG;4,667.0 4,225.7 3,435.9 72.68 XO BUSHING CROSSOVER BUSHING 3.930 e1 4,229.1 3,436.9 72.70 SWIVEL CASING SWIVEL 3.920 I• 4,235.7 3,438.9 72.74 HANGER LEM ABOVE HOOK HANGER 3.930 F--.1 4,246.3 3,442.0 73.00 HANGER LEM INSIDE HOOK HANGER 3.688 4,371.8 3,4742 77.80 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 6 LINER LEM;4.345.8 ,748.5 Is Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 4 1/2 3.96 222 4221.8 3,434.7 12.60 L-80 IBTM Completion Details Top(TVD) Top Incl Nominal Top(ftKB) (ftKB) (1) Item Des Com ID(in) INTERMEDIATE;27.3-5,358.0 222 222 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 474.9 474.9 0.86 NIPPLE CAMCO DB-6'NO GO NIPPLE w13.875"PROFILE 3.875 SLOTS;5,399.0a,430.0 4,137.9 3,409.4 72.21 SLEEVE-C BAKER CMU SLIDING SLEEVE w13.81"PROFILE(CLOSED 3.812 12/23/2005) SLOTS;5,586.0.5,710.0 4,183.2 3,423.2 72.46 LOCATOR BAKER LOCATOR 3.875 SLOTS;5,802.06,049.0 4,184.9 3,423.7 72.46 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLOTS;6,384.06,846.0 Top(TVD) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) SLOTS;7.524.0-7,774.0 4,236.0 3,439.0 72.74 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM 4/19/2018 2.590 4,580.0 3,509.1 8028 DIVERTER TYPE-I DIVERTER SET IN B-SAND LEM 4/18/2018 3.100 4,667.0 3,525.1 78.10 DB PLUG 3"GS PROFILE DB PLUG/PRONG(PRONG 2.72"OD 4117/2018 0.000 SLOTS;8,144.0-8,545.0 X 8.20',TOP OF=4662'MD)SET IN DB-6 NIPPLE liiir Perforations&Slots Shot Dene Top(TVD) Btm(TVD) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Corn 5,399.0 5,430.0 3,6624 3,666.7 WS A2,1J-164 11/12/2005 32.0 SLOTS ALL A-SAND SLOTS= Alternating Slotted/Blank sLors;9,087.0-9.427.0Pipe 0.125"x 2.5"x 32 spf I @ 4 Circumferential SLOTS;9,705.0-9.766.0 adjacent rows,3"Centers staggered 18 deg.,3 ft.non- slotted ends 5,586.0 5,710.0 3,687.9 3,6972 WS A2,13-164 11/12/2005 32.0 SLOTS non- SLOTS;1o,z66.0-10,ssz.D I I f- 5,802.0 6,049.0 3,697.2 3,6873 WS A2 1J-164 11/12/2005 32.0 SLOTS SLOTS;11,179.0-11,365.0 6,384.0 6,846.0 3,671.9 3,673.9 WS A2,1J-164 11/12/2005 32.0 SLOTS A-SAND LINER;4,702.9- 11,4mo'\ KUP 01 0 1J-164 ConocoPhillips Alaskd,Inc. La ode', lM1pc 1J-164,502018 853:39 AM Vertical schemaac(actual) HANGER;22.2 ,1 t h Perforations&Slots CONDUCTOR Insubted;30.0-- - 'u III Shot • 108.0 Dena NIPPLE;474.9 _ Top(TVD) Btm(TVD) (shots/ft Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com l 7,524.0 7,774.0. 3,697.9 3,696.5 WS A2,1J-164 11/12/2005 32.0 SLOTS 8,144.0 8,545.0 3,685.7 3,695.1 WS A2,1J-164 11/12/2005 32.0 SLOTS SURFACE;29.6-2,332.6 9,087.0 9,427.0 3,705.5 3,685.3 WS A2,1J-164 11/12/2005 32.0 SLOTS GAS LIFT;2,336.4 9,705.0 9,766.0 3,676.6 3,673.6 WS A2,1J-164 11/12/2005 32.0 SLOTS iii 10,286.0 10,592.0 3,692.2 3,706.9 WS A2,1J-164 11/12/2005 32.0 SLOTS GAS LIFT;3,902.8 11,179.0 11,365.0 3,730.7 3,743.2 WS A2,1J-164 11/12/2005 32.0 SLOTS 11 Mandrel Inserts St SLEEVE-C;4,137.9 eti N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;4,183.2 1 2,336.4 2,207.3 CAMCO K30-2 1 GAS LIFT DMY BK-5 0.000 3/24/2006 9:00 sEALAssv;a,164.a .� 2 3,902.6' 3,335.7 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 3/24/2006 1:00 f Notes:General&Safety End Date Annotation 12/7/2005 NOTE:MULTI-LATERAL WELL:A-SAND(1J-164),B-SAND(1J-164-L1),D-SAND(1J-164-L2) 6/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 • ISO SLEEVE;4,236.0 0-SAND LINER;4,248.6- 11,502.6 ,248.611,502.6 I. D-SAND WINDOW;4,248.0- 4,258.0 • i •M D LINER LEM;4,187.1-4,375.0 G lel DIVERTER;4,580.0 B-SAND LINER;4,587.4- II I 11,452.0 B-SAND WINDOW;4,594.6 I 4,804.0 08 PLUG;4,667.0 ill { Iffi B LINER LEM;4,345.84,748.5 a: INTERMEDIATE;27.35,358,0 SLOTS;5,399.05,430.0 SLOTS;5,686.0-5,710.0—.-0 SLOTS;5,802.06,049.0 SLOTS;6,384.0-6,846.0 SLOTS;7,524.67,774.0....._.4 SLOTS,8144.0-8,545.0 1-- 1 _1 w iir SLOTS;9,087.05,427.0 SLOTS;9,705.09,768.0 - ( SLOTS;10,288.0-10,592.0 ] L- SLOTS;11,179.0-11,365.0 A-SAND LINER;4,11702.9-1 Ill/ ,400.0 1 KUP1J-164L1 ConocoPhillips 1 Well AttriW Max Anil D TD Field Name Wellbore API/UWI Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) Alaska.1110. '" WEST SAK 500292327860 INJ 95.29 9,395.80 11,472.0 Comment H2S(ppm) Date Annotation -End Date IKB-Grd(ft) Rig Release Date ... SSSV:NIPPLE Last WO: 31.01 1215/2005 1J-164L1,5/30/2018 6:54:06AM Last Tag Vertical schematic(actual) Annotation End Date Depth(ftKB) Last Mod By Last Tag: Imosbor HANGER;22.2 Last Rev Reason ,,,,,,,,,,, a._r :er Annotation End Date Last Mod By �rj:��' REV REASON:INSTALL DB PLUG,TYPE-I DIVERTER AND TYPE-II 409/2018 raffep CONDUCTOR Insulated;30.0- 1 I • LEEVE 1080 1� CasingStrings NIPPLE;474.9 #. g I III I Casing Description O0(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtJLen(I...Grade Top Thread B-SAND LINER 141/2 13.96 14,567.4 1114520 13,612.0 112.60 IL-80 IIBT SURFACE;29.6-2,332.8 Liner Details GAS LIFT;2,336.4 Nominal ID Top(kKB) Top(TVD)(ftKB) Top Incl(7 Item Des Com (in) 4,587.4 3,510.3 80.19 HANGER Baker Mod El FHH(Inside Casing 16.75') 3.930 GAS LIFT;3,902.6 4,604.7 3,513.1 81.07 HANGER Baker Mod Bt FHH(Outside Casing 6.19') 3.688 SLEEVE-0;4,137.9 4,612.3 3,514.4 81.67 SWIVEL Baker Casing Swivel 3.960 • 8,803.4 3,576.D 87.05 SWELL PKR 4-1/2",Swell Packer,BTC 3.960 LOCATOR;4,183.2 I,_0 9,462.5 3,555.3 94.72 SWELL PKR 4-1/2",Swell Packer,BTC 3.960 SEAL ASSY;4,184.9 11,420.1 3,611.1 88.35 XO Reducing 4-1/2"X 3-1/2"XO sub 3.500 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Topincl ISO SLEEVE;4,236.0 /1 !1 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) D-SAND LINER;4,246.6- 8,226.0 3,553.1 88.48 CMT Retainer BAKER INFLATABLE CEMENT RETAINER-MID 11/2/2010 'fl 11,502.61 ra ELEMENT 8231' D-SAND WINDOW;4,248.0- �" 4,2580 4 I 9,000.0 3,585.9 89.63 CMT Retainer BAKER INFLATABLE CEMENT RETAINER SET IN L1 8/6/2009 LINER(OAL=2.5"x9.4') 111 9,200.0 3,576.9 93.95 PLUG B-SAND BAKER IBP(2.125"x 10.53) 1/26/2008 0.000 D LINER LEM;4,187.1<,375.0 art Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots t Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com DIVERTER;4,58O.0 • 4,661.0 5,127.0 3,519.8 3,526.0 WS B,1J-164L1 11/19/2005 32.0 SLOTS ALL B-SAND SLOTS= INTERMEDIATE;27.35,358.0; 1 it I Alternating Slotted/Blank B LINER LEM;4,345.6-4,748.5 Pipe 0.125"z2.5"z32 spf 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft.non- slotted ends 5,399.0 5,862.0 3,531.3 3,526.6 WS B,1J-164L1 11/19/2005 32.0 SLOTS - 6,140.0 6,605.0 3,529.1 3,528.5 WS B,1J-164L1 11/19/2005 32.0 SLOTS SLOTS;4,681.0.5,127.0 - 6,884.0 7,283.0 3,528.1 3,5312 WS B,1J-164L1 11/19/2005 32.0 SLOTS - 7,562.0 8,148.0 3,538.0 3,551.9 WS B,1J-164L1 11/19/2005 32.0 SLOTS - 8,300.0 8,794.0 3,555.9 3,575.5 WS B,1J-164L1 11/19/2005 32.0 SLOTS 8,550.0 9,555.0 3,565.9 3,548.4 WS B,1J-164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG I- PERFS,BH CHARGES,31 SLOTS;5,399.0-5,862 0 1CHARGES • I` 9,132.0 9,137.0 3,581.4 3,581.1 WS B,1J-164L1 8/4/2009 6.0 PERF CT Perfs,60 degree phase `- pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS B,1J-164L1 11/19/2005 32.0 SLOTS • 10,035.0 10,591.0 3,548.2 3,578.7 WS B,1J-164L1 11/19/2005 32.0 SLOTS SLOTS;6,144.0-6,605.0 10,927.0 11,389.0 3,593.5 3,610.1 WS B,1J-164L1 11/19/2005 32.0 SLOTS - Cement Squeezes - Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn - 8,200.0 9,400.0 3,552.5 3,560.8 CMT SQZ 11/2/2010 Notes:General&Safety - End Date Annotation SLOTS;6,684.47,283.0 12/4/2005 NOTE:MULTI-LATERAL WELL:A-SAND(1J-164),B-SAND(1J-164L1),D-SAND(1J-164L2) 6/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SLOTS;7,562.0-8,148.0 CMT SOZ;8,200.0 ftKB CMT Retainer;8,226.0 SLOTS;8,300.0-8,794.0 CMT Retainer;9,000.0 SQZ;8,550.0-9,555.0 PERF;9,132.0-9,137.0 PLUG;9,200.0 SLOTS;9,477.0-9,788.0 SLOTS;10,035.410,591.0 SLOTS;10,927.0-11,389.0 8-SAND LINER;4,587.4lit - 11,452.0 • • Proposed 1J-164L1 to 1J-166L1 MARCIT Treatment of B MBE 1J-164L1 is a West Sak B Sd horizontal injector lateral. An initial MBE from 1J-164 to 1J-166 offset producer occurred January 2008. On 1/26/08, an IBP was set at 9200' RKB in a 683' blank section of 4.5 liner in 1J-164L1 to isolate the MBE, but communication resumed on 5/24/09 to the B MBE. A 6/1/09 IPROF showed 100% of PWI entering 1J-164L1. A 6/15/09 IPROF in 164L1 showed 100% of flow bypassing a swell packer on the 4.5" liner at 8803' RKB to a B MBE located toward the toe of the lateral, but no flow was seen going by the IBP at 9200' inside liner. All flow to B MBE was seen exiting to liner x OH annulus. On 8/4/09, 5' of 'big hole' perfs were shot above the IBP. On 8/5/09, CT Fluff & Stuffed perf debris and circulated lubricant. On 8/6/09, an inflatable Cmt Retainer was set at 9000' RKB at 135' above the perfs to complete a `straddle' in 4.5" liner, then 24 bbls of 8.5 ppg UltraLite Cement was pumped into the straddle to Cement 200' inside 4.5 liner and 683' of adjacent liner x OH annulus to isolate B MBE. This MBE isolation lasted 7 months until communication resumed to toe B MBE (per 4/6/10 B IPROF). On 10/31/10, 5' of big hole perfs were shot at 8550 - 8555' RKB. On 11/2/10, a Cmt Retainer was set at 8231' RKB and 28 bbls of Ultra-Lite 8.5 ppg Cement was pumped to add additional Cement Plug to re-isolate the toe B MBE. This successful job allowed 1J-164L1 BOI until 2018, before a new MBE occurred. A 4/7/18 IPROF saw all flow enter B Lat, and 4/24/18 B IPROF revealed a new B MBE present at 5100' RKB. This confirms the Cement Plug still effectively isolates the toe B MBE of 2008. 1J-164 is currently configured with A Lat Plug set, B Diverter set, and D Iso-Sly set. Per B Diverter issues during B (PROF, successful CT entry into the B Lat has been hit or miss lately. Proposed Procedure: 1) Coil Tubing: RIH with IBP on CT through B Diverter to set IBP at 5263' RKB in middle of 272' OAL Blank section of 4.5" Liner. If more than 3 RIH attempts to pass B Diverter with IBP have failed, we may halt IBP set efforts to pump a MARCIT job without an IBP set. POOH with CT. RD. 2) Accelerated MARCIT Treatment to B MBE: RU Pumping unit & PT equipment. SI 1J-164L1 SWI & MBE offset 1J-166 producer. Fullbore Pump: a) 50 bbls of 2% KCL Brine Pre-Flush at 1 bpm to establish injectivity to MBE at —5100' RKB, then b) 30 bbls of 10000 ppm Lead Linear Gel Spacer (mixed in 2% KCL Brine) at 1 bpm, then c) 80 bbls of Accelerated X-linked MARCIT Gel at 10000 ppm (in 2% KCL Brine) at —0.75 bpm, then d) 35 bbls 10000 ppm Tail Linear Gel Spacer (mixed in 2% KCL Brine) at —0.75 bpm, then e) 10.5 bbls 2% KCL Brine Spacer at —0.75 bpm, then f) 32 bbls Diesel FP at —0.75 bpm, then g) SD pumping & RD pumping equipment. SD is —3.4 hrs after first bbl of X-linked Gel was pumped, to leave viscous Moderately Deformable Non-Flowing Gel in the B MBE at SD. 3) Coil Tubing: (perform if IBP was set per Step 1 above): RIH & latch IBP set at —5263' RKB. POOH w/IBP. RD CTU. Put 1J-164L1 BOI to evaluate treatment. JWP 5/31/2018 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o<~~ - .~ ~ S Well History File Identifier Organizing (aone> RE CAN Color ltems: ^ Greyscaie Items: Two-sided IIIIIIIIIIIIIIIIIII DIGITAL DATA Diskettes, No. ^ Other, No/Type: Re,~a~~e.cea Illlllllltllllllll ^ Poor Quality Originals: ^ Other: NOTES: BY: Date: T /~~ OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: lsl ~~~ t ~ Project Proofing III IIIIIIIIIII I11II BY: Maria Date: ~ D V !s/ Scanning Preparation _~ x 30 = _~ + ,~ ~ =TOTAL PAGES, (Count does not include cover sheet) ~n /~ , f BY: Maria Date: ~ . ~ ~ //~ 7~i /s/ y v I ~" Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: __~YES NO BY: Maria Date: ~,~' ~'f 0 ~ /s/ Inn Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO 1 BY: Maria Date: /s/ Scanning is compete at this point unless rescanning is required. III II'I II I II II I I III Rescanned fllllfllllllll IIIII BY: Maria Date: ls/ Comments about this file: Quality Checked III IIIII III II11 III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALAS•IL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r" Rug Perforations r Stimulate r Other go- " Matrix Bypass Alter Casing P Tubing P New Pool Waiver Isolation A g 9 � T ime Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 4 205 - 145 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 .0 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25650 — 1J -164L1 9. Field /Pool(s): -, Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11472 feet Plugs (measured) 9200 true vertical 3613 feet Junk (measured) 8226', 9000' Effective Depth measured 11451 feet Packer (measured) 0 true vertical 3612 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108 SURFACE 2303 10.75 2333 2202 INTERMEDIATE 5330 7.625 5358 � 3656 B -SAND LINER 6865 7.625 �� JAN 1 . 2 n 3612 Perforation depth: Measured depth: slotted liner from 4635' - 11389' 1 t True Vertical Depth: 3525' -3610' )74-41/34") - op ,sr- 45s Cl(- NOV 3 0 2010 Nes Tubing (size, grade, MD, and TVD) 4.5, L -80, 4183 MD, 3423 TVD es a Oil & G d' Cana. Comm $$slot Packers & SSSV (type, MD, and TVD) no packer ,";r: Or'it0, Camco No - Go Nipple @ 475' MD and 475' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na na 479 Subsequent to operation na na 1236 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory Development f Service :, Stratigraphic 15. Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations _ XXX GSTOR r WIND Iv WAG r GINJ r SUSP r SPLUG r , 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'sundry Number or N/A if C.O. Exempt: (i 2 310 -300 Contact Randy Kanady aC� 265 -6471 11 __Z '1_ (c) Printed Name Randy Kanady Title Wells E ineer Signature Phone: 265 -6471 Date RBDMS NOV 3 0 2010, 1 t7-1 % 0 Form 10 -404 Revised 10/2010 Submit Original Only f .7, /v 1J -164L1 Well Work Summary DATE SUMMARY 10/30/10 FISH TYPE # 1 ISO SLEEVE Fa B SAND LATERAL @ 4611 MD, SET Tik # 1 DIVERTER IN THE B SAND LATERAL @ 4611 MD, IN PROGRESS, 10/31/10 PERFORM FLUFF & STUFF W/ SAFE LUBE S WATER FROM 4300' TO 8600' MD, PERFORATE 5 FT. OF THE B SAND LATERAL FROM 8550' FT TO 8555' CORRECTED DEPTH. 11/1/10 Fluff and stuff "B" later with SafeLube from 4200' to 9100'. Diesel from surface down to 4200'. 11/2/10 SET 2.5" INFLATABLE CEMENT RETAINER IN B -LAT AT 8231' CTMD (MID ELEMENT), PUMPED A TOTAL OF 28bbls Ultra - LiteCrete W/ 2 PPB CemNet BELOW RETAINER LEAVING 3/4 bbls ON TOP. AVERAGE PRESSURE WILL PUMPING CEMENT WAS 1960# CIRCULATING PRESSURE @ .6 bpm & 512 PSI WHP. DISPLACED WITH WATER TO D -LAT WHILE POOH 1:1. WELL FREEZE PROTECTED WITH 37bbls DIESEL.TURN WELL OVER TO DSO TO REMAIN SHUT IN FOR NO LESS THAN 5 DAYS. ( COMPLETE) • Conoco 1 g a : y�ell Attributes KU l P ama Wei stains l c a , Angle & MD TD 64L1 J O 64L1 Akis In W f V * Ik - Comment 860 lWEST SAK [Date nn l INJ I M 9 9,395.80 11,472. ) ( ppm) End Date 'KB - rd (ft) Rig Release Date SSSV: NIPPLE Last WO: 31.01 12/5/2005 Well Goan 1J-164L 11/4/2010 9.2404 AM _ -T A .. __ Schematic Actual Annotation Depth (ftKB) I End Date Annotation Last Mod By End Dab Last Tag I Rev Reason: Set Diverter B -Lat, Pull ISO SLV, Imosbor 11/4/2010 HANGeR. 23 -Q 60 02005.022..2290 ' . " " Casing Strings "` `c Casing Description String 0... String ID . .. p (ftKB) Set Depth (f... Set Depth (TVD). in Strg Wt. String... String Top Thrd BAND LINER 4 1/2 3 958 I To 4,587 4 I 11,452 0 I 3,612 0 ` 12 60 I L 80 I IBT CONDUCTOR 1 � _.. _.. _..- .. -1 Insulated, 0 -108 3' - ` Liner Details - NIPPLE, 475- .e. Top - - - -- o --- - "` " (TVD) Top Inc! Nonni_ - Top ( ftKB) ( °) Item Description Comment ID (in) SURFACE, ,,, "" 4,587.4 3,510.4 80.19 HANGER Baker Mod B1 FHH ( Inside Casing 16.75') 4.500 30 - 2,333 --- _. ,..... .�__ GAS LIFT, 4,604.1 3,529.4 93.53 HANGER Baker Mod B1 FHH ( Outside Casing 6.19') 4.500 2,336 eta 4,612.3 3,528.5 93.35 SWIVEL Baker Casing Swivel 3.958 OW GAS LIFT, 8,803.4 3,575.8 86.44 SWELL PKR 4 -1/2 ", Swell Packer, BTC 3,903 JAN 9,462.5 3,555.4 94.72 SWELL PKR 4 -1/2 ", Swell Packer, BTC ■ MOM SLEEVE-q__ 11 A20. 3,611.1 88.37 4 X0 5x3.5 4 - 1/2" X 3 - 1/2" XO sub 3.500 4,138 _.. mow LOCATOR, � ttl .-,: Other In Holrelineretrievable plugs, valves, pumps, fish, etc.) 4,183 = Top Depth - - - -- - - SEAL ASSY, _ -_ (TVD) Top Inc! 4,185 Top ftK6 (ftKB) J' -- p ( ) C) Description Comment Run Date ID (in) ritoollit 4,611.0 3,528.6 93.38 DIVERTER TYPE 1 DIVERTER 10/30/2010 ---'' 8,226.0 3,552.1 86.78 Cement BAKER INFLATABLE CEMENT RETAINER - MID 11/2/2010 Retainer ELEMENT8231' D - SAND WINDOW, 9,000.0 3,585.8 89.89 Cement - -- BAKER INFLATABLE CEMENT RETAINER SET IN L1 8/6/2009 0.000 4,248.4,258 Retainer LINER (OAL =2.5 "x9.4') °LINER LEM, I I 3.576.9' 93.92 _ - 4,187 - 4,375 _ 9200.0 PLUG BSAND BAKER IBP (2 125' x 10 53) 1/26/2008 0.000 4,661-5,127 Perforations & Slots 4.'-- BLINER ,611 PCI"tOra S DIVERTER, 4,346 <,748 hot Top (TVD) Btm (TVD) Dens NTERMEDWTE, , Top (ftKB) Btm (ftKBj IfIKB) (ftKB) Zone Date fah... Type Comment 27 - 5,358 4,661.0 5,127.0 3,524A 3,526.0 WS B, 1J -164L1 11/19/2005 32.0 Slots ALL B-SAND SLOTS = Alternating Slotted/Blank Pipe 0.125" x 2.5" x 32 spf © 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non - slotted ends 5,399.0 5,862.0 3,534.1 3,526.6 WS B, 1J -164L1 11/192005 32.0 _ -_ 6,140.0 6,605.0 3,527.9 3,528.5'WSB, 1J -164L1 11/19/2005 32.0 Slots 6,884.0 7,283.0 3,5272 3,531.7 WS B, 1J -164L1 11/192005 32.0 Slots 7,562.0 8,148.0 3,538.0 3,551.8 WS B, 1J -164L1 11/19/2005 32.0 Slots E 8,300.0 8,794.0 3,555.8 3,575.2 WS B, 1J -164L1 11/192005 32.0 Slots 8,550.0 9,555.0 3,565.9 3,548.3 WS 8, 1J -164L1 10/31/2010 6.0 SQZ PRE CEMENT PLUG PERFS, BH CHARGES, 31 CHARGES 9,132.0 9,137.0 3,580.9 3,580.7 WS 8, 1J -164L1 8/4/2009 6.0 PERF CT Perfs, 60 degree phase pre cement retainer for L1 liner 9,477.0 9,786.0 3,554.2 3,536.1 WS 8, 1J -164L1 11/19/2005 32.0 Slots 10,035.0 10,591.0 3,548.2 3,578.8 WS B, 1J -164L1 11/19/2005 32.0 Slots ,.,,, !_,. Slots, 5,395 - 5,862 10,927.0 11,389.0 3593.4 3,610.2 WS B, 1J -164L1 11/19/2005 32.0 Slots "JL Notes: General & Safety _ " End Date Annotation " -f I-- 12/4/2005 NOTE: MULTI - LATERAL WELL: A -SAND (1J-164), B -SAND (1J- 164L1), D -SAND (1J- 164L2) __ __ 6/21/2009 NOTE: VIEW SCHEMA [IC w /Alaska Schematic9.0 Slots, 6,140.6,fi05 �''' F. Slots, 6,884 -7,283 77 " .e Sl, ots 7,562-8,148 Cement Retainer, 8,226 1 " I Slots, 8,300 -8,794 Cement Retainer, 9,000 SQZ, 8,550-9,555 �___ 05. 1 PERF, 9,132.9,137 PLUG, 9,200 CMT SOZ, 8,200 �,..;..... Sloes, - '- -' 9,47] -9,786 ■ .._.- __... _. .... """ 1 Mandrel Details Slats, •� Top Depth Top Port 10,03510591 i BSAND • (TIM) I cl OD Valve Latch Size TRO Run 3014 Stn Top(ft683 (ftKB) C) Make Model (in) Sere TYPe Type (m) (psi) Run Date Com... 10,927 �__ ____ 7 1 777 1 2,336.5 2,207.4 26.03 CAMCO KBG 1 GAS LIFT DMY BK - 5 0.000 0.0 3/24/2006 _ LINER,""�� TD 4,5 164L ' 2 3,902.5 •2 3,336.8 72.01 CAMCO KBG 1 GAS LIFT DMY BK - 5 0.000 0.0 3/24/2006 11,472 M A~ ~ ~ 201 ~ STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISS~ ~ack~~"~ilkt,9~t'`nn~ c~oir~~~T OF SUNDRY WELL OPERATIONS 1. operations Performed: pmt; ~ j Faepair w ell ~ Plug F~rforations ~ Stimulate ^ Other ~ Isolated B sand Alter Casing ~ Pull Tubing ~ Perforate New Pbol ^ Waiver ~ Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: ~ Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Expbratory ~~ 205-145 3. Address: Stratigraphic [' Service r lE~ API Number. P. O. Box 100360, An horage, Alaska 99510 50-029-23278-60 7. Property Designation: 8. Well Name and Number: ADL 25661, 25650 ~ 1J-164L1 9. Field/Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11472 feet Plugs (measured) 9200 true vertical 3613 feet Junk (measured) retainer @ 9000' Effective Depth measured 11451 feet Packer (measured) true vertical 3612 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 108 20 108 108 0 0 SURFACE 2303 10.75 2333 2202 0 0 INTERMEDIATE 4566 7.625 4593 3656 0 0 B-SAND LINER 6865 7.625 11452 3612 0 0 Perforation depth: Measured depth: Slots: 4661'-5127';5399'-5862';6140'-6605';6884'-7283';7562'-8148';8300'-8794';9132'-9137';9477'-9786';10035'-10591';10927'-11389' True Vertical Depth: Slots: 3524'-3526';3534'-3527';3528'-3532';3538'-3552;3556'-3575';3581'-3581 ;3554'-3536';3548'-3579';3593'-3610' Tubing (size, grade, MD, and TVD) 4.5, L-80, 4222 MD, 3423 TVD ,,~ ,k;.~it~i~_ f ; ~, ~r s ! 0'(~i Packers &SSSV (type, MD, and TVD) No packer SSSV=NIPPLE @ 475 MD and 475 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressun; Tubing Pressure Prior to well operation 854 884 261 Subsequent to operation 1114 207 335 13. Attachments 'h~. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development [ Service r . Well Status after work: Oil r` Gas ~ WDSPL [ Daily Report of Welt Operations ~, GSTOR ~ WAG ~ GASINJ r WINJ ~ SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A contact Bob Christensen/Darrell Hum Ohre Printed Name b D. C istens Title Production Engineering Specialist Signature Phone: 659-7535 Date ~~~~_ / RBDMS ~-y 1 s zo~~ ~ ~ ~ ~~ Form 10-404 Revised 7/2009 ~~~~j~~~ Submit Original Only • • 1J-164L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/07/10 Injector 1J-164L1 had a B sand MBE to offset producer 1J-166 on March 2, 2010. PULL B-LEM TYPE 1 DIVERTER FROM 4611' CTMD. RUN B-LEM TYPE1 ISOLATION SLEEVE AND SET AT 4611' CTMD. WELL LEFT ON INJECTION. JOB COMPLETE. ~ KUP 1J-164 . ~,. ' ~Or1000PF'll~~lp5 ell Attributes ax An le 8 MD TD ,1i I M ~ ~~ WeIlDora APINWI Fieltl Name Well SbN• Incl (°) MD (Ftl(B) Act Btm (ftKB) 500292327800 WEST SAK INJ 94.67 9,091.14 11,400.0 Comment H23 (ppm) Dale Annotation End Date KB-Grd (R) Rig Release Dat "' Wall Confl 1J 1814H8201D B a5 01 AM SSSV: NIPPLE Last WO: 31.01 12/5/2005 - . . - Schemetk-Actual Annotation Deptll (RI(B) End Dale An notetlon Last Mo d ._ Entl Dale HANGER, za Last Tag: Rev Reason: Pull Diverter, Set B-LEM ISO SLV Imosbor 4/18/2011 CONDUCTOR Inama,eaD-,oe Casin Strin s NIPPLE. a75 i i Casing Deacrlptlon String 0... String ID ... Top (ttKB) Sat Oaplh (I... Set Oepth (TVD) ... String Wt... String ... String Top Thrd - s ~ a33 - - - _ - ~ - - - - - - CONDUCTOR 20 19.124 0.0 108.0 108.0 91.50 H-40 WELDED Insulated GAS LIF7, Caaing Descriptlon String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd asos SURFACE 103/4 9.794 29.8 2,332.8 2,204.1 45.50 L-80 BTC SLEEVE-C, " t Casing Descriptlon String 0... SVing ID ... Top (ftNB) Set Depth (f... Sel Depth (TVD) ... String Wt... String ... String Top Thrd LOCATOR, INTERMEDIATE 75J8 6.875 27.1 5,358.0 3,660.0 29.70 L-80 BTC-M 0,183 SEAL ASSY ~ Casing Descriptlon String 0... 341ng ID ... Top (fIKB) Sat Depth (/... Set Depth (TVD) ... String WL.. Shing ... String Top Thrd a,1es D-SAND WINDOW 7 5.625 4,248.0 4,258.0 3,442.3 12.60 L-80 IBTM D-SAND Casing Descriptlon String 0... String ID ... Top (RKB) 581 Depth (/... Set DepN (TVD) ... String Wt... String ... String Top Thm wlNDOw, a,zaa-a,zse BSAND WINDOW 7 5.625 4,594.0 4,604.0 3,513.2 12.60 L-80 IBTM D-SAND LEM, Casing Deacrlptlon String 0... String ID ... Top (RKB) Sat Depth (/... Set Depth (TVD) ... String Wt... String ... String Top Thrd a,1ez43ie s-SAND DSAND LEM 41/2 2.958 4,187.1 4,375.0 3,474.0 12.60 L-80 IBT WINDOW, Casing Deacrlptlon String 0... String ID ... Top (/tKB) Sat Depth (/... Set Depth (TVD) ... String Wt... String ... String Top Thrd a ssa-a soa B BAND LEM BSAND LEM 4 112 3.958 4,345.8 4,748.5 3,542.9 12.60 L-80 - q yys-q 7qg ~ Casing Descriptlon String 0... String ID ... Top (ttl(B) Set Oepth (/... Set Depth (TVD) ... String Wt... String ... String Top ThrO rERMEDIATE, A SAND LINER 4 1l2 3.958 4.703.0 11.400.0 3.745.4 12.60 L-80 IBT 3.958 ~~~ ~ ' 22.5 e ~T-t Dab t G h Comment DttedlBlank Pipe 0.125" x 2.5" x 32 f @ 4 Circumferential adjacent N3, 3" Centers staggered 18 deg., 3 rwn-slotted ends IRKS) I Incl I I I OD I I Vatvs Latch Sixe TRO RunI Stn Tee I/fl(BI l ) (°) Make Madel Iinl Serv Type Type (nl (psi) Run Date Com... 04/22/10 l schUerger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~~-1~~L2 Job B Log Description NO.5511 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL COlor CD 1J-160L7 J-164L1 3N-08 BAUJ-00015 BAUJ-00014 BD68-00009 MEMORY INJECTION PROFILE ~ Q MEMORY INJECTKN PROFY.E MEMORY LDL 04/10/10 04/06/10 04/14/10 1 1 1 1 1 1 Please sign and return one copy of thla transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~~~ I~PR ~ ~ 2010 6~ 4R it4J7~. ~:~~~~ • '~{S , 1 • STATE OF ALASKA ~ ~~~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ;~~.9~ ",~~ ~ 1~~1~ REPORT OF SUNDRY WELL OPERATIOI~~~~ ~~~~ ~~at ~r~~~~, ~;~~~~,~~;~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ""`".~ r'~~?atnx ypass event ~~,,,` Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ ` Waiver ^ Time Extension ^ ~~~ Change Approved Program ^ Operat. Shutdown^ Perforate [] Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, II1C. Development ^ Exploratory ~ 205-145 /'~ 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23278-60 " 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-164L1 8. Property Designation: ~ 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11472' feet true vertical 3613' feet Plugs (measured) 9200' Effective Depth measured 11451' feet Junk (measured) retainer @ 9000' true vertical 3612' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2305' 10-3/4" 2333' 2202' INTERMEDIATE 5330' 7-5l8" 5358' 3656' B-SAND LINER 6865' 4.5" 11452' 3612' Perforation depth: Measured depth: slotted liner from 4635'-1 1389' true vertical depth: ~`, ~~f~ ~'~ i., _~~ ~, `~~'` 4:. t..`~t.~% ~.:~~„ `s ~ .~ ~~~~.~„I Tubing (size, grade, and measured depth) tubing in main wellbore , , Packers 8~ SSSV (type & measured depth) no packer nipple @ 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9000' 24 bb~s of 8.5 ppg LiteCRETE Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 945 -- Subsequent to operation 1132 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ~ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 309-232 ~ contact John Peirce @ 265-6471 Printed Name John Peirce T~tie Wells Engineer Q ~~Z ^~~ Signature ~ ~- Phone: 265-6471 Date ~+ ~+ P re b Sharon Allsu -Dr k 263-4612 ~~"~~ v = ~~' ', <; a,~- Form 10-404 Revised 04/2006 ~ ~ Uf'A.- ~~!~' ~`~ Za09 ~ ~ ~ ~ Submit Original Only 1J-164L1 Well Events Summary DATE SUMMARY 6/1/09 PERFORM MAINBORE IPROF T 690 CTMD, SHUT IN WELL @ FREEZE • PROTECTED. 6/14/09 WASHED ACROSS D~ B LEM.SET TYPE 1 DIVERTER ACROSS B-LEN @ 4598' CTMD.PERFORM FLUFF AND STUFF INSIDE B LATERAL DOWN TO 9112' CTMD.RETURN IN AM FOR IPROF. 6/15/09 USED MEMORY TOOLS TO PERFORM IPROF INSIDE B-LATERAL FROM 4575' CTMD TO 9100' CTMD. VERIFIED GOOD DATA. RETURN IN AM TO PULL DIVERTER FROM B-LATERAL LEM. 6/16/09 RIH WITH GS SPEAR AND PULLED DIVERTER FROM B-LEM @ 4598' CTMD.RETURN WELL TO INJECTION.JOB COMPLETE. 6/20/09 SET TYPE-1 ISOLATION SLEEVE IN THE B-LATERAL LEM (4580'). LEFT WELL H -IN AND FRE ZE PROTECTED. TURNED WELL BACK TO DSO. 7/3/09 PULLED ISO SLEEVE FROM B-SAND LEM @ 4573 CTMD, SET DIVERTER IN B- SAND LEM @ 4573 CTMD, WELL IS FREEZE PROTECTED. 7/26/09 PERFORMED SBHPS. RESULTS: 4360' ELMD: 1603 PSI; 86 DEG F AND GRADIENT STOPS OF 4150' ELMD: 1580 PSI; 83 DEG F AND 3850' ELMD: 1543 PSt; 83 DEG F. 8/4/09 RIH W/ HALLIBUTON PERF GUN TO 9160' CTMD. PUH TO 9132' CTMD TOP SHOT & PERFORATED 4.5" BLANK LINER FOR UP COMING CEMENT JOB, IN PROGRESS. 8/5/09 PERFORM FLUFF & STUFF ON L-1 LINER FROM 4300' CTMD TO 9150' CTMD W/ 290 BBLS OF SEAWATER W/ MI SAFE LUBE. IN PROGRESS. 8/6/09 SET BAKER INFLATABLE CEMENT RETAINER IN L-1 LAT @ 9000' CTMD. ~Dli~'E6" .5 LITE CRETE MIXED WITH FIBERS BELOW RETAINER. SPOTTED .05 BBLS OF CEMENT ON TOP OF RETAINER. MAX TREATING PSI WITH 24 BBLS OF CEMENT LOADED IN COIL=2160 PSI FINAL TREATING PSI BEFORE RELEASING FROM RETAINER=940 PSI INITIAL WHP=357 FINAL WHP=359 ConotoPhiilips il~._ an_t, ii f;. ~~~ KUP ~ 1J-164L1 ~ Well Attributes ~Max Angle & MD ~TD ~ ~ WellboreAPVUWI FieltlName ~~ ~iWellStatus Ilncl(°~ IMD(ftK8) A<tBhn~kKB) Da~e MAN6ER.23 - SEAL AS! a, i D-SAND wmoow. 4.248i.256 o-snNO ~eM, d,18]-4,3]5 ~ DIVERTER, 4,5]5 B-SAND LEM. S~oes, _ 5,399-5,86P Slms, 6,140-6.605 Slo~s, _ 6,884-7.283 Slo~s, ,__ 7,562-B.t48 Slots. _ B 300-8,]96 Cemenl _ Retainer. 9.000 PERF, 9,132-9.13]~ PLUG.9,200- Slots._ 9.677-9.786 Slots, 10,035-10,591 Slott, 10,92]-11.389--~- - B-SAND LINER, 4,58]~11.452 TD (t J-166L t l. 11.4]4 - ~ .__..~.._.. ~.....~ .,... .,.....~ ..... . ...a ... LINER 41/2 3.958 4,587.4 11,452.0 3612.0 ' 12.60_ ~.L-80 IBT lntailc ~ ~ ~ ~ Top Depth (ND) Top Incl Top (ftK8) (ryKg) (°) Itam Deser{ption Comment ID (in) 4,587.4 3,510.4 80.19 HANGER Baker Motl B7 FHH ( InsiOe Casing 16J5' ) 4.500 i 4,604.1 3,529.4 93.53 HANGER I Baker Mod 81 FHH ( Outside Casing 6.19' ) ~ 4.500 4,612.3I 3,528.5 93.35 SWIVEL BakerCasingSwivel 3.958 8,803.4 3.575.8 86 44'~ __ SWELL PKR 4-1/2", Swell Packer, BTC _- _. __.__ ,,46251 3,SSSA 94J2~SWELL PKR 4-1/2", Swell Packer, BTC 1 . ._ _____.__..-__. _. - ____ 11.420.1 ' 3,611.1 88.37 XO 45x3.5 4-1/2" X 3-VY' XO sub 3.500 . . ..__..___- - . .__ - Other In Hole (wreline retrievable_plugs, valves, pumps, fish, etc.) ~ TopDepthl ~ ~ ~ I (T~D) . Top Incl ~. Top (ftKB) (ftK6~ (°) Description Commant Run Date ID (in) 9,000 3.SR5.8 89.89 Cement BAKER INFLATABLE CEMENT RETAINER SET IN L1 8/6/2009 0.000 i Retainer ;~LINER (OAl.=2 5"x9 4') ~ ~ . ~ i . _.__ . ._ 9,200 3,576.9 93.92'IPLUG '~B-SAND BAKER IBP (2.125' x 10.53) 1126/2008 0.000 Perforations 8 Slots Shot Top (TVD) B~m ~ Dens Top(flKB) Btrn((iKH) (ftK8) (ftKB) Zona Dale (sh~~~ Type '.~ CommarA _ 4,661 5,727' 3,5244 3,5260~WS6,1J-164L7 ~71119l2005 32.OSIOtS 'ALLBSANDSLOTS=AItema[irg ', Sloned/Blank Pipe 0./25" x 25' x 32 spf aQ 4 Circumferemial a0jacent rows, 3" Cenrers staggered 18 deg., 3 it. non-slottetl ends 5,399 5,862 3534.1 3,526.6 WSB, 1J-764L7 11/19/2005 32.0 Slots 6,140 6,605 3.527.9 3,528.5 WSB, 1J-164L1 11/192005 320 Slots 6,884 7,283 3,5272 3,531J WSB, 1J-164L7 , 11/192005 32.O; SIOts 7,562 8,148! 3,538.0 3,551.8 WSB, 1J-164L7 11/192005 320~ SIOts '~ 8,300 8,7941 3.555.8 3,5752 WS B, 1J-164L7 11/792005 32.0 Slots . - 9,132 9,137 3,580.9 3,SSOJ WSB,IJ-1641.1 8/42009 6.O PERF ~ CTPeds,60degreephasepre cement retainerfor L7 liner 9,47~ 9J861 3,5542 3,536.1 WS B, 1J-164L7 1 V7&2005 32.0 Slots - 10,035 1Q591; 3.5482 3,578.8 WSB, 1J-164L7 11/19/2005 32.OI SIOts ~ _ 10.927 11.389i 3.593.4 3.6102j WS6,. iJ-164L7 17/19/2005i 32.0 Slots I i ..__.._.. ~~~W~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job #, ~ ~^ 1 ' ~f~~.t ~ l::.` +~ ~~.~c Y. di` ~~. .l ~° ~.. J~ Log Description 07/17/09 NO. 5314 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color C~ i ~ LJ ,;,; ~ Please s+gn and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . - ~~ r ~ ~ . 4 i k~~ f~ t v k /:~~, h 5 3 f~ f ~ . ~ r ~ ~ h ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~ ~~ ~--~ ~ fi~ SARAH PALIN, GOVERNOR ~. _ ~ . ~ a.~ ~~ ' ~ c, a ._ 4 _ ~~` . ~_. ~~ ~. ° ~ ~~ "~ R~ ~ ~ ~ G~ ~ t' ~5~ 0~ ~~ ~5 ~~ 333 W. 7thAVENUE, SUITE 100 COI~TSERQA'1`IO1DT COrIl-IISSIOIIT % ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 ~ ~ FAX (907) 276-7542 Mr. John Pierce Wells Engineer ConocoPhillips Alaska, Inc. r~~~~'~~~~ ~ U i. ~~` ~~~~ P.O. Box 100360 Anchora.ge, Alaska 99510 ~,~j~ ~ ~~ Re: Kuparuk River F`ield, West Sak Oil Pool, 1J-164L1 ~~-" Sundry Number: 309-232 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. When providing 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 Corrunission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of July 2009 Encl. ~1~ ~I STATE OF ALASKA • ~~~~~~~ ~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ Q~ ~~0~ APPLICATION FOR SUNDRY APPROVAL '~I~, Zo a~,c 2s.2so ~~aska 0'I & Gas Con~~ ~ommissin~~ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver dr~~}~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ cement plugback Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ r'1~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ ~ 205-145 - 3. Address: Stratigraphic ~ Service O 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-60 ~ 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 Requires? Y2S ^ NO ~ 1J-164L1 ~ 9. Property Designation: ADL 25661,~25650 ~ 10. KB Elevation (ft): RK8 28' ~ 11. Field/Pool(s): ~ Kuparuk River Field / West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective ~epth nn~ (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11472' ' 3613' ~ 11451' ~ 3612' ~ 9200' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 2305' 10-3/4" 2333' 2202' INTERMEDIATE 5330' 7-5/8" 5358' 3656' B-SAND LINER 6865' 4.5" 11452' 3612' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 4635'-11389~ tubin in main we llbore Packers and SSSV Type: Packers and SSSV MD (ft) no packer nipple @ 475' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat July 18, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WtNJ 0' WDSPL ~ Commission Representative: 18. 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 (,c/ • ^ Phone 265-6471 Date 7~~"O~ Commission Use Onl hC~ t~ ~~ ~ Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~. ~-- Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~~~ APPROVED BY J _] ~ ~ Approved by: C M ISSIONER THE COMMISSION Date: '~ ~ Form 10-403 Revised 06/2006 U K I V( 1 Y~ L ~~~ .~~li~ SJ $~QQ~ Submit in Duplicate ~ ! • 1J-164 L1 Proposed Procedure for Matrix Bypass Event (MBE) Isolation 1J-164L1 is a horizontal injector completed in the West Sak B sand. The eartiest indications of an MBE in 1J-164 were seen in January 2008. This resulted in IPROF diagnostics and setting an inflatable bridge plug in 1J-164L1 at 9200' on 1/26/08. The IBP was set in a 683' section of blank 4.5" liner and it effectively isolated the MBE until 5/24/09 before indications of communication to an MBE again appeared. A mainbore IPROF on 6/1/09 showed 100% of PWI entering the B lateral (1J-164 L1). An IPROF on 6/15/09 in the B lateral showed 100% of flow going past a swell packer on the 4.5" liner at 8803' MD, thus the MBE must be below 8803'. No flow was seen through the liner past the IBP at 9200' RKB, thus all flow to the MBE is via the annulus. The swell packer at 8803' appears to be leaking. This allows communication to the MBE through the uncemented 6.75" OH x 4.5" liner annulus. This procedure will cement the annulus to halt communication to the MBE. Procedure: Coil Tubinq: RIH & pull the isolation sleeve (set 6/20/09 to isolate MBE) at 4587' RKB. Set a diverter in the `B' LEM at 4587' RKB. Slickline 2. Obtain SBHPS at the `B' LEM at ~4587' RKB. Coil Tubinq: 3. RIH with perforating gun. Shoot 5' of squeeze perforations at 9132-9137' RKB at the mid-point of a 683' section of blank 4.5" liner. 4. RIH with inflatable cement retainer. Set the cement retainer in blank 4.5" liner at ~9000' RKB. Circulate one CT volume of freshwater through cement retainer to the annulus (to verify good communication to the annulus), followed by 20 bbls of 8.5 ppg ultra- light weight cement at 1 bpm, followed by a freshwater spacer. PU to disconnect CT from retainer as the last barrel of cement passes through the cement retainer. POOH slow with CT displacing liner with water and tubing with diesel to surface. 5. Pull the diverter from the `B' LEM at 4587' RKB. Wait on cement at least 7 days then return 1J-164 to PWI. JWP 7/2/2009 1J-164 L1 Cement Plugback for MBE Isolation Procedure: 1) CT Perforate 5' interval 2) CT Set Cement Retainer 3) Pump 20 bbls 8.5 ppg Cmt at 0.5 bpm 4) Disconnect CT & POOH after 20 bbls of cement passes through retainer 4.5" Liner Volume from Cement Retainer to Bridge Plug is 3.0 bbls 4.5" Swell Packers Top Pkr 8803 - 8813' Btm Pkr 9462 - 9472' 4.5" Liner Slotted 8300 - 8794' Blank 8794 - 9477' Slotted 9477 - 9786' ~ 20 bbls Cement fills 200' Straddle in 4. 5" Liner & 683' of Blank Liner x OH Annulus to isolate MBE 6.75" OH 4.5" Liner ~ g~~ ~ Swell Set Perforate Bridge West Sak 8 Sand Packer Cement 9132 - 9137' Plug MBE somewhere at 8803' Retainer 9200' below 8800' in toe leaks to at 9000' puts perfs MBE at mid-point set 1/26/08 of 683' Blank JWP 7-2-09 KUP 1J-164L1 ~,, ,; ~ ; Ct~~to~illips , -„ ~ ~ : . ... ... .... ...: ~.: ,an ~i~ ~ v.-ru ~ r+ad~~3 ir We116oreAPWWI FieldName Incl~) MD~ttKB) IWeIISWtus ActBt (ftf(B~ ,. , ,... . «. . . 500292327860 WESTSAK ----- ~ INJ ~ 95.29~_9,39580 - ~ 11,472.0 ... .._.__ ._... ~ ~ ~ Comment H2S (ppm) Date iM otatbn End DMe KBGrd (ft) ~ Rig Releace Da~ ... . .SSSV:NIPPLE ~'iLastWO: 31.01 12/5/2005 ~~ :~ web,~ f qWt?~ary *: r ~~ Mnotation Depth (ftl(B) ~End Date _____ iAnnotffiion ~Laat Mod By ~End Date Last Tag: j Rev Reason: Set ISO Sleeve in B-Lateral i Imosbor ~ 6/21/2009 HANGER 23- ~~'„~~ ~~ E ,€ i'~ \\ ~~1,~.1E~~. '~.,, ,,, ~•~•.,: ~i`~' ,,,,. >,'~ \ ` ~ ~~~<_ ~ ;. . ._ . ._, . . , _., . . ., ,, : ; ~~' ,, ~ . ~ '~ ~:~~~. .:: .. ... g .. 'IStnnglD... :Str n SetOeptb(f... SMDepth~ND~._ StnngWt... Stnng.. Top~fiNB) , . StnnBTopThrd coNOUCroR , i ~ 2 BaSANDLINER ' 3 958 . 4 SS7 4 11,452.0 3 612 0 12 60 L 80 IBT i~:waeea, aios % NIPPLE.475 ~ ,.. .~~~`.' - -: > , .,,x° ~~ ' ~' , ~ . . ~ ,...;;,, .r .. \ ` a.; SURFACE, - T p Depth, ,,,,, , , , ~~ Jo-2,a93 ~ND) Tap Ind ~ ~ GAS LIFT. 2 336 TpP (~B) , ~ftKB) I. (°) ~', Comment Item De cription - ~~ ID 1 ( 4,587.4 3,510.4 ~ 80.19 HANGER ker Mod 81 FHH ( Inside Casing 16J5' ) '~~ 4Si GAS LIFT, I 3•~ 4,604.1 3,529.4. 93.53 HANGER ~ Baker Mod Bt FHH ( Outside Casing 6.19' ) : 4S~ SLEEVE-C, <,+~ ~ 4,612.3 , 3,5285~ 93.35 SWNEL BakerCasing Swivel ' 3.9! LOCATOR, ~ _ ~ <•» 8,803.4 3,575.51 86.44 SWELL PKR '4-t12", Swelt Packer, BTC SEAL ASSV, a,ias „ 9,462.5 ' 3,555.4 ~ 94J2 SWELL PKR 4-1/2", Swetl Packer, BTC , (rvo~ rop i~~i ~ ~ D-SANO To ~B (RKB) (°) Deseri Comment I Run Dah ID WINDOW.-- PI ) p~ion a.zmr.zse 4,579 3,509.0 80.30 SLEEVE-C &SAND LEM ISOLATION SLEEVE ~ ~~ 6/20I2009 2 ....... . 9200 3.576.9 93.92 PLUG ! BSAND BAKER IBP (2.125" x 10.531 J 7YL6I2008 rop ~rvo~ Btm (ND) ; i I oens ~ Top (Po(8) Btm (RKB) (RKB) (RKB) j Zone Date (sh~~• I Type Comment 4,661 5,127 3,524.4 3,526.OIWSB,IJ-164L1 11/19/2005 32.OSIots ALLB-SANDSIOTS=Altemating ! , , SlotteNBlank Pipe 0.125" x 2.5" x 32 I I ' spf @ 4 Circumferential adjacent i '~I rows, 3" Centers staggered 18 deg., 3 , , , i 4 ft. non-slotted ends I 1 I 11/19/2005 Sbh, 5,39SS,B82 Sbts, 6,f A06.805 Slois, 8.884-7.283 Sb~s, 7.562-8.748 Sbh, 8.300.8.794 PLUG, 9,200 Sbta, 9,4T/9,~85 Slots, 70.03570.597 Sbts, 10.927-11.369 B-SAN~ LINER, 4,58]-11.452 TD (iJ-164L1). 11.4]2 5,300 8,7941 3,555.8: 3,5752 WS B, 1J-164L1 11/192005 32Ai51ots - 9.477I 9,786~ 3,5542~ 3,536.1IWSB,IJ-164L1 11/19/Z005 32AISIots : 10,0351 10.5911. 3,548.21 3,578.8 WS B, 1J-164L1 ~11/19/2005 32.O~ISIots . , I Top Depth Top Port ( (ND) Incl ~I OD Valve ~-; Latch Size 7~y0 Run '~. Stn Tno Iftl(B1I (ftKB) (°) '~, Make Motlel (in) Serv TYPe ', TYPe (~~) IPSi) Run Date ~! Com... 2~207.4 ~~~a KUP 1J-164 , ~ ; Cttt°to~aPhillips ~~~~ ir~a~t~ ! ~ ~ a-~a -~ , . ~ ~~,~~ ~~ ; Wellbore APUUWI F~eld Name I Well Staha Ind () I,MD (ftKB) 1/1ct Btm ~Po(B) ~ ~ , « 500292327800 WESTSAK 'IINJ I 94.67 ~~ 9,091.14 ~ 17.400.0 Comment H2S (ppm) Dete !Mnotation End Date iK8-Grd (ft) Rig Release Dab ... _ ~~~ ,~~~~~~~~~.~RM - ~ SSSV: NIPPLE L I ILest WO: I_ 31.01 12/5@005 I Sd~ariatk.A~WeF ~~~ -: MnotMion Depth (fIHB) EnA Date Annotation Laat Mod By Entl DMe HnNCee, ra Last Tag: ~~ Rev Reason: Set ISO Sleeve in B-Lateral I Imosbor i 6/21/2009 CONDUCTOR ioswa«a. aioe ,-,. '~ECit) ~ '~ i i: ~ a ~ ': ~> ~ : ;:: ~ ~ t-. S~E ~~ : \ ~ ~. .; NIPPLE 475 ~ C ng Deacnption Stnng 0... St ~ng ID ... Top (flK8) Set Depth (f... Set Depth (ND~ . Stnng Wt... String ... String Top Thrd _ SURFACE aazssa~ _~ ~ CONDUCTOR 20 19.124 I 00 108.0 108.0 91.50 H-40 WELDED aas uFT. ~ . ~~ Insulated ~ ~~ 2'~ GASUFT.~ . . .: I Casm Deacrl tion 9 P~ Strin 0... 9 Strin ID._ 9 T HKO B ~SetDe h f I PI ) P~ (... SNDe h ND P~ ( )... Stnn Wt... g Strin 9... Strin To Thrd 9 P a,so3 ~~ SURFACE 10 3/4 9J94 ~ 29 S ~ 2,332.8 2,204.1 45.50 L-80 BTC SLEEVE-C, _ 4,139 I Casing Deswiption Stnng 0... Stnng ID ... Top (TtltB) ;Set Depth (f... SM Depth (ND~ ... I String Wt... Shing ... String 7op 7hrtl I ~ocnroR, INTERMEDIATE 75/8 6.875 271 '~~. 5,358.0 3,660.0 29J0 L-80 BTC-M 4,183 SEALASSY, 1 a,iesl ", ~~ I % Casing Descnption aSANDWINDOW String 0... 7 Stri~g ID ._ 5.625 Top (ltlte) ;Set Depth (L.. .':. 4,245.0 4,258.0 SM Depth (TVD) ... 3,442.3 String Wt... 12.60 String ... L-80 String 7op Thrd IBTM ~-SAND i I -~'~ Strin 0... Sh ISetDepth~f... T4 SMDepth~TVD~... SiringWt... Stnng... StringTopThrd qW~~°~' ~ ! , &SANDWINDOW ~ 5625 594.0 . 4,604.0 3,513.2 12.60 i L-80 IBTM o sAND LEM, ~ ii Casing Description String 0... String ID ... 7op (1tKB) i5et Depth (f... ' SM Depth (ND) ... String Wt... String ... String 7op Thrcl 4,187-0,375 :: ° s~eeve-c ! 0.SANDLEM I 41/2 2.958 4,187.1 ; 4,375.0 3,474.0 12.60 L-80 IBT . 4,57& ~ Casing Description String 0... String ID ... Top (Ttl(B) ~Set Depth (f... Set Depth (ND) ... String Wt.. Stnng ... String Top 7hrtl B-SAND ~ WINDOW -- ` I 8-SAND LEM '~~, 4 1@ 3.958 4,3458 ' 4,748.5 3,542.9 12.60 L-80 . q,5gyy,5pq I ~ I Caamg Deee pt IStr ng O Stnng ID Top (itl(B) iSet Depth (f SM Depth (7VD) .. String Wt... Stnng Str ng Top Thrd e-saNO ~eM, ; ~ A SAND LINER ~ 4 1/2 3 958 4 703 0 ~ 11 400 0 3 745.4 12.60 L-80 IBT a,aa~n,~ne NTERMEDIATE, II ' ~~~`% ' .'.; 3 '. , « ".' C k.G ~" ~.~ ~ .. ~: . -:, " : ' 't :y 1 f r !t{~^ ,'; ~ 27-5.350 sm~s . I ,I .. Top Depth ; ~, ,~, , ..o . ~ . e ... ... nl . .~ , .i , , . ~ , 5355-S,aw I (ND) Toplncl siots, I s,sess,~m Slols, '~ ~ ~I To pKg (ttKB) P (°) ~m Deseription Comment PACKER 'HRD' ZXP LINER TOP PACKER ID (ir 4.9E sio~, 6 384fi 848 I 5~ I 4 ~22 ~ 3,537.2 ~~ ~ ~ NIPPLE ---'"' ~ I 'RS' PACKOFF SEAL NIPPLE 4.8E -_ . . sio~s, , ~ sza~ na ~ ~ _ I 4.725.Oi 3,537.8 77.13 IHANGER FLEX-LOCKLINERHANGER 4.8C , , ~ 4 734 8 3 539 g 'SBE ~~22 190-07 CASING SEAL BORE EXTENSION 4J' sio 8 140.8 595 I I . . . • ~ ~ .. . ~ ~ sb~, ~~ 4.754.5 3,5442 77.40~XOBUSHING ~ _ XOBUSHING ~ 3.9~ 9.087-9, 427 sio~, ~~ 9 ]OS9 ]fifi ~~ 8,555.8~ 3,695.1 -~ ~88.9 SWELLPKR ; ,. --"'-- , , sro~s, II ~- ~ 9,W2.5 3 706.7 94 73 SWELL PKR , ~oaes-io.ssz ' . , .~ ~ I Sbis. . . ,., ~ ~ ,~. .. ~ :.~. ~ . : ~ ,. ,. ~j~ .~ . ;: ,: , ,: : ;h ~ ~ '~ . : . : : ,'',. .: : it~t]&11~385 A-SAND T bing Deacnpdon ~ St ing 0... '~String ID ._ T .,,, ,_ _.. : , . , op (ftl(B) ISM Depth (f... ~,Set Depth (TVD) . ~ . . Stnng Wt... Stnng .. Stnng Top ., ,,, , Thrd uNER, :;. ... TUBING 41/2 I 3.958 22.5 4221.8 ~ 3,434.7 ~ 12.60 L-80 IBT M a,~os-ii,ma TDl7J-160). ,,..,,~.,, ~.-3.~.. ,. i~~ ~ ~ ~ . ~ '.l , ~ ~ :: ~. -, / ; , ..~: ;--_ ; .; ~. [i ~ . ~ '~'. + - ,~ j 11~aao B-SAND . .,.,. - Top pDptA ~ . ' ~ ,, , .. ,,., , .....;. ., , ,.,,, I T \% Toplnel l 4~~~'~ ~N~Z Top (ftlCB) (RKB) I (°) Item Descriptbn ~ Comment ID Qr D-SAND I ~ ~ ~ 22.5 22.5 -0.07IHA NGER ' ~,VETCOGRAYTUBINGHANGER 4.5( 4,2461 1N503 . I i ~ .-.~. .. ....~ . ~ ..... ~..............~~.-...~~....~~__,...,~.~~.. ....~~~~ - ..~-. ' i '~.. '~. Shot , I. ~I Top (ND) Btm (ND) ~~i Dena ~ Top (RKB) i Btm (ftKB~'~~ (ftKB) (ftK8) 'I Zone ' Date (ch.- TYpe Comment i, 5,399;I 5,430'~I 3,663J 3,667.0, WS A2, 1J-164 i 11/122005 32.0 Slots ALL A-SAND SLOTS = Altemating i ', '~~~, Sbned/Blank Pipe 0.125" x 2.5" x 32 ~ i ~~, ~~. ~~, spT @ 4 Circumferential adjacent ~~ '~I . '~~, iows, 3" Centers staggered 18 deg., 3 ~, . ~~~. ~~~: '~.. ft. noo-slotted ends 5,586 5,7101i 3,686.9 3,696.8~WSA2,1J-164 '~,11/12/2005 32.O SIOts 5,802 6,049 3,697J 3,687.7,WSA2,1J-164 ~11/12/2005 ~ 32A SIots 6,384 I 6,846 3,671.8 3,674.OIWSA2,1J-164 'i11/12/2005 32.O SIOts i 7,524 7,774 3,697.6 3,696.6~~~WS A2, 1J-164 11/12/2005 32.0 Slots 8,144 8,545 3,686.0 3,695.OIWSA2,1J-164 ''~~,11/12/2005 32.O SIOts ~ 9,087 9,427 3,705.5 3,684.3iWSA2,1J-164 111/1Z2005 32A SIots 9,705 9,766I 3,676.5 3,680.OiYVS A2, 1J-164 '~.11/1y2005 32.0 Slots ~. 10,286 10,592I 3,692.1 3,709.4!WSA2,1J-164 111/1y2005 32.O SIots ~; 11,179 17,3651 3,730J 3,743.2iWSA2,1J-164 111/1Z2005 32.O SIots Schema6c9.0 Top Depth Top I I PoA 'I (N0~ Inel OD Valve Latch Size TRORUn~ ~ StnlTop~llKB) (RKB) (°l I Make I Model (~) I Serv TYPe TYPe I lin) (psi) I RunOMe i Com... i 1 i, 2,336.5 2,207.4 26.03 CAMCO KBG2 1,GAS LIFT DMY BK-5 0.000 0.0~3/24/2006 ~i •. S~ ~~r~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051450 Well Name/No. KUPARUK RIV U WSAK 1J-164L1 Operator CONOCOPHILLIPS ALASKA INC MD 11472 TVD 3613 REQUIRED INFORMATION Completion Date 12/5/2005 Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type ed/Frmt Number Name D Lis 13766 Induction/Resistivity i n D Asc Directional Survey 13766 LIS Verification (~ Lis 15025 Induction/Resistivity ', Log Injection Profile Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? -Y'7-N"`~ Analysis Y~tv" Received? Comments: Completion Status 1-OIL Current Status 1WINJ Samples No API No. 50-029-23278-60-00 Directional S Interval Start Stop (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 2297 11406 Open 4/6/2006 GR EWR4 ABI ROP ACAL j PWD GeoPilot 0 0 Open 1/17/2006 DEFINITIVE SURVEY 2297 11406 Open 4/6/2006 GR EWR4 ABI ROP ACAL I PWD GeoPilot 2297 11472 Open 4/17/2007 LIS Veri, FR, FET, ROP w/Graphics CGM, EMF, PDF 5 Blu 1 4552 9488 Case 1/28/2008 Mem Injection Profile, Mem Lee CCL, GR, PRES, Temp, Spin 22-Jan-2008 Sample Set Sent Received Number Comments Daily History Received? ~--'" Formation Tops ~/ N t DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051450 Well Name/No. KUPARUK RIV U WSAK 1J-164L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23278-60-00 MD 11472 TVD 3613 Com I tion Date 12/5/2005 Completion Status 1-OIL Current Status 1WINJ UIC Y Compliance Reviewed By: _ ________ ___-__ _ __ _ __ ______- Date: ~_~,~~ L,~~ ~~i~~~1~L1~~1- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Well Job # Log Description Date BL Kuparuk Color CD 01 /25/08 2B-13 11996584 PRODUCTION PROFILE gj~ - j p 01110/08 1 1E-112 11994598 INJECTION PROFILE V= - g 01/11/08 1 1J-164L1 12005203 MEM INJECTION•PROFILE ~Q~j - ~ J ~~ 01122108 1 2M-20 11996596 PRODUCTION PROFILE -Q~-( 01/22/08 1 1C-170 11970605 USIT 12/02/07 1 2G-O6 11994596 PSP MULTI-FINGER CALIPER - 01/10/08 1 3K-102 11994599 MDT ~ - 01114/08 1 1J-127 11994603 INJECTION PROFILE {)1',~ ~O(a-p~(~- 01121/08 1 2T-21 11839639 RST 1 ~ 08/02/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~b Ll 1 / VV 1 •lV1vil.l.Vta Vii iir .. a~~'.vu~ a.r au. ~ ~.. . v ~ ~.. ~. .. .~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, iJ-102, iJ-127, 1J-164, iJ-180 Tom ;Jim, The LPP/SSV's on all ofi the ~J!/est Sak DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I ~niasn't sure ifi you ~nranted the permit to drill number for the mainbore only or the laterals as we!I so I included both. WELL ID Permit to ®rill No. 1E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-"112 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1), 207-029 (L?_) 1J-"127 206-047 (MAINBORE), 206-048 (L1 ), 206-049 (L2~ 1J-160 207-015 (N1All~fBORE), 207-016 (L1), 207-017 (L2) ..-~i 1J-164 205-144 (MAINBORE), 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAiNBORE), 206-151 (L1) Note: 1J-105 and 1J-1 G0 were defeated in early July 2007,. before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Flat Hunt /Pete Nezaticky /Eric Hollar NSK Vilest Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1G38@ConocoPhillips.com WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-164, L1, L2 & L2 PB1, AK-MW-4025932 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 1J-164 1J-164 Ll, 1J-164 LZ & 1J-164 L2 PBl: LIS & Digital Log Images: 50-029-23278-00, 60, 61, 70. ~ -- . ; ,~ ° ,~ ~v~ ~~~;7 ~§ _; , f u~ ~ aos - ~v~~ ~ ~ soay Vic 205 =t~1S '~ t5 daS U S- C 2 b 5- /~/~ '~ I Sba ~ ~ I S ba"~- LI April 16, 2007 1 CD Rom STATE OF ALASKA ; ~R Q ~ ~c~s ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska t3a~ s~ REPORT OF SUNDRY WELL OPERATIONS ~~~v e,~,~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other , ~ tyd to WINJe~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-145 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-164L1 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11472' feet true vertical 3613' feet Plugs (measured) Effective Depth measured 11451 feet Junk (measured) true vertical 3612 feet 4-1/2" Casing Length ~ Size MD - TVD -_ Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2223' 10-3/4" 2332' 2203' INTERMEDIATE 5249' 7-5/8" 5358' 3443' PROD. CASING 1' 5-1/2" 4249' 3512' WINDOW B-SAN 1' 5-1/2" 4596' Perforation depth: Measured depth: None true vertical depth: None Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4221' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2053 2678 850 360 Subsequent to operation 2115 1000 346 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt ®~ '" ~Q contact Robert D. Christensen Printed Name Title Production Engineering Technician Signature Phone 907-659-7535 Date ~ ~ ®~ S BFI. ~~~ ~ zoos `~~, Form 10-404 Revised 04/2004 _ f~ ~.~, s!~i~o~ Submit Origina~~ply eZ'G~r2 '~l/r~ 1J-164L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/2/2006 Commenced Water Injection Service i • WELL LOG TRANSMITTAL To: State of Alaska March 24, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-164 L1, AK-MW-4025932 1 LDWG formatted Disc with verification listing. ~ Cp API#: 50-029-23278-60 J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETCJRNING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Q Signed: • { ;~ _ ~.~ ~ ;~.~ ALASSA OIL A1QD GcAS COI~TSERQATIOI~T CODil~II5SIOIQ Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River, 1 J-164L 1 Sundry Number: 306-050 Dear Mr. Christensen: r~ ~~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99507-3539 PHONE (907) 279-7433 FAX (907} 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice 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 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. DATED this /0 day of February, 2006 ~ `~ STATE OF ALASKA ~ ,~-! ALASKA OIL ~L) AND GAS CO NSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2n aAC ~s ~Rn 1. Type Of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver ^ ~~~Qi@r ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 205-145 '~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-164L1 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 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): 11472' 3613' 11451 3612 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 2223' 10-3/4" 2332' 2203 INTERMEDIATE 5249' 7-5/8" - 5358' 3443 WINDOW D-SAND 1' 5-1/2" 4249' 3512 WINDOW B-SAND ~~ 5-1/2" 4596' 3656 B sand Slotted Liner 6865' 4-1/2" 11452' 3612 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4-1/2" L-80 4221' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 475' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 02/14/06 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: 0 08/06 WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert D. Christensen Printed Name Robert D. ChrlSterlSen Title: Production Engineering Technician Signature Phone 659-7535 Date ~.. Q Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3~jG p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ .Other: l Subsequent F e -1 A rove C APPROVED BY ~~/D ~ D ,6 pp OMMISSIONER THE COMMISSION Date: FEB 1 0 2ao6 Alaska Oil & Gas Cons. COmmissil Form 10-403 Rev~07l2005 ~ ~~ ~ ~ f ~ it ~ L„ Submit in Duplicate • 1J-164L1 ~ , DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Multi-lateral Well 1J-164L1. This well was pre-produced fora 39 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Well 1 J-164L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surtace casing (2332' and / 2203' tvd) was cemented with 480 sx AS Lite followed by 145 sx DeepCrete. The 7-5/8" Intermediate casing (5358' and / 3656' tvd) was cemented with 230 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer D- Lateral Hook Hanger LEM w/isolation Seal Bore located @ 4187' and / 3424' tvd. This well also contains a Lower B sand 5-1/2" x 7-5/8" ZXP Liner Top Packer located @ 4346' and / 3468' tvd. The top of West Sak D sand was found at 4219'md / 3434' tvd. The top of West Sak B sand was found at 4578'md / 3509' tvd. The top of West Sak A sand was found at 4770'md / 3548' tvd. - ~__- • KRU 1 J-164L1 Ct~~t~~~h~i~ip;~ .Ai~~~~~t; ~>~~<. 1J-164L1 I nPr snn~4~•t~~RFn i wou s~~.,o• IaRnn I v,,,,io n T.e i no„ n I SSSV T e: NIPPLE Ori Com letion: 12/5/2005 An le TD: 88 de 11472 Annular Fluid: Last WIO: Rev Reason: NEW WELL Reference Lo 28' RKB Ref Lo Date: Last U date: 1/28/2006 Last Ta TD: 11472 ftK8 ,,. . -Last Tag Date: _ T T Max_Hole_Angls: Casin Strip -COMMON STRINGS Descri lion Size To 95 de~@ 9396 __ _ _ _ Bottom TVD Wt _ _ Grade Thread SURFACE 10.750 0 2332 2203 45.50 L-80 BTC INTERMEDIATE 7.625 0 5358 3532 29.70 L-80 BTC-M :•.,'•::'•.#::-:::;#:';' CONDUCTOR 20.000 0 108 108 91.50 H-40 WELDED LINER TOP D-SAND 4.500 4246 4248 3442 12.60 L-80 IBTM WINDOW D-SAND 6.875 4248 4249 3443 12.60 L-80 IBTM LINER B-SAND 4.500 4587 11452 3612 12.60 L-80 IBTM i WINDOW B-SAND 6.875 4595 45.96 _ 3512 12.60 L-80 IBTM Tobin Strip TUBING ize- ~_ To ~_ Bottom TVD _ 1W60 Grade I IBTM r a .,oo i ~ - ~ ~ ~ - - -- -..Thread o f Pertorations Su _ _ _ G mma~ - -~ _ T -~ - interval TVD _T -Zone Status Ft SPF Date T e Comment J 4661 - 5127 3517 - 3526 WS B 466 32 11/19!2005 Slots Alternating slotted/blank i e 5399 - 5862 3531 - 3527 WS B 463 32 11/1912005 Slots Alternating slotted/blank i e 6140 - 6605 3529 - 3528 WS B 465 32 11/19/2005 Slots Alternating slotted/blank i e ..................... 6884 - 7283 3528 - 3531 WS B 399 32 11/19!2005 Slots Alternating s{ottedJblank i e " 7562 - 8148 3538 - 3552 WS B 586 32 11/19/2005 Slots Alternating slotted/blank i e 8300 - 8794 3556 - 3576 WS B 494 32 11/19/2005 Slots Alternatin slotted/blank i e 9477 - 9786 3554 - 3536 WS B 309 32 11/19/2005 Slots Alternatin slotted/blank i e 10035 - 10591 3548 - 3579 WS B 556 32 11/19/2005 Slots Alternatin slotted/blank i e t ,;; ~ J 10927 - 1_1389 3593 - 3610 WS B 462 32 11/19/200.5 Slots ,4lternatin slotted/blank ~ e _ _ _ - _ ~_ - - -- - _ g _ __ PL Gas Lift MandrelsNalves _ _ _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port ~ TRO Date Vlv Run Cmnt i 2336 2207 CAMCO KBG-2 GLV 1.0 BK-5 0.188 1450 12/24/2005 I 2 3902 3335 CAMCO -Other lu s .equip~etc De th TVD T e KBG-2 OV 1.0 BK-5 0.250 0 12/24/2005 - - _ .)~COMMON JEWELRY -- - -~_.- Descri lion __' ID 23 23 HANGER TUBING HANGER VETCO GRAY w/4.909" MCA TOP CONNECTION 4.500 475 475 NIP CAMCO'DB-6' NIPPLE NO GO PROFILE 3.875 4137 3409 SLEEVE-C BAKER CMU SLIDING SLEEVE w/3,81" DB PROFILE -CLOSED 12123/2005 3.812 4183 3423 LOCATOR BAKER LOCATOR GBH-22 SPACED OUT 3.88' ABOVE FULLY INSERTED 3.875 4184 3423 SEAL BAKER SBE SEAL ASSEMBLY 3.875 ~ 4221 Other De th 3434 plus, ND SHOE MULE SHOE - ' equl~. _etc~_- D~SAND LE_ M_ _ _ __ T e Descri lion 6.875 -- - ~ ID 4187 3424 PACKER ZXP LINER TOP PACKER 4.960 4188 3424 PUP PUP JOINTS 3.958 4206 3430 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 4226 3436 XO CROSSOVER BUSHING 3.958 4229 3437 SWIVEL CASING SWIVEL 3.920 4236 3439 HANGER LEM ABOVE HOOK HANGER 3.930 ~~ ''~ ' [ 4246 Other 3442 l~s HANGER equip etc LEM INSIDE HOOK HANGER 3.930 ) B SAND LEM ; '. De th ND . T e . -_ - Descri lion ID Pert 5127 4661 4346 3468 PACKER ZXP LINER TOP PACKER 4.960 ( - ) 4347 3468 PUP PUP JOINTS 3.958 4364 3472 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 ~-- 4384 3476 XO CROSSOVER BUSHING 3.958 • 4385 3476 SWIVEL CASING SWIVEL 3.920 4577 3509 HANGER LEM ABOVE HOOK HANGER 3.930 _ ' ~ ~ ~ 'I i 4587 Other 3510 lu s HANGER LEM INSIDE HOOK HANGER 3.930 e ui .etc. - B-SAND LINER JEWELRY _ .- De th ND T e Descri lion ID t S 4670 3517 NIP CAMCO 'DB-6' NIPPLE 3.563 I r I 4745 3522 SEAL BAKER SEAL ASSEMBLY 3.880 _ ~` I 8803 3576 PACKER SWELL PACKER 0.000 _ w ' ~ 9462 3556 PACKER SWELL PACKER 0.000 _I ~ ~ =~ ~ ', ~ ' 11451 3612 SHOE ROT SILVER BULLET GUIDE SHOE {NO F_LOAT~ _ - _ _ 0_.000 G_ eneraf Notes __ _ _ Date Note ~-- 12/4/2005 MULTI-LATERAL WELL: A-SAND 1J-164 B-SAND 1J-164L1 D-SAND iJ-164L2 ~ F --p -1 t f ~ Pert i '10035-10591) ~ ' - F ' ~- Re: Verbal approval to convert Wsak 1J-164 from Preproduction to... • Subject: Re: Verbal appro~ ~1~to convert Wsak 1J-164 from Preproduction to ~VIN.i From: Thomas Maunder tom__maunder@admin.state.ak.us== Date:`~Jed, 08 Feb ?006 0~):~ 1 :~7 -0900 To: NSK Prod En~r Tech <nl l3~)~~l'~:conocophillips.crnn=> CC: ASK Vv'est Sak Prod En<~r <_n16~~"a?conocop}lillips.com>, .%!0000 l~~orth Slope Office °~~=ao~~cc_prudhoe_bayi~i;admin.state.al~.us- c~a ~'S' ~'1~ Bob, I have completed my assessment of the cement isolation for 13-164, -L1 and -L2 and determined that the well construction meets the requirements for conversion to injection. By copy of this email, you have verbal approval to proceed as planned. I will look forward to seeing the three 403s sometime next week. I do not show having received a copy of the MIT you refer to in your message. Please send that in to Bob Fleckenstein/Jim Regg as usual. Once the well is warmed up, you should contact the Inspector for a witnessed MIT. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2!8!2006 7:52 AM: Bob, I have to do a little paperwork in here. I will get back with you later this morning. Tom Maunder NSK Prod Engr Tech wrote, On 2/8/2006 7:42 AM: Tom, We have completed the Preproduction phase to recover the oil based drilling muds in Wsak 1J-164/L1/L2 (PTD#'s: 205-144, 205-145, 205-146) . Well 1J-164 was originally permitted as a WIND well. The 10-407 was completed with the well as a Oil producer for the preproduction period. An MITIA was performed on 12/21/05; MITIA 3000 psi, 30 minutes, Passed. We intend to turn the well to WINJ on or about 02/14/06. I am currently working up the 10-403 conversion application but due to the timing I am requesting a verbal approval to proceed with the conversion. Bob Buchholz /Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager {907} 659-7000 {924} 1 of 1 2/8/2006 9:23 AM r~C:~.ANIC~ INTEGRITY REPORT ~ ~ ~~~ ~ ` - i ~-l C~ .?UD u'.T_~ : - 1 ~ fi ' VSO _ OPER ~ FZELD ~~' ~~ ~~~~ ~~ S -.. G c. ~ ~ ~ ~ ., I . ~ ~ ~/ S~ ~ ~ it I.I.. NtTMB ER ~ ~ '_ ~ ~ L"~ ,i_._~ 1.-_ n ~ LL DAT ~_ / TD : i ~ ~~~ ice.. 7`1`-15.^TVD ; ?BTD : ?-ID `` "I'VD Cc51_^.~ : ~hl~` St10G' : ~ 7~~ ~ ~~J~::•TV-D ; L/V : ~~ ~ `'~ -'''Z11~ _-:le= . - Shoe . '~ T'TG ; :Cr . ''~ _','J -u~~='e PaciceT '~ TV-D; Set at ~~ ~:,s:`~.w _o1e S_~e ~ `Z1~45 and Perfs ~- ~ ~ to '~'Ci?~?~=C~?. ZNTEGRSTY - a4RT #I r_nnuius Press Test: _? 15 nin ~0 min CoQents : ~CHpNIC~1, iNTEGRTT`~ _ PA~'T # 2 ~---~ ~~-bhls C~ .LL ~ ~ f J /-~, Q ~ ~J Cement Volumes s Amt. Liner Cs~ ~3<;5~ DV ~~ Cr,t -JOl to cover oers ~ ~~n``~~ ~C~ s~ }~ cev~~ ~ ~n vv`~.N:..Ci~J~~c~`i~ _ _:eore tical TCC C 3C~7o `X ^~ 5 ~-;,, ~~ -~. ' "lea ~S Cement Bond Log (Yes or No) ~ ~ "G S Zn AOGCC File ~~S C5L Evaluation, gone aoove perfs ~Z~ <<,c;~.~ ccav ~~_~-~ ~~~~`~ ~ ~ st~~E ~~ ~~~y Production Log: Tyve CONCLUS ~ ONS : Part #1: Evaluation Part 12 . ~~ ~~ ~~C~s ~ ~~ ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: ~h~f~ Q Development O Exploratory ^ Service ^ Stratigraphic Test ^ 2.Operator Name: ConocoPhillips Alaska, Inc. - 5. Date Comp., Susp., orAband.: December 5, 2005 12. Permit to Drill Number. , 205-145 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: r3 CD _/_ November , 2005 •14'1 13. API Number: 50-029-23278-60 4a. Location of Well (Governmental Section): Surface: 1919' FSL, 2517' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: November 17, 2005 ~ 14. Well Name and Number: 1J-164L1 At Top Productive Horizon: 1239' FNL, 2198' FWL, Section 35, T11 N, R10E UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 361' FSL, 2210' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 11451' MD / 3612' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558693 ~ y- 5945730 Zone- 4 10. Total Depth (MD + ND): 11472' MD ! 3613' TVD ' 16. Property Designation: , ADL 25661, 25650 TPI: x- 558109 y- 5947848 Zone- 4 Total Depth: x- 558060 ' y- 5954727 Zone- 4 11. Depth where SSSV set: nipple @ 475' 17. Land Use Permit: ALK 471, 468 18. Directional Survey: Yes ^~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3077' MD 21. Logs Run: LC~ T sg•'3 ~~~i ,3,~~~ ~'fy~ !~~ /• /$ • O~ GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE 70P BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 325 sx AS1 10.75" 45.5# L-80 28' 2333' 28' 2202' 13.5" 480 sx AS Lite, 145 sx DeepCrete 7-5/8" 29.7# L-80 28' 5358' 28' 3656' 9-7l8" 230 sx DeepCrete 4.5" 12.6# L-80 4587' 11452' 3510' 3612' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 4703' slotted liner from 4635'-11389' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 31, 2005 Method of Operation (Flowing, gas lift, etc.) Production shared with 1J-164 and 1J-164L2 Date of Test 114/2006 Hours Tested 15.5 hours Production for Test Period --> 694 GAS-MCF 844 WATER-BBL 0 CHOKE SIZE 176 bean GAS-OIL RATIO 1292 Flow Tubing press. 693 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1025 GAS-MCF 1324 WATER-BBL 1 OIL GRAVITY -API (corr) 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". ii,, ~ ~*` ~~~~YI~ ~ ~}~~ ~ $ ~~~~ ~ a NONE zL~ ~...~I Form 10-407 Revised 12/2003 ~ ~~ ~ ~ ~~~ Jj ~ CONTINUED ON REVERSE ~}J--ill ~--. r< ,.u RED ~~ x ~. ~..., .~~ A`~ ~ .~ if (' WELL COMPLETION OR RECOMPLETION REPORT ~@~ldD~181ft~Gi:~;~~, c:~k~m' sior lJ 2s. 2s. 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". 1J-164L1 West Sak B 4585' 3510' Base West Sak B 11472' 3613' 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 Printed Nam Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader 1 ( ~ ~ ~/ ~ Signature one ~S-~~ ~~ Date - INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval .(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken. indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 A ~ ConocoPhillips Alaska Page 1 of 24 ~ Operations Summary Report Legal Well Common Event Nam Contractor Rig Name: Date Name: Well Name: e: Name: .From - To 1J-164 1J-164 ROT -D n1334@ Dayon 1 Hours RILLIN ppco.co 41 Code G m Code Phase Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 10/31/2005 00:00 - 02:30 2.50 WAITON EQIP MOVE Change top drive saver sub to 4-1/2" IF. 02:30 - 03:00 0.50 WAITON EQIP MOVE Service top drive & Drawworks. 03:00- 03:30 0.50 WAITON EQIP MOVE Change Iron Rough Neck, Elvators, Dog collar Etc. over to 5" Handling tools. 03:30 - 07:00 3.50 MOVE DMOB MOVE Rig down rig for move. 07:00 - 12:00 5.00 MOVE MOVE MOVE Move rig f/ 1 J-154 to 1 J-164 12:00 -12:30 0.50 MOVE MOVE MOVE Spot Sub over 1 J-164 12:30 - 15:30 3.00 MOVE MOVE MOVE Lay Mats and Spot Pits, Pumps, Motors, Boilers, Lay herculite and Spot Rock Washer and Pipe sheds. 15:30 - 18:00 2.50 MOVE RURD RIGUP Hook up all service lines, Steam, Air & Water lines, Work on rig acceptance check list. 18:00 - 20:30 2.50 DRILL PULD RIGUP Accept rig @ 18:00 hrs 10131/05, Load Pipe shed with 45 jts. 5" drill pipe, 29 jts. HWDP & jars, Strap same, Begin mixing spud mud. 20:30 - 22:30 2.00 WELCT NUND RIGUP Nipple up 20 1/4" Diverter, All lines, Bell nipple, Diverter line, Apply steam to warm up diverter, Continue to mix spud mud. 22:30 - 00:00 1.50 DRILL PULD RIGUP Pick up 21 jts. 5" drill pipe and stand back in derrick, Continue to mix spud mud. 11/1/2005 00:00 - 02:15 2.25 DRILL PULD RIGUP Finish picking up total of 15 stands 5" drill pipe, 10 stands HWDP (Including Jars). 02:15 - 02:45 0.50 DRILL PULD RIGUP Bring lifters, Stab, UBHO sub, Crossover subs, to floor thru beaver slide. 02:45 - 03:45 1.00 DRILL PULD RIGUP Pick up 3-Non Mag DC's and stand back in derrick, Lay down mouse hole. 03:45 - 04:00 0.25 WELCT BOPE RIGUP Function test Diverter system, Test waived by AOGCC Jeff Jones. 04:00 - 05:00 1.00 DRILL PULD SURFAC Make up Bit, Motor, 1 stand HWDP, Flood conductor and check for leaks, Pressure test mud lines to 3000 psi-OK, Tag ice plug @ 80', Clean out to 108'. 05:00 - 06:30 1.50 DRILL DRLG SURFAC Spud well @ 05:00 hrs 11/1/05, Drill f/ 108' to 212' MD, 212' TVD (104'), ADT 1.00 hrs, 420 gpm @ 525 psi, 55 RPM. 06:30 - 07:00 0.50 DRILL TRIP SURFAC POOH f/ 212' to 30'. 07:00 - 08:00 1.00 DRILL PULD SURFAC Finish picking up BHA #1, Pick up Stab, X/O subs, MWD, Orient Motor w/ MWD. 08:00 - 08:30 0.50 DRILL RIRD SURFAC PJSM, Rig up Sperry-Sun GYRO & Wire unit. 08:30 - 09:00 0.50 DRILL TRIP SURFAC RIH to 212'. 09:00 - 12:00 3.00 DRILL DRLG SURFAC Drill f/ 212' to 349' MD, 349' TVD (137'), ADT 2.38 hrs, 5/7K WOB, 504 gpm @ 1100 psi, 65 RPM. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 13-1/2" Hole f/ 349' to 1,096' MD, 1,087' TVD (747'), ART= 2.66 hrs, AST= 6.69 hrs, ADT= 9.35 hrs., 560 gpm @ 1400 psi, WOB 20-25K, RPM 60- 70, UP 94K, DN 90K, ROT 89K, TO on 3500 ft/Ib, TQ off 1500 ft/Ib, Ran GYRO #1 @ 50', 100', 200', 300', 355', #2 @ 443', #3 @ 533', Sliding 70' and Rotating 20' per stand, Mud wt 8.9, Vis 300. 11/2/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill 13-1 /2" Hole f! 1,096' to 2,170' MD, 2,060' TVD (1,074'), ADT= 8.74 hrs, ART= 1.5 hrs, AST= 7.24 hrs., 721 gpm @ 2100 psi, WOB 10-20K, RPM 75, UP 110K, DN 100K, ROT 105K, TO on 3000 ft/Ib, TQ off 2000 ft/Ib, Sliding 70' and Rotating 20' per stand, Mud wt 8.9, Vis 300. 12:00 - 13:30 1.50 DRILL DRLG SURFAC Drill 13-1/2" Hole f/ 2,170' to 2,342' MD, 2,212' TVD (172'), ADT= 1.08 hrs, ART= 0.61 hrs, AST= 0.47 hrs., 763 gpm @ 2300 psi, WOB 0-25K, RPM 75, UP 120K, DN 104K, ROT 109K, TO on 5/ 6000 ft/Ib, TQ off 5000 ft/Ib, Mud wt 8.9, Vis 300. 13:30 - 14:00 0.50 DRILL CIRC SURFAC Circ btm's up at rate of 763 gpm @ 2300 psi, 80 RPM, TQ 5500 ft/Ib, Reciprocate pipe f/ 2,342' to 2,285' while circ. 14:00 - 17:00 3.00 DRILL TRIP SURFAC Back Ream out of hole at rate of 763 gpm @ 2300 psi, 80 RPM, 25 to ~ 35 ft/min., Slowed down to 5 to 10 ft/min. and let hole clean up after Printed: 12/29/2005 9:54:06 AM • • ConocoPhillips Alaska Page 2 of 24 Operations Summary Report Legal Well Name: 1 J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 11/2/2005 ~ 14:00 - 17:00 3.00 DRILL TRIP SURFAC 17:00 - 17:30 0.50 DRILL TRIP SURFAC 17:30 - 19:30 2.00 DRILL PULD SURFAC 19:30 - 21:00 1.50 CASE RURD SURFAC 21:00 - 00:00 l 3.001 CASE RUNC SURFAC 11/3/2005 00:00 - 00:15 0.25 CASE RUNC SURFAC 00:15 - 00:45 0.50 CASE CIRC SURFAC 00:45 - 01:30 0.75 CEMEN'T(PULD SURFAC 01:30 - 02:30 I 1.001 CEMENlf CIRC I SURFAC 02:30 - 05:30 I 3.001 CEMENlf PUMP I SURFAC 05:30 - 07:30 2.00 CEMENT PULD SURFAC 07:30 - 09:00 1.50 CASE RURD SURFAC 09:00 - 11:00 2.00 WELCT NUND SURFAC 11:00 - 13:15 2.25 WELCT NUND SURFAC 13:15 - 16:30 3.25 WELCT NUND SURFAC 16:30 - 18:00 1.50 WELCT BOPE SURFAC __ pulling 8 stands f! 1,549' to 1,363' -Hole unloaded large amounts of Clay and Sand, Continue to Back Ream out to 895' -Hole cleaned up. POOH on elevators & rack back HWDP & Jars. Lay down BHA #1, NMDC's, UBHO sub, X/O, MWD, Motor, Bit. Rig to Run 10-3/4" Casing, Held PJSM with all personnel running casing. Run 55 jts of 57 jts of 10 3/4", 45.5#, L-80 BTC csg to 2,225' per well plan, MU 10 3/4 Weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker locked btm 3 conn. and pumped thru checking float equipment, cont RIH with 10 3!4" csg to 2,225' at 00:00 hrs, Ran 19 bow spring centralizers on 1st 17 jts ran 1 cent on jt. # 56 @ 20" conductor @ 108' (Total of 20 centralizers and 3 stops). No problems RIH, st wt up 130K, down wt 110K Finish running 10-3/4" casing (Total 57 jts.), Pick up Vetco Gray casing i hanger and land w! Shoe @ 2,332.83', Float collar @ 2,249.12'. Circ btm's up, Stage rate up to 6.0 bpm @ 250 psi, Reciprocate pipe 10'-15' Up 130K, Dn 107K. Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell cement head. Finish circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 280 psi, reciprocating pipe 15' with 130K up wt and 107K do wt, circ and cond mud to 8.9 ppg and lowered PV to 21 and YP to 16, held PJSM on cement job with Dowell, ASRC and rig crew while circ and cond mud. Turned over to Dowell and cemented 10 314" csg, Pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 380.4 bbls (480 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.7 bpm at 225 psi, Followed with 63.7 bbls (145 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.4 bpm at 230 psi, reciprocated csg 10 to 15' and had full returns, shut down and dropped top plug, Kick plug out with 20 bbls fresh water. Rig displaced cement with 194.2 bbls (Total 214.2 bbls to bump) of 8.9 ppg mud, displaced cmt at 7.0 bpm, initial circ pressure 420 psi, max pressure 650 psi, Observed red dye at shakers after pumping 40.2 bbls mud, slowed rate to 3 bpm @ 425 psi and bumped plug, Pressured up to 1000 psi, held 5 min, checked floats and held, CIP @ 05:10 hrs 1113/05, Reciprocated casing until 56 bbls cement around shoe then pipe became tight and land pipe on hanger, Up 130K, Dn 107K, Float shoe at 2,332' and Float collar at 2,249' Had full returns during job with 58.3 bbls of 10.7+ ppg cmt back to surface- Note; Hanger plugged as cmt came to surface- picked pipe up 1" to unplug; then set back down- OK Flush out diverter system with fresh water, Wash cement from flow line & drip pans, Rig down Dowell cement head, Lay down landing joint. Rig down all casing tools, Clear rig floor. Nipple down Diverter system. Nipple up Vetco Gray 13-5/8" Wellhead & test to 5000 psi. Nipple up BOPE Rig & Test Lower 7-5/8" Rams, Annular, Choke valves 1, 12,13,14, Printed: 721297201)5 9:~4:UFiAM • ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Code Phase 11/3/2005 116:30 - 18:00 1.501 WELCTI~ ROPE SURFAC 18:00 - 19:00 1.00 19:00 - 20:15 1.25 20:15 - 21:00 0.75 21:00 - 00:00 3.00 11/4/2005 00:00 - 01:00 1.00 WELC 01:00 - 03:00 2.00 DRILL 03:00 - 08:00 5.00 DRILL 08:00 - 12:00 4.00 DRILL 12:00 - 13:30 1.50 DRILL 13:30 - 14:00 0.50 DRILL 14:00 - 15:15 1.25 DRILL 15:15 - 16:15 1.00 DRILL 16:15 - 16:45 I 0.501 DRILL 16:45 - 17:30 I 0.751 DRILL 17:30 - 00:00 6.501 DRILL 111/5/2005 100:00 - 12:00 12.00 DRILL 12:00 - 00:00 I 12.001 DRILL 111/6/2005 100:00 - 00:30 00:30 - 01:15 01:15 - 01:45 01:45 - 02:45 02:45 - 05:00 0.501 DRILL 0.75 DRILL j 0.50 DRILL 1.00 DRILL 2.25 DRILL BOPE SURFAC ROPE SURFAC BOPE SURFAC BOPE SURFAC BOPE SURFAC PULD SURFAC PULD SURFAC PULD SURFAC TRIP SURFAC CIRC SURFAC DEOT SURFAC DRLG SURFAC CIRC SURFAC LOT SURFAC DRLG INTRM1 DRLG INTRMI DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 DRLG INTRM1 CIRC INTRM1 TRIP INTRMI Page 3 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number. Description of Operations HCR Kill, 5" Inside dart to 250 psi Low & 3500 psi High, Note: Upper Varible Rams Failed Test. AOGCC Chuck Scheve waived test. Open top doors on BOP Stack and remove 3-1/2"x 6" varible Rams. Continue testing BOPE, Annular w/ 5", Manule Kill valves 4,5,6,7,8,9,10,11, 5" floor safety valve, Upper IBOP. Open top doors on BOP & Install 3-1 /2" x 6" varible Rames. Continue testing BOPE, Top Rams w/ 4" & 5", .Lower IBOP, Manule Choke valves 2 & 3, 4" Floor valves, Blind Rams, Annular w/ 4", HCR Choke, Choke valves 2 i~ 3, Rig down test equip. Install wear bushing. Change top drive saver sub to 4" XT-39. Pick up 35 stands 4" drill pipe and stand back in derrick. Make up 9-7/8 MXC1 Bit, Motor w/ 1.5 deg. bend, Stab, Float sub, MWD, Orient same, GR/RES/PWDlHCIM/ACAL/TM HOC, Up load MWD tools, NMDC's, Surface test MWD- OK. RIH & Tag Float collar @ 2249'. Circ btm's up at rate of 600 gpm @ 1800 psi. Rig & Test 10-3/4" casing to 3000 psi f/ 30 min.- OK. Drill out Float Collar @ 2,249', Cement, Float Shoe @ 2,332' and drill 20' new hole to 2,362', 600 gpm @ 1700 psi, 50 RPM, TO 5K. Pump Hi-vis weighted sweep, Change over to LSND Mud, Had 511 units gas on btm's up, Cric hole clean w/ 650 gpm @ 2000 psi, 50 RPM, TO 6K. Rig & Perform LOT of 15.4 EMW w/ 9.0 ppg mud, 737 psi @ 2202' TVD. Drill 9-7/8" Hole f/ 2,362' to 3,063' MD, 2,831' TVD (701'), ADT= 3.43 hrs, ART= 1.22 hrs, AST= 2.21 hrs, WOB 5-10K, 606 gpm @ 1900 psi, 85 RPM, TO on 6 to 8,000 ft/Ib, Up 130K, Dn 91 K, ROT 105K, Pump 1 Hi-vis weighted sweep w/ 20% increase in cuttings, Max ECD's 9.65, Max gas 58 units. Drill 9-7/8" Hole f! 3,063' to 4,184' MD, 3,423' TVD (1121'), ADT= 9.91 hrs, ART= 6.28 hrs, AST= 2.91 hrs, WOB 5-20K, 625 gpm @ 2580 psi, 85 RPM, Up 127K, Dn 85K, ROT 101 K, TO on btm 6 to 7,000 fUlb, TO off btm 6 to 7,000 ft/Ib, Pump 2 Hi-vis weighted sweeps w/ 20% increase in cuttings on 1st one and 10% on the 2nd, Max ECD's 9.7, Max gas 78 units. i Drill 9-7/8" Hole f/ 4,184' to 5,226" MD, 3,632' TVD (1042'), ADT= 8.76 'hrs, ART= 5.85 hrs, AST= 2.91 hrs, WOB 5-25K, 657 gpm @ 2850 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TO on btm 6500 fUlb, TQ off btm 5500 ft/Ib, Pump 1 Hi-vis weighted sweep w! 10% increase in cuttings, Max ECD's 10.0, Max gas 155 units. Drill 9-7/8" Hole f/ 5,226' to 5,305' MD, 3,648' TVD (79'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TO on btm 6500 ft/Ib, TQ off btm 5500 ft/Ib, Max ECD's 10.1. Pump Hi-vis weighted sweep &Circ 2 x Btm's up to evaluate logs. Drill 9-7/8" Hole f/ 5,305' to 5,358' MD, 3,656' TVD (53'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TQ on btm 6500 ft/)b, TQ off btm 5500 ft/Ib, Max ECD's 10.1. Circ 2 x Btm's up at rate of 655 gpm @ 2800 psi w/ 85 RPM, TO 5000 ft/Ib. Monitor well, Back Ream out of hole f/ 5,358' to 4187' at drilling rate of Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-1.64 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ,Hours Code Code Phase 11/6/2005 02:45 - 05:00 2.25 DRILL TRIP {NTRM1 05:00 - 06:30 1.50 DRILL TRIP INTRMI 06:30 - 09:15 09:15 - 11:15 2.75 DRILL TRIP INTRM1 2.00 DRILL TRIP INTRMI 11:15 - 12:00 12:00 - 14:30 14:30 - 17:15 17:15 -17:45 17:45 - 20:30 20:30 - 21:00 0.75 DRILL PULD INTRMI 2.50 CASE RURD INTRM1 2.75 CASE RUNC INTRMI 0.50 CASE CIRC INTRMI 2.75 CASE RUNC INTRM1 0.501 CEMEN7PULD I INTRM1 21:00 - 23:00 I 2.001 CEMENTCIRC I INTRMI 23:00 - 00:00 I 1.001 CEMENliPUMP I INTRM1 111/7/2005 100:00 - 01:00 I 1.001 CEMENIiPUMP I INTRM1 01:00 - 01:15 01:15 - 04:30 04:30 - 04:45 04:45 - 05:45 05:45 - 09:15 0.25 CEMEN PULD INTRMI 3.25 CASE ~NUND INTRMI 10.00 I DRILL LOOT R INTRMI 3.50! DRILL (PULD (INTRMI Page 4 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 650 gpm @ 2800 psi w/ 85 RPM, Pulling speed of 35 to 45 ftlmin. Slowed pulling speed to 3-5 fUmin. while circ 2 x Btm's up & hole clean f/ 4,187' to 4000'. Monitor well, POOH w/ 3 std's to check f/ swabbing-OK, Pump dry job, POOH to Shoe @ 2332' (Hole in very good shape). POOH & Lay down 5" drill pipe, 5" HWDP i~ Jars. Lay down NMDC's, Down load MWD tools, Lay down remainder of BHA #2. Lay down BHA tools from rig floor, Clean rig floor. Pull wear bushing (1 hr. to pull), Rig to run 7-5/8" casing. Ran 7 5/8" Weatherford float shoe, 2 jts 7 5/8", 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 conn, circ thru float equip and ck ak, RIH with 7 5/8" csg to 2,315', Ran 60 tandem rise centralizers on 1st 60 jts, 1-5' above shoe over stops & 1 -10' above and below-float collar, the remaining over collars, did not run any centralizers on both window jts. Circ btm's up, Stage rate f! 3 bpm @ 300 psi to 5 bpm @ 350 psi. RIH w/ 7-5/8" csg to 3,860' with no problems, Break circ at rate of 3 bpm @ 500 psi-OK, Continue to RIH & Tag btm @ 5,358' Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell cement head. Circ & Cond. mud, Stage rate up f/ 3.5 bpm @ 450 psi to 6.5 bpm @ 425 psi, Reciprocate pipe 30' to 35' while circ Up 160K, Dn 95K. Held PJSM w/all rig personnel for cement job, initial MW out, 9.9 ppg, 75 vis, PV 18, YP 22, Conditioned mud to final MW of 9.2 ppg, 44 vis, PV 7andPVof13. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 550 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4 bpm @ 570 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.0 bpm @ 550 psi, Dropped btm plug then pumped 92.3 bbls, (230 sxs - 10% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, ave 4.8 bpm at 550 psi, Reciprocated pipe with full returns 30' to 35'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water. Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 1234.2 bbls OBM (Total of 244.2 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to ~ slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 550 psi with 10 bbls left to pump and bumped plug to 1100 psi, ck floats and held. CIP at 01:00 hrs, 11-7-05. Reciprocated pipe 30' to 35' until MudPUSH at shoe, then recip. 20' until Cmt at shoe, then recip. 10' until last 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 5358', Float Collar @ 5268', Calc TOC @ 3052', Had full returns thru out job. Well static after shut down. Rig down cement head and equip. Installed 7-5/8" csg slips, Set slips with 60K over string weight (150K on slips), Cut off csg and LD cut offjt and installed pack-off, Test Packoff to 250 low & 3500 psi high f/ 10 min. Install wear bushing. Rig & at 05:00 hrs. Perform LOT on 10-3/4"x 7-518" annulus of 440 psi, 9.2 ppg mud, 2202' TVD @ 10-3/4" shoe, = 13.0 ppg EMW used 5 bbls to perform test., Pump additional 25 bbls down annulus to insure no cement in annulus at rate of 2 bpm @ 680 psi. PJSM, Pick up & RIH w/ 120 jts. 4" drill pipe, Note; At 07:00 hrs, Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11/7/2005 105:45 - 09:15 I 3.501 DRILL I PULD 09:15 - 10:15 1.00 DRILL PULD 10:15 - 18:00 7.75 DRILL PULD 18:00 - 21:00 I 3.001 DRILL I PULD 21:00 - 00:00 I 3.001 DRILL I PULD 111/8/2005 100:00 - 00:45 I 0.751 DRILL I PULD 00:45 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 06:45 06:45 - 07:45 2.75, DRILL `TRIP 0.501 DRILL (TRIP Start: 10/31/2005 Rig Release: 12/5/2005 Rig Number: Page 5 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations INTRM1 Flushed 10-3/4"x 7-5/8" annulus with 120 bbls fresh water at rate of 2 bpm @ 660 psi (Total 150 bbls fresh water to flush annulus). INTRM1 Pick up Lo-Tad's and Sliders to rig floor f/ beaver slide. INTRMI POOH picking up Lo-Tads (1 per std.) & Slides (3 per stand) & Rack back same, Note: At 10:23 hrs, Rig Little red service and freeze protect 10-3/4"x 7-5/8" annulus with 85 bbls diesel. INTRM1 Pick up & RIH w! 7 stands 4" HWDP, 6 stands 4-314" DC's & 4" HWDP Hybrid Push pipe, POOH & Stand back same. INTRMI Make up BHA #3, 6-3/4" Bit, 4-3/4" 5200 GeoPiolt, NM Pony collar, DM collar, Stab, MWD tools, NMDC's, 1-HWDP, Jars, 4- HWDP, Upload MWD tools, Surface test MWD tools. INTRM1 Continue Make up BHA # 3. Make up 1 - jnt 4 1/2" Non Mag flex drill collar (30.79'), Crossover (1.07'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling - Jars (28.59'), and 4 - 4" HWDP (120.96'). Jars = 60.55 HRS to start. INTRM1 Trip in hole from 367' - 3908' (3541), picking up singles of 4" DP XT-39 from pipe shed. INTRMI Continue trip in hole running from derrick from 3908' - 5241' (1333') to tag cement at 5241'. 0.50 CEMEN DSHO INTRM1 Drill hard cement from 5241' - 5268' (27'). Drill with 60 RPM's @ 3K torque, 250 GPM's - 1550 PSI. PU WT = 100K, SO WT = 75K, ROT WT = 85K. 1.00 DRILL CIRC INTRMI Circulate bottoms up @ 60 SPM, 250 GPMs - 1400 PSI. 1.25 RIGMNT RSRV INTRM1 RU and Slip & Cut 60' of drilling line. Inspect brakes, and service Top Drive. 1.00 CASE DEOT INTRMI RU & test casing to 3000 PSI for 30 minutes. Record on chart. Good Test. Bleed pressures and RD test equipment. 07:45 - 11:00 3.25 CEMEN DSHO INTRM1 Drill out Float equipment and shoe- track f/ 5268' to 5358' and 20' of new hole from 5358' - 5378' .Parameters @ 70 SPM - 250 GPM's - 1900 PSI. 60 RPM's - 3K Torque. ART = .59 HRS. 11:00 - 12:00 1.00 DRILL CIRC INTRM1 Circulate Bottoms up @ 330 GPM's - 3000 PSI. 92 SPM, Reciprocating & rotate drill string 60 RPM's - 3k Free torque. PU WT = 100K, SO WT = 75K, ROT WT = 85K. Jars @ 61.14 Total HRS, Bit Hrs = .59. Mud WT = 9.0 PPG, YP = 18, Visc = 90 12:00 - 12:30 0.50 DRILL LOT INTRMI RU & and pump down drill pipe annulus to perform LOT to EMW of 14.9 PPG w/ 9.0 ppg mud, 1123 psi & 3656' TVD. Bleed 12:30 - 00:00 11.50 DRILL DRLG PROD Directional drill 6 3/4" Hole in the "A" Lateral from 5378' - 6711' (1333'). TVD = 3671'. ART = 7.36 HRS, PU WT = 106K, SO WT = 66K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4.5K. WOB = 5-7K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3025 PSI. Total Jar Hrs = 68.5 Total Bit Hrs = 7.95 ECD at 10.6 PPG. Mud WT = 9.0 PPG Viscosity = 82, YP = 17. SPR's @ 6338' MD, 3670' TVD. Pump #1 - 25 SPM - 440 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM - 640 PSI. Survey @ 6583' MD , 3670 TVD - {nc = 89.10 Deg. AZ = 3.31 Deg. MAX GAS = 65 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% increase in cuttings when sweep returned. 11/9/2005 ' 00:00 - 12:00 12.00 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 6711' - 8411 (1700'). TVD = 3690'. ART = 8.32 HRS, PU WT = 107K, SO WT = 68K, ROT WT = 84K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Total Jar Hrs = 76.82 Total Bit Hrs = 16.60 ECD at 11.1 PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. SPR's @ 7772' MD, ~ 3696' TVD. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 690 PSI. Pump #2 Printed: 12/29!2005 9:54:06 AM • ConocoPhillips Alaska Page 6 of 24 Operations Summary Report Legal Well Name: 1J-164 Common W ell Name: 1J-164 Spud Date: 11/1/2005 Event Nam e: ROT -D RILLIN G Start: 10/31/2005 End: 12/5/2005 Contractor Name:. n1334@ ppco.co m Rig Release: 12/5/2005 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations 11/9/2005 00:00 - 12:00 12.00 DRILL DRLG PROD - 25 SPM - 490 PSI, 35 SPM - 700 PSI. Survey @ 8220' MD , 3687 ND -Inc = 86.66 Deg. AZ = 359.29 Deg. MAX GAS = 57 Units. Pumping weighted sweeps to control ECD and clean hole @ 7192', 7390', 7582', 8260'. Observe 10% - 20% increases in cuttings when sweep returned. 12:00 - 13:00 1.00 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8411' - 8617' (206'). ND = 3696'. ART = 1.0 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Mud WT = 9.O PPG Viscosity = 68, YP = 17. MAX GAS = 69 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. 13:00 - 13:15 0.25 DRILL OTHR PROD Stop drilling for Geologists to evaluate logs. Crossed fault @ 8855 MD 3710 TVD. Observed fault bigger than expected. 50' Throw. 13:15 - 16:15 3.00 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 861T - 8933' (316'). TVD = 3711'. ART = 2.05 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Also observed bigger sized shale cuttings in sweep. 16:15 - 16:30 0.25 DRILL OTHR PROD . Stop drilling for Geologists to evaluate logs with town, as we went from sand to shale. 16:30 - 18:15 1.75 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8933' - 9127' (194'). ND = 3702'. ART = .90 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. 18:15 - 18:45 0.50 DRILL OTHR PROD Stop drilling for Geologists to evaluate logs with town on orders for proceeding. 18:45 - 00:00 5.25 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 9127' - 9752' (625'). ND = 3674'. ART = 3.52 HRS, PU WT = 129K, SO WT = 56K, ROT WT = 85K, Torque off btm = 5.5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Total Jar Hrs = 84.29 Total Bit Hrs = 24.07 ECD at 11.5 PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. Gels @ 19/27. SPR's @ 9707' MD, 3672' TVD. Pump #1 - 25 SPM - 550 PSI, 35 SPM - 750 PSI. Pump #2 - 25 SPM - 540 PSI, 35 SPM - 760 PSI. Survey @ 9671' MD , 3678 TVD -Inc = 92.18 Deg. AZ = 3.04 Deg. MAX GAS = 169 Units. BGG = 48 units. Pumping weighted sweeps to control ECD and clean hole @ 9513'. Observe 10% - 20% increases in cuttings when sweep returned. 11/10/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Continue Directional drill 6 3/4" Hole in the "A" Lateral from 9752' - 10971' (1219'). TVD = 3718'. ART = 7.10 HRS, PU WT = 145K, SO WT = 45K, ROT WT = 89K, Torque off btm = 6K, Torque on bottom = ~ 6K. WOB = 5-10K, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 3650 PSI. Total Jar Hrs = 91.39 Total Bit Hrs = 31.41 ECD at 12.19 PPG. Mud WT = 9.0 PPG Viscosity = 71, YP = 19. Gels @ 20/30. SPR's @ 10673' MD, 3702' TVD. Pump #1 - 25 SPM - 690 PSI, 35 SPM - 860 PSI. Pump #2 - 25 SPM - 690 PSI, 35 SPM - 850 PSI. Survey @ 10911' MD , 3718 TVD -Inc = 88.68 Deg. AZ = 356.33 Deg. Printed: 12/29/2005 9:54:06 AM ConocoPhillips Alaska Page 7 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To 1J-164 1J-164 ROT -D n1334@ Doyon 1 Hours RILLIN ppco.co 41 Code G m Code hase 11/10/2005 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 15:15 3.25 DRILL DRLG PROD 15:15 - 16:45 1.50 DRILL CIRC PROD 16:45 - 20:00 3.25 DRILL WIPR PROD 20:00 - 00:00 4.00 DRILL WIPR PROD 11!11/2005 00:00 - 01:00 1.00 DRILL CIRC PROD 01:00 - 04:00 3.00 DRILL WIPR PROD 04:00 - 04:15 0.25 DRILL REAM PROD 04:15 - 06:30 2.25 DRILL CIRC PROD 06:30 - 08:00 1.50 DRILL CIRC PROD 08:00 - 12:00 4.00 DRILL TRIP PROD 12:00 - 13:00 1.00 DRILL TRIP PROD 13:00 - 13:45 0.75 DRILL PULD PROD 13:45 - 14:30 0.75 DRILL OTHR PROD 14:30 - 15:30 1.00 DRILL PULD PROD Spud Date: 11/1/2005 Start: 10/31!2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations MAX GAS = 132 Units. Pumping weighted sweeps to control ECD and clean hole @ 9822', 10094', 10190', 10382'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 10971' - 11400 MD (429'). TVD = 3742'. ART = 2.59 HRS, PU WT = 150K, SO WT = 60K, ROT WT = 93K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 5-10K, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 4000 PSI. Total Jar Hrs = 94.22 Total Bit Hrs = 34.0, ECD at 12.30 PPG. Mud WT = 8.9+ PPG Viscosity = 75, YP = 19. Gels @ 21/28. SPR's @ 11400' MD, 3745' TVD. Pump #1 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Pump #2 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Survey @ 11400' MD , 3745.43 TVD - Inc= 86.38 Deg. AZ = 358.75 Deg. MAX GAS = 104 Units. Pumping weighted sweeps to control ECD and clean hole @ 11320'. Observe 10% - 20% increases in cuttings when sweep returned. Pump 35 BBLS Hi Visc weighted sweep, and two bottoms up @ 93 SPM, 330 GPM - 4000 PSI. Rotate & Reciprocate drill string @ 130 RPM's with 6K torque. Obtain SPR's. Monitor well -Static. POOH on elevators observiing well taking proper hole fill and normal drag of 15 - 20K from 11400' - 7939' (3461'). Observed little overpull @ 9175' and weight fell off. At 7939' observed 20K overpull, 3 times. Attempt to wipe through spot without success. Screw into TD and BROOH from 7939' - 5358' (2581') =Shoe depth. Back ream at 93 SPM, 330 GPM's - 3150 PSI. RPM's of 130 with 6K torque. PU WT = 95K, SO WT = 75K, ROT WT = 85K @ 5850'. Pump a 35 BBL Hi Visc weighted sweep @ 93 SPM, 330 GPM - 2700 PSI, and 3 Bottoms up to observe 10-15% increase in cutting when sweep returned. Trip back in hole on elevators, observing clean hole conditions, and filling drill string every 25 stands. We did not need to pump into the hole as we had downweight of 55-60K. Make up top drive, wash & ream from 11259' -11400' (141'). Pumps @ 93 SPM, 330 GPM - 3950 PSI. Pump a 35 BBL Hi Visc sweep @ 93 SPM, 330 GPM - 3950 PSI, and 2 bottoms up observing 10% increase in cuttings at shakers and cleaned up. PU WT = 140K, SO WT = 65K, ROT WT = 65K, RPM's at 130 with 3-5K torque. Displace well from 8.9 PPG MOBM, to 8.8+ pPG SFMOBM, at 7 BPM - 84 SPM - 4000 PSI. Observed good displacement, no spins. Obtain SPR's @ 11395' MD, 3745' TVD. Pump #1 = 25 SPM - 610 PSI. 35 SPM - 830 PSI. Pump #2 = 25 SPM - 650 PSI. 35 SPM - 840 PSI. Monitor well -static. POOH on elevators observing good clean hole conditions taking proper hole fill. Monitor well @ shoe 5358', static. Continue POOH to 2048'. (9352'). Continue POOH from 2048' - 366' (1682'). Rack back in derrick 4 jnts 4" HWDP (102.96'), 4 3/4" Drilling Jars 28.59'), 1 - jnt 4" HWDP (30.33'), crossover (1.07'), 3 - NMFC's (92.80'), breakout & lay down 4.688" Integral Blade Stabilizer (5.46'). P{ug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 4 3/4" TM hang off collar (10.90'), 4 3/4" PWD collar (10.73'), 4 3/4" Slimphase 4 w/ DGR & EWR (24.18'), 4.3/4" Smart Stabilizer (3.59'), 4 3/4" DM Collar (8.56'), 4 3/4" GP NM Flex Pony collar (11.54'), 5200 series Printed: 12/29/2005 9:Sd:06 AM • ConocoPhillips Alaska operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Code Phase 11/11/2005 14:30 - 15:30 ~ 1.00 ~ DRILL ~ PULD ~ PROD 15:30 - 16:00 16:00 - 17:45 17:45 - 18:15 18:15- 20:00 20:00 - 00:00 11/12/2005 00:00 - 00:15 00:15 - 02:00 02:00 - 02:30 0.50 DRILL BIRD CMPLTN 1.75 LOG RURD CMPLTN 0.501 LOG ELOG I CMPLTN 1.75 I LOG I ELOG I CMPLTN 4.00 I LOG I ELOG CMPLTN 0.251 LOG I ELOG I CMPLTN 1.75 I LOG I RURD I CMPLTN 0.501 CASE (RURD (CMPLTN 02:30 - 02:45 0.25 CASE SFTY CMPLTN 02:45 - 09:30 6.75 CASE PULR CMPLTN 09:30 - 10:30 1.00 CASE PULR CMPLTN 10:30 - 12:00 I 1.50 I CASE I RUNL I CMPLTN 12:00 - 14:30 I 2.50 I CASE I RUNL I CMPLTN 14:30 - 15:15 0.751 CASE I OTHR I CMPLTN 15:15 - 16:30 I 1.251 CASE I CIRC I CMPLTN Page 8 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations Geo-Pilot { 16.20 and Security DBS 6 3/4" FM2641 Bit (1.26'). Bit grade@ 1/1/RG/N/0/1/NO/TD. Clean and clear rig floor area, lay down tools. PJSM with entire crew and SWS wireline crew. Discuss Safety issues and procedure. Rig up SWS wireliners, pull tools to rig floor, Make up USIT bond logging tools and test same. Wirline in hole to 700' WLM, observe Toss of telemetry. No Communication with tools. WLOH with tools. Inspect & trouble shoot same. Observe "Knuckle Joint" on Centralizer failed and flooded tool. Remove Knuckle Joint and replace Centralizer. Test tools. OK WLIH with USIT bond logging tools to locate and log form 5280' - 3080'. Logs indicated TOC @ 3360'. Effective TOC @ 3450'. Continue with USIT bond log: Logged from 5280' - 3080'. Logs indicated TOC @ 3360'. Effective TOC @3450'. Sent copy of logs to town engineer. WLOH with tools, and lay down same. Rig down all logging equipment, and tools. Clear floor area. Pull tools to floor and Rig up casing running equipment. Verify all equipment in pipe shed ready to run. PJSM with entire crew. Discuss safety, and liner running procedure. Pick up 4 1/2" L80, 12.6# IBT slotted /blank liner assembly and RIH. Make up torque =3000 Ft/Ibs. Run liner as per detail. MU Blank joint with ROT Silver Bullet Guide shoe and pup. Continue with blanks and slots space out as per engineer, with Swell packers installed @ 8555', and 9072'. Run 214 Jnts = 6696.97', with Spiral glider centralizers floating on each jnt except the Constrictor packer jnts. (177 total) Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. 17 Total Constrictor packers run. Total BHA length of liner assembly = 6707.90'. PU WT = 85K, SO WT = 65K. Continue RIH with Liner on Drill Pipe from 6708' • 8341' (1633'). PU WT = 92K, SO WT = 66K. Observed no issues when going through shoe area into open hole. Continue RIH with Liner on Drill Pipe from 834.1' - 11400' (3059'). Observed string taking weight at depths of 10280', 10644', 10915'and 11005' having to work free each time to free up and RIH to tag bottom @ 11413' Liner Measurements. Position string with Guide Shoe at planned depth of 11400'. Constrictor Packer depths area as follows, Jnt # 7 - 11175', Jnt # 25 - 10615', Jnt # 36 - 10285', Jnt # 52 - 9785', Jnt # 55 - 9685', Jnt# 63 - 9445', Swell Packer @ 9072', and 8555', Jnt # 104 - 8125', Jnt # 115 - 7785', Jnt # 124 - 7505', Jnt # 146 - 6845', Jnt # 161 - 6383', Jnt # 171 - 6055', Jnt # - 179 - 5804', Jnt # 183 - 5708', Jnt # 18T - 5565', Jnt # 191 - 5445', and Jnt # 193 - 5375'. Lay down 1 Lo-Tad in connection at rig floor. PU WT = 140K, SO WT = 70K. Drop 1 1/2" ball, chasing with pump to 400 stks and pressure up to 2000 PS1. Set down 55K to set slips as per BOT rep, continue pressure up to 4200 PSI, to complete setting PKR. Bleed pressure and pull up to 115K allowing "dogs" to kick out. Re-Tag liner top to verify for space out. Liner top = 4703.62'. Rig up and pressure test down annulus to test PKR at 1000 PSI - 5 Minutes. Stand back one stand and CBU - 2000 STks @ 63 SPM -1000 PSI. Blow down Top Drive and Kill Line. Monitor well -Static. Printed: 12/29!2005 9:54:06 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11/12/2005 16:30 - 21:30 21:30 - 22:30 22:30 - 00:00 11/13/2005 00:00 - 01:45 5.00 ~ CASE L RUNL ~ CMPLTN 1.001 CASE I RURD I CMPLTN 1.50 1.75 01:45 - 02:45 1.00 02:45 - 03:15 0.50 03:15 - 05:45 2.50 05:45 - 06:45 1.00 06:45 - 07:30 I 0.75 07:30 - 08:15 0:75 08:15 - 12:00 3.75 12:00 - 12:45 0.75 WIN 12:45 - 13:45 1.00 WIN 13:45 - 15:30 1.75 WIN 15:30 - 16:00 0.50 WIN 16:00 - 16:30 I 0.50 CMPLTN PROD2 ~THR PROD2 ULD PROD2 RIP PROD2 THR PROD2 ETW I PROD2 IRC PROD2 TWP PROD2 fWP IPROD2 RC PROD2 21P PROD2 JLD PROD2 rHR PROD2 Page 9 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Re{ease: 12/5/2005 Group: Rig Number: Description of Operations POOH, breakout and lay down all 40 Lo-Tads on drill string, leaving 30 stands of Sliders on Drillers side, and 10 stands of Slick DP on Off Drillers Side. Make Breaks, inspect BOT running tool assembly. Clean up all Lo-Tads, drained and wiped off for Target Zero, and remove from Rig Floor area. Clean & Clear floor, and lay down BOT running tools. PJSM with entire crew and BOT rep, Sperry Sun MWD & DD. Discuss Safety issues, and whipstock pick up procedure. Change elevators and pull tools to rig floor. PJSM with entire crew & BOT rep. Discuss Safety Issues and Whipstock Make up Procedure. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 5/8" Unloader Sub (5.20'), 2 - 3 1/2 IF pups (11.85', 4.75'), 2-jnts 3 1/2 DP (31.33', 31.28'); Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup (1.69'}, 8~ 518" Whipstock slide (15.47'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 -jnt 3 1/2" HWDP (29.8'), 4 3/4" NM Float sub (1.41 `), DM HOC (8.56`), Slimphase 4 w/ DGR & RES (24.18'), TM HOC (10.90'), 2 - 4 3/4" Bumper jars (7.84', 7.57'). Plug in and Up load MWD assembly. Make up 2 stands of Hybrid Drill Collars (180.94') and Crossover (1.07') and MU Top Drive. Perform shallow pulse test on MWD with 78 SPM - 850 PSI, 275 GPM's. Good Test TIH at 2 minutes /stand as per BOT rep, from 395' - 4259'. (3864). Perform Mad Pass from 4259' - 4325' (66') as per GEO @ 86 SPM - 300 GPM , 1850 PSI. Orient whipstock face to 8 degrees left of high side while Mad Pass. Continue TIH from 4325' - 4703' (378'). PU WT = 125K, SO WT = 114K. Orient Whipstock face to 5 Degrres left of high side as per DD & i Co. Rep. Tag top of A2 liner @ 4703' and set bottom trip anchor with 15k Set down. Pull 10K over to verify set. Shear bolt setting down 35-45K, 3 times, and pull up to neutral position. Rotate free at 4-6K free Torque. Top of window = 4593'. Bottom = 4605'. Displace well from 8.9 PPG SFMOBM to 8.9 PPG MOBM @ 93 SPM - 330 GPM's , 2350 PSI. Mud @ YP - 19, Visc - 66. Total displacement = 183 BBLS. Mill window as per BOT rep from 4593' - 4605' (12'}, and open hole from 4605' - 4632' (27'), leaving 20' of gauged hole as per plan. Avg mill speed through window = 5.50 ft/hr. Avg Weight on mills = 2-7K, with torque at 3-8K at 50-110 RPM's. 93 SPM - 330 GPM's and 2350 PSI. Obtain SPR's @ 4593 MD 3510 TVD Pump #1 = 25 SPM - 300 PSI, 35 SPM - 460 PSI. Pump #2 = 25 SPM - 310 PSI, 35 SPM - 450 PSI. PU WT = 105K, SO WT = 80K, ROT WT = 80K. Wash & ream through window area, while pump sweep to clean window. Work window with and without pump to verify good & clean. Pump sweep @ 90 SPM - 330 GPM, 2170 PSI, with 110 RPM's - 3-4K torque. Monitor well -static. Pump dry job, and blow down Top Drive. POOH with milling assembly, monitor well at BHA -static. PJSM, discuss Safety and Lay down procedure. Lay down both Bumper jars. Plug in and download MWD assembly. Printed: 12/29!2005 9:54:06 AM • ConocoPhillips Alaska Page 10 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Nam e: ROT -D RILLIN G Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ ppco.co m Rig Release: 12/512005 Group: ' Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations ~ 11!13!2005 16:30 - 17:15 0.75 WINDO ULD PROD2 Continue Breakout & lay down remaining BHA. Lay down 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 -jnt 3 1/2" HWDP (29.8'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR &RES (24.18'}, TM HOC (10.90'). Upper mill gauged to full 6.750". 17:15 - 18:30 1.25 WINDO ULD PROD2 Clean & clear rig floor. Send tools out. Pull stack washer to rig floor. RU, BOLDS 8~ pull wear bushing.. MU stack washer and flush stack. Lay do stack washer. 18:30 - 20:15 1.75 WELCT BOPE PROD2 Rig up to test BOP's. Install test plug. Fill stack & lines. 20:15 - 23:00 2.75 WELCT BOPE PROD2 Test BOP stack, HCR's & manual valves. Test Choke mainfold valves, upper & lower IBOP valves, floor safety valve & dart valve. Pu11 test joint &-test Blind rams. All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Perform Accumulator test @ 1900 PSI after close, 2minutes -36 sec. 3000 PSI -3 minutes -12 sea John Crisp with AOGCC waived witness of test. 23:00 - 00:00 1.00 WELCT BOPE PROD2 Pull test plug, install wear bushing i~ RILDS. Rig down all test equipment. Blow down equipment. 11!14/2005 00:00 - 00:30 0.50 DRILL PULD PROD2 Clean & Clear Rig Floor area. Send tools out. Pull tools to Rig Floor. 00:30 - 01;45 1.25 DRILL PULD PROD2 PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #6. Make up 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.83'), 4 3/4" Non Mag float sub (1.41'), 4 314" Integral 81ade stabilizer (5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR &RES (24.18'), PWD Collar (10.73'), TM HOC (10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars i 94.55 Hrs on 11/11/05) (28.59'), 4 - Jnts 4" HWDP (120.96'). Total BHA length = 369.1T. 01:45 - 02:45 1.00 DRILL OTHR PROD2 Plug In and Upload MWD assembly 02:45 - 03:15 0.50 DRILL TRIP PROD2 RIH to 369' and perform shallow pulse test @ 85 SPM - 300 GPM - 2225 PSI. 03:15 - 05:30 2.25 DRILL TRIP PROD2 Continue Trip In hole from 369' - 1953' (1584'). MU 4 3/4" Andergauge Agitator and Shock Sub with crossovers. Agitator = 1975.55' from bit. Continue TIH to 4588'. 05:30 - 07:00 1.50 RIGMNT RSRV PROD2 Slip & Cut 60' of drilling line. Inspect Saver sub. Good. 07:00 - 07:15 0.25 DRILL TRIP PROD2 PU WT = 95K, SO W7 = 75K. Orient toolface to High Side, pumps off, slide through window area from 4592' - 4605' with no issues to bottom of gauged hole @4623'. Pumps on @ 300 GPM's - 3450 PSI. Obtain clean hole ECD @ 9.64 PPG before begin drilling. MW = 9.0 PPG. YP = 17, Visc = 72 07:15 - 07:30 0.25 DRILL REAM PROD2 Wash i;< Ream from 4623' - 4632' (9'). Pumps @ 86 SPM, 300 GPM's - 3450 PSI. 07:30 - 12:00 4.50 DRILL DRLG PROD2 Directional drill 6 3/4" Hole in the "B" lateral from 4632' - 4962' MD (330'). TVD = 3523'. ART = 1.18 HRS, AST = 1.64 HRS, ADT = 2.82 HRS. PU WT = 95K, SO WT = 72K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 5-10K, RPM's = 80, Pumps @ 86 SPM, 300 GPM's - 3450 PSI. Total Jar Hrs = 97.04. Total Bit Hrs = 2.82 ECD at 9.72 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4679' MD, 3526' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 890 PSI. Pump #2 - 25 SPM - 630 PSI, 30 SPM - 870 PSI. 12:00 - 00:00 12.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole in the "B" lateral from 4962' - 5581' MD (889'). TVD = 3523'. ART = 9.50 HRS, AST = .60 HRS, ADT = 10.10 HRS. PU WT = 96K, SO WT = 71 K, ROT WT = 83K, Torque off Printed: 1229/2005 9:54:06 AM • ConocoPhillips Alaska Page ~ ~ of 2a Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Gode Phase Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 11/14/2005 112:00 - 00:00 12.00 DRILL DRLG PROD2 11/15/2005 100:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 00:00 I 12.00 DRILL DRLG I PROD2 11/16/2005 00:00 - 12:00 I 12.00 I DRILL DRLG PROD2 12:00 - 00:00 12.00 DRILL DRLG I PROD2 btm = 4K, Torque on bottom = 4-5K. WOB = 2-12K, RPM's = 75-80, Pumps @ 86 SPM, 300 GPM's - 3550 PSI. Total Jar Hrs = 109.96. Total Bit Hrs = 12.92 ECD at 9.81 PPG. Mud WT = 8.9 PPG Viscosity = 71, YP = 18. SPR's @ 5333' MD, 3532' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 880 PSI. Pump #2 - 25 SPM - 620 PSI, 30 SPM - 910 PSI. Observed Drilling through Concretions at 5082' - 5090' (8'), 5106' - 5128' (22'), 5235'-5248' (13'), 5440' - 5445' (5'). Max Gas units = 135 Continue Directional drill 6 3/4" Hole in the "B" lateral from 5581' - 6581' MD (1000'). ND = 3528'. ART = 7.90 HRS, AST = 2.30 HRS, ADT = 9.39 HRS. PU WT = 100K, SO WT = 69K, ROT WT = 81 K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, Pumps @ 86 SPM., 300 GPM's - 3700 PSI. Total Jar Hrs = 119.35. Total Bit Hrs-= 22.31 ECD at 10.20 PPG. Mud WT = 8.8 PPG Viscosity = 65, YP = 18. SPR's @ 6264' MD, 3527 ND. Pump #1 - 25 SPM - 630 PSI, 35 SPM - 810 PSI. Pump #2 - 25 SPM - 630 PSI, 30 SPM - 860 PSI. Observed Drilling through Concretions at 5581' - 5589' (8'}, 5702' - 5705' (3'), 5778'-5782' (4'), 5784' - 5793' (9'), 5809'-5822' (13'), 5993'-6001' (8'), 6240'-6243' (3'), 6436'-6440' (4'),.6506'-6518' (12'), 6524'-6533' (9'). Max Gas units = 131. Survey @ 6499' MD, 3525' ND = 89.73 Deg Inc, AZ - 358 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 6581'-7655' MD (1074'). TVD = 3541'. ART = 6.85 HRS, AST = .62 HRS, ADT = 7.47 HRS. PU WT = 106K, SO WT = 64K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, Pumps @ 91 SPM, 320 GPM's - 3750 PSI. Total Jar Hrs = 126.82. Total Bit Hrs = 29.13 ECD at 10.34 PPG. Mud WT = 8.8 PPG Viscosity = 66, YP = 18. SPR's @ 7480' MD, 3535' TVD. Pump #1 - 25 SPM - 630 PSI, 35 SPM - 840 PSI. Pump #2 - 25 SPM - 690 PSI, 30 SPM - 910 PSI. Observed Drilling through Concretions at 6809' - 6814' (5'), 6774' - 6784' (10'), 6983' - 6986' (3'), 7634'-7640' (6'). Max Gas units = 248. Survey @ 7526' MD, 3536' ND = 87.86 Deg Inc, AZ - 1.91 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 7655' -8813' MD (1158'). TVD = 3575'. ART = 6.87 HRS, AST = 1.82 HRS, ADT = 8.69 HRS. PU WT = 103K, SO WT = 65K, ROT WT = 81 K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 91 SPM, 320 GPM's - 3900 PSI. Total Jar Hrs = 135.51. Total Bit Hrs = 37.82 ECD at 10.41 PPG. Mud WT = 8.8 PPG Viscosity = 63, YP = 18. Gels 17/25 SPR's @ 8320' MD, 3550' TVD. Pump #1 - 25 ,SPM - 660 PSI, 35 SPM - 850 PSI. Pump #2 - 25 SPM - 650 PSI, 30 SPM - 860 PSI. Observed Drilling through Concretions at 7702' - 7709' (7'), 7989' - 7998' (9'), 8225' - 8232' (7'), 8236'-8260' (24'), 8476'-8492' (16'), 8682'-8700' (18'), 8705'-8723' (18'), 8749'-8755' (6'). Max Gas units = 243. Survey @ 8645' MD, 3570' TVD = 87.68 Deg Inc, AZ - 357.0 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 8813' - 9880' MD (1067'). TVD = 3575'. ART = 5.60 HRS, AST = 1.94 HRS, ADT = 7.54 HRS. PU WT = 110K, SO WT = 60K, ROT WT = 84K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 88 SPM, 310 GPM's - 3850 PSI. Total Jar Hrs = 143.05. Total Bit Hrs = 45.20 ECD at 11.0 PPG. Mud WT = 8.85 PPG Viscosity = 62, YP = 18. Gels 17/25 SPR's @ 9722' MD, 3536' TVD. Pump #1 - 25 SPM - 650 PSt, 35 SPM - 900 PSI. Pump #2 - 25 SPM - 680 PSI, 30 Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Start: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 11/16!2005 12:00 - 00:00 I 12.00 DRILL ~ DRLG ~ PROD2 11/17/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD2 12:00 - 00:00 I 12.00 I DRILL I DRLG I PROD2 11/18/2005 100:00 - 01:15 01:15 - 05:30 05:30 - 06:30 06:30 - 08:00 08:00 - 10:30 10:30 - 12:00 12:00 - 18:00 18:00 - 18:30 1.25 DRILL ~ CIRC PROD2 4.251 DRILL I WIPR I PROD2 1.00 RIGMNT RGRP PROD2 1.50 DRILL WIPR PROD2 2.501 DRILL CIRC PROD2 1.501 DRILL ;CIRC I PROD2 6.001 DRILL (TRIP IPROD2 0.501 DRILL (TRIP IPROD2 Page 12 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations SPM - 920 PSI. Observed Drilling through Concretions at 9600' - 9606' (6'). Max Gas units = 167. Survey @ 9770' MD, 3536' TVD = 91.14 Deg Inc, AZ - 358.45 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 9880' - 10748' MD (868'). TVD = 3591'. ART = 7.57 HRS, AST = .95 HRS, ADT = 8.52 HRS. PU WT = 118K, SO WT = 57K, ROT WT = 82K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 3900 PSI. Total Jar Hrs = 151.57. Total Bit Hrs = 53.72 ECD at 10.92 PPG. Mud WT = 8.8 PPG Viscosity = 66, YP = 17. Gels 17/26 SPR's @ 10189' MD, 3557' TVD. Pump #1 - 25 SPM - 770 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 710 PSI, 30 SPM - 970 PSI. Observed Drilling through Concretions at 9942' - 9956' (12'), 10146'-10150' (4'), 10184'-10191' (7'), 10264'-10281' (17'), 10376'-10381' (5'), 10395'-10460' (65'), 10471'-10495 (24'). Max Gas units = 85. Survey @ 10607' MD, 3580' TVD = 85.40 Deg Inc, AZ - 359.00 Deg. Continue Directional drill 6 3!4" Hole in the "B" lateral to TD from 10748'-11472' MD (724'). TVD = 3612'. ART = 7.45 HRS, AST = .69 HRS, ADT = 8.14 HRS. PU WT = 140K, SO WT = 55K, ROT WT = 90K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 4000 PSI. Total Jar Hrs = 159.71. Total Bit Hrs = 61.86 ECD at 11.34 PPG. Mud WT = 8.85 PPG Viscosity = 70, YP = 17. Gels 17/26 SPR's @ 11017' MD, 3596' TVD. Pump #1 - 25 SPM - 760 PSI, 35 SPM - 1040 PSI. Pump #2 - 25 SPM - 790 PSI, 30 SPM - 1080 PSI. Observed Drilling through Concretions at 10497' - 10503' (6'), 10513'-10525' (12'), 10582'-10600' (18'), 10699'-10715' (16'), 10780'-10800' (20'), 11095'-11102' (7'), 11186'-11188' (2'), 11297'-11303' (6'}, 11325'-11327' (2'), 11338'-11345' (7'). Max Gas units = 75. Survey @ 11472' MD, 3612' TVD = 83.37 Deg Inc, AZ - 2.88 Deg. Last survey @ TD and projected Inc and AZ. Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 84 SPM- 300 GPM's - 4100 PSI. Reciprocate & Rotate drill dtring @ 100 RPM's, 6K Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% increase in cutting when sweep across shakers, and shakers clean. Monitor well -Static: BROOH from 11472' - 8791' (2681'). Back ream rate at 86 SPM - 300 GPM's - 3900 PSI. Torque = 6K. 80 RPM's. PU WT = 107K, SO WT = 64K @ 8791'. Observed clean hole and no issues. Finish circulating bottoms up and shakers clean. Hole took proper fill ,Observed Swivel packing leaking. Change out swivel packing. ~ Trip back in hole on elevators from 8791' -11472' (2681'}. Observed clean hole conditions. PU WT = 125K, SO WT = 52K. Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 85 SPM- 300 GPM's - 4000 PSI. Reciprocate & Rotate drill dtring @ 95 RPM's, 6K Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% increase in cutting when sweep across shakers, and shakers clean. Displace well from 8.85 PPG MOBM to 8.80 PPG SFMOBM @ 81 SPM -4000 PSI. 95 RPM's, 5-6K torque. POOH on elevators form 11472' - 1975' (9497'). Observe clean hole conditions and hole taking proper fill. Make up Top drive and pump down drill string to verify Anderguage Agitator working. Observe Agitator working with "LESS" vibration than normal or expected. Breakout and lay down Agitator & Shock Sub with Printed: 12/29/2005 9:54:06 AM • • ConocoPhillips Alaska Page 13 of 24 Operations Summary Report Legal Well Common i Event Nam Contractor Rig Name: Date Name: Well Name: e: Name: From - To 1J-164 1J-164 ROT -D n1334@ Doyon 1 Hours RILLIN ppco.co 41 Code G m Sub Code Phase 11/18/2005 18:00 - 18:30 0.50 DRILL TRIP PROD2 18:30 - 20:15 1.75 DRILL PULD PROD2 20:15 - 21:15 1.00 DRILL OTHR PROD2 21:15 - 22:00 0.75 DRILL PULD PROD2 22:00 - 22:30 -0:50 DRILL PULD GMPLT2 22:30 - 23:00 0.50 RIGMNT RSRV GMPLT2 23:00 - 23:30 0.50 WINDO ULD GMPLT2 23:30 - 00:00 0.50 WINDO ULD GMPLT2 11/19/2005 00:00 - 00:45 0.75 WINDO ULD GMPLT2 00:45 - 05:15 4.50 WINDO RIP GMPLT2 05:15 - 05:30 0.25 WINDO RIP GMPLT2 05:30 - 06:15 0.75 WINDO RIP GMPLT2 06:15 - 06:45 0.50 WINDO RIP GMPLT2 06:45 - 07:30 0.75 WINDO IRC GMPLT2 07:30 - 10:15 2.75 WINDO RIP GMPLT2 10:15 - 11:15 1.00 WINDOV~ IP 11:15 - 12:00 0.75 WINDO , ULD GMPLT2 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations crossovers. Continue POOH from 1975' - 95' (1880'). Stand back 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.66'), t - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars (159.71 Hrs on 11!18!05) 28.59'), 4 - Jnts 4" HWDP (120.96'). Plug in and download MWD assembly. Continue POOH, breakout and lay down BHA #6. Lay down 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6R - 6.0 stage with a 1.5 degree bend in motor (32.83'), 4 3/4" Non Mag float sub (1.41'), 4 3/4" Integral Blade stabilizer (5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR 8~ RES ( 24.18'), PWD Collar (10.73'), TM HOC (10.90'). Bit Gauged to 2 / 2 / WT/T/X/I/NO/TD. Clear & Clean Rig Floor area. Send tools outside. Service Top Drive, and Lubricate rig. Inspect Swivel packing. Pull tools to rig floor for next BHA. PJSM with crew & BOT REP. Discuss safety issues, new hands on rig crew, and procedure for picking up next BHA. PJSM -New Crew, Discuss Safety issues, weather @ -34 Degrees and Procedure for PU whipstock retrieving assembly. MU BHA. MU Retrieving Nook (7.5'}, 1 - jnt 3 1/2" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), 2 - 4 3/4" Bumper jars (7.84', 7.57'), 4 3/4"Oil Jars 11.14'), Crossover (1.66'), 2 -stands Hybrid Push Pipe (180.94'). Trip in hole from 248' - 3051' (2803'), stopping on each joint to reposition and inspect, and retorque each super slider, 90 total. Fill drill string with mud, and blow down Top Drive. . Continue TIH from 3051' - 4600' (1549'). PU WT = 102K, SO WT = 80K. Pump @ 313 GPMs - 1650 PSI. Locate & hook whipstock @ 4596' (slot). Pull up to 50K over to jar 3 times and observe assembly pull free @ 190K, @ 4597' Circulate Bottoms up @ 313 GPM's - 1600 PSI. No Gas observed, well static. Blow down Top Drive. PU WT = 108K. POOH from 4597' - 247' (4350'), slow at first to observe well taking correct hole fill, not swabbing. Breakout & lay down Retrieving Hook assembly. ,Breakout & lay down whipstock and space out assembly. Crew change. 12:00 - 12:30 ~ 0.50 ~ WINDOWPULD ~ GMPLT2 ~ Continue Breakout & lay down whipstock and space out assembly. Observe debris, sand ,shale above and below Debris Barrier cup, with quite a bit of clay and sand on Space out pipe as well. Observed Debris cup folded over. Recovered a "Small Fitting" on cup. ??? Pictures sent to town. 12:30 - 13:30 1.00 CMPLTN FCO GMPLT2 Clean & clear rig floor area. perform thorough Inspection of Top Drive. Observed no missing fittings. 13:30 - 14:30 1.00 CMPLTN FCO GMPLT2 Pull tools to rig floor. MU clean out BHA. MU 6 3/4" HTC STR09 Roller Cone insert Bit (.80'), Bit sub (2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'), 4 314" Drilling Jar (156.52 HRS on 11118105) (28.59'), and 4 jnts 4" HWDP (120.96'). Total BHA = 282.62'. 14:30 - 16:30 2.00 CMPLTN TRIP GMPLT2 Trip in hole from 283' - 4575' (4292'). 16:30 - 18:00 1.50 CMPLTN FCO I GMPLT2 Break circulation @ 80 SPM - 1290 PSI, UP WT = 103K, SO WT = 80K, ROT WT = 84K. Wash down from 4575' - 4703' (128'). Continue rotate and wash from TOW @ 4593' back down to top of PKR at 4703'. Printed: 12/29/2005 9:54:06 AM 2.501 RIGMNT RSRV CMPLT2 0.501 CMPLTN RURD CMPLT2 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-164 Common Well Name: 1 J-164 Event Name: ROT -DRILLING Start: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 11/19/2005 16:30 - 18:00 1.501 CMPLTN FCO CMPLT2 18:00 - 21:00 3.00 CMPLTN TRIP CMPLT2 21:00 - 23:30 23:30 - 00:00 11 /20/2005 100:00 - 04:15 04:15 - 04:30 04:30 - 07:00 07:00 - 08:30 08:30 - 12:00 4.251 CMPLTN{ RUNT I CMPLT2 0.25 ~ CMPLTNI RUNT ~ CMPLT2 2.501 CMPLTNI RUNT CMPLT2 1.501 CMPLTNI RUNT I CMPLT2 -r.~ Page 14 of 24 Spud Date: 11/1/2005 End: 12/5/2005. Group: Description of Operations Observed lots of sand across shakers at bottoms up, work drill string and circulate until shakers clean. Trip out of hole from 4703' - 383' (4420'). Breakout & lay down clean out assembly. Lay down 6 3!4" HTC STR09 Roller Cone insert Bit .80'), Bit sub (2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling Jar (156.52 HRS on 11/18/05) (28.59'), and 4 jnts 4" HWDP 120.96'). Total BHA = 282.62'. Clear & clean rig floor area. Change out Saver sub on Top Drive. Pull tools to floor & RU casing running equipment. Check out all Liner running order, pups, and Hook hanger assembly in Pipe shed. PJSM with new crew. Discuss safety issues and procecure for PU 4 1/2" Liner assembly. Make up Guide shoe joint with ROT Silver Bullet Guide shoe and crossover (31.86'). Continue RIH with 4 1/2" Blanks / Slots as per liner detail. Run a total of 109 Blanks, 109 Slots, with 2 Swell packers spaced out to locate at 9462' & 8804'. We tagged the A2 liner top Crossover, and pulled back to rotate 1/2 RH turn in string and went through window on second attempt. Continue RIH picking up 4 1/2" liner as per detail, from 4595' - 6833' (2238'). PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model 61 FHH Hook Hanger assembly, pups, with crossover joint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Total Hook Hanger assembly = 55.70'. 3.50 ~ CMPLTNI TRIP ~ CMPLT2 ~ Continue TIH with liner assembly on drill pipe from 6877 -9681' (2804'). Perform pulse test on MWD assembly, good test, and fill drill string every 10 stands @ 128 GPM's -700 PSI. 12:00 - 13:00 1.00 CMPLTN TRIP CMPLT2 Continue TIH with liner on Drill pipe from 9681' - 11421' (1740'). Fill every 10 stands. 13:00 - 15:30 2.50 CMPLTN OTHR CMPLT2 Break circulation at 125 GPM - 1100 PSI. Orient to 10 Degrees left of high side, slack off to liner depth at 11452'. Hook window. PU and orient 180 degrees out and slack off to RIH past bottom of window to liner depth of 11460'. Pull Back up, reorient to 10 degrees left of high side and land Hook Hanger on bottom of window @ 4605'. Set down 30K. Drop 1 3/4" ball and chase with 3 BPM - 1100 PSI. Slow pump to 1 BPM -observe ball land 8 seat, pressure to 2800 PSI. Shear off & pull up to 11 OK. Attempt to shear ball with pressure to 4200 PSI. Not sheared. Pull 1 stand, RU test pump and shear ball at 4800 PSI. Rig do test pump & blow down lines. Top of hook hanger @ 4587.37' 15:30 - 17:30 2.00 CMPLTN TRIP CMPLT2 POOH with running and setting tools. 17:30 - 18:30 1.00 CMPLT RURD CMPLT2 Breakout, lay down and inspect running and setting tools. 18:30 - 19:30 1.00 CMPLTN RURD CMPLT2 Clean & clear rig floor area. Pull tools to floor. RU casing running equipment for LEM run. 19:30 - 20:00 0.50 CMPLTN SFTY CMPLT2 PJSM with entire crew, BOT rep. Discuss safety Issues and procedure for LEM make up with 2 7/8" inner string. 20:00 - 21:30 1.50 CMPLTN PULD CMPLT2 Make up LEM assembly. Baker Seal assembly (3.26'), Crossover joint IBT x STL (42.74'), 4 1/2" IBT pup (30.84'), Camco "DB" Nipple 3.563" ID (1.52'), 4 1/2" IBT JNT (31.09'), 3 - 4 1/2" IBT pups (14.08',9.83',3.82'), LEM assembly (34.62'), 6 - JNTs of 4 1/2" IBT (182.35'), 4 1/2" IBT pup (5.80'), Baker Casing Swivel (2.81'), XO Bushing (1.41'), 109-47 Casing Seal Bore receptacle (19.65'). Set low Printed: 1212912005 9:54:06 AM • ConocoPhil~ips Alaska Page 15 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1 J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11/20/2005 210.30 - 00:00 2.50 CMPLT~ PULD CMPLT2 11/21/2005 ~ 00:00 - 00:30 ~ 0.501 CMPLTNI PULD CMPLT2 00:30 - 01:15 I 0.751 CMPLTNI PULD I CMPLT2 01:15 - 01:45 0.50 CMPLTN PULD CMPLT2 01:45 - 02:30 0:75 RIGMNT RSRV CMPLT2 02:30 - 03:15 0.75 RIGMNT RSRV CMPLT2 03:15 - 05:15 2.00 WAITON EQIP CMPLT2 05:15 - 08:30 I 3.251 CMPLTNI PULD I CMPLT2 08:30 - 11:15 ~ 2.751 CMPLTNI TRIP I CMPLT2 11:15 - 12:00 I 0.751 CMPLTNI RUNT I CMPLT2 12:00 - 12:30 0.501 CMPLTNI PCKR CMPLT2 12:30 - 14:15 1.75 CMPLTN TRIP CMPLT2 14:15 - 16:30 2.25 CMPLTN PULD CMPLT2 16:30 - 17:00 0.501 CMPLTNI PULD CMPLT2 17:00 - 17:30 ~ 0.501 WINDOV'~IPULD ~ PROD3 17:30 - 19:00 1.501 WINDOWPULD I PROD3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number. Description of Operations in slips for inner string. RU 2 7/8" inner string tools. MU Ball seat and XO (2.49'), on first joint. Observe joint galded when torque applied.. Breakout & change out joint and inspect crossover. Good. Make up first joint. MU torque = 1500 ft/Ibs. RIH with 5 joints of 2 7/8" 8.7# inner string tubing. Continue RU 2 7/8" inner string tools. MU torque = 1500 ft/Ibs. RIH with 3 more joints of 2 7/8" 8.7# inner string tubing. Observe Tag up solid on inner string. Calculate that the Collars on 2 7/8" tbg were 3.68" OD. ID of LEM = 3.68", and DB nipple ID = 3.56". We tagged with the Shear Sub (3.66") on the LEM. Rig Up & POOH with 8 joints of 2 7/8" Inner String. Breakout ~ lay down Shear Sub assembly. Rig down 2 7/8" equipment to run inner string.Clear & clean floor area. Slip ~ Cut drilling line.-Inspect brakes on draw works. - Service Top Drive. Wait on 2 3/8" inner string pipe, and equipment form Baker Fishing shop. Load pipe shed with 2 3/8" DP. Pull handling tools to rig floor. Strap all tools and pipe. MU Mule shoe & Shear Sub assembly with 11 jnts of 2 3/8" spaced out to 13' below seals. MU ZXP packer assembly (18.90'). PU WT = 45k, SO WT = 45K. Total BHA = 420.97' TIH with LEM assembly & inner string from 421' -4685' (4264'). PU WT = 118K, SO WT = 93K. Rig up and pump down string @ 160 GPMs- 850 PSI to wash from 4685' -4748' (63'). wITH pumps off, seals going into CSB and observe "LAtch Up" on Hook Hanger with LEM @ 4749' as per detail. Drop 1 3/4" ball down string. Allow ball to fall chase with 2 BPM and observe ball landed. Pressure up to 3000 PSI to set ZXP packer, continue pressure to 4000 PSI to release setting tool. Pull up to 115K, bleed pressure. RU and pump down annulus to pressure test ZXP to 1000 PSt for 5 Minutes. Record on chart. Bleed all pressures and blow down lines. B Lateral Liner top @ 4345.76'. POOH with LEM Running and setting tools, from 4345' - 384' (3961'). PJSM, discuss safety issues, and procedure for laying down tools. Lay down & inspect running tool. Rig up and lay down 2 3/8" inner string with shear sub and mute shoe. Clean & clear floor area, lay down all 2 3/8 handling equipment and tools. PJSM with crew, MWD and BOT reps. Discuss Safety issues and procedure for PU Whipstock assembly and space out pipe. Pull all tools and equipment to rig floor. Make up D Lateral whipstock assembly. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 518" Unloader Sub (5.18'), Kelly saver sub (2.70'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.00'), Bottom Trip Anchor (3.22'), Safety Disconnect (2.63'), Ported Drain Sub (1.50'), Debris Barrier sub w/ Cup (1.55'), & 5/8" Whipstock slide (14.10'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.46'), 6.750" Upper mill (5.84'), 1-jnt 3 112" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18'), TM HOC (10.90'), 2 - 4 3!4" Bumper jars (7.84', 7.57')Crossover IF x XT39 (1.66'), 2 stands 4 3/4" Hybrid Push pipe(180.94'). Total BHA = 381.43' Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11 /21 /2005 19:00 - 19:45 19:45 - 20:45 Operations Summary Report 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon141 Hours Code Code Phase 0.75 WINDO THR PROD3 1.00 WINDORIP IPROD3 20:45 - 00:00 3.25 ~ WI 11 /22/2005 00:00 - 01:15 1.25 W I N 11 01:15 - 01:45 0.50 WIN 01:45 - 02:15 0.50 WIN 02:15 - 03:00 0.75 03:00 - 09:00 6.00 09:00 - 09:45 0.75 09:45 - 1.3:30 3.75 13:30 - 14:00 0.50 14:00 - 16:00 2.00 RIP PROD3 RIP PROD3 RIP PROD3 ETW PROD3 IRC PROD3 TWP PROD3 IRC PROD3 RIP PROD3 THR PROD3 THR PROD3 16:00 - 19:15 I 3.251 DRILL I PULD PROD3 19:15 - 21:00 1.75 DRILL TRIP PROD3 21:00 - 21:30 0.50 DRILL REAM PROD3 21:30 - 00:00 2.501 DRILL DRLH I PROD3 111/23/2005 100:00 - 12:00 12.001 DRILL I DRLH ~ PROD3 12:00 - 21:00 I 9.001 DRILL I DRLH I PROD3 21:00 - 21:30 I 0.501 DRILL DEOT I PROD3 21:30 - 00:00 2.50 DRILL TRIP PROD3 11/24/2005 00:00 - 01:30 1.50 DRILL TRIP PROD3 01:30 - 05:30 4.00 WELCTI,~ ROPE I PROD3 Start: 10/31/2005 Rig Release: 12/5/2005 Rig Number: Page 16 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations Plug in and up load MWD assembly Pick up last stand of push pipe and perform shallow pulse test @ 300 i Gpms - 1000 PSI. TIH with whipstock assembly and space out pipe at 2 minutes !stand as per BOT rep. from 381' - 3548' (3167'). Fill drill string @ 2250'. Wash & MADD Pass K-13 f/ 3,361' to 3,542'. Continue to RIH to 4,212'. Orient Whipstock to 11 deg. left of highside, Set same @ 4,248', Up wt. 110K, Dn 87K. Change over to 8.8 ppg MOBM at rate of 298 gpm @ 2200 psi. Mill 6-3/4" window f/ 4,248' to 4,260', Continue to mill to 4,294' with 6-3/4" gauged hole to 4,284'. Pump Hi-vis weighted sweep & Circ hole clean at rate of 302 gpm @ 2000 psi, 60 RPM; Up 105K, Dn 93K, Rot 97K. - POOH, Lay down Jars & Bumper sub, Down load MWD tool,. Lay down & gauge mill- OK. Lay down tools from floor, Clean floor. Pull wear bushing, Flush out stack, Function alf rams, Reflush stack, Rig down ,Set wear bushing. PJSM, Pick up 6-3/4" HTC, HCM 5052 Bit, 5200 series GeoPilot, Load MWD tools, Shallow test tools. RIH to 4,196', Fill pipe & Check MWD @ 2,700'. Break circ, Work thru window @ 4,248' to 4,260' - No Problem, RIH to 4,284', Ream out of gauge hole to 4,294'. Drill 6-3/4" hole w/ GeoPilot f/ 4,294' to 4,476' MD 3,479' TVD (182'), ADT= 1.83 hrs, WOB 10/20K, 95 RPM, 265 gpm @ 1700 psi, Up 100K, Dn 78K, Rot 90K, TO on 4500 ft/Ib, TQ off 4000 ft/Ib, PWD Clean hole ECD= 9.8 ppg, PWD ECD 9.97 ppg, Max Gas 68 units, Drilled concretion f/ 4,302' to 4,310'. Drill 6-3/4" hole w/ GeoPilot f/ 4,476' to 5,555' MD 3,462' TVD (1,079'), ADT= 8.32 hrs, WOB 10/20K, 120 RPM, 302 gpm @ 2200 psi, Up 98K, Dn 76K, Rot 86K, TO on 4000 ft/Ib, TO off 4000 fUlb, Ave. ECD's 9.9 ppg, Max Gas 125 units, Drilled concretions f/ 4933' to 4955', 5037' to 5051', 5084' to 5097', 5156' to 5176', 5433' to 5447', 5453' to 5456'. Drill 6-3/4" hole w/ GeoPilot f/ 5,555' to 5,947' MD 3,465' TVD (392'), ADT= 3.79 hrs, WOB 8/25K, 80/130 RPM, 310 gpm @ 2300 psi, Up 100K, Dn 75K, Rot 86K, TO on 5000 ft/Ib, TO off 4000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 110 units, Drilled concretions f/ 5542' to 5560', 5626' to 5628', 5674' to 5682', 5697' to 5700', 5832' to 5835'. After drilling on asumed concretion for 4 hours, Lost 200 psi pump pressure, Sent command to GeoPilot and regained 200 psi then lost 200 psi again, Picked up off btm and lost 350 psi, Tagged btm and gained 500 psi, Perp to POOH. POOH on elevators, No problems- Hole in good shape. POOH (GeoPilot & Bit Twisted off), Down load MWD, Lay down Tools, Clean rig floor. Note; Fish in hole= Bit, Bit sub stab, GeoPilot (Total 15.80'), TOF @ 5931'. Rig & test BOP to 250 psi low & 3500 psi High, Choke & kill valves and maniflod, Top & Blind rams Hydrill & floor valves. Note; Unable to contact AOGCC, Left messages with Slope pager & Anchorage number, Also sent a-mail. Pflntetl: 12/29!2005 9:54:06 AM • • ConocoPhillips Alaska Page 17 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11/24/2005 05:30 - 06:30 1.00 FISH ~ PULD PROD3 06:30 - 09:15 2.75 FISH TRIP PROD3 09:15 - 09:30 0.25 FISH FISH PROD3 09:30 - -14:30 I 5.00 {FISH TRIP { PROD3 14:30 - 15:00 0.50 FISH PULD PROD3 15:00 - 17:15 2.25 FISH TRIP PROD3 17:15 - 17:45 0.50 FISH FISH PROD3 17:45 - 21:30 3.75 FISH TRIP PROD3 21.:30 - 23:00 1.50 FISH PULD PROD3 23:00 - 00:00 1.00 DRILL PULD PROD3 11/25/2005 00:00 - 00:15 0.25 DRILL PULD PROD3 00:15 - 01:15 1.00 DRILL PULD PROD3 01:15 - 01:45 0.50 DRILL PULD PROD3 01:45 - 02:00 0.25 DRILL DEOT PROD3 02:00 - 05:00 3.00 DRILL TRIP PROD3 05:00 - 05:15 0.25 DRILL REAM PROD3 05:15 - 08:15 3.00 DRILL DRLH PROD3 08:15 - 09:00 I 0.751 DRILL ! OTHR I PROD3 09:00 - 12:00 3.001 DRILL (TRIP { PROD3 12:00 - 12:45 0.75 DRILL OTHR PROD3 12:45 - 15:00 2.25 FISH PULD PROD3 15:00 - 17:45 2.75 FISH TRIP PROD3 17:45 - 18:00 0.251 FISH 1 FISH PROD3 18:00 - 21:30 3.50 FISH TRIP PROD3 21:30 - 22:30 1.00 FISH PULD PROD3 22:30 - 00:00 1.50 DRILL PULD PROD3 11/26/2005 00:00 - 00:45 0.75 DRILL PULD PROD3 00:45 - 02:15 1.50 DRILL PULD PROD3 02:15 - 03:15 1.00 DRILL PULD PROD3 03:15 - 04:00 0.75 DRILL PULD PROD3 04:00 - 04:15 0.25 DRILL DEOT PROD3 04:15 - 07:15 3.00 DRILL TRIP PROD3 07:15 - 08:45 1.50 DRILL SURV PROD3 08:45 - 09:15 I 0.501 DRILL I TRIP I PROD3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations Make up Baker fishing tools 6-1/4" Overshot w/ 5-1/4" grapple. RIH w/ fishing tools to 5901'. Break circ w/ 2.5 bpm @ 300 psi, 25 rpm w/ 3K TO, Work over fish 8~ had 200 psi pump increase, 6K TO, Set Dn w/ 20K, Pick up off bttm w! 5 to 10K drag off bttm. Monitor wel{, POOH to 4221', Monitor well, POOH- No fish recovery, Break out and inspect grapple (Showed scaring and signs that fish was inside overshot), Clean rig floor. Make up Baker fishing tools 6-1/4" Overshot w/ 5-1 /8" grapple. RIH w/ fishing tools to 5901'. Break circ w/ 2.5 bpm @ 320 psi, Up 98K, Dn 75K, 30 rpm w/ 4K TO, Work over fish @ 5931' & had no pump increase, Set Dn w/ 30K & Stalled top drive, Pick up off bttm w/ 115K & Broke back to 105K, Set back down w/ 30K. - POOH w! fish- No problems. Lay down fish and fishing tools, Clear & clean rig floor. Make up BHA #13, 6-3/4" Bit &GeoPilot. Continue to make up BHA #13. Program MWD Tools. Continue to make up BHA #13. Pulse test MWD tools, Break in GeoPilot bearings, 300 gpm @ 1550 psi, Stage rpm f! 5 to 55. RIH with no problems to 5,876', Filled pipe @ 2702' & 5036'. Precautionary wash & ream to bttm @ 5,947'. Drill 6-3/4" hole w/ GeoPilot f/ 5,947' to 6,155' MD 3,458' TVD (208'), ADT= 1.83 hrs, WOB 5/7K, 120 RPM, 313 gpm @ 2600 psi, Up 105K, Dn 65K, Rot 85K, TO on 5000 fUlb, TO off 4000 ft/1b, Ave. ECD's 10.1 ppg, Max Gas 99 units. At 6,155' Down linked to GeoPilot and observed 1500 psi pressure loss in pump pressure, Checked surface equipment- OK, Prep to POOH, Monitor well, Blow down top drive. POOH looking for wash out- Found Drilling Jars had parted at lower body section - (Total fish in hole= 220.66', TOF @ 5934'), Lay down upperjar section. Clear & Clean rig floor. Pick up & Make up 6-318" Over shot, Jars & Bumper sub, 1 std HWDP. RIH with no problems to 5939', Up 95K, Dn 68K, 30 rpm w/ 3500 ft/Ib TQ. Engage fish f/ 5,939' to 5,945', 2.5 bpm @ 350 psi, 30 rpm, Set down 18K, Gained 7K extra wt. POOH w/ fish, Had 25K drag @ 5,685'. Lay down remainder of broken Jars, Lay down fishing tools. Lay down 4-HWDP, X-O, 3-NMDC's, Float sub, Stab. Finish laying down BHA #13. Pick up 8< Make all new BHA #15, MWD tools, Stabs, PWD, Float sub, X/O sub. Program MWD tools. Pick up 3 new NMDC's, 4- HWDP, Jars, 1-HWDP. Shallow test MWD tools, Blow down top drive. RIH to 5,940' with no problems, Filled pipe @ 270' i;< 5035'. Take check shot surveys every 30' f/ 5940' to 6153' -Found 22.18 deg. dogleg @ 5933'. POOH to 5,460' & Resurvey for open hole side track. Printed: 12!29/2005 9:54:06 AM • ConocaPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11/26/2005 ~ 09:15 - 11:30 ~ 2.25 ~ DRILL ~ DRLH ~ PROD3 11:30 - 18:30 I 7.00 I DRILL I DRLH I PROD3 18:30 - 00:00 ~ 5.501 DRILL ~ DRLH ~ PROD3 111/27/2005 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00- 00:00 I 12.001 DRILL I DRLH I PROD3 111/28/2005 100:00 - 02:30 02:30 - 03:45 03:45 - 08:45 2.501 DRILL DRLH PROD3 1.251 DRILL I DEOT ~ PROD3 5.001 DRILL (TRIP IPROD3 08:45 - 09:30 0.75 DRILL TRIP PROD3 09:30 - 10:15 0.75 DRILL PULD PROD3 10:15 - 10:45 0.50 DRILL OTHR PROD3 10:45 - 12:00 1.25 DRILL PULD PROD3 12:00 - 13:45 13:45 - 15:00 15:00 - 16:15 16:15 - 18:30 18:30 - 20:00 20:00 - 00:00 1.751 DRILL I PULD I PROD3 1.25 DRILL TRIP PROD3 1.25 RIGMNT RSRV PROD3 2.25 DRILL TRIP PROD3 1.50 DRILL REAM PROD3 4.00 DRILL DRLH PROD3 111 /29/2005 100:00 - 06:30 6.50 I DRILL I DRLG I PROD3 Page 18 of 24 Spud Date: 11!1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12!5/2005 Group: Rig Number: Description of Operations Trough w/ GeoPilot f/ 5,460' to 5,470' in order to side track well, Up 102K, Dn 72K, Rot 84K, 300 gpm @ 2250 psi, 120 rpm, 5000 ft/Ib TO. Drill 6-3/4" hole w/ GeoPilot f/ 5,470' to 6,155' MD 3,473' TVD (685'), ADT= 5.44 hrs, WOB 8/17K, 100 RPM, 284 gpm @ 2300 psi, Up 105K, Dn 73K, Rot 86K, TO on 5000 ft/Ib, TO off 4000 ft/Ib. Drill 6-3/4" hole w/ GeoPilot f/ 6,155' to 6,560' MD 3,467' TVD (405'), ADT= 3.67 hrs, WOB 8/15K, 120 RPM, 313 gpm @ 2500 psi, Up 112K, Dn 69K, Rot 85K, TO on 5500 ft/Ib, TO off 5000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 83 units. Drill 6-3/4" hole w/ GeoPilot f/ 6,560' to 7,577' MD 3,486' TVD (1,017'), ADT= 8.58 hrs, WOB 3/15K, 115 RPM, 305 gpm @ 2550 psi, Up 112K, Dn 69K, Rot 86K, TO on 5500 ft/Ib, TO off 5000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 99 units, 6533' to 6573', 6584' to 6609', 7264' to 7267', 7278' to 7282', 7326' to 7332', 7366' to 7374', 7442' to 7444', 7467 to 7479'. Drill 6-3/4" hole w/ GeoPilot f/ 7,577' to 8,512' MD 3,506' TVD (935'), ADT= 9.41 hrs, WOB 5/18K, 100/120 RPM, 316 gpm @ 2800 psi, Up 125K, Dn 62K, Rot 85K, TQ on 7000 fUlb, TO off 6000 ft/Ib, Ave. ECD's 10.4 ppg, Max Gas 99 units, 7594' to 7603', 7683' to 7685', 7745' to 7747', 7791' to 7794', 7826' to 7830', 7908' to 7915', 7955' to 7964', 8122' to 8131', 8137' to 8150', 8160' to 8171', 8180' to 8188', 8195' to 8200', 8430' to 8435'. Drill 6-3/4" hole w/ GeoPilot f/ 8,512' to 8,620' MD 3,504' TVD (108'), i ADT= 2.73 hrs, WOB 7l14K, 90 RPM, 270 gpm @ 2200 psi, Up 122K, Dn 66K, Rot 83K, TO on 7000 ft/Ib, TO off 6000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 99 units. GeoPilot failure- Circ & Attempt to reestablish communication with GeoPilot. POOH to 7650' (No swabbing -Good fill), Observe well, Pump Dry job, POOH to BHA & Stand back same. Down load MWD Lay down hangoff collar, PWD, MWD, Stab, GeoPilot, Bit. Clear and c{ean rig floor. Pick up Bit, GeoPilot, Pony collar, DM collar, Smart stab, SlimPhase 4 w/DGR, PWD, Hangoff collar. Program MWD tools, RIH w/ NMDC's, HWDP, Jars, Surtace test MWD tools. RIH to 4192'. Slip & cut drilling line, Service top drive and drawworks. RIH with no problems to 8211' (Pipe stopped-Ran out of weight). Wash & ream f/ 8211' to 8620'. Drill 6-3/4" hole w/ GeoPilot f/ 8,620' to 8,955' MD 3,494' TVD (335'), ADT= 2.41 hrs, WOB 8/12K, 120 RPM, 330 gpm @ 3200 psi, Up 134K, Dn OK, Rot 85K, TO on 6000 ft/Ib, TO off 5000 ftilb, Ave. ECD's 11.0 ppg, Max Gas 57 units. No Concretions. Continue Directional drill 6 3!4" Hole in the "D" lateral from 8955'-9474' MD (519'). TVD = 3479'. ADT = 5.34 HRS. PU WT = 130K, SO WT = 60K, ROT WT = 85K, Torque off btm = 5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 120, Pumps @ 92 SPM, 327 GPM's - 3100 PSI. Total Jar Hrs = 37.58 Total Bit Hrs = 7.75 ECD at 10.94 PPG. Mud WT = 8.8 PPG Viscosity = 79, YP = 17. Gels 15/22. Max Gas units = 79. Survey @ 9388' MD, 3475.3' ND = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9259' - 9262' (3'), Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 19 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 11 /29/2005 00:00 - 06:30 06:30 - 08:15 08:15 - 12:00 12:00 - 13:00 13:00 - 14:15 6.50 ~ DRILL DRLG ~ PROD3 1.751 DRILL I OTHR I PROD3 3.751 DRILL (TRIP IPROD3 1.001 DRILL (TRIP IPROD3 1.251 DRILL PULD PROD3 14:15 - 16:30 16:30 - 21:00 21:00 - 21:15 21:15 - 22:00 22:00 - 00:00 2.251 DRILL I PULD I PROD3 4.501 DRILL (TRIP I PROD3 0.251 DRILL I REAM I PROD3 0.75 DRILL REAM PROD3 2.00 DRILL DRLG PROD3 11/30/2005 00:00 - 12:00 12.00 DRILL ~ DRLG ~ PROD3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 9279'-9290' (11'), 9430'-9434' (4'), 9464'-9474' (10') = 28' total concretions. Observed MWD failure. Attempted to restart MWD, cycle pumps multiple times, adding 20K to WOB as per DD pulling from 9474' - 9239'. No success achieved. Monitor well -static. Pump dry job. POOH from 9239' - 4196' (5043'). Monitor well at window depth. Static. Continue POOH from 4196' - 368' (3828'). Calculated hole fill at 50 BBLs, Actual hole fill @ 56 BBLS. Rack back 4" HWDP 8r Jars, NM Flex Drill collars. Lay down Stabilizer & Float sub: Plug in and download MWD assembly. Lay down TM, PWD, Slimphase 4 w/ DGR & EWR, Smart Stabilizer, DM Pony Collar Gea Pilot and Bit. PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #17. Make up 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES (24.38'), PWD Collar (10.78'), TM HOC (10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11/29/05) (28.88'), 4 - Jnts 4" HWDP (121.21').Total BHA length = 369.34'. Perform Shallow pulse test @ 84 SPM - 1900 PSI. Good Test. Trip in hole from 369' - 8727' (8358'). Run 17 stands of 4" DP(1587.96'), Install Crossover sub (1.64'), Andergauge Agitator (8.73'), Shock Sub (8.37'), and Crossover Sub (1.66').Fill drill string every 20 stands. Continue TIH to 8727'. PU WT = 92K, SO WT = 80K, Orient and observe no issues going through window area. Wash i~ Ream from 8727' - 8793' (66'), @ 40 SPM, 142 GPM's - 1500 PSI, 70 RPM's Torque @ 6K. Observe correct hole fill. Continue RIH to 9354' on elevators. !Wash & Ream from 9354' - 9474' (120'). Continue Directional drill 6 3/4" Hole in the "D" lateral from 9474' - 9496' MD (18'). TVD = 3478'. ADT = .85 HRS. AST = .38 HRS. ART = .47 HRS. PU WT = 110K, SO WT = 47K, ROT WT = 77K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 5-12K, RPM's = 75, Pumps @ 81 SPM, 287 GPM's - 3800 PSI. Total Jar Hrs = 38.43 Total Bit Hrs _ .85 ECD at 10.39 PPG. Mud WT = 8.85 PPG Viscosity = 88, YP = 18. Gels 16/24. Max Gas units = 30, BGG = 17 units. Survey @ 9388' MD, 3475.3' TVD = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9474' - 9480' (6') = 6' total concretions. SPR's @ 9537' MD, 3481' TVD. Pump #1 - 25 SPM - 740 PSI, 35 SPM - 1060 PSI. Pump #2 - 25 SPM - 840 PSI, 30 SPM - 1190 PSI. Continue Directional drill 6 3/4" Hole in the "D" lateral from 9496'-10070' MD (574'). TVD = 3501'. ADT = 7.84 HRS. AST = 1.48 HRS. ART = 6.36 HRS. PU WT = 110K, SO WT = 50K, ROT WT = 79K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 3-15K, RPM's = 75, Pumps @ 82 SPM, 291 GPM's - 3800 PSI. Total Jar Hrs = 46.27 Total Bit Hrs = 8.69 ECD at 10.83 PPG. Mud WT = 8.85 PPG Viscosity = 80, YP = 18. Gels 15/24. Max Gas units = 65, BGG = 15 units. Survey @ 9957' MD, 3497.41' TVD = 87.6 Deg Inc, AZ - 357.82. Deg. Observed drilling through concretions @ 9492' - 9505' (13'), Printed: '12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 20 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 11/30/2005 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD3 12:00 - 00:00 ~ 12.001 DRILL DRLG ~ PROD3 112/1/2005 100:00 - 05:30 5.50 I DRILL I DRLG I PROD3 05:30 - 07:30 2.00 DRILL CIRC PROD3 07:30 - 09:15 1.75 DRILL WIPR PROD3 09:15 - 09:30 0.25 DRILL WIPR PROD3 09:30 - 10:30 1.00 DRILL WIPR PROD3 10:30 - 12:00 1.50 DRILL WIPR PROD3 12:00 - 18:15 6.25 DRILL WIPR PROD3 18:15 - 19:00 0.75 DRILL CIRC PROD3 19:00 - 20:30 1.50 DRILL WIPR PROD3 20:30 - 21:45 1.25 DRILL , WIPR PROD3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 9574'-9580' (6'), 9585'-9591' (6'), 9600'-9604' (4'), 9610'-9620' (10'), 9628'-9632' (4'), 9640'-9675' (35'), 9714'-9721' (7') = 85' total concretions. SPR's @ 10005' MD, 3504' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 640 PSI, 30 SPM - 910 PSI. Continue Directional drill 6 3/4" Hole in the "D" lateral from 10070' - 11047' MD (977'). TVD = 3541'. ADT = 7.02 HRS. AST = 5.92 HRS. ART = 1.10 HRS. PU WT = 122K, SO WT = 50K, ROT WT = 81 K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 3-10K, RPM's = 80, Pumps @ 81 SPM, 287 GPM's - 3975 PSI. Total Jar Hrs = 53.29 Total Bit Hrs = 15.71 ECD at 11.06 PPG. Mud WT = 8.90 PPG Viscosity = 80, YP = 17. Gels 15/22. Max Gas units = 94, BGG = 11 units. Survey @ 10974' MD, 3537.11' ND = 87.22 Deg Inc, AZ - 357.39 Deg. Observed drilling through no concretions this tour, SPR's @ 10929' MD, 3532' TVD. Pump #1 - 25 SPM - 820 PSI, 35 SPM - 1160 PSI. Pump #2 - 25 SPM - 810 PSI, 30 SPM - 1140 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep returned. Continue Directional drill 6 3/4" Hole in the "D" lateral from 11047' - 11524' MD (477'). TVD = 3561'. ADT = 3.35 HRS. AST = .29 HRS. ART = 3.06 HRS. PU WT = 132K, SO WT = 45K, ROT WT = 92K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 4-6K, RPM's = 85, Pumps @ 80 SPM, 284 GPM's - 4100 PSI. Total Jar Hrs = 56.64 Total Bit Hrs = 19.37 ECD at 11.23 PPG. Mud WT = 8.80 PPG Viscosity = 81, YP = 18. Gels 16!24. Max Gas units = 87. Survey @ 11524' MD, 3561.5' ND = 89.03 Deg Inc, AZ - 358.56 Deg. Observed drilling through concretions @ 11509' -11514' (5'). SPR's @ 10929' MD, 3532' TVD. Pump #1 - 20 SPM - 750 PSI, 30 SPM - 950 PSI. Pump #2 - 20 SPM - 740 PSI, 30 SPM - 940 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep returned. Pump a 35 BBL Hi Visc sweep @ 80 SPM - 284 GPM's - 4100 PSI. Observed 20% increase in cuttings on shakers. Monitor well -static. POOH on elevators from 11524' - 10102' (1422'). PU WT = 150K, SO WT = 60K. Flow check -static. Pump dry job, blow down Top Drive & Lines. Continue POOH from 10102' - 8980' (1122'). Pulled into cutings bed. RU & BROOH from 8980' - 8793' (187'), @ 281 GPM - 3500 PSI, 90 RPM's - 6K torque. Continue BROOH from 8793' - 8682' (101'), observing hole packing off. Work string to clean up hole and continue BROOH from 8682' - 4404' 4278') with no issues. Back ream @ 85 SPM - 302 GPM - 3825 PSI. 90 RPM's with 5K torque. Pull on elevators from 4404' - 4218' observing no issues through window area. Pump a 35 BBL Hi Visc weighted sweep + 3 Bottoms up @ 93 SPM - 330 GPM's - 3500 PSI. Observed 10% increase in cuttings on shakers. PU WT = 91 K, SO WT = 81 K. Orient and TIH through window with no issues, and continue TIH on elevators to tag up at 6150' DPM. Obtain survey and verify we had traveled into OLD hole. Survey indicated oriented at 35 degrees left of high side. POOH from 6150' - 5430' (720'). Orient to low side at 168 degrees right and RIH slowly to bit depth. of 5602' to obtain and compare surveys to Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 21 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Phase Code 12/1/2005 20:30 - 21:45 1.25 DRILL WIPR PROD3 21:45 - 00:00 2.25 DRILL WIPR PROD3 12/2/2005 00:00 - 03:00 3.00 DRILL WIPR PROD3 03:00 - 05:45 2.75 {DRILL {CIRC I PROD3 05:45 - 07:00 I 1.25 I DRILL {CIRC ~ PROD3 07:00 - 07:30 I 0.501 DRILL OBSV { PROD3 07:30 - 12:00 I 4.501 DRILL I TRIP I PROD3 15:00 - 17:00 I 2.001 DRILL I PULD I PROD3 17:00 - 17:30 0.50 DRILL PULD CMPLT3 17:30 - 19:45 2.25 DRILL PULD CMPLT3 19:45 - 20:30 0.75 WINDO ULD CMPLT3 20:30 - 22:15 I 1.751 WINDOINTRIP I CMPLT3 22:15 - 22:45 I 0.501 WINDOWOTHR I CMPLT3 22:45 - 23:15 I 0.501 WINDOWCIRC f CMPLT3 23:15 - 00:00 I 0.751 WINDOV~(T'RIP I CMPLT3 12/3/2005 100:00 - 02:30 I 2.501 WINDOWfRIP I CMPLT3 02:30 - 03:45 I 1.251 WINDOWPULD I CMPLT3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations verify traveling into new hole back to 6150'. Continue TIH on elevators from 6150' - 9890' (3740'). Wash & Ream from 9890' - 11524' (1634') @ 90 RPM's,6K torque, 270 GPM - 4100 PSI. Pump 35 BBL Hi Visc weighted sweep + 2 Bottoms up @ 275 GPM's - 4100 PSI. Observed 10% increase in cuttings at shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 275 GPM's - 4100 PSI. ECD = 11.64 PPG. Obtain SPR's. #2 pump - 20 SPM - 910 PSI, 30SPM - 1210 PSI. Monitor well -static. Drop 1 7/8" drift in drill pipe.. POOH on elevators from 11524' - 5710' (5814'). Observe no swabbing and hole taking correct hole fill. Continue POOH on elevators from 5710' - 369' (5341'). Observe no swabbing and hole taking correct hole fill. Stop @ top of window, monitor well -static. Breakout & lay down BHA #17. Lay down after plug in and download MWD assembly, 6 314" Reed Hycalog PDC CRXE1005H Bit (.80') TFA _ ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES (24.38'), PWD Collar (10.78'), TM HOC 10.90'), Rack back 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11/29/05) (28.88'), 4 - Jnts 4" HWDP (121.21').Total BHA length = 369.34'. Gauge Bit to 1 / 1 / CT / G / X ! I / NO i TD Clean 8 clear rig floor area. Send tools outside. Pick up 9 stands of Push Pipe from pipe shed. (2 -4 3/4" DC's and 1 - 4" DP). Pick up 1 more stand of 4" HWDP, for upcoming 4 1/2" liner run. Rack back all stands in derrick. PJSM with crew & BOT rep. Discuss safety and Procedure for picking up BHA. Make up Whipstock retrieving BHA as per BOT rep. MU Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 -stands of 4" HWDP (181.56'), and crossover (1.04'). Total BHA = 210.99' TIH with retrieving assembly, fill drill string every 25 stands. Obtain parametrs @ 4178'. PU WT = 125K, SO WT = 104K. Locate & hook window slot by working drill string and putting 1/8 turns in DP to hook. Pull up to 200K to fire jars, repeat 2 times, and pull to 250K to observe assembly free and moving up hole with 7K increase in upweight. Observe well swabbing. Circulate Bottoms up @ 248 GPM's - 1300 PSI. Observe 27 BBL loss of fluid as we CBU. Monitor well -static. POOH slow @ 10 ftlminute observe swabbing for 3 stands and then hole taking fluid. Slowly increase string speed as we wore out cup on the assembly. Observe hole taking proper fill after 3 full stands pulled. Continue POOH with whipstock retrievinig assembly from 3906' - 210' (3696'). Breakout & lay down Whipstock retrieving assembly. Layed down Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 -stands of 4" HWDP (181.56'), and crossover (1.04'). Total BHA = 210.99'. Continue POOH lay down whipstock and space out assembly. Layed down Seal Assembly with Stop Sub (1.92'), 4 5/8" Printed: 12/29!2005 9:54:06 AM • ConocoPhillips Alaska Page z2 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 12/3!2005 102:30 - 03:45 I 1.251 WINDOWPULD I CMPLT3 04:15 - 05:15 10.00 CMPLTONI RURD CMPLT3 05:15 - 09:30 I 4.25 I CMPLTNI RUNT ~ CMPL73 09:30 - 09:45 0.25 CMPLTN RUNT CMPLT3 09:45 - 10:15 0.50 CMPLTN RUNT CMPLT3 10:15 - 10:45 I 0.501 CMPLTNI RUNT I CMPLT3 10:45 - 12:00 I 1.251 CMPLTNI RUNT I CMPLT3 12:00 - 13:00 1.00 CMPLTN RUNT CMPLT3 13:00 - 14:15 1.25 CMPLTN RUNT CMPLT3 14:15 - 16:30 I 2.251 CMPLTNITRIP (CMPLT3 16:30 - 18:00 I 1.501 CMPLTNI OTHR I CMPLT3 18:00 - 18:15 I 0.251 CMPLTNI OTHR I CMPLT3 18:15 - 19:00 0.75 CMPLTN CIRC CMPLT3 19:00 - 21:00 2.00 CMPLTN TRIP CMPLT3 21:00 - 22:00 ( 1.00 ! CMPLTNI PULD I CMPLT3 22:00 - 23:15 1.25 RIGMNT RSRV CMPLT3 23:15 - 00:00 0.75 CMPLTN RURD CMPLT3 12/4/2005 100:00 - 00:45 ~ 0.75 CMPLTN; RUNT I CMPLT3 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5!2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations Unloader Sub (5.20'), 2 - 3 1/2 IF pups (11.85', 4.75'), 2- jnts 3 1!2 DP (31.33', 31.28'), Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup (1.69'), & 5/8" Whipstock slide (15.47'). Clear ~ Clean rig floor area, send tools outside.. Rig up casing equipment, power tongs, slips, elevators etc... Hold PJSM with crew and BOT rep. Discuss safety issues and procedure for picking up 4 1/2 slotted liner assembly. Pick up Baker 3 1/2" Guide shoe & bent joint with crossover. Continue RIH with 130 joints 4 1/2" L80 IBT 12.6# slotted /blank liner as per detail. PU Swell packers spaced out @ 9158' & 8637'. Install 150, 6 1/8" x 4 112" HydroForm Centralizers & stop rings on each joint except constrictor joints, all as per running detail. Constrictors space out to depths of , 10858', 10608', 10008', 9758', 8078', 7828', 7238', 6988', 6398', 6148', 5558', 5308', 4718', and 4418'. Total of 14 constrictors. Pull 2 7/8" tools and handling equipment to floor. Continue RIH with Liner assembly. Ran by window with bent joint to tag lower liner XO @ 4384' (Took 2 attempts to get thru window). Pull assembly back to above window top, orient to slack off and RIH to observe going into open hole. Continue RIH with 176 joints total liner from 4248' - 5522' (1274'). PU WT = 80K, SO WT = 64K. Crew Change. PJSM. (Note; 4 joints prior to side track @ 5460' turned pipe 1-1/2 turns to the right to turn bent joint to 180 deg.) Continue RIH with liner from 5522' - 7225' (1703'). 231 joints total ran. Make up 3 1/8" Slimhole MWD assembly with BOT shear sub assembly, on inner string of Hook Hanger. Orient MWD to high side of Hook. Make up Hook Hanger assembly, Perform shallow pulse test @ 117 GPM - 650 PSI. PU WT = 86K, SO WT = 63K. Trip in hole with drill string, and push pipe as calculated for weight, from 7268' - 11417' (4149'). Observe no issues getting liner down in open hole. PU WT = 175K, SO WT = 65K. Orient with MWD assembly to 11 degrees left of high side @ 124 GPM - 1100 PSI, slack off to hook window @ 4263' (3' deep). Pull up 40', and orient~to low side, slack off to pass bottom of window to 4276'. Pull up 40', re-orient to window @ 11 deg left, slack off to observe hooking window. Set down 30k to verify set. Repeat. Shoe depth @ 11502'. Final survey @ 2 Degrees left of high side. RU & drop a 29/32" ball, pumping down @ -124 GPM - 1100 PSI, slowing pumps until observed ball on seat. Pressure to 4200 PSI. Pull up 90' to 11412' & verify release. Bleed pressure. PU WT = 125K, SO WT = 50K Circulate bottoms up @ 124 GPM - 1100 PSI. Monitor well -static. POOH with BOT setting and releasing tool.. Observed correct hole fill @ 36 BBIs. Breakout, inspect and lay down running and setting tools. Breakout & lay down MWD assembly & shear sub assembly. All tools looked good. Slip & cut 220' of drilling line. Service top drive. Rig up casing equipment for 4 1/2" LEM run. PJSM, Discuss & verify running order of tools. PU Seal Assembly with bent joint & first joint of tubing. Crew Change. Continue RIH with LEM Assembly. Run 4 1/2" Baker Seal Assembly (3.26'), 4 1!2" Bent Joint STL x IBT (31.04'), 1-Jnt 4 1/2" IBT (31.02'), 4 Printed: 12!29!2005 9:54:06 AM • • ConocoPhillips Alaska Page 2.3 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code ~ Phase 12/4/2005 00:00 - 00:45 0.75 CMPLTN RUNT CMPLT3 00:45 - 03:30 2.75 CMPLTN TRIP CMPLT3 I 03:30 - 04:00 -0.50 CMPLTN -PCKR CMPLT3 04:00 - 04:30 0.50 CMPLTN PCKR CMPLT3 04:30 - 07:00 2.50 CMPLTN TRIP CMPLT3 07:00 - 07:45 0.75 CMPLTN TRIP CMPLT3 07:45 - 12:00 4.25 CMPLTN TRIP CMPLT3 12:00 -19:30 7.50 CMPLT TRIP CMPLT3 19:30 - 19:45 0.25 CMPLT RURD CMPLT3 19:45 - 20:15 0.50 CMPLTN RURD CMPLT3 20:15 - 00:00 3.75 CMPLTN RUNT CMPLT3 12/5/2005 00:00 - 00:30 0.50 CMPLTN RUNT CMPLTN 00:30 - 01:00 0.50 CMPLT SOHO CMPLTN 01:00 - 03:00 2.00 CMPLTN SEOT CMPLTN 03:00 - 04:30 1.50 CMPLTN NUND CMPLTN 04:30 - 09:00 4.50 CMPLTN, NUND , CMPLTN Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 1/2" IBT pup (7.85'), 1-Jnt 4 12/" IBT (31.0'), LEM below Hook Hanger (24.52'), LEM above Hook Hanger (10.61'), 4 1/2" IBT pup (3.83'), 4 1/2" Casing Swivel (2.74'), 4 1/2" IBT pup (2.02'), XO Bushing 5 1/2" Hydril x 4 1/2" IBT (1.41'), 190-47 Casing Seal Bore Receptacle 19.68'), 7 5!8" x 5 112" ZXP Liner top Packer (18.90'), Install shear sub assembly, and MU Baker Hydraulic & Setting tools, with crossover sub (17.26'), Make Up Torque = 3500 Ft /Lbs Trip in hole with LEM assembly from 205' - 4375' (4170'). Work seals past Hook Hanger & bottom of window, observing seals going into liner top and Latching up on Hook Hanger@ 4246' as planned. Pull 10K over to verify Latch up. UP WT = 124K, SO WT = 105k. Seals spaced out to land @ 4375.01, inside Seal bore 10.35'. Drop 1 3/4" Ball and chase with 350 stks @ 3 BPM - 600 PSI to - observe ball seated. Pressure up to 2500 PSI to allowZXP to set, continue pressure up to 4000 PSI to neutralize and release. Bleed pressure. Rig up and fill lines. Test down annulus 1000 PSI for 10 minutes, on chart to ensure packer integrity. Bleed pressure. Monitor well - static.Pull up and & retag top of ZXP to verify depth @ 4187' as planned. POOH from 4187' - 40' (4147'). Breakout & lay down ~ inspect Running & Setting tool assembly. All tools looked good. Clear & clean rig floor area, send tools outside. Rig up to lay down drill string. PJSM with crew. Discuss safety issues and plan for laying down drill string. Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. Crew Change. Continue Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. 90 Total. Rig up. BOLDS and pull wear bushing. Clean ~ clear rig floor area. Rig up equipment to run 4 1/2" completion string. Verify all tools in order in pipe shed. PJSM with crew. Discuss Safety issues, and procedure to run 4 1/2" completion string. MU Baker 4 3/4" SBE Seal assembly and continue RIH with 4 112" L80 12.6# IBT Tubing to 3960'. Install Baker 4 1/2" CMU Sliding Sleeve (OPEN) spaced out to 4137.87', 2 -Camco GLM's with Dummy BK-5 Latch space out to 3902.53, 2336.46',. and a Camco DB-6 Nipple with 3 .875" NO-GO profile spaced out at 475.13'. Make up Torque = 3500 Ft /Lbs NOTE: SIMOPS -Change out mud pump liners from 5 1/2" to 6", & cleaning pits. Continue Run 4 112" Completion string to 4225.71'. Make up torque = 3500 Ft/ Lbs. Tag XO @ 4225.83' with mule shoe and Pull up to install space out pups, to locate mule shoe @ 4221.83' as planned. PU WT = 74K, SO WT = 70K. Make up Vetco Gray 11" x 4 1/2" tubing hanger with 2 -way check installed. Mu Landing joint, RIH to locate and land hanger. RKB = 22.53'. Run in all lock down screws. Test upper and lower Hanger seals to 5000 PSI. 10 minutes each test. PJSM with crew. Discuss safety and cold weather issues. Discuss procedure for ND / NU. Nipple down BOP stack and all lines. ~ Nipple up Vetco Gray Tree and actuator valve. Test Void to 5000 PSI - Printed: 12/29/2005 9:54:06 AM • • ConocoPhillips Alaska Page 2a of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hcurs Code Sub Phase Description of Operations Code 12/512005 04:30 - 09:00 4.50 CMPLTN NUND CMPLTN 10 minutes. Test tree to 250 PSI low, 5000 PSI high - 10 minutes. Pull 2 -way check. Note: SIMOPS - RU scaffolding in cellar & RU Little Red for freeze protection services. 09:00 - 10:00 1.00 CMPLT FRZP CMPLTN PJSM with crew and Little Red reps. Discuss safety issues and spill prevention. Displace well with 190 BBLS of freeze protect diesel @ 5 BPM - 800 PSI. 10:00 - 12:00 2.00 CMPLT OTHR CMPLTN Rig Up Lubricator & set BPV. Repeat with no success. RU & put Steam on tree. NOTE : SIMOPS -Suck out cellar box with Super Sucker truck. 12:00 - 14:00 2.00 CMPLT OTHR CMPLTN Continue attempt to set BPV. Set BPV. Rig down lubricator Simops -Rig Down pipe shed skate, remove & clean all pits. Shut down all Glycol heaters. Blow down all steam ,glycol, and H2O lines. Rig Released @ 1400 HRS Printed: 12/29!2005 9:54:06 AM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1J-164L1 Job No. AK ZZ-0004025932, Surveyed: 17 November, 2005 Survey Report 28 December, 2005 Your Ref: API 500292327860 Surface Coordinates: 5945730.87 N, 558693.02E (70° 15' 44.4085" N, 149° 31' 31.8702" VI/) • Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945730.87 N, 58693.02E (Grid) Surface Coordinates relative to Structure: 188.01 S, 98.41 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelty Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~t ~ ~ Survey Ref: svy2230 A i~faHkburton Compa~~fy Ha/liburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-164L1 Your Ref.• API 500292327860 Job No. AK ZZ-0004025932, Surveyed: 17 November, 2005 Western North Slape Measured Depth (ft) 4515.90 4593.00 4726.41 4817.83 4862.43 4912.28 5005.88 5069.09 5101.66 5194.05 Incl 81.090 80.120 90.830 88.810 89.170 89.650 90.280 88.980 87.430 87.440 True Azim. 358.690 0.160 358.060 359.310 358.890 357.980 359.550 359.470 359.870 359.980 Sub-Sea Depth (ft) 3389.72 3402.31 3412.82 3413.11 3413.89 3414.41 3414.47 3414.87 3415.89 3420.03 Vertical Depth (ft) 3498.72 3511.31 3521.82 3522.11 3522.89 3523.41 3523.47 3523.87 3524.89 3529.03 Local Coordinates Northings Eastings (ft) (ft) 2053.52 N 566.53 W 2129.58 N 567.29 W 2262.36 N 569.38 W 2353.75 N 571.47 W 2398.33 N 572.17 W 2448.16 N 573.54 W 2541.74 N 575.55 W 2604.94 N 576.09 W 2637.49 N 576.28 W 2729.79 N 576.40 W Global Coordinates Northings Eastings (ft) (ft) 5947779.91 N 558110.50 E 5947855.96 N 558109.14 E 5947988.72 N 558106.03 E 5948080.09 N 558103.22 E 5948124.67 N 558102.17 E 5948174.49 N 558100.42 E 5948268.04 N 558097.67 E 5948331.24 N 558096.64 E 5948363.79 N 558096.20 E 5948456.09 N 558095.36 E Dogleg Vertical Rate Section (°/100ft) 2053.52 2.263 2129.58 8.179 2262.36 2.598 2353.75 1.240 2398.33 2.064 1.807 2.061 4.915 0.119 2448.16 2541.74 2604.94 2637.49 2729.79 5286.98 88.860 0.820 3423.03 3532.03 2822.67 N 575.75 W 5948548.96 N 558095.28E 1.775 2822.67 5380.02 91.400 0.290 3422.82 3531.82 2915.69 N 574.85 W 5948642.00 N 558095.46E 2.789 2915.69 5473.25 92.190 0.850 3419.90 3528.90 3008.87 N 573.92 W 5948735.18 N 558095.66E 1.038 3008.87 5566.60 89.920 0.850 3418.18 3527.18 3102.19 N 572.54 W 5948828.50 N 558096.32E 2.432 3102.19 5658.89 91.150 1.090 3417.32 3526.32 3194.46 N 570.98 W 5948920.78 N 558097.16E 1.358 3194.46 5750.52 89.520 0.880 3416.78 3525.78 3286.07 N 569.40 W 5949012.41 N 558098.02E 1.794 3286.07 5846.24 89.670 1.080 3417.46 3526.46 3381.78 N 567.77 W 5949108.12 N 558098.91E 0.261 3381.78 5939.37 88.780 1.240 3418.72 3527.72 3474.88 N 565.88 W 5949201.23 N 558100.07E 0.971 3474.88 6031.06 89.600 0.230 3420.01 3529.01 3566.55 N 564.70 W 5949292.91 N 558100.53E 1.419 3566.55 6126.75 90.280 2.810 3420.11 3529.11 3662.20 N 562.17 W 5949388.57 N .558102.32E 2.788 3662.20 6219.41 89.550 1.270 3420.25 3529.25 3754.80 N 558.87 W 5949481.19 N 558104.90E 1.839 3754.80 6313.20 90.210 358.290 3420.45 3529.45 3848.57 N 559.23 W 5949574.97 N 558103.81E 3.254 3848.57 6406.08 92.320 358.910 3418.40 3527.40 3941.40 N 561.50 W 5949667.77 N 558100.82E 2.368 3941.40 6499.28 89.730 358.580 3416.73 3525.73 4034.55 N 563.54 W 5949760.91 N 558098.05E 2.801 4034.55 6593.25 87.430 357.840 3419.06 3528.06 4128.44 N 566.47 W 5949854.77 N 558094.39E 2.571 4128.44 6686.92 91.030 359.870 3420.32 3529.32 4222.06 N 568.34 W 5949948.37 N 558091.79E 4.412 4222.06 6780.00 90.960 358.090 3418.70 3527.70 4315.11 N 570.00 W 5950041.41 N 558089.40E 1.914 4315.11 6873.42 88.860 358.470 3418.85 3527.85 4408.48 N 572.80 W 5950134.75 N 558085.87E 2.284 4408.48 6966.71 88.850 358.900 3420.71 3529.71 4501.73 N 574.94 W 5950227.98 N 55$083.00 E 0.461 4501.73 7059.79 89.520 359.460 3422.04 3531.04 4594.79 N 576.28 W 5950321.03 N 558080.95E 0.938 4594.79 7153.42 89.830 359.230 3422.57 3531.57 4688.41 N 577.35 W 5950414.64 N 558079.15E 0.412 4688.41 7246.74 90.410 0.150 3422.37 3531.37 4781.73 N 577.85 W 5950507.95 N 558077.91E 1.165 4781.73 7340.34 89.410 0.900 3422.52 3531.52 4875.32 N 576.99 W 5950601.55 N 558078.04E 1.335 4875.32 7433.47 88.190 1.110 3424.47 3533.47 4968.42 N 575.36 W 5950694.65 N 558078.95E 1.329 4968.42 7526.92 87.860 1.910 3427.69 3536.69 5061.78 N 572.90 W 5950788.03 N 558080.68E 0.926 5061.78 ConocoPhillips Comment Tie-On Point Window Point 28 December, 2005 - 15:36 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-164L1 Your Ref.• API 500292327860 Job No. AK 2.Z-0004025932, Surveyed: 17 November, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 7619.71 87.940 0.380 3431.09 3540.09 5154.48 N 571.05 W 5950880.75 N 558081.81E 1.650 7712.43 89.840 359.740 3432.89 3541.89 5247.18 N 570.95 W 5950973.44 N 558081.19E 2.162 7805.51 88.620 0.550 3434.14 3543.14 5340.25 N 570.71 W 5951066.51 N 558080.70E 1.573 7898.20 88.290 358.660 3436.64 3545.64 5432.90 N 571.35 W 5951159.15 N 558079.34E 2.069 7991.61 88.930 359.650 3438.90 3547.90 5526.27 N 572.73 W 5951252.51 N 558077.23E 1.262 8085.59 88.070 359.820 3441.36 3550.36 5620.22 N 573.16 W 5951346.45 N 558076.07E 0.933 8178.78 89.600 0.390 3443.26 3552.26 5713.38 N 572.99 W 5951439.61 N 558075.51E 1.752 8272.55 87.370 359.610 3445.74 3554.74 5807.11 N 572.99 W 5951533.34 N 558074.78E 2.519 8366.65 88.560 0.730 3449.08 3558.08 5901.15 N 572.71 W 5951627.38 N 558074.33E 1.736 8460.75 87.080 0.680 3452.66 3561.66 5995.17 N 571.56 W 5951721.41 N 558074.75E 1.574 ConocoPhillips Vertical Section Comment 5154.48 5247.18 5340.25 5432.90 5526.27 5620.22 5713.38 5807.11 5901.15 5995.17 8554.01 87.440 359.480 3457.11 3566.11 6088.33 N 571.43 W 5951814.56 N 558074.15E 1.342 6088.33 8645.72 87.680 357.740 3461.02 3570.02 6179.92 N 573.65 W 5951906.13 N 558071.22E 1.914 6179.92 8740.58 88.250 358.490 3464.39 3573.39 6274.67 N 576.77 W 5952000.85 N 558067.36E 0.993 6274.67 8835.04 86.450 358.240 3468.76 3577.76 6368.99 N 579.46 W 5952095.15 N 558063.93E 1.924 6368.99 8927.51 86.490 359.000 3474.45 3583.45 6461.25 N 581.68 W 5952187.39 N 558060.99E 0.821 6461.25 9022.09 90.590 1.280 3476.86 3585.86 6555.78 N 581.45 W 5952281.91 N 558060.49E 4.960 6555.78 9115.02 93.550 1.730 3473.50 3582.50 6648.60 N 579.01 W 5952374.76 N 558062.20E 3.222 6648.60 9208.96 93.990 0.980 3467.33 3576.33 6742.31 N 576.79 W 5952468.48 N 558063.69E 0.924 6742.31 9302.35 94.670 0.310 3460.27 3569.27 6835.43 N 575.75 W 5952561.60 N 558064.01E 1.021 6835.43 9395.80 95.290 358.980 3452.16 3561.16 6928.52 N 576.32 W 5952654.69 N 558062.71E 1.565 6928.52 9489.14 94.490 0.700 3444.20 3553.20 7021.52 N 576.58 W 5952747.68 N 558061.73E 2.026 7021.52 9582.28 93.740 358.570 3437.52 3546.52 7114.41 N 577.17 W 5952840.56 N 558060.41E 2.419 7114.41 9675.48 93.800 359.040 3431.39 3540.39 7207.39 N 579.11 W 5952933.52 N 558057.75E 0.507 7207.39 9769.95 91.140 358.450 3427.32 3536.32 7301.74 N 581.18 W 5953027.86 N 558054.94E 2.884 7301.74 9862.17 88.230 359.540 3427.83 3536.83 7393.93 N 582.80 W 5953120.03 N 558052.61E 3.370 7393.93 9955.47 85.220 1.500 3433.16 3542.16 7487.06 N 581.95 W 5953213.17 N 558052.72E 3.848 7487.06 10047.52 86.140 359.440 3440.09 3549.09 7578.84 N 581.20 W 5953304.95 N 558052.76E 2.445 7578.84 10141.07 86.620 358.380 3446.00 3555.00 7672.18 N 582.98 W 5953398.28 N 558050.26E 1.242 7672.18 10235.44 87.240 358.910 3451.05 3560.05 7766.39 N 585.21 W 5953492.46 N 558047.29E 0.864 7766.39 10330.56 88.060 0.050 3454.95 3563.95 7861.42 N 586.07 W 5953587.49 N 558045.69E 1.475 7861.42 10422.45 87.800 0.910 3458.27 3567.27 7953.25 N 585.30 W 5953679.32 N 558045.74E 0.977 7953.25 10514.89 85.470 1.430 3463.70 3572.70 8045.50 N 583.42 W 5953771.58 N 558046.91E 2.582 8045.50 10607.07 85.400 359.630 3471.04 3580.04 8137.38 N 582.57 W 5953863.47 N 558047.04E 1.948 8137.38 10698.55 88.360 0.420 3476.01 3585.01 8228.72 N 582.53 W 5953954.80 N 558046.37E 3.349 8228.72 10789.65 87.560 0.670 3479.26 3588.26 8319.76 N 581.66 W 5954045.84 N 558046.53E 0.920 8319.76 • 28 December, 2005 - 15:36 Page 3 of 5 DrillQuesf 3.03.06.008 Ha/liburton Sperry-Sun Survey Report forKuparuk 1J Pad -1J-184L1 Your Ref: API 500292327860 Job No. AK-ZZ-0004025932, Surveyed: 17 November, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10880.44 87.880 1.430 3482.87 3591.87 8410.46 N 580.00 W 5954136.55 N 558047.48 E 10971.02 88.360 1.470 3485.84 3594.84 8500.96 N 577.71 W 5954227.07 N 558049.07 E 11062.32 88.490 2.230 3488.35 3597.35 8592.18 N 574.76 W 5954318.31 N 558051.30 E 11152.78 87.500 0.990 3491.52 3600.52 8682.54 N 572.22 W 5954408.69 N 558053.14 E 11241.94 87.310 1.210 3495.55 3604.55 8771.60 N 570.51 W 5954497.75 N 558054.16 E 11333.87 88.000 1.590 3499.31 3608.31 8863.42 N 568.27 W 5954589.59 N 558055.68 E 11424.33 88.370 2.860 3502.18 3611.18 8953.76 N 564.76 W 5954679.96 N 558058.49 E • 11472.00 88.370 2.860 3503.53 3612.53 9001.36 N 562.38 W 5954727.57 N - 558060.50E 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). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11472.OOft., The Bottom Hole Displacement is 9018.91ft., in the Direction of 356.425° (True). Comments Measured Station Coordinates Depth ND Northings Eastings (ft) (ft) (ft) (ft) 4515.90 3498.72 2053.52 N 566.53 W 4593.00 3511.31 2129.58 N 567.29 W 11472.00 3612.53 9001.36 N 562.38 W Comment Tie-On Point Window Point Projected Survey ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 0.908 8410.46 0.532 8500.96 0.844 8592.18 1.753 8682.54 0.326 8771.60 0.857 8863.42 . 1.462 8953.76 0.000 9001.36 Projected Survey • 28 December, 2005 - 15:36 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-184L1 Your Ref: API 500292327860 Job No. AK-ZZ-0004025932, Surveyed: 17 November, 2005 Western North Slope Survey tool program for 1J-164L1 From To Measured Vertical Measured Depth Depth Depth 0.00 0.00 533.00 533.00 532.98 11472.00 Survey Tool Description Vertical Depth (ft) 532.98 CB-SS-Gyro (1J-164) 3612.53 MWD+IIFR+MS+SAG (1J-164) ConocoPhillips • • 28 December, 2005 - 15:36 Page 5 of 5 DrillQuesf 3.03.06.008 • • 10-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-164 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,515.90' MD Window /Kickoff Survey: 4,593.00' MD (if applicable) Projected Survey: 11,472.00' MD aos-i¢S PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 I~~~ ~OCfl Signed Please call me at 273-3545 if you have any que ions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) '~ j ;. ;~ ~ ~° ~ J r ALA$SA OIL A1~TD (irAS COI~TSLR`PA7`I011t COl-II-IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 C7 d~ ~~, FRANK H. MURKOWSKI, GOVERNOR s r" 1 333 W. 7"' AVENUE, SUITE 100 ,>' ANCHORAGE, ALASKA 995013539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU West Sak 1J-164L1 ConocoPhillips Alaska, Inc. Permit No: 205-145 Surface Location: 1919' FSL, 2517' FEL, Sec. 35, Tl 1N, RlOE, UM 8ottomhole Location: 541' FSL, 2212' FWL, Sec. 23, Tl 1N, R10E, 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 1J-164, Permit No. 205--144, API -No,-50-02-9-22327_8=-00. -.Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or 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. 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} 659-360? (pager). BY ORDER THE COMMISSION DATED this day of October, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~~ STATE OF ALASKA ~,~~t_ ALASKA OIL AND GAS CONSERVATION COMMISSION N PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ~ Redrill 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service Q Development Gas ^ Single Zone Q 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-164L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11665' ~ TVD: 3619' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1919' FSL, 2517'~FEL, Sec. 35, T11 N, R10E, UM ADL 25661, 25650 ~ West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1254' FNL, 2204' FWL, Section 35, T11N, R10E ALK 471, 468 11/5/2005 Total Depth: 9. Acres in Property: 541' FSL, 2212' FWL, Sec. 23, T11N, R10E, UM 2560 Near ~ 1 ' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15(t)iC nc e to Neare r Surface: x- 558693. y- 5945730 ~ Zone- 4 AA'' ~'1/ (Height above GL): 28' RKB ~ gg Weu wittfin ~r~../. ~S ~~ ~ ~ 16. Deviated wel{s: Kickoff depth: 4583 i ft. 17. Maximum Anticipated Pressures in psi C 25.035) ~, , ~ ~~~ Maximum Hole Angle: 94° deg Downhole: 1629 psig ' a ig ~ 18. Casing Program S if ti Setting Depth uan ent Size ica pec ons Top Bottom , f. or sac Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2318' 28' 28' 2318' 2197' 480 sx ASLite, 140 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 5419' 28' 28' 5419' 3600' 380 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 7082' 4583' 3518' 11665' ~ 3619" slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Pertoration Depth MD (ft): Pertoration Depth TVD (ft): {~~t trot Q 20. Attachments: Filing Fee BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature Phone ~;5 ~~3 ~ Date ~( f2~ (~,j \ ~ ~-- r h n( r k Commission Use Only Permit to Drill API Number Permit Approval See cover letter Number: ~,,`~ r ~ ~~ s.} 50- a Z` ' ~ ~Z~~ '°' ~ (~ Date: for other requirements Conditions of approval m es required Yes ^ No ~ Mud log required Yes ^ No ^ gen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No / Other: ~S~' 0.S ~ `~~~ , ~ ~ i MGk c1 ~.~"T`i ~nS \ re CACC®~ w/ ~l0 ~-~ APPROVED BY ~~ Approve y: THE COMMISSION Date: Form 10-401 Revised 06/2004 Submit in Duplicate a Permit It -West Sak Well #1J-164 L1 Application for Permit to Drill Document .cation for Permit to Drill, Well 1 J-164 L1 Revision No.O Saved: 22-Sep-05 Well vQlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.OD5(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 t y ~.~a~~~a}di 1J-164L1 PERM/T/T.doc Page 1 of 6 Printed: 22-Sep-05 • cation for Permit to Drill, Weil 1J-164 L1 Revision No.o Saved: 22-Sep-05 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a we/l with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a sul~x to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1]-164 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on frle with the commission and identified in the app/ication: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B} the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surtace 1 919' FSL 2 517' FEL Section 35, T11N R10E ~ ASPZone 4 NAD27Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,730 Eastings: 558,693 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 1,254' FNL, 2,204' FWL, Section 35, T11N, R10E ~' West Sak ~~B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 4 583 Northings: 5,947,832 Eastings: 558,115 Total 1/ertical De th RKB.• 3 518 Total 1/ertical De th SS.• 3 409 Location at Total De th 541' FSL, 2 212' FWL Section 23 T11N R10E ASP zone 4 NAD 27 Coordinates Measured De th RKB,' 11 665 Northings: 5,954,906 Eastings: 558,061 Total I/ertical De th RKB: 3 619 Total 1/ertica! De th SS: 3 510 and (D) other information required by 20 AAC 25.050(b); 1J-164L1 PERMIT/T.doc Page 2 of 6 Printed: 22-Sep-OS -. r cation for Permit to Drill, Well 1 J-164 L1 Revision No.O Saved:22-Sep-05 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the app/ication for a Permit to Dii// (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed we/!bore, including a/l adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2} for all wells within 200 feet of the proposed we//bore (A) list the names of the operators of those wel/s, to the extent that those names are known or discoverab/e in pub/ic records, and show that each named operator has been furnished a copy of the application by certified mai/; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Orill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-164 L1. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (4} information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected. reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "B" sand formation is 1,230 psi, calculated thusly: MPSP =(3,619 ft TVD)(0.45 - 0.11 psi/ft) =1,230 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circu/ation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-164 Li Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(t}; The parent wellbore, 1J-164, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-164L1 PERMIT IT.doc Page 3 of 6 Printed: 22-Sep-05 1 , • r cation for Permit to Drill, Well 1J-164 L1 Revision No.O Saved: 22-Sep-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready an fi/e with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slotted liner, pre- perforated liner, or screen to be instaUed,• Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weigh Length MDlTVD MDlrVD OD (in) in) t (Ib/ft Grade Connection ft) (ft ft) Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 7,005 4,673 / 3,530 11,67$ / 3,768 Slotted- no cement Slotted Lateral (1J-164) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,082 4,583/ 3,518 11,665 / 3,619 Slotted- no cement Slotted Lateral (1J-164 L1) 4_1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,408 4,250/ 3,446 11,658 / 3,570 Slotted- no cement Slotted Lateral (1]-164 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application far a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.03s(h)(2); No diverter system will be utilized during operations on iJ-164 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Dri!/must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified /n the app/ication: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit (p) 8.6 Plastic Viscostiy 15 - 25 (Ib/900 s1) Yield Point ~ 8.28 cP) HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 ! 30 Ratio Electrical 650-900 Stabilit 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. ~~~ ~~ ~~~ 7J-164L1 PERMIT /T.doC Page 4 of 6 Printed: 22-Sep-05 • cation for Permit to Drill, Well 1J-164 L1 Revision No.O Saved: 22-Sep-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri//must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (9) far an exploratory or stratigraphic test we/% a tabu/atioh setting out the depths ofpredicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fallowing items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on frfe with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Dri/F must be accompanied by each of the fo/towing items, except for an item already an file with the commission and identified in the application: (12) evidence showing that the requirements of ZO AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Plote: Previous operations are covered under the i]-164 Application for Permit to Drill. y 1. Run and set Baker WindowMaster whipstock system, at window point of 4,583' MD / 3,518' TVD, the top of the B sand. ' 2. Mill 6-3/4" window. POOH. f ~ 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at 11,665' MD / 3,619' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. i~~~~~~ 7J-164L1 PERMtT IT.doc Page 5 of 6 Printed: 22-Sep-05 C] cation for Permit to Drill, Well 1J-164 L1 Revision No.O Saved: 22-Sep-05 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the ~~D" sand lateral 1J-164 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dril/ mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of dril/ing mud and cuttings and a statement of whether the operator intends to request authorization under 10 AAC 25.080 for an annular disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed. of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-164L1 PERMIT /T.doc Page 6 of 6 Printed: 22-Sep-05 • ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 1J-164 L1 Plan: 1J-164 L1 (wp06) Proposal Report 13 September, 2005 HALLi F3U RTC~N Sperry Drilling Services ORIGINAL -1500 1 1 `~ ConocoPhillips Alaska TOW ~ 4584ft MD, 3518ft ND : 1254ft FNL & 2204ft FWL -Sec 35-T11N-R10E Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Pian 1J-164 (L6) Wellbore: 1J-164 L7 Plan: 1J-164 L1 (wp06) For:wwnoN ToP DeTats N3alDPath MDPath Fomtation 1 1643.00 1693.06 Base otPermafrost 2 1e4a.oo no3.s7 Ts J 1935.00 2026.77 K16 4 2203.00 2324.66 T3 • 660 (CBG PTI 6 2922.00 3162.82 Uynu C 6 3110.00 3434.03 Ugnu B 7 3149.00 3487.27 Uynu A 8 3283.00 3747.38 K-13 9 3448.00 4250.33 Weest Sak D (77°) 1034%.00 444b.93 West Ssk C 11 3b20.71 46%.63 Wkst Sak B (80°) LEGEND -~- Plan 1J-164 (L6), 1J-164, 1J-164 (wp06) 1J-164 Lt (wp06) BOW 4596ft MD, 3520ft ND -Drill Out 6 3/4 Hole End 30' Rathole - Build ~ 5°/t00R, 4626ft MD, 3525fl ND Sail (8191.56° Inc : 4819ft MD, 3535ft ND I Continue Build (B 5°/100ft , 5180ft MD, 3525fl ND Base Pe ---T3-- - K1b T3;660 (CSG - - ~ 10 3/4" Ugnu C 3000 Ugnu 6 Ugnu A - - - - - -_- --= K-13 ----- -- - - - - - - - - - - - _ Wast Sak D (77° - 3500 -___ __ ___-___ West Ssk C West Sek B (BO° 4000 1J-164 L1 T1 (wp06) 1J-164 L1 T2 (wp06) CASING DETAILS No ND MD Name Size 1 2203.00 2324.56 10 314" 10-314 2 3518.42 4583.68 7 5/8" 7-5/8 3 3619.0011665.22 41/2" 4-112 Begin GeoSteer in B-Sand 5259ft MD, 3525fl ND Sail (HJ 90.11 ° Inc : 5209ft MD, 3525fl ND TD @ 11665ft MD, 3619ft TVD : 541ft FSL & 2212ft FWL -Sec 23T11-R10E Cross fault - Build (~ 3°/100ft to Reacquire Sand , 8985ft MD, 356211 ND Possible Fault Crossing - 89608 MD, 3563ft ND i 1J-164 L1 T3 (wp06) 1J-164 L1 T4 (wp06) -500 0 500 1000 1500 2000 2500 3000 i i i ~ i i ~ i i i ~ i i i ' ~ ~ 1J-164 Lt T13 (wp06) ' ~ ~ ~ , , ~, ~ i i ~ ~ ~ ~ , ; ~ 1J-164 Lt Tce (wp06) ,' ' ~ ~ ~ , i r ~ i ' ~ i ~ ~ i ~ ' ~ ~ iJ-164 L1 T6 (wp06) 1J-164 L1 T8 (wp06) ~, 1J-164 L1 T10 (wp06) ~~ 1J-164 L1 T12 (wp06) 1J-164 L1 T5 (wp06) 1J-164 L1 T7 (wp06) 1J-164 L1 T9 (wp06) 1J-164 L1 T11 (wp0~ 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section at 0.00° (1000 ft/in) ConocoPhillips Alaska 1J-164 Lt Toe (wp08 1J-184 L1 T13 (wp08 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164 (L6) Wellbore: 1J-164 L1 Plan: 1J-164 L1 (wp06) M Azimuths to True North agnetic North: 24.54° Magnetic Field Strength: 57578.6nT Dip Angle: 80.72° Date: 11/24/2004 Model: BGGM2004 ____` IO° 1J-184 L1 T12 (wp08 u- 360° 1J-164 L1 T11 (wp06 _ 0' 1J-184 L1 T10 (wp06 _ _ _ _ _ _ - _ _ 360° ----- ---- -- - 360° 0° 1J•164 L1 T8 (wp08 _ _ _ _ _ _ _ 0° 1J-184 L1 T81N'P08 - - - - - - - - - - - - - - 0° 1J-184 L1 T7(wp08 ------- -------- ---' 1J-184 L1 TB(wp06 ~----_----- _ _ -_-- 1J-164 L1 T5 (wp08 0° c p 1J-184 L1 T4 (wp06~ ~ - N_ 360° + 1J-164 L1 T3 (wp06 - - - - - = 3so° r 0 Z 1J-164 L7 T2 (wp06 _ _. - t 0° O 1J-164 L1 T1 (wp06 10° 360° 360° 0° 0° 360° CASING DETAILS -625 No ND MD Name Size 1 2203.00 2324.56 10 3/4" 10-3/4 2 3518.42 4583.68 7 5l8" TOW 7-5/8 3 3619.0011665.22 41/2" 4-1/2 -1250 TD ~ 11665ft MD, 3619ft ND : 541ft FSL & 2212ft FWL -Sec 23-T11-R10E Cross fault - Build ~ 3°/100ft to Reacquire Sand , 8985ft MD, 3562ft ND Possible Fault Crossing - 8960ft MD, 3563tt ND Sail ~ 90.11 ° Inc : 5209ft MD, 3525ft ND Begin GeoSteer in B-Sand 5259ft MD, 3525ft ND - - ~ Continue Build ~ 5°/t00ft , 51808 MD, 3525ft ND Sail (~ 91.58° Inc : 4819ft MD, 3535ft ND ------- - _ _ _ End 30' Rathole - Builtl ~ 5°/100tt, 4626ft MD, 3525ft ND BOW 4596ft MD, 352011 ND -Drill Out 63/4 Hole TOW @ 4584ft MD, 3518ft ND : 1254ft FNL 8 2204ft FWL -Sec 35-T1 t N-R t0E s~` -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 • --' ~011CK0~'ll~~#p5 Halliburton Company Pl i r hi R t G MALLIBURTON - - - --. _, ann ng epor - eog ap c Alaska Sp~vry OritlMg SsrviEass Database: EDM 2003.11 Single User Db LocatCo-ordinate Reference: Well Pfan 1J-164 (L6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1 J-164 (28'+81') @ 109.OOft (D141 (2$GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') (a3 109.OOft (D141 (28GL + 81'RF)) Site: Kuparuk 1 J Pad North. Reference: True Well: Plan 1J-164 (L6) Surv®y Calculation Method: Minimum Curvature Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06) project Kuparuk River Unit, North Slope Alaska, United States ` Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor ~I Well Plan 1J-164 (L6) Well Position +N/-S 0.00 ft Northing: 5,945,730.87 ft ~ Latitude: 70° 15' 44.408" N +E/-W 0.00 ft Easting: 558,693.02 ft ~ Longitude: 149° 31' 31.870" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ---- Wellbore 1J-164 L1 Magnetics Model Name Sample Date Di3Clination Dip Angle Field Strength I I BGGM2004 11/24/2004 24.54 80.72 57,579 rDesign ---- 1J-164 L1 (wp06) ----- Audit Notes: Version: Phase: PLAN Tie On Depth: 4,583.67 Vertical Section: Depth From (TVD) +N/.S +E/-W Direction (ft) (~3 (ft) (°) I 28.00 0.00 0.00 0.00 9/13J2005 1:5238PM Page 2 of 8 COMPASS 2003.11 Build 48 ~~~~ GonocoPhi~li}~s Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164{L6) Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06) Halliburton Company HALL18UfilTON Planning Report -Geographic ~- ~ ~ ~- - -- ~ ~ ~ --~ -~ Spsirry DAIliillg Swnricss Local Co-ordinate Reference: Well Plan 1J-164 (L6) ND Reference: 1 J-164 (28'+81') ~ 109OOft (D141 (28GL + 81'RF)) MD Reference: 1 J-.164 (28'+81') ~ 109:OOft (D141 (28GL + 81'RF)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 4,583.67 80.00 0.07 3,518.42 2,106.07 -560.84 0.00 0.00 0.00 0.00 4,595.67 81.91 0.07 3,520.31 2,117.92 -560.83 15.90 15.90 0.00 0.00 4,625.67 81.91 0.07 3,524.53 2,147.62 -560.80 0.00 0.00 0.00 0.00 4,819.20 91.58 359.91 3,535.50 2,340.60 -560.83 5.00 5.00 -0.08 -0.91 5,180.09 91.58 359.91 3,525.53 2,701.36 -561.38 0.00 0.00 0.00 0.00 5,209.59 90.11 359.99 3,525.10 2,730.86 -561.41 5.00 -4.99 0.26 177.00 5,259.59 90.11 359.99 3,525.00 2,780.86 -561.42 0.00 0.00 0.00 0.00 5,263.76 90.17 0.05 3,524.99 2,785.02 -561.42 2.00 1.49 1.34 41.92 6,259.72 90.17 0.05 3,522.00 3,780.98 -560.62 0.00 0.00 0.00 0.00 6,297.80 89.41 359.99 3,522.14 3,819.06 -560.61 2.00 -1.99 -0.15 -175.59 7,259.90 89.41 359.99 3,532.00 4,781.11 -560.83 0.00 0.00 0.00 0.00 7,264.55 89.31 0.05 3,532.05 4,785.75 -560.83 2.50 -2.16 1.26 149.74 8,260.09 89.31 0.05 3,544.00 5,781.23 -560.03 0.00 0.00 0.00 0.00 8,379.46 86.93 0.01 3,547.92 5,900.53 -559.97 2.00 -2.00 -0.03 -179.19 8,660.62 86.93 0.01 3,563.00 6,181.28 -559.91 0.00 0.00 0.00 0.00 8,833.56 91.24 359.82 3,565.76 6,354.15 -560.17 2.50 2.50 -0.11 -2.57 8,960.76 91.24 359.82 3,563.00 6,481.32 -560.58 0.00 0.00 0.00 0.00 8,985.76 91.24 359.82 3,562.46 6,506.31 -560.65 0.00 0.00 0.00 0.00 9,089.08 94.32 0.16 3,557.44 6,609.50 -560.67 3.00 2.98 0.33 6.38 9,532.30 94.32 0.16 3,524.02 7,051.46 -559.41 0.00 0.00 0.00 0.00 9,762.53 87.42 359.87 3,520.51 7,281.53 -559.34 3.00 -3.00 -0.13 -177.59 9,862.53 87.42 359.87 3,525.00 7,381.42 -559.56 0.00 0.00 0.00 0.00 10,062.76 87.42 359.87 3,534.00 7,581.45 -560.00 0.00 0.00 0.00 0.00 10,097.78 86.80 0.19 3,535.77 7,616.43 -559.98 2.00 -1.79 0.90 153.42 10,263.09 86.80 0.19 3,545.00 7,781.47 -559.44 0.00 0.00 0.00 0.00 10,273.46 86.85 359.99 3,545.57 7,791.83 -559.43 2.00 0.53 -1.93 -74.61 11,264.73 86.85 359.99 3,600.00 8,781.60 -559.65 0.00 0.00 0.00 0.00 11,286.80 87.29 0.02 3,601.13 8,803.65 -559.65 2.00 2.00 0.14 3.96 11,665.23 87.29 0.02 3,619.00 9,181.65 -559.53 0.00 0.00 0.00 0.00 911312005 1:52:38PM Page 3 of 8 COMPASS 2003.118ui1d 48 OR!6!f~.';~L C `y Halliburton Company Con~oPhil~~ps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plah 1J-164 (L6) Survey Caicufation Method: Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06) Planned Survey 1J-164 L1 (wp06) MD Inclination Azimuth ND SSND +N1-S - +E/-W (ft) (°) (°) (ft) fft) (ftI (ft) 4,583.67 80.00 0.07 3,518.42 3,409.42 2,106.07 -560.84 7 5!8" • HALLIBUATON Sperry Driilling Services Well Plan 1J-164{L6) 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) 1J-164 (28'+81') @.109:OOft (D141 (28GG+ 81'RF)) True Minimum Curvature Map Map Northing Easting DLSEV Vert Section i (ft) (ft) (°/100ft) (ft) i 5,947,832.30 558,115.83 0.00 2,106.07 j 4,595.67 81.91 0.07 3,520.31 3,411.31 2,117.92 -560.83 5,947,844.15 558,115.75 15.90 2,117.92 BOW 4596ft MD, 3520ft ND -Drill Out 63/4 Hole 4,598.53 81.91 0.07 3,520.71 3,411.71 2,120.75 -560.83 5,947,846.98 558,115.74 0.00 2,120.75 West Sak B (80°) 4,600.00 81.91 0.07 3,520.92 3,411.92 2,122.20 -560.82 5,947,848.43 558,115.73 0.00 2,122.20 4,625.67 81.91 0.07 3,524.53 3,415.53 2,147.62 -560.80 5,947,873.85 558,115.56 0.00 2,147.62 End 30' Rathole - Build ~ 5°/100ft, 4626it MD, 3525it ND 4,700.00 85.62 0.01 3,532.60 3,423.60 2,221.50 -560.75 5,947,947.71 558,115.03 5.00 2,221.50 4,800.00 90.62 359.93 3,535.87 3,426.87 2,321.41 -560.81 5,948,047.62 558,114.19 5.00 2,321.41 4,819.20 91.58 359.91 3,535.50 3,426.50 2,340.60 -560.83 5,948,066.81 558,114.01 5.01 2,340.60 Sail ~ 91.58° Inc : 481 9ft MD, 3535ft ND 4,900.00 91.58 359.91 3,533.27 3,424.27 2,421.37 -560.96 5,948,147.57 558,113.26 0.00 2,421.37 5,000.00 91.58 359.91 3,530.51 3,421.51 2,521.34 -561.11 5,948,247.51 558,112.33 0.00 2,521.34 5,100.00 91.58 359.91 3,527.74 3,418.74 2,621.30 -561.26 5,948,347.46 558,111.40 0.00 2,621.30 5,180.09 91.58 359.91 3,525.53 3,416.53 2,701.36 -561.38 5,948,427.51 558,110.65 0.00 2,701.36 Continue Buiid ~ 5°11 00ft , 5180ft MD, 3525ft ND 5,200.00 90.59 359.96 3,525.15 3,416.15 2,721.26 -561.40 5,948,447.41 558,110.48 5.00 2,721.26 5,209.59 90.11 359.99 3,525.10 3,416.10 2,730.86 -561.41 5,948,457.01 558,110.40 5.00 2,730.86 Sail ~ 90.11° Inc : 5209ft MD, 3525ft ND 5,259.59 90.11 359.99 3,525.00 3,416.00 2,780.86 -561.42 5,948,507.00 558,110.00 0.00 2,780.86 Begin GeoSteer in B-Sand 5259ft MD, 3525ft ND -1J-164 L1 T1 (wp06) 5,263.76 90.17 0.05 3,524.99 3,415.99 2,785.02 -561.42 5,948,511.17 558,109.97 2.00 2,785.02 5,300.00 90.17 0.05 3,524.88 3,415.88 2,821.26 -561.39 5,948,547.40 558,109.72 0.00 2,821.26 5,400.00 90.17 0.05 3,524.58 3,415.58 2,921.26 -561.31 5,948,647.39 558,109.02 0.00 2,921.26 5,500.00 90.17 0.05 3,524.28 3,415.28 3,021.26 -561.23 5,948,747.38 558,108.32 0.00 3,021.26 5,600.00 90.17 0.05 3,523.98 3,414.98 3,121.26 -561.15 5,948,847.36 558,107.62 0.00 3,121.26 5,700.00 90.17 0.05 3,523.68 3,414.68 3,221.26 -561.07 5,948,947.35 558,106.92 0.00 3,221.26 5,800.00 90.17 0.05 3,523.38 3,414.38 3,321.26 -560.99 5,949,047.34 558,106.22 0.00 3,321.26 5,900.00 90.17 0.05 3,523.08 3,414.08 3,421.26 -560.91 5,949,147.33 558,105.52 0.00 3,421.26 6,000.00 90.17 0.05 3,522.78 3,413.78 3,521.26 -560.83 5,949,247.31 558,104.82 0.00 3,521.26 6,100.00 90.17 0.05 3,522.48 3,413.48 3,621.26 -560.75 5,949,347.30 558,104.12 0.00 3,621.26 6,200.00 90.17 0.05 3,522.18 3,413.18 3,721.26 -560.67 5,949,447.29 558,103.42 0.00 3,721.26 6,259.72 90.17 0.05 3,522.00 3,413.00 3,780.98 -560.62 5,949,507.00 558,103.00 0.00 3,780.98 1J-164 L7 T2 (wp06) 6,297.80 89.41 359.99 3,522.14 3,413.14 3,819.06 -560.61 5,949,545.07 558,102.71 2.00 3,819.06 6,300.00 89.41 359.99 3,522.16 3,413.16 3,821.26 -560.61 5,949,547.28 558,102.70 0.00 3,821.26 6,400.00 89.41 359.99 3,523.19 3,414.19 3,921.25 -560.63 5,949,647.26 558,101.89 0.00 3,921.25 6,500.00 89.41 359.99 3,524.21 3,415.21 4,021.25 -560.66 5,949,747.24 558,101.09 0.00 4,021.25 6,600.00 89.41 359.99 3,525.24 3,416.24 4,121.24 -560.68 5,949,847.22 558,100.29 0.00 4,121.24 6,700.00 89.41 359.99 3,526.26 3,417.26 4,221.24 -560.70 5,949,947.20 558,099.49 0.00 4,221.24 6,800.00 89.41 359.99 3,527.29 3,418.29 4,321.23 -560.72 5,950,047.18 558,098.69 0.00 4,321.23 9/13x7005 1:52:38PM Page 4 of 8 COMPASS 2003.11 Build 48 ~OI'10Ct3~'11~~1p5 Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164 (L6) Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06} Planned Survey 1J-164 L1 (wp06) Hailiburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North. Reference•_ Survey Calculation Method: HALLiBURTON Spiny DrilNng Ssrvicea Well Plan 1J-164 (L6) 1 J-164 (28'+81') (ti; 109.OOft (D141 (28GL + 81'RF)) 1J-164 (28'+81') C~ 149.OOft (D141 (28GL + 81'RF)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-3' +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (it} Ift) (fit) (ft) (ft) (°/100ft) (ft) 6,900.00 89.41 359.99 3,528.31 3,419.31 4,421.23 -560.75 5,950,147.17 558,097.89 0.00 4,421.23 7,000.00 89.41 359.99 3,529.34 3,420.34 4,521.22 -560.77 5,950,247.15 558,097.08 0.00 4,521.22 7,100.00 89.41 359.99 3,530.36 3,421.36 4,621.22 -560.79 5,950,347.13 558,096.28 0.00 4,621.22 7,200.00 89.41 359.99 3,531.39 3,422.39 4,721.21 -560.81 5,950,447.11 558,095.48 0.00 4,721.21 7,259.90 89.41 359.99 3,532.00 3,423.00 4,781.11 -560.83 5,950,507.00 558,095.00 0.00 4,781.11 1J-184 L1 T3 (wp06) 7,264.55 89.31 0.05 3,532.05 3,423.05 4,785.75 -560.83 5,950,511.65 558,094.97 2.50 4,785.75 7,300.00 89.31 0.05 3,532.48 3,423.48 4,821.20 -560.80 5,950,547.09 558,094.72 0.00 4,821.20 7,400.00 89.31 0.05 3,533.68 3,424.68 4,921.20 -560.72 5,950,647.07 558,094.02 0.00 4,921.20 7,500.00 89.31 0.05 3,534.88 3,425.88 5,021.19 -560.64 5,950,747.06 558,093.32 0.00 5,021.19 7,600.00 89.31 0.05 3,536.08 3,427.08 5,121.18 -560.56 5,950,847.04 558,092.62 0.00 5,121.18 7,700.00 89.31 0.05 3,537.28 3,428.28 5,221.18 -560.48 5,950,947.02 558,091.92 0.00 5,221.18 7,800.00 89.31 0.05 3,538.48 3,429.48 5,321.17 -560.40 5,951,047.00 558,091.22 0.00 5,321.17 7,900.00 89.31 0.05 3,539.68 3,430.68 5,421.16 -560.32 5,951,146.98 558,090.52 0.00 5,421.16 8,000.00 89.31 0.05 3,540.88 3,431.88 5,521.15 -560.24 5,951,246.96 558,089.82 0.00 5,521.15 8,100.00 89.31 0.05 3,542.08 3,433.08 5,621.15 -560.16 5,951,346.94 558,089.12 0.00 5,621.15 8,200.00 89.31 0.05 3,543.28 3,434.28 5,721.14 -560.08 5,951,446.92 558,088.42 0.00 5,721.14 8,260.09 89.31 0.05 3,544.00 3,435.00 5,781.23 -560.03 5,951,507.00 558,088.00 0.00 5,781.23 1J-164 L1 T4 (wp06) 8,300.00 88.51 0.03 3,544.76 3,435.76 5,821.13 -560.00 5,951,546.90 558,087.72 2.00 5,821.13 8,379.46 86.93 0.01 3,547.92 3,438.92 5,900.53 -559.97 5,951,626.29 558,087.13 2.00 5,900.53 8,400.00 86.93 0.01 3,549.02 3,440.02 5,921.03 -559.97 5,951,646.79 558,086.97 0.00 5,921.03 8,455.55 86.93 0.01 3,552.00 3,443.00 5,976.50 -559.96 5,951,702.25 558,086.55 0.00 5,976.50 1J-164 L1 T5 (wp06) 8,500.00 86.93 0.01 3,554.38 3,445.38 6,020.89 -559.95 5,951,746.63 558,086.22 0.00 6,020.89 8,600.00 86.93 0.01 3,559.75 3,450.75 6,120.74 -559.93 5,951,846.48 558,085.46 0.00 6,120.74 8,660.62 86.93 0.01 3,563.00 3,454.00 6,181.28 -559.91 5,951,907.00 558,085.00 0.00 6,181.28 1J-164 L1 T6 (wp06) 8,700.00 87.91 359.97 3,564.77 3,455.77 6,220.62 -559.92 5,951,946.34 558,084.69 2.50 6,220.62 8,800.00 90.41 359.86 3,566.25 3,457.25 6,320.60 -560.08 5,952,046.30 558,083.75 2.50 6,320.60 8,833.56 91.24 359.82 3,565.76 3,456.76 6,354.15 -560.17 5,952,079.85 558,083.40 2.50 6,354.15 8,900.00 91.24 359.82 3,564.32 3,455.32 6,420.58 -560.38 5,952,146.27 558,082.67 0.00 6,420.58 8,960.76 91.24 359.82 3,563.00 3,454.00 6,481.32 -560.58 5,952,207.00 558,082.00. 0.00 6,481.32 Possible Fault Crossing - 8960ft MD, 3568ft TVD -1J-164 L1 T7 (wp06) 8,985.76 91.24 359.82 3,562.46 3,453.46 6,506.31 -560.65 5,952,231.99 558,081.73 0.00 6,506.31 Cross fault - Build ~ 3°/100ft to reacquire Sand , 8985ft M D, 3562ft TVD 9,000.00 91.67 359.87 3,562.10 3,453.10 6,520.55 -560.69 5,952,246.23 558,081.58 2.99 6,520.55 9,089.08 94.32 0.16 3,557.44 3,448.44 6,609.50 -560.67 5,952,335.17 558,080.90 3.00 6,609.50 9,100.00 94.32 0.16 3,556.61 3,447.61 6,620.39 -560.64 5,952,346.05 558,080.85 0.00 6,620.39 9,200.00 94.32 0.16 3,549.07 3,440.07 6,720.11 -560.36 5,952,445.76 558,080.36 0.00 6,720.11 9,300.00 94.32 0.16 3,541.53 3,432.53 6,819.82 -560.07 5,952,545.46 558,079.86 0.00 6,819.82 9,400.00 94.32 0.16 3,533.99 3,424.99 6,919.54 -559.79 5,952,645.17 558,079.37 0.00 6,919.54 9,500.00 94.32 0.16 3,526.45 3,417.45 7,019.25 -559.50 5,952,744.87 558,078.88 0.00 7,019.25 9,532.30 94.32 0.16 3,524.02 3,415.02 7,051.46 -559.41 5,952,777.08 558,078.72 0.00 7,051.46 9,600.00 92.30 0.08 3,520.11 3,411.11 7,119.04 -559.27 5,952,844.65 558,078.33 3.00 7,119.04 9,700.00 89.30 359.95 3,518.72 3,409.72 7,219.02 -559.24 5,952,944.62 558,077.58 3.00 7,219.02. 9,762.53 87.42 359.87 3,520.51 3,411.51 7,281.53 -559.34 5,953,007.12 558,077.00 3.00 7,281.53 9/13/7005 1:52:38PM Page 5 of 8 COMPASS 2003.11 Build 48 lIGINAL 1r' ~ Halliburton Company HALLIBUiiTON ~t?t14C0~'11~j1}~5 Planning Report -Geographic - - --- - Alaska Sps~ryr ariuing s.rvFaes Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-164 (L6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+g1') @ 109.OOft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) Site: Kuparuk 4J Pad North Reference: True Well: Play 1J-164 (L6) Survey Caiculaton Method: Minimum Curvature Wellbore: 1J-164 L1 Design: 1J-164 L1 (v/p06) --- -------- Planned Survey 1J-164 L1 (wp06) ~ 'i Map Map MD inclination Azimuth TVD SSTVD +N/-S +EJW Northing Easting DLSEV Vert Section ~ 9,800.00 87.42 359.87 3,522.19 3,413.19 7,318.96 -559.42 5,953,044.54 558,076.62 0.00 7,318.96 9,862.53 87.42 359.87 3,525.00 3,416.00 7,381.42 -559.56 5,953,107.00 558,076.00 0.00 7,381.42 1 J-164 L1 T10 (wp06) 9,900.00 87.42 359.87 3,526.68 3,417.68 7,418.85 -559.64 5,953,144.42 558,075.63 0.00 7,418.85 10,000.00 87.42 359.87 3,531.18 3,422.18 7,518.75 -559.86 5,953,244.31 558,074.63 0.00 7,518.75 10,062.76 87.42 359.87 3,534.00 3,425.00 7,581.45 -560.00 5,953,307.00 558,074.00 0.00 7,581.45 1J-164 L1 T11 (wp06) 10,097.78 86.80 0.19 3,535.77 3,426.77 7,616.43 -559.98 5,953,341.97 558,073.75 2.00 7,616.43 10,100.00 86.80 0.19 3,535.89 3,426.89 7,618.64 -559.97 5,953,344.18 558,073.74 0.00 7,618.64 10,200.00 86.80 0.19 3,541.48 3,432.48 7,718.48 -559.65 5,953,444.02 558,073.28 0.00 7,718.48 10,263.09 86.80 0.19 3,545.00 3,436.00 7,781.47 -559.44 5,953,507.00 558,073.00 0.00 7,781.47 1J-164 L1 T12 (wp06) 10,273.46 86.85 359.99 3,545.57 3,436.57 7,791.83 -559.43 5,953,517.36 558,072.94 2.00 7,791.83 10,300.00 86.85 359.99 3,547.03 3,438.03 7,818.33 -559.43 5,953,543.85 558,072.72 0.00 7,818.33 ~ 10,400.00 86.85 359.99 3,552.52 3,443.52 7,918.18 -559.45 5,953,643.69 558,071.92 0.00 7,918.18 i 10,500.00 86.85 359.99 3,558.01 3,449.01 8,018.03 -559.48 5,953,743.52 558,071.12 0.00 8,018.03 i 10,600.00 86.85 359.99 3,563.50 3,454.50 8,117.88 -559.50 5,953,843.36 558,070.32 -0.00 8,117.88 I 10,700.00 86.85 359.99 3,568.99 3,459.99 8,217.73 -559.52 5,953,943.20 558,069.52 0.00 8,217.73 i 10,800.00 86.85 359.99 3,574.48 3,465.48 8,317.57 -559.54 5,954,043.03 558,068.72 0.00 8,317.57 ~ 10,900.00 86.85 359.99 3,579.97 3,470.97 8,417.42 -559.57 5,954,142.87 558,067.92 0.00 8,417.42 11,000.00 86.85 359.99 3,585.47 3,476.47 8,517.27 -559.59 5,954,242.70 558,067.12 0.00 8,517.27 ~ 11,100.00 86.85 359.99 3,590.96 3,481.96 8,617.12 -559.61 5,954,342.54 558,066.32 0.00 8,617.12 ~ 11,200.00 86.85 359.99 3,596.45 3,487.45 8,716.97 -559.63 5,954;442.38 558,065.52 0.00 8,716.97 ~ 11,264.73 86.85 359.99 3,600.00 3,491.00 8,781.60 -559.65 5,954,507.00 558,065.00 0.00 8,781.60 1J-164 L1 T13 (wp06) ~ 11,286.80 87.29 0.02 3,601.13 3,492.13 8,803.65 -559.65 5,954,529.04 558,064.83 2.00 8,803.65 11,300.00 87.29 0.02 3,601.75 3,492.75 8,816.83 -559.64 5,954,542.22 558,064.73 0.00 8,816.83 11,400.00 87.29 0.02 3,606.47 3,497.47 8,916.72 -559.61 5,954,642.10 558,063.98 0.00 8,916.72 11,500.00 87.29 0.02 3,611.20 3,502.20 9,016.61 -559.58 5,954,741.98 558,063.24 0.00 9,016.61 11,600.00 87.29 0.02 3,615.92 3,506.92 9,116.50 -559.55 5,954,841.85 558,062.49 0.00 9,116.50 . 11,665.23 87.29 0.02 3,619.00 3,510.00 9,181.65 -559.53 5,954,907.00 558,062.00 0.00 9,181.65 4112" • 1J-164 L1 Toe (wp06) 9/13/2005 1:52:38PM Page 6 of 8 COMPASS 2003.118ui1d 48 ORIGINAL ' • b- ~t)i"IQCO~'11~~ip5 Halliburton Company Pl i t hi R G MAfL.I.IBiUgTON ann ng - epor eograp c q~s~ Sperry Drill Servt>rss Database: EDM 2003.11 Single User Db Locet Co-ordinate Reference: Well Plan 1 J-164 (L6) Company: ConocoPhillips Al aska (Kuparuk) ND Reference: 1J-164 (28'+81') @ 109:OOft (D141 (28GL + 81'RF)) Project: Kuparuk River Un it MD Reference: 1J-164 (28'+81') @ 109OOft (D141 (28GL + $1'RF)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-164 (L6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06) Geologic Targets 1J-164 L1 _-- TVD Target Name +N!-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,619.00 1J-164 L1 Toe (wp06) 9,181.65 -559.53 5,954,907.00 558,062.00 - Point 3,563.00 1J-164 Li T7 (wp06) 6,481.32 -560.58 5,952,207.00 558,082.00 - Point 3,519.00 1J-164 L1 T8 (wp06) 6,581.33 -559.80 5,952,307.00 558,082.00 - Point 3,522.00 1J-164 L1 T2 (wp06) 3,780.98 -560.62 5,949,507.00 558,103.00 - Point 3,519.00 1J-164 L1 T9 (wp06) 6,781.35 -560.24 5,952,507.00 558,080.00 - Point 3,525.00 1J-164 L1 T1 (wp06} 2,780.86 -561.42 5,948,507.00 558,110.00 - Point 3,534.00 1J-164 L1 T11 (wp06) 7,581.45 -560.00 5,953,307.00 558,074.00 - Point 3,525.00 1J-164 Lt T10 (wp06) 7,381.42 -559.56 5,953,107.00 558,076.00 - Point 3,563.00 1J-164 L1 T6 (wp06) 6,181.28 -559.91 5,951,907.00 558,085.00 - Point 3,545.00 1J-164 L1 T12 (wp06) 7,781.47 -559.44 5,953,507.00 558,073.00 - Poini 3,544.00 1J-164 Li T4 (wp06) 5,781.23 -560.03 5,951,507.00 558,088.00 - Point 3,532.00 1J-164 L1 T3 (wp06) 4,781.11 -560.83 5,950,507.00 558,095.00 - Point 3,600.00 1J-164 L1 T13 (wp06) 8,781.60 -559.65 5,954,507.00 558,065.00 - Point 3,552.00 1J-164 L1 T5 (wp06} 6,081.27 -560.69 5,951,807.00 558,085.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter ~ (ft) (ft) (") (") 2,324.56 2,203.00 10~/d 13-1/2 4,583.68 3,518.42 7-5/8 8-5/S 11,665.22 3,619.00 4.1/2 6-314 9/13J2005 f:52:38PM Page 7 of 8 COMPASS 2003.118ui1d 48 ORIGINAL l ~' ~OI'10C0~'11~~1 Halliburton Company Pl i R hi t G NALLtBUi~tfi©N _._ , -- ann ng epor eograp - c ~ ~~ ® ~*s arji~n Database: EOM 2003.11 Single User Db Locat Co-ordinate Reference: Well Plan 1J-164 (L6) Company: ConocoPhiilips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109:OOft (D141 (28GL + 81'R>7) Project: Kuparuk River Unit Mt) Reference: 1 J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'R~) Site: Kuparuk 1J Pad Nortfi Reference: True Well: Plan 1J-164 (L6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 L1 Design: 1J-164 L1 (wp06) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W j (n) (°) (°} (ftl (ft) ift) Name ~ 1,593.05 23.79 343.04 1,543.00 285.84 4.64 Base of Permafrost 1,703.47 24.02 332.14 1,644.00 327.04 -12.37 T3 2,025.77 26.24 314.23 1,935.00 431.61 -102.06 K15 2,324.56 26.24 314.23 2,203.00 523.73 -196.72 T3 + 550 (CSG PT) 3,162.82 41.39 339.41 2,922.00 863.85 -442.30 Ugnu C 3,434.03 50.80 346.95 3,110.00 1,050.71 -497.73 Ugnu B 3,497.27 53.05 348.41 3,149.00 1,099.34 -508.34 Ugnu A 3,747.36 62.11 353.45 3,283.00 1,307.57 -541.10 K-t3 4,250.33 77.00 0.07 3,446.00 1,780.72 -561.21 West Sak D (77°) 4,445.93 77.00 0.07 3,490.00 1,971.31 -561.00 West Sak C 4,598.53 81.91 0.07 3,520.71 2,120.75 -560.83 West Sak B (80°) 9N3l1005 1:52:38PM Page 8 of 8 COMPASS 2003.118ui1d 48 • ConocoPhillips ~~~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 (L6) 1 J-164 L1 Anticollision Summary 13 September, 2005 HA1..1..~~L.~RTC~lV Sperry Dritling Services ORIG~Nl+I SURVEY PROGRAM Date: 2dL~0?0.5'1'011:00:011 Validated: Yes Verxion: Depth Fmm Depth lb Sunc~/Plan Tool 2&INI 8g1.IN1 CB-GYRO-SS lNM1.IM1 .L5f0.67 MWDfIFR-AK-CAZSC ).583.(,7 1166-5,7~ IJ-IW Ll (MINK.) MWDfIFR-AK-CAZSC 0 270 1J-09 ~ 5; 180 90 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X200 ft/ink REFERENCE INFORMATION Coordinate (WE) Reference: Well Plan 1J-164 (L6), True North Vertical (ND) Reference: 1J-164 (28'+81') ~ 109.OOfl (D141 (28GL+81'RF)) Section (VS) Reference: Slot -(O.OON, O.OOE) Measured Depth Reference: 1J-164 (28'+81') ~ 109.001[ (D141 (28GL + 81'RF)) Calculation Method: Minimum Curvature NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-164 (L6) ConocoPhillips Alaska (Kuparuk) Ground Level: 81.00 Engineering .WS +EJ-W Northing Easting Latittude Longhude Slot West Sak 0.00 0.00 5945710.87 558691.02 70°15'44.408N 149°31'31.87W Calcuation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trev. Cylinder North Ercor Surface: Elliptical Conic 30 blaming Methotl: Rules t3asetl 330 25 20 300 60 15 10 5 ' 270 90 1 240 1 120 2 210 150 From Colour 0 250 500 To MD 250 500 750 180 Travelling Cylinder Azimuth (TFO+AZI) I°I vs Centre to Centre Separation 115 ftlinl , 750 1000 SECTION DETAILS 1000 1250 Sec MD lac Azi ND +WS +E!-W DLeg TFace VSec Target 1250 1500 1 4583.67 80.00 0.07 1518.42 2106.07 560.84 0.00 0.00 2106.07 T 4595.67 81.91 0.07 3520.11 2117.92 560.83 15.90 0.00 2117.92 1500 -- - 1750 3 4625.67 81.91 0.07 3524.51 2147.62 560.80 0.00 0.00 21d7.62 1750 2000 4 4819.20 91.58 159.91 3535.50 2340.60 360.83 5.00 -0.91 2340.60 5 5180.09 91.58 159.91 3525.53 2701.16 561.18 0.00 0.00 2701.36 2000 3000 6 5209.59 90.11 159.99 3528.10 2710.86 561.41 5.00 177.00 2730.86 3000 4000 7 5259.59 90.11 159.99 3525.00 2780.86 561.42 0.00 0.00 2780.86 1J-164 L1 Tt (wp06) 8 5263.76 90.17 0.05 3524.99 2785.02 561.42 2.00 41.92 2785.02 4000 5000 9 6259.72 90.17 0.05 3522.00 3780.98 560.62 0.00 0.00 3780.98 1J-164 L1 T2 (wp06) 5000 6000 10 6297.80 89.41 359.99 3522.14 3819.06 560.61 2.00 -175.59 3819.06 11 7259.90 89.d1 359.99 3532.00 4781.11 560.83 0.00 0.00 4781.11 1J-164 L1 T3 (wp06) 6000 7000 12 7264.55 89.31 0.05 1532.05 4785.78 360.83 2.50 149.74 4785.75 13 8260.09 89.11 0.05 3544.00 5781.23 560.03 0.00 0.00 5781.23 1 J-164 L1 T4 (wp06) 7000 8000 14 8379.46 66.93 0.01 3547.92 5900.53 559.97 2.00 -179.19 5900.53 8000 9000 15 8660.62 86.93 0.01 3563.00 6181.28 559.91 0.00 0.00 6181.28 1J-164 L7 T6 (wp06) 16 8813.56 91.20 159.82 3565.76 6354.15 560.17 2.b0 -2.57 6154.15 9000 10000 17 6960.76 91.24 359.82 1563.00 6481.32 560.58 0.00 0.00 6481.32 1J-164 L1 T7 (wp06) 10000 11000 18 8985.76 91.24 159.82 3562.46 6506.31 560.65 0.00 0.00 6506.31 19 9089.08 94.32 0.16 3557.44 6609.50 560.67 1.00 6.38 6609.50 11000 12000 20 9512.30 94.32 0.16 3524.02 7051.46 559.41 0.00 0.00 7051.46 21 9762.53 87.42 359.87 3520.51 7281.53 559.34 3.00 -177.59 7281.53 22 9862.53 87.d2 159.87 1525.00 7381.42 559.56 0.00 0.00 7181.42 1J-164 Lt 210 (wp06) 23 10062.76 87.42 359.87 1534.00 7581.45 560.00 0.00 0.00 7581.45 1J-164 L1 211 (wp06) 2410097.78 86.80 0.19 3535.77 7616.43 559.98 2.00 153.42 7616.41 25 10263.09 86.80 0.19 3546.00 7781.47 559.44 0.00 0.00 7781.47 1J-164 L1 212 (wp06) 2610273.46 86.85 359.99 3845.57 7791.8) 559.43 2.00 -74.61 7791.83 27 11264.71 86.85 359.99 1600.00 8781.60 589.65 0.00 0.00 8781.60 1J-164 L1 213 (wp06) 2811286.80 87.29 0.02 3601.13 8801.65 559.85 2.00 3.96 8801.65 29 11665.21 117.29 0.02 3619.00 9181.65 559.53 0.00 0.00 9181.65 1 J-164 L1 Tce (wp06) ANTISOWSION SETTINGS Interpolation McNOd: MD Interval: SOStations Depth Range From: 4583 To 11662.23 Maximum Range:5000 Reference: Plan: 1J-164 L1 (wp06) • ~t)110t0~"11~~1pS Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-164 (L6) Well Error: O.OOft Reference Welibore 1J-164 L1 Reference Design: 1J-164 L1 (wp06) Halliburton Company Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: • HALLIBtJRTON sp+.rry Drtllin~ Ssrvicws.~_~ WeII Plan 1J-164 (L6) 1 J-164 (28'+g1') @ 109.OOft (D141 (28GL + 81'RF}) 1 J-164.(28'+g1') @ 109:OOft (D141 (28GL + 81'RF)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-164 L1 (wp06)_ Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 5,OOO.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Prograrrt Date 9/13/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 0.00 1J-164 (wp06) (1J-164) CB-GYRO-SS Camera based gyro single shot 800.00 4,583.67 1J-164 (wp06) (1J-164) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,583.67 11,665.23 iJ-164 L1 (wp06) (1J-164 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9!13/2005 2:18:07PM Page3 of 5 COMPASS 2003.11 Build 48 IL • Coinc~cc~~'I Company: Project: Reference Site: Sit® Error: ~iilps A ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad O.OOft Reference Well: Plan 1J-164 (L6) Well Error: O.OOft Reference Wellbore 1J-164 L1 Reference Design: 1J-164 L1 (wp06) Haliiburton Company • Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Ref®rence: North Reference:: Survey Calcutatlon Method: Output errors are at Database:. Offset TvD Reference: Ha~>~uaroll~ 8psrry Drilling S~rvirrras WeII Plan 1J-164 (L6) 1J-164:(28'+81') @ 109.OOft (D141 (28GL + 81'RF)) 1J-164 (28'+81') @ 109.OOft (D141 (28GL.+ 81'RF)) True Minimum Curvature 1:00 sigma, EDM 2003.14 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth. Depth. Distance (ft) from Plan Offset Well -Wellbore- Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 192.86 200.00 213.55 3.39 210.16 Pass -Major Risk 1J-09 - 1J-09 - 1J-09 5,460.36 4,800.00 335.32 143.55 191.77 Pass -Major Risk 9J-10 - 1J-10 - 1J-10 800.74 800.00 74.24 14.96 59.28 Pass -Major Risk Plan 1J-101 (L7) -Plan 1J-L7 A Lat -Plan 1J-L7 A 1,663.63 1,600.00 96.87 29.62 67.24 Pass -Major Risk Plan 1J-102 (M8) - 1J-102 - 1J-102 (wp03) 1,312.84 1,200.00 270.09 24.15 245.94 Pass -Major Risk Plan 1J-102 (M8) - 1J-102 L1 - 1J-102 L1 (wp03) 1,312.84 1,200.00 270.09 24.06 246.03 Pass -Major Risk Plan 1J-102 (M8) - 1J-102 L2 - iJ-102 L2 (wp03) 1,312.84 1,200.00 270.09 24.06 246.03 Pass -Major Risk Plan 1J-103 (M9} -Plan 1J-M9 -Plan 1J-M9 1,089.25 1,000.00 308.16 19.49 288.67 Pass -Major Risk Plan 1J-105 (M10) -Plan 1J-M10 Lat A -Plan 1J-t 963.25 900.00 287.94 17.59 270.35 Pass -Major Risk Plan 1J-107 {M11) -Plan 1J-M11 Lat A -Plan 1J-t 301.00 300.00 247.08 5.81 241.27 Pass -Major Risk Plan 1J-109 (M13) -Plan 1 J-M13 Lat A -Plan 1 J-I 300.99 300.00 202.28 5.81 196.47 Pass -Major Risk Plan 1J-111 (M12) -Plan 1J-M12 Lat A -Plan 1J-t 301.00 300.00 176.41 5.81 170.59 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L 604.83 600.00 148.12 11.49 136.64 Pass -Major Risk Plan 1 J-118 (L10) -Plan 1 J-L10 Lat A -Plan 1 J-L' 401.00 400.00 151.05 7.69 143.36 Pass -Major Risk Plan 1J-12 -Plan 1J-12 (K2 Prelim) - 1J-12 (K2 Pr 1,200.00 1,200.00 109.81 24.21 85.61 Pass -Major Risk Plan 1J-120 (L11) -Plan 1J-L11 Lat A -Plan 1J-L' 401.00 400.00 166.19 7.69 158.51 Pass -Major Risk Plan 1J-122 (L12) -Plan 1 J-L12 Lat A -Plan 1 J-L' 301.00 300.00 188.83 5.81 183.02 Pass -Major Risk Plan 1J-124 (L13) -Plan 1J-L13 Lat A-Plan 1J-L' 300.99 300.00 217.27 5.81 211.46 Pass -Major Risk Plan 1J-152 (M5) - 1 J-152 - 1 J-152 (wp04) 300.00 300.00 279.78 6.49 273.29 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L1 - 1J-152 L1 (wp04) 300.00 300.00 279.78 6.49 273.29 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L2 - 1J-152 L2 (wp04) 300.00 300.00 279.78 6.49 273.29 Pass -Major Risk Plan 1J-154 - 1J-154 - 1J-154 (wp06) 2,684.10 2,599.99 108.56 52.81 55.75 Pass -Major Risk Plan 1J-154 - 1J-154 L1 - 1J-154 L1 (wp06) 2,684.10 2,599.99 108.56 52.82 55.74 Pass -Major Risk Plan 1J-154 - 1J-154 L2 - 1J-154 L2 (wp06) 2,684.10 2,599.99 108.56 52.82 55.74 Pass -Major Risk Plan 1J-156 (M4) -Plan 1J-M4 A Lat -Plan 1J-M4 921.39 900.00 166.80 17.31 149.49 Pass -Major Risk Plan 1J-158 (M3) - 1J-M3 A Lateral - 1J-M3 A Late 300.99 300.00 139.98 5.65 134.33 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 - 1J-159 (wp03) 1,210.37 1,200.00 43.69 21.74 21.95 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 L1 - 1J-159 L1 (wp03) 1,210.37 1,200.00 43.69 21.74 21.95 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 L2 - 1J-159 L2 (wp03) 1,210.37 1,200.00 43.69 21.74 21.95 Pass -Major Risk Plan 1J-160 (M2) -Plan 1J-M2 Lat A -Plan 1J-M2 300.99 300.00 99.94 5.81 94.13 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 - 1J-162 (wp03.1-North 300.99 300.00 39.84 6.35 33.49 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) 300.99 300.00 39.84 6.25 33.60 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 (wp3.1) 300.99 300.00 39.84 6.25 33.60 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 - 1J-166 (wp03) 598.53 600.00 41.80 12.76 29.04 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 L1 - 1J-166 L1 (wp03) 500.00 500.00 39.80 9.70 30.10 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 L2 - 1J-166 L2 (wp03) 500.00 500.00 39.80 9.70 30.10 Pass -Major Risk Plan 1J-168 - 1J-168 - 1J-168 (wp10 -Revised 8/ 399.85 400.00 82.19 8.66 73.53 Pass -Major Risk Plan 1J-168 - 1J-168 - 1J-168 Rig 399.85 400.00 82.19 8.66 73.53 Pass -Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 399.85 400.00 82.20 8.66 73.54 Pass -Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1(wp10 - Revis 399.85 400.00 82.20 8.66 73.54 Pass -Major Risk Plan 1J-168 - 1J-168 L2 - 1J-168 L2 (wp10 - Revi; 399.85 400.00 82.20 8.66 73.54 Pass -Major Risk Plan 1J-168 - 1J-168 L2 - 1J-168 L2 Rig 399.85 400.00 82.19 8.66 73.53 Pass -Major Risk Plan 1J-170 (L4) -Plan 1J-L4 LatA -Plan 1J-L4 La 500.00 500.00 120.96 9.53 111.44 Pass -Major Risk Plan 1J-174 (Q1) -Plan 1J-Q1 B Lat -Plan 1J-Q1 300.92 300.00 201.91 5.79 196.11 Pass -Major Risk Plan 1J-176 (Q2) -Plan 1J-Q2 B Lat -Plan 1J-Q2 300.99 300.00 240.84 5.80 235.04 Pass -Major Risk Plan 1J-50 (Ugnu Disposal) -Plan 1J-UgnuDispos 301.00 300.00 319.85 5.81 314.04 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 1,309.25 1,300.00 140.20 26.83 113.37 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 1,119.51 1,100.00 153.23 27.00 126.23 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 995.66 1,000.00 162.81 20.60 142.21 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 882.64 900.00 192.56 23.95 168.61 Pass -Major Risk WSP-06 -WSP-06 -WSP-06 584.81 600.00 221.31 15.55 205.76 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 677.01 700.00 258.00 20.88 237.12 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 1,422.40 1,400.00 118.08 32.42 85.66 Pass - Ma~or Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9/'!32005 2: t 8; 07PM Page 4 of 5 COMPASS 2003.11 Build 48 OR~GIn!pl • C011000~'tl~~lp5 Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk iJ Pad Site Error: O:OOft Reference Well: Plan 1J-164 (L6) Well Error: O.OOft Reference Wellbore 1J-164 L1 Reference Design: 1J-164 L1 (wp06) Hallibulrton Company MAI~.L.MBURTON Anticollision Report s-~~- ~r n vi i~~i g ser ce - Local Co-ordinate Reference: Well Plan 1J-1.64 (L6) tVD Reference: 1 J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) MD Reference: 1J-164 (28'+81') @ 109:OOft(D141 (28GL + 81'RF)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad WSP-1 S -WSP-1 S -WSP-1 S 1,535.17 1,500.00 109.29 64.35 44.94 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 603.07 600.00 40.38 15.02 25.36 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9!132005 2:18:07PM Page 5 of 5 COMPASS 2003.11 Build 48 1~-164L Drilling Hazard Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-314" Open Hole 14-112" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets um in out, backreamin 1J-164L1 Drilling Hazards Summary.doc prepared by Shane Cloninger ' 9/21/2005 1:18 PM O V Z 0 Q Insulated Conductor f1 Casing, 20", 94#, K55 s ~~ 34", 0.312" WT (d +/- 8d M D ~. rD .,5 °~ R'1 ~ ~' C"' ~ w ~' ~ 'o' 0 3 0 m ~ ^• a A b Be ~~ gg a~ ti~ ~, Y ~ Wellhead /Tubing Head /Tree, 10-3/4" x q_~^, 5 000 ksi Tubing String: 4-1/2", 12.6 #, L-80, IBTM (I) 3.875" DB nipple set @ S00' 10-3/4", 68#, L-80, BTC, R3 ~ 2,318' MD / 2,193' TVD ~~ @ 26.24 degrees TD 13-3/8" hole Top of Ugnu C @ ~ 3,163' MD / 2,922' TVD Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak B @ _ __~ 3,434' MD / 3,110' TVD Lateral Entry Module #1 (L.EM), Baker, with seal bore and ZXP packer above. Top of West Sak A ~ ~ 3,497' MD / 3,149' TVD Tubing, 4-'~z" IBl'M, from LEM to A2 Liner, with seal stem and CAM('O 3.562" "DB" nipple. Seal bore and ZXP packer for A2 liner +)- 90' below "B" window 7-5/8", 40#, L-80, BTCM, R3 Csg @ 5,419' MD / 3,670' TVD --- 80 degrees TD 9-5/8" hole (I) Gas Lift Mandrel, CAMCO 4-I/2" z l" Model KBG- 2, one (1) set at 67 deg, X,XXX' MD, X,XX~ TVD. (I) Gas LiFl Mandrel, CAMCO 4-1/2" x I" Model KBG- ~ 2, one (I) set at 68 deg, X,XXX' MD, X.X XX TVD, (I) Sliding Sleeve, with 3.812" nipple, ane (I )joint above packer. X.XXX' MD, X,XXX' TVD 164 L2 "D" Sand Window - @ 4,546' MD / 3,518' TVD 77 degrees "D" Liner, 4-I/2", 12.8#, L80, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9%open area) 1641,1 "B"and Window a 4,239' MD 3,446' TVD 77 degrees "B" Liner, 4-I/2", 12.81, 0, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9% open area) A2 Sand Lin~4"'1~£ BTCM, R3 % slotted and''/z coastricracs,jor isolalioa IE-105 FINAL: Atil' NAI7 271!a.ting.: Sil1,:t0[I Atil' NAI) 27 Northing.. J.15) 9Ar1 I'ad t:lc~'arion fif.. I' AMtiI. Doyon Rig 141 Rig Floor (RF) ~a?, 0' Elevation: 94.t' AMSL I1-164 L2: 6-3/4" D sand lateral TD 11,648' MD / 3,570' TVD Angle 87 degrees ~--~. U-164 L I 6-3/4" "B TD 11,655' MD / 3 619' TVD Angle 87 degrees IJ-164. 6-3/4 A2 sand lateral Angle 87 degrees •i / 1 ` ~ 7E-D2 E-28 , ---- - -- ~ 1 -31 tE 779 -09 tL-28 ,r_.~ 1E-38 ~"~ ,~29 • 1J-1 ' /~ • tG-t 32 R • i~.g 1D-72~. y -t i~ ~ 1~ ~7 1D 38 -« 1D-, 2, ~~~ 1J-164 ,~~_,34 D-jjF `,,nVt~nmri 7 \ tE-1n5P81 ~ ~ ~, 2 26 ~- 1 D -~ Area of Review 7 E-34 ' i €=1 tlSL~ ,.~-+~~, 1J-168 '~ Slotted Liner ,\ ~a 12000 '~ 1 E-35 ltppp ` `,~_ 9~~ 4 _ ~ ,D-3e ..`,` ` 8000 `1 .~ - ~,,~r_ b--- ~ " 7 ago tE-„7L: ~o°°g `' - -' T11 N, R10E, UM p N ~ ~~-7 7 ~ ~~P-13 (' 'HSP-74 '~ I d I• T10N, R11 E, UM KRU 1 J-164 Proposed 1-Winj West Sak "A2" Sand 2051440 Cont,dentral wells are red S F D 10/5/2005 -~ iJ-n3 Feet 0 1 ,1700 0.:,0 3 r~0~~~ 4,00~~~ ~1J-154U • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~ ~ `~ ~f° PTD# ~~.~ ~ ~ 7" CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellb re segment of l~ r'~~ J LATERAL existing well k=- ~~Z3G~ I N '= , o. > AP Permit No, ~ (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. av Rev: 04101/05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-164L1 Program SER Well bore seg ~ PTD#:2051450 Company CONOCOPHILLIPS ALASI(A INC Initial ClasslType $ER / PEND GeoArea 890 _ __ Unit 1.1160__-. _ OnlOff Shore On Annular Disposal n Administration 1 Permit-fee attached_ - _ _ _ _ N_A_ - _ _ West Sak B Sand multilateral_ injection well_segment;_fee waived per_20 AAC_25,005(e). - - _ - _ _ 2 Lease number appropriate_-_____-____-______ _______ ____-__Yes_ ___--____-_____ 3 Uniquewell_nameandnumber____________________________ __________Yes- -_____-_________-__-___--__ ---------------------------------------------- 4 Welllocat_edina_defined_pool___________________-._______ ______-___Yes- ______KRUWest_Sak_0_ilPgol,governed_by Consen!aiion_OrderNo,4066_-___--_-__-.______---_ 5 Well located proper distance from drilling unit_boundary. Yes _ - Well is more-than_ 500 feet from an external property line_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --------------- 6 Well located properdistance_fromotherwells___________________ __________Yes_ __--_Norestrictionsas_to well spacing in CO.4.06B._-______-._________--_____.____--____ 7 Sufficient acreage ayail_able in_drilling unit- _ _ _ Yes - - - - No restrictions as_to well spacing except that no_pay shall be opened in a well closer _ - - 8 If_deYiated,is_wellboreplat_included_________________________ __________ Yes_ _.____than500feetto_a_Wexlernal_propertyline._____-_____-____--_____. ------------------ 9 Operatoronlyaffectedparty__-.______________________ _______Yes_ __ ---------------------------------------------------------------------- 10 Ope[atorhas-appropriate_bondinforce----------------------- -----_-_-Yes_ -----------.----_---_--_- ------------------------------------------------ 11 Permit can be issued without conseruatioh order Yes Appr Date 12 Permitcan be issued without administrative_appr_oyal - - _ _ . _ _ - Yes - - - - - - - - - SFD 10/5/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by_Injection Orrder# (put_Ip# in_ comments)_(For_ Yes Area Injection Order IJo._2B- _ - _ _ - 15 Allwellswithin1/4_mil_earea_ofreyiewidentified(Forservicewellonly)____ __-___--_Yes_ _____-KRU1D-131_isabout750'away._____________________________--_______________- 16 Pre-produced injector; duration of pre-p[oduction less than_ 3 months_ (For service well only) _ _ Yes _ _ _ _ - _ _ Well may be_ pn-produced for about 1_ month per Mike Greener, CPAI,101512005._ .. _ _ _ _ _ - - _ _ _ _ . _ _ _ _ _ 17 ACMP-Finding of Consiskency-hasbee_nissued_forthisproject_________ _________ NA__ _-___-_--_________-____---_____--____-- Engineering 18 _C_onductorstring_provided__ ___________________________ ___-___--_ NA__ ______Conductor_set_inmotherbore,_1J-164(205-144).,______-___________-_____--_____-___-- 19 Surface casing_protects all known U$DWs _ . - _ - - NA_ - . - All a uifers exem ted, 40 CFR_147.1Q2 (b)(3)._ . ~ p - 20 CMT_vol_ atlequate_to ci[cul_ate-on cond_ucto[& surf_csg - _ _ _ _ . _ NA- - - _ Surface eosin set in mgtherbore. - 9- - 21 CMT_vol-adequate_totie-in long stringt_osu_rfcsg__________________ __________ No__ __-_____-.__________, - - - - 22 CMT-will coverall know_n_productiye horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- - - _ _ _ _ _ Slotted liner c4mpletfonplanned.- Any hydrocarbon_zones above WS will be cemented. - _ _ _ _ _ _ - - _ _ 23 Casing designs adequate for G, T B &_pe-rmafrost_ _ - _ _ _ - - NA_ Motherbore tubulars meet_design requirements.. NA for slotted liner._ - - - _ 24 Adequate tankage_or reserve pit _ - _ - - _ _ - _ - - - - - Yes - - - - - Rig is_equipped with steel-pits. No reserve_pitplanned, All waste to approved annulus_or disposal well. - 25 Ifa_re-drill,has-a_1.0-403 for abandonmenkbeenapproved__---___--_ __--_ -NA__ _________________________________--_____.-____-__-_____-______-____--___ 26 Adequate weNbore separation-proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ Yes - _ - - - _ -Proximity analysis performed. Nearest wellbore.is mgtherbore X12 tud pelow. Vertical separation increases._ - - - 27 If_diveCterrequired,doesitmeetregu_lotions_____________________ __________ NA-- ____-BOPStackwillalready_beinplaee,___-_____.-_. ----__-.---__----__-- ------ Appr Date 28 Drilling fluid_program Schematic & equip list adequate- - _ _ Yes - - - - - -Maximum expected fo[mation pressure ~8 7 EMW._ 8.6 ±ppg planned in WS.-Weight adjusted as_necessary.- - /¢/2005 29 BOPEs, do they meet regulation - - - - - - - - - - -Yes - - - - - - - V~Y+'Jt` 30 BOPE-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ MASP calculated at 1230 psi. 3000_psi_BOP testproposed.- _ _ _ _ - - - _ _ - _ - _ _ _ _ _ _ - - _ _ _ - _ _ - _ _ - - _ 31 Choke.manifoldcomplieswlAPl_RP-53(May84)_________________ _________Yes- _____-_____-_______-___-___________--___-__-_._________-______-____--__ 32 Work will occur without operation shutdown_____________________ _________Yes_ ___-_-____-______-_- - - - 33 Is presence_ of H2S gas_probable - - - - - - . - - _ - - .. _ _ _ No- - . H2S has not been reported in WS._ Ry is equippetl_with sensors and alarms, _ _ _ - _ 34 Mechanical-condition of wells within AOR verified (For_s_ervice well onlya - _ - . _ _ - - Yes - _ - 2 wells in_AOR._ No issues identified. . Geology 35 Permit_canbeissuedw/ohydrogen-sulfidemeasures____________ _______.-Yes_ _____----__-----__- --_ __.---__------_-..-___-_-_.--__---.__-.__ 36 _D_ata_presented on_ pote_ntlal overgres_sur_e zones - - - - Yes - . _ None expected;_estimated r_eservojrpressure is 8,7_ppg EMW. _ _ Appr Date 37 Seismicanalysisofshallowgas_zones________________________ __--__-__ NA__ -__-__Multilaterakwellbranch.--_---_._--___----_--.--_-_.--__---.__----.-__..-__ SFD 10!512005 38 Seabed condition survey_(if off-shore) _ - 39 _ Contact name/phone for w-eekly progress_reports [exploratory onlyJ_ _ - _ NA_ . - - - _ Geologic Engineering P i Date Date: Date Multilateral well branch - in ector within West Sak B sand. 1 Commissioner: Commissioner: Co sio ~~~ a-Id~~ ~~lb-~-~~ ~a ~-~.~ • • • Well History File APPENDIX information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Y • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 23 09:58:45 2006 Reel Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004025932 T. CALVIN M. THORTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services 1J-164 L1 500292327860 ConocoPhillips Alaska, Inc. Sperry Drilling Services 23-MAR-06 MWD RUN 4 MWD RUN 5 MW0004025932 MW0004025932 T. CALVIN T. CALVIN M. THORTON M. THORTON 35 11N l0E 1919 2517 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2332.0 7.875 4605.0 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. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL) THE PURPOSE OF MWD RUN 4 WAS TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 4593'MD/3499'TVD), MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. MWD RUN 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,4,5 REPRESENT WELL 1J-164 L1 WITH API#:50-029-23278-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11472'MD/3613'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTTVITY (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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2297.0 11406.5 FET 2310.0 11414.0 • RPD 2310.0 11414.0 RPS 2310.0 11414.0 RPM 2310.0 11414.0 RPX 2310.0 11414.0 ROP 2342.5 11472.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 2297.0 4 4605.5 5 4632.0 REMARKS: MERGED MAIN PASS. MERGE BASE 4605.0 4632.0 11472.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 11472 6884.5 18351 2297 11472 RPD MWD OHMM 4.06 2000 74.3876 18209 2310 11414 RPM MWD OHMM 0.41 2000 56.2732 18209 2310 11414 RPS MWD OHMM 3.75 2000 49.3119 18209 2310 11414 RPX MWD OHMM 2.2 2000 51.3147 18209 2310 11414 FET MWD HOUR 0.2 206.24 1.00503 18209 2310 11414 GR MWD API 22.29 124.57 64.477 18220 2297 11406.5 ROP MWD FT/H 0.85 641.18 181.697 18260 2342.5 11472 First Reading For Entire File..........2297 Last Reading For Entire File...........11472 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06f03f23 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.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2297.0 4605.0 FET 2310.0 4605.0 RPX 2310.0 4605.0 RPS 2310.0 4605.0 RPM 2310.0 4605.0 RPD 2310.0 4605.0 ROP 2342.5 4605.0 LOG HEADER DATA DATE LOGGED: 06-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4605.0 TOP LOG INTERVAL (FT) 2342.0 BOTTOM LOG INTERVAL (FT) 4605.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.4 MAXIMUM ANGLE: 81.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT): 2332.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) : 9.10 MUD VISCOSITY (S): 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) • MUD AT MEASURED TEMPERATURE (MT) 2.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 115.0 MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.000 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 2297 4605 3451 4617 RPD MWD020 OHMM 4.06 2000 33.8795 4591 RPM MWD020 OHMM 0.41 114.25 14.1215 4591 RPS MWD020 OHMM 3.75 1217.56 14.2192 4591 RPX MWD020 OHMM 2.2 80.99 12.4502 4591 FET MWD020 HOUR 0.2 52.32 1.34027 4591 GR MWD020 API 22.29 111.65 69.3501 4617 ROP MWD020 FT/H 7.32 641.18 176.007 4526 First Reading For Entire File..........2297 Last Reading For Entire File...........4605 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...,...06/03j23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 First Last Reading Reading 2297 4605 2310 4605 2310 4605 2310 4605 2310 4605 2310 4605 2297 4605 2342.5 4605 Physical EOF • • File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4605.5 4632.0 LOG HEADER DATA DATE LOGGED: 13-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4632.0 TOP LOG INTERVAL (FT) 4605.0 BOTTOM LOG INTERVAL (FT) 4632.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2332.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 85.0 MUD PH: •® MUD CHLORIDES (PPM): 94000 FLUID LOSS (C3) • 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 96.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: . Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4605.5 4632 4618.75 54 4605.5 4632 ROP MWD040 FT/H 9.81 43.3 29.7648 54 4605.5 4632 First Reading For Entire File..........4605.5 Last Reading For Entire File...........4632 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 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.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENTe .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4605.5 11414.0 RPD 4605.5 11414.0 GR 4605.5 11406.5 RPM 4605.5 11414.0 FET 4605.5 11414.0 RPS 4605.5 11414.0 ROP 4632.5 11472.0 n LOG HEADER DATA DATE LOGGED: 17-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11472.0 TOP LOG INTERVAL (FT) 4632.0 BOTTOM LOG INTERVAL (FT) 11472.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.1 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2332.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 129.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 _ _ FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4605.5 11472 8038.75 13734 4605.5 11472 RPD MWD050 OHMM 6.03 2000 88.044 13618 4605.5 11414 RPM MWD050 OHMM 5.52 2000 70.4837 13618 4605.5 11414 RPS MWD050 OHMM 5.51 2000 61.1426 13618 4605.5 11414 RPX MWD050 OHMM 5.41 2000 64.417 13618 4605.5 11414 FET MWD050 HOUR 0.22 206.24 0.892011 13618 4605.5 11414 GR MWD050 API 31.36 124.57 62.8231 13603 4605.5 11406.5 ROP MWD050 FT/H 0.85 564.97 184.18 13680 4632.5 11472 First Reading For Entire File..........4605.5 Last Reading For Entire File...........11472 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06j03j23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
