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Home My WebLink About205-0361. 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 Pumping 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 11285'feet None feet true vertical 3456' feet 4080' feet Effective Depth measured 11285'feet 4194', 4200', 4355'feet true vertical 3456' feet 3467', 3469', 3508' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3475' TVD Packers and SSSV (type, measured and true vertical depth) 4021' MD 4017' MD 4190' MD N/A 3438' TVD 3437' TVD 3475' 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. 12. Stimulation or cement squeeze summary: Intervals treated (measured):RPPG pumped down 1J-154L1 (Injector) (See Well Events.) Treatment descriptions including volumes used and final pressure: N/A Packer: Baker SBE Seal Assembly Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 265-6471Staff Well Interventions Engineer Alternating Slotted Liner: 4406-11217' Alternating Slotted Liner: 3517-3456' 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 205-036 50-029-23254-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL 0025662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-154L1 Plugs Junk measured Length Production B Sand Liner 5138' 6882' Casing 3649' 4-1/2" 5165' 11252' 3456' 2271' 108'Conductor Surface Intermediate 20" 10-3/4" 79' 2300' 2199' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:03 pm, Aug 20, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.20 11:25:19-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne J.Lau 11/4/25 DSR-9/11/25 RBDMS JSB 082525 DTTMSTART JOBTYP SUMMARYOPS 7/21/2025 ACQUIRE DATA PUMP FULL BORE RPPG TO MBE AT 8389' RKB IN THE B SAND LATERAL. PUMPED 13933 LBS OF DAQING RPPG PRODUCT, FLUSH CALLED @ 913 PSI AND 835 BBL JSV. SLIGHT PSI INCREASE TO MAX PSI 935, JSV 835 BBLS. WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1J-154/ 1J-159 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-154 haggea Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Plug, set Diverter, set IsoSleeve. 1J-154 5/9/2025 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: B-LEM PROFILE SEVERELY ERODED. NEED TO SET GENTLY WITHOUT HAMMER OR AGITATOR. SEE WSR 5/7/25 5/9/2025 famaj NOTE: Multi-lateral Well: 1J-154 (A-SAND), 1J-154L1 (B-SAND), 1J-154L2 (D-SAND) 10/30/2005 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 40" 20 19.12 29.0 108.0 108.0 94.00 H-40 WELDED SURFACE 10 3/4 9.95 28.8 2,300.0 2,199.2 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 26.8 5,165.0 3,648.9 29.70 L-80 BTCM D-SAND LINER LEM 4 1/2 3.88 4,017.0 4,219.2 3,481.5 12.60 L-80 IBTX B-SAND LINER LEM 4 1/2 3.96 4,189.5 4,511.2 3,538.3 12.60 L-80 IBT A LINER 4 1/2 3.96 4,463.9 8,126.0 3,627.3 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 … 4,047.5 Set Depth … 3,443.2 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 11" X 4.5" w/4.909" MCA TOP CONNECTION 3.958 489.9 489.8 1.75 NIPPLE 5.984 CAMCO DB-6 NIPPLE no go CAMCO DB-6 3.875 2,393.9 2,289.9 14.08 GAS LIFT 6.437 CAMCO KBUG CAMCO KBUG 3.860 3,766.2 3,362.9 65.92 GAS LIFT 6.437 CAMCO KBUG CAMCO KBUG 3.860 3,971.9 3,427.1 77.33 SLEEVE-C 5.510 BAKER CMU Sliding Sleeve W/DB PROFILE closed 11/18/2005 BAKER CMU 3.813 4,019.2 3,437.3 77.87 LOCATOR 5.520 BAKER LOCATOR BAKER 3.875 4,020.9 3,437.6 77.89 SEAL 4.740 BAKER SBE SEAL ASSEMBLY BAKER 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) 4,066.0 3,446.9 78.30 ISO-SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM (19' OAL) 5/8/2025 2.590 4,080.0 3,449.8 78.00 FISH TRACTOR ARM 1" x 21" TRACTOR ARM, BELIEVED TO BE IN L2 LEM - LOST 2/5/2006 2/5/2006 0.000 4,360.0 3,510.2 80.57 DIVERTER TYPE-I DIVERTER SET IN B- SAND LEM (18.6' OAL) 5/7/2025 4,430.7 3,522.9 78.81 PLUG DB PLUG (3.562" OD X 2' LONG) 5/7/2025 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) 2,393.9 2,289.9 14.08 1 GAS LIFT DMY BK 1 0.0 3/8/2006 0.000 3,766.2 3,362.9 65.92 2 GAS LIFT DMY BK 1 0.0 3/8/2006 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) 4,017.0 3,436.8 77.85 PACKER 6.550 ZXP LINER TOP PACKER 5.5x7.625 4.950 4,035.9 3,440.8 78.06 SBR 6.280 190-47 SEAL BORE RECEPTACLE 190-47 4.750 4,055.5 3,444.8 78.29 XO BUSHING 6.040 XO BUSHING Hydril 563x4.50 Hydril 563 3.950 4,056.9 3,445.1 78.31 SWIVEL 5.770 LINER CASING SWIVEL 3.960 4,189.5 3,474.5 76.35 PACKER 6.550 D-SAND ZXP LINER TOP PACKER 5.5x7.625 4.950 4,208.5 3,479.0 76.32 SBR 6.260 B-SAND 109-47 SEAL BORE RECEPTACLE 109-47 4.750 4,227.9 3,483.6 76.30 XO BUSHING 6.040 B-SAND XO BUSHING 5.5x4.5 Hydril 563 3.950 4,229.2 3,483.9 76.29 SWIVEL 5.770 BAKER CASING SWIVEL BAKER 3.960 4,433.2 3,523.4 78.75 NIPPLE 5.570 CAMCO DB6 NIPPLE CAMCO DB6 3.563 4,464.8 3,529.6 78.83 XO THREAD 4.500 3.958 4,463.9 3,529.4 78.82 PACKER 6.540 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.950 4,483.0 3,533.1 79.09 NIPPLE 6.070 "RS" Packoff Seal Nipple 5.5" 4.875 4,515.1 3,539.0 79.53 XO BUSHING 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 8,080.0 3,628.1 91.17 Swell Packer 6.300 4-1/2" Swell Packer 3.960 1J-154, 8/11/2025 2:27:14 PM Vertical schematic (actual) A LINER; 4,463.9-8,126.0 SLOTS; 7,826.0-8,072.0 SLOTS; 7,055.0-7,486.0 SLOTS; 6,433.0-6,870.0 SLOTS; 5,412.0-6,124.0 PRODUCTION; 26.8-5,165.0 B-SAND LINER LEM; 4,189.5- 4,511.2 PLUG; 4,430.7 DIVERTER; 4,360.0 D-SAND LINER LEM; 4,017.0- 4,219.2 FISH; 4,080.0 FISH; 4,080.0 ISO-SLEEVE; 4,066.0 GAS LIFT; 3,766.2 GAS LIFT; 2,393.9 SURFACE; 28.8-2,300.0 NIPPLE; 489.9 CONDUCTOR Insulated 40"; 29.0-108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 10/30/200 5 Other Elev… 1J-154 ... TD Act Btm (ftKB) 9,063.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292325400 Wellbore Status INJ Max Angle & MD Incl (°) 93.50 MD (ftKB) 5,744.62 WELLNAME WELLBORE1J-154 Annotation Last WO: End DateH2S (ppm) 25 Date 9/4/2017 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,412.0 6,124.0 3,661.0 3,640.8 WS A2, 1J-154 10/12/2005 32.0 SLOTS ALL SLOTS A-LINER = Alternating solid/slotted pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 6,433.0 6,870.0 3,641.6 3,638.3 WS A2, 1J-154 10/12/2005 32.0 SLOTS 7,055.0 7,486.0 3,636.4 3,639.0 WS A2, 1J-154 10/12/2005 32.0 SLOTS 7,826.0 8,072.0 3,635.4 3,628.2 WS A2, 1J-154 10/12/2005 32.0 SLOTS 1J-154, 8/11/2025 2:27:14 PM Vertical schematic (actual) A LINER; 4,463.9-8,126.0 SLOTS; 7,826.0-8,072.0 SLOTS; 7,055.0-7,486.0 SLOTS; 6,433.0-6,870.0 SLOTS; 5,412.0-6,124.0 PRODUCTION; 26.8-5,165.0 B-SAND LINER LEM; 4,189.5- 4,511.2 PLUG; 4,430.7 DIVERTER; 4,360.0 D-SAND LINER LEM; 4,017.0- 4,219.2 FISH; 4,080.0 FISH; 4,080.0 ISO-SLEEVE; 4,066.0 GAS LIFT; 3,766.2 GAS LIFT; 2,393.9 SURFACE; 28.8-2,300.0 NIPPLE; 489.9 CONDUCTOR Insulated 40"; 29.0-108.0 KUP INJ 1J-154 ... WELLNAME WELLBORE1J-154 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-154L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S & PERF 1J-154L1 7/19/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: 7040 LBS RPPG PUMPED INTO MBE 7/6/2018 aappleh NOTE: MULTI-LATERAL WELL: 1J-154 (A-SAND), 1J-154L1 (B-SAND), 1J-154L2 (D-SAND) 10/30/2005 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B LINER 4 1/2 3.96 4,370.0 11,252.5 3,455.9 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) 4,080.0 3,449.8 78.00 FISH TRACTOR ARM 1" x 21" TRACTOR ARM, BELIEVED TO BE IN L2 LEM - LOST 2/5/2006 2/5/2006 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) 4,400.0 3,516.3 83.27 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 11,230.6 3,456.1 90.53 XO Reducing 4.500 4-1/2" IBT Box x 3-1/2" IBT Pin Crossover 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,406.0 4,560.0 3,517.0 3,514.2 WS B, 1J-154L1 10/20/2005 32.0 SLOTS ALL SLOTS B LINER = 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 4,871.0 5,145.0 3,522.0 3,517.8 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 5,363.0 5,762.0 3,518.1 3,508.9 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 6,067.0 6,560.0 3,503.6 3,492.4 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 6,806.0 7,301.0 3,490.9 3,482.0 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 7,544.0 8,158.0 3,475.3 3,478.0 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 8,393.0 8,398.0 3,484.5 3,484.8 WS B, 1J-154L1 7/1/2018 6.0 APERF SLB 2" HSD, 6 SPF, 60 DEG PH, 2006 PF HMX 8,466.0 8,961.0 3,487.1 3,485.2 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 9,209.0 9,703.0 3,485.3 3,469.5 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 10,012.0 10,506.0 3,468.1 3,464.0 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 10,752.0 11,217.0 3,462.9 3,456.2 WS B, 1J-154L1 10/20/2005 32.0 SLOTS 1J-154L1, 8/11/2025 2:27:15 PM Vertical schematic (actual) B LINER; 4,370.0-11,252.5 SLOTS; 10,752.0-11,217.0 SLOTS; 10,012.0-10,506.0 SLOTS; 9,209.0-9,703.0 SLOTS; 8,466.0-8,961.0 APERF; 8,393.0-8,398.0 SLOTS; 7,544.0-8,158.0 SLOTS; 6,806.0-7,301.0 SLOTS; 6,067.0-6,560.0 SLOTS; 5,363.0-5,762.0 SLOTS; 4,871.0-5,145.0 SLOTS; 4,406.0-4,560.0 B-SAND LINER LEM; 4,189.5- 4,511.2 PRODUCTION; 26.8-5,165.0 D-SAND LINER LEM; 4,017.0- 4,219.2 FISH; 4,080.0 FISH; 4,080.0 ISO-SLEEVE; 4,066.0 GAS LIFT; 3,766.2 GAS LIFT; 2,393.9 SURFACE; 28.8-2,300.0 NIPPLE; 489.9 CONDUCTOR Insulated 40"; 29.0-108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 10/30/200 5 Other Elev… 1J-154L1 ... TD Act Btm (ftKB) 11,285.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292325460 Wellbore Status INJ Max Angle & MD Incl (°) 94.30 MD (ftKB) 4,518.50 WELLNAME WELLBORE1J-154 Annotation Last WO: End DateH2S (ppm) 25 Date 9/4/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-154L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: SET TYPE-II ISO SLEEVE 1J-154L2 4/22/2018 raffep Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1J-154 (A-SAND), 1J-154L1 (B-SAND), 1J-154L2 (D-SAND) 10/30/2005 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 LINER 4 1/2 3.96 4,074.3 10,917.8 3,361.1 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) 4,080.0 3,449.8 78.18 FISH TRACTOR ARM 1" x 21" TRACTOR ARM, BELIEVED TO BE IN L2 LEM - LOST 2/5/2006 2/5/2006 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) 4,104.8 3,454.0 82.04 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 10,896.9 3,362.8 94.87 BENT JT 3.500 3-1/2", 9.2 ppf, L-80, IBT (Bent Joint) 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,111.0 4,539.0 3,454.8 3,452.0 WS D, 1J-154L2 10/28/2005 32.0 SLOTS ALL SLOTS D-LINER = Alternating slotted/solid pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,813.0 5,304.0 3,465.3 3,454.8 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 5,550.0 5,980.0 3,447.1 3,428.2 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 6,258.0 6,752.0 3,420.2 3,406.9 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 7,027.0 7,489.0 3,405.6 3,396.5 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 7,768.0 8,106.0 3,396.4 3,400.6 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 8,354.0 8,849.0 3,413.0 3,410.6 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 9,125.0 9,587.0 3,398.0 3,368.8 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 9,866.0 10,359.0 3,358.8 3,375.9 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 10,574.0 10,881.0 3,383.2 3,364.2 WS D, 1J-154L2 10/28/2005 32.0 SLOTS 1J-154L2, 8/11/2025 2:27:13 PM Vertical schematic (actual) D LINER; 4,074.3-10,917.8 SLOTS; 10,574.0-10,881.0 SLOTS; 9,866.0-10,359.0 SLOTS; 9,125.0-9,587.0 SLOTS; 8,354.0-8,849.0 SLOTS; 7,768.0-8,106.0 SLOTS; 7,027.0-7,489.0 SLOTS; 6,258.0-6,752.0 SLOTS; 5,550.0-5,980.0 SLOTS; 4,813.0-5,304.0 SLOTS; 4,111.0-4,539.0 FISH; 4,080.0 PRODUCTION; 26.8-5,165.0 D-SAND LINER LEM; 4,017.0- 4,219.2 GAS LIFT; 3,766.2 GAS LIFT; 2,393.9 SURFACE; 28.8-2,300.0 NIPPLE; 489.9 CONDUCTOR Insulated 40"; 29.0-108.0 KUP INJ KB-Grd (ft) 31.01 RR Date 10/30/200 5 Other Elev… 1J-154L2 ... TD Act Btm (ftKB) 10,964.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292325461 Wellbore Status INJ Max Angle & MD Incl (°) 95.59 MD (ftKB) 10,779.46 WELLNAME WELLBORE1J-154 Annotation Last WO: End DateH2S (ppm) 25 Date 9/4/2017 Comment C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-08_16029_KRU_1J-154L1_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16029 KRU 1J-154L1 50-029-23254-60 Injection Profile 08-May-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 205-036 T40429 5/16/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 15:05:00 -08'00' 29326 RECEIVED • 20 50 WELL LOG MAY 2 9 2018 TRANSMITTAL AOGCC II. � PROACTIVE DiAgNosTIC SERVICES, INC. C 03(.0O To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 1) Injection Profile 04-May-18 1J-154L1 1 Report /CD 50-029-23254-60 2) UPI(.571 SI9ned : � Date .. � Print Name: ra 1 mpg PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(d MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSbeets\ConocoPhillips_Transmit.docx IIS • OFTy� \ I�y, sem THE APE Alaska Oil and Gas Of A T A Conservation Commission 1 1L1 l 333 West Seventh Avenue Anchorage, Alaska 99501-3572 �*h GOVERNOR BILL WALKER 9 Main: 907.279.1433 ®� LAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. 5CpaiNE® MAY 2 4 2O1& PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-154L1 Permit to Drill Number: 205-036 Sundry Number: 318-214 Dear Mr. 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, LA123T1--- Hollis S. French Chair DATED this Z3 day of May, 2018. ' I,I ; NO 141O OD" RECEIVED • 0 0 STATE OF ALASKA AV 2 2 20$31 /1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate I J• Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TrtmtU• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 205-036 3.Address. Stratigraphic ❑ Service 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 50-029-23254-60 7.If perforating: _ 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? �� /�y�" KRU 1J-154L1 • .2 Will planned perforations require a spacing exception? Yes ❑ No ❑ t.2-7z41) ) 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25662 ' 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): 11,285' ' 3,456' • 11285 3456 1500psi 4431 4080 Casing Length Size MD TVD Burst Collapse Conductor 79' 20" 108' 108' Surface 2,271' 103/4 2,300' 2,199' Production 4,320' 7 5/8 4,347' 2,649' Liner 6,882' 4 1/2 11,252' 3,456' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4406'-11217' 3517'-3456' 4.500" L-80 4,047' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers=none N/A SSSV: =none N/A 12.Attachments: Proposal Summary 2 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 6/20/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ 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 / Contact Phone: (907)265-6471 Authorized Signature: ff. �, - Date: MIS 1 f i COMMISSION USE ONLY Conditions of approval: otify Commis ion so that a representative may witness Sundry Number: 31 —' 11(4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No 1 10,1q Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: /6 U 4 4 I of 2 R8� �` 622g.T-..., APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S IZ3AtJ VT-I- 5723/18 I NAL /elA(` 0 R I G Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 5-22:45- • a KUP INJ 1J-154 I ConocoPhillips Well tes Ma 8 MD TD Wellbore Field Name Wellbore Status ncl(°) (ftKB) Act Btm(ftKB) AI -,F.E.I'I 500292325400 WEST SAK INJ 93 50 5,744.62 9,063.0 CanxoMnt • • LPs Comment H2S(ppm) Date Annotation End Date IKB-Grd(ft) 'Rig Release Date ... SSSV:NIPPLE Last WO: 31.01 10/30/2005 1,1-154,5/17/2010 6.45.43 AM Last Tag • Vertical schematic(actuals Annotation Depth(ftKB) End Date Last Mod By Last Tag: haggea • HANGER;22.2 111V111 Last Rev Reason I• if a l Annotation End Date Last Mod By . e r. M . a I r W REV REASON:SET DB PLUG,TYPE-I DIVERTER AND TYPE-II ISO SLEEVE 4/22/2018 raffep Casing Strings Casing Description OD(in) ID 5n) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 40';- , �CONDUCTOR Insulated 20 19.124 29.0 108.0 108.0 94.00 H-40 WELDED 29.0-108.0 40" NIPPLE;4e9.9 - Casing Description OD(in) ID(In) -Top(ftKB) -Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread III SURFACE 103/4 9.950 28.8 2,300.0 2,199.2 45.50 L-80 BTC _ 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 75/8 6.875 26.8 5,165.0 3,648.9 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE;280-2,300.0 L D-SAND LINER LEM 41/2 3.880 4,017.0 4,2192 3,481.5 12.60 L-80 IBTX Liner Details GAS LIFT;2,393.9 III Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel(°) Item Des Com (in) 4,017.0 3,436.8 77.85 PACKER 'ZXP LINER TOP PACKER 5.5x7.625 4.950 4,035.9 3,440.8 78.06 SBR 190-47 SEAL BORE RECEPTACLE ' 4.750 GAS LIFT;3,766.2 _ 4,055.5 3,444.8 78.29 XO BUSHING XO BUSHING Hydri)563x4.50 3.950 __ 4,056.9 3,445.1 78.31 SWIVEL LINER CASING SWIVEL 3.960 i-� 4,063.6' SLEEVE-C;3,9]1 9 3,446.4 78.35 HANGER 'LEM ABOVE HOOK HANGER 3.950 4,074.3 3,448.6 78.12 HANGER 'LEM INSIDE HOOK HANGER 3.688 4,216.1 3,480.8 76.31 SEAL 'BAKER SEAL ASSEMBLY 3.880 Casing Deseription IOD(in) IID(In) I Top(ftKB) !Set Depth(ftKB) Set Depth(TVD)...I WtlLen(1...IGrade I-Top Thread LOCATOR;4,0192 • LINER LEM 4 1/2 3.958 4,189 5 4,51121 3,538.31 12.601L-80 I IBT I- Liner Details SEAL;4,020.9 -E ' rer Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) i' 4,189.5 3,474.5 76.35 PACKER D-SAND ZXP LINER TOP PACKER 5.5x7.625 4.950 -r 4,208.5 3,479.0 76.32 SBR B-SAND 109-47 SEAL BORE RECEPTACLE 4.750 4,227.9 3,483.6 76.30 XO BUSHING B-SAND XO BUSHING 5.5x4.5 3.950 4,229.2 3,483.9 76.29 SWIVEL BAKER CASING SWIVEL 3.960 ISO SLEEVE;4,088.0, 4,359.4 3,510.1 80.58 HANGER BAKER LEM ABOVE HOOK HANGER 3.950 FISH;4,080.0 FISH;4,080.01 4,370.0 3,511.9 80.32 HANGER BAKER LEM INSIDE HOOK HANGER 3.950 4,433.2 3,523.4 78.75 NIPPLE CAMCO DB6 NIPPLE 3.563 ( 4,507.9 3,537.7 79.43 SEAL BAKER B-SAND SEAL ASSEMBLY 3.890 Casing Description IOD(in) !ID(in) ITop(ftKB) lSet Depth(ftKB) ISet Depth(ND)...I WtlLen(I...I Grade ITop Thread A LINER 4112 3.958 4,4639 8,126.0 3,627.3 12.60 L-80 IIBT • Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Com (in) 4,463.9 3,529.4' 78.82 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.950 o-SAND LINER LEM, 0182 4,483.0 3,533.1 ' 79.09 NIPPLE '"RS"Packoff Seal Nipple 5.5" 4.875 #_= 4,485.8 3,533.6' 79.13 HANGER 'FlexLock Liner Hanger 5.5"X 7.6" 4.853 4,495.7 3,535.5' 79.26 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.25"OD 4.750 4,515.1 3,539.0' 79.53 XO BUSHING XO Bushing 3.92"ID,6.02 OD 3.920 8,080.0 3,628.1 91.17 Swell Packer 4-1/2"Swell Packer 3.960 Tubing Strings DIVERTER;4,350.0 Tubing Description Mal./..11D(in) Top(ftKB)2221 Set Depth(ft..Set Depth(ND)(...1 Wt(lb/It) 601 Grade Top Connection TUBING 'String 42 3.9581 4,047.51 3,443.2 12 L-80 IIBTM Completion Details Top(TVD) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Com ID(in) PLUG;4,430.7 22.2 22.2 0.00 HANGER VETCO GRAY 11"X 4.5"w/4.909"MCA TOP CONNECTION 3.958 489.9 489.8 1.75 NIPPLE CAMCO DB-6 NIPPLE no go 3.875 3,971.9 3,427.1 77.33 SLEEVE-C BAKER CMU Sliding Sleeve W/DB PROFILE closed 11/18/2005 3.813 4,019.2 3,437.3 77.87 LOCATOR BAKER LOCATOR 3.875 I 4,020.9 3,437.6 77.89 SEAL BAKER SBE SEAL ASSEMBLY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl B-SAND LINER LEM;4,159.5- Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 4,511'2 4,066.0 3,446.9 78.30 ISO SLEEVE TYPE-II ISO SLEEVE SET ACROSS D-SAND LEM 4/22/2018 2.590 4,080.0 3,449.8 78.00 FISH TRACTOR ARM 1"x21"TRACTOR ARM,BELIEVED 2/5/2006 0.000 TO BE IN L2 LEM-LOST 2/5/2006 4,360.0 3,510.2 80.57 DIVERTER TYPE-I DIVERTER SET IN B-SAND LEM 4/22/2018 3.100 4,430.7 3,522.9 78.81 PLUG DB PLUG WITH PRONG(PRONG 2.72"OD X 8.19' 4/20/2018 0.000 PRODUCTION;25.8-5,185.0 TOP=44271 SET IN DB6 NIPPLE 1 Perforations 8 Slots SLOTS;8,412.06,124.0 Shot Dens Top(TVD) Btm(TVD) (shots/ft SLOTS;8,433.06,870.0 4- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com 5,412.0 6,124.0 3,661.0 3,640.8 WS A2,1J-154 10/12/2005 32.0 SLOTS ALL SLOTS A-LINER= Alternating solid/slotted pipe 0.125"x2.5"x 32 spf SLOTS;7,055.0-7,486.0@ 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 h.non • - slotted ends SLOTS;7,828.06,072.0 6,433.0 6,870.0 3,641.6 3,638.3 WS A2,1J-154 10/12/2005 32.0 SLOTS _ • „-- 7,055.0 7,486.0 3,636.4 3,639.0 WS A2,10-154 10/12/2005 32.0 SLOTS • • 7,826.0 8,072.0 3,635.4 3,628.2 WS A2,10-154 10/12/2005 32.0 SLOTS • • A LINER;4,4E3.9-8,126.0 KUAaP:INJ •• 1J-154 ConocoPhillips • AL-1,,,,1,II). can« lei 1J-154,5/17/2018 6:45:44 AM Vertical schematic(actual) HANGER,22.2 M or I.I'm . . IIA Mandrel Inserts St CONDUCTOR Insulated 40:- II III I 29.0-108.0 10 N Top(TVD) Valve Latch Port Size TRO Run NIPPLE,489.9 r Top(kKB) (kKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,393.9 2,289.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/8/2006 i 2 3,766.2 3,362.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/8/2006 Notes:General&Safety SURFACE;28.8-2,300.0 End Date Annotation 10/30/2005 NOTE:Multi-lateral Well: 1J-154(A-SAND),1J-154L1(B-SAND),1J-154L2(D-SAND) GAS LIFT;2,393.9 2/7/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV I GAS LIFT;3,766.2 :IN SLEEVE-C;3,971.9 LOCATOR;4,019.2 iT. :dI SEAL;4,020:9 - - - iit`9 ISO SLEEVE;1,066 0, FISH;4,080.01 FISH;4,080.0 D-SAND LINER LEM;4,017.0 4,219.2 , ar DIVERTER;4,3600 r7r 11.. i I I PLUG;4,430.7 70C, I 11„Oyyc.. 1,_,, B-SAND LINER LEM;4,189.5 I r 4,511 2 m. PRODUCTION;28.85,165.0 SLOTS;5,412.05,124.0 SLOTS;6.433.06.870.0 SLOTS;7,055.0-7,488.0 1 1 SLOTS;7,826.05,072.0 A LINER;4,483.9-8,126.0 KUNJ 1J-154L1 1,-,ConocoPhillips Well s Mae&MD TD Wellbo Field Name Wellbore Status ncl(° D(ftKB) Act Btm(ftKB) • Alaska,InC. 500292325460 WEST SAK INJ 94.30 4,518.50 11,285.0 .00050Dhdhpu Comment H2S(ppm) Date Annotation End Date IKB-Grd(ft) -Rig Release Date ... SSSV:NIPPLE Last WO: 31.01 10/30/2005 1J-1540,5/17/2018 7:26:25 AM Last Tag Vertical schematic raceme) Annotation Depth(ftKB) End Date Last Mod By Last Tag: Imosbor HANGER;222 W.T ail Last Rev Reason anlos Annotation End Date Last Mod By ,,,,,,,,,,,,,,00,0,„,0,„„,„„,,,,„,y„„0„r, 0„0„„�REV REASON:SET TYPE-I DIVERTER 4/22/2018 raffep Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread CONDUCTOR Insulated 40',_ -, 29.0-108.0 B LINER 41/2 3.958 4,370.0 11,252.5 3,455.9 12.60 L-80 IBT NIPPLE;489.9 ,. Liner Details ' Nominal ID r Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 4,370.0 3,511.9 80.32 HANGER 1 BAKER Mod B1 FHH(Inside Casing 6.23') 3.930 SURFACE;28.8-2,300.0 A L 4,386.6 3,514.6 81.70 HANGER 2 BAKER Mod 91 FHH(Outside Casing 6.23') 3.688 — 4,400.0 3,516.3 83.27 SWIVEL BAKER CASING SWIVEL 3.960 GAS LIFT;2,393.9 Ili: 11,230.6 3,456.1' 90.53 XO Reducing 4-1/2”IBT Box x 3-1/2”IBT Pin Crossover 3.500 ' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - Top(TVD) Top Mel GAS LIFT;3,7662 Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 4,080.0. 3,449.8 78.00 FISH TRACTOR ARM 1”x 21”TRACTOR ARM,BELIEVED 2/5/2006 0.000 — TO BE IN L2 LEM-LOST 2/5/2006 SLEEVE-C,3,971.9 1 1 Perforations&Slots • Shot • Dens Top(TVD) Btm(TVD) (shotstft ' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com ALL SLOTS B LINER= . B, . , . , 44060 4,560.0 35170 3,514.2 WS 1J-154L1 10/20/2005 320 SLOTS LOCATOR;4,019.2 , Alternating slotted/blank �- pipe 0.125"x2.5"x329 f SEAL;a,ozo.9 = spf 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft.non- = slotted ends t 4,871.0 5,145.0 3,522.0 3,517.8 WS B,1J-154L1 10/20/2005 32.0 SLOTS ISO SLEEVE;4086.0, 5,363.0 5,762.0 3,518.1 3,508.9 WS B,1J-154L1 10/20/2005 32.0 SLOTS FISH;4,080.0, FISH,4,080.0 6,067.0 6,560.0 3,503.6 3,492.4 WS B,1J-154L1 10/20/2005 32.0 SLOTS 6,806.0 7,301.0 3,490.9 3,482.0 WS B,1J-154L1 10/20/2005 32.0 SLOTS 7,544.0 8,158.0 3,475.3 3,478.0 WS B,1J-154L1 10/20/2005 32.0 SLOTS - ,5. 8,466.0 8,961.0 3,487.1 3,485.2 WS B,1J-154L1 10/20/2005 32.0 SLOTS D-SAND LINER LEM;4,0170- - 9,209.0 9,703.0 3,485.3 3,469.5 WS B,1J-154L1 10/20/2005 32.0 SLOTS 4,219.2 .a 10,012.0 10,506.0 3,468.1 3,464.0 WS B,1J-154L1 10/20/2005 32.0 SLOTS B-SAND LINER LEM;4,1895- 4,5112 10,752.0 11,217.0 3,462.9 3,456.2 WS B,1J-154L1 10/20/2005 32.0 SLOTS PRODUCTION;26.8-5,185 0 I I Notes:General&Safety End Date Annotation 10/30/2005 NOTE:MULTI-LATERAL WELL:1J-154(A-SAND),1J-154L1(B-SAND),1J-154L2(D-SAND) 2/7/2011 'NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 ME SLOTS;4,406.0-4680.0..—. [ SLOTS;4,8710-5,145.0 .__ I SLOTS;5,363.0-5,762.0 SLOTS;6,0670-8,5600 SLOTS;6,806.0-7,301.0 SLOTS;7,544.06,158.0 1 ~ SLOTS;8,466.0-8,961.0 SLOTS;9,209.0-9,703.0 -4I— SLOTS; 4HSLOTS;10,012.0-10,506.0 I 1 SLOTS;10,752.0-11,217.0 - 1— B LINER;4,370.0-11,252.5 • • • Proposed 1J-154L1 to 1J-159 B Sand MBE Retreatment with RPPG 1 J-154 is a West Sak Tri-lateral injector with horizontal laterals in the D, B, and A sands. All 3 laterals contain 4.5", L-80, slotted liners. An MBE occurred 3/3/18 in 1J-154 to offset 1J-159 producer. This is the first MBE in 1J-154. A mainbore IPROF performed on 4/3/18 indicated all injection was going to B lateral. The D lateral was seen crossflowing to B lateral as well, and slight crossflow was seen from A Lat to B Lat. A 1J-154L1 B Lat (PROF of 5/4/18 verified a robust B MBE exists at —8395' MD. This MBE is about half way down the B Lat Liner. 1J-154 is currently configured with an A Lat Plug set, and B Diverter set, and a D Iso-Sly set. Per this procedure, a functional waterflood pattern is to be restored between 1J-154L1 and 1J-159L1 by pumping an RPPG treatment in 1J-154L1 to seal off the B MBE. CT will first deploy a 5' Perf Gun . to perf large holes at 6 spf, 60 deg ph, in 4.5" B lateral Liner at 8393 - 8398' RKB over the B MBE at 8395' RKB. This will enable good passage of RPPG slurry through the liner to the B MBE. Due to wellbore volume of —127 bbls to B MBE, CT will be used to pump the RPPG treatment. Pumping down CT allows for monitoring RPPG treatment response development earlier than possible by pumping fullbore. CT also enables placing the RPPG to the MBE faster at any pump rate. Following MBE treatment, 1J-154L1 will be returned to injection to evaluate 'B Lat only' performance s for long enough to verify that the B MBE is successfully sealed before normaling up the A and D Lats. Proposed Procedure Coil Tubing: 1) RIH to shoot 5' of `big hole' add perforations at 8393 - 8398' RKB near the B MBE at —8395' RKB. The perfs are shot over the MBE to provide better passage of RPPG through slotted liner to the MBE. 2) Have 1J-159 producer online and put 1E-105 BOI at —1000 BWPD 12 - 24 hrs before CTU RU on 1J-154. Flow 1J-159 to 1J test separator to avoid CPF1 upset. This establishes flow through MBE between the wells to ensure MBE is open for RPPG, and pushes away gas head from 1J-154 to MBE. Ideally, we want tubing liquid packed for pumping RPPG treatment. RU CT with 2" CT on 1J-154. Request 1J-159 SI when CT is ready to RIH, but keep 1J-154 on injection at —1000 BWPD. RIH with large single down port Nozzle while displacing Diesel FP from CT pumping —50 bbls of 2% KCL Water down CT at —0.5 bpm as injection continues down CT x Tbg annulus. Park Nozzle at Safety above all liner slots at 4405' RKB, and then halt pumping down CT to check WHIP on CT x Tbg. Record starting WHIP on tubing. Any gas head that was in tubing should have been fully displaced from tubing to MBE, so WHIP on tubing should be low to start the RPPG treatment. . r i • SI SWI to 1J-154 CT x Tbg annulus, and swap to pumping 2% KCL Water from transport down CT x Tbg annulus at minimum rate (-0.4 bpm), to keep CT x Tbg annulus flushed of any potential RPPG stacking up CT backside during RPPG pumping as precaution to prevent stuck CT. Pump short Step Rate Injection Test (SRIT) down CT with 2% KCL Water at 1 bpm, 1.5 bpm, and 2 bpm to record a stable CT treating pressure at each rate. Pick a steady treating rate between 1 to 2 bpm that yields a good starting CT treating pressure somewhere in range of 1000 - 2000 psi. After a steady pump rate is determined, start mixing 2% KCL Water from transport with 1 - 4 mm mesh RPPG at 0.75 ppg concentration (31.5 lbs/bbl) in mixing van to make RPPG slurry on-the-fly while pumping it down CT at established steady rate. Note: CT x Tbg pump rate + CT pump rate = total rate entering MBE, so we will calculate proper RPPG ppg concentration to pump down CT to yield a Net = 0.75 ppg Slurry in the total rate to B MBE. Pump 0.75 ppg RPPG slurry in 2% KCL Water until WHP on CT x Tbg annulus approaches -800 psi. We may pump up to 10 sacks of 'Tail slurry' of Crystal Seal or PolySwell at 0.25 ppg in 2% KCL to leave an easier slurry to FCO in wellbore and to reserve some RPPG stock on hand. Make frequent precautionary PU weight checks, then RBIH to park nozzle at safety at 4405' RKB. When Flush is called, continue simultaneous pumping down CT and CT backside as follows: Down CT: With nozzle parked at 4405' RKB, swap to 5 bbls of 2% KCL Brine Spacer at established steady rate down CT, followed by 1 CT volume (-50 bbls) Diesel down CT at established steady rate down CT, followed by SD pumping down CT, and start POOH to surface. Down CT Backside: Closed end displacement volume of 2" CT to 4405' RKB = 17.1 bbls = voidage created in well when CT is POOH. We need to replace 17.1 bbls during CT Backside pumping, plus need to pump additional 60.6 bbls displacement volume to push RPPG top down 4.5"liner from 4405' RKB to MBE at 8395'RKB. Thus, pump total of 77.7 bbls down CT Backside after CT SD. Proceed with CT Backside pumping as follows: Continue 2% KCL Water pumping at minimum rate (-0.4 bpm) to maintain steady total rate to well (to monitor treating pressure) until CT pumping SD, then increase CT x Tbg rate by rate equal to rate CT was pumping before SD. This maintain total steady rate to well to monitor treating pressure at constant rate. Pump 46.7 bbls of 2% KCL Brine at new increased rate, followed by 31 bbls of Diesel to FP Tubing at new increased rate, followed by SD. This leaves tubing FP to 2000' TVD; 2089' RKB, and puts RPPG slurry fully displaced to the MBE at 8395' RKB. Rate down CT can be reduced to keep WHP < 1200 psi (est Frac pressure), if needed. RD CTU. Wait 48 hours for RPPG particles to crosslink together in MBE before 1J-154L1 is put BOI. Coil Tubing - FCO RPPG (optional, if needed): 3) RIH with jet swirl nozzle to tag RPPG in 1J-154L1. Jet down through slurry Gel with Diesel to as deep as possible while injecting away RPPG and Diesel to MBE &/or formation. POOH. RD CTU. Place 1J-154L1 on injection to evaluate results of B MBE treatment. Evaluate `B only' SWI performance and monitor producer 1J-159 performance to verify that the B MBE has been isolated. • Image Project Well History Fite 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. Q~ - ~~~j Well History File Identifier Organizing (done) r~j Two-sided ill II~I~I II ll~ II Ill ^ Rescan Needed III (t'lll I~ II III NI RE CAN D{GITAL DATA OVERSIZED (Scannable) Color Items: ~iskettes, No. 1 ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable} ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: ' ~~, ~ ~ ~ /s/ Project Proofing t ~I I ~~I I) I (I II I t ~II BY: _ Maria a Date: ~ ~~"~~/0 O /s/ ~ ~ - - _ _ - + =TOTAL PAGES ~~ jj Scanning Preparation __~ x 30 = l.(/t'~ 1~ f `'T (Count does not include cover sheet) BY: Maria Date: ''3O / O S lsl Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES _ BY: Maria Date: ` t ~ ~~O Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ NO iuiuuuuuuu ReScanned BY: Maria Date: /s/ Comments about this file: a~.~,~.~~e~,~ iiuumiuumii 10/6/2005 Well History File Cover Page.doc • • Page 1 of 2 Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Tuesday, October 11, 2011 4:52 PM To: NSK West Sak Prod Engr; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV Returned to Service on 1J -127 and 1J -154 West Sak injectors Tom and Jim, The low pressure pilots (LPP) on the wells listed below have been returned to service on 10/11/2011 after the wellhead injection pressures stabilized above the setting of the low pressure pilot. Current wellhead pressure pressure and injection rate are also listed below. This pilot had been defeated on 9/16/2011 in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J-127 (206- 047,206 -048, 206 -049) 555 7-X11 1205 - 03 -037) 557 92 �- 5 -- In addition to the LPP being returned to service on 1J -164, I have summarized the current defeated LLP situation at 1J below. The wells in red still have LLPs defeated, and the others wells have been returned to service with their returned to service date at the end. An email has been sent for all wells that have had their LLP returned to service. Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 ; a Mobile - 303.248.6641 °,. ` ' ` ` y :� Z t; ;, From: CPF1 Prod Engr Sent: Friday, September 16, 2011 6:44 PM To: 'tom.maunder @alaska.gov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 13 West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) Returned to normal 10/11/2011 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -105 (207- 027,207- 028,207 -029) 345 639 1J-118 (206- 176,206- 177,206 -178) 327 1020 1 J -127 (206- 047,206 -048, 206 -049) 337 934 1 J -036 05 -037) 369 623 1J-160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205- 144,205 -145, 205 -146) 479 1082 1J-180 (206- 150,206 -151) 537 478 1 J -184 (206- 044,206 -045) 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 9/19/2011 3 c~ NUJ ~>~~7 DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050360 Well Name/No. KUPARUK RIV U WSAK 1J-154L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23254-60-00 MD 11285 TVD 3456 Completion Date 10/30/2005 Completion Status 1-OIL Current Status 1WINJ IC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Log s Run: GR/Res, CBL (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number -`lJame Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 4346 11285 Open 1/9/2006 ,. Lis 13784 Fv~/~ Induction/Resistivity 2256 11228 Open 3/9/2006 ASLD GR EWR4 CNP SLD ROP ACAL PWD GeoPilot pt 13784 LIS Verification 2256 11228 Open 3/9/2006 ASLD GR EWR4 CNP SLD ROP ACAL PWD GeoPilot ~~ C Lis 15015 Induction/Resistivity 2256 11285 Open 4/17/2007 LIS Veri, GR, FET, ROP i w/Graphics CGM, EMF, t PDF Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? ~YTfT~ Analysis `~'T l~ Received? Comments: Compliance Reviewed By: Daily History Received? Formation Tops Sample Set Number Comments N V/N Date: ~~ WELL LOG T12A~iSMITTAL 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-154, Ll & L2, April 13, 2007 AK-MW-3956462 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-154, 1J-154 Ll, 1J-154 L2: LIS & Digital Log Images: 50-029-23254-00, 60, 61. ~.~~ ~~ , s ~ ~ ~~ S ~ 7 ,~ ~~ ~~ (i.lV/` - U ~G ao5 - 03 S~ ~ 150 ~~ r~~ _ u =~ a os -03~ ~lS~(5 1 CD Rom u 1~ 245 =03~ ~~SO~~ 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION t-~ I~ l.A ~. $~ ~ . e~18i3'~8 I~ ~~ ~a8: ~i;Er,~.x i~OiYf!'ilv3i~'s REPORT OF SUNDRY WELL OPERATIONS ~alr~'t•~ra 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^ Prod to WINJ Alter Casing. ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-036. ' 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23254-60 ' 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-154L1 ' 8. Property Designation: ~ 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11285' ' feet true vertical 3456' ,feet Plugs (measured) Effective Depth measured 11285' feet Junk (measured) true vertical 3456' feet 4-1/2" Casing Length - Size MD TVD Burst - Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3/4" 2300' 2199' L2 WINDOW 1' 7-5/8" 4092' 3452' PROD. CASING 1' 7-5/8" 4371 3512' INTERMEDIATE 5056' 7-5/8° 5165 Perforation depth: Measured depth: 4406' - 11217 true vertical depth: 351 T - 3456' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4047 MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 490' 12. Stimulation or cement squeeze summary: Intervals treated (measured) I70I7G' °a ~~~ 1i3~ ~ ~ 2C)p6 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 2044 2851 750 335 Subsequent to operation 2649 437 332 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 NiA if C.O. Exempt: ~~~ ~~~ Contact Robert W. Buchholz Printed Name Title Production Engineering Technician Signature ~ Phone 907-659-7535 Date ~L/!3~D~ n (~ ~~ ~ zG•aG Form 10-404 Revised 04/2004 1 1 ["( ~ ~' ~ L ~ ~~'~\ Submi Origi~tal/Only 1J-154L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/10/2006 Commenced Water Injection Service 4~ r ~ WELL LOG TRANSMITTAL To: State of Alaska March 03, 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-154 L1, AK-MW-3956460 1 LDWG formatted Disc with verification listing. API#: 50-029-23254-60 C~° PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Q Signed: ~ <~ • 7~ ~(~5 ~ ~ ~ ~ ~ ?°~~g ~ , ~~ ` .~ s ~ FRANK H. MURKOWSK/, GOVERNOR ~~~ ~ ~~~~ ~~~~++ ~t~~ ~t~~+ 4i~[>•-7~ OIL t>•lsil u47 ~ 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQ~TI011T COD'II~'II55IO1~T ~ ANCHORAGE, ALASKA 99501-3539 i' PHONE (907) 279-1433 FAX (907) 276-7542 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, 1J-154L 1 Sundry Number: 306-067 Dear Mr. Buchholz: 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. C~;,.,,.o..e1~, DATED this~3day of February, 2006 Encl. _ _ A ~ Z/~ / ~ ~ ~-z3 G~ ~-- RECELVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ ~~B 2 L 2006 APPLICATION FOR SUNDRY APPROVA~aska Oil & Gas Cans. Conxrlission 20 AAC 25.280 ._ _ _ _ _ 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Pertorations ^ 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 ^~ Exploratory ^ 205-036 '~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23254-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-154L1 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 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): 11285' 3456' 11285' 3456' Casing. Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3/4" 2300' 2199' L2 WINDOW 1' 7-5/8" 4092' 3452' L1 WINDOW 1' 7-5/8" 4371 3512' INTERMEDIATE 5056' 7-5/8" 5165 3649` B Sand Slotted Liner 6811' 4-1/2" 11217' 3456 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4406' - 11217' 3517' - 3456' 4-1 /2" L-80 4047' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV=NIP SSSV= 490' 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work:.- Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 03/10/06 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert W. Buchholz Printed Name Robert W. Buchholz . Title: Production Engineering Technician ~~/ , ~ Signature ~iY,~ Phone 659-7535 Date O Z ~~ ~~ Commis on Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~- (~ Plug Integrity ^ BOP Test ^ Mechanical Inte r Test ~~ Location Clearance ^ ~ Other: ~ ~ "~~~.3~~ ~f~ ~ ~ ~ ~IJ~~t. ~ ~Xc.~ ~ y,~,t'~.S ~l~ . DMS ~F~ ~~~ ~ ~ zoos Subsequent Form Required: ~~-- APPROVED BY /, ~ 2 O~ Approved by: O STONER THE COMMISSION ~ ~ Date: ~1 J ~/ u E ~ ~ ~,J f E §i / , t~ Form 10-403 Revised 07/2005 Submit in Duplicate s a 1J-154L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-154. This well was pre-produced fora 52 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Lateral 1J-154L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (2300' and / 2199' tvd) was cemented with 470 sx AS Lite followed by 149 sx DeepCrete. The 7-5/8" Intermediate casing (5165' and / 3628' tvd) was cemented with 360 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 @ 4071' and / 3448' tvd. This well also' contains a lower B sand 5-1/2" x 7-5/8" ZXP Liner Top Packer w / HRD located @ 4346' and / 3508' tvd. The top of West Sak D sand was found at 4107'md / 3454' tvd. The top of West Sak B sand was found at 4406'md / 3517' tvd. The top of West Sak A sand was found at 5412'md / 3661' tvd. W k - - ~~~ -~~ /~ .~ jti ~ V r'.I.'C:iA.NICAL INTEGRITY REPORT ~j -~ti3~ - ~l~c;'°C ; OPER ~ FIELD C~(~-~ ~` ~,~ ~"~ ~~~-~v°-~~ ;.ALL NU2~ER ~ :~ -' , ~ ~~ ~--'~L. ' L- NrLL D~T~_ TD: 4~~~.?~.. ~(~~~'I'VD; PBTD ?°ID Cas i^g : '~1~1~. Shoe : ~~~;`~~ t-ff3 ~~~ ~ ~ ; i~V : ~'~,- ?~ _.:,e.: ~,~oi~~LD Shoe : '~ 5 ~~ .~ _=o1e S_~e ~~~~ and `~Cr.~?~-r~-i. .NTEGRTTY - P?.RT #~ ~nZul~:s Press Test: _? Cocrsents ~VL T~~ T V-D ; C e C c t "~ V~ ~. •~. ,fly `~~hc~c ~ l ~ S 15 Qin ~0 min i '~CH,A ~IIC?i, INTEGRTT`~ _ p~~_T # 2 ~ ~ ~y ~ ~ ,~ ~. Cement Volumes : Amt. Liner ~ ~ Cs~ ~„ DV ~~ C.~t Jol to cover pens ~~ ~~~~ \\4~..r~~~ ci~-~~~e~~~- ~ _ _' e o r e t i C a 1 T_ C C ~~rzc-~ #. C c_ ~ `~~C l~ c. ~-- '~v : ~ CSc. CrC Cement Bond Log (Yes or No) ~~~ In AOGCC File_ C3L Evaluation, ;one above perfs ~->~`u~L`~~ ~~«~~v~~--- Production 'Log: T~De r.v81L'ntlon CONC-LJS ~ Ot1S Part r 1 Pdr ~ { ~: ... ~ ~ ~~N a ~ zaos STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ,~~ ,~ ~~~ ~p~s Cpmmissi0n WELL COMPLETION OR RECOMPLETION REPORT ANDdadb~~e 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: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ or Aband.: October 30, 2005 12. Permit to Drill Number: 205-036 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:~Q¢o~. ~3 Zpps,~ Sept , 2005 D ~ ~~S t3. API Number: ~ s 50-029-23254-60 4a. Location of Well (Governmental Section): Surface: 2133' FSL, 2569' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD eached: October 18, 2005 14. Well Name and Number: 1J-154L1 At Top Productive Horizon: 1262' FSL, 2190' FWL, Sec. 35, T11 N, R10E 8. KB Elevation (ft): 28' RKB / 108' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 354' FNL, 2201' FWL, Sec. 11, T10N, R10E 9. Plug Back Depth (MD + ND): 11285' MD / 3456' TVD West Sak Oil POOI 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558640 ~ y- 5945944 ' Zone- 4 10. Total Depth (MD + ND): 11285' MD / 3456' ND ~ 16. Property Designation: , , ADL 25661 & 25662 TPI: x- 558126 y- 5945069 Zone- 4 Total Depth: x- 558198 ~ - 5938174 ~ Zone- 4 11. Depth where SSSV set: Camco nipple @ 490' 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1582' MD 21. Logs Run: ~Gt~ cwti.sW J~ 'r3 ? ~f ~/7! ~5 ~ .3.5 ~3 ~ •~•y.~ ./S'~ GR/Res, CBL ~~/8 ~d6 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 169 sx ASI 10.75" 45.5# L-80 28' 2300' 28' 2201' 13.5" 470 sx AS Lite, 149 sx DeepCrete 7-5/8" 29.7# L-80 28' 5165' 28' 3649' 9-7/8" 360 sx DeepCrete 4.5" 12.6# L-80 4406' 11253' 3514' 3456' 6.75" slotted liner 23. Pertorations 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 4189' slotted liner from 4406'-11217' 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 25, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-154 and 1J-154L2 Date of Test 12/28/2005 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1121 GAS-MCF 974 WATER-BBL 1 CHOKE SIZE 53 Bean GAS-OIL RATIO 869 Flow Tubing press. 319 ps Casing Pressure 1180 Calculated 24-Hour Rate -> OIL-BBL 2241 GAS-MCF 1948 WATER-BBL 3 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". .. '! 1 NONE ~~~ .i~t~ ~ ~ 2DDfi ~ ~- Form 10-407 Revised 1212003 ' CONTINUED ON REVERSE O~IG1~A~ G r 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-154L1 Top West Sak B 4366' 3511' Base West Sak B 11284' 3456' 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 Name Ran omas Title: Greater Kuoaruk Area Drilling Team Leader Signature Phone Date Prepared by Sharon Alisup-Drake ~~ ~~;,~.~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and {eases 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 AOGCG 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 • • ConocoPhillips Alaska Page 1 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name:. n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code 9/27/2005 103:00 - 04:30 1.50 MOVE 04:30 - 05:00 0.50 MOVE 05:00 - 07:00 2.00 MOVE 07:00 - 08:00 1.00 MOVE 08:00 - 11:30 3.50 MOVE 19/30/2005 ~ 00:00 - 01:00 Sub Phase Code Description of Operations DMOB MOVE Disconnected service loops between complex's and blow down lines MOVE MOVE Moved rigs complex's off well and spotted on pad, moved off boilers, motors, pumps, pits and pipe sheds MOVE MOVE Moved sub base off well 1J-168 OTHR MOVE Removed steering arm and bracket alond with spare tire on side of sub base, had to remove to set sub over well due to close proximity of well 1 J-09 POSN MOVE Spotted sub base on well 1J-154 MOVE MOVE Set in rigs complex's and connected service loops, set rock washer by rig for maintenance and fin rigging up. NOTE: Rig off highline at 00:30 hrs and back on highline at 11:30 hrs Turnkey inline move. "'Special Note'*' The Rig will now go on Summer Maintanace 1.00 RIGMNT RSRV SURFAC Slip and cut 65' of drilling line. NOTE: Accepted rig at 00:01 hrs 9/30/2005 110/1 /2005 01:00 - 02:30 1.50 WELCT NUND SURFAC Installed riser and hydraulic control lines to diverter, MU turnbuckles and knife valve 02:30 - 04:00 1.50 DRILL OTHR SURFAC Loaded pipe shed with BHA and 5" DP and strapped same 04:00 - 08:00 4.00 DRILL PULD SURFAC PU and stood back out of pipe shed 10 stds of 5" HWDP and jars then 15 stds of 5" DP 08:00 - 09:00 1.00 DRILL PULD SURFAC PU 13 1/2" BHA tools to rig floor 09:00 - 09:45 0.75 WELCT ROPE SURFAC Function tested diverter and Kommey unit, test witnessed by John Crisp with AOGCC, added 1 more. jt of 16" diverter line to clear flow line manifold (105' total length) 09:45 - 11:00 1.25 DRILL PULD SURFAC MU 13 1/2" bit #1 on 8" motor with 1.5 deg bend and 1 std HWDP, RIH and tagged fill inside conductor at 97' 11:00 - 12:00 1.00 DRILL OTHR SURFAC Flooded conductor checking for leaks and ck ok, pressure tested standpipe and manifold to 3,000 psi 12:00 - 12:45 0.75 DRILL DRLG SURFAC Cleaned out conductor from 97' to 108', spudded well and drilled 13 1/2" hole from 108' to 144'. ADT .76 hrs when flowline plugged off 12:45 - 14:30 1.75 DRILL OTHR SURFAC Took apart flowline and unplugged same, loaded with large pieces of cement and gravel 14:30 - 15:30 1.00 DRILL DRLG SURFAC Drilled 13 1/2" hole from 144' to 219', ADT 1.08 hrs 15:30 - 15:45 0.25 DRILL TRIP SURFAC POOH from 219' to 38' 15:45 - 17:45 2.00 DRILL PULD SURFAC MU 13 1/2" BHA #1 with 8" MWD and UBHO sub, oriented and uploaded MWD, RIH with NMFDC's to 219', RU Gyro 17:45 - 21:00 3.25 DRILL DRLG SURFAC Drilled 13 1/2" hole from 219' to 495' (276') ADT 2.4 hrs. 21:00 - 21:30 0.50 DRILL SURV SURFAC Ran surface read out gyro at 495', (determined rig team had left out 1 NMFDC out of BHA) 21:30 - 22:30 1.00 DRILL TRIP SURFAC POOH from 495' to 133', PU additional NMFDC and RIH to 495' 22:30 - 23:00 0.50 DRILL DRLG SURFAC Drilled 13 1/2" hole from 495' to 525' (30') ADT .3 hrs, drilled with 8-12K wob, 60-80 rpm's, 130 spm, 550 gpm at 1,050 psi, off btm torque 1K ft-Ibs, on btm 1.5K ft-Ibs, rot wt 62K, up wt 60K, do wt 64K 23:00 - 00:00 1.00 DRILL SURV SURFAC Ran surface read out gyro's at 444', 344', 244', 144' and 50' 00:00 - 12:00 12.00 DRILL DRLG SURFAC Directionally drilled 13 1/2" hole per directional plan from 525' to 1,458' MD/1 ,427' TVD (933') ART 2.94 hrs, AST 4.45 hrs, 15-25K wob, 80 rpm's, 144 spm, 610 gpm, off btm pressure 1,600 psi, on btm 1,800 psi, off btm torque 2K ft-Ibs, on btm 3.5K ft-Ibs, rot wt 95K, up wt 93K, do wt 93K. NOTE: Took gyro survey's at 617', 709' and 801', took 85 minutes to gyro including RD 12:00 - 19:30 7.50 DRILL DRLG SURFAC Directionally drilled 13 1/2" hole per directional plan from 1,458' to 2,302' MD/2,201' TVD (844') (10 3/4" Csg Pt.) ART 2.07 hrs, AST 2.95 Printed: 12!9/2005 3:20:17 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Start: 9/30/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Rig Name: Doyon 141 Rig Number: Date 10/1 /2005 10/2/2005 From - To Hours Code Code Phase 12:00 - 19:30 ~ 7.50 ~ DRILL ~ DRLG ~ SURFAC 19:30 - 20:15 I 0.751 DRILL I CIRC I SURFAC 20:15 - 22:45 2.501 DRILL REAM I SURFAC 22:45 - 00:00 I 1.251 DRILL I TRIP I SURFAC 100:00 - 01:45 I 1.751 DRILL I PULD I SURFAC 01:45 - 03:15 I 1.501 CASE I RURD I SURFAC 03:15 - 03:30 I 0.251 CASE I SFTY I SURFAC 03:30 - 08:00 I 4.50 I CASE I RUNC I SURFAC 08:00 - 09:00 I 1.001 CEMENTI CIRC I SURFAC 09:00 - 09:30 0.50 CEMENTI RURD SURFAC 09:30-11:00 1.50 CEMENTCIRC SURFAC 11:00 - 13:15 2.251 CEMEN7PUMP SURFAC 13:15 - 14:00 I 0.751 CEMENTI DISP I SURFAC Page 2 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations hrs, 4-20K wob, 80-85 rpm's, while sliding would pump at 147 spm, 625 gpm, off btm pressure 1,650 psi, on btm 1,900 psi, while rotating would increase pump rate to 650 gpm at 2,000 psi, off btm torque 2.5K ft-Ibs, on btm 4K ft-Ibs, rot wt 106K, up wt 110K, do wt 102K. No gas hydrates seen on surface hole. Pumped weighted hi vis sweep and circ out of hole, had 15-20% increase in cuttings back from sweep, circ at 155 spm, 650 gpm at 1,825 psi and 85 rpm's Backreamed out of hole from 2,302' to HWDP at 1,070', BROOH at 85 rpm's, 155 spm, 650 gpm at 1,825 psi, pumped out of hole 3 stds of HWDP to 795' at 530 gpm at 1,200 psi, no problems BROOH Cont to POOH standing back remaining 7 stds of HWDP and jars, POOH to BHA and NMFDC's at 163' Cont. POOH from 163' LD BHA #1, LD 3-NMFDC's, MWD and motor,. cleared rig floor RU Doyon's 10 3/4" csg equipment with Franks fill up tool and changed I out elevator bales 'Held PJSM with rig crew and discussed running order and hazards, also discussed operation with new hands and people working in new positions Ran 10 3/4" csg 2,300' 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 and tagged btm at 2,302', RIH with an add 55 jts (58 total) of 10 3/4", 45.5#, L-80, BTC csg, Total ran 2,309', ran 17 bow spring centralizers on 1st 17 jts. No problems RIH, st wt up 130K, down wt 103K Circ btms up thru Franks fill up tool while conditioning mud for cementing, reciprocated pipe 35' and staged pump rate up to 4 bpm at 200 psi RD Franks fill up tool and MU Dowell cement head Fin circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 380 psi, reciprocating pipe 35' with 160K up wt and 105K do wt, circ and cond mud to 9.2 ppg and lowered PV to 13 and YP to 5, held PJSM on cement job with Dowell, ASRC and rig crew while circ and cond mud. Turned over to Dowell and cemented 10 3/4" 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), then pumped 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 370.5 bbls (470 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, followed with 66 bbls (149 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full returns, shut down and dropped top plug and Dowell pumped 5 bbls fresh water then turned over to rig. Rig displaced cement with 206.5 bbls (2045 stks) of 9.2 ppg mud, displaced cmt at 6.5 bpm, initial circ pressure 350 psi, max pressure 640 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1000 psi, held 5 min, checked floats and held, CIP 14:03 hrs, had full returns during job and had 46.5 bbls of 10.7+ ppg cmt back to surface, reciprocated csg throught job, st wt up 140K, do wt 100K, coat to tag btm at 2,302' while reciprocating pipe and PU and Printed: 12/9!2005 3:20:17 PM • ConocoPhillips Alaska Page 3 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud. Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10!30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/2/2005 13:15 - 14:00 0.75 CEMENl ~ DISP SURFAC landed csg with float shoe at 2,300' and float collar at 2,217' 14:00 - 14:30 0.50 CEMEN-- ff RURD SURFAC RD Dowell cement head and csg slips 14:30 - 16:15 1.75 WELCT NUND SURFAC Flushed out diverter and flowline, ND diverter and knife valve, PU on diverter 16:15 - 17:00 0.75 WELCT EQRP SURFAC PU on csg to 150K and set 10 3/4" emergecy slips with SOK over final down wt, made rough cut on csg and set diverter back down, LD landing jt and RD csg elevators and bales 17:00 - 18:30 1.50 WELCT NUND SURFAC ND riser, diverter mud cross and conductor mud cross and set out diverter 18:30 - 21:00 2.50 WELCT EQRP SURFAC Made final cut on 10 3/4" csg and welded on Vetco Gray 11" x 5M wellhead adapter flange 21:00 - 00:00 3.00 RIGMNT RSRV SURFAC While waiting on welhead to cool down, installed Totco's revolution counter for K-revs onto top drive and iron roughneck extensions, RU mousehole to PU5" DP 10/3/2005 00:00 - 04:15 4.25 WELCT EQRP SURFAC PU 35 stds of 5" DP while waiting on 11" x 5M adaptecflange to cool down 04:15 - 04:30 0.25 WELCT OTHR SURFAC Tested weld on adapter flange to 2,000 psi for 10 min and ck ok (80% of collapse) 04:30 - 05:45 1.25 WELCT NUND SURFAC Oriented and NU Vetco Gray 11" x 5" MB 228 wellhead, tested seals to 5,000 psi for 10 min, good test 05:45 - 08:30 2.75 WELCT NUND SURFAC NU 13 5/8" x 5M BOP stack to 13 5/8" x 11" 5M adapter spool, had to adjust bell nipple 08:30 - 16:15 7.75 WELCT BOPE SURFAC RU and tested BOPE, tested rams, valves, manifold and annular to 250 psi low and 3,000 psi high, tested rams with 4" and 5" DP along with 7 5/8" csg test jts. NOTE: John Crisp W/AOGCC witnessed test 16:15 - 1.6:30 0.25 DRILL PULD SURFAC Installed wear bushing 16:30 - 16:45 0.25 DRILL PULD SURFAC PU and stood back 3 additional stds of 5" DP 16:45 - 17:15 0.50 RIGMNT RSRV SURFAC Leveled sub base 17:15 - 20:15 3.00 DRILL PULD SURFAC MU 9 7/8" BHA #2 RIH to 171, MU 9 7/8" bit #2 on 6 3/4" motor with 1.5 deg bend, oriented MWD and uploaded same, RIH with 2 NMFDC's and shallow tested MWD, did not get a signal 20:15 - 21:00 0.75 DRILL OTHR SURFAC Trouble shoot MWD signal, found problem in computer, tool ck'd ok 21:00 - 21:45 0.75 DRILL PULD SURFAC Fin MU BHA #2 RIH to 567', MU 1 add. NMFDC, loaded radioactive sources and RIH with HWDP and jars 21:45 - 23:00 1.25 DRILL TRIP SURFAC RIH with BHA #2 from 567' to 2,210' (above Flt Collar @ 2,217') 23:00 - 23:45 0.75 DRILL CIRC SURFAC Circ hole for casing test evening MW in and out at 9.4 ppg, circ at 550 gpm at 1,275 psi, 25 rpm's, 4-6Kft-Ibs off btm torque, rot wt 90K, up wt 98K, do wt 85K 23:45 - 00:00 0.25 CASE RURD SURFAC RU to test 10 3/4" csg 10/4/2005 00:00 - 01:00 1.00 CASE DEOT SURFAC Tested 10 3/4" csg to 3,000 psi for 30 min, good test 01:00 - 02:00 1.00 CEMEN DSHO SURFAC Drilled out float collar at 2,217', shoe track and float shoe at 2,300', cleaned out to TD at 2,302', drilled 20' of new formation to 2,322', drilled out at 10-12K wob, 30 rpm's, 454 gpm at 1,100 psi, rot wt 90K, up wt 98K, do wt 85K 02:00 - 02:45 0.75 DRILL CIRC SURFAC Displaced out spud mud with re-conditioned 9.0 ppg mud, evened MW in and out at 9.0 ppg, circ hole at 454 gpm at 1,100 psi 02:45 - 03:45 1.00 DRILL LOT SURFAC RU and performed LOT to 14.7 ppg EMW, 650 psi at 2,201' TVD with 9.0 Pp9 MW 03:45 - 12:00 8.25 DRILL DRLG INTRM1 Directionally .Drilled 9 7/8" hole from 2,322' to 3,126' MD/2,976' TVD, (804'), ART 1.99 hrs, AST 3.72 hrs, 4-17K wob, 70-75 rpm's, 141 spm, 598 gpm, off btm pressure 1,600 psi, on btm pressure 1,700 psi, off btm torque 2-6Kft-Ibs, on btm 4-5K, rot wt 107K, up wt 117K, do wt 96K 12:00 - 18:45 6.75 I DRILL ~ DRLG i I INTRM1 Directionally drilled 9 7/8" hole from 3,126' to 3,816' MD/ 3,384' TVD, Printed: 12/9/2005 3:20:17 PM • ~ ConocoPhillips Alaska Page 4 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Nam e: ROT -D RILLIN G Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ ppco.co m Rig Release: 10/30/2005 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code ' Phase Description of Operations 10/4/2005 12:00 - 18:45 6.75 DRILL DRLG INTRM1 (690') ART 2.37 hrs, AST 2.69 hrs 18:45 - 19:15 0.50 RIGMNT RSRV INTRM1 Removed turnbuckle assembly used for centering of top drive torque tube, bolt on turnbuckle was snagging top drive blower duct work 19:15 - 00:00 4.75 DRILL DRLG INTRMI Directionally Drilled 9 7/8" hole from 3,816' to 4,102' MD/3,447' TVD, (286'), ART 1.39 hrs, AST 3.28 hrs, 4-20K wob, 80 rpm's, while sliding pumped at 600 gpm and while rotating circ at 650 gpm, off btm pressure 2,050 psi, on btm pressure 2,200 psi, off btm torque 4-7K tt-Ibs, on btm 5-6K, rot wt 107K, up wt 117K, do wt 98K, ave BGG 30 units, max gas 137 units, 9.05 ppg MW, ave ECD 10.0 ppg 10/5/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Directionally Drilled 9 7/8" hole from 4,102' to 4,871' MD/3,604' TVD, (769'), ART 6.3 hrs, AST 3.01 hrs, 7-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm torque 4-7K ft-Ibs, on btm 5-6K, rot wt 106K, up wt 120K, do wt 96K, ave BGG 75 units, max gas 501 units, 9.2 ppg MW, ave ECD 10.2 ppg, pumped wt'd hi vis sweep at 4,102' with 10% increase in cuttings back from sweep 12:00 - 14:45 2.75 DRILL DRLG INTRMI Directionally Drilled 9 7/8" hole from 4,871' to 5,172' MD/3,651' TVD, (301'), (7 5/8" Csg Pt.) ART 1.45 hrs, AST .33 hrs, 10-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,250 psi, on btm pressure 2,400 psi, off btm torque 3-7K ft-Ibs, on btm 5-6K, rot wt 106K, up wt 124K, do wt 96K, ave BGG 100 units, max gas 433 units, 9.3 ppg MW, ave ECD 10.4 ppg 14:45 - 16:30 1.75 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean while geologist evaluated logs, geologist and town ok'd 5,172' as 7 5/8" csg pt. circ hole at 650 gpm, 2,300 psi, 80 rpm's with 4-5K fl-Ibs off btm torque, had no increase in cuttings back from sweep and circ a total of 3x btms up 16:30 - 18:30 2.00 DRILL REAM INTRM1 Monitored well-static, backreamed out of hole from 5,172' to 3,915', pumped weighted hi vis sweep on last std, BROOH at 80 rpm's, 153 spm, 650 gpm 2,250 psi 18:30 - 19:00 0.50 DRILL CIRC INTRMI Fin circ out sweep and had 100% increase in cuttings back from sweep, decided to cont BROOH to 10 3/4" csg shoe 19:00 - 20:45 1.75 DRILL REAM INTRM1 Cont to BROOH from 3,915' to inside 10 3/4" shoe to 2,285', BROOH at 80 rpm's, 650 gpm at 1,850 psi, BROOH at 20-25'/min at 35-40'/min would attempt to pack-off, no other problems BROOH 20:45 - 22:15 1.50 DRILL CIRC INTRM1 Pumped weighted hi vis sweep at 2,285' and circ out of hole, had 50% increase in cuttings back from sweep, mainly silver dollar sized clay patties, mixed and pumped 2nd sweep and shakers were clean, circ sweep out of hole and had a 10% increase in cuttings, circ an add. btms up and shakers were clean, circ hole at 600 gpm at 1,825 psi and 80 rpm's, rot wt 95K up wt 97K, do wt 90K, 9.3 ppg MW 22:15 - 00:00 1.75 DRILL TRIP INTRM1 Monitored well-static, POOH from 2,285' wet 5 stds and hole took talc fill, pumped dry job and cunt POOH to BHA #2 at 567' 10/6/2005 00:00 - 00:45 0.75 DRILL PULD INTRM1 POOH from 567' to 140', POOH LD 11 jts of 5" HWDP and jars, LD 1-NMFDC 00:45 - 01:15 0.50 DRILL PULD INTRM1 Held PJSM and removed radioactive sources, POOH to 78' LD 2-NMFDC's 01:15 - 02:45 1.50 DRILL PULD INTRM1 Downloaded MWD 02:45 - 04:15 1.50 DRILL PULD INTRM1 Fin POOH from 78' LD BHA #2, MWD/LWD and motor, cleared rig floor 04:15 - 04:30 0.25 DRILL PULD INTRM1 Pulled wear bushing 04:30 - 05:45 1.25 CASE RURD INTRMI RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool, changed oul elevator bales " 05:45 - 06:00 0.25 CASE SFTY INTRMI Held PJSM with rig crew and tong operator on running of 7 5/8 csg 06:00 - 06:45 0.75 CASE RUNC INTRMI ~ Ran 7 5/8" Csg to 21 T, MU 7 5/8" Weatherford float shoe, 2 jts 7 5/8", Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/6/2005 ~ 06:00 - 06:45 ~ 0.75 ~ CASE ~ RUNC ~ INTRM1 06:45 - 07:45 1.00 RIGMNT RGRP INTRM1 07:45 - 10:30 2.75 CASE RUNC INTRMI 10:30 - 10:45 0.25 CASE CIRC INTRM1 10:45 - 13:45 I 3.001 CASE I RUNC I INTRMI 13:45 - 14:15 0.50{ CEMENI~CIRC INTRM1 14:15 - 15:00 0.75 CEMENI~RURD INTRM1 15:00 - 16:00 1.00 CEMEN CIRC INTRMI 16:00 - 17:00 I 1.001 CEMENlf PUMP I INTRM1 17:00 - 17:45 I 0.751 CEMENTlDISP I INTRM1 17:45 -.18:00 0.25 CEMEN RURD INTRM1 18:00 - 19:00 1.00 CASE NUND INTRM1 19:00 - 20:45 1.75 CASE OTHR INTRM1 20:45.- 21:15 0.50 CASE NUND INTRM1 21:15 - 21:30 0.25 CASE DEOT INTRM1 21:30 - 21:45 0.25 DRILL PULD INTRMI 21:45 - 22:45 1.00 CMPLTN OTHR INTRMI 22:45 - 23:30 I 0.751 CMPLTNI OTHR I INTRM1 10/7/2005 100:00 - 06:00 6.00 DRILL PULD INTRM1 Page 5 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 conn, circ thru float equip and ck ok, RIH with 2 add jts csg to 217' and had problems with the pipe skate Repaired pipe skate, cable on traveling drum had gotten crossed Cont RIH with 7 5/8" csg from 217' to 2,278', (9 5/8" csg shoe at 2,300') Circ btms up at 2,278', circ at 5 bpm at 320 psi, st wt up 100K, do wt 86K Fin RIH with 7 5/8" csg from 2,278' and tagged btm at 5, 172', no problems RIH to btm, ran a total of 121 jts and 2-pup jts of 7 5/8", 29.7#, L-80, BTCM csg, total RIH including float equipment 5,165', ran 60 tandem rise centralizers on 1st 62 jts, 1st 3 over stops, the remaining over collars, did not run any centralizers on both windowjts, st wt up 164K, do wt 102K Circ btms up thru Franks fill up tool while conditioning mud. for cementing, staged pump rate up to 6.5 bpm at 525 psi, st wt up 145K, do wt 95K RD Franks fill up tool and MU Dowell's cement head Fin circ and cond mud for cementing, circ at 6.5 bpm at 375 psi, st wt up 165K, do 105K, initial MW out, 9.4 ppg, 66 vis, PV 18, YP 27, Conditioned mud to final MW of 9.05 ppg, 38 vis, 10 YP and 13 PV, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementing csg while circ hole Dowell pumped 5 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 35 add. bbls of CW 100 at rate of 5 bpm @ 320 psi, Pumped 40 bbls of MudPush at 10.5 ppg at rate of 4.6 bpm @ 160 psi, Dropped btm plug then pumped 144.2 bbls, (360 sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 330 psi, Reciprocated pipe with full returns. Drop top plug and Dowell kicked top plug out with 5 bbls fresh water. Rig displaced cement with 9.0 ppg OBM, Bumped plug on calc displacement after pumping 229.4 bbls OBM (Total of 234.4 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Max pressure 1050 psi, Slowed pump rate to 3 bpm (650 psi) with 10 bbls left to pump and bumped plug to 1150 psi, ck floats and held. CIP at 17:35 hrs, 10-6-05. Reciprocated pipe until 134 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 5165.00', Float Collar @ 5075', Calc TOC @ 2529', Had full returns thru out job with a trace of CW 100 back at surface. Well static after shut down. RD cement head ND Btm flange on BOP stack and lifted up same Installed 10 3/4" csg slips, set slips with 75K st wt, cut off csg and LD cut offjt and installed pack-off NU BOP stack Tested 7 5/8" pack-off to 3,500 psi for 10 min, good test Installed wear bushing RU on 10 3/4" x 7 5/8" annulus and performed Infectivity test /LOT to 13.8 ppg EMW, assuming 9.0 ppg MW at 2,201' TVD and 550 psi Began to flush 10 3/4" x 7 5/8" annulus, pumped 40 bbls water, ave 1 bpm at 850 psi Held PJSM and began LD 5" HWDP derrick LD 6 stds of HWDP and 53 stds of 5" DP down out of derrick thru Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 6 of 21 Operations Summary Report Legal WeII Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/7/2005 00:00 - 06:00 I 6.00 DRILL ~ PULD ~ INTRM1 06:00 - 07:30 1.501 DRILL RIRD INTRM1 07:30 - 10:15 2.75 DRILL OTHR INTRM1 10:15 - 11:30 1.25 RIGMNT RSRV INTRM1 11:30 - 12:00 0.50 WELCT BOPE INTRMI 12:00 - 12:15 0.25 DRILL SFTY INTRM1 12:15 - 17:15 5.00 DRILL PULD INTRM1 17:15 - 20:30 3.25 DRILL PULD INTRM1 20:30 - 00:00 I 3.501 DRILL I PULD I INTRM1 10/8/2005 00:00 - 01:30 1.50 DRILL PULD INTRM1 01:30 - 02:00 0.50 DRILL PULD INTRM1 02:00 - 05:30 3.50 DRILL PULD INTRM1 05:30 - 09:45 4.25 DRILL TRIP INTRMI 09:45 - 10:15 0.50 DRILL CIRC INTRM1 10:15 - 12:00 I 1.751 CASE I DEOT I INTRM1 12:00 - 14:30 I 2.501 CEMEN~(DSHO I INTRM1 14:30 - 15:00 I 0.501 DRILL I CIRC I INTRM1 15:00 - 15:30 I 0.501 DRILL I LOT I INTRM1 15:30 - 00:00 I 8.501 DRILL I DRLG I PROD 10/9/2005 100:00 - 12:00 ~ 12.001 DRILL ~ DRLG ~ PROD 12:00 - 00:00 I 12.00 I DRILL I DRLG I PROD Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Releaser 10/30/2005 Group: Rig Number. Description of Operations mousehole , at 01:45 hrs, 2 hrs from initial 40 bbl water flush, pumped an additional 10 bbls of water down 10 3/4" x 7 5/8" annulus at 1.5 bpm at 850 psi RU Sperry Sun's Geo-Span unit on rig floor, At 06:15 hrs (12.75 hrs after bumping plug) finished flushing annulus with 100 bbls of water, ave 2 bpm, max pressure 900 psi, ave 825 psi, flushed annulus with 154 bbls water total Changed over top drive saver sub to 4" XT-39 Slip and cut 38' of drilling line, serviced top drive and drawworks Tested 4" floor valve and dart valve to 250 psi low and 3,000 psi high, 1st dart valve test failed, tested back-up dart valve and tested ok Held PJSM on PU DP and installing Lo-Tads RIH with 90 jts of 4" DP, POOH installing 30 Lo-tads. At 13:30 RU little Red on 103/4" x 7 5/8" annulus and freeze protected same with 80 bbls diesel, ave 1 bpm at 1.,050 psi. Strapped and stood back 6 stds of hybrid push pipe with 2-4 3/4" Dc's and 1 HWDP on top, then PU and stood back 7 stds of 4" HWDP PU out of pipe shed 138 jts of 4" DP and RIH, preparing to POOH & stand back same POOH and stood back 46 stds of 4" DP PU 6 3/4" BHA to rig floor MU 6 3/4" BHA #3 and RIH to 369', MU 6 3/4" bit #3 with 4 3/4" model 5200 Geo-pilot and MWD, uploaded MWD and RIH PU 3-NMFDC's, HWDP and jars, shallow tested MWD and broke in Geo-pilot RIH with BHA #3 from 369' PU 4" DP, PU 147 jts of DP RIH to 5,034' Circ btms up at 5,034', circ at 327 gpm at 2,800 psi, st wt up 96K, do wt 73K I RU and tested 7 5/8" csg to 3,000 psi for 30 min, pressure bled down 130 psi in 30 min, bled off pressure and re-pressured up to 3,050 psi and held for 15 min and held ok Drilled out float collar at 5,075', shoe track and float collar at 5,165', cleaned out to TD at 5,172' then drilled 20' of new formation to 5,192', drilled out at 2-10K wob, 90 rpm's, 70 spm, 248 gpm, 1,850 psi Circ btms up for LOT, circ at 320 gpm at 2,900 psi, 90 rpm's and 4K ft-Ibs torque, rot wt 85K, up wt 97K, do wt 72K, 8.9 ppg MOBM MW in & out with 10.0 ppg clean hole ECD Performed LOT to 13.6 ppg EMW, 900 psi at 3,649' TVD with 8.9 ppg MOBM Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 5,192' to 5,769' MD/3,652' TVD (577') ART 6.29 hrs, 4-10K wob, 120 rpm's, 84 spm, 300 gpm, off btm pressure 2,500 psi, on btm 2,600 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt 82K up wt 97K, do wt 68K, 8.95 ppg MOBM, ave ECD 9.9 ppg, ave BGG 25 units, max gas 66 units, drilled thru 8 concretions for a total of 50' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 5,769' to 7,043' MD/3,636' TVD (1,274') ADT 8.59 hrs, 5-15K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 81 K up wt 108K, do wt 62K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 25 units, max gas 118 units, drilled thru 10 concretions for a total of 80' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot Printed: 12/9/2005 3:20:17 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 07:00 - 07:30 07:30 - 08:00 Date From - To Hours Code Sub Phase Code 10/9/2005 ~ 12:00 - 00:00 12.00 ~ DRILL ~ DRLG ~ PROD 110/10/2005 100:00 - 07:00 08:00 - 09:30 110/11 /2005 09:30 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 19:30 19:30 - 20:15 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon141 7.00 DRILL DRLG PROD 0.50 DRILL CIRC PROD 0.50 DRILL ~ DRLG PROD 1.501 DRILL I CIRC I PROD 5.501 DRILL I REAM I PROD 1.00 DRILL CIRC PROD 2.00 DRILL TRIP PROD 1.50 DRILL CIRC PROD 0.751 DRILL CIRC PROD 20:15 - 00:00 3.75 DRILL TRIP PROD 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 01:00 0.50 DRILL PULD PROD 01:00 - 02:00 1.00 DRILL PULD PROD 02:00 - 03:00 1.00 DRILL PULD PROD 03:00 - 03:30 ' 0.50 DRILL PULD 'CMPLTN 03:30 - 03:45 0.25 LOG SFTY CMPLTN Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 7 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations assembly from 7,043' to 8,321' MD/3,635' TVD (1,278') ADT 8.46 hrs, 4-10K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,125 psi, on btm 3,150 psi, off btm torque 5.5K ft-Ibs, on btm 5.5K tt-Ibs, rot wt 80K up wt 110K, do wt 54K, 9.0 ppg MOBM, ave ECD 11.15 ppg, ave BGG 30 units, max gas 97 units, pumped weighted hi vis sweeps at 7,650' with a 50% increase in cuttings and 7,837' with 25% increase in cuttings Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 8,321' to 8,997' MD/3,642' TVD (671') ADT 5.12 hrs, 5-12K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,150 psi, on btm 3,200 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 82K up wt 120K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.25 ppg, ave BGG 30 units, max gas 76 units, pumped weighted hi vis sweep at 8,415' with a 10% increase in cuttings Trouble shoot problem with MWD computer, reboot same and ck ok Directionally drilled 6 3/4" hole from 8,997' to 9,063' MD/3,643' TVD (66') ADT .36 hrs, determined to have crossed fault at 8,370' and zone below fault was wet, decision was made to stop drilling on A2 lateral Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ at 330 gpm, 3,200 psi and 130 rpm's, rot wt 83K up wt 120K, do wt 55K, monitored well-static Backreamed out of hole from 9,063' to to 5,130' (7 5/8" shoe @ 5,165') BROOH at 130 rpm's, 330 gpm, initial circ pressure 3,200 psi, final circ pressure 2,800 psi, no problems BROOH to 5,130' rot wt 83K, up wt 110K, do wt 60K Pumped 35 bbl weighted hi vis sweep and circ hole clean at 5,130', had 5% increase in cuttings back from sweep, circ at 330 gpm, 2,550 psi and 130 rpm's with 3.5K ft-Ibs torque, circ 3X btms up and was clean at shakers, monitored well-static RIH from 5,103' to 9,000', washed 63' to btm at 9,063' with no problems Pumped weighted hi vis sweep and circ out of hole, had no increase in cuttings back from sweep and was clean at shakers, circ at 330 gpm, 3,200 psi, 130 rpm's with 5.5K ft-Ibs torque Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 330 gpm at 3,350 psi, 130 rpm's and 5.5K ft-Ibs torque, rot wt 85K, up wt 117K, do wt 57K gpm, monitored well-static POOH wet from 9,063' to 1,768', POOH 5 stds and hole took talc fill, dropped 1 7/8" rabbit on a wire and cunt POOH to 1,768' Continue POOH from 1768' - 368' (1400'). POOH, breakout & lay down BHA. Rack Back HWDP with Jars and NMDC's. Download MWD assembly. Continue lay down 6 3/4" PDC Security FSF2641 bit w/ .5591 restrictor (1.26') TFA = 1.015 Sq In, 4 3/4" 5200 Geo-Pilot (16.20'), GP Non-Mag Flex Pony Collar (11.54'), DM Collar (8.56'), 4 314" Smart Stabilizer 3.59'), 4 3/4" Slimphase 4 with DGR & EWR Phase (24.16'), PWD collar (10.76'), TM HOC (11.12'), Non-Mag Float sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'), 3 -Non Mag Flex drill collars (92.76'), Crossover sub (1.07'), 2 -stands of 4" HWDP with jars (180.27'). Bit Gauged at 1 / 1 / CT / G /0 / I / EC ! TD Clean Floor area, and lay down tools at beaver slide. Held PJSM with crew and Schlumberger hands. Discuss Safety and wireline PUlLD procedures. Td 7- /S~/ b x.06 Printetl: 1L920US 3:"LU:1/ PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date .From - To Hours Code Code Phase 110/11 /2005 ~ 03:45 - 06:00 ~ 2.25 LOG PULD CMPLTN 06:00 - 07:30 ~ 1.50 LOG ~ ELOG ~ CMPLTN 07:30 - 12:00 I 4.501 LOG ELOG CMPLTN 12:00 - 14:30 2.501 LOG OTHR CMPLTN 14:30 - 15:00 ~ 0.50 ~ LOG ~ OTHR ~ CMPLTN 15:00 - 15:30 0.50 LOG ELOG CMPLTN 15:30- 16:30 1.00 LOG ELOG CMPLTN 16:30 - 17:00 0.50 LOG ELOG CMPLTN 17:00 - 18:00 18:00 - 00:00 1.00 LOG ELOG CMPLTN 6.00 LOG ELOG CMPLTN 110/1212005 100:00 - 01:00 1.00 I LOG ELOG CMPLTN 01:00 - 01:30 I 0.501 LOG I ELOG I CMPLTN 01:30 - 02:00 0.50 LOG ELOG CMPLTN 02:00 - 02:45 0.75 LOG ELOG CMPLTN 02:45 - 03:45 1.00 LOG ELOG CMPLTN 03:45 - 05:00 1.25 LOG ELOG CMPLTN 05:00 - 06:30 1.50 LOG ELOG CMPLTN 06:30 - 09:15 2.75 LOG ELOG CMPLTN 09:15 - 11:15 2.00 LOG ELOG CMPLTN 11:15 - 12:00 0.75 CASE RURD CMPLTN 12:00 - 15:00 3.00 CASE RUNC CMPLTN 15:00 - 16:00 ~ 1.00 CASE I RUNC ~ CMPLTN 16:00 - 19:30 3.501 CASE RUNL CMPLTN Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 8 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations Rig up Schlumberger wireliners, and equipment. Pull tools to rig floor and make up same. Wireline in hole with USIT bond logging tools on Welltec tractor, to 4000' where observed tractor failure. Communication through tractor failed to logging tools. Could not "start" tractor. POOH with USIT logging tools and tractor. Lay down tractor and tools,. and trouble shoot problem. Note: Make a trip in to Deadhorse to retrieve test cable. Continue troubleshoot Welltec tractor problem. Suspect oil viscosity not correct and observe burnt head. Install correct oil, and change head. Make up USIT bond logging tools with Welltec tractor. Perform surface test and tools tested good, WLIH with tools and tractor to 5051'. Turn on Logging tools, all OK. Attempt to log from 5051' to 4010' (1041'), Tools failed (No log acquired). Unable to get Logging tools to work, trouble shoot and attempt to gain communication. WLOH from 4010' to surface. Breakout and lay down tools. Change out transducer. Trouble shoot tractor. Observed wires were damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. Continue change out transducer. Trouble shoot tractor. Observed wires were damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. PJSM with crew. Discuss Safety and handling procedures. Pull Well Tech tractor to rig floor. MU on wireline USIT logging tools and surface test same. Good test. WLIH from surface to 1700': Observe tool failure. No Communication through tractor. WLOH, breakout i~ lay down Well Tech Tractor. Prep Schlumberger Tractor. Pull tractor to floor and MU to E-Line tools. Surface test same. Good Test. WLIH to 5055' WLM. Tractor working fine. Locate & perform USIT Bon Log from 5050' - 2200' (2850'). WLOH to surface, breakout & lay down E-Line USIT logging tools. Rig up Liner running equipment, slips, power tongs etc... Make up 4 1/2"joint (30.83') blanked off on end with crossover (2.03') and Swell Packer with pups (19.55'), and crossover (2.07'). Pick up 4 1/2 slotted /blank liner assembly, RIH to 3610'. Run total of 57 blank joints, 59 slotted joints with a total of 7 constrictor packers spaced out to be at 7815', 7484', 7035', 6885', 6425', 6135', and 5415'. Make up 4 3/4" Casing Seal Bore Ext. and Crossover Bushing with pups (24.83'), Flexlock Liner Hanger 5.5" x 7.6" (9.82'), 5 1/2" "RS" packoff Seal Nipple (2.85'), and "HRD" ZXP Liner top Packer (19.05'), with Liner Running Tool and XO (11.04'). Add PAL mix as per BOT Rep. RIH with 4 1/2" Liner assembly on 4" DP from 3673' - 8125' (4452') with SLM, and 1 7/8" Drift in Drill Pipe.. PU WT = 120K, SO WT = 80K. 19:30 - 20:15 0.75 CASE RUNL ~ CMPLTN I Locate bottom of liner at 8126', drop b1 7/16" Ball, allaow to fall and pump down at 35 SPM, 375 PSI, until observed ball seated. Pressure up to 1300 PSI, set Liner Hanger, and continue Pressure up to 4000 Printed: 12/9/2005 320:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common W ell Name: 1J-154 Event Nam e:. ROT -D RILLIN G Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To Hours Code Phase Code 10/12/2005 19:30 - 20:15 0.75 CASE RUNL CMPLTN 20:15..- 21:00 0.75 CASE RUNC CMPLTN 21:00 - 21:30 0.50 CASE CIRC CMPLTN 21:30 - 23:30 2.00 CASE RUNC CMPLTN 23:30 - 00:00 0.50 CASE RUNC CMPLTN 10/13/2005 00:00 - 00:30 0.50 WINDO ULD PROD2 00:30 - 03:00 2.50 WINDO ULD PROD2 03:00 - 04:00 1.00 WINDO THR PROD2 04:00 - 04:30 0.50 WINDO ULD PROD2 04:30 - 04:45 0.25 WINDO THR PROD2 04:45 - 07:15 2.50 WINDO RIP PROD2 07:15 - 08:15 1.00 WINDO THR PROD2 08:15 - 09:15 1.00 WINDO ETW PROD2 09:15 - 09:45 0.50 WINDO IRC PROD2 09:45 - 12:00 2.25 WINDOW STWP PROD2 12:00 - 14:45 2.75 WINDO TWP PROD2 14:45 - 15:45 1.00 WINDO i TWP PROD2 15:45 - 18:30 2.75 WINDOW i'RIP PROD2 18:30 - 20:00 I 1.50 WINDOW PULD PROD2 Page 9 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations PSI to set Z:XP PKR. Observe "bobble" on weight indicator at 3500 PSI. Bleed pressure. Rig up to test. Pump down annulus to pressure test to 1000 PSI for 10 minutes. Good test. All pressures and test recorded on chart. Pull out of ZXP PKR to allow "dogs" to kick out and Slack off to verify Top of Liner at 4464' DPM. Repeat. PU WT = 105K, SO WT = 90K. Pull out of Liner assembly with setting tools and CBU at 83 SPM - 1400 PSI. Monitor well -Static POOH from 4394' - 15'. Observe well taking proper fill. Breakout & lay down running tool. Inspect seals and breaks, all looked good as per BOT rep: Clean floor area, Pull tools to rig floor. Held PJSM. Discuss Safety and Whipstock assembly make up procedure. Make up 7 5/8" Whipstock assmy. MU 5 11/16" Seal assmy with No-Go Locator Sub (4.76'), 4 5/8" Unloader sub (5.1.9'), 3 - 3 1/2" IF pup joints (4.72', 6.52', 16.46'), 1 -jnt 3 1/2 DP (31.21'), Blanking sub (1.28'), 7 5/8" Bottom Trip Anchor (3.23'), 4 5/8" Shear Disconnect Sub (2.69'), 4 3/4" Ported drain Sub (1.47'), 4 11/16" Debris Barrier sub with cup (1.86'), & 5/8" Whipstock Slide (14.42'), 6.156" Starting Mill (1.08'), 6.30" Lower MiII (5.46'), 6 3/4" Upper Mill (5.81'), 1 -jnt 3 1/2" HWDP (29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly (43.43'), 2 - 4 3/4" Bumper Jars (7.85', 7.86' ), 4 3/4" Crossover. Install 35K shear Bolt on starting mill. BTA shear setting = 14K. Plug In & Upload MWD assembly. Make up remaining BHA. PU 2 -stands Hybrid Push Pipe (178.98). Total BHA = 378.57. Screw into string with TD, and perform Shallow pulse test. Good test. 300 GPM's - 1000 PSI. Trip in hole with whipstock assembly from 378' - 3622' (3244') at 2 minutes per stand as per BOT rep. PU WT = 92K, SO WT = 82K Perform MAD PASS log from 3622' - 3822 ' (200') @ 240' FT/HR Continue TIH from 3822' - 4465' (643'). Orient Whipstock Face as per DD and Co. Rep to 10 Degrees Left of High Side. Slack off and tag Top of Liner with Seals @ 4465' DPM. Set BTA, and verify set by pulling 10K over up weight. Slack off and shear bolt @ 35K down weight. Pull to Neutral position and obtain free rotation. PU WT = 104K, SO WT = 87K, ROT WT = 82K, TO = 2-5K. Displace well from 9.0 PPG SFMOBM to 9.0 PPG MOBM @ 300 GPM's - 2100 PSL Mill window from 4374' - 4381', @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mud Wt = 8.9 PPG, Visc = 74 and YP = 16 Continue mill window from 4381'- 4386'. Continue mill in open hole to 4416' allowing 20' of gauged hole out of bottom of window, @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mill 12' WINDOW IN 4.93 HRS for an avg ROP of 4.36 FT/HR Pump Hi Visc sweep @ 4416'. Circulate out while working mills through window until clean. Window looked good.- Monitor well -static. Pump dry job. Pooh from 4416' - 378' (4038'). Breakout & lay down Milling BHA. Lay down 6.156" Starting Mill (1.08'), 6.30" Lower Mill (5.46'), 6 3/4" Upper Mill (5.81'), 1 - jnt 3 1/2" HWDP 29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly 43.43'), 2 - 4 3!4" Bumper Jars (7.85', 7.86' ), 4 3/4" Crossover. Gauge ~r <sY L/ y ~~ ~ ,.I o Printed: 12/9{2005 3:20:17 PM • • ConocoPhillips Alaska Page 10 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Phase Code __ _ - 10/13/2005 .18:30 - 20:00 1.50 WINDOV ~IPULD PROD2 20:00 - 20:15 0.25 WINDO THR PROD2 20:15 - 20:45 0.50 WINDO THR PROD2 20:45 - 00:00 3.25 WELCT. BOPE PROD2 10/14/2005 ~ 00:00 - 01:00 ~ 1.00 ~ WELCTL~ BOPE I PROD2 0.1:00 - 01:30 0.50 WELCT BOPE PROD2 01:30 - 02:45 1.25 DRILL PULD PROD2 02:45 - 03:30 0.75 DRILL OTHR PROD2 03:30 - 04:30 1.00 DRILL OTHR PROD2 04:30 - 06:15 I 1.751 DRILL I TRIP I PROD2 06:15 - 06:45 0.501 DRILL I TRIP PROD2 06:45 - 12:00 I 5.251 DRILL I DRLG PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group:. Rig Number. Description of Operations Upper mlll to full gauge of 6 3/4". BOLDS and pull wear bushing. Make up stack washing tool and flush stack. Rig down same. Install test plug. Test BOP stack and all choke manifold valves, Upper & lower IBOP on TD, HCR -, Choke and Kill, Manual Choke and Kill, Dart valve and floor safety valve. Perform Accumulator function test to 3:47 Minutes. All test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived witness of test. Chuck Sheave. Continue Perform Accumulator function test to recovery of 3:47 Minutes. Test Annular, and Blind rams. All test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived witness of test. Chuck Sheave. Rig Down test equipment,. Install Wear Bushing, RILDS PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA. Pull tools to floor. Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor (32.50'), 4 3/4" Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer (5.24'), DM HOC (8.49'), Slimphase 4 w/ DGR & RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'), 3 - 4 3/4" Non Mag Flex Drill Collars 92.76'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.13'), 4 3/4" Drilling jars (177.63 Hrs on 10/10/05) (28.90'), 4 - Jnts 4" HWDP 121.24'). Total BHA length = 369.32'. Plug in and upload MWD assembly. RIH & RU. Perform Shallow pulse test @ 86 SPM, 305 GPM's - 1700 PSI. Trip in hole from 369' - 4290' (3921'). Orient bit & motor to High side above top of window area @ 4374'. Work 6 3/4" Bit and drilling assembly through window area from 4374' to 4386' DPM. Observed tag at 9' down whipstock to take 8K in downweight. Pull up above window, RIH to observe little or no tag and continue in through window to open hole depth at 4400'. Suspect cement chunks on slide. Wash down from 4400' - 4416' (16'). PU WT = 91 K, SO WT = 75K. Baker rep on floor to witness Drilling assembly through whipstock. Directional drill 6 3/4" Hole from 4416' - 4508' MD (92'). TVD = 3514'. ART = 1.94 HRS, AST = 2.64 HRS, ADT = 4.58 HRS. PU WT = 93K, SO WT = 72K, ROT WT = 81 K, Torque off btm = 3K, Torque on bottom = 4K. WOB = 2-10K, RPM's = 80, Pumps @ 85 SPM, 300 GPM's - 2300 PSI. Total Jar Hrs = 182.21. Total Bit Hrs = 4.58. Clean hole ECD at 9.8 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4400' MD, 3514' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 590 PSI. Pump #2 - 25 SPM - 430 PSI, 35 SPM - 650 PSI. Observed Drilling through Concretion at 4453' - 4501' (48'). Continue Directional drill 6 3/4" Hole from 4508' - 5224' MD (716'). TVD = 3516'. ART = 3.14 HRS, AST = 2.74 HRS, ADT = 5.88 HRS. PU WT = 100K, SO WT = 64K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-10K, RPM's = 80, Pumps @ 93 SPM, 330 GPM's - 2300 PSI. Total Jar Hrs = 188.09. Total Bit Hrs = 10.45 ECD at 9.3 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 5029' MD, 3524' TVD. Pump #1 - 20 SPM - 360 PSI, 30 SPM - 540 PSI. Pump #2 - 20 SPM - 400 PSI, 30 SPM - 560 PSI. Observed Drilling Printed: 12/9/2005 320:17 PM • ConocoPhillips Alaska Page 11 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/14/2005 112:00 - 00:00 10/15/2005 100:00 - 12:00 12.001 DRILL I DRLG I PROD2 12.00 I DRILL I DRLG I PROD2 12:00- 00:00 I 12.001 DRILL I DRLG I PROD2 110/16/2005 100:00 -D7:45 I 7.751 DRILL I DRLG I PROD2 07:45 - 08:45 I 1.001 DRILL I CIRC I PROD2 08:45 - 11:15 I 2.501 DRILL I TRIP PROD2 11:15 - 12:00 I 0.751 DRILL (TRIP I PROD2 12:00 - 13:30 1.50 DRILL TRIP PROD2 13:30 - 14:00 0.50 DRILL TRIP i PROD2 14:00 - 14:30 0.50 DRILL OTHR ~ PROD2 14:30 - 16:00 1.50 DRILL PULD ~ PROD2 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations through Concretions at 4602' - 44614' (12'}, 4618' - 4628' (10'), 4633'-4640' (7'), 5223' - 5231' (8'), 5236' - 5248' (12'), 5259' - 5268' 9'). Encountered Fault @ 4697 MD, with a 12' down throw. Continue Directional drill 6 3/4" Hole from 5224' - 6130 MD (906'). TVD = 3501'. ART = 5.65 HRS, AST = 1.94 HRS, ADT = 7.59 HRS. PU WT = 105K, SO WT = 62K, ROT WT = 80K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-10K, RPM's = 80, Pumps @ 93 SPM, 330 GPM's - 2800 PSI. Total Jar Hrs = 195.68. Total Bit Hrs = 18.65 ECD at 10.2 PPG. Mud WT = 8.9 PPG Viscosity = 77, YP = 19. SPR's @ 5968' MD, 3512' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 580 PSI. Pump #2 - 25 SPM - 520 PSI, 35 SPM - 610 PSI. Observed Drilling through no Concretions this tour. Survey @ 6014' MD ,'3506 TVD -Inc = 92.8 Deg. AZ = 176 Deg. Continue Directional drill 6 3/4" Hole from 6130' - 7187 MD (1057). TVD = 3482'. ART = 6.77 HRS, AST = .47 HRS, ADT = 7.24 HRS. PU WT = 105K, SO WT = 60K, ROT WT = 83K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-5K, RPM's = 80, Pumps @ 86 SPM, 302 GPM's - 2700 PSI. Total Jar Hrs = 202.92 Total Bit Hrs = 25.29 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 67, YP = 19. SPR's @ 6949' MD, 3484' TVD. Pump #1 - 25 SPM - 450 PSI, 35 SPM - 640 PSI. Pump #2 - 25 SPM - 480 PSI, 35 SPM - 690 PSI. Observed Drilling through concretions @ 7099' - 7110' (11'). Survey @ 7043' MD 3484 TVD -Inc = 91.1 Deg. AZ = 180 Deg. Continue Directional drill 6 3/4" Hole from 7187' - 7691' MD (504'). ND = 3472'. ART = 4.4 HRS, AST = .97 HRS, ADT = 5.37 HRS. PU WT = 106K, SO WT = 56K, ROT WT = 80K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-18K, RPM's = 80, Pumps @ 86 SPM, 302 GPM's - 2700 PSI. Total Jar Hrs = 208.29 Total Bit Hrs = 30.66 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 19. SPR's @ 7641' MD, 3474' TVD. Pump #1 - 25 SPM - 480 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 650 PSI. Observed Drilling through concretions @ 7261' - 7280' (19'),7299' - 7306' (7'), 7312' - 7319' (7'), 7339' - 7348' (9'), 7354' - 7360' (6'), 7457' - 7459' (2'), 7470'- 7487 (17'), 7524' - 7528' (4'), 7639' - 7655' (16'). Survey @ 7623' MD 3474 TVD -Inc = 91.06 Deg. AZ = 180 Deg. Observed running out of down weight to Slide as per DD. Decision to POOH fo BHA change. Pump Weighted sweep @ 93 SPM, 340 GPM's, 3100 PSI while reciprocating drill string at 80 RPM's with TO @ 5K. Observed 15% increase in cuttings at shaker when sweep returned. POOH from 7691' - 4374' (3317'). Added NRP Super Sliders to Lo-Tad stands on stands # 78,77,76,75,74,73. 1per joint as reccomended. Pulled assembly through window area with no issues. Observed clean hole conditions while POOH and proper hole fill Monitor well -static. Pump dry job, and blow down TD. Continue POOH to 4289'. Continue POOH from 4289' - 369' (3920') Monitor well. POOH stand back Drilling Jars, HWDP and NM Flex drill collars. Total Length = 274.10'. Plug in and down load MWD assembly. POOH, breakout & lay down remaining BHA. Layed down 4.60" TM HOC (11.12'), PWD Collar (10.76'), 4 3/4" Slimphase 4 w/ DGR & RES. (23.82'), DM HOC (8.49'), 4 3/4" Integral Blade stabilizer (5.24'), 4 3/4" Non Mag Float sub (2.49'), 5" Sperry Drill lobe 7/8 -6.0 Stage Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 12 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 10/16/2005 14:30 - 16:00 1.50 ~ DRILL PULD I PROD2 16:00 - 16:30 0.50 DRILL PULD PROD2 16:30 - 18:00 1.50 DRILL PULD PROD2 18:00 - 18:30 0.50 DRILL OTHR PROD2 18:30 - 19:15 0.75 DRILL PULD PROD2 19:15 - 20:00 0.75 DRILL OTHR PROD2 20:00 - 21:30 1.50 DRILL TRIP PROD2 21:30 - 23:00 1.50 RIGMNT RSRV PROD2 23:00 - 00:00 1.00 DRILL TRIP PROD2 110/17/2005 100:00 - 01:15 I 1.25 I DRILL ~ TRIP ~ PROD2 01:15 - 02:00 0.751 DRILL REAM PROD2 02:00 - 12:00 I 10.00 I DRILL DRLG ~ PROD2 12:00 - 00:00 I 12.001 DRILL I DRLG I PROD2 10/18/2005 i 00:00 - 08:45 I 8.751 DRILL i DRLG I PROD2 32.50), and 6 3/4" Reed Hycalog PDC CRXE1005 Bit. Gauge bit to 1 / 1 / NO /ALL / / 1/ NO / PR NOTE: Pictures of Bit sent to Engineer Clean & clear rig floor area, lay down tools. PJSM with crew. Discuss Safety Issues and BHA pick up procedure. MU BHA #6. Make up 6 3/4" SDBS FAF2641Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR & EWR phase 4 23.82'), PWD Collar (10.76'), TM HOC (10.07'), 4 3/4" Non Mag Float Sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). Plug in and down load MWD assembly. Continue MU BHA #6 picking up 3-jnts Non Mag Flex Drill Collars 92.76'), Crossover sub (1.07'), 1 - jnt 4" HWDP (30.13'), 4 3/4 Drilling Jars (28:90'}, and 4-jnts 4" HWDP (121.24'). - Perform shallow pulse test and test Geo-Pilot. Trip in hole from 36T - 4288' (3921'). Fill DP every 25 stands. PJSM, RU and Slip & Cut 72' of Drilling line. Inspect and adjust brakes on draw works. Fill Drill string and RIH from 4288' - 4611' (323'). Pump to check Geo -Pilot tools. Observed no issues with BHA assembly passing through window area from 4374' - 4386'. Tag Spot @ 4611. DPM. MU Top Drive and rotate & pump through spot ,with no issues. Continue TIH form 4611' - 7573' (2962'), with little or no issues. Wash & Ream hole from 7573' -7691' (118'), to tag bottom on depth. Pumps @ 300 GPM's, 84 SPM -2650 PSI. 80 RPM's and 5K Torque. Down Link Geo -Pilot tool. Continue Directional drill 6 3/4" Hole from 7691' - 8691' MD (1000'). TVD = 3479'. ART = 6.56 HRS, PU WT = 116K, SO WT = 50K, ROT WT = 80K, Torque off btm = 5.5K, Torque on bottom = 6K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Total Jar Hrs = 213.85 Total Bit Hrs = 5.56 ECD at 11.03 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 7765' MD, 3469' TVD. Pump #1 - 25 SPM - 470 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 620 PSI. Observed Drilling through concretions @ 7690' - 7702' (12'), 7712' - 7714' (2'), 7745' - 7750' (5'), 7764' - 7767' (3'), 8509' - 8514' (5'), 8526' - 8530' (5'), 8538' - 8540' 2'), 8582' - 8591' (9'), 8621' - 8624' (3'). Survey @ 8698' MD , 3482 TVD -Inc = 88.4 Deg. AZ = 182.4 Deg. Pumping weighted sweeps to control ECD and clean hole. Continue Directional drill 6 3/4" Hole from 8691' - 10081' MD (1390'). TVD = 3470'. ART = 8.01 HRS, PU WT = 120K, SO WT = 45K, ROT WT = SOK, Torque off btm = 6K, Torque on bottom = 7K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3250 PSI. Total Jar Hrs = 221.86 Total Bit Hrs = 14.57 ECD at 11.04 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 8733' MD, 3483' TVD. Pump #1 - 25 SPM - 480 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM - 740 PSI. Observed Drilling through concretions @ 8708' - 8720' (12'), 8732' - 8741' (9'), 8768' - 8772' (4'), 8797' - 8812' (15'). Survey @ 10045' MD , 3468.5 TVD -Inc = 89.10 Deg. AZ = 183.74 Deg. Pumping weighted sweeps to control ECD and clean hole: Continue Directional drill 6 3/4" Hole from 10081' - 11285' MD (1204'). TVD = 3455'. ART = 5.37 HRS, PU WT = 145K, SO WT = 40K, ROT I S` (S~ c- E- T~ ~D i-18~' rnntea: i~ar~wa s:z~:v rm • ConocoPhillips Alaska Page 13 of 21 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon 141 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Date From - To Hours Code Code Phase 110/18/2005 100:00 - 08:45 08:45 - 10:15 10:15 - 12:00 8.751 DRILL I DRLG I PROD2 1.501 DRILL I CIRC I PROD2 1.751DRILL (WIPR IPROD2 12:00 - 14:00 2.00 DRILL WIPR PROD2 14:00 - 15:00 1.00 DRILL ~ CIRC PROD2 15:00 - 20:00 I 5.001 DRILL IWIPR I PROD2 20:00 - 23:30 I 3.501 DRILL I REAM I PROD2 23:30 - 00:00 0.501 DRILL CIRC PROD2 110/19/2005 100:00 - 01:30 I 1.501 DRILL I CIRC I PROD2 01:30 - 03:15 1.751 DRILL CIRC . PROD2 03:15 - 12:00 I 8.75) DRILL I TRIP I PROD2 12:00 - 13:00 I 1.001 DRILL I PULD I PROD2 13:00 - 14:00 1.00 DRILL OTHR PROD2 14:00 - 15:00 1.00 DRILL PULD PROD2 Description of Operations WT = 95K, Torque off btm = 8K, Torque on bottom = 8K. WOB = 5-10K, RPM's = 80 -120, Pumps @ 93 SPM, 330 GPM's - 3900 PSI. Total Jar Hrs = 227.23 Total Bit Hrs = 19.93 ECD at 11.55 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 18. SPR's @ 11262' MD, 3455' TVD. Pump #1 - 25 SPM - 650 PSI, 35 SPM - 840 PSI. Pump #2 - 25 SPM - 600 PSI, 35 SPM - 820 PSI. Survey @ 11285' MD , 3455.63 TVD -Inc = 90.53 Deg. AZ = 172.41 Deg. MAX GAS = 107 Units. Pumping weighted sweeps to control ECD and clean hole. Rack Back 1 stand DP. Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. Monitor well -static. POOH on elevators from 11285' - 10538' (747'). Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. Continue POOH on elevators from 10538' - 4350' (6188'). Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. Pull to above top of window @ 4374'. MU top Drive and Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. Monitor well -static. Trip back in hole from 4350' - 9123' (4773'). Observe clean hole•conditions,no hanging up issues, but ran out of down weight to continue in on elevators. MU top drive on each stand and wash & ream from 9123' - 11284' 2161') @ 2-3 minutes per stand. Observed no hole condition issues and string went to bottom good @ 62 SPM - 1600 PSI, 60 RPM's - 5K torque. Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate & rotate drill string. Rack back 1 stand. Continue circulate pumping Hi Visc weighted sweep @ 11266' working string. Continue Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate & rotate drill string, pumping Hi Visc weighted sweep + 1 Bottoms up @ 11266' working string. Observe 10% increase in cuttings across shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 88 SPM -.4150 PSI. Vac truck broke down and we slowed pumps to 60 SPM - 2200 PSI on last 70 BBIs of displacement. Obtain Slow pump rates @ 11266' MD 3455 TVD. Pump #1 - 25 SPM - 560 PSI. 35 SPM - 750 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM - 670 PSI. PU WT = 145K, SO WT = 35K, ROT WT = 92K. 140 RPM's - 7.5K TQ Monitor well -static. POOH from 11266' - 367' (10900'). Install Super Sliders in the middle of each joint of Lo-Tad stands on TOH. Total installed = 90. Change out drilling jars and rack back HWDP & NM Flex Drill collars. (181.27). Plug in and download MWD assembly. Breakout & lay down remaining BHA #7. 6 314" SDBS FAF2641Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR & EWR phase 4 23.82'), PWD Collar (10.76'), TM HOC (10.07'), 4 3/4" Non Mag Float Sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). Bit Gaugedto3/1 /WT/N/X/IlERlTD. Printed: 12/9/2005 3:20:1 7 PM - • 1.001 WIN ConocoPhillips Alaska 0.50 WIND 0.75 CMPL Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/19/2005 15:00 - 15:30 0.50 WIN 15:30 - 18:30 3.00 WIN 18:30 - 19:00 0.50 WIN 19:00 - 19:30 0.50 WIN 19:30 - 00:00 . 450 WIN 10/20/2005 00:00 - 01:00 01:00 - 01:30 01:30 - 02:15 02:15 - 02:30 02:30 - 09:15 09:15- 09:30 09:30 - 11:30 11:30 - 12:00 12:00 - 15:00 15:00 - 17:00 Operations Summary Report rOTHR CMPLT2 rrRIP CMPLT2 'OTHR CMPLT2 CIRC CMPLT2 TRIP CMPLT2 PULD CMPLT2 PULD CMPLT2 RURD CMPLT2 0.251 CMPLTNI SFTY I CMPLT2 6.751 CMPLTNI RUNT I CMPLT2 • Page 14 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10!30/2005 Group: Rig Number: Description of Operations Clean 8~ Clear Rig Floor area, lay down all tools. PJSM with crew. Discuss safety issues and procedure for BHA make up. Make up 7 5/8" Whipstock retrieving tools. Make up Fixed Lug retrieving tool (7.49'), 1 jnt 3 1/2 HWDP (29.84'), 4 3/4" Float sub 2.49'), 4 314" Bumperjar (7.85'), 4 3/4" Oil Jar (11.13'), Crossover sub ( 1.66'), and 18 juts 4" HWDP (543.62'). Total BHA = 604.08'. Trip in hole with BHA above top of whipstock. UP WT = 94K, SO WT = 73K. Slack off and locate slot washing down past slot to clean it up. Pull up to observe hooked whipstock slide. Located slot @ 4377' per BOT rep. Pull to 150K to observe jars fire and assembly free. Observe 5K increase in upweight. Pull up hole 30' verify swabbing. Circulate bottoms up @ 71 SPM - 920 PSI. Verify no gas and monitor well -static. POOH. slow at 10-15 ft/minute-for 15 stands with proper hole fill as we observed swabbing by pulling faster. Cup wore out. and continue POOH at an increased rate observing hole taking proper hole fill. PuIlWhipstock slide to rotary table. PJSM with crew. Mill marks on slide indicated milling down to 10' on slide. Continue breakout & lay down 7 5/8" Whipstock assembly and space out pipe. Clean & Clear Rig floor area, and send tools down slide. .Rig up Liner running equipment, power tongs, slips, elevators etc.. Pull 89 HydroFORM centalizers to rig floor. PJSM with crew, and BOT reps. Discuss safety issues and procedure to run 4 1/2" IBT liner and Hook Hanger assembly. Verify joint placement in pipe shed in correct running order. Make up 3 1/2" Bent joint with Open guide shoe (20.42'). Breakout pack off bushing from top of joint. Install IBT Crossover (1.45'), and continue RIH making up 4 1/2" 12.6# IBT slotted /blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #96, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10750',10518',10010',9716', 9208',8974',8465',8170',7542',7313',6804',6 572',6065',5775',5360',5156',4865', and 4568'. RIH to 4353'. Rotate 3/4 turn to attempt to go through window @ 4374'. NOGO, tag up on A2 liner at 4496.5'. Pull back to 4353', rotate 3/4 turn to observe Guide shoe through window. Continue RIH with remaining liner to 6882'. Total BHA = 6894.41'. No issues in open hole. PU WT = 76K, SO WT = 56K. 0.25 ~ CMPLTN RUNT ~ CMPLT2 I Make up Baker Casing Swivel & Pup Jnt Assembly with Baker Model B1 FHH Hook Hanger & Running tool (48:22'). 2.00 CMPLTN RUNT CMPLT2 Pull 2 7/8 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1!4" Slimhole MWD assembly on BOT Shear sub and Ball seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. 0.50 CMPLTN RUNT CMPLT2 TIH from 6895' - 6950' (55'). Perform Shallow pulse test on MWD assembly. Good. 3.00 CMPLTN RUNT CMPLT2 Continue RIH with 4 1/2" 12.6# IBT slotted /blank liner assembly from 6950' - 11176' (4226'). 2.00 CMPLTN OTHR CMPLT2 RU and break circulation @ 11176'. 34 SPM - 700 PSI. UP WT = 143K, I SO WT = 55K. Orient with MWD assembly to 10 Degrees left of high Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 15 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 10/20/2005 15:00 - 17:00 2.00 ~ CMPLTNI OTHR CMPLT2 17:00 - 19:15 2.25 CMPLTN TRIP CMPLT2 19:15 - 20:15 1.00 CMPLTN RURD CMPLT2 20:15 - 20:45 0.50 CMPLTN RURD CMPLT2 20:45 - 21:15 0.50 CMPLTN RURD CMPLT2 21:15 - 23:00 1.75 CMPLTNI RUNT CMPLT2 23:00 - 00:00 1.00 CMPLTN RUNT CMPLT2 10/21/2005 00:00 - 02:00 2.00 CMPLTN TRIP CMPLTN 02:00 - 02:15 ~ 0.25 ~ CMPLTNI PCKR ~ CMPLTN 02:15 - 02:45 I 0.501 CMPLTNI PCKR I CMPLTN 02:45 - 05:15 I 2.50 I CMPLTNI TRIP I CMPLTN 05:15 - 05:45 0.50 WINDOWPULD PROD3 05:45 - 07:45 2.00 WINDOV~IPULD PROD3 Description of Operations side. RIH to tag up @ 11253' DPM. Set down 30K. Pull up 20' and rotate string 90 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 10 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4386'. Drop 1 1/2" Ball and chase with 3 BPM - 700 PSI, slowing pumps to 1.5 BPM - 330 PSI to observe ball seated. Pressure to 3000 PSI to set Hook Hanger and shear with 4300 PSI. Pull up to observe weight loss and Runnng tool free. Monitor well -static. Open Guide shoe depth = 11252'. Top of Hook Hanger = 4370'. POOH to running tools. Observe well taking proper hole fill. Breakout, Visually Inspect and lay down Hook Hanger Running tools and MWD assembly. All Good. Clean & Clear Rig Floor area. Send tools outside. PJSM with crew. Discuss Safety Issues and procedure to make up LEM asembly. Double check running order in pipe shed. Make up LEM assembly. MU BOT Seal assembly (3.26'), and 4 1/2" 12.6# L80 XO joint to IBT (43.12').1 - jnt 4 1/2" tubing (30.12'), Camco "DB-6" nipple w/ 3.563" ID (1.52'), 1 -jnt 4 1/2" tubing (30.84').4 1/2" TBG pup (7.86', LEM assembly (35.13'), 4 -jnts 4 1/2" TBG (123.61'), 4 1/2" TBG pup (3.78'), Baker Casing Swivel (2.73'), XO Bushing 5 1/2" Hydril 563 x 4 1/2" IBT (1.37'), 109-47 Casing Seal Bore Receptacle 6.26" x 4.75" (19.39'), 5 1/2" x 7 5/8" ZXP Liner top PKR 19.0'), and Baker Hydraulic Setting tool (5.29'), Baker Running tool 6.16'), and XO to DP (1.66'). Total BHA = 334.84' Install Ball Catcher & Shear sub as per BOT rep. Rig down all tubing running equipment, and clear floor of tools. Trip in hole w/ Lem Assembly from 804' - 4225' (4216'). Fill DP. Continue TIH to tag top of Hook Hanger @ 4368' DPM. PU WT =105K, SO WT = 85K. Pull up 20', rotate 1/4 turn RH, and slack of to tag again. Pull up, rotate 1/4 turn and observe shoe pass through top of Hook Hanger and RIH to observe LEM latch up to Hook Hanger on depth @ 4370'. Pull to 15K over upweight to verify latch up, slack off to neutral weight. Baker seal assembly @ 4511.20' RU & Drop 1 1/2" ball down drill string & chase with 3 BPM - 475 PSI, slowing pumps to 2 BPM to observe ball seat @ 335 Strokes pumpedo Pressure up to 3000 PSI to set ZXP Packer, and continue to 4300 PSI to release from LEM. Hold 5 minutes. Bleed pressure. Close annular and fill all lines. Pressure test down annulus to test ZXP @ 1000 PSI f/ 10 Minutes. Record on chart. Good test. Bleed all pressure. Pull up to allow "dogs" to kick out & slack off to verify top of liner @ 4189'. Monitor well -static. UP WT = 100K, SO WT = 86K. POOH from 4189' to surface. Breakout, Inspect and lay down running and setting tools. Clean & clear rig floor area, send tools out. Pull tools to rig floor. PJSM with crew. Discuss Safety issues, and procedure to pick up Whipstock assembly. MU 5 3/4" Seal Assembly, 6 1/2" No-go sub 1.92'), 4 5/8" Unloader Sub (5.20'), 3 1/2" Pup Jnt (16.46'), 2 -jnts of 3 1/2" Dp (62.44'), Balanking Sub (1.08'), Bottom Trip Anchor (3.21'), Shear Disconnect sub (2.63'), Ported drain sub (1.02'), Debris Barrier Sub (1.71'), Whipstock Slide (15.49'), 6 3/16" Starting Mill (1.08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill (5.84'), 1 - jnt 3 1/2" HWDP (29.84'), 4 3/4".Float sub (2.49'), MWD assembly (42.45'), 4 3/4" Bumper Jar (7.85'), Crossover sub (1.66') and 6 stands of Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/21/2005 05:45 - 07:45 2.00 WINDO ULD PROD3 07:45 - 08:30 0.75 WINDO THR PROD3 08:30 - 09:00 0.50 WINDO RIP PROD3 09:00 - 11:30 I 2.501 WINDOWTRIP I PROD3 11:30 - 12:00 0.501 WINDOVVITRIP PROD3 12:00 - 12:30 I 0.501 WINDOWSETW I PROD3 110/22/2005 12:30 - 13:30 I 1.001 WINDOVVCIRC I PROD3 13:30 - 17:15 I 3.751 WINDOVVSTWP I PROD3 17:15 - 18:15 I 1.00 WINDOV~/CIRC ~ PROD3 18:15 - 20:15 2.00 WINDO RIP PROD3 20:15 - 21:00 0.75 WINDO THR PROD3 21:00 - 21:30 0.50 WINDO ULD PROD3 22:00 - 23:00 10.00 RIGMNTI RGRP PROD3 23:00 - 00:00 I 1.001 RIGMNTI RGRP I PROD3 00:00 - 01:15 1.25 RIGMNT RGRP PROD3 01:15 - 02:30 1.25 DRILL OTHR PROD3 02:30 - 03:30 I 1.001 DRILL I PULD I PROD3 03:30 - 04:30 1.00 DRILL OTHR ~ PROD3 04:30 - 05:15 0.75 DRILL PULD ~ PROD3 05:15 - 05:30 0.25 DRILL (TRIP PROD3 05:30 - 06:15 0.75 DRILL TRIP PROD3 06:15 - 06:45 ~ 0.50 DRILL PULD PROD3 Start:. 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 16 of 21 Spud Date: 9/30/2005 End: 10/31/2005 Group: Description of Operations push pipe (543.62'). Total BHA = 751.46'. Plug in and upload MWD assembly TIH to 895', and perform Shallow pulse test. Good pulses @ 78 SPM - 820 PSL. Trip in hole with Whipstock assembly from 895' - 3780' (2885'). Run @ 2 minutes per stand as per BOT rep. Fill drill pipe, perform MAD PASS for K13 from 3780' - 4018' (238'), @ 200 ft/hr. Pumps at 285 GPM's - 1750 PSI. UP WT = 105K, SO WT = 82K. Continue TIH to 4140'. Pump down drill string to Orient Whipstock face at 10 degrees left of high side as per DD. Tag top of ZXP @ 4190' DPM. Set BTA, Pull 10K over to verify set. Shear bolt @ 35K down weight,and pull to neutral positon. Obtain free rotation. Displace well with 8.9 PPG MOBM, from 9.O SFMOBM. Pumps at 300 GPM's - 1800 PSL Mill window from 4079' - 4091' (12'), and continue mill open hole from 4091' - 4107' (15'). Avg WOM = 2K, 295 GPM's - 1750 PSI. Work mills through window until clean. Pump Hi Visc weighted sweep until clean, while working window with no noticeable increase in cuttings across shakers. Momitor Well -static. Pump dry job. POOH with milling assembly from 4107' - 639' (3467'). Change elevators, Pull up and plug in to download MWD assembly. POOH, breakout & lay down Milling Asembly. Lay down 6 3/16" Starting Mill (1:08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill 5.84'), 1 -jnt 3 1/2" HWDP (29.84'), 4 3/4" Float sub (2.49'), MWD assembly (42.45'), 4 3/4" umper Jar (7.85'), Crossover sub (1.66' ) and rack back 6 stands of push pipe (543.62'). Upper string mill in gauge @ 6.750". Clean & clear floor area. Send tools outside. BOT rep released. PJSM with crew. Discuss safet issues and procedure. Change out washpipe assembly on top drive. PJSM with crew. Discuss safety issues and procedure. Change out Saver Sub on top drive. 'Continue Change out Saver Sub on the Top Drive. PU 5" test joint -wear ring puller, BOLDS, pull wear bushing. Lay down same. MU 4" DP jnt with stack washer & RIH to flush BOP stack. Lay down stack washer & install WB. RILDS. PJSM with crew. Discuss Safety Issues and MU procedure for BHA. MU BHA #10, Pull tools to floor. Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor 32.44'), 4 3/4" Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer ( 5.24'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'). Plug in and upload MWD assembly. Continue Make up remaining BHA, 3 - 4 3/4" Non Mag Flex Drill Collars (92.76'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP 30.13'), 4 3/4" Drilling jars (28.59'), 4 - Jnts 4" HWDP (121.24'). Total BHA length = 369.61'. Perform Shallow pulse test @ 75 SPM - 1600 PSI. Good test. Trip in hole from 369' - 1956' (1587). Make up 4 3/4" Andergauge Agitator sub (8.71), IF - XT39 Crossover Printed: 12/9/2005 3:20:77 PM • ConocoPhillips Alaska Page 1 r of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/22/2005 06:15 - 06:45 06:45 - 07:30 0.50 DRILL PULD PROD3 0.75 DRILL TRIP PROD3 07:30 - 08:30 08:30 - 08:45 08:45 - 12:00 12:00 - 00:00 10/23/2005 100:00 - 12:00 12:00 - 00:00 1.00 RIGMNT RSRV PROD3 0.25 DRILL TRIP PROD3 3.251 DRILL I DRLG I PROD3 12.001 DRILL I DRLG I PROD3 12.00 DRILL. DRLG PROD3 12.00 DRILL DRLG ; PROD3 Spud Date: 9/30/2005 Stan`: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations (1.64'), 4 3/4" Shock sub (7.00'), and Crossover XT39 - IF (1.07'). Continue TIH from 1974' - 4026' (2052'). Fill drill string with mud @ 2721'. 82 SPM - 3400 PSI. Slip & Cut 71' of drilling line. Inspect Brakes. Orient bit & motor to 10 Degrees left of high side. Pass through window area from 4079' - 4091' with no issues and tag at 4097' DPM. UP WT = 80K, SO WT = 76K, ROT WT 80K, 5K torque. Observed hole fill on trip = proper displacement, 24 BBLs. Directional Drill 6 3/4" hole in "D" Lateral from 4097' - 4308' MD (211'). TVD = 3458'. ADT = 1.54 HRS, AST =.92 HRS, ART = .62 HRS. Pumps @ 86 SPM (total) - 3500 PSI. Pump # 1 @ 45 SPM. Pump # 2 @ 41 SPM. UP WT = 90K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K RPM's = 90. Torque on bottom = 3K, Torque off bottom = 3K. MUD WT = 8.9 PPG,. VISC.= 77, YP =,1$. Establish. ECD Baseline @, 9.72 PPG EMW. Jar Hrs total = 1.54. Bit Hrs total = 1..54. Obtain SPR's @ 4168' MD, 3470 TVD. Pump #1 = 20 SPM - 420 PSI, 30 SPM - 720 PSI. Pump #2 = 20 SPM - 400, 30 SPM -720 PSI. Survey @ 4292' MD, 3456' TVD. INC = 93.13 DEG, AZ = 179.74 DEG. Continue Directional Drill 6 3/4" hole in "D" Lateral from 4308' - 4775' MD (467'). TVD = 3475'. ADT = 7.44 HRS, AST =4.62 HRS, ART = 3.41 HRS. Pumps @ 93 SPM - 3640 PSI. Pump # 1 @ 93 SPM. UP WT = 94K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K. RPM"S = 90. Torque on bottom = 5K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 9.92 PPG EMW. Jar Hrs total = 8.98. Bit Hrs total = 8.98 Obtain SPR's @ 4772' MD, 3468 TVD. Pump #1 = 20 SPM - 380 PSI, 30 SPM - 610 PSI. Pump #2 = 20 SPM - 390, 30 SPM -610 PSI. Survey @ 4633' MD, 3456' TVD. INC = 86.79 DEG, AZ = 181.16 DEG. Observed Concretions @ 4282' - 4284' (2'), 4395' - 4413' (18'), 4422' - 4446' (24'), 4450' - 4460' (10'), 4505' - 4508' (3'), 4722' - 4743' (21'), 4745' - 4756' (1'), 4760' - 4769' (9'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 4775' - 5969' MD (1194'). TVD = 3430'. ADT = 8..19 HRS, AST = 2.93 HRS, ART = 5.26 HRS. Pumps @ 88 SPM - 3450 PSI. Pump # 1 @ 88 SPM. Pump sweeps as needed to clean hole. UP WT = 92K, SO WT = 65K, ROT WT = 80K. WOB = 5-10K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD @ 10.4 PPG EMW. Jar Hrs total = 16.10. Bit Hrs total = 16.10 Obtain SPR's @ 5800' MD, 3446 TVD. Pump #1 = 20 SPM - 440 PSI,. 30 SPM - 670 PSI. Pump #2 = 20 SPM - 460, 30 SPM -680 PSI. Survey @ 5844' MD, 3434' TVD. INC = 93.21 DEG, AZ = 179.78 DEG. Observed Concretions @ 4836' - 4839' (3'), 4982' - 4987' (15'), 5787' - 5790' (3'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 5969' - 7138' MD (1169'). TVD = 3404'. ADT = 6.06 HRS, AST = 1.90 HRS, ART = 4.16 HRS. Pumps @ 85 SPM - 3250 PSI. Pump # 2 @ 85 SPM. Pump sweeps as needed to clean hole. UP WT = 103K, SO WT = 56K, ROT WT = 80K. WOB = 2-10K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 73, YP = 18. ECD @ 10.3 PPG EMW. Jar Hrs total = 22.16. Bit Hrs total = 22.16 Obtain SPR's @ 6828' MD, 3410 TVD. Pump #1 = 20 SPM - 460 PSI, 30 SPM - 780 PSI. Pump #2 = 20 SPM - 500, 30 SPM -780 PSI. Survey @ 6966' MD, 3406' TVD. INC = 90.84 DEG, AZ = 179.98 DEG. Observed Concretions @ 6624' - 6628' (4'), 6653' - 6657' (4'), 6768' - Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 18 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Gode 110/23/2005 112:00 - 00:00 ~ 12.001 DRILL 1 DRLG 110/24/2005 100:00 - 12:00 I 12.00 I DRILL I DRLG 12:00 - 00:00 I 12.00 I DRILL I DRLG 110/25/2005 100:00 - 12:00 I 12.001 DRILL I DRLG 12:00 - 00:00 12.00 DRILL DRLG 10/26/2005 100:00 - 12:45 I 12.751 DRILL I DRLG Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Phase Description of Operations PROD3 6780' (12'). Max Gas units = 179. Observed 35% increase in cuttings at shakers when sweep returned. PROD3 Continue Directional Drill 6 3/4" hole in "D" Lateral from 7138' - 8195' MD (1057'). TVD = 3407'. ADT = 6.35 HRS, AST = 1.06 HRS, ART = 5.29 HRS. Pumps @ 86 SPM - 3800 PSI. Pump # 1 @ 86 SPM. Pump sweeps as needed to clean hole. UP WT = 107K, SO WT = 56K, ROT WT = 79K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.5 PPG EMW. Jar Hrs total = 28.51. Bit Hrs total = 28.51 Obtain SPR's @ 8173' MD, 3405 TVD. Pump #1 = 20 SPM - 510 PSI, 30 SPM - 750 PSI. Pump #2 = 20 SPM - 520, 30 SPM -720 PSI. Survey @ 8027' MD, 3396' TVD. INC = 87.5 DEG, AZ = 178.3 DEG. Observed Concretions @ 7449' - 7456' (7'), 7774' - 7780' (6'), 8132' - 8140' (8'). Max Gas units = 135. Observed 40%° increase in cuttings at shakers when sweep returned from 7322'. Sweep @ 7883', 15% increase in cuttings. PROD3 Continue Directional Drill 6 3!4" hole in "D" Lateral from 8195' - 8879 MD (784'). TVD = 3404'. ADT = 7.21 HRS, AST = 2.52 HRS, ART = 4.69 HRS. Pumps @ 84 SPM - 3400 PSI. Pump # 1 @ 84 SPM. Pump sweeps as needed to clean hole. UP WT = 110K, SO WT = 52K, ROT 'i WT = 82K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 6K, Torque off bottom = 5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.67 PPG EMW. Jar Hrs total = 35.72. Bit Hrs total = 35.72 Obtain SPR's @ 8850' MD, 3408 TVD, Pump #1 = 20 SPM - 480 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 500, 30 SPM -810 PSI.Survey @ 8899' MD, 3408' TVD. INC = 92.89 DEG, AZ = 181.25 DEG. Observed Concretions @ 8342' - 8349' (7'), 8381' - 8401' (20'), Max Gas units = 182. Observed 25% increase in cuttings at shakers when sweep returned from 8947'. PROD3 Continue Directional Drill 6 3/4" hole in "D" Lateral from 8879' - 9721' MD (842'). TVD = 3359'. ADT = 7.43 HRS, AST = 2.64 HRS, ART = 4.79 HRS. 309 GPM @ 3750 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 115K, SO WT = 45K, ROT WT = 80K. WOB = 2-15K. RPM"S = 90. Torque on bottom = 6.5K, Torque off bottom = 6.5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 43.77. Bit Hrs total = 43.77 Obtain SPR's @ 9524' MD, 3372 TVD. Pump #1 = 20 SPM - 560 PSI, 30 SPM - 790 PSI. Pump #2 = 20 SPM - 550, 30 SPM -780 PSI. Observed Concretions @ 9288' - 9291' (3'), 9311' - 9318' (7'), 9331'-9343' (12'), 9380'-9394' (14'), 9421'-9429' (8'), 9435'-9440' (5'). PROD3 Continue Directional Drill 6 3/4" hole in "D" Lateral from 9721' - 10286' MD (565'). TVD = 3379'. ADT = 6.42 HRS, AST = 2.07 HRS, ART = 4.35 HRS. 318 GPM @ 3850 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 125K, SO WT = 42K, ROT WT = 87K. WOB = 2-12K. RPM"S = 100. Torque on bottom = 6.OK, Torque off bottom = 5.4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total= 50.19. Bit Hrs total = 50.19 Obtain SPR's @ 10283' MD, 3379 TVD. Pump #1 = 20 SPM - 570 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 570, 30 SPM -820 PSI. Observed Concretions @ 9940' - 9946' (6'), 10188' - 10195' (7'), 10230'-10250' (20')e PROD3 ~ Continue Directional Drill 6 3/4" hole in "D" Lateral from 10286' - 10964' j MD (TD) (678'). TVD = 3356'. ADT = 9.36 HRS, AST = 4.49 HRS, ART Printed: 12/9!2005 3:20:17 PM • ConocoPhillips Alaska Page 19 of 21 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 22:45 - 00:00 Date From - To Hours Code Code Phase 10/26/2005 ~ 00:00 - 12:45 ~ 12.75 ~ DRILL ~ DRLG 12:45 - 14:30 14:30 - 16:30 16:30 - 19:45 19:45 - 22:45 09:45 - 16:30 16:30 - 17:00 17:00.- 18:00 18:00 - 18:30 18:30 - 19:45 19:45 - 20:45 20:45 - 21:15 21:15 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 01:00 10/27/2005 00:00 - 00:30 0.50 RIGMNT RSRV PRODS 00:30 - 03:30 3.00 DRILL. WIPR PRODS 03:30 - 05:15 1.75 DRILL WIPR PRODS 05:15 - 08:00 2.75 DRILL CIRC PRODS 08:00 - 09:45 110!28/2005 01:00 - 01:30 01:30 - 04:00 04:00 - 06:30 06:30 - 07:00 07:00 - 11:00 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon 141 1.75 DRILL CIRC 2.00 DRILL WIPR 3.25 DRILL WIPR- 3.00 DRILL WIPR I PRODS PRODS PRODS PRODS PRODS 1.25 f DRILL I CIRC I PRODS 1.75 I DRILL I CIRC I PRODS 6.75 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 1.25 DRILL 1.00 DRILL 0.50 DRILL 0.75 WIND( 2.00 WIND( 0.50 WIND( 0.50 WIND( 0.50 WIND 2.50 WINDi 2.50 WIND 0.50 DRILL 4.00 WELC TRIP PULD TRIP PULD PULD PULD SFTY PULD SFTY BOPE 11:00 - 18:15 I 7.251 CASE I PULR I PRODS PRODS PRODS PRODS PRODS PRODS CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30!2005 Group: Rig Number: Description of Operations = 4.87 HRS. 309 GPM @ 4000 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 135K, SO WT = 45K, ROT WT = 89K. WOB = 2-15K. RPM"S = 100. Torque on bottom = 7.OK, Torque off bottom = 7.OK. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 60.55. Bit Hrs total = 60.55 Obtain SPR's @ 10851' MD, 3365 TVD. Pump #1 = 20 SPM - 610 PSI, 30 SPM - 860 PSI. Pump #2 = 20 SPM - 610, 30 SPM -850 PSI. Observed Concretions @ 10290' - 10299' (9'), 10319' - 10322' (23'), 10364'-10367' (3'), 10846- 10850 (4'). Pump Hi-vis weighted sweep around and 1 btm's up at rate of 300 gpm @ 3950 psi, Observe well, Pump up survey. POOH on elevators f/ 10,964' to 10,195', Pump dry job & continue to POOH to 9,543' (Pulled 20K over @ 9,543') Make up top drive). Back ream out of hole f/9,627`toS,369' with no problems at rate of 330 gpm.@ 3900 psi w/ 100 RPM. POOH on elevators f/ 8,369' to 7,629', Pump dry job, Continue to POOH to 4,028' (Window @ 4,079'), No problems POOH or Pulling thru window. Pump Hi-vis weighted sweep ~ circ 3 times btm's up at rate of 330 gpm @ 3400 psi w/ 100 RPM. Service top drive RIH with no problems f/ 4,028' to 9,723' (Ran out of weight) Wash 8~ Ream f! 9,723' to 10,964' w! 128 GPM @ 1200 PSI & 50 RPM. Pump 35 bbl Hi-vis weighted sweep &Circ 3 times btm's up at rate of 288 GPM @ 4100 PSI, 100 RPM. Change well over f/ MOBM to SFOBM at rate of 288 GPM @ 4100 PSI w/ 100 RPM, Obtain SPR's, Monitor well- OK. POOH on elevators with no problems. 'Lay down Agitator & Shock sub. Continue to POOH to BHA. Lay down DC's. Down load MWD tools. Finish laying down BHA. Clear & Clean rig floor, Bring Whipstock retrieving tools to rig floor. Make up Baker Whipstock retrieving tools. RIH w/ BHA to 2,539', Fill pipe - 50 SPM @ 550 PSI. Continue RIH to 4,083' Work & Hook whipstock @ 4,083', Pull loose w/ 70K over, Pull 1 stand drill pipe. Circ btm's up at rate of 6 bpm @ 1200 psi. Drop 1-3/4" rabbit, POOH to whipstock. Lay down whipstock & Baker retrieving tools. Clear tools from rig floor, Clean rig floor. Pull wear bushing, Rig & test all BOPE to 250 psi low & 3000 psi high, Test waived by AOGCC Jeff Jones, Install wear bushing. PJSM, Rig & Make up 3 1/2" Bentjoint X 4-1/2" with Open guide shoe as shoe jt.. Breakout pack off bushing from top of joint, Continue RIH making up 4 1/2" 12.6# IBT slotted /blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #116, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10555', 10356', 9855', 9605', 9105', 8855', 8352', 8105', 7755', 7505', 7005', 6755', 6255', 6005', Printed: 12/9/2005 3:20:17 PM • • ConocoPhillips Alaska Page 20 of 21 Operations Summary Report Legal Well Name: 1J-154 Common WeII Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31./2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number. Date From - To Hours Code Code Phase 10!28/2005 11:00 - 18:15 7.25 CASE PULR CMPLT3 18:15 - 19:45 I 1.501 CASE I PULR I CMPLT3 19:45 - 22:45 I 3.00 I CASE I RUNL I CMPLT3 22:45 - 00:00 1.251 CASE OTHR ~ CMPLT3 110/29/2005 100:00 - 00:30 ~ 0.50 ~ CASE ~ OTHR ~ CMPLT3 00:30 - 01:00 0.50 CASE CIRC CMPLT3 01:00 - 03:45 2.75 CASE RUNL CMPLT3 03:45 - 04:15 0.50 CASE OTHR CMPLT3 04:15 - 13:00 8.75 DRILL PULD CMPLT3 13:00 - 14:15 1.25 RIGMNT RSRV CMPLT3 14:15 -14:45 0.50 CMPLTN RURD CMPLT3 14:45 - 16:15 1.50 CMPLTN PULD CMPLT3 16:15 - 19:00 I 2.751 CMPLTNI TRIP I CMPLT3 19:00 - 19:45 I 0.751 CMPLTNI CIRC I CMPLT3 110!30!2005 19:45 - 22:15 2.50 CMPLTN TRIP CMPLT3 22:15- 22:45 0.50 CMPLTN PULD CMPLT3 22:45 - 00:00 1.25 CMPLTN RURD CMPLT3 00:00 - 03:30 3.50 CMPLTN RUNT CMPLT3 03:30 - 04:30 I 1.00 CMPLTNI SOHO CMPLT3 04:30 - 06:00 1.50 CMPLTN NUND !CMPLT3 06:00 - 07:30 1.50 CMPLTN; NUND CMPLT3 07:30 - 13:00 I 5.501 CMPLTNI PULD (CMPLT3 Description of Operations 5557, 5302',. 4805' and 4555'. RIH and enter btm of window @ 4091'. Continue RIH with remaining liner to 6,820'. Total BHA = 6,843.47'. No issues in open hole. PU WT = 75K, SO WT = 68K. Pull 2 7/8 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1/4" Slimhole MWD assembly on BOT Shear sub and Ball seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. RIH w/ 4-1/2" liner f! 6843' to 10,877', Perform. Shallow pulse test on MWD assembly. Good. Break circulation @ 10,877'. 37 SPM - 1000 PSI. UP WT = 145K, SO WT = 65K. Orient with MWD assembly to 12 Degrees left of high side. RIH to tag up w/ shoe @ 10,917.80' -Hook btm of window @ 4,091' {Measurements exact), Toolface oriented to 4 Degress Left .Set down 30K. Pull up 20' and rotate string 180 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 12 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4,091' and Toolface again pulled around to 4 Degress left of high side. Top of Hook Hanger @ 4,074.33', Shoe @ 10,917.80' ,Drop ball & pump down at rate of 130 gpm @ 1000 psi. Pressure up release f/ liner & shear out ball w/ 4400 psi. '.Pick up & circ btm's up at rate of 5 bpm @ 700 psi. POOH, Break & lay down liner running tools &MWD. Lay down tools from beaver slide, Clean rig floor. Rig & lay down 95 std's 4" drill pipe f/ off drillers side. Slip & cut drilling line 70', Service top drive. Rig casing tools to run LEM Assembly. PJSM, Make up LEM assembly as per detail, UP 37K, DN 40K, Rig down casingf tools. RIH to 4200', UP 110K, DN 92K, Slack off and latch LEM (On depth), Pull test latch 20K over twice-OK, Slack off 40K. Drop ball & pump down at 163 gpm @ 700 psi, Seat ball & pressure up to 4000, Bleed pressure, Test ZXP to 1000 psi f/ 10 min-OK. Monitor well, POOH to running tools. Lay down running tools. Pull wear bushing, Rig to run 4-1/2" completion string, PSJM. Run Baker 4.75" Seal assembly, 1 jt. 4-1/2", 12.6#, L-80, IBT Tubing, Baker4-1/2" CMU Sliding sleeve (In Open position), 6 jts. 4-1/2", 12.6#, L-80, IBT tubing, Camco 4-1/2"x 1 "- KBMG GLM, 44 jts. tbg, Camco 4-1/2"x 1"-KBMG GLM, 62 jts. tbg, Camco 4-1/2" DB Nipple w/ 3.875" Profile, 15 jts tbg., Tag No-Go @ 4,025.13' w/ Tail @ 4,051.78' (2.75' High with tubing measurements). Note: Day Light savings time 1 hour back. Make up Vetco Gray 4-1/2" x 11"Tubing hanger ~ land tubing 4.23' above fully located position w/ Tail @ 4,047.55', Attempt to test seals on hanger- No Good, Pull hanger, Change O-rings and reland hanger, Test hanger seals to 250 low and 5000 psi high- OK. Nipple down BOPE. Nipple up Vetco Gray Tree and test same to 250 psi low & 5000 psi high. Lay down all 4" HWDP, DC's, Drill pipe w/ Lo-Tad's & Sliders, Rig down mouse hole. Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 21 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1 J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Code Phase Description of Operations 10/30/2005 13:00 - 16:00 3.00 CMPLTN FRZP CMPLT3 Rig Little Red service and freeze protect well with 166 bbls diesel thru sliding sleeve @ 3,971'., Remove all tools and equip: from rig floor, Change liners in pumps to 6". 16:00 - 16:30 0.50 CMPLTN NUND CMPLT3 Rig lubricator and set BPV. 16:30 - 19:00 2:50 CMPLTN PULD .CMPLT3 Rig mouse hole finish laying down 4" drill pipe, Lo-Tad's & Sliders, Rig down mouse hole. 19:00 - 00:00 5.00 CMPLTN OTHR CMPLT3 Clean pits, Rock washer, Cuttings boxes. Release rig @ 2400 hrs. 10/30/05 Printed: 12/9/2005 3:20:17 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad , 1 J-154L 1 Job No. AK-ZZ-0003956462, Surveyed: 18 October, 2005 Survey Report 9 November, 2005 Your Ref.• API 500292325460 Surtace Coordinates: 5945944.17 N, 558639.59E (70° 15' 46.5105" N, 149° 31' 33.3768" I~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 • Surtace Coordinates relative to Project H Reference: 945944.17 N, 58639.59E (Grid) Surtace Coordinates relative to Structure: 25.70 N, 150.17 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference _ Kelly Bushing Elevation: 109.001`t above Structure ~M t_.tnrc~ ~v~c~ SurveyRef.•svy2132 A t€nN@burEan Company Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-154L1 Your Ref: AP1500292325460 Job No. AK-ZZ-0003956462, Surveyed: 18 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 4346.92 80.890 177.190 3399.13 3508.13 851.36 S 520.67 W 5945088. 78 N 558125 .57E 851.36 4374.00 80.220 177.790 3403.58 3512.58 ~ 878.04 S 519.50 W 5945062. 11 N 558126. 94E 3.301 878.04 4488.99 93.690 179.610 3409.67 3518.67 992.57 S 516.91 W 5944947. 60 N 558130. 42E 11.820 992.57 4518.50 94.300 180.820 3407.62 3516.62 1022.01 S 517.02 W 5944918. 16 N 558130. 54E 4.583 1022.01 4614.87 89.680 184.730 3404.27 3513.27 1118.16 S 521.69 W 5944821. 98 N 558126. 63E 6.278 1118.16 4707.80 88.840 185.680 3405.47 3514.47 1210.70 S 530.12 W 5944729. 38 N 558118. 92E 1.365 1210.70 4801.64 86.340 180.730 3409.42 3518.42 1304.28 S 535.36 W 5944635. 77 N 558114. 40E 5.905 1304.28 4893.56 88.240 180.250 3413.76 3522.76 1396.08 S 536.14 W 5944543. 95 N 558114. 33E 2.132 1396.08 4984.17 89.670 179.410 3415.42 3524.42 1486.68 S 535.88 W 5944453. 37 N 558115. 31E 1.830 1486.68 5081.44 94.090 177.650 3412.23 3521.23 1583.83 S 533.38 W 5944356. 23 N 558118. 56E 4.891 1583.83 5174.75 91.280 178.640 3407.86 3516.86 1676.98 S 530.37 W 5944263. 11 N 558122. 30E 3.192 1676.98 5267.36 89.030 180.500 3407.61 3516.61 1769.58 S 529.67 W 5944170. 52 N 558123. 71E 3.152 1769.58 5359.65 89.160 179.190 3409.06 3518.06 1861.85 S 529.42 W 5944078. 25 N 558124. 68E 1.426 1861.85 5453.84 91.620 177.520 3408.42 3517.42 1955.99 S 526.72 W 5943984. 13 N 558128. 12E 3.157 1955.99 5545.80 91.860 180.770 3405.63 3514.63 2047.89 S 525.35 W 5943892. 25 N 558130. 21E 3.542 2047.89 5640.10 91.280 181.880 3403.05 3512.05 2142.13 S 527.53 W 5943798. 00 N 558128. 76E 1.328 2142.13 5733.35 91.710 181.760 3400.61 3509.61 2235.30 S 530.49 W 5943704. 81 N 558126. 52E 0.479 2235.30 5827.35 89.830 179.230 3399.35 3508.35 2329.27 S 531.30 W 5943610. 83 N 558126. 44E 3.353 2329.27 5919.72 90.100 178.960. 3399.41 3508.41 2421.63 S 529.84 W 5943518. 49 N 558128. 62E 0.413 2421.63 6014.17 92.810 176.170 3397.01 3506.01 2515.95 S 525.83 W 5943424. 20 N 558133 .37E 4.117 2515.95 6108.29 92.150 177.060 3392.93 3501.93 2609.81 S 520.28 W 5943330. 38 N 558139. 65E 1.177 2609.81 6202.49 91.380 178.230 3390.03 3499.03 2703.89 S 516.41 W 5943236. 34 N 558144. 25E 1.486 2703.89 6296.08 90.350 178.990 3388.62 3497.62 2797.44 S 514.14 W 5943142. 81 N 558147. 25E 1.368 2797.44 6389.18 90.830 178.920 3387.66 3496.66 2890.52 S 512.44 W 5943049. 75 N 558149. 67E 0.521 2890.52 6482.56 91.870 179.140 3385.46 3494.46 2983.86 S 510.86 W 5942956. 43 N 558151 .98E 1.138 2983.86 6575.17 91.090 181.160 3383.07 3492.07 3076.43 S 511.11 W 5942863. 85 N 558152 .46E 2.337 3076.43 6669.60 89.680 181.150 3382.43 3491.43 3170.84 S 513.01 W 5942769. 44 N 558151 .29E 1.493 3170.84 6762.49 90.290 181.110 3382.46 3491.46 3263.71 S 514.84 W 5942676. 55 N 558150. 18E 0.658 3263.71 6857.28 92.140 179.980 3380.45 3489.45 3358.47 S 515.74 W 5942581. 79 N 558150 .02E 2.287 3358.47 6949.50 91.590 180.760 3377.45 3486.45 3450.63 S 516.34 W 5942489. 62 N 558150 .14E 1.035 3450.63 7042.98 91.140 180.150 3375.22 3484.22 3544.08 S 517.08 W 5942396. 17 N 558150 .13E 0.811 3544.08 7140.14 89.140 179.330 3374.98 3483.98 3641.24 S 516.64 W 5942299. 02 N 558151 .32E 2.225 3641.24 7235.81 91.370 177.660 3374.56 3483.56 3736.86 S 514.13 W 5942203. 42 N 558154 .58E 2.912 3736.86 7331.54 91.490 177.200 3372.17 3481.17 3832.47 S 509.84 W 5942107. 85 N 558159 .62E 0.496 3832.47 7428.69 92.850 177.020 3368.49 3477.49 3929.42 S 504.94 W 5942010. 94 N 558165 .26E 1.412 3929.42 ConocoPhillips Comment Tie-On Point Window Point • 9 November, 2005 - 13:07 Page 2 of 5 DrillQuest 3.03.06.008 Hal-iburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-154L1 Your Ref.• API 500292325460 Job No. AK ZZ-0003956462, Surveyed: 18 October, 2005 Western No-th Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 7523.20 89.800 179.520 3366.30 3475.30 4023.84 S 502.09 W 5941916.54 N 558168.85E 4.172 4023.84 7623.54 91.060 180.910 3365.55 3474.55 4124.18 S 502.47 W 5941816.21 N 558169.26E 1.870 4124.18 7730.23 88.600 179.700 3365.87 3474.87 4230.85 S 503.04 W 5941709.53 N 558169.52E 2.570 4230.85 7825.81 89.360 181.780 3367.57 3476.57 4326.41 S 504.27 W 5941613.97 N 558169.03E 2.317 4326.41 7919.52 90.590 183.940 3367.61 3476.61 4419.99 S 508.95 W 5941520.35 N 558165.08E 2.652 4419.99 8019.11 89.220 184.970 3367.78 3476.78 4519.28 S 516.68 W 5941421.01 N 558158.12E 1.721 4519.28 8116.31 89.480 186.650 3368.88 3477.88 4615.97 S 526.52 W 5941324.24 N 558149.03E 1.749 4615.97 8214.69 91.150 187.900 3368.34 3477.34 4713.55 S 538.98 W 5941226.57 N 558137.34E 2.120 4713.55 8309.69 86.480 185.370 3370.30 3479.30 4807.86 S 549.95 W 5941132.17 N 558127.10E 5.590 4807.86 8406.42 86.310 182.970 3376.38 3485.38 4904.13 S 556.97 W 5941035.85 N 558120.83E 2.482 4904.13 8502.26 92.780 185.560 3377.15 3486.15 4999.65 S 564.09 W 5940940.28 N 558114.45E 7.271 4999.65 8599.97 91.940 184.890 3373.12 3482.12 5096.87 S 572.98 W 5940843.00 N 558106.32E 1.099 5096.87 8698.54 88.470 182.430 3372.77 3481.77 5195.21 S 579.27 W 5940744.60 N 558100.79E 4.315 5195.21 8796.15 90.600 182.480 3373.56 3482.56 5292.72 S 583.45 W 5940647.06 N 558097.37E 2.183 5292.72 8892.26 88.350 179.840 3374.44 3483.44 5388.80 S 585.40 W 5940550.98 N 558096.17E 3.609 5388.80 8989.39 88.800 178.050 3376.86 3485.86 5485.87 S 583.61 W 5940453.92 N 558098.72E 1.900 5485.87 9085.54 91.030 179.720 3377.00 3486.00 5582.00 S 581.74 W 5940357.81 N 558101.34E 2.897 5582.00 9183.19 89.780 172.930 3376.31 3485.31 5679.38 S 575.49 W 5940260.48 N 558108.35E 7.070 5679.38 9279.77 91.520 173.480 3375.21 3484.21 5775.28 S 564.06 W 5940164.68 N 558120.52E 1.889 5775.28 9376.81 90.580 170.010 3373.44 3482.44 5871.28 S 550.13 W 5940068.78 N 558135.20E 3.704 5871.28 9473.22 92.010 166.960 3371.26 3480.26 5965.71 S 530.89 W 5939974.51 N 558155.17E 3.493 5965.71 9569.51 93.190 169.680 3366.89 3475.89 6059.90 S 511.42 W 5939880.47 N 558175.38E 3.076 6059.90 9665.87 92.620 169.870 3362.00 3471.00 6154.61 S 494.34 W 5939785.90 N 558193.20E 0.623 6154.61 9763.73 90.820 172.480 3359.07. 3468.07 6251.25 S 479.33 W 5939689.37 N 558208.95E 3.239 6251.25 9857.99 90.340 175.830 3358.11 3467.11 6345.00 S 469.74 W 5939595.70 N 558219.28E 3.590 6345.00 9954.95 89.350 179.700 3358.37 3467.37 6441.87 S 465.96 W 5939498.87 N 558223.82E 4.120 6441.87 10045.06 89.100 183.740 3359.59 3468.59 6531.91 S 468.66 W 5939408.81 N 558221.81E 4.492 6531.91 10134.75 89.040 186.120 3361.05 3470.05 6621.25 S 476.37 W 5939319.41 N 558214.80E 2.654 6621.25 10225.14 90.350 188.390 3361.53 3470.53 6710.91 S 487.78 W 5939229.67 N 558204.09E 2.899 6710.91 10315.49 91.330 188.410 3360.21 3469.21 6800.28 S 500.98 W 5939140.20 N 558191.59E 1.085 6800.28 10407.05 91.760 186.390 3357.74 3466.74 6891.04 S 512.77 W 5939049.35 N 558180.51E 2.255 6891.04 10496.81 91.450 183.810 3355.22 3464.22 6980.40 S 520.74 W 5938959.93 N 558173.23E 2.894 6980.40 10589.69 90.580 182.240 3353.58 3462.58 7073.13 S 525.64 W 5938867.16 N 558169.05E 1.932 7073.13 10679.90 89.030 178.860 3353.88 3462.88 7163.32 S 526.51 W 5938776.96 N 558168.89E 4.122 7163.32 10769.93 91.340 184.420 3353.59 3462.59 7253.27 S 529.08 W 5938687.00 N 558167.01E 6.687 7253.27 ConocoPhillips Comment • • 9 November, 2005 - 13:07 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-154L1 Your Ref: AP1500292325460 Job No. AK ZZ-0003956462, Surveyed: 18 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10860.35 92.450 184.340 3350.60 3459.60 7343.38 S 535.98 W 5938596.84 N 558160.81E 1.231 7343.38 10951.75 90.390 178.300 3348.34 3457.34 7434.68 S 538.09 W 5938505.53 N 558159.42E 6.980 7434.68 11043.14 90.590 173.910 3347.55 3456.55 7525.83 S 531.88 W 5938414.42 N 558166.34E 4.808 7525.83 11134.07 89.720 172.640 3347.31 3456.31 7616.13 S 521.23 W 5938324.21 N 558177.69E 1.693 7616.13 11227.34 90.530 172.410 3347.11 3456.11 7708.61 S 509.10 W 5938231.83 N 558190.54E 0.903 7708.61 11285.00 90.530 172.410 3346.57 3455.57 7765.76 S 501.48 W - 5938174.74 N 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 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11285.OOft., The Bottom Hale Displacement is 7781.94ft., in the Direction of 183.695° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 4346.92 3508.13 851.36 S 520.67 W Tie-On Point 4374.00 3512.58 878.04 S 519.50 W Window Point 11285.00 3455.57 7765.76 S 501.48 W Projected Survey ConocoPhillips Comment 558198.60 E - 0.000 7765.76 Projected Survey • • 9 November, 2005 - 13:07 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-154L1 Your Ref: API 500292325480 Job No. AK-ZZ-0003956462, Surveyed: 18 October, 2005 Western North Slope Survey tool program for 1J-154L1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 719.00 718.67 719.00 718.67 11285.00 3455.57 ConocoPhillips Survey Tool Description CB-SS-Gyro (1J-154) MWD+IIFR+MS+SAG (1J-154L1) • • 9 November, 2005 - 13:07 Page 5 of 5 DrillQuest 3.03.06.008 • 05-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-154 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,346.92' MD Window /Kickoff Survey: 4,374.00' MD (if applicable) Projected Survey: 11,285.00' MD 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 ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a~s~_~3~ a~l.~ ~: ~~~ " ~ ~ ~ ~ ~ ~ a ,~i ~ '~ ~! ~' ~ q'~' FRANK H. MURKOWSKI, GOVERNOR l~iIC~~78A O~ ~ ~ 333 W. T" AVENUE, SUITE 100 COI~TSERQA~`IOrT CODIl~iISSIOI~IT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99540-0360 Re: Kuparuk 1J-154L1 ConocoPhillips Alaska, Inc. Permit No: 205-036 Surface Location: 2133' FSL, 2569' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 352' FNL, 2188' FWL, SEC. 11, T10N, RlOE 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-154, Permit No. 205-035, API 50-029-23254-00. 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 t tness any required test. Contact the Commission's petroleum field inspector at (907) 659 6~ ( ager). DATED thi day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Type of Work: Drill U Re-entry ^ )perator Name: ConocoPhillips Alaska, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill 1b. Current Well Class: Exploratory Devel RECEIVE ~~5 BAR o 7 2aa5 Stratigraphic Test ^ Service ^~ Development Gas ^ P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Wel{ (Governmental Section): Surface: 2133' FSL, 2569' FEL, Sec. 35, T11 N, R10E, UM Top of Productive Horizon: 1276' FSL, 2191' FWL, Sec. 35, T11N, R10E Total Depth: 352' FNL, 2188' FWL, Sec. 11, T10N, R10E 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 558640 ~ y- 5945944 ~ Zone- 4 16. Deviated wells: Kickoff depth: 4364 ft. ' Maximum Hote Angle: 92° 18. Casing Program Size Specifications . Hole Casing Weight Grade Coupling Length 42" 20x34" 94# K-55 Welded 80' 13.5" 10.75" 45.5# L-80 BTC 2273' L-80 I"IBTM I 6912' Zone Bond No. 59-52-180 1J-154L1 Proposed Depth: 12. Field/Pool(s): MD: 11276' ~ TVD: 3439' ~ Kuparuk River Field Property Designation: ADL 25661 & 25662 West Sak Oil Pool Land Use Permit: 13. Approximate Spud Date: ALK 471 & 2177 4/26/2005 Acres in Property: 14. Distance to c...?T ,za,;`, ~,~" ' 2560 Nearest Property: s:3.railes~xsra~ . ~r i. KB Elevation 15. Distance to Nearest /~ -/Y7 i .nci ~~ eight above GL): 108' AMSL feet Well within Pool: '. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 3, ~~ a~- Downhole: 1589 psig Surface: 1201 psig ' MD TVD MD TVD (including stage data) 28' 28' 108' 108' 260 cf ArcticCrete 28' 28' 2301' 2203' 470 sx AS Lite, 140 sx Deet; 28' epCrete 4364' 3513' 11276' 3439' 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 ND Structural Conductor Surtace Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ' ~ ~ BOP Sketch LJ Drilling Program U Time v. Depth Plot LJ Shallow Hazard Analysis U Property Plat U Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane C/oninger @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~--~~- Phone ~S fi$ 3a Date 3~3~os •~. `_~„ ar n All Commission Use Only Permit to Drill ~* API Number: Permit Approval See cover letter Number: ~~~'. C..J~ r ~` C~ ~' ` ~~. ~ ~ s~1c...tr~ .~ {O 50- ~ ~ ~ Z Date: ..~~ ~/ OS for other requirements Conditions of approval Sa les required Yes ^ No ,~ Mud log required Yes ^ No dr en sulfide measures Yes ^ No'~~ Directional survey required Yes ,~ No ^ Other: ~~ `~ ~CS~z SQ.~ ~,,- ~'S W CrJ~C3~"G~i~~ ~Cy~`'C3~,rt:6'_'~ C ~~C~ v~~~ ~ /h~l ~ ~~~~ - ~ ~ ~ ~ ~ ~ ~~.~Za t~~ '~ i~ C~ CC© ~~'C.~ A PROVE~~/{//~~~ Aoor ~ /f THE COMMISSION Date: ~~~' r / " Form 10-401 Revised 06/2004 \ /'1 ('~ ~ t"~ ~ ~ ~ ~ Submit in Duplicate ~lication for Permit to Drill, Well 1J-154 L1 Revision No.0 Saved: 1-Mar-05 Permit It -West Sak Well #1J-154 L1 Application for Permit to Drill Document ~ulpxirnizg V1ell +lvlue Table of Contents 1, Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 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 25.005(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 1J-154L1 PERMIT IT.doc Page 1 of 6 Printed: 1-Mar-05 o~~~ • ~lication for Permit to Drill, Well 1 J-154 L1 Revision No.O Saved: 1-Mar-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. Weil Name Requirements of 20 AAC 25.005 (fl Fach well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2Q AAC 25.04tT(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated far the we/l by the operator and to the number assigned to the we/I by the LOmmiSS%On. The well for which this Application is submitted will be designated as 1J-154 Li. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri/I must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (2) a plat identifying the property and the property's o~vners 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 Uceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at Iota/ depth; Location at Surface 2 133' FSL 2 569' FEL Section 35 T11N R10E ASPZone4NAD27Coordinates RKBE/evation 108.0'AMSL Northings: 5,945,944 ~ Eastings: 558,640 ~ Pad Elevation 80.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 1,276' FSL, 2,191' FWL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 4 364 Northings: 5,945,083 Eastings: 558,127 Total l/er(rcal De th RKB: 3 513 Total vertical De th SS.• 3 405 Location at Total De th 352' FNL 2 188' FWL Section 11 T10N R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB." 11 276 Northings: 5,938,175 Eastings: 558,185 Total vertical De th RKB.• 3 439 Total I/erticai De th SS: 3 331 and (D) other information required by 20 AAC 15.OSfl(b); 1J-154L1 PERMIT IT.doc Page 2 of 6 Printed: 1-Mar-05 eRisin~a~ ~3 ~tication for Permit to Drill, Well 1J-154 L1 Revision No.O Saved: 1-Mar-05 Requirements of 20 AAC 25.050(b) If a well is to be intentional/y deviated, the app/ication for a Permit to Dri/1 (Farm 10-401) must (1) include a p/at, drawn to a suitab/e scale, showing the path of the proposed wellbore, including al/ adjacent wellbares within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for a/! we//s within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable m public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only ah`ected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dri/! must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC25.03s, 20 AAC25.036, or 20 AAC Zs.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-154 Li. 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 app/ication for a Permit to Drill must be accompanied by each of the fot/owing 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 potentia/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 1,201 psi, calculated thusly: MPSP =(3,531 ft TVD)(0.45 - 0.11 psi/ft) =1,201 psi , (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes ofho% problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: 1J-154 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Grill must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the application: (S) a description of the procedure for conducting formation integrity tests, as required under 10 AAC25, 030(t}; The parent wellbore, 1J-154, 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-154L1 PERMIT /T.doc Page 3 of 6 Printed: 1-Mar-05 ~~lg ~. • ~lication for Permit to Drill, Well 1J-154 L1 Revision No.O Saved: 1-Mar-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file 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 of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ibfft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A sand 12.6 L-80 IBTM 8,432 4,440 / 3,526 12,872 / 3,588 Slotted- no cement fled Lateral (1]-154) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 6,912 4,364/ 3,51 11,276 / 3,439 Slotted- no cement slotted Lateral (1J-154 LS) 6-3/4 Sand 12.6 L-80 IBTM 6,922 4 048/ 3 441 10,97 , Slotted- no cement Slotted Lateral (1J-154 Lz) , , 7. Diverter System information Requirements of 20 AAC 25.005(c)(7) An application far a Permit to ©rr// must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the app/ication: (7) a diagram and description of the diverter system as required by 20 AAC25.035, unless this requirement is waived by the commission under 20AAC25.035(h)(2); No diverter system will be utilized during operations on iJ-154 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to ©ri// must be accompanied by each of the faf/owing items, except for an item already on file witfi the commission and identified in the application: (8) a dirt/ing fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 2s.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 ( 9.0 Plastic Viscostiy Ib/100 s 15-25 Yield Point (cP) 18-28 HTHP Fluid loss (ml/30 min @ 200psi & <4.0 150° Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. oRir~n~a~ 1J-154L1 PERMIT IT.doc Page 4 of 6 Printed: 1-Mar-05 • I~cation for Permit to Drill, Well 1J-154 L1 Revision No.O Saved: 1-Mar-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the foilowing items, except for an item already on file with the commission and identified in the application: (9) far an expioratory ar stratigraphic test wel/, a tabulation setting aut the depths ofpredicted abnormally geo pressured strata as required by ZO AAC25.033(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 app/icatron for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (i0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by ZO AAC25.06i(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the fo1/owing items, except for an item already on fi/e with the commission and identified in the application.• (ZI) for a we// drilled from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20 AAC25.06.t(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drift must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/icatron for a Permit to Dri/I must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-154 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4,364' MD / 3,513' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at 11,276' MD / 3,439' 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. j 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-154L1 PERMIT ITdoc Page 5 of 6 Printed: 1-Mar-05 c~~riNa~ • ~lication for Permit to Drill, Well 1J-154 L1 Revision No.O Saved: 1-Mar-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 17-154 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 accompany"ed by each of the following items, except for an item already on file with the cammisslon and identified in the application: (14) a general description of how the operator plans to dispose of dri!/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ 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 lJ 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-154L1 PERMIT iT.doc Page 6 of 6 Printed: 1-Mar-05 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-154 (M6) 1 J-154 L1 Plan: 1 J-154 L1 (wp06) Proposal Report 14 February, 2005 L'~R[LLING SERV[~E5 A Halliburton Company ORIGINAL i ConocoPhilli s p ~'1~~SbCa 0 c ~ 2500 N L N ~ 3125 r$ m m F 3750 sooo Project: Kuparuk River Ui Site: Kuparuk 1J Pad Well: Plan 1J-154 (M5) Wellbore: 1J-154 L7 Plan: 1J-154 L1 (wpO6) A /UII[6urton 7 5/8" TOW - 1276'FSL 8 2191'FWL -Sed 35 - T11N - R10E :Drill out 6 314" Hole : 4364 ft MD, 3513 ft ND Bottom Whipstock :Assume 15.90°/100ft : 4376 ft MD, 3515 ft ND End 30' Rathole :Begin Build @ 5.00°/100ft , 4406 ft MD, 3519 ft ND Continue Build ~ 4.00°/100ft , 4565 ft MD, 3531 ft ND 10 3/4" Casing Pt - -- -- - - - Begin Sail @ 90.79° Inc & 179.97° Azi, 4588 ft MD, 3530 ft ND Continue Dir @ 4.00°I100ft , 5134 ft MD, 3523 ft TVD Begin Sail @ 89.86° Inc & 179.97° Azi, 5157 ft MD, 3523 ft ND -~ - - LEGEND $ Plan 1J-154 (M6), 1J-154, 1J-154 (wp06) VO -~ Plan 1J-154 (M6), 1J-154 L2, 1J-154 L2 (wp06) VO $ 1J-154 L1 (wp06) Begin Geosteering in B-Lateral -Target 8' from top of B-Sand : 5257 ft MD, 3523 ft ND BHL 352' FNL & 2188' FWL -Sed 11 - T10N - R10E : 11275.67 ft MD, 3439.00 ft ND 1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 8125 6750 9375 Vertical Section at 180.00° (1250 fUin) • ~~~ Sibe: Kuparuk 1J Pad ;,,_H;, Well: Plan 1J-154(M6) Wellbore: 1J-154 L1 Plan: 1J-154 L1 (wp06) West(-)/East(+) (1250 ft/in) -2500 -1875 -1250 -625 0 825 1250 1875 2500 3125 3750 4375 5000 7 5/8" TOW - 1276'FSL & 2191'FVV~ -Sect 35 - T11 N - R10E :Drill out 6 3/4" Hole : 4364 ft MD, 3513 ft TVD 10 3/4" Casing Pt _ ,~ Bottom Whipstock :Assume 15.90°/100ft : 4376 ft MD, 3515 ft TVD -625 1250 1875 -31 -81 T M Azimuths to True North Magnetic North: 24.54° Magnetic Field Strength:57578.5nT Dip Angle: 80,72° Date: 11/22/2004 Model: BGGM2004 c_ 0 u~ N L 1= O Z t 7 0 180° 180° a End 30' Rathole :Begin Build @ 5.00°/100ft , 4406 ft MD, 3519 ft TVD 180° ~~ 180 180° 180° 180° 180° 180° 180° Continue Build @ 4.00°/100ft , 4565 ft MD, 3531 ft TVD Begin Sail ~ 90.79° Inc & 179.97° Azi, 4588 ft MD, 3530 ft ND Continue Dir @ 4.00°/100ft , 5134 ft MD, 3523 ft TVD Begin Sail @ 89.86° Inc & 179.97° Azi, 5157 ft MD, 3523 ft TVD ~ 0 c in B-Lateral -Target 8' from top of B-Sand : 5257 ft MD, 3523 ft TVD Z 0 3 + N (,T1 O c~ 3' Plan 1J-154 (M6)/1J-154 L2 (wp06) 180° BHL:352'FNL&2188'FWL-Sed11-T10N-R10E:11275.67ftMD,3439.tX1ftTVD 1250 1875 / -/JUV LEGEND 4 1 /2" -8125 ~ Plan 1J-154 (M6), 1J-154, 1J-154 (wp06) VO $ Plan 1J-154 (M6), 1J-154 L2, 1J-154 L2 (wp06) VO $ 1J-154 L1 (wp06) -8750 Plan 1J-154 (M6)/1J-154 (wp06) -2500 -1875 -1250 -625 1250 1875 2500 3125 3750 4375 5000 West(-)/East(+) (1250 ftlin) ORIriNQ~ • • •-' C Philli Halliburton Company ~p~-,r,y..si,,,~n onoco ps Planning Report -Geographic Alaska A Nalllbunon Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) ND Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Weilhead(108') @ 108.OOft (WeNhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L1 Design: 1J-154 L1 (wp06) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-154 (M6) Well Position +N/-S 0.00 ft Northing: 5,945,944.10 ft Latitude: 70° 15' 46.510" N +E/-W 0.00 ft Easting: 558,639.50 ft Longitude: 149° 31' 33.379" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore I ~, Magnetics J-154 L1 Model Name Sample Date BGG M2004 11 /22/2004 Declination Dip Angle Field Strength (°) 1°) InTI 24.54 80.72 57,578 Design Audit Notes: Version: Vertical Section 1J-154 L1 (wp06) Phase: PLAN Tie On Depth: Depth From (TVD) +N/-S +FJ-W (ft) (ft) (ft) 28.00 0.00 0.00 Direction (°) 180.00 4,364.24 2/14!2005 11:55:03AM Page 2 of 8 COMPASS 2003.11 Build 50 ~!_~ 3 ~~ ~~.~ s ~ `' C PhiHi Halliburton Company ~7~1"~~,/-~Ut'1 onoco ps Planning Report -Geographic ~ Alaska A wlllhunon Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Weilhead(108') @ 108.008 (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108')-@ 108.OOft (Wellhead(108')) Site: Kuparuk 1J Pad North Reference: True Weli: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wetlbore: 1J-154 L1 Design: 1J-154 L1 (wp06) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate -~O (ft) {°) (°) (ft) (ft) (tt) {°1100ft) (°I100ft) (°11008) (°) 4,364.24 80.00 179.97 3,513.00 -857.14 -519.68 0.00 0.00 0.00 0.00 4,376.24 81.91 179.97 3,514.89 -868.99 -519.67 15.90 15.90 0.00 0.00 4,406.24 81.91 179.97 3,519.11 -898.69 -519.66 0.00 0.00 0.00 0.00 4,565.28 89.86 179.97 3,530.52 -1,057.19 -519.58 5.00 5.00 0.00 360.00 4,588.46 90.79 179.97 3,530.38 -1,080.37 -519.56 4.00 4.00 -0.01 -0.16 5,134.24 90.79 179.97 3,522.89 -1,626.10 -519.25 0.00 0.00 0.00 0.00 5,157.42 89.86 179.97 3,522.76 -1,649.28 -519.24 4.00 -4.00 0.01 179.84 5,257.42 89.86 179.97 3,523.00 -1,749.28 -519.19 0.00 0.00 0.00 0.00 5,307.84 91.37 180.07 3,522.46 -1,799.70 -519.20 3.00 2.99 0.19 3.65 5,703.59 91.37 180.07 3,513.00 -2,195.33 -519.66 0.00 0.00 0.00 0.00 5,716.06 91.74 180.03 3,512.66 -2,207.80 -519.67 3.00 2.98 -0.32 -6.18 6,659.15 91.74 180.03 3,484.00 -3,150.45 -520.10 0.00 0.00 0.00 0.00 6,692.83 90.74 179.93 3,483.27 -3,184.12 -520.08 3.00 -2.99 -0.30 -174.34 7,103.25 90.74 179.93 3,478.00 -3,594.51 -519.56 0.00 0.00 0.00 0.00 7,118.50 91.19 180.00 3,477.74 -3,609.76 -519.55 3.00 2.96 0.51 9.70 7,878.51 91.19 180.00 3,462.00 -4,369.61 -519.59 0.00 0.00 0.00 0.00 7,986.28 87.95 180.05 3,462.81 -4,477.36 -519.64 3.00 -3.00 0.04 179.20 8,303.91 87.95 180.05 3,474.15 -4,794.79 -519.91 0.00 0.00 0.00 0.00 8,430.41 91.75 180.12 3,474.47 -4,921.26 -520.10 3.00 3.00 0.06 1.15 9,003.15 91.75 180.12 3,457.00 -5,493.73 -521.35 0.00 0.00 0.00 0.00 9,043.55 90.54 180.06 3,456.19 -5,534.12 -521.41 3.00 -3.00 -0.17 -176.82 9,596.26 90,54 180.06 3,451.00 -6,086.80 -521.97 0.00 0.00 0.00 0.00 9,597.86 90.50 180.03 3,450.99 -6,088.41 -521.97 3.00 -2.49 -1.67 -146.21 10,975.48 90.50 180.03 3,439.00 -7,465.97 -522.71 0.00 0.00 0.00 0.00 11,033.59 89.95 178.38 3,438.77 -7,524.08 -521.90 3.00 -0.95 -2.85 -108.45 11,275.68 89.95 178.38 3,439.00 -7,766.07 -515.04 0.00 0.00 0.00 0.00 2/14/2005 11:55:03AM Page 3 of 8 COMPASS 2003.11 Build 50 ~~~~.r • ~ Halliburton Company Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single UsecDb Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc:(Kuparuk) TVD Reference: Project: KuparukRiver Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-154 (M6) Survey Calculation Method: Welltwre: 1J-154 L1 Design: 1J-954 L1 (wp06) Planned Survey 1J-154 L1 (wp06) • Sperry- A HaIIIDurton Company WeIi-Plan 1J-154 (M6) Wellhead(108') @ 108.OOft (Wellhead(~OS')) Wellhead(108') @ 108:OOft (Vllellhead(108')) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +Nl-S +E/_yy Northing Easting (ft) (°) (°1 Ift) Ift) (ft) (ft) Ift) (ft) 4,364.24 80.00 179.97 3,513.00 3,405.00 -857.14 -519.68 5,945,083.02 558,126.56 7 5/8" TOW - 1278'FSL 8 2191'FWL -Sect 35 - T11 N - R 10E :Drill out 83/4" Hole : 4384 ft MD, 3513 ft TVD - 7518" Window Top 4,376.24 81.91 179.97 3,514.89 3,406.89 -868.99 -519.67 5,945,071.18 558,126.66 Bottom Whipstock :Assume 15.90°1100ft : 4378 ft MD, 3515 ft TVD 4,400.00 81.91 179.97 3,518.23 3,410.23 -892.51 -519.66 5,945,047.66 558,126.85 4,406.24 81.91 179.97 3,519.11 3,411.11 -898.69 -519.66 5,945,041.48 558,126.91 End 30' Rathole :Begin Build ~ 5.00°I100ft , 4408 ft MD, 3519 ft TVD 4,500.00 86.60 179.97 3,528.50 3,420.50 -991.95 -519.61 5,944,948.23 558,127.68 4,565.28 89.86 179.97 3,530.52 3,422.52 -1,057.19 -519.58 5,944,883.00 558,128.22 Continue Build ~ 4.00°I100ft , 4585 ft MD, 3531 ft TVD 4,588.46 90.79 179.97 3,530.38 3,422.38 -1,080.37 -519.56 5,944,859.82 558,128.42 Begin Sail Q 90.79° Inc 8 179.97° Azi, 4588 ft MD, 3530 ft TVD 4,600.00 90.79 179.97 3,530.23 3,422.23 -1,091.91 -519.56 5,944,848.28 558,128.51 4,700.00 90.79 179.97 3,528.85 3,420.85 -1,191.90 -519.50 5,944,748.31 558,129.35 4,800.00 90.79 179.97 3,527.48 3,419.48 -1,291.89 -519.44 5,944,648.33 558,130.18 4,900.00 90.79 179.97 3,526.10 3,418.10 -1,391.88 -519.39 5,944,548.35 558,131.02 5,000.00 90.79 179.97 3,524.73 3,416.73 -1,491.87 -519.33 5,944,448.37 558,131.85 5,100.00 90.79 179.97 3,523.36 3,415.36 -1,591.86 -519.27 5,944,348.40 558,132.69 5,134.24 90.79 179.97 3,522.89 3,414.89 -1,626.10 -519.25 5,944,314.16 558,132.98 Continue Dir ~ 4.00°I100ft , 5134 ft MD, 3523 ft TVD 5,157.42 89.86 179.97 3,522.76 3,414.76 -1,649.28 -519.24 5,944,290.99 558,133.17 Begin Sail ~ 89.88° Inc 8 179.97° Azi, 5157 ft MD, 3523 ft TVD 5,200.00 89.86 179.97 3,522.86 3,414.86 -1,691.86 -519.22 5,944,248.41 558,133.52 5,257.42 89.86 179.97 3,523.00 3,415.00 -1,749.28 -519.19 5,944,191.00 558,134.00 Begin Geosteering in B•Lateral -Target 8' from top of B-Sand : 8257 ft MD, 3523 ft TVD • 1J-154 L1 T1 (v3) 5,300.00 91.13 180.05 3,522.63 3,414.63 -1,791.86 -519.20 5,944,148.43 558,134.32 5,307.84 91.37 180.07 3,522.46 3,414.46 -1,799.70 -519.20 5,944,140.59 558,134.38 5,400.00 91.37 180.07 3,520.26 3,412.26 -1,891.83 -519.31 5,944,048.47 558,134.99 5,500.00 91.37 180.07 3,517.87 3,409.87 -1,991.80 -519.43 5,943,948.51 558,135.65 5,600.00 91.37 180.07 3,515.48 3,407.48 -2,091.77 -519.54 5,943,848.55 558,136.31 5,700.00 91.37 180.07 3,513.09 3,405.09 -2,191.74 -519.66 5,943,748.59 558,136.98 5,703.59 91.37 180.07 3,513.00 3,405.00 -2,195.33 -519.66 5,943,745.00 558,137.00 1J-154 L1 T2 w3{ 5,716.06 91.74 180.03 3,512.66 3,404.66 -2,207.80 -519.67 5,943,732.53 558,137.09 5,800.00 91.74 180.03 3,510.11 3,402.11 -2,291.70 -519.71 5,943,648.65 558,137.70 5,900.00 91.74 180.03 3,507.07 3,399.07 -2,391.65 -519.75 5,943,548.70 558,138.44 6,000.00 91.74 180.03 3,504.03 3,396.03 -2,491.60 -519.80 5,943,448.76 558,139.17 6,100.00 91.74 180.03 3,500.99 3,392.99 -2,591.56 -519.85 5,943,348.82 558,139.90 6,200.00 91.74 180.03 3,497.95 3,389.95 -2,691.51 -519.89 5,943,248.88 558,140.63 6,300.00 91.74 180.03 3,494.91 3,386.91 -2,791.47 -519.94 5,943,148.94 558,141.37 6,400.00 91.74 180.03 3,491.88 3,383.88 -2,891.42 -519.98 5,943,049.00 558,142.10 6,500.00 91.74 180.03 3,488.84 3,380.84 -2,991.37 -520.03 5,942,949.06 558,142.83 6,600.00 91.74 180.03 3,485.80 3,377.80 -3,091.33 -520.07 5,942,849.11 558,143.57 6,659.15 91.74 180.03 3,484.00 3,376.00 -3,150.45 -520.10 5,942,790.00 558,144.00 1J-154 L1 T3 w3) DLSEV Vert Section (°/100ft) (ft) 0.00 857.14 15.90 868.99 0.00 892.51 0.00 898.69 5.00 991.95 5.00 1,057.19 4.00 1,080.37 0.00 1,091.91 0.00 1,191.90 0.00 1,291.89 0.00 1,391.88 0.00 1,491.87 0.00 1,591.86 0.00 1,626.10 4.00 1,649.28 0.00 1,691.86 0.00 1,749.28 3.00 1,791.86 3.00 1,799.70 0.00 1,891.83 0.00 1,991.80 0.00 2,091.77 0.00 2,191.74 0.00 2,195.33 3.00 2,207.80 0.00 2,291.70 0.00 2,391.65 0.00 2,491.60 0.00 2,591.56 0.00 2,691.51 0.00 2,791.47 0.00 2,891.42 0.00 2,991.37 0.00 3,091.33 0.00 3,150.45 2H4/2005 11:55:03AM Page 4 of 8 COMPASS 2003.11 Build 50 ~.. ~-' C Philli Halliburton Company ~,~',r,y_~,,,,~-, onoto ps Planning Report -Geographic Alaska a FlalllbuROn Company Database: EDM 2003:11 Single User Db Local Ca-ordinate Reference: Well Plan 1J-t54 (M6) Company: ConocoPhillipsAlaska lnc:(Kuparuk) TVD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Site: Kupa[uk 1 J Pad North Reference: True Well: PIarr1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L1 Design: 1J-154 L1 (wp06) Planned Survey 1J-t54 L1 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-yy Northing Easting DLSEV Vert Section (ftl (°) (°) Iftl Iftl (ftl (ft) (ft) Ift) (°/100ft1 (ft) 6,692.83 90.74 179.93 3,483.27 3,375.27 -3,184.12 -520.08 5,942,756.33 558,144.28 3.00 3,184.12 6,700.00 90.74 179.93 3,483.18 3,375.18 -3,191.29 -520.08 5,942,749.16 558,144.34 0.00 3,191.29 6,800.00 90.74 179.93 3,481.90 3,373.90 -3,291.28 -519.95 5,942,649.18 558,145.25 0.00 3,291.28 6,900.00 90.74 179.93 3,480.61 3,372.61 -3,391.27 -519.82 5,942,549.21 558,146.16 0.00 3,391.27 7,000.00 90.74 179.93 3,479.33 3,371.33 -3,491.27 -519.69 5,942,449.23 558,147.06 0.00 3,491.27 7,100.00 90.74 179.93 3,478.04 3,370.04 -3,591.26 -519.56 5,942,349.25 558,147.97 0.00 3,591.26 7,103.25 90.74 179.93 3,478.00 3,370.00 -3,594.51 -519.56 5,942,346.00 558,148.00 0.00 3,594.51 1J-154 L7 T4 (v3) 7,118.50 91.19 180.00 3,477.74 3,369.74 -3,609.76 -519.55 5,942,330.75 558,148.13 3.00 3,609.76 7,200.00 91.19 180.00 3,476.06 3,368.06 -3,691.24 -519.55 5,942,249.28 558,148.76 0.00 3,691.24 7,300.00 91.19 180.00 3,473.98 3,365.98 -3,791.22 -519.56 5,942,149.32 558,149.53 0.00 3,791.22 7,400.00 91.19 180.00 3,471.91 3,363.91 -3,891.19 -519.56 5,942,049.35 558,150.30 0.00 3,891.19 7,500.00 91.19 180.00 3,469.84 3,361.84 -3,991.17 -519.57 5,941,949.39 558,151.08 0.00 3,991.17 7,600.00 91.19 180.00 3,467.77 3,359.77 -4,091.15 -519.58 5,941,849.42 558,151.85 0.00 4,091.15 7,700.00 91.19 180.00 3,465.70 3,357.70 -4,191.13 -519.58 5,941,749.45 558,152.62 0.00 4,191.13 7,800.00 91.19 180.00 3,463.63 3,355.63 -4,291.11 -519.59 5,941,649.49 558,153.39 0.00 4,291.11 7,878.51 91.19 180.00 3,462.00 3,354.00 -4,369.61 -519.59 5,941,571.00 558,154.00 0.00 4,369.61 1J-154 Li TB (v3) 7,900.00 90.54 180.01 3,461.68 3,353.68 -4,391.09 -519.60 5,941,549.52 558,154.16 3.00 4,391.09 7,986.28 87.95 180.05 3,462.81 3,354.81 -4,477.36 -519.64 5,941,463.26 558,154.79 3.00 4,477.36 8,000.00 87.95 180.05 3,463.30 3,355.30 -4,491.07 -519.65 5,941,449.56 558,154.89 0.00 4,491.07 8,100.00 87.95 180.05 3,466.87 3,358.87 -4,591.00 -519.74 5,941,349.63 558,155.58 0.00 4,591.00 8,200.00 87.95 180.05 3,470.44 3,362.44 -4,690.94 -519.82 5,941,249.71 558,156.27 0.00 4,690.94 8,300.00 87.95 180.05 3,474.01 3,366.01 -4,790.87 -519.91 5,941,149.78 558,156.97 0.00 4,790.87 8,303.91 87.95 180.05 3,474.15 3,366.15 -4,794.79 -519.91 5,941,145.87 558,156.99 0.00 4,794.79 1J-154 L1 T7 (v3) 8,400.00 90.84 180.11 3,475.16 3,367.16 -4,890.86 -520.04 5,941,049.81 558,157.61 3.00 4,890.86 8,430.41 91.75 180.12 3,474.47 3,366.47 -4,921.26 -520.10 5,941,019.42 558,157.79 3.00 4,921.26 8,500.00 91.75 180.12 3,472.35 3,364.35 -4,990.82 -520.25 5,940,949.86 558,158.18 0.00 4,990.82 8,600.00 91.75 180.12 3,469.30 3,361.30 -5,090.77 -520.47 5,940,849.92 558,158.74 0.00 5,090.77 8,700.00 91.75 180.12 3,466.25 3,358.25 -5,190.72 -520.69 5,940,749.98 558,159.30 0.00 5,190.72 8,800.00 91.75 180.12 3,463.20 3,355.20 -5,290.68 -520.90 5,940,650.04 558,159.86 0.00 5,290.68 8,900.00 91.75 180.12 3,460.15 3,352.15 -5,390.63 -521.12 5,940,550.09 558,160.42 0.00 5,390.63 9,000.00 91.75 180.12 3,457.10 3,349.10 -5,490.58 -521.34 5,940,450.15 558,160.98 0.00 5,490.58 9,003.15 91.75 180.12 3,457.00 3,349.00 -5,493.73 -521.35 5,940,447.00 558,161.00 0.00 5,493.73 1J-154 L1 T8 (v3) 9,043.55 90.54 180.06 3,456.19 3,348.19 -5,534.12 -521.41 5,940,406.62 558,161.25 3.00 5,534.12 9,100.00 90.54 180.06 3,455.66 3,347.66 -5,590.57 -521.47 5,940,350.18 558,161.63 0.00 5,590.57 9,200.00 90.54 180.06 3,454.72 3,346.72 -5,690.56 -521.57 5,940,250.19 558,162.31 0.00 5,690.56 9,300.00 90.54 180.06 3,453.78 3,345.78 -5,790.56 -521.67 5,940,150.21 558,162.99 0.00 5,790.56 9,400.00 90.54 180.06 3,452.84 3,344.84 -5,890.56 -521.77 5,940,050.23 558,163.67 0.00 5,890.56 9,500.00 90.54 180.06 3,451.90 3,343.90 -5,990.55 -521.87 5,939,950.24 558,164.35 0.00 5,990.55 9,596.26 90.54 180.06 3,451.00 3,343.00 -6,086.80 -521.97 5,939,854.00 558,165.00 0.00 6,086.80 1J-154 L1 T9 (v3) 9,597.86 90.50 180.03 3,450.99 3,342.99 -6,088.41 -521.97 5,939,852.40 558,165.01 3.00 6,088.41 9,600.00 90.50 180.03 3,450.97 3,342.97 -6,090.55 -521.97 5,939,850.26 558,165.03 0.00 6,090.55 9,700.00 90.50 180.03 3,450.10 3,342.10 -6,190.54 -522.02 5,939,750.27 558,165.75 0.00 6,190.54 9,800.00 90.50 180.03 3,449.23 3,341.23 -6,290.54 -522.07 5,939,650.29 558,166.48 0.00 6,290.54 2H4/2005 11:55:03AM Page 5 of8 COMPASS 2003.11 Build 50 QR!(~~~!AI. / Phitli C Halliburton Company ~~-'r'y-~ onoco ps Planning Report -Geographic AIBSI(a A Halliburton Compa~ry Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-1 .54 (M6) Company: ConocoPhillipsAl aska Inc.(Kuparuk)- TVD Reference: Wellhead(108') @ 108,OOft (Wel lhead(108~) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108:OOft (Wel lhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L1 Design: 1J-154 L1 (wp06) Planned Survey 1J-154 L1 (wp06) - - -- - - - - - - i Map Map MD I nclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section tftl (°) (°) tft1 Iftl Iftl Ift) Iftl (ft) 1°1100ft) (ft) 9,900.00 90.50 180.03 3,448.36 3,340.36 -6,390.54 -522.13 5,939,550.31 558,167.20 0.00 6,390.54 10,000.00 90.50 180.03 3,447.49 3,339.49 -6,490.53 -522.18 5,939,450.32 558,167.93 0.00 6,490.53 10,100.00. 90.50 180.03 3,446.62 3,338.62 -6,590.53 -522.24 5,939,350.34 558,168.65 0.00 6,590.53 10,200.00 90.50 180.03 3,445.75 3,337.75 -6,690.52 -522.29 5,939,250.35 558,169.38 0.00 6,690.52 10,300.00 90.50 180.03 3,444.88 3,336.88 -6,790.52 -522.34 5,939,150.37 558,170.10 0.00 6,790.52 10,400.00 90.50 180.03 3,444.01 3,336.01 -6,890.52 -522.40 5,939,050.39 558,170.83 0.00 6,890.52 10,500.00 90.50 180.03 3,443,14 3,335.14 -6,990.51 -522.45 5,938,950.40 558,171.55 0.00 6,990.51 10,600.00 90.50 180.03 3,442.27 3,334.27 -7,090.51 -522.50 5,938,850.42 558,172.28 0.00 7,090.51 10,700.00 90.50 180.03 3,441.40 3,333.40 -7,190.50 -522.56 5,938,750.43 558,173.00 0.00 7,190.50 10,800.00 90.50 180.03 3,440.53 3,332.53 -7,290.50 -522.61 5,938,650.45 558,173.73 0.00 7,290.50 10,900.00 90.50 180.03 3,439.66 3,331.66 -7,390.50 -522.66 5,938,550.47 558,174.45 0.00 7,390.50 10,975.48 90.50 180.03 3,439.00 3,331.00 -7,465.97 -522.71 5,938,475.00 558,175.00 0.00 7,465.97 1J-154 L1 Dtoe (v3- 11,000.00 90.27 179.33 3,438.84 3,330.84 -7,490.49 -522.57 5,938,450.48 558,175.33 2.99 7,490.49 11,033.59 89.95 178.38 3,438.77 3,330.77 -7,524.08 -521.90 5,938,416.91 558,176.26 3.00 7,524.08 11,100.00 89.95 178.38 3,438.84 3,330.84 -7,590.46 -520.02 5,938,350.55 558,178.66 0.00 7,590.46 11,200.00 89.95 178.38 3,438.93 3,330.93 -7,690.42 -517.18 5,938,250.63 558,182.27 0.00 7,690.42 11,275.68 89.95 178.38 3,439.00 3,331.00 -7,766.07 -515.04 5,938,175.00 558,185.00 0.00 7,766.07 BHL :352' FNL 8 2188' FWL -Sect 11 - T10N - R10E : 11275.07 ft MD, 3439.00 ft TVD - 41/2" -1J-154 L1 etoe (v3) 2H4/2005 11:55:03AM Page 6 of 8 COMPASS 2003.11 Build 50 OR!GIN,41_ • • / ' Halliburton Company 5~~1'~~J-5U1~1 ConocoPl ullips Planning Report -Geographic Alaska A Ha111Durton Company Database: EDM 2003.11 Single User Db Local Co-oMinate Reference: Weil Plam1J-154 (M6) Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: Wellhead(108') @ 108.OOft (Weghead(108'p Project: Kuparuk River Unite MD Reference: Wellhead(108') @ 108.OOft (Wetlhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-.154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L1 Design: 1J-154 L1 (wp06) - - ~ Geologic Targets 1 J-154 L1 I TVD Target Name +w_S +EJ-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,479.00 1J-154 L7 T7 (v3) -4,794.66 -519.90 5,941,146.00 558,157.00 - Point 3,523.00 1J-154 L1 T1 (v3) -1,749.28 -519.19 5,944,191.00 558,134.00 - Point 3,451.00 1J-154 L1 T9 (v3) -6,086.80 -521.97 5,939,854.00 558,165.00 -Point 3,457.00 1J-154 L1 T8 (v3) -5,493.73 -521.35 5,940,447.00 558,161.00 - Point 3,439.00 1J-154 L7 Dtoe (v3) -7,465.97 -522.71 5,938,475.00 558,175.00 - Point 3,478.00 1J-154 L1 T4 (v3) -3,594.51 -519.56 5,942,346.00 558,148.00 - Point 3,462.00 1J-154 L1 T5 (v3) -4,369.61 -519.59 5,941,571.00 558,154.00 - Point 3,439.00 1J-154 L1 Btoe (v3) -7,766.07 -515.04 5,938,175.00 558,185.00 - Point 3,473.00 1J-154 L1 Prognosed Fault#1 -4,717.64 -521.30 5,941,223.00 558,155.00 - Point 3,484.00 1J-154 L1 T3 (v3) -3,150.45 -520.10 5,942,790.00 558,144.00 - Point 3,456.00 13-154 L7 T6 (v3) -4,594.63 -520.35 5,941,346.00 558,155.00 - Point 3,513.00 1J-154 L1 T2 (v3) -2,195.33 -519.66 5,943,745.00 558,137.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 2,301.04 2,203.00 10-314 13-112 4,364.25 3,513.00 7-818 9-7/8 11,275.67 3,439.00 4112 8-3/4 2H4/2005 11:55:03AM Page 7 of 8 COMPASS 2003.11 Build 50 Y ~% ConocoPhilli Halliburton Company ~p~rty..~~ ps Planning Report - Geographic 1 Alaska a ru,mearton compaey Database: EDM 2003:11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154. (M6) Company: ConocoPhillips Alaska Ina(Kuparuk) ND Reference: Wellhead(108') @ 108;OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wetlhead(108') @ 108:OOft (1/Vellhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L1 Design: 1J-154 L1 (wp06j Prognosed Formati on Intersection Points Measured Vertical Depth Inclination Azimuth Depth +NI-E +E/-W (ft) 1°) 1°1 {ft) Iftl (ftl Name 1,582.21 25.25 326.50 1,538.00 203.39 -134.62 Base of Permafrost 1,704.94 25.25 326.50 1,649.00 247.05 -163.52 T3 2,016.52 23.68 326.17 1,934.00 351.69 -233.55 K75 2,301.04 14.23 295.08 2,203.00 415.85 -297.31 T3+550 2,427.38 12.59 268.50 2,326.00 422.07 -325.17 T3 + 675 3,031.91 32.17 197.57 2,890.00 263.23 -442.35 Ugnu C 3,314.57 45.39 189.50 3,110.00 91.38 -481.87 Ugnu6 3,425.28 50.68 187.31 3,184.00 9.97 -493.84 UgnuA 3,641.32 61.10 183.86 3,305.00 -167.81 -510.89 K13 4,047.85 76.00 179.97 3,441.00 -549.12 -519.84 West Sak D 4,209.06 76.00 179.97 3,480.00 -705.54 -519.76 C 4,364.24 80.00 179.97 3,513.00 -857.14 -519.68 B 2/14/2005 11:55:03AM Page 8 of 8 COMPASS 2003.11 Build 50 ~'~~, i. i • • Halliburton Company Anticollision Report Company: " ConocoPhillips Alaska IttC. Date: 2/22/2005 Time: 16:21:49 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-154, Tru e North Reference Well: Plan 1J-154 Vertrcal (TVD) Refere nce: Plans: 108.0 Reference Wellpath: 1J-154 Li Db: Orade NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: 1J-154 L1 (wp06) & NOT PLANNE Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 4364.24 to 11275.68 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in ' in 4364.24 3513.00 7.875 9.875 7 518 11275.68 3439.01 5.500 6.750 51/2" Plan: 1J-154 L1 (wp06) Date Composed: 2/13/2005 Version: 2 Principal: Yes Tied-to: From: Definitive Path Summary <---------------- Offset Wellpath --------------~ Reference ` Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MA Ml) Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad Plan 1J-152 1J-152 L1 V1 Plan: 1J- 11129.29 12623.45 1225.83 271.09 954.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 L2 V1 Plan: 1J- 10865.21 12317.36 1236.15 265.25 970.90 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 V1 Plan: 1J-152 11269.26 12775.00 1248.09 289.27 958.82 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L1 V1 Plan: 1J- 11218.01 10448.75 1227.60 257.98 969.62 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L2 V1 Plan: 1J- 10882.70 10142.55 1235.04 253.22 981.81 Pass: Major Risk Kuparuk 1 J Pad Plan 1 J-159 1 J-159 VO Plan: 1 J-159 11258.86 10500.00 1245.38 269.51 975.87 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 L1 V1 Plan: 1J- 9792.24 7225.00 987.60 205.34 782.26 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 VO Plan: 1J-182 9792.24 7225.00 987.60 205.34 782.26 Pass: Major Risk Kuparuk 1J Pad Plan 1J-184 1J-184 L1 VO Plan: 1J- 11269.94 8500.00 211.31 137.62 73.70 Pass: Minor 1/5000 Kuparuk 1J Pad Plan 1J-184 1J-184 V1 Plan: 1J-184 11269.94 8500.00 211.31 137.62 73.70 Pass: Minor 1/5000 Kuparuk 1J Pad WSP-06 WSP-06 V1 Out of range Kuparuk iJ Pad WSP-07 WSP-07 V1 Out of range Kuparuk 1J Pad WSP-10 WSP-10 V1 4365.24 4025.00 497.74 81.53 416.21 Pass: Major Risk Kuparuk 1J Pad WSP-14 WSP-14 V1 4819.86 3675.00 652.65 120.21 532.44 Pass: Major Risk ROG ~ ~ ,.t D F SURVEY PROGRAM Date: 2005-112-0RTO11:00:00 Validalcd: Vlw Veraioe: Depth Fmm Dcpth To Sur3ev/PIaR Tool 0.00 BW.00 CB-GYRO-SS 900.00 J36J.2J MWD+IFR-AR-CAZSC 4J6J.2J 11275,68 IJ-ISl L11npD61 M1IWD+•IFR-Ali-CAZSC En9lnming Nb saY cabwertn ue6,aa: 6Bnertum c«.aw« Ert« Syalm'. ISCVVSA s~.e Memoa'. rrav cNlrtaer ROnn Error Surf'r<'. EXiPtiultmb Wamlig Metlwd. Ruka BaaM ANTI-COLLISION Interpolation Method: MD Interval: 25Stations I Depth Range From: 4364.24 to 11275.68 Maximum Ran~t'Rf94.Qe4 Plan: 1J-154 L1 (wp06) V .rs.~.>. `' z7o ~•~-- 9~, ~; ~,. -~ ~r M D4ar6nale (BYE) Ralere«e. WeW Pbn 1J-154 (8161. True NoM Verticel(ND)Relere«e WagMad108'I®108008IWeIFeatl(1 1 6bt-10 OOOE) nu' V6 R l S B T . on ( J e are ec Maawetl DepM Relarenu'. WelMatl(100)®10&0011 IWepaeatl(1 )) --11- GEWaBon Metlmtl. Miivr4an CurveNre .r+ +m WELL DETAILS: Plan 1J-154 (M6) ~- Ground Level: 90' w N +WS +EI-W Northing Easting Latittude Longitude Sbt ~- "°'"^ 0.00 0,00 5945944.10 558619.50 70°15'46.57N 149°11'33.379W 180 90 {~ m --0-- ~ ~..,, Travelling Cylinder Azimuth (TFO+AZ1) [°[ vs Centre to Centre Separation [100 ft/in[ REFERENCE INFORMATION From Colour To MD 180 90 0 100 10o Trg~lling Cylinder Azimuth (TFO+AZI) [°[ vs Centre tD Centre Separation [15 200 400 400 800 800 1000 1000 1500 1500 ~ - 2000 s6cnoN DETAILS 2000 2500 Sec MD Nic Azi ND ~WS *Fl-W DLeg 1 4364.24 8000 1]99] 3s1300 851.14 519.68 000 2 43]6.24 8191 1]99] 351d 89 4160.99 519.6] 15.90 TFace Vsec Taryel 000 8$114 D00 86899 2500 - ~ 3000 q 856528 &986 1]98] 353052 -05].19 -519.50 500 000 105]19 3000 3500 5 458846 90.]9 1]99] 353038 1080.3] 51956 4.00 s s13a z4 eD.]9 n9 s] 3s2z ee .lbz6m ~slszs Dao -0.16 '080.3] ooD 62sro 350() 4000 ] 515].42 89.86 1]9.9] 3523]6 -164928 51934 000 8 525)42 88.86 1]9.9] J52300 -1]4928 519.18 000 1]98d 164928 000 1]49.28 1J-159 Lt Tl lv3) ]0 65 1]93 B 530]84 91.3] 180.0] 3522.46 ~1 ]99.]0 ~5192D ].CO 10 5)03.59 913] 180.0] 351300 -2195.33 51966 000 . 3 000 219533 11154 L1 T2 (v37 4000 4500 11 5]16.06 91]4 1800) 351166 -220].00 .518fi] 300 518 220)80 4 FjQO 5~0 12 6659.15 91'!4 18003 348190 -3150.45 -520.10 000 1J 6692.83 80]4 1]9.83 348J 21 -318412 -52008 3.00 000 3150.45 1}154 L1 TJ (vJ) -1]I.31 3184.12 T J 5~() 6~0 14 ]10J 25 90.]4 1]993 34]800 3594.51 -51956 000 15 ]11850 9119 180.00 34]]]4 ~J809.T6 -51955 J00 18 ]8]851 9119 180.00 J46200 -4369.61 51958 000 4 (v ) 000 359451 11154 L1 9]0 Jfi(19.]6 000 436961 1J-154 L1 T5 (v3) 6000 7000 17 ]98628 8195 180.05 348281 -44]]36 51964 300 10 830391 BT 95 18005 3d]4.15 -4]94.]9 51991 000 1T9.20 44]].35 000 4]94]9 1J-154 L1 T](JJI 700Q 8~0 19 843(141 91 ]5 18013 J4]4d] -4921 M 52010 300 20 900315 91]5 180.12 345]00 5493]3 -521 JS 000 1 15 4921 36 000 5493]3 1J-154L1 T8 (v3) 9000 21 904355 90.54 18006 ]456.19 55]4.12 52141 J.CO 22 Y:%.26 9054 18006 345100 -600600 -5219] 0.00 -1 ]6 B2 SSJ4.12 000 fi086 B0 1J-154 L1 T9 (YI 1 fi0884t BDOD 23 959]86 90.50 1800) 345099 -6068.41 -521.91 300 24109]540 90.50 18003 343900 -]4659] -523]1 000 1463 000 ]4659] 1115/L1 Dloe (v3) 9000 100 26112]568 8995 1]038 3439.00 ~]]664~ -5504 000 1000 ]]6608 1J-I54L1 RIoe (v3) 10000 11000 11000 12000 12000 0 1~- .... (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, 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-154L1 Drilling Hazards Summary.doc prepared by Shane C/oninger ~ ~' , ~ 2/28/2005 9:04 AM 'Tubing Head Assy, 13-5/8" X 4-1/2". 'Tubing Hanger, concentric, no penetrations. 10-314" Casing Shoe,) set ~ 2301' MD, 2203' TVD / Tubing String 4-112" 12.6#, L-60, IBTM 3.958" ID, 3.833" Drift 5-112" X 7318" ZXP Seal Assembly Liner Top Packer 4.75" Seal OD with Hold Downs 3.875" ID 17' Length Tubing Swivel, 4-112" Tubing, Special Drift to +/- 500' MD CanoCAPhi I I ips DB Nipple, for Possible SSSV, set at+/_ 500' MD West Sak 7-5/8" Injector GLM, Camco 1" KBG-2 1 J-154 GLM, Camco 1" KBG-2 Tri-Lateral Completion CMU Sliding Sleeve, wl DB Nipple, set at 70 deg max inclination Casing Sealbore Receptacle _ 4.75" ID, 6.25" OD 20' Length / Lateral Entry Module(LEM) Orienting Profile D•sand Window at 4048' M D, 3441' TVD 4-112" 12.6# L-80 Slotted 11KK Liner Swivel Liner Every Other Joint 4-112" X 7316" Seal Bon Model'B' HOOK Hander 3.68" ID 5-112" X 7518" ZXP Liner Top Packer with Hold Downs Lateral EntryJVlodule (LEM) Assembly f - - 5-112" X 7518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID -- Tubing Swivel, 4-112" -- Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~' Access window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID .\ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbor~ Receptacle 4.75" ID, 6.25" OD 20' Length 4-112" X Seal Assembly 4.75" Seal OD i 3.875" ID 2' Length 'D' Sand Lateral 3-112" Bent Joint 1 3-112" Guide Shoe 4-1/2" Casing Shoe, 12.6#, L-80 IBTM Set ~ 10970' MD, 3366' TVD PackoH Bushing ~aterel Entry Module(] Orienting Profile B-sand Window at 4364' MD, ''~ f 3513' TVD Liner Swivel Seal ores___.-.-- -.~; ID 4-112" 12.6 ubin~_~ - 3.833" Drill - ~~~ XKY6NE5 Baker Oil Tools Late With ral Entry Module ILEMI Diverters and Isolation Lateral Access Diverter Lateral Isdation Diverter GS Running 7001 String Insfalletl Installed (3.00" Lateral Drirt) (2.50" ID Mainbor e Orifp •GS Prorile r« -Coil Connector ~ RunninglRetrieving ~ (1.00' Length) I Snap InSnap Out 1 Positive Locating ti r Back Pressure Valve ~~ I (1.60' Length) i Lateral IsoWtion ~' ~~ Fbw-Thru Swivel Seals '~ ~~, j (1.25' Length) ~ Lateral Diverter ~ I / Hydraulic Ramp ~ Disconnect ~- Isolation/ Mainbore (1.50' Length) Diverter Sleeve i i ,. GS Spear ~- (1.50' Length) Lateral Isolation Seals 6.BShApprox. OAL' i 'Jars maybe re~quited.in highly tleviated tg.5' Diverter Length 18.5' Sleeve Length d f C s.,~' _.....,... ,___.A, 'B' Sand Lateral °` cep app Ica ion 4-112" 12.6# Lb0 Slotted Liner Every Other Joint / 3-112" Bent Joint ~.~,~`_ - 3-112" Guide Shoe ~~ 4-112" Casing Shoe, 12.6#, L-80 IBTM DB Nipple Set ~ 11276' MD, 3439' TVD PaekoH Bushing '~ „ ~ /`~, ~? 5-112" X 7518" ZXP Liner Top Packer with Hold Downs 5-112" X 7518" Liner Hanger 1 Packer Assembly at Flex Lock +1-4440' MD Liner Hanger / Casing Sealbore Receptacle 4.75" ID, 6.25" OD 20' Length o cower aagnes Zoos. mis aocument may not x reproaacea or alstdbutea, m wnme or m win. m any roan o. by any means eleeo-onm «mecnanlcal, Incluaina pnotocapNna, recoraing, or by any Inrormation seoraae and retrieval system now known or nerearrcr Invenfea, wlthoul written permission from Baker Hughes Inc. Seal Assembly 4.75" Seal OD " 3.875" ID 'A' Sand Undulating Lateral 2' Length 4-112" 12.6# L-60 Slotted Liner Every Other Joint 4-112"Eccentric ~ ~ / ,Guide Shce Equipment Specifications 4-1 /2" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drill, no diverter or LEM: 3.88" Lateral Drill, wl diverter, no LEM: 3.88" LateregMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: *I- 3.89" Diverter and Sleeve Length: +I-18.5' 4-1/2" Casing Shoe, 12.6#, L-80 IBTM Set ~ 12872' MD, 3586' TVD Pack-oH Bushing 7-5/8" Casing Shoe, Set at ~ 5350' MD, 3670' TVD, 60 deg °"9T'"`' zoos west sax Tara- rdaateral completion -m)eceor °"'~ FaDrua 2a, 2003 Drawn ey: ReNalon 1 rY Marc D. Kuck • i• ~' iL-2£ 1L-08 Yr~ f ~ -- _ ~J l ---~" ,.,-,o ,L-2D4 ~~ ~-~~__ _L__ 1 L-21 D PN ~ ---~ ` `~ _ ~r n¢s ``~~,1 _,:,' ~.. Area of Review • KRU 1J-154L1 Proposed Injector 35 ~ 2050360 Confidential wells are red ~. '" SFD 3/10/2005 " T11 N, R10E, UM ~~00 2 1 _ Slotted Liner \ "'0 T10N, R10E, UM >ao ~ooo ~oooo >>oo0 11 12 iJ-154L1 w sak Piv o'r o. A i N Feei D 1 ,G00 2,L~OG 3,4Q0 ~},D00 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~/2L~ l ~T ~S7 L. PTD# Z~~ -~ ~ Development Exploration Service Stratigraphic CHECK WHAT ADD-OHS CLUE" APPLIES (OPTIONS y'• MULTI The permit is for a new wellbore 'segment of LATERAL, eYisiing weU k:2~ ~ °~:" ~5 ~ Z 3ZS Permit No,' ' '=b3 API No. ~' `'~~~ . (lf 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 I-]OLE In accordance vvitb ' 20 AAC 25.005(1), all (PII) records, data and logs acquired, for the pilot bole must be clearly differentiated 'in both ' name (name on permit pins PIS and API ioumber (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 io perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ e=ception. (Comaanv Hamel assumes the liability of any • protest to the spacing .eiception that may occur. DRY DITCH ~ All dry ditch sample .sets submitted to the SAMPLE Commission must be in ao greater than 30' sample intervals from below the permafrost . ~ or from where samples are fiirsi caught and ] 0' sample intervals through target zones. _~ WELL PERMIT CN~CKLfST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-154L1 .Program SER- Well bore seg ^ PTD#:2050360 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 111 0 _ OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached- _ - - _ NA_ - _ - - _ West Sak D Sand multilateral well-segment; fee_waived per 20 AAC 25:005(e), _ - . _ - - - 2 Lease number appropriate_____________________-____----____---_ Yes, -___-Top_productivei_ntervalinADL025661;_TDinADL025662.___--___--_---_----_--__--_---- 3 Unique well-nameandnumbe[ - --- --------- -- ---------------- Yes. ------- ----- ------------- - - -----..-- 4 Well located in a_defned_pool _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes , _ _ _ _ KRU West-$ak OiI Pool, governed-by Conserv_ation_Order No. 406B_ _ _ _ _ - - - _ _ _ - - _ _ _ _ - - _ _ _ _ - - - _ 5 Well located proper distance from drilling unit_boundary_ _ . - - - .. - - Yes . Np restrictions alto wryli spacing except that no_pay shall be opened in a well closer - _ - , _ - - 6 Well locatedp[operdistance-from otherwells__________________________--- Yes_ _---_than500 feet to-an external-property line._____--____-_____-____.--____--_--_--__--_- 7 Sufficientacreageayailablein_drillingunit_____________ ________________ Yes- ___.---____--_____-- ----------------------------------------------------- 8 If_deviated, is-wellbore plat_inclu_ded _ - - _ _ _ - - - _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , - - - - - 9 Operator only affected party___--------------------------- -- Yes- --------------_ -- ----------------------------------------------------- 10 Ope[atorhas_appropriate_boDdinforce----- -- --- -- ---------- -- - Yes- ----- -- -- ------------ -- ------- -- - --- -- -- ----------------- - 11 Permitcan be issued without conservation order- - - - - - - - - - - - - - - - - - Yes - - - - Appr Date 12 Permit-can be issued without administrative-approval _ - - . - - . _ Yes - - _ _ ... - - _ - ----------------------------------------------------- SFD 3!1112005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by.lnjection Order # (put_1O# in_comments}-(FOr_ Yes _ - - _ . - .Area Injection Order No, 2B _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells within 114-mile area of review ident~ed (For service well only) _ _ _ _ _ _ _ _ __ _ _ __ _ Yes _ _ _ .:. _WSP-14~WSP-12, WSP-13, WSP-10, WSP-01, WSP-7, WSP,6, WSP,5, WSP-2, WSP-15, WSP-4- - - - - - - . _ 16 Pre-produced injector; duration of pre production less tha4 3 months_(For service well only) _ Yes - - Well will be cleaned up for 30 --60 days_priorto injection, - - _ . - . - - , - - - - 17 ACMP_FindingofConsistency-hasbeenissuedfor_thisproject___________________ NA__ --__ __--_____-_____--_____-_-__--_--,--____-___------_---_-___-__,---- Engineering 18 Conductorstring-provided_____________________ ______________„__.- NA__ ---__Conductorsetinmotherbore,_1J-154(205-035)---___ -__-_-_____--___--__-__-,_-_-_- t9 Surface casing-protects al! known USOWS - - - - - - - - - - - -- - _ . _ - NA_ _ - _ _ - All aquifers exempted, 40 CFR_147.102(b)(3). , - _ - 20 CMT_voladequate_tocirculate_onconductor&surf_csg___ ____________________ NA-- ,___-Surface casing setig1J-1.54._-.____-__---,__--_____--__-_---__--_-----__ 21 CMT_vol_adequate_totte-in long string to surf csg_ _ - - - NA Production_casing se_t in-iJ-154. _All-hydrocarbon zonesplanne_d to be covered.- - _ _ 22 CMT will coverall known_pro_ductiye hcrizon_s_ - - - - - _ No_ Slotted liner completion pl_anned._ 23 Casing desjnsadequateforC,T6&_permaftost___--.___________________ Yes_ ___-- --___--__ -_- 24 Adequate tankage_or reserve pit _ - - _ - - Yes _ - Rig is equipped with steel_pits. _ No reserve-pitplanned, All waste to unapproved annulus orClass II well - - . - 25 Ifa-re-drill,has-a.t0.403for abandonment been approved-----------------__.- NA__ -_______-____,--___.-_--__,.-_ - - 26 Adequate wellbore separationproposed- - - - - - - - - - - - - --- - - - - - - - - - - - - - - - - - Yes - _ - _ _ - - Proximit analysisperfo_rmed. -Nearest-"well" is A sand lateral 13 -150' tyd below. - _ , _ - _ - - - - , - _ - _ _ - - - _ 27 If_diverter required, does it meet regulations- - - , _ _ - , NA_ _ - BOP stack_will already_be in place, . - - - - _ - -- - Appr Date 28 Drilling fluid_program schematic 8 equip list adequate- - - - _ - - - Yes Maximum expected formation pressure 8,7_EMW.- PI_anned MW 9.0_ppg._ - - TEM 311512005 29 BOPEs,-do they meet regulation----------------------------------- - Yes- ____--.____---____-_-__----____--___--___._--_____- -,._-_-----__--_,-- rn~, /) . 30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ Yes _ - - _ _ _ MASP calculated-at 1201 psi.- 3000 psi pl_anned.- - - _ _ _ - - _ _ _ _ _ . _ _ _ , _ _ . _ _ _ - _ _ _ . _ - _ _ _ _ _ . _ ~ ':'J~Y~ +1/fj X31 Choke.manifofdcomplie&wtAPl_RP-53GMay$4)__--__ Yes_ ___________________--____--_____--____-- _ 32 Work willoccurw~houtoperationshutdown___--_____________________ Yes_ _-__-_ -- - - - - 33 Is presence_of H2$ gas-prpbable _ . - _ .. - - - .... - _ _ . - - - _ .. No- - - , H2S has notbeen reported in WS Pilotproduetipn. Riq is equipped with sensprs and alarms.- - , . 34 Mechanical_condition of wells within AOR verified ~For_service well only) _ _ Yes . - . - - Examined all wells on WS Pilot and W. Sak 05. -Initial cementing and P&AS acceptable. No exceptions_noted.- Geology 35 Permit-can be issued w/o hydrogen-sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ _ - - - .. - _ - _ _ .. - _ ... . 36 Data_presented 4n_ potential overpressure zones _ _ - - _ _ - _ _ NA- _ _ Expected reservoirpressure is 8,7-ppg EMW; will be drilled with 9.0 ppq mud. - Appr Date 37 Seismic.analysisofshallcwgas_zones____-____________________________ NA__ _.__--_-.._-___.-_- -- - - SFD 3!1112005 38 Seabedcgnditionsurvey-(ifoff-shore)-_-______________________________ NA-_ __ 39 ,Contact name/phonefor_weekly progressreports[exRloratoryonlyj-___-_--__--_--_ NA_ ___________________,-_ _______-_-____--____-,____-.__--____--___-,--- Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ~j S ~l ~s1s • • 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. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 02 12:56:24 2006 Reel Header Service name ....... ......LISTPE Date ............... ......06/03/02 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......06/03/02 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 MWD RUN 2 JOB NUMBER: MW-000395646 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN MWD RUN 6 JOB NUMBER: MW-000395646 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Te ni al Services 1J-154 L1 500292325460 ConocoPhillips Alaska, Inc. Sperry Drilling Services 02-MAR-06 MWD RUN 4 MWD RUN 5 MW-000395646 MW-000395646 T. GALVIN T. GALVIN M. THORNTON M. THORNTON 35 11N l0E 2133 2569 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2302.0 2ND STRING 6.750 7.875 4374.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE X65 -~3 ~ • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 4374'MD/3513'TVD WITHIN THE RUN 2 INTERVAL OF THE 1J-154 WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 6 ALSO INCLUDED GEO- PILOT ROTARY-STEERABLE BHA (GP) MWD RUN 2 ALSO INCLUDED RECORDED-ONLY COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ABED), AND ACOUSTIC CALIPER (ACAL) THESE POROSITY .DATA ARE PRESENTED FOR THE MAIN WELLBORE, AND ARE NOT INCLUDED HERE. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW MILLED DURING MWD RUN 4, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,4-6 REPRESENT WELL 1J-154 L1 WITH API#:50-029-23254-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11285'MD/3456'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. 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.......06/03/02 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 2256.5 11228.0 • FET 2280.0 11235.0 RPM 2280.0 11235.0 RPS 2280.0 11235.0 RPD 2280.0 11235.0 RPX 2280.0 11235.0 ROP 2302.5 11285.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 4 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2256.5 4374 .0 4374.5 4416 .0 4416.0 7691 .0 7691.0 11285 .5 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 11285.5 6771 18059 2256.5 11285.5 RPD MWD OHMM 2.92 2000 45.0871 17911 2280 11235 RPM MWD OHMM 4.01 1743.45 43.2145 17911 2280 11235 RPS MWD OHMM 3.85 2000 44.6768 17911 2280 11235 RPX MWD OHMM 3.7 2000 46.5744 17911 2280 11235 FET MWD HOUR 0.18 219.9 1.95868 17911 2280 11235 GR MWD API 22.41 120.76 64.0144 17944 2256.5 11228 ROP MWD FT/H 0.42 1523.82 185.553 17967 2302.5 11285.5 First Reading For Entire File..........2256.5 Last Reading For Entire File...........11285.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 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.......06/03/02 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 2256.5 4374.0 RPD 2280.0 4374.0 RPX 2280.0 4374.0 RPM 2280.0 4374.0 FET 2280.0 4374.0 RPS 2280.0 4374.0 ROP 2302.5 4374.0 LOG HEADER DATA DATE LOGGED: OS-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4374.0 TOP LOG INTERVAL (FT) 2302.0 BOTTOM LOG INTERVAL (FT) 4374.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 12.2 MAXIMUM ANGLE: 81.4 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) 2302.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.05 MUD VISCOSITY (S) 61.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.390 95.0 MUD FILTRATE AT MT: 4.500 67.0 MUD CAKE AT MT: 3.000 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • S 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 5pacing ................. ....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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 4374 3315.25 4236 2256.5 4374 RPD MWD020 OHMM 2.92 2000 18.9733 4189 2280 4374 RPM MWD020 OHMM 4.01 1743.45 14.857 4189 2280 4374 RPS MWD020 OHMM 3.85 2000 14.1661 4189 2280 4374 RPX MWD020 OHMM 3.7 1043.9 12.0381 4189 2280 4374 FET MWD020 HOUR 0.2 56.81 1.31458 4189 2280 4374 GR MWD020 API 22.41 115.29 67.2509 4236 2256.5 4374 ROP MWD020 FT/H 3.28 580.58 165.203 4144 2302.5 4374 First Reading For Entire File..........2256.5 Last Reading For Entire File...........4374 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 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 4374.5 4416.0 • LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER {FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 13-OCT-OS Insite 66.37 Memory 4416.0 4374.0 4416.0 .0 .0 TOOL NUMBER 135134 6.750 2302.0 Mineral Oil Base 9.00 75.0 .0 40500 3.0 .000 .0 .000 79.0 .000 .0 .000 .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 Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FTfH 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4374.5 4416 4395.25 84 4374.5 ROP MWD040 FT/H 0.42 91.16 29.5794 84 4374.5 Last Reading 4416 4416 First Reading For Entire File..........4374.5 Last Reading For Entire File...........4416 • • File Trailer Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name......... .STSLIB.003 .1.0.0 .06/03/02 .65535 .LO .STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 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 INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4358.0 7632.5 RPX 4358.0 7632.5 RPM 4358.0 7632.5 RPD 4358.0 7632.5 RPS 4358.0 7632.5 GR 4374.5 7625.0 ROP 4416.5 7691.0 LOG HEADER DATA DATE LOGGED: 16-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7691.0 TOP LOG INTERVAL (FT) 4416.0 BOTTOM LOG INTERVAL (FT) 7691.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.0 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2302.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 33500 FLUID LOSS (C3) 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 91.3 MUD FILTRATE AT MT: .000 .0 • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................ :.0 Data Specification Block Type... ..0 Logging Direction ............... ..Down Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .lIN Max frames per record ........... ..Undefined Absent value .................... ..-999 Depth Units ..................... .. Datum Specification Block sub-type...0 000 Name Service Order Units Size Nsam Rep Code Offset Channel • 0 DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4358 7691 6024.5 6667 4358 7691 RPD MWDO50 OHMM 6.49 2000 54.7663 6550 4358 7632.5 RPM MWDO50 OHMM 4.71 2000 51.9732 6550 4358 7632.5 RPS MWDO50 OHMM 4.99 2000 53.2603 6550 4358 7632.5 RPX MWDO50 OHMM 3.83 2000 57.4093 6550 4358 7632.5 FET MWDO50 HOUR 0.34 219.9 4.79546 6550 4358 7632.5 GR MWDO50 API 32.33 115.9 63.009 6502 4374.5 7625 ROP MWDO50 FT/H 3.08 697.45 167.642 6550 4416.5 7691 First Reading For Entire File..........4358 Last Reading For Entire File...........7691 File Trailer Service name ..... ........STSLIB.004 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 06/03/02 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.004 Comment Record • • FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7625.5 11228.0 RPX 7633.0 11235.0 RPD 7633.0 11235.0 FET 7633.0 11235.0 RPM 7633.0 11235.0 RPS 7633.0 11235.0 ROP 7691.5 11285.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... 19-OCT-OS Insite 66.37 Memory 11285.0 7691.0 11285.0 86.3 93.2 TOOL NUMBER 135134 73634 6.750 5165.0 Mineral Oil Base 8.95 67.0 .0 24000 3.8 .000 .0 .000 123.8 .000 .0 .000 .0 • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 S First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7625.5 11285.5 9455.5 7321 7625.5 11285.5 RPD MWD060 OHMM 8.2 139.67 56.3932 7205 7633 11235 RPM MWD060 OHMM 7.48 233.86 55.1811 7205 7633 11235 RPS MWD060 OHMM 7.21 2000 58.9653 7205 7633 11235 RPX MWD060 OHMM 7.14 2000 62.267 7205 7633 11235 FET MWD060 HOUR 0.18 20.33 0.745647 7205 7633 11235 GR MWD060 API 31.06 120.76 63.0188 7206 7625.5 11228 ROP MWD060 FT/H 2,49 1523.82 215.426 7189 7691.5 11285.5 First Reading For Entire File..........7625.5 Last Reading For Entire File...........11285.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 06/03/02 Maximum Physical Record.. 65535 File Type ................ LO Next File Name........... STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/03/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File