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Home My WebLink About206-0631. 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 12602'feet None feet true vertical 3552' feet 6397', 6820'feet Effective Depth measured 12602'feet 6353', 6491'feet true vertical 3552' feet 3391', 3417'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 6383' MD 3396' TVD Packers and SSSV (type, measured and true vertical depth) 6353' MD 6491' MD N/A 3391' TVD 3417' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 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. N/A Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Alternating Slotted Liner: 3484-3545' Alternating Slotted Liner: 6863-12475' 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 206-063 50-029-23310-60-00 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: ADL0025660, ADL0025661 Kuparuk River Field/ West Sak Oil Pool KRU 1J-170L1 Plugs Junk measured Length Production B Sand Liner 7867' 5726' Casing 3650' 4-1/2' 7894' 12550' 3549' 3011' 108'Conductor Surface Intermediate 20" 10-3/4" 80' 3041' 2146' 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 1:33 pm, Aug 07, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.08.07 07:14:43-08'00' Foxit PDF Editor Version: 12.1.2 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 7/11/2023 ACQUIRE DATA RPPG TREATMENT COMPLETED PUMPED 7216 LB RPPG, 430 BBL 2%KCL, 40.9 BBL DIESEL MAX SURFACE PSI 1488, MAX RATE 3.5 BPM. SLB E-LINE: OBJECTIVE TO MONITOR TEMPERATURE & PRESSURE IN WELL 20' TO 50' ABOVE B-SAND LEM AT 6812' WHILE RPPG IS PUMPED INTO LATERAL. IF UNABLE TO REACH TARGET DEPTH, PARK AS FAR DOWN. TARGET DEPTH REACHED OF 50 FT ABOVE LATERAL B. 1J-170/ 1J-166 RPPG MBE Treatment Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-170 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DB Plug, Set Diverter across B-LEM, Set Iso Sleeve across D-LEM, & Closed CMD 1J-170 5/18/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1J-170 (A-SAND), 1J-170L1 (B-SAND), 1J-170L2 (D-SAND)7/1/2006 triplwj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 20 19.12 28.0 108.0 108.0 94.00 H-40 WELDED SURFACE 10 3/4 9.95 30.2 3,041.1 2,146.4 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 27.1 7,894.0 3,649.6 29.70 L-80 Buttress Thread D LINER LEM 4 1/2 3.95 6,353.0 6,521.3 3,422.5 IBT D LINER HH 4 1/2 3.48 6,423.9 6,625.3 3,442.0 11.60 L-80 BTC B LINER LEM 4 1/2 3.48 6,491.4 6,973.6 3,506.3 11.60 L-80 IBT A LINER 4 1/2 3.48 6,931.0 12,470.0 3,701.2 11.60 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.5 Set Depth 6,382.7 Set Depth 3,396.2 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection 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) 22.5 22.5 0.00 HANGER 10.000 Vetco Gray Tubing Hanger 4.909 508.9 508.2 6.84 NIPPLE 5.210 Camco DB Nipple 3.875 3,604.3 2,393.7 64.05 GAS LIFT 5.984 Camco GLM, KBG-2-1R Camco KBG-2- 1R 3.938 5,175.3 3,052.7 65.08 GAS LIFT 5.984 Camco GLM, KBG-2-1R Camco KBG-2- 1R 3.938 6,308.9 3,382.6 79.12 SLEEVE-C 5.480 Baker CMD Sliding Sleeve (CLOSED 5/16/2023) 3.810 6,358.3 3,391.8 79.39 LOCATOR 5.500 Baker Locator 3.875 6,360.0 3,392.1 79.40 SEAL ASSY 4.750 Seal Assembly 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,397.0 3,398.9 79.32 ISO-SLEEVE SET TYPE 2 BAKER ISOLATION SLEEVE (19' OAL) ACROSS D-LEM 5/15/2023 3.620 6,397.0 3,398.9 79.32 FISH Collapsable Centrailizer LOST 4 ARMS, 4 ROLLERS, 4 AXLES (ARMS ARE 3 1/2" LONG, 3/8" THICK, & 3/4" WIDE) WHILE TRYINGTO GO THRU ISO SLEEVE @ 6097'. EXACT LOCATION IS UNKOWN (SEE PICTURE IN ATTACHMENTS) 5/18/2023 0.000 6,812.0 3,475.1 79.95 DIVERTER SET TYPE-1 DIVERTER (18.60' OAL) ACROSS B-LEM 5/16/2023 3.000 6,820.0 3,476.5 79.96 FISH Centralizer 3 BOTTOM HALF OF CENTRALIZER ARMS, 3 ROLLERS, 3 ROLER AXELS - LOST 3/17/2007 BELOW DIVERTER - EXACT LOCATION UNKNOWN 3/17/2007 6,896.0 3,490.4 78.59 TUBING PLUG 3.562" DB PLUG (2' OAL)5/15/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,604.3 2,393.7 64.05 1 Gas Lift DMY BK-5 1 0.0 9/22/2006 0.000 5,175.3 3,052.7 65.08 2 Gas Lift DMY BK-5 1 0.0 9/23/2006 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) 6,353.0 3,390.8 79.37 PACKER 6.550 ZXP LINER TOP PACKER 4.950 6,372.0 3,394.3 79.47 SBR 6.280 190-47 CASING SEAL BORE RECEPTACLE 4.750 6,391.6 3,397.9 79.35 XO BUSHING 5.990 CROSSOVER BUSHING 3.950 6,475.1 3,413.7 78.91 BENT JT 4.500 3.950 6,522.8 3,422.8 79.05 ECP 5.630 BAKER PAYZONE EXTERNAL CASING PACKER 3.930 6,553.0 3,428.5 79.13 BENT JT 4.500 3.950 6,491.4 3,416.8 78.96 PACKER 6.540 ZXP LINER TOP PACKER 5.750 6,510.4 3,420.4 79.01 SBR 6.280 CASING SEAL BORE 4.750 6,530.1 3,424.2 79.07 XO BUSHING 5.990 CROSSOVER BUSHING 3.950 6,896.2 3,490.5 78.59 NIPPLE 5.100 CAMCO DB-6 NIPPLE 3.562 6,927.6 3,496.9 77.82 BENT JT 4.750 3.950 6,931.0 3,497.6 77.73 PACKER 7.600 "ZXP" LINER TOP Packer 5.500 6,950.2 3,501.6 78.19 NIPPLE 6.060 "RS" Packoff Nipple 4.870 6,982.5 3,508.0 79.06 XO BUSHING 5.960 CROSSOVER BUSHING 3.930 1J-170, 7/26/2023 12:10:52 PM Vertical schematic (actual) A LINER; 6,931.0-12,470.0 SLOTS; 12,175.0-12,435.0 SLOTS; 11,657.0-12,003.0 SLOTS; 10,890.0-11,354.0 SLOTS; 10,030.0-10,590.0 SLOTS; 9,258.0-9,732.0 SLOTS; 8,281.0-9,000.0 SLOTS; 7,896.0-7,980.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 TUBING PLUG; 6,896.0 B LINER; 6,823.5-12,550.0 DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 ISO-SLEEVE; 6,397.0 FISH; 6,397.0 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 31.31 RR Date 6/29/2006 Other Elev 1J-170 ... TD Act Btm (ftKB) 12,479.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331000 Wellbore Status INJ Max Angle & MD Incl (°) 92.23 MD (ftKB) 8,139.31 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,896.0 7,980.0 3,649.7 3,653.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS THIS WELLBORE = 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 8,281.0 9,000.0 3,653.5 3,651.3 WS A2, 1J-170 6/9/2006 32.0 SLOTS 9,258.0 9,732.0 3,653.3 3,650.4 WS A2, 1J-170 6/9/2006 32.0 SLOTS 10,030.0 10,590.0 3,649.0 3,645.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS 10,890.0 11,354.0 3,651.2 3,657.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS 11,657.0 12,003.0 3,664.9 3,671.9 WS A2, 1J-170 6/9/2006 32.0 SLOTS 12,175.0 12,435.0 3,679.6 3,699.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS 1J-170, 7/26/2023 12:10:55 PM Vertical schematic (actual) A LINER; 6,931.0-12,470.0 SLOTS; 12,175.0-12,435.0 SLOTS; 11,657.0-12,003.0 SLOTS; 10,890.0-11,354.0 SLOTS; 10,030.0-10,590.0 SLOTS; 9,258.0-9,732.0 SLOTS; 8,281.0-9,000.0 SLOTS; 7,896.0-7,980.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 TUBING PLUG; 6,896.0 B LINER; 6,823.5-12,550.0 DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 ISO-SLEEVE; 6,397.0 FISH; 6,397.0 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 KUP INJ 1J-170 ... WELLNAME WELLBORE Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-170L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: PERF 1J-170L1 5/10/2021 appleha 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 3.48 6,823.5 12,550.0 3,549.2 11.60 L-80 Buttress Thread 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) 6,858.1 3,482.9 81.05 SWIVEL 5.770 Casing Swivel 3.960 12,518.4 3,547.4 86.79 XO Reducing 4.500 CROSSOVER 4.5x3.5"3.500 12,519.8 3,547.5 86.78 BENT JT 3.500 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,863.0 7,080.0 3,483.7 3,504.3 WS B, 1J-170L1 6/18/2006 32.0 SLOTS ALL SLOTS THIS WELLBORE = 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 7,293.0 7,807.0 3,504.3 3,504.5 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 8,057.0 8,062.0 3,504.9 3,504.9 WS B, 1J-170L1 5/10/2021 6.0 APERF HES 2.5" BIG HOLE GEO, 60 DEG PH , 6 SPF, 11 GM. 8,067.0 8,577.0 3,505.0 3,509.7 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 8,836.0 9,302.0 3,508.3 3,512.3 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 9,554.0 10,071.0 3,511.1 3,499.9 WS A1, 1J- 170L1 6/18/2006 32.0 SLOTS 9,681.0 10,071.0 3,509.2 3,499.9 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 10,325.0 10,715.0 3,500.5 3,495.4 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 10,972.0 11,486.0 3,501.3 3,514.1 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 11,745.0 12,475.0 3,516.8 3,545.1 WS A1, 1J- 170L1 6/18/2006 32.0 SLOTS 1J-170L1, 7/26/2023 12:10:58 PM Vertical schematic (actual) B LINER; 6,823.5-12,550.0 SLOTS; 11,745.0-12,475.0 SLOTS; 10,972.0-11,486.0 SLOTS; 10,325.0-10,715.0 SLOTS; 9,681.0-10,071.0 SLOTS; 9,554.0-10,071.0 SLOTS; 8,836.0-9,302.0 SLOTS; 8,067.0-8,577.0 APERF; 8,057.0-8,062.0 SLOTS; 7,293.0-7,807.0 SLOTS; 6,863.0-7,080.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 ISO-SLEEVE; 6,397.0 FISH; 6,397.0 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 31.31 RR Date 6/29/2006 Other Elev 1J-170L1 ... TD Act Btm (ftKB) 12,602.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331060 Wellbore Status INJ Max Angle & MD Incl (°) 93.14 MD (ftKB) 9,502.25 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-170L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: PERF 1J-170L2 7/19/2018 pproven 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 3.48 6,573.5 12,671.5 3,498.8 11.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,573.5 3,423.3 84.44 SLEEVE 5.500 BAKER 'HR' SETTING SLEEVE 2.000 6,631.3 3,428.2 85.80 XO Reducing 5.500 CROSSOVER 5.5x4.5"3.930 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,637.0 7,110.0 3,428.6 3,432.1 WS D, 1J-170L2 6/25/2006 32.0 SLOTS ALL SLOTS THIS WELLBORE = 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 7,362.0 7,835.0 3,426.4 3,426.9 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 8,093.0 8,728.0 3,429.9 3,425.5 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 8,983.0 9,449.0 3,431.2 3,430.7 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 9,350.0 9,355.0 3,432.0 3,431.9 WS D, 1J-170L2 7/2/2018 6.0 APERF SLB 2.5" HSD, POWERFLOW 2506, HMX, 11.2 GM, 6 SPF, 60 DEG PH 9,702.0 10,213.0 3,426.5 3,430.4 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 10,461.0 11,095.0 3,430.7 3,438.8 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 11,354.0 11,868.0 3,444.4 3,460.9 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 12,117.0 12,550.0 3,478.9 3,493.7 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 12,592.0 12,635.0 3,495.9 3,497.5 WS D, 1J-170L2 6/25/2006 32.0 SLOTS 1J-170L2, 7/26/2023 12:11:01 PM Vertical schematic (actual) D LINER; 6,573.5-12,671.5 SLOTS; 12,592.0-12,635.0 SLOTS; 12,117.0-12,550.0 SLOTS; 11,354.0-11,868.0 SLOTS; 10,461.0-11,095.0 SLOTS; 9,702.0-10,213.0 APERF; 9,350.0-9,355.0 SLOTS; 8,983.0-9,449.0 SLOTS; 8,093.0-8,728.0 SLOTS; 7,362.0-7,835.0 SLOTS; 6,637.0-7,110.0 INTERMEDIATE; 27.1-7,894.0 D LINER LEM; 6,353.0-6,521.3 ISO-SLEEVE; 6,397.0 FISH; 6,397.0 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 31.31 RR Date 6/29/2006 Other Elev 1J-170L2 ... TD Act Btm (ftKB) 12,678.1 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331061 Wellbore Status INJ Max Angle & MD Incl (°) 92.98 MD (ftKB) 7,063.76 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-21138_KRU_1J-170L1_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21138 KRU 1J-170L1 50-029-23310-60 Injection Profile 18-May-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 206-063 T37668 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.24 13:51:20 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Date:Monday, October 17, 2022 10:00:56 AM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, October 16, 2022 1:55 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/16/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/14/2022 after a significant injection pressure reduction (due to well communication with an offset producer) could not satisfy the LPP. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, October 14, 2022 12:03 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when 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. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Date:Friday, October 14, 2022 1:31:11 PM Attachments:image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, October 14, 2022 12:03 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when 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. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com ! " # " $%&' ( ') * +,! - *( ./ !0 1"!! 2/ ./ 34354-04 6. 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *!!6 ') ! 8 ", ' ' ? .24-03+5#+4<1 8! " 8 ",!="$ ! " !" #$ % # &' % & ! 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'((&$ $ $$$$"#$# ('()!!(!($('(# )%)!( ) $ '(% # ' '(""" " ''' )! ! +,-./ 0012%-3. 41+56#$0012%!51+33789:6 ;$105!<=.3<>.?@A?.A:3<:9@A@4$#-->001%2 41+56#001/9.5.143..B.-3@:.?:'.11:@5:<756+:9A4@3#6@+35 :3.<:,.A:?@,-1.:. $!3.<:,.A: +,,<37@4-.3<:9@A5 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-170 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: PULL TYPE I ISO SLEEVE,SET DB-6 PLUG, SET TYPE I DIVERTER,SET TYPE II ISO, ADD PERF 5/10/2021 1J-170 appleha Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.2 Set Depth (ftKB) 3,041.1 Set Depth (TVD) … 2,146.4 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.1 Set Depth (ftKB) 7,894.0 Set Depth (TVD) … 3,649.6 Wt/Len (l… 29.70 Grade L-80 Top Thread Buttress Thread Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.95 Top (ftKB) 6,353.0 Set Depth (ftKB) 6,521.3 Set Depth (TVD) … 3,422.5 Wt/Len (l…Grade Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,353.0 3,390.8 79.37 PACKER ZXP LINER TOP PACKER 4.950 6,372.0 3,394.3 79.47 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 6,391.6 3,397.9 79.35 XO BUSHING CROSSOVER BUSHING 3.950 6,396.9 3,398.8 79.32 HANGER LEM ABOVE HOOK HANGER 3.980 6,407.4 3,400.8 79.25 HANGER LEM INSIDE HOOK HANGER 3.980 6,475.1 3,413.7 78.91 BENT JT 3.950 6,518.0 3,421.9 79.04 SEAL ASSY BAKER SEAL ASSEMBLY 4.000 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,423.9 Set Depth (ftKB) 6,625.3 Set Depth (TVD) … 3,442.0 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,423.9 3,403.9 79.15 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM (OUTSIDE CSG) 5.600 6,522.8 3,422.8 79.05 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.930 6,553.0 3,428.5 79.13 BENT JT 3.950 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,491.4 Set Depth (ftKB) 6,973.6 Set Depth (TVD) … 3,506.3 Wt/Len (l… 11.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,491.4 3,416.8 78.96 PACKER ZXP LINER TOP PACKER 5.750 6,510.4 3,420.4 79.01 SBR CASING SEAL BORE 4.750 6,530.1 3,424.2 79.07 XO BUSHING CROSSOVER BUSHING 3.950 6,812.9 3,475.3 79.96 HANGER LEM ABOVE HOOK HANGER 3.950 6,823.6 3,477.2 79.96 HANGER LEM INSIDE HOOK HANGER 3.688 6,896.2 3,490.5 78.59 NIPPLE CAMCO DB-6 NIPPLE 3.562 6,927.6 3,496.9 77.82 BENT JT 3.950 6,970.3 3,505.7 78.73 SEAL ASSY BAKER SEAL ASSEMBLY 3.950 Casing Description A LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,931.0 Set Depth (ftKB) 12,470.0 Set Depth (TVD) … 3,701.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,931.0 3,497.6 77.73 PACKER "ZXP" LINER TOP Packer 5.500 6,950.2 3,501.6 78.19 NIPPLE "RS" Packoff Nipple 4.870 6,953.0 3,502.2 78.26 HANGER Liner Hanger 5.510 6,962.8 3,504.2 78.53 SBE BAKER SEAL BORE EXTENSION 4.750 6,982.5 3,508.0 79.06 XO BUSHING CROSSOVER BUSHING 3.930 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.5 Set Depth (ft… 6,382.7 Set Depth (TVD) (… 3,396.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.5 22.5 0.00 HANGER Vetco Gray Tubing Hanger 4.909 508.9 508.2 6.84 NIPPLE Camco DB Nipple 3.875 6,308.9 3,382.6 79.12 SLEEVE-C Baker CMD Sliding Sleeve (CLOSED 5/27/2009) 3.810 6,358.3 3,391.8 79.39 LOCATOR Baker Locator 3.875 6,360.0 3,392.1 79.40 SEAL ASSY Seal Assembly 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,308.0 3,382.4 79.11 SLEEVE - CLOSED CMD OPEN/CLOSED 5-9-21 5/9/2021 3.810 6,396.0 3,398.7 79.32 TYPE II ISO SLEEVE TYPE II NEW STYLE ISO SLEEVE 2.75" ID 3.66" OD 18.32' LONG ACROSS D LEM 6396' 5/9/2021 2.750 6,812.0 3,475.1 79.95 TYPE I DIVERTER TYPE I DIVERTER 3.1" ID, 3.66" OD, 18.6' LONG 6812' B LEM 5/9/2021 3.100 6,820.0 3,476.5 79.96 FISH Centralizer 3 BOTTOM HALF OF CENTRALIZER ARMS, 3 ROLLERS, 3 ROLER AXELS - LOST 3/17/2007 BELOW DIVERTER - EXACT LOCATION UNKNOWN 3/17/2007 6,896.0 3,490.4 78.59 3.562 DB-6 PLUG 3.562" DB-6 PLUG 2' LONG 5/9/2021 0.000 1J-170, 5/11/2021 5:58:10 AM Vertical schematic (actual) A LINER; 6,931.0-12,470.0 SLOTS; 12,175.0-12,435.0 SLOTS; 11,657.0-12,003.0 SLOTS; 10,890.0-11,354.0 SLOTS; 10,030.0-10,590.0 SLOTS; 9,258.0-9,732.0 SLOTS; 8,281.0-9,000.0 SLOTS; 7,896.0-7,980.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 3.562 DB-6 PLUG; 6,896.0 B LINER; 6,823.5-12,550.0 TYPE I DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 TYPE II ISO SLEEVE; 6,396.0 SEAL ASSY; 6,360.0 LOCATOR; 6,358.3 SLEEVE-C; 6,308.9 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 HANGER; 22.5 KUP INJ KB-Grd (ft) 31.31 Rig Release Date 6/29/2006 1J-170 ... TD Act Btm (ftKB) 12,479.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331000 Wellbore Status INJ Max Angle & MD Incl (°) 92.23 MD (ftKB) 8,139.31 WELLNAME WELLBORE1J-170 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,896.0 7,980.0 3,649.7 3,653.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS THIS WELLBORE = 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 8,281.0 9,000.0 3,653.5 3,651.3 WS A2, 1J-170 6/9/2006 32.0 SLOTS 9,258.0 9,732.0 3,653.3 3,650.4 WS A2, 1J-170 6/9/2006 32.0 SLOTS 10,030.0 10,590.0 3,649.0 3,645.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS 10,890.0 11,354.0 3,651.2 3,657.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS 11,657.0 12,003.0 3,664.9 3,671.9 WS A2, 1J-170 6/9/2006 32.0 SLOTS 12,175.0 12,435.0 3,679.6 3,699.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,604.3 2,393.7 64.05 Camco KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/22/2006 2 5,175.3 3,052.7 65.08 Camco KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/23/2006 Notes: General & Safety End Date Annotation 8/14/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 7/1/2006 NOTE: MULTI-LATERAL WELL: 1J-170 (A-SAND), 1J-170L1 (B-SAND), 1J-170L2 (D-SAND) 1J-170, 5/11/2021 5:58:11 AM Vertical schematic (actual) A LINER; 6,931.0-12,470.0 SLOTS; 12,175.0-12,435.0 SLOTS; 11,657.0-12,003.0 SLOTS; 10,890.0-11,354.0 SLOTS; 10,030.0-10,590.0 SLOTS; 9,258.0-9,732.0 SLOTS; 8,281.0-9,000.0 SLOTS; 7,896.0-7,980.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 3.562 DB-6 PLUG; 6,896.0 B LINER; 6,823.5-12,550.0 TYPE I DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 TYPE II ISO SLEEVE; 6,396.0 SEAL ASSY; 6,360.0 LOCATOR; 6,358.3 SLEEVE-C; 6,308.9 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 HANGER; 22.5 KUP INJ 1J-170 ... WELLNAME WELLBORE1J-170 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-170L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: PERF 5/10/2021 1J-170L1 appleha Casing Strings Casing Description B LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,823.5 Set Depth (ftKB) 12,550.0 Set Depth (TVD) … 3,549.2 Wt/Len (l… 11.60 Grade L-80 Top Thread Buttress Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,823.5 3,477.2 79.96 HANGER Hook Hanger 3.960 6,858.1 3,482.9 81.05 SWIVEL Casing Swivel 3.960 12,518.4 3,547.4 86.79 XO Reducing CROSSOVER 4.5x3.5" 3.500 12,519.8 3,547.5 86.78 BENT JT 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,863.0 7,080.0 3,483.7 3,504.3 WS B, 1J-170L1 6/18/2006 32.0 SLOTS ALL SLOTS THIS WELLBORE = 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 7,293.0 7,807.0 3,504.3 3,504.5 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 8,057.0 8,062.0 3,504.9 3,504.9 WS B, 1J-170L1 5/10/2021 6.0 APERF HES 2.5" BIG HOLE GEO, 60 DEG PH , 6 SPF, 11 GM. 8,067.0 8,577.0 3,505.0 3,509.7 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 8,836.0 9,302.0 3,508.3 3,512.3 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 9,554.0 10,071.0 3,511.1 3,499.9 WS A1, 1J- 170L1 6/18/2006 32.0 SLOTS 9,681.0 10,071.0 3,509.2 3,499.9 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 10,325.0 10,715.0 3,500.5 3,495.4 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 10,972.0 11,486.0 3,501.3 3,514.1 WS B, 1J-170L1 6/18/2006 32.0 SLOTS 11,745.0 12,475.0 3,516.8 3,545.1 WS A1, 1J- 170L1 6/18/2006 32.0 SLOTS Notes: General & Safety End Date Annotation 8/14/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 7/1/2006 NOTE: MULTI-LATERAL WELL: 1J-170 (A-SAND, 1J-170L1 (B-SAND), 1J-170L2 (D-SAND) 1J-170L1, 5/25/2021 3:05:43 PM Vertical schematic (actual) B LINER; 6,823.5-12,550.0 SLOTS; 11,745.0-12,475.0 SLOTS; 10,972.0-11,486.0 SLOTS; 10,325.0-10,715.0 SLOTS; 9,681.0-10,071.0 SLOTS; 9,554.0-10,071.0 SLOTS; 8,836.0-9,302.0 SLOTS; 8,067.0-8,577.0 APERF; 8,057.0-8,062.0 SLOTS; 7,293.0-7,807.0 SLOTS; 6,863.0-7,080.0 INTERMEDIATE; 27.1-7,894.0 B LINER LEM; 6,491.4-6,973.6 TYPE I DIVERTER; 6,812.0 FISH; 6,820.0 D LINER HH; 6,423.9-6,625.3 D LINER LEM; 6,353.0-6,521.3 TYPE II ISO SLEEVE; 6,396.0 GAS LIFT; 5,175.3 GAS LIFT; 3,604.3 SURFACE; 30.2-3,041.1 NIPPLE; 508.9 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 31.31 Rig Release Date 6/29/2006 1J-170L1 ... TD Act Btm (ftKB) 12,602.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331060 Wellbore Status INJ Max Angle & MD Incl (°) 93.14 MD (ftKB) 9,502.25 WELLNAME WELLBORE1J-170 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q2~ ~ - ~ ~~ Well History File Identifier Organizing (done) ~wo-sided III IIIIII II III II III ^ Rescan Needed III IIIII IIII III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ^ Color Items: Diskettes, No. ~ ^ 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/ Protect Proofing III IIIIIIIIIII II III YY, BY: Maria Date: ~ Dg /s/ Scanning Preparation ~_ x 30 = ~_ + ~~ =TOTAL PAGES~~ BY: Maria Date: ~/ p ~ O /D $ (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~]/`~ ~/O 8 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II IIIII iRescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked ~3 10/6/2005 Well History File Cover Page.doc .~..~ ~~ y~ .~; 4 f • . u ;. MICROFILMED .6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 20" 91.5# x 34" Insulated Conductor, K-55, set at +/- 80' 11" x 5" Vetco Gray MB 228 Wellhead Tubing, Special Drift to +/- 500' MD 508' MD - 3.875" DB Nipple, for Possible SSSV 3604' MD -GLM, Camco KBG-2, 4-1 /2" X 1" 5175' MD -GLM, Camco KBG-2, 4.1/2" X 1" 10-3/4", 45.5#, BTC ~ 6308' MD - CMD Sliding Sleeve, w/ 3.81" DB Nipple Shoe set ~ 3018' MD, ;. o 2145' rvD, 66 deg /~ 6371' MD-Casing Sealbore Receptacle, 20' Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift ~ _~ Length 6396' MD -Lateral Entry Module(LEM) ~ ~~ " ~ D-sand window 'D' San d Lateral Seal / /at 6409' MD, 3413' rvD 6353' MD - 5-112" X 7518" Assembly 4-112" 11.6# L-80 Slotted ZXP Liner Top Packer wl 4.75" Seal OD Liner Every Other Joint " ' Hold Downs Bottom ~ 6522 MD -Baker 5-% ECP / 4-112" Eccentric 6382' MD / 1 Guide Shoe / ~ _ 4-112" Liner Shoe, 11.6#, L-80 BTC / Set ~ 12671' MD, 3499' TVD / , ' 6573' MD - 5-112" Tieback Sleeve 4-112" X 75/8" Seal Bores Model'B' HOOK Hanger 3.68" ID 6407' MD fi491' MD - 5-112" X 7518" ZXP Liner Top Packer wl Hold Downs Lateral Entr~Module (LEM- Assembly - 5-112" X 7516" ZXP Liner Top Packer with Hold Downs --_ Casing Sealbore Receptacle 4.75" ID 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 6510' MD Sealbore F 20' Le ConocoPhillips West Sak 7-5/8" Injector 1 J-170 Tri-Lateral Completion MMI~[5leral Entry Module(LEM) B-sand Window at 6584• MD,rvD 'B' Sant ~'~1( 4-112" 11.6# L-80 Slotted • ~`~'L~- Liner Every Other Joint Seal Bores ~ 6858' MD -Liner .68" ID Swivel 6896' MD - 3.5 4-112" 12.6# Tubin -~ ~~ ---- - DB Nipple 3.833" Drift 3.958" ID 5-112" X 7518" ZXP j Liner Top Packer with Hold Downs ,, / 1 5-112" X 7518" /'~ Flex Lock Liner Hangerl Packer Assembly at Liner Hanger j ' 6931 MD 6962' MD -Casing Sealbore Receptacle, 20' Length BAXIUC~~ Biker Oil Tools As Completed Lateral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (7.00" Lateral DriTt) (2.50" ID Mainbor e Drdtl 'GS' Profile for Coil Connector fRunning/Retnevmg \ (1.00'Length) Snap In/Snap Out .= Back Pressure Valve .~~POSitive Locating-ti (1.60' Length) Collet Lateral Isolation t- Flow-Thru Swivel Seals (1.25' Length) / Lateral Diverter i Hydraulic Ramp r Disconnect Isolation/ Mainbore (1.50' Length) Diverter Sleeve GS Spear (1.50' Length) Lateral Isolation-' 6.85 ft Approx. Seals OAL' 'Jars may be required in highly deviated 18.5' Diverter Length 18.5' Sleeve Length ~~ ' approx leng or deep applications (6 th). + 3-112" Bent 3-11f' Guide Shoe /2"~ner Shoe, 11.6#, L-80 BTC Set 12550' MD, 3552' TVD Seal Assembly 4.75" Seal OD Bottom ~ 6973' MD ~ (` 'A' Sand Undul 4-112" 11.6# L~0 Slotted \ Liner Every Other Joint J `, •_ V~~ sting Lateral 4-112" Eccentric ,Guide Shoe Eauioment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: d.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-112" 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, 11.6#, L-80 BTC Set ~ 12470' MD, 3702' rvD 7-518" Casing, L-80, BTC M, Set at © Baker Hughes 2005. ThH document may not Ee reproducetl or tllsMbutetl, In whole or In part, In any roan or by ~ 7894' MD, 3649' rvD (85 deg) any means electronle or mechanical, Inclutling pholocopying, recortling, or by any Informatlon storage and reMeval system now known or hereaRer Invented, wlMOUt written pennisslon hom Baker Nughes Inc. JuIY 19, 2007 Seal Assembly 4.75" Seal OD Bottom ~ 6521' MD • • • • ~ • • ConocoPhiitips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ECEIVED FEB ~ 7 2009 February 13, 2009 ~ : Ai~ska pi1 g~ G83 ~ona, ~p Anal~or,qp~ mmission Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 i~ y~jj(~~ Anchorage, AK 99501 ~~~~~~~ ~~ ~ Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, inc. Trilateral West Sak injection well 1J-170 (206-062), 1J-170L1 206-063 , 1J-170L2 (206-064) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, /'`/~~ MJ veland ConocoPhillips Well Integrity Projects Supervisor Enclosures -~~iv~D ~~~ ~. ~ 20D9 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Alasica ~ll &~a, Cons. Co ~ssio~ APPLICATION FOR SUNDRY APPROVAL Anc~iorage 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other Q Altercasing ^ Repairwell ^ Plug Pertorations ^ Stimulate ^ Time Extensio , Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspe ded I ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: . P rmit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 206-063 ' 3. Address: Stratigraphic ~ Service 0. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well N d Number: where ownership or landownership changes: Spacing Exception Required? Y2S NO ~ L1 ' 9. Property Designation: 10. KB Elevation (ft): : i d/Pool(s): ADL 25660 &~ Z.~7•~ RKB 109' • u uk River UniU West Sak Oil Pool • 12. PRESENT WELL CONDI 10 MARY Total depth MD (ft): , Total Depth ND (ft1: Effective oepth nno (ft): Effective Depth TVD }:~ lugs (measured): Junk (measured): ' l~y ;3352: Casing ,~• Length y t ,d~ Size MD ~ ND Burst Collapse CONDUCTOR g0 20" 10 108' SURFACE 3013 10-3/4" 0 1 2146' Intermediate 7866 7-5/8" ~ 4 3649' B sand Liner 5727 4.5" 255 3549' Perforation Depth MD (ft): Perforation Depth ): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted & Blank liner fr 7080-11745' 3504-3516' . ; 4.5" L-80 6382.65' Packers and SSSV Type: ackers and SSSV MD (ft) ~ Packer - Seal assy, ZXP liner top ~ 6491 No SSSV - Nipple 508 13. Attachments: Description Summary of Proposal 14. Well Class after proposed work: Detailed Operations Program ^ BOP Ske h^ Exploratory [] Development ^ Service ~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: C~ U~ L~ Cn Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date~ WAG ~~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is tru and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/ er Klei j Title: Well Integrity Project Supervisor Signature ,r~! ~~~~r~..~ ''~- • -- ~ Phone659-7043 Date ~ ~} C Commission Use Onl Sundry Number: Conditions of approval: N ify Commission so that a representative may witness ~ ~~ Plug Integrity ~ OP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~ 1~C1~ G`~~~'"dtJt..Q ~tt't-e. -f'a /"1l~;.: . C,LL /4~~I'4.1 °~`" J ~ Subseque t Form Required: APPROVED BY Approved by: COMMISSIONER . THE COMMISSION : Date: Form 70-403 Revised 06/2006 ~~~~ ~~~ ~ t ~~1 Submit in Duplicate ,`"~~~ ~ /~~t~~' ~~.~~ot 1 J-170 • DESCRIPTION SUMMARY • OFPROPOSAL ConocoPhillips Alaska, Inc. 1J-170 (PTD 206-062) & 1J-170L1 (PTD 206-063) & 1J-170L2 (PTD 206-064) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in West Sak Injection Well 1J-170 and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1J-170 was drilled and completed in June 2006 as a pre produced trilateral injection well and converted to a water only injector in October September 2006 The well was drilled with a 20" conductor to 108'. The surface hole was drilled with a 13.5"" bit and cased with 10-3/4"" casing to a TD of 3041'. The casing was cemented in place with 462 bbl of lead cement (Arctic set) and 79.5 bbl of tail cement (Deepcrete). Bumped plug on calculated displacement volume and the floats held. Good cement returns were seen, 120 bbl to surface. The intermediate hole was driiled with a 9-7/8" bit and cased to 7894' with 7 5/8" casing. The casing was cemented in place with 185 bbl Deepcrete cement. Bumped plug on calculated volume and good returns were mentioned. The top of cement is confirmed at 3036' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1J-170 2. Injection well 1J-170 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 J-170 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oi( and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. 2009 WSAK EOR Pattern Targets `- 1 J-170 ~- ~ --_- - ~--~ - 1 ;~ „ ~ f _'~ ~ i~ r~ ~ ~ ~~. ~ ( 1E-117 - C7R~@f lSRIJ YIABII i ~'' AAB(Of S4e7~IN- F8U1L5 ~ F~M~ ~ CiL. PrOduCOt ~ Produoer • S~ Producsr + P arW A ~ ~nn.rcLOr ._~'~,~.~ tE-702 1!4 rna Buf4er L Row tfd mi BuMsr N Row /~4 rn~ BuTMBr ~ • 1J-170 Cement Log Gas? Interval Top interval 5,924-5,742 3,135-2,954 Tops UG C 4,575 UG B 5,06c UG A 5,34E K13 5,73E D 6,41( rn c ~ ~Z Uc w • GASR MDR C G? w~ a+C D • •Interval between 6,920' and 2,950' logged • "micro" debonded near shoe •"Micro" debonded pattern continues upwards but improves slightly •Top of cement on log @3036' •570' of cumulative cement bond with 0-20% "micro" debonding ~ I ~~ u ~ Bottom interval 6,924-6,750 ~ • Schwartz, Guy ~ (DOA From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM Ta Roby, David ~(DOA); Schwartz, Guy L(DpA); Davies, Stephen F(DOA) Subject: FW: Update of Wsak VRWAG Pilot Project 8~ additional 10-403 information for wells 1 E-102 & 1 J-9 70L9 Atta~hmen#s: Picture (Metafi(e); Picture (Metafile) Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist [mailto:n1139Calconoco~hillips.com]. Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-f02 & iJ-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to Zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. 1Ne11 1E-102 M~E to offset Producer 1E-121 Date Well 1 E-102 PTD# 204-231 10/25l2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB ( 1 3/8 FISH fdECK-43" OAL ). (( &SAND IS ISOLATED )). JOB COMPLETE. Well 1J-'070L1 AABE to offset Producer 1J-186 Date Wep 1J-170L1 PTD# 206-063 8J10/2008 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE S ET. Please provide direction as to what is needed to move the process fonrvard. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in errar, please notify the sender and delete this emaif immediately. • ~ Page 1 of 2 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, October 17, 2009 9:42 AM To: Schwartz, Guy L(DOA); Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Prod Engr Specialist; NSK Well Integrity Proj Subject: FW: Update of Wsak VRWAG Pi1ot Project 8~ additional 10-403 information for wells 1 E-102 & 1J-170L1 Attachments: 1E-102 Schematic.pdf; 1J-170 schematic.pdf Guy, Per our discussion, ConocoPhillips requests the withdrawal of Sundry Applications for VRWAG on the B laterals of the following we!!s: 1 E-102 (PTD 204-231) 1J-170L1 (PTD 206-063) ~/ Sundry Applications for the remaining laterals on each well are still requested. 1 E-102L 1(PTD 204-232) - D Sand Lateral 1J-170 (PTD 206-062) - A Sand ~ateraf 1J-170L2 (PTD 206-064) - D Sand Lateral The B sand laterals will remain isolated with sleeves during any VRWAG injection periods. Conceptual schematics are attached to show the approximate location of each lateral. Please let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-9687 From: NSK Prod Engr Specialist Sent: Tuesday, October 06, 2009 5:28 PM To: Thomas Maunder Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 1]-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), 1 have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. Well 1 E-102 MBE to offset Producer 1 E-121. 10/20J2009 Page 2 of 2 ~ ~ Date Weil 1E-102 PTD# 204-231 10t25~2~06 BRUSH DS NIPP~E c'(,~,z? 6060'RKB. SET 3.51~2 DBP PLUG @ 6Q60'RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB (1 3~i8 FISH NECK 43" OAL ). (( B-SAND IS ISOLA~EQ . J08 COMPLETE. Well 1J-170L1 MBE to offset Producer 1J-166 Date 1Ne11 1J-1?OL1 PTD# 206-OQ 8/1012008 PULLB-SAND DIVERTER AND SET B~SAND ISOLATION SLEEVEAT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLA710N SLEEVE SET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc, Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. i oi~a~~oo9 • Conoco~illips C] Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 ~-~; ~ F~ac 659-7314 ;~I.i ' ~ f3 /; August 21, 2~ ~ ''',a.~'~~ .~i` ~ r, Tom Maunder, P.E. Senior Petroleum Engineer ~~ State of Alaska, Oil & Gas Conservation Commission ~ d 33 W. 7~' Ave. Ste. 100 _ a~ Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set a blanking sleeve in the Lateral Entry Module (LEM) of one West Sak multilateral injection well. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1J-170, 1 J-170L1, and 1 J-170L2. These reports record the setting of an LEM isolation sleeve in the Ll lateral water injection well. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, Robert D. Chistensen ~~~~ ~-Q~t ~ ~ ~OQ$ Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CONIMISSIOf~~BSI(a C)II & G3v ~ ~"'I~• ti "` " REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other a et -san so Sleeve Alter Casing ^ .Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhilllps Alaska, InC. Development ^ Exploratory ^ 206-063 ' 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-170L1 ' 8. Property Designation: 10. Field/Pool(s): ADL 25660; 25661 Kuparuk River Field /West Sak Oil Pool 11. Present Wel! Condition Summary: Total Depth measured 12602' feet true vertical 3552' feet Plugs (measured) 6818' Effective Depth measured 12548' feet Junk (measured) true vertical 3549' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3013' 10-3/4" 3041' 2147' INTERMEDIATE 3.55' 7-5/8" 7894' 3652' SLOTTED LINER 5726' 4-1/2" 12550' 3549' Perforation depth: Measured depth: 6863'-12475' true vertical depth: 3483'-3545' 11 ` ~ \ Tubing (size, grade, and measured depth) 4-1/2", L-80, 6382.6 5' MD. , _ ~h\~ C~-C~-~~' ~~~~Cs~V ~ l~ Packers ~ SSSV (type & measured depth) Packer = ZXP Liner top Pkr Packer = 6383', 6491' SSSV =NIP SSSV = 509' ~h, ~~`~,~. 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~~ Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 917 1564 672 Subsequent to operation 991 612 348 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 ^Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Vacant Printed Name obert D.Chris ensen Title Production Engineering Technician Signature ~ Phone 659-7535 Date ~a` ~~ r Form 10-404 Revised 04/2004 ~ Submit Original Only • ~ ^~ .. 1J-170L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/10/08 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED: HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-170+PB1+PB2+L1+L2 AK-MW-4406587 July 18, 2008 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-170+PBl+PB2+Ll+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 310-00,60,61,70,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23310-00,60,61,70 Digital Log Images ~~~~~ „-~ Ali ~ ~~ ~~~~ 1 CD Rom 50-029-23 310-00,60,61,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage,:Alaska 995.1.8 - Anchorage, Alaska 99508 ~. ~- ~ Date: - Signed: ~ ~ /\/~-~~ ~`~ u~~ ~o~-o~~ t(v°~~q ~/ vse ao(, o~ ~~ • ~8 jw DATA SUBMITTAL CO PLIANCE REPORT 6/25/2008 Permit to Drill 2060630 Well Name/No. KUPARUK RIV U WSAK 1J-170L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23310-60-00 _\ MD 12602 TVD 3552 Completion Date 6/28/2006 Completion Status 1-OIL Current Status 1WINJ ~_ UIC Y REQUIRED INFORMATION ---~ Mud Log No Samples No Directional Surveys Yes i i _ .. DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments °~--_ 14043 LIS Verification 8/22/2006 i C Lis 14043 Induction/Resistivity 3004 12545 Open 8/22/2006 GR, Res, FET, ROP D- D Asc Directional Survey 6748 12602 Open 8/22/2006 g Injection Profile 5 Blu 1 8760 11708 Case 5/4/2007 Mem Injection profile, GR, j CCL, Pres, Temp, Spin 25- ------ _.. -- ---- - Apr-2007 Nell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~/~~N~ Chips Received? `~">`i~- Analysis ~.~N Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~` N Formation Tops N Date: Schlumberger -DCS ~~,~ t -~ ~ ~ ~ ~ J 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ATTN: Beth ~~r~¢~ ~ ~ ~~f.~?~ Well Job # NO. 4239 Company: Alaska Oil 8 Gas Cons Comm _ // ~~ Attn: Christine Mahnken U ~G ~~~ dl~] 333 West 7th Ave, Suite 100 Anchorage, AK 99507 Field: Kuparuk Log Description Date BL Color CD 04/20/07 2F-17 11632699 INJECTION PROFILE 04130/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24107 1 3A-01 11632691 PRODUCTION PROFILE 04122/07 1 2H-17 11665423 INJECTION PROFILE 04!24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. tU n ~` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J ~ ~ ~~ ~ 1 :;~ REPORT OF .SUNDRY WELL OPERATION~~~~~~ gib, ~ °:~ ' .:.. 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ` -~ Prod to WINJ Alter Casing ^ Pull Tubing ^ Perforate 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: COnOCOPhilhpS Alaska, InC. Development ^ Exploratory ^ 206-063 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-170L1 • 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25661 Kuparuk River Field / Wesf Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 12602' • feet true vertical 3552' ~ feet Plugs (measured) Effective Depth measured 12548 feet Junk (measured) true vertical 3549 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 1.08' SURFACE 2932' 10-3/4" 3041' 2146' L2 WINDOW 1' 7-5/8" 6410' 3401' L1 WINDOW 1` 7-5/8" 6841' 3480' INTERMEDIATE 7785' 7-5/8" 7894' Perforation depth: Measured depth: 6863'-12475' true vertical depth: 3483'-3545' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6383' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pp Treatment descri tions in l di l d d fi l ~~ ~ 7~0~ p c u ng vo umes use an na pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2206 ~ 4003 3 1269 222 Subsequent to operation 21 ' 875 1612 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 Q< WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-295 contact Bob Christensen /Bob Buchholz Printed Name Robert D. ri tensen Title Production Engineering Technician Signatur Phone 659-7535 Date ~D / ~ D f ^ }n- ~1 ~ ~c~ /o •23.06 Form 10-404 Revised 04/2004 ~ ~ E ~ ~ ~ ~ ~~15~~~~Su/bm_i 'gi~~ nl Ettt [[[ ~ ~~~ 1J-170L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/09/06 Well shut in for Producer to Injector conversion 10!02/06 Commenced Water Injection service 7 ~ ~ q ~ r ~~r ~ ~ ,q~%j ~ 1~ i ~~ ~ y i ~~ ~ ~ ~'~ ~ ~ ' ~ ; a~~ i , '~ ~ ~ ~ , e. ~.~ FRANK H. MURKOWSKI, GOVERNOR a ~~ OIL ~ ~ ~' L 333 W. 7"' AVENUE, SUITE 100 COI~TSERQAZ'I011I COMI~IISSIOIQ s''~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170L1 Sundry Number: 306-295 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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. Sincerely, DATED thisay of September, 2006 Encl. _~L~~ Chairman V\ STATvEIOF ALASKA '3~ ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED AUG 2 9 2006 APPLICATION FOR SUNDRY APPROVA~aska Oil & Gas Cons. Commission 20 AAC 25.280 •--~- - 1 . Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ~~~~'~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ~ h`rc.C~t- v 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Numbe r: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 206-063 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-60 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Ye8 NO Q 1J-170L1 9. Property Designation: 10. KB Elevation (ft}: 11. Field/Pool(s): ADL 25660, 25661 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12602' 3552' ~ 12548 3549 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2932' 10-3/4" 3041' 2146' L2 WINDOW 1' 7-5/8" 6410' 3401' L1 WINDOW 1' 7-5/8" 6841' 3480' INTERMEDIATE 7785' 7-5/8" 7894' 3650' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6863'-12475' 3483'-3545' 4-~/2" L-80 6383' Packers and SSSV Type: Packers and SSSV MD (ft) no packer "~ert~c-~~eP3~~ SSSV= NIP SSSV= 509' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG '^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name RObet-t D. ChrlSt2r1SEr1 Title: Production Engineering Technician Signature Phone 659-7535 Date ~ (Q p (p Commission Use Onl Sundr Number: Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test {~ '--~ Location Clearance ^ Other: ~~~14~5 ~~[.., SEP ~ 2 2006 Subsequent Form Required: ""t~ ~-~~ APPROVED BY ~ /Q~ ~ ~ Approved by: OMMISSIONER THE COMMISSION Date: ~ Form 10-403 Revised 06/2006 ~ U ~ I ~~ ~ ~ Submit in uplic~e3~ •o` 1J-170L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- ~ lateral Well 1 J-170L1. This well was pre-produced fora 64 day period in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-170L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (.3041' and / 2146' tvd) was cemented with 560 sx AS Lite followed by 180 sx DeepCrete. The 7-5/8" Intermediate casing (7894' and / 3649' tvd) was cemented with 460 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6353' and / 3391' tvd. This well also contains a Lower B sand 5-1/2" x 7-5/8" ZXP Liner Top Packer located @ 6491' and / 3417' tvd. The top of West Sak D sand was found at 6410' and / 3401' tvd. The top of West Sak B sand was found at 6826' and / 3478' tvd. The top of West Sak A sand was found at 7829' and / 3645' tvd. Tuemic CD:4 W0, ~. IMERMEDIATE (0-7QBd, OD 7 p5, w~2e za} PUP 1~ )~a2~ia, t 0o zio) ,4SAM LIFER TOP (47P3{945, OD:4b00, Wt:11 60) Perf (SNE~ 12475) &SAnD LIFER M. ~ ,;~: (E223-1251P, II, ~, W:4 FAO, w111 f-0) ,. • KRU 1 J-170L1 1J-170L1 API: 500292331060 Well T e: PROD An le TS: de SSSV T e: NIPPLE Ori Com letion: 6/29/2006 An le TD: 87 de 12602 Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo : 28' RKB Ref Lo Date'. Last U date: 77212006 Last Ta TD: 12602 ftKB lLastTa Date: ____ __ Max Hole Angle: Casing String -ALL STRINGS Descri tion Size To 93 deg (m 9502_,___ _ __ _ Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED SURFACE 10.750 0 3041 2147 45.50 =80 BTC INTERMEDIATE 7.625 0 7894 3505 29.70 L-80 BTCM A-SAND LINER TOP 4.500 4703 6845 3480 11.60 L-80 BTC L2 WINDOW 8.000 6409 6410 3401 0.00 B-SAND LINER 4.500 6823 12518 3547 11.60 L-80 BTC L1 WINDOW 8.000 6840 6841 3480 0.00 Tubing Strin -TUBING _ _ _ . -- _ _ Size __ _ Top _ ~ Bottom I TVD I Wt __Grade Th-ead 4.500 0 ~ 6383 3396 12.60 L-80 IBTM '- _~ - - Perforations Summary Interval TVD Zone ~ Status Ft _! SPA Dat~TypeT Comment 6863 - 12475 ~ 3483 - 3545 WS B,WS ~ 5612 32 ~ 6!18/2006 ~ SLOTS Alternating slotted/solid pipe CWSB ' 1_ -Gas Lift MandrelsNalves _ St MD~ TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3604 2394 CAMCO KBG-2-1R GLV 1.0 BK-5 0.188 1502 7/142006 2 5175 3052 CAMCO :Other (plugs, equip., et - De th TVD T e KBG-2-1R _ OV 10 BK-5 0.313 0 7/14_2006 c.) -COMPLETION - - - - -_ _ Descri tion D 22 22 HANGER VETCO GRAY TUBING HANGER 4.500 509 508 NIP CAMCO'DB-6' NO GO NIPPLE 3.875 6309 3382 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"'DB' PROFILE OPEN 3.812 6358 3392 LOCATOR BAKER GBH-22 LOCATOR SPACED OUT 4' ABOVE FULLY INSERTED 3.875 6360 3392 SEAL BAKER SBE SEAL ASSEMBLY 3.875 6382 3396 SHOE 3.958 Other De th lugs, TVD egui~et T e _ _ c.Z- D-SAND 8~ B-SAND LEMs __ Descri ion ID 6353 3391 PACKER D ZXP LINER TOP PACKER 4.950 6372 3394 SBR D 190-47 CASING SEAL BORE RECEPTACLE 4.750 6392 3398 BUSHING D CROSSOVER BUSHING 3.950 6394 3398 PUP D 3.958 6397 3399 HANGER D ABOVE HOOK HANGER 3.980 6407 3401 HANGER D INSIDE NOOK HANGER 3.980 6491 3417 PACKER B ZXP LINER TOP PACKER 4.950 6510 3420 SBR B 109-47 CASING SEAL BORE RECEPTACLE 4.750 6530 3424 BUSHING B CROSSOVER BUSHING 3.950 6532 3424 PUP B 3.958 6813 3475 HANGER B ABOVE HOOK HANGER 3.980 6823 t er De th ( 3477 _ plugs, TVD HANGER(B) -_ a ui ., etc - T e INSIDE HOOK HANGER - -- - . - B-SAND LINER DETAIL - - - - Descri tion 3.980 D 6840 3480 HANGER BAKER MOD 81 FHH 3.980 6858 3482 SWIVEL BAKER CASING SWIVEL 3.980 6896 3487 NIP CAMCO'DB-6' NIPPLE 3.563 6970 3496 SEAL BAKER SEAL ASSEMBLY 4.000 12518 3547 XO CROSSOVER 4.5" TO 3.5" 3.500 12519 3547 PUP 2.992 12548 Genera Date 3549 SHOE l Notes Note BAKER OPEN GUIDE SHOE _ 2.992_ _ 7/1/2006 MULTI-LATERAL WELL: 1J-170 (A-SAND), 1J-170L1 (B-SAND ), 1J-170L2 (D-SAND) TREE: VETCO GRAY / HORZ / 4-1/8" 5M -TREE CAP CONNECTION: 9.5" OT IS ~t3d~t~CQ~"~llips ~~~5~~, 1E~~. MEC:iANICAL INTEGRITY R :PORT ~ ~ _ ~6 °UD u'-:= =..G r~..~~~~. ~~~ S Cement Volumes :~ Amt. Liner CsQ ~--~coC~S~; DV `~(~ Cmt -col to cover oers ~-.o~~~~ Co`~~C~~~ ~~~b~~~~~c(oS~~ _ eoretical TOC C ~~ ~S ~~S ~,~,~Sr-1~~ `~c,~~~~eCv~~e,,cc --~~~~f n ~ LL DAT ~_ TD : ?-~.. TVD ; . BTD : ?~D Z'VD Casing '~~~" Shoe . 'Z4~i'1MD ~~1~ TVD ; liV . ~ ~ ?~ ~ d,~ ;tip -==ie= - Shoe . '~ 'I'`1r ; .GP . '•~ _'i~ u o ~ ~ V _P a c is e r ~'~ TVD ; Set a t `s~. sE~\ ~~ ole S .-ce " ~1 ~ and Perfs to ~~~«, ~~ C"r'..r~?Z =C~.L INTEGR?-TY - P?_RT # I c_nnulus Press Test: _? Conents : 15 nin ~0 min '~'CHPUICr~, 1NTEGRTT r - PART # 2 ~S ~ " .G/ ~~ ~J ~~ J y 3L OPER ~ FZELD ~ 1 _ k~Z~ ~~ i:~LL NUI~ER ~~ "" i~,~ _ ~~~~.`~ ~ ~~~~~ Cement Bond Log (Yes or No) ~ In AOGCC File v C3L Evaluation, cone above perfs '1~~~~~`~~ g~~~ec_=~~ ~E~, Production Log: Type Evaluation CONCLUSIONS: az t ~ 1 Part r 2 ~'~-,~.. '~ 5 • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs • July 19, 2006 1J-170, PB1, PB2, Ll & L2, AK-MW-4406587 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-33100-00, 70, 71, 60, 61. 5 v ~_ U~7`3 -a33 !U °-00 ~d~vt e o ~t e i-~ ~}d~{- c~. c~ -' PLEASE ACKNOWLEDGUE 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 REC~I~/'~G~ Dat~UG 2 2 2006 Ica pil & Gas Cons. (;ommissk~ Mchora9~ Signed: ~ ~t---''~~ • r1 LJ 07-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-170 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,748.08' MD Window /Kickoff Survey: 6,828.00' MD (if applicable) Projected Survey: 12,602.00' 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 d~~ ~ Si ned g ease call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~-0~3 - ~m- 1VED STATE OF ALASKA ~ ~` ~-~ ~' ®~ ZOO6 ALASKA OIL AND GAS CONSERVATION COMMISSION , a ~ ~a Cofnmission WELL COMPLETION OR RECOMPLETION REPOR~11~`~`~`~~~~- 1a. Well Status: Oil ^/ Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _XX Pre-produced Injector 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or,4band.: June 28, 2006 12. Permit to Drifl Number: 206-063 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded/~~` ~~! LOVL M 006 13. API Number: Qb 50-029-23310-60 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2489' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: June 16, 2006 14. Well Name and Number: 1J-170L1 At Top Productive Horizon: 2378' FSL, 668' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (ft): 2g' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 2427' FNL, 567' FEL, Sec. 27, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 12548' MD / 3549` ND West Sak Oil POOI 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 y- 5945614 Zone- 4 10. Total Depth (MD + TVD): 12602' MD / 3552' TVD 16. Property Designation: ADL 25660, 25661 TPI: x- 555259 y- 5946164 Zone- 4 Total Depth: x- 555308 - 5951918 - Zone- 4 11. Depth where SSSV set: nipple @ 509' 17. Land Use Permit: ALK 470 18. birectional Survey: Yes ^/ No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 4574' MD 21.logs Run: kpP Za J 3 78 TY 8'8'x` GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.6# H-40 28' 108' 28' 108' 42" 395 sx AS 1 10.75" 45.5# L-80 28' 3041' 28' 2146' 13.5" 560 sx AS Lite, 180 sx DeepCRETE 7-5/8" 29.7# L-80 28' 7894' 28' 3649' 9-7/8" 460 sx DeepCRETE 4.5" 11.6# L-80 6823' 12550' 3476' 3549' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slotted liner from 7080'-7293', 7807'-8067', 8577'-8837', 9302'-9554', 10071'-10325', 10715'-10972', 11486'-11745' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production July 18, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced gas lift oil -shares production with 1J-170 and 1J-170L2 Date of Test 7/20/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1521 GAS-MCF 615 WATER-BBL 0 CHOKE SIZE 5 Bean GAS-OIL RATIO 438 Flow Tubing Not available Casing Pressure 1360 Calculated 24-Hour Rate -> OIL-BBL 2535 ~ GAS-MCF 1111 ~ WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". COf~PLETiJN DATE NONE ,v ~~DdNiS BFI AUG X 4 2006 VERIFI -0 Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ~ J'8'O6 r, ~, zs. zs. 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". 1 J-170L1 Top West Sak 6410' 3401' West Sak B 6826' 3478' - N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed Name Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader ~ Signature ~t-~~y~~ Phone Date ~~ -J~ Prepared by Sharon Allsup-Drake r ~/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ail types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken. indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~ono~ Phiiiips Time Log Summary Wellviev/ Web ReADrting -- _-_ _ _ _ - -J -- _-- - Time Logs _ - _ - - -- Date - -__ Froi~~ To- - Dur S. Depth E De th Phase Code Subcode T COM -- 05/25/2006 20:00 00:00 4.00 0 0 MIRU MOVE MOB P ~ Move rig to 1J-170. 05/26/2006 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Cont. to move rig from 1J-184 to 1J-170, Lay mat boards, spot pits, um s, motor & broiler com lexes. 03:00 03:30 0.50 0 0 MIRU MOVE PSIT P Spot rock washer 03:30 04:30 1.00 0 0 MIRU MOVE PSIT P Spot pipe sheds 04:30 09:00 4.50 0 0 MIRU MOVE OTHR P Work on rig pre-acceptance checklist. Install service lines, prepare pits to take on water. Assemble mud pump lines, assemble skate, level pipe shed. Berm rock washer. ACCEPT RIG @ 08:00 hrs. 09:00 12:00 3.00 0 0 SURFA DRILL PULD P PJSM: P/U 5" DP from shed and rack back in derrick. total of 78 'oints. 12:00 13:00 1.00 0 0 SURFA DRILL PULD P Cont to P/U DP and 6 stands of HWDP with 'ars and rack back. 13:00 13:30 0.50 0 0 SURFA WELC7 BOPE P Perform diverter test. AOGCC Jeff Jones waived witnessin at 09:30 hrs. 13:30 14:30 1.00 0 0 SURFA DRILL PULD P Clean rig floor. P/U BHA from beaver slide. 14:30 15:30 1.00 0 0 SURFA DRILL PULD P Make up monels, bit and stablizer. 15:30 16:00 0.50 0 0 SURFA DRILL CIRC P Flood mudlines and conductor. 16:00 17:30 4.50 0 0 SURFA DRILL RURD P PJSM. Rig up gyro. 17:30 20:30 3.00 108 222 SURFA DRILL DRLG P Make up Bit #1 & Mud Motor, Spud well @ 17:30 hrs, Drill f/ 108' to 222' with 2 std's HWDP. 525 gpm, 550 psi, 60 r m, 0 for ue, 8K on bit. 20:30 23:00 2.50 222 222 SURFA DRILL TRIP P POOH, Change Motor bend to 1.83, P/U MWD and RIH to bottom. 23:00 00:00 1.00 222 254 SURFA DRILL DRLG P Drill from 222' to 254' @ 500 gpm, 900 psi, 40 rpm, 0 torque, 60 ROP, 8K on bit. 05/27/2006 00:00 12:00 12.00 254 966 SURFA DRILL DRLG P Drilled 13.5" hole from 254' to 966' MD. ART=4.15, AST=2.18, ADT=6.33 PU=77K, S0=76K, ROT=79K, TQon=3, TOoff=1 Jar hours=8.38 hrs, Max Gas=47 btu Byro depths: 253, 347, 440, 530, 621, 713, 816 ~_ Q~g~ ~i czf27 'Time Logs Date From To Dur S. e th E. Depth Phase Code Subcode T - -- OM 05/'L7/2006 12:00 22:30 10.50 966 2,110 SURFA DRILL DRLG P Drilled 13.5" hole from 966' to 2110' MD, 1771 TVD 570 gpm, 1550 psi on btm, 1400 psi off btm, 6K TQ with pumps on PU=93K, S0=76K, ROT=89K with pumps on Jar hours=16.25 22:30 22:45 0.25 2,110 2,110 SURFA DRILL CIRC P Circ to clear BHA 22:45 00:00 1.25 2,110 1,835 SURFA DRILL REAM P Monitor well: Static. BROOH from 2110 to 1835 @ 700 gpm, 2000. psi, 45 rom, 4-5 TQ 05/28/2006 00:00 01:45 1.75 1,835 723 SURFA DRILL REAM P Cont to BROOH from 1835' MD to 732' MD. ROT at 40 rpm, 168 spm, 1900 si. 01:45 03:00 1.25 723 0 SURFA DRILL TRIP P POOH on elevators to surface. 03:00 03:30 0.50 0 0 SURFA DRILL OTHR P Drain motor, grade bit, turn motor to 1.15 de .Orient to MWD. 03:30 05:00 1.50 0 2,110 SURFA DRILL TRIP P RIH to 2020' wash and ream to 2110' MD at 520 gpm, 123 spm, ROT 10 r m, TO=3K. 05:00 12:00 7.00 2,110 2,759 SURFA DRILL DRLG P Drilled from 2110' to 2759' MD, 2031' TVD. ART=2.48, AST=1.52, ADT=4.0 PU=100K, S0=72K, TQon=8K, TOoff=4-6K Max Gas=1732 BTU @ 2642' MD, 1982' TVD. Jar hrs=20.25 12:00 14:45 2.75 2,759 3,050 SURFA DRILL DRLG P Drilled from 2759' to 3050' MD, 2149' TVD. ART=0.4, AST=0.67 ADT=1.07 PU=100K, S0=72K, TQon=BK, TQoff=SK Max Gas=67 BTU Jar hrs=22.22 14:45 15:15 0.50 3,050 3,050 SURFA DRILL CIRC P Circ and condition mud. 15:15 18:00 2.75 3,050 1,186 SURFA DRILL REAM P Monitor well and BROOH from 3050' MD to 1186' MD at 700 gpm, 40 fpm, 2000 si, 100 r m, 5-8K. 18:00 19:30 1.50 1,186 163 SURFA DRILL TRIP P Pull last 4 stds of DP on elevators, LD - ghost reamer and 3 stds HWDP. Rack back last 3 stands of HWDP & 'ars. 19:30 21:00 1.50 163 0 SURFA DRILL PULD P LD collars, MWD, motor and bit. 21:00 23:30 2.50 0 0 SURFA CASIN( RURD P Clear and clean rig floor. RU to run 10 3/4", 45.5#, L-80 BTC casin . 23:30 00:00 0.50 0 0 SURFA CASIN( RNCS P Dummy run landing joint. 05/29/2006 00:00 05:15 5.25 0 3,041 SURFA CASIN( RNCS P PJSM, Pick up 10-3/4" Shoe, 2jts 10-3/4", 45.5#, L-80, BTC casing,. Float collar and check floats- OK, Run 10-3/4" Casing to 3007' (Pumped down f/ 1707' to 1825'), Make up hanger and land casin 3041. 05:15 06:15 1.00 3,041 3,041 SURFA CASIN< CIRC P Circ btm's up at rate of 6 bpm @ 350 si. ~ ~ _ ~ ~ "~gA 2 ~f ~7 Time Logs - _ _ - f~atP Frnm Tn four anth F ---- - -- - -- -_ - - - - Unnth f~hase ('nrie Siihcnrie T _,nM 05/29/2006 06:15 06:45 0.50 3,041 3,041 SURFA CEMEf~ RURD P Lay down Franks fill up tool, Make up Dowell cement head. 06:45 08:30 1.75 3,041 3,041 SURFA CEMEI~ CIRC P Continue to Circ. & Cond. mud for cement at rate of 7.0 bpm @ 4000 psi, Reciprocate pipe 10'-Mud prior to circ.= Wt. 9.4 ppg, Vis 278, PV 35, YP 58, Mud after= Wt. 9.1 ppg, Vis 44, PV 16, YP 5, Held PJSM with all hands and Dowell. 08:30 11:15 2.75 3,041 3,041 SURFA CEMEI~ CIRC P 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 462.4 bbls (560 sxs) of lead cement at 10.7 ppg and 4.63 yield with additives, ave 7.0 bpm at 200 psi, followed with 79.5 bbls (180 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 6.9 bpm at 435 psi, reciprocated csg 10' and had full returns, shut down and dropped top plug and Dowell pumped 20 bbls fresh water then turned over to rig. Rig displaced cement with 261.0 bbls (2592 stks) of 9.1 ppg mud, displaced cmt at 7.0 bpm, initial Circ pressure 600 psi, max pressure 900 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1300 psi, held 5 min, checked floats and held, CIP @ 11:15 hrs, had full returns during job and had 120.0 bbls of 10.7+ ppg cmt back to surface, reciprocated csg until 112.5 bbls cmt around shoe -then pipe became tight, st wt up 165K, do wt 86K, Landed casing with Shoe @ 3,041.12' and Float collar 2,954.08'. 11:15 12:00 0.75 0 0 SURFA CEMEf~ RURD P Check float equipment, R/D cement e ui ment. 12:00 13:00 1.00 0 0 SURFA CEMEf~ RURD P Cont to R/D cmt equipment, clear and clean ri floor. 13:00 17:00 4.00 0 0 SURFA WELCT NUND P Flush stack & N/D diveterwith Crain. 17:00 18:30 1.50 0 0 SURFA RIGMN SVRG P Change out saver sub. 18:30 20:00 1.50 0 0 SURFA WELCT NUND P N/U wellhead & test to 5000 psi for 10 min. NU BOPE. 20:00 21:30 1.50 0 0 SURFA WELCT BOPE P RU BOPE test equipment. .~._~_. ~ e -- - ~~~d's G.i ~i'. Time Lo~c s Date -- - From To - Dur S. epth E. Depth Phase _ Code Subcode_ T QOM 05/29/2006 21:30 00:00 2.50 0 SURFA WELCT BOPE P Start BOPE test with top set #1, #12, #13, #14, M/Kill, 4" dart valve, 2nd test: 4" TIW, HCR kill, #9, #11, 3rd: test lower IBOP, #5, #8, #10.4th test Upper IBOP, #4, #6, #7. 5th test: 5" TIW, #2. 6th test HCR choke, 5" Dart, 7th test annular w/ 4" DP, manial choke, all test 250 low, 3000 psi high. Jeff Jones waived witnessing 5/28/06 12:30 hrs. 05/30/2006 00:00 02:15 2.25 0 0 SURFA WELCT BOPE P Cont to test BOPS to 250 psi low, 3000 psi high. Test top rams w/ 5" DP, blind rams, lower pipe rams w/ 7 5/8", annular w/ 7 5/8".Accumulator test=inital 3000 psi, close 1800 psi, 200 psi attained 42 sec, full pressure in 3 min 21 sec, 5 bottle nitrogen avera a 2250 si. 02:15 02:45 0.50 0 0 SURFA WELCT OTHR P Set wear ring bushing. 02:45 03:45 1.00 0 0 SURFA DRILL OTHR P PJSM. RU short bails, elevators, inspect top drive. C/O heads on iron rou h neck. 03:45 06:45 3.00 0 0 SURFA DRILL. TRIP P PJSM. RIH with 4" DP and rack back in derrick. 78 'oints 26 stands . 06:45 09:45 3.00 0 0 SURFA DRILL TRIP P PJSM. RIH with 87 joints 4" DP and rack back in derrick. 09:45 10:30 0.75 0 0 SURFA DRILL PULD P Clear and clean rig floor. P/U BHA from Beaver slide. 10:30 12:00 1.50 0 26 SURFA DRILL PULD P M/U 9 7/8" BHA: bit, motor, C/O roughneck heads to 5" for picking up M WD. 12:00 13:30 1.50 26 1,000 SURFA DRILL PULD P M/U float sub, stabilizer, MWD, NMFC, 'ars, HWDP, GR. 13:30 14:30 1.00 1,000 2,951 SURFA DRILL TRIP P TIH and tag float collar at 2,951' MD. 14:30 15:30 1.00 2,951 2,951 SURFA DRILL CIRC P Circ and condition mud for casing test. 15:30 16:00 0.50 2,951 2,951 SURFA CASIN( DHEO P Test casing to 3000 psi for 30 mins on chart. 16:00 17:15 1.25 2,951 3,070 SURFA DRILL REAM P Wash and ream to shoe at 3,041', drill out shoe track plus 20' of rat hole to 3,070' MD. 17:15 17:45 0.50 3,070 3,070 SURFA DRILL CIRC P Circ and condition mud and R/U for LOT. 17:45 18:30 0.75 3,070 3,070 SURFA DRILL LOT P Perform LOT on chart at 10 spm, 56 strokes, 5.6 bbls. at 3041' MD, 2,146' TVD w/ 600 psi, 9.0 ppg = 14.4 ppg EMW 18:30 00:00 5.50 3,070 3,755 INTRM1 DRILL DRLG P Drill from 3,070' to 3,755' MD, 2,463' TVD AST=1.62, ART=1.14, ATD=1.67 hrs PU=112K, So=65K, ROT=82K, TQoff=S-7K Jar hrs=2.76 hrs ~ Time Lis Date From To Dur e th E De th Phase Code Subcode T OM 05/31/2006 00:00 1'L:00 12.00 3,755 5,007 INTRM1 DRILL DRLG P Drill from 3,755' to 500T MD, 2981' TVD AST=4.97, ART=,4.97 ATD= 7.24hrs PU= 128K, S0= 65K, ROT= 85K, TQoff= 7K, TQon= 8K Jar hrs =31.94 hrs 600 gpm, 2000 psi, WO6=5-30K, ROT=85 rpm Pumped sweep at 4586' with 15% increase in returns. 12:00 00:00 12.00 5,007 5,947 INTRM1 DRILL DRLG P Drill from 5,007' to 5,947' MD, 3,313' TVD AST=7.04, ART= 3.37, ATD= 10.41 hrs PU= 116K, S0= 79K, ROT= None to maintain directional work, TQon= 6K Jar hrs = 42.35 hrs ECD=10.04, Max Gas = 59 btu 500 gpm, 85 rpm, WO6=5-30K, 2250 psi Added 2% lubricants at 16:00, 5300' MD 06/01/2006 00:00 12:00 12.00 5,947 6,747 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 5,947 to 6,747' (800') 3,463' TVD, WOB 10-35K, RPM 85, 600 gpm @ 2100 psi, Up 117K, Dn 72K, Rot 87K, TQ 8K on/ 5-7K off, Ave ECD's 9.89 ppg, Max gas 137 Units, Concretions 6,150' to 6,170', 6,510' to 6,530'.. 12:00 00:00 12.00 6,747 7,814 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/6,747'to 7,814' (1,06T) 3,643' TVD, ART= 7.25 hrs, AST= 2.42 hrs, ADT= 9.67 hrs, WOB 15-25K, RPM 85, 625 gpm @ 2675 psi, Up 121 K, Dn 71 K, Rot 87K, TQ 7K on/ 5-7K off, Ave ECD's 10.41 Max as 88 Units. 06/02/2006 00:00 02:00 2.00 7,814 7,900 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 7,814' to 7,900' (86') 3,650' TVD, ART= 1.05 hrs, AST= 0.62 hrs, ADT= 1.67 hrs, WOB 10-30K, RPM 90, 650 gpm @ 2400 psi, Up 121 K, Dn 71 K, Rot 87K, TQ 6-8K on/ 5-7K off, Ave ECD's 10.01 Max as 89 Units. 02:00 03:15 1.25 7,900 7,900 INTRM1 DRILL CIRC P Pump Hi-vis Weighted sweep &Circ hole clean at rate of 600 gpm @ 2200 psi, 90 RPM - No increase in cuttings from swee . 03:15 09:45 6.50 7,900 3,040 INTRM1 DRILL REAM P Monitor well, Back Ream out of hole f/ 7,900' to 3,040' at rate of 40/45 ft/min. w/ 650 gpm @ 2350 psi & 90 RPM, TQ 6-7K. Hole in ve ood sha e. 09:45 10:30 0.75 3,040 3,040 INTRM1 DRILL CIRC P Pump Hi-vis weighted sweep &Circ hole clean with 3 Btm's u 10:30 15:00 4.50 3,040 0 I NTRM1 DRILL PULD P Pump dry job, POOH & Lay down all 5" drill pipe, HWDP, Jars, Down load MWD tools, La down BHA. - ~ ~ r~~g~ ;~ T ~7 __ .~ ~~ _ ~:' _~ s. ~ . . -- - - -- Time Logs - -_ -_ _ _ _ __ Date From Tn four tenth F nenth Phace ('nriF ~iihrnrie T nM 06/02/2006 15:00 16:00 1.00 0 0 INTRM1 DRILL PULD P Clean & clear rig floor of all drill tools. 16:00 17:30 1.50 0 INTRM1 CASIN ( RURD P Rig to Run 7,5/8" casing. 17:30 00:00 6.50 0 4,360 INTRM1 CASIN O RNCS P Run 7-5/8" Shoe (1.51'), 2jts 7-5/8", 29.7#, L-80, BTCM (87.36'), Float Collar (1.28'), 22 jts csg (937.91'), 1- Pup jt (6.18'), 1- Window jt. (43.04`), 8 jts csg (337.47'), 3- Pup jts (37.37'), 1- Window jt (42.15'), Continue running to a total of 100 jts to 4,360' at 23:59 hrs., Circ Btm's up at shoe @ 3,030' with no problems at rate of 6 bpm @ 350 si. 06/03/2006 00:00 02:45 2.75 4,360 7,894 INTRM1 CASIN( RNCS P Continue to run 7-5/8" casing f/ 4,360' to 7,894' (Tagged 8tm with extra joint #184 & la ed down same . 02:45 03:45 1.00 7,894 7,894 INTRM1 CEME~ PULD P RD Franks fill up tool and MU Dowell's cement head. 03:45 06:00 2.25 7,894 7,894 INTRM1 CEMEI~ CIRC P Circ and Cond mud for cementing, Circ at 6.5 bpm at 425 psi, Up 195K, Dn 80K, Initial MW out, 9.3+ ppg, 56 vis, PV 12, YP 23, Conditioned mud to final MW of 9.0 ppg, 39 vis, 7 PV and 12 YP, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementin cs while circ hole. 06:00 08:30 2.50 7,894 7,894 INTRM1 CEME~ CIRC T While priming up Dowell cement unit one of the engines had a fuel pump failure. Wait on another cement unit while continuing to circ & condition mud. ------ ~ -- -- --- ~--- -- - `_ ___ ~;~c~~ r~ of ~7 Time Lois -- ,Date From To Clur S. ~e th E_ De nth Phase Code Subcode 7 ~OM 06/03/2006 08:30 11:00 2.50 7,894 7,894 INTRM1 CEMEh DISP P Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.6 bpm @ 185 psi, Pressure tested lines to 3,500 psi, Then pumped 65 add. bbls of CW 100 at rate of 4.5 bpm @ 190 psi, Dropped btm plug, Pumped 75 bbls of MudPush at 11.0 ppg at rate of 4.6 bpm @ 230 psi, Followed by 184.9 bbfs, (460 sxs - 25% over calculated) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, ave 4.5 bpm at 205 psi, Reciprocated pipe 30' 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 353.2 bbls OBM (Total of 358.2 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Initial pressure 300 psi, Max pressure 1150 psi, Slowed pump rate to 3 bpm 750 psi) with 10 bbls left to pump and bumped plug to 1300 psi, ck floats and held. CIP at 11:00 hrs. 6/3/06. Reciprocated pipe until 87.3 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 7,894.00', Float Collar @ 7,803.85', Calc TOC @ 4,16T, Had full returns thru out job. Well static after shut down. 11:00 12:00 1.00 0 0 INTRM1 CEMEf~ PULD P Rig down Dowell cement head, Vacuum out OBM from cut off stub. 12:00 12:30 0.50 0 INTRM1 CASIN( NUND P Nipple down well head and raise stack, Set casing slips w/ 155K on indicator - tention 75K. 12:30 16:30 4.00 0 0 INTRM1 CASIN( NUND P Cold cut 7-5/8" casing, Remove cut off, Install pack off, Nipple up well head & stack, Test pack off and flange break to 3800 psi f/ 10 min- OK, Install wear bushin . 16:30 18:00 1.50 0 INTRM1 DRILL PULD P Bring 4" Lo-Tad's to rig floor, Rig to pickup 4" drill pipe, Pick 21 joints 4" XT-39 HWDP. Note; Pertorm infectivity test on 7-5/8" x 10-3/4" annulaus with 9.0 ppg mud, 450 psi, 2149' TVD= 13.0 ppg EMW. Flush annulus with total of 141 bbls fresh water at rate of 2.0 bpm @ 760 si. ~~ ~~ 4~ 7 ref ~7 __ i Time Low ~ ' Date From To Dur e th E Depth Phase Code_ Subccde l ;OM - - - - - - __ - --- 06/03/2006 18:00 19:00 1.00 INTRM1 DRILL PULD P Pick up 51 jts 4" XT-39 drill pipe from pipe shed. Note; Rig little red servixce and freeze protect 7-5/8" x 10-3/4" annulus with 85 bbls diesel at rate of 1.8 bpm @ 800 si. 19:00 21:00 2.00 INTRM1 DRILL PULD P POOH installing 4" Lo-Tad's and rack back 17 stands in derrick. 21:00 00:00 3.00 INTRM1 DRILL PULD P Pick up 99 joints 4" XT-39 drill pipe with WWT Sliders installed from pipe shed. 06/04/2006 00:00 03:15 3.25 3,720 0 INTRM1 DRILL PULD P POOH and stand back 33 stands 4" D. P. with Sliders and install 1-Lo Tad per stand, Stand back 7 stands 4" HWDP. 03:15 03:45 0.50 0 0 INTRM1 DRILL PULD P Clear & Clean rig floor. 03:45 07:00 3.25 0 0 INTRM1 DRILL PULD P Rig & Pick up 15 stands Hybrid Push Pipe (2-jts 4-3/4" Spiral DC's & 1-jt HWDP), POOH and stand back 15 stands Push Pi e. 07:00 10:45 3.75 0 360 INTRM1 DRILL PULD P PJSM, Pick up BHA #4 - 6-3/4" Bit #3, 4-3/4" 5200 Geo Pilot, MWD tools, Stab's, Flex collars & HWDP, Break in Geo Pilot. 10:45 12:30 1.75 360 2,160 INTRM1 DRILL TRIP P Pick up 60 jts 4" Drill pipe from pipe shed. 12:30 15:00 2.50 2,160 7,803 INTRM1 DRILL TRIP P RIH w/ pipe from derrick to 7,790', Screw into top dive, Pump down and to float collar 7,803'- OK. 15:00 15:30 0.50 7,803 7,803 INTRM1 DRILL CIRC P Circ Btm's up for 7-5/8" Casing test. 15:30 16:45 1.25 7,803 7,803 INTRM1 RIGMN SVRG P Cut & Slip drilling line 86', Service top drive & Drawworks, Check saver sub. 16:45 17:45 1.00 7,803 7,803 INTRMI DRILL DHEQ P Rig & Test 7-5/8" Casing to 3000 psi for 30 min.- OK. 17:45 20:00 2.25 7,803 7,920 INTRM1 CEME~ DRLG P Drill out float collar @ 7,803', Cement & Shoe 7,894', 20:00 20:15 0.25 7,900 7,920 INTRM1 DRILL DDRL P Drill 20' new hole to 7920' MD / 3,651' TVD. 20:15 21:00 0.75 7,920 7,920 INTRMI DRILL LOT P Rig & perform LOT with 8.7 ppg mud, 3650' TVD, 1184 si = 14,9 EMW. 21:00 00:00 3.00 7,920 8,270 PROD1 DRILL DDRL P Drill ahead with Sperry-Sun Geo Pilot f/ 7,920' to 8,270' MD / 3,668' TVD, ADT= 1.71 hrs., WOB 7-8K, RPM 110, 300 gpm @ 2650 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max as 62 units, Ave ECD's 10.2 06/05/2006 00:00 00:30 0.50 8,270 8,367 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,270' to 8,367' MD (97'), ADT= .56 hrs., WOB 5-7K, RPM 120, 306 gpm @ 2600 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 _' ~~~e ~ ~~ ~7 ', Time Loys - -- Date From To Dur 5 Epth E. Depth Phase CocJe Subcode ON1 06/05/2006 00:30 02:30 2.00 8,367 8,367 PROD1 DRILL WOOR NP Circ at rate f/ Geologist to evaluate to s with Anchora e. 02:30 03:45 1.25 8,367 8,514 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,367' to 8,514' MD (147'), ADT= .56 hrs., WOB 12-15K, RPM 100, 270 gpm @ 2250 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 03:45 04:30 0.75 8,514 8,514 PROD1 DRILL REAM NP Evaluate for Geologist -Back ream f/ 8,514' to 8,365' for possible Sidetrack - . Chan a of Ian & Return to Btm. 04:30 10:45 6.25 8,514 9,281 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,514' to 9,281' MD / 3,634' TVD (76T), ADT= .4.53 hrs., WOB 8-12K, RPM 130, 313 gpm @ 2875 psi, Up 135K, Dn 52K, Rot 86K, Tq on 6.5K/7K off, Max gas 132 units, Ave ECD's 10.7 10:45 12:15 1.50 9,281 7,887 PROD1 STK TRIP NP Monitor well- OK, POOH on elevators to 7,887' for SideTrack. 12:15 13:00 0.75 7,887 7,940 PROD1 STK KOST NP Orient Geo Pilot & Trench f/ 7,887' to 7,940'. 13:00 16:30 3.50 7,940 7,990 PROD1 STK KOST NP Time drill f/ 7,940' to 7,990', ADT= 2.0 hrs w/ 100 RPM 300 m 2600 si. 16:30 00:00 7.50 7,990 8,657 PROD1 DRILL DDRL NP Drill w/ Geo Pilot f/ 7,990 to 8,657' MD / 3,652' TVD (3,652'), ADT= 6.18 hrs., WOB 5-12K, RPM 130, 313 gpm @ 2600 psi, Up 130K, Dn 65K, Rot 84K, Tq on 6K/6K off, Max gas 144 units, Ave ECD's 10.3 06/06/2006 00:00 05:30 5.50 8,657 9,206 PROD1 DRILL DDRL NP Drlg f/ 8657' to 9206'MD / 3650' TVD ADT= 5.34 hrs, PU wt 138k, SO wt 55k, Rot wt 85k, Troq on bttm 7k, off bttm 7.5k 05:30 06:00 0.50 9,206 9,206 PROD1 DRILL CIRC NP Circu -Geologist evaluate logs 06:00 12:00 6.00 9,206 9,875 PROD1 DRILL DDRL P Drlg f/ 9206' to 9875' MD ADT 3.48 - Pumped WUHiVis sweep @ 9527 MD with NO % increase in cuttings. Up wt and Dn wt showing large increases on T&G model. Rig engineer checking all. data to make sure it is correct. PU wt 150k, SO wt Ok, Torq off bttm 7k, on bttm 7k, MAx Gas 102, ECDs 10.88, Jar hrs. total 99.65 12:00 13:30 1.50 9,875 10,159 PROD1 DRILL DDRL P Drlg f/ 9875' to 10,159' MD / 3646' TVD - PU wt 165k, SO wt Ok, Rot wt 84k, Torq on bttm 7k, off bttm 7k -ADT 1.15 hrs 13:30 13:45 0.25 10,159 10,159 PROD1 DRILL CIRC T Circu - MWD computer reboot- Locked u 13:45 15:30 1.75 10,159 10,397 PROD1 DRILL DDRL P Drlg f/ 10,159' to 10,397' MD / 3646' TVD. ECDs Model still showed T&D with large increases on Up wt and NO do wt. Decission was made to make wiper trip to the shoe to evaluate hole conditions. .~ ____.~ P~y~ ~~s~~ 2? _ ~ ~ Time Loc,~s___ _ Date __ From 10 Dur~ . Depth E. pepth Phase Code Subcode ~ QOM 06/06/2006 15:30 15:45 0.25 10,397 10,397 PROD1 DRILL CIRC P Circu- Pump sweep & condition hole for wi er tri -Zero toolface on GeoPilot 15:45 19:00 3.25 10,397 7,894 PROD1 DRILL REAM P Wiper Trip - BROOH f/ 10,397' MD to 7894' MD(7.625" shoe) PR 310 GPM, RPMs 85 - No roblems seen. 19:00 20:15 1.25 7,894 7,894 PROD1 DRILL CIRC P Pump 30 bbl WUHiVis sweep -Rot & Recip string - PR 310 gpm, RPMs 85- Sweep to surface saw 5% increase in cutting. Up wt 170k, Dn wt 70k in casin . 20:15 20:45 0.50 7,894 7,940 PROD1 DRILL TRIP P TIH -Pump down 3 stds -orient tool thru kick off area @ 7940' -Entered new well bore without an roblems. 20:45 21:45 1.00 7,940 10,111 PROD1 DRILL TRIP P TIH on elevators to 10,111' 21:45 22:15 0.50 10,111 10,396 PROD1 DRILL REAM P Wash & Ream 10,111' to 10,396' MD - PR 310 m, RPMs 80, PP 2800 si 22:15 00:00 1.75 10,397 10,558 PROD1 DRILL DDRL P Top Drive up @ Std #106, Orient Geo Pilot, Drlg f/ 10,397' to 10,558' MD / 3649' TVD - PR 310 gpm, PP 3000 psi, RPMs 125, WOB 6-8k, Torq 7k on bttm. ADT= .76 06/07/2006 00:00 00:30 0.50 10,558 10,558 PROD1 DRILL CIRC T Made several attempts to get GeoPilot to respond to signal - No responce - Monitorwell -Static 00:30 02:00 1.50 10,558 7,870 PROD1 DRILL TRIP T POOH on elevators 10,558' to 7870' MD with no roblems 02:00 02:30 0.50 7,870 7,780 PROD1 DRILL OWFF T Observe well for flow -Pump dry job 02:30 05:00 2.50 7,780 360 PROD1 DRILL TRIP T POOH on elevators 7,870' to 360'. Displ for trip =actual 66 bbls, calculated 60.2 05:00 05:30 0.50 360 90 PROD1 DRILL TRIP T Stand back 2 stds HWDP w/Jars and 1 std NMFDCs 05:30 06:00 0.50 90 90 PROD1 DRILL SRVY T Down Load MWD 06:00 07:.00 1.00 0 0 PROD1 DRILL PULD T UD BHA #4 - FS, Stab, MWD, Smart Sub, DM, NM Geo flex, Geopilot & bit.. Bit looks good -grade 1 -1 will run back. 07:00 07:45 0.75 0 90 PROD1 DRILL PULD T PU & MU BHA #5 -GeoPilot, Bit, NM Geo Flex, DM, Smart Stb &MWD 07:45 08:30 0.75 90 90 PROD1 DRILL SRVY T Up Load MWD 08:30 09:15 0.75 90 360 PROD1 DRILL PULD T Con't MU BHA#5 - PU FS, Stab, 1 std NMFDCs, 2 stds HWDP w/jars - Break in GeoPilot bearings -Shallow test MWD 80SPM = 1200 psi -good Ulse. 09:15 12:00 2.75 360 7,403 PROD1 DRILL TRIP T TIH on elevators f/ 360' to 7,403' MD , U wt 110k, Dn wt 70k 12:00 13:30 1.50 7,403 9,020 PROD1 DRILL TRIP T TIH on elevators f /.7,403' to 9,020' Floor crew doing visual check on WWT SS and Lo Tads on trip in) observed no problems. @ 9020' encountered tight hole, No SO wt. ~__~_ -- Time Low Date From To Dur ~e th E De th Phase Code Subcode -I ~.OM 06/07/200613:30 17:00 3.50 9,020 10,558 PROD1 DRILL REAM T Wash & Ream f/ 9020' to 10,558' MD . PR 300 gpm, 50 RPMs, Torq on bttm 7-8k, PP 2700 si, 17:00 17:15 0.25 10,558 10,558 PROD1 DRILL SRVY T Orient and Set Tool deflection 17:15 00:00 6.75 10,558 11,168 PROD1 DRILL DDRL P Drlg f/ 10,558' to 11,168' MD / 3660' TVD, PR 310 gpm, RPMs 120, PP 3000 psi, WOB 7-9k, Stage up ROP timed out to clean hole from 100 - 125 fph PU wt 160 k/, SO wt 0 k, Rot wt 84 k Torq on bttm 6 k, off bttm 7 k Max gas 80 units, ECDs 10.92ppg Total jar hrs 107.34 @ Midnight - 99 WWT SS & 50 Lo Tads in hole. 06/08/2006 00:00 08:00 8.00 11,168 11,915 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ Geo Pilot f/ 11,168' - 11,915' MD / 3667' TVD, ADT 5.93 hrs, PR 310 gpm, PP 3100, RPMs 130, WOB 5-14 k, *** Geologist reported they had deflected out of zone*** 08:00 09:00 1.00 11,915 11,267 PROD1 DRILL REAM T BROOH for Side Track t/ 11,267' MD , FR 300. m, RPMs 110, Tor 7 k 09:00 10:00 1.00 11,267 11,280 PROD1 DRILL KOST T Set Up for side track, Trench f/ 11,267' to 11,280' MD / 3656' TVD, PP 2900 si, RPMs, Tor 7 k 10:00 12:00 2.00 11,280 11,284 PROD1 DRILL KOST T Time drlg for sidetrack. f/ 11,280' to 11,284' MD ADT 1.37 hrs # of T&D tools in hole, 99 WWT SS and 50 4" Lo Tads @11,915'MDPUwt154k,SOwtOk, Rot wt 85k, Tor on bttm 7 k, off bttm 8.5 k 12:00 14:30 2.50 11,284 11,304 PROD1 DRILL KOST T Con't Time drlg f/ 11,284' to 11,304' *** Departure Point 11, 285' MD / 3656.69' TVD 14:30 16:00 1.50 11,304 11,358 PROD1 DRILL DDRL T Drlg 6 3/4" hole w/Geo Pilot f/ 11,304' MD to 11,358' MD. Pump 35 Bbl wt/hi-vis sweep while drilling ahead @ 11,358' MD. 250 gpm, 2750 psi, 120 rpm, and 80-90 fph until sweep past MWD tool (1500 stks), then increase rate to 310 gpm, 3000 psi, 125-135 fph, 130 rpm ... sweep brought back 20% increase in cuttin s. 16:00 21:45 5.75 11,358 11,915 PROD1 DRILL DDRL T Drlg 6-314" hole w/ Geo-Pilot f/ 11,358' MD to 11915' MD. SPR @ 12,006' MD, 3673' TVD, MW = 8.7+, MP#1 25 spm = 660 psi, @ 35 spm = 830 psi, MP#2 @ 25 spm = 660 psi, @ 35 s m = 830 si ~_. v.~. ~~ .~ ~ ae 1 ~ ~rf ~' __ T mi e Logs _ Date From To Dur 5,__ epth E. Depth Phase Code Subco~ie T ~~M - - - - - - - - 06/08/2006 21:45 00:00 2.25 11,915 12,006 PROD1 DRILL DDRL P Drlg 6-3l4" hole w/ Geo-Pilot f! 11,915' MD to 12,006' MD (3,673' TVD). ADT = 8.81, PU = 165, SO = 0, Rot wt = 84, TQ On = 8k, TQ Off = 9k, Max Gas = 110 units, ECD = 11.34, Jar Hrs = 123.45. #/Lo-TADs in Hoie = 50, Su er-Sliders = 99 06/09/2006 00:00 05:00 5.00 12,006 12,479 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ GeoPliot f/ 12,006' to 12,479' MD / 3703' TVD,= "A" Lat TD - ADT 4.19 hrs PU wt 170k, SO wt 0 k, Rot wt 90k, Torq 8 k, MAx gas 69 units, ECDs 11.42 ppg, Jar Hrs 127.64 PR 310 gpm, PP 3200 psi, RPMs 120-130 05:00 06:15 1.25 12,479 12,479 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep on last stand down -Circu BU 06:15 06:30 0.25 12,479 12,479 PROD1 DRILL OWFF P Record SPR -Observe Well- Static 06:30 12:00 5.50 12,479 8,757 PROD1 DRILL TRIP P BROOH f/ 12,479' to 8757' MD. FR 310 gpm, RPMs 120. Pull slow and steady +/- 45 fpm. No problems encounted. 12:00 13:00 1.00 8,757 7,790 PROD1 DRILL TRIP P PJSM- Con't BROOH f/ 8757' to 7790' MD. PR 310 gpm, RPMs 120. Slowed to 100 RPMs at shoe. 13:00 14:00 1.00 7,790 7,790 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep -Circu and recip csg until clean, PR 310 gpm, RPMs 100, Recip 90'- 0% excess cuttin on BU 14:00 18:00 4.00 7,790 12,479 PROD1 DRILL TRIP P RIH- Fill DP every 2000' -Tight @ 10,720' -Break crcu and PD f/ 10,691' to 10,788'. Con't RIH to Bttm with no problems on elevators. Wash & Ream 12,372' to 12,479' - PU wt 170k, SO wt 45k, Rot wt 85k 18:00 20:00 2.00 12,479 12,479 PROD1 DRILL CIRC P Pump sweep -Circu & Condition hole PR 310 gpm, RPMs 120, Recip DP 90' - Circu until clean at shakers. 20:00 21:00 1.00 12,479 12,479 PROD1 DRILL CIRC P Change out to SFOBM -Displace to SFOBM from 12,479' to 6600' (200' above B lat window) -Last 20 bbls dis lacement is d 'ob. 21:00 00:00 3.00 12,479 8,885 PROD1 DRILL TRIP P POOH - SLM - Ck and Servive WWT SS. Sliders were moved do one space for wear protection to pipe. Had to re lace 1 element sleeve. 06/10/2006 00:00 01:30 1.50 9,144 7,887 PROD1 DRILL TRIP P Con't TOH f/ 9144' MD to 7887' MD - WWT SS were inspected and move down 1 position to minimize pipe ex osure to wear. 01:30 01:45 0.25 7,887 7,887 PROD1 DRILL SFTY P Observe well at 7-5/8" csg shoe - STATIC ~.Q ~ ~~~~ ~'I - - - - Time Lis - - __ _ - - - --- -- - - - - - _ -- - - -- 1 Date From To Dur S Depth E. Depth - - Phase Code Subcode T - QOM - __ 06!10/2006 01:45 04:15 2.50 7,887 6,243 PROD1 DRILL TRIP P Con't TOH f/ 7887 to 6243' MD WWT SS were inspected and moved down 1 position to minimize pipe exposure to wear. -Replaced 1 bad sleeve due to wear. -Inspected total 90 WWT SS - All Lo Tads appeared to be in good shape -minimal wear. 50 total in strin . 04:15 06:15 2.00 6,243 360 PROD1 DRILL TRIP P Con't TOH f/ 6243' to 360' 06:15 06:45 0.50 360 360 PROD1 DRILL TRIP P BHA #5 -Stand back 2 std HWDP w/ 'ars and 1 std of NMFDCs 06:45 07:30 0.75 360 90 PROD1 DRILL SRVY P Down Load MWD - ** Note** Due to comm problem tool had to be laid down before data could be down loaded. After tool was LD in the shed the data was exstracted "OK" 07:30 08:15 0.75 90 0 PROD1 DRILL PULD P Con't LD BHA #5 - LD stab,NM Flt sub, TM HOC, PWD, SP 4 w/ Gm & Rec, Smart stab, DM HOC, NM sht DC, Geo- ilot 5200 Sr# 4 & bit 08:15 08:30 0.25 0 0 PROD1 DRILL PULD P Clear all tools from rig floor -Clean rig floor 08:30 09:15 0.75 0 0 PROD1 RIGMN SVRG P PJSM -Slip & Cut drill line (85.5' cut) 09:15 10:15 1.00 0 0 COMPZ CASIN( RURD P PJSM - RU to run 4.5" slotted liner 10:15 12:00 1.75 0 756 COMPZ CASIN( RUNL P Run 4.5" slotted liner in "A" lat per detail -Run 18 'ts. 12:00 14:30 2.50 756 5,550 COMPZ CASIN( RUNL P PJSM - Con't Run 4.5" slotted liner in "A" lat. per detail. Total jts ran 127, 68 jts slotted and 59 jts blank + 1 blank shoe 'oint. 14:30 16:00 1.50 5,550 5,590 COMPZ CASIN( PUTB P PU Liner Hanger Assy - 7.625' X 5.5" HRD ZXP LTP, RS packoff seal nipple, Flex Lock LH, 190-47 CSB Ext, XO bushing w/ 3.93" ID -See running detail for full data -Install PAL mix - RD Csg Tools & clear off all un-needed equip from rig floor. Up wt 77k, SO 60k, Rot wt 67k, Torq 2k 16:00 17:30 1.50 5,590 7,871 COMPZ CASIN( RUNL P TIH w/ Liner on DP to shoe -Fill DP @ 7871' - Up wt 100k, SO wt 65k, Rot wt 78k, Tor 3k 17:30 22:00 4.50 7,871 12,470 COMPZ CASIN( RUNL P. TIH f/ 7871' to 12,470' -Had to rotate thru several spots, @ 10,045', 10,330', 10,830' 11,080', 11,180', 11,595', 11,614'. 50 RPMs, Max torq seen 8 k. @ 12,470 = UP wt 180k, SO wt 70k - Brk circu. 22:00 22:30 0.50 12,470 12,470 COMPZ CASIN( CIRC P Drop & Circu setting ball to seat. - PR 3 bpm, 550 psi, Slow to 2 bpm for last 500 stks. Ball on seat - - -- -- a'~ge ~~ ~~ ~7 ~ Time Logs - Date From _ To Dur ~e th E. De th Phase Code Subcode i,OM _ _ 06/10/2006 22:30 00:00 1.50 12,470 12,470 COMPZ CASIN( RUNL P Ball on seat -Pressure up to 1800 psi, Set liner hanger, apply do wt 20k, Increase pressure to 3000 psi to set packer, Pressure test packer do back side to 1000 psi on chart and hold for 10 min. "OK" Pick up and expose dog sub. Apply do wt w/dog sub to confirm liner set. "OK" Top of Liner @ 6931' MD, 06/11/2006 00:00 02:00 2.00 6,990 0 COMPZ CASIN( RUNL P TOH f/ 6990' with liner setting tool - Hole fill Calcu 55 bbls, Actual 61 bbls - Settin tool all com lete. Worked well 02:00 02:45 0.75 0 0 COMPZ CASIN( RUNL P Service Brk & UD Baker Liner running tool 02:45 03:15 0.50 0 0 COMPZ RIGMN SVRG P Service Rig and Top Drive 03:15 03:45 0.50 0 0 COMPZ CASIN( RURD P Clear all tools from rig floor and clean u work area. 03:45 05:30 1.75 0 0 COMPZ EVALVI~ RURD P RU Schlumberger wire line to run CBL on 7.625" interm. 05:30 06:30 1.00 0 0 COMPZ EVALV~ RURD P PU wireline tools from unit to rig floor. RU sheave 06:30 07:30 1.00 0 0 COMPZ EVALVI~ PULD T Trouble shoot wireline tractor, 07:30 12:00 4.50 0 0 COMPZ EVALVI~ ELOG P Start in hole with USIT CBL logging tools. Ran to 5940' (76.4*) without tractor. Tractor in f/ 5940' to 6915' MD- Lo u 1400 ft/hr noon 4400' 12:00 13:30 1.50 0 0 COMPZ EVALV~ ELOG P Con't logging up from 4400' to 2950'. Cmt appears good up to 3700'. And diminishes from there to 3050' MD. 13:30 14:30 1.00 0 0 COMPZ EVAL1l~ PULD P LD wireline tools - RD Logging unit and tools 14:30 16:30 2.00 0 0 PROD2 DRILL PULD P PJSM - PU Mill and Whipstock assy. Usin 35k shear bolt. 16:30 17:00 0.50 0 0 PROD2 DRILL SRVY P PU Super Slim MWD and orient to WS. PU Bum er sub 17:00 18:00 1.00 0 0 PROD2 DRILL SRVY P Up Load program MWD 18:00 18:30 0.50 0 210 PROD2 DRILL TRIP P TIH w/ 2 stds Hybrid push pipe & shallow pulse test @ 393' MD, 6 bpm, 850 si "OK" 18:30 19:00 0.50 210 1,651 PROD2 DRILL TRIP P Con't TIH with whipstock assy to 1651' 19:00 19:30 0.50 1,651 1,651 PROD2 DRILL PULD NP CO 2 joints of 4" DP with galled threads 19:30 21:30 2.00 1,651 5,430 PROD2 DRILL TRIP P Con't TIH 5430' (fill pipe @ 3394' & break circu 5430' 21:30 22:15 0.75 5,430 5,520 PROD2 DRILL SRVY P MADD pass f/ 5430' to 5520' for tie in of K-13 logs assuring proper depth. Orient TF to 10-15*L) during this rocess 22:15 23:00 0.75 5,520 6,894 PROD2 DRILL TRIP P Con't TIH to 6863' PU single to space Kelly to mill window. Up wt 144k, SO wt 87k ~~~ ~ ~ ~, 'I~ 0~~7 'Time Logs Dafe From To Dur . Je th E De th Phase Code Subcode i COM _ 06/11/2006 23:00 00:00 1.00 6,894 6,931 PROD2 DRILL MILL P Orient & Set Whipstock @ 7* Left - Good indication of positive shear. No Go tagged up on depth @6931' MD After shear window starter mill @ 6826' TOW 06/12/2006 00:00 10:00 10.00 6,826 6,855 PROD2 DRILL MILL P Mill window for "B" sand lat. TOW 6828' MD, Bttm OW 6842'. Full guage 6 3/4" hole to 6855'. UP wt 135k, DN wt 86k, Rot wt 100k, Tor 5-5.5k 10:00 10:15 0.25 6,855 6,855 PROD2 DRILL MILL P Work Mill thru window 3 times - No roblems or for noted. 10:15 11:15 1.00 6,855 6,855 PROD2 DRILL CIRC P Pump Wt/ Hi Vis sweep to recover and clean out metal cuttings - 250 gpm, 1900 psi, 50 rpms. Noted very good recove ma nets. 11:15 12:00. 0.75 6,855. 6,855 PROD2 DRILL CIRC P Flow ck well -Pump dry job - Blow do to drive 12:00 12:15 0.25 6,855 6,855 PROD2 DRILL SFTY P PJSM -Discuss TOH and all expected hazards 12:15 14:30 2.25 6,855 6,855 PROD2 DRILL TRIP P TOOH w/ Milling assy - UD bumper sub 14:30 15:00 0.50 6,855 6,855 PROD2 DRILL SRVY P Dn Load MWD -Monitor well "Static" 15:00 16:00 1.00 6,855 6,855 PROD2 DRILL PULD P UD MWD & Milling assy. Mills look good. Top mill ck "Full Guage" -Clear tools from ri floor 16:00 16:30 0.50 6,855 6,855 PROD2 WELC7 BOPE P Set Test Plug -Fill BOPs and Choke Manifold w/ water - MU floor valves and test manifold 16:30 17:30 1.00 6,855 6,855 PROD2 WELCT BOPE P Pull wear bushing & flush stack with cleanin tool - UD tool -Drain stack 17:30 21:30 4.00 6,855 6,855 PROD2 WELCT BOPS P Test BOPs and Choke Manifold -Test all components 250 psi Low and 3000 psi High. Make sure complete test is charted. All components tested good. See BOP test sheet for detail. Pull test plug. Install wear bushing - UD all testin tools and clear floor. 21:30 22:45 1.25 6,855 6,855 PROD2 DRILL PULD P PU BHA # 7 w/ Geo Pilot per Sperry Sun detail w/ MDW.""* Note"** We are running the new Baker/Hughes HCR - 5052 box u bit. 22:45 23:30 0.75 6,855 PROD2 DRILL SRVY P Program MWD -Monitor well (Static) 23:30 00:00 0.50 PROD2 DRILL TRIP P PU Flt sub - TIH w/ BHA #7 06/13/2006 00:00 00:15 0.25 PROD2 DRILL SFTY P . PJSM for Trip in hole, Discussed Hazzards & Communication with all. hands. 00:15 00:45 0.50 PROD2 DRILL DHEO P Break in Geo Pilot bearings, Surface test MWD &Geo Pilot "Geo Pilot Failed". 00:45 02:30 1.75 60 PROD2 DRILL PULD T POOH, Down load MWD, Break bit, Lay down Geo Pilot, Pick up new Geo Pilot, Make u bit, U load MWD. <'~g ~ ~1 ~ ~>f `,.~~i ____ ~ A~ ~ - - _ _ - _-_ Time Logs _ -- - - - i - __. -- Date From _ To D__ur _ . ~~e th E De th Phase Code Subcod_e _ COM _ 06/13/2006 02:30 03:00 0.50 60 453 PROD2 DRILL DHEQ T RIH to 453', Break in Geo Pilot bearings, Shallow test MWD tools - OK 03:00 05:00 2.00 453 6,736 PROD2 DRILL TRIP P RIH f/ 453' to 6,736' (Filled pipe @ 2695', 5028' 05:00 05:15 0.25 6,736 6,864 PROD2 DRILL REAM P Run thru window @ 6,828', Ream down to 6,864' w/ 264 gpm @ 1900 si, 60 RPM, TQ 6K. 05:15 05:30 0.25 6,864 6,864 PROD2 DRILL SFTY P PJSM on Drilling and Making connections. 05:30 12:00 6.50 6,864 7,217 PROD2 DRILL DDRL P Drill f/ 6,864' to 7,217' MD 3,505' ND (353'), ADT= 4.82 hrs, WOB 8/12K, RPM 120, Up 125K, Dn 60K, Rot 84K, Tq 6K on / 6K Off, Max gas 48 units, ECD's 10.2 ppg, Concretions 6916', 6923', 6941', 6944'. 12:00 12:15 0.25 7,217 7,217 PROD2 DRILL SFTY P Held PJSM with crew on Making connections and Pinch oints 12:15 00:00 11.75 7,217 8,667 PROD2 DRILL DDRL P Drill f/ 7,217' to 8,667' MD 3,510' ND (1,450'), ADT= 8.84 hrs, WOB 10/12K, RPM 120, Up 135K, Dn 60K, Rot 85K, Tq 6-7K on / 6K Off, Max gas 92 units, ECD's 10.9 ppg, Concretions 8068'-8081', 8083'-8089', 8206'-8215', 8628'-8634'. 06/14/2006 00:00 00:15 0.25 8,667 8,667 PROD2 DRILL SFTY P Held PJSM with crew on hazard reco nition of tasks. 00:15 09:00 8.75 8,667 9,440 PROD2 DRILL DDRL P Drill f/ 8,667' to 9,440' MD 3,515' ND (773'), ADT= 10.31 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 54K, Rot 84K, Tq 7K on ! 8K Off, Max gas 125 units, ECD's 10.9 09:00 09:30 0.50 9,440 9,440 PROD2 DRILL CIRC T Circ hole clean for trip due to ROP Dro and unable to build an le. 09:30 11:30 2.00 9,440 7,219 PROD2 DRILL TRIP T Monitor well, POOH on elevators f/ 9,440' to 7,219' -Began pulling 25K over. 11:30 12:00 0.50 7,219 7,122 PROD2 DRILL REAM T Back Ream out of hole f/ 7,219' to 7,122' w/ 313 gpm @ 2300 psi & 120 RPM. 12:00 12:15 0.25 7,122 7,122 PROD2 DRILL SFTY T PJSM with crew on back reaming out of hole and related hazards. 12:15 12:30 0.25 7,122 6,760 PROD2 DRILL REAM T Back Ream out of hole f/ 7,122' to 6,929' w/ 313 gpm @ 2300 psi & 120 RPM, Pull to 6,760' thru window @ 6,828'-OK, Pum d 'ob. 12:30 14:30 2.00 6,760 30 PROD2 DRILL TRIP T POOH, Stand back BHA, Break Bit, Monitor well- OK. Note; Found Bit to have rin ed out in nose row. 14:30 15:00 0.50 30 30 PROD2 DRILL TRIP T Down load MWD tools. 15:00 15:30 0.50 30 30 PROD2 DRILL PULD T Change out GeoPilot & Make up Bit #5. 15:30 16:30 1.00 30 30 PROD2 DRILL TRIP T Program MWD tools, Change out float. __ ~ ---~_~ _~a ~~~~e 'I ~ ~a~ ~7 _ ~- -- __ _ - __ -_ _ _ - _ -- Time Logs Date F~grn_ To Dur 5 ep__th E. Depth Phase Code Subcode T OIv1 _ ' - - _ -- - - 06/14/2006 16:30 17:00 0.50 30 539 PROD2 DRILL TRIP T RIH w/ BHA to 539', Break in GeoPilot bearin s & Shallow test Tools- OK. 17:00 22:30 5.50 539 9,440 PROD2 DRILL TRIP T RIH to 6,960' (Filled pipe @ 3161' & 6736'), RIH to 9,440' - Wash & Reamed bridges @ 6960' to 7015', 7460' to 7510', 7606' to 7992', 8186' to 8282', 8863' to 9440'- Reamed w/ 300 m & 120 RPM. 22:30 00:00 .1.50 9,440 9,590 PROD2 DRILL DDRL P Drill f/ 9,440' to 9,590' MD 3,505' TVD (150'), ADT= 1.00 hrs, WOB 8/12K, RPM 130, 310 gpm @ 2950 psi, Up 140K, Dn 54K, Rot 82K, Tq 6K on / 6K Off, Max gas 51 units, ECD's 11.1 06/15/2006 00:00 00:15 0.25 9,590 9,590 PROD2 DRILL SFTY P PJSM., Discussed hazard assessment of tasks. 00:15 12:00 11.75 9,590 10,315 PROD2 DRILL DDRL P Drill f/ 9,590' to 10,315' MD 3,501' TVD (725'), ADT= 9.21 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 50K, Rot 80K, Tq 7K on / 6K Off, Max gas 88 units, ECD's 10.75 ppg, Concretions= 9888'-9902', 9986'-10000', 10008'-10021', 10043'-10050', 10055'-10063', 10066'-10070', 10082'-10092', 10288'-10300', 10311'-10315'. 12:00 12:15 0.25 10,315 10,315 PROD2 DRILL SFTY P PJSM for Drlg ahead/Hazard reco nition 12:15 00:00 11.75 10,315 11,462 PROD2 DRILL DDRL P Drill f/ 10,315" to 11,462' MD 3,514' TVD (1,147'), ADT= 8.47 hrs, WOB 8/14K, RPM 130, 310 gpm @ 3,000 psi, Up 145K, Dn 40K, Rot 85K, Tq 7.5K on / 7K Off, Max gas 151 units, ECD's 11.42 ppg, Concretions= 10,450' - 10,455 - 10,898' - 10,902' - 10,908' - 10,910' - 10,915' - 10,918' - 10,929' - 10,934' - 11,060' - 11,066' - 11,196' - 11,205'. Total concretion foots e = 34' 06/16/2006 00:00 12:00 12.00 11,462 12,602 PROD2 DRILL DDRL P Drill 6-3/4" hole from 11,462'- 12,602' MD (3,552' tvd). ADT = 8.82 hrs. Pump 30 bbl hi-vis sweep at 12,561'. Concretions at 11,593 - 595', 11,870 - 872', 11,954-956', 12,030-038',12,193-207'. Total daily foots a of concretion drl = 28'. 12:00 12:15 0.25 12,602 12,602 PROD2 DRILL SFTY P PJSM for BROOH. 12:15 13:00 0.75 12,602 12,602 PROD2 DRILL CIRC P Circ sweep out at 310 GPM and 125 rpm, while reciprocating, with 5 excess cuttings. Survey. Monitor well - static. 13:00 20:30 7.50 12,602 6,736 PROD2 DRILL REAM P BROOH from 12,602' - 7,026'. POOH to inside of 7-5/8" csg to 6,736'. Monitor well -static. .~ _ .~ ~~ ~~~ ~ .7 ~i 27 - -_ - _-- --- -- - - Time Loc,~s - - -- - -- _--- Date ___ From To Dur S_ epth E Depth Phase _ Code Subcode T COM 06/16/2006 20:30 22:45 2.25 6,736 6,639 PROD2 DRILL CIRC P Pump 35 bbl Hi-Vis sweep. CBU 3x at 310 GPM and 80 rpm, while reci rcatin i e from 6,736-6,639'. 22:45 00:00 1.25 6,736 6,639 PROD2 DRILL OTHR P Cut and slip 70' of drill line. 06/17/2006 00:00 01:15 1.25 6,639 6,639 PROD2 DRILL OTHR P Change out Top Drive Saver sub. 01:15 03:00 1.75 6,639 9,733 PROD2 DRILL TRIP P RIH to 9,733' until ran out of down wei ht. 03:00 06:45 3.75 9,733 12,602 PROD2 DRILL REAM P Rotate at 90 rpm and wash in hole to 12,602' with 300 GPM, 2,700 psi and 7K ft-Ib of for ue. 06:45 08:30 1.75 12,602 12,602 PROD2 DRILL CIRC P Rack back stand in derrick and PU single jt from shed. Pump 30 bbl weighted Hi-Vis sweep at 12,591' with 130 rpm, 300 GPM, 3,200 psi, and 8,000 ft-Ib TO: Increase in returns of 15%. 08:30 09:15 0.75 12,602 12,602 PROD2 DRILL CIRC P Displace B-Lateral hole to 8.7 ppg, 60/40 SFMOBM with 281 bbl, while rotating at 130 rpm, with 300 GPM and 7,500 ft-Ib of TQ. 09:15 12:00 2.75 12,602 8,379 PROD2 DRILL TRIP P Monitor well -static. Pump dry job. LD single. PU=165K, S0=0. POOH to 8,379' with hole takin ro er fill. 12:00 12:15 0.25 8,379 8,379 PROD2 DRILL SFTY P PJSM for POOH and LD BHA 12:15 14:30 2.25 8,379 359 PROD2 DRILL TRIP P Continue to POOH to HWDP at 359' (15K overpull at 6,830'). Monitor well - static. 14:30 15:00 0.50 359 0 PROD2 DRILL PULD P Flush MWD tools with 15 bbl of new LVT base mineral oil and stand back in derrick. 15:00 16:00 1.00 0 0 PROD2 DRILL PULD P Download MWD. 16:00 16:30 0.50 0 0 PROD2 DRILL PULD P Break bit, LD Geo-Pilot and MWD. Clear ri floor. 16:30 17:30 1.00 0 0 COMPZ DRILL PULD P PU/MU whipstock retrieving assembly. 17:30 20:00 2.50 0 6,791 COMPZ DRILL TRIP P RIH filling DP at 3,282'. Continue RIH to 6,791'. PU=130K, S0=70K. Break ci rc. 20:00 21:00 1.00 6,791 6,740 COMPZ DRILL OTHR P Wash and latch onto whipstock at 6,833'. Work and jar free. Maximum overpull = 85K (PU=215K). Jar free with PU=195K. POOH one stand to 6,740' with PU=140K. 21:00 22:00 1.00 6,740 6,740 COMPZ DRILL CIRC P Circ bottoms up with max gas = 41 units. Monitor well -static. Pum slu . 22:00 00:00 2.00 6,740 2,280 COMPZ DRILL TRIP P POOH 06/18/2006 00:00 01.:00 1.00 2,280 60 COMPZ DRILL TRIP P Continue POOH 60' with whipstock. 01:00 03:00 2.00 60 0 COMPZ DRILL PULD P LD BHA, whipstock and trip anchor, with No-Go seal assembl . ( _ _ _ Time Logs __ - - ---- Date From To Dur S. _ e_pth__E._ Depth Phase Code__ Subcode T ___ _ - OM_ 06/18/2006 03:00 03:30 0.50 0 0 COMPZ CASIN( RURD P Clear and clean rig floor. RU casing eui. 03:30 03:45 0.25 0 0 COMPZ CASIN ( SFTY P PJSM for running 4-1/2" liner. 03:45 06:45 3.00 0 5,726 COMPZ CASIN ( RNCS P RIH with 132 joints R3, 4-1/2", 11.6 Ib/ft, L-80, BTC Blank/Slotted liner, with Hydroform centralizers on stop collars in the center of each joint. Tor ue rin s run in 'oints 55-132. 06:45 08:45 2.00 5,726 5,727 COMPZ CASIN( OTHR P MU liner swivel assembly, slimhole MWD, hook hanger and orient. PU = 75K, SO = 60K. 08:45 12:00 3.25 5,726 11,304 COMPZ CASIN< RUNL P RIH to 193' and shallow test MWD - good test. Continue RIH with liner and tag up on A-lateral at 6,976'. PU, orientate and pass through window on second attempt. RIH to 11,304'. PU=125K, S0=65K. 12:00 12:15 0.25 11,304 11,304 COMPZ CASIN( SFTY P PJSM for running liner. 12:15 13:00 0.75 11,304 12 COMPZ CASIN( RUNL P Continue RIH w/ liner to 12,465' (PU=160K, S0=40K). Broke circulation with 130 GPM at 1,200 si. 13:00 14:30 1.50 12,465 12,550 COMPZ CASIN( RUNL P Work liner to 12,560' with Hook 8' past window at 6,834'. PU, orient hook and work torque out of string. Set hook with all appearances of proper hook. PU with 35K in string weight loss. Shoe set at 12,550' and and TOL at 6,823' md. Monitor well -static. 14:30 17:30 3.00 12,550 0 COMPZ CASIN( RUNL P POOH with wet string. 17:30 18:30 1.00 0 0 COMPZ CASIN< OTHR P Pull and inspect liner running tool - okay. Clean rig floor. PU small handlin tools. 18:30 19:30 1.00 0 0 COMPZ CASINC RURD P LD running tool and MWD. LD handling tools. 19:30 20:00 0.50 0 30 COMPZ CASIN( PUTB T PU casing tools and seal assembly for Hook hanger verification run. RD casin tools. 20:00 23:30 3.50 30 6,748 COMPZ CASIN( OTHR T RIH with seal assembly to 6,748' (PU= 130K, S0= 75K . 23:30 00:00 0.50 6,748 6,823 COMPZ CASIN( OTHR T Tag top of liner at 6,822.77'. 06/19/2006 00:00 01:00 1.00 6,823 6,930 COMPZ CASINC OTHR T Tag top of liner at 6,822.77', Made 7 attempts to get inside TOL- No Good, Rotate at 10 RPM to get inside liner- . OK, RIH & Tag top of Hook Hanger @ 6,823' -OK w! Tail of seals 6,930'. 01:00 03:30 2.50 6,930 114 COMPZ CASIN( OTHR T POOH, pump dry job, continue POOH. 03:30 04:30 1.00 114 0 COMPZ CASINC OTHR T LD BHA for hanger verification run. 04:30 06:30 2.00 0 743 COMPZ CASINC PUTB P RU casing equipment, MU DB nipple, PU/MU LEM/ZXP assembl . 06:30 07:00 0.50 743 743 COMPZ CASIN( RURD P RD casing equipment. ~ ~_ age ~~ ~f ~7 ® ~ _- .~ ~ ~~d _ ~ !Time Logs - - --- - - - ~ Date From To__D__ur S. epth_ F Dept_h_ Phase Code Subcode T ON1 06/19/2006 07:00 10:00 3.00 743 6,973 COMPZ CASIN( RUNL P RIH and Stab into A-lateral seal bore recepticle to 6,973'. Top of liner at 6,491' All measurements on depth Up 127K, Dn 80K, Observed LEM latch into position (Set 30K down on LEM), Pull test LEM to 10K over- OK, Reset 30K down on LEM. 10:00 11:00 1.00 6,973 6,973 COMPZ CASIN( RNCS P Drop ball and pump down at 127 GPM, 600 psi. Ball went on seat at 520 strokes. Pump and stage up to 4,000 si. Set acker. 11:00 11:15 0.25 6,973 6,973 COMPZ CASIN( OTHR P Pressure test ZXP to 1,000 psi for 5 minutes. 11:15 12:00 0.75 6,973 6,500 COMPZ CASIN( CIRC P CBU at 6,500' at 254 GPM and 1,500 si max as = 28 units 12:00 12:15 0.25 6,500 6,500 COMPZ CASIN( SFTY P PJSM on POOH. Monitor well -static. 12:15 14:30 2.25 6,500 100 COMPZ CASIN( OTHR P POOH with running tools. 14:30 15:00 0.50 100 0 COMPZ CASIN( OTHR P LD running tools, clear rig floor. Monitor well -static. 15:00 15:30 0.50 0 0 PROD3 STK PULD P PU mills and whipstock. 15:30 17:00 1.50 0 150 PROD3 STK PULD P MU mills and whipstock assembly pinned with 35K shear bolt. PU/MU MWD and bum er sub. Orient MWD. 17:00 18:00 1.00 150 150 PROD3 STK OTHR P Upload MWD. 18:00 18:30 0.50 150 457 PROD3 STK TRIP P RIH to 457' and shallow pulse test MWD at 280 GPM and 900 si. 18:30 20:45 2.25 457 5,663 PROD3 STK TRIP P RIH w/ whipstock. Fill DP at 3,358'. Break circ at 5,663' 20:45 21:30 0.75 5,663 5,671 PROD3 STK OTHR P MAD pass across K-13 from 5,581'-5,671' md, and orient to 14 deg left. 21:30 21:45 0.25 5,671 6,437 PROD3 STK TRIP P RIH to 6,437'. PU 120K, S0= 78K. Break circulation. 21:45 22:30 0.75 6,437 6,410 PROD3 STK WPST P Orient whipstock to 20L, shear with 40K and set to at 6,409.5' tmd . 22:30 00:00 1.50 6,410 6,412 PROD3 STK MILL P Mill window 6,409.5 - 6,412' at 100 RPM, 235 GPM and torge = 4-6,000 ft-Ib. 06/20/2006 00:00 06:30 6.50 6,412 6,452 PROD3 STK MILL P Continue milling window from 6,412'-6,422' with 230 GPM, 1,650 psi and torque = 3-5,000 ft-Ib. Drill to 6,452' with 6-3/4" guaged hole to 6,442'. Work mills through window and dress off same. 06:30 09:00 2.50 6,452 92 PROD3 STK TRIP P Monitor well -static. POOH to 92'. 09:00 09:15 0.25 92 92 PROD3 STK PULD P LD BHA, XO and bumper sub 09:15 10:00 0.75 92 92 PROD3 STK OTHR P Download MWD. 10:00 10:30. 0.50 92 0 PROD3 STK PULD P Continue LD BHA, MWD, Mills. Upper f ull ua e 6-3/4" mill in ua e. __, Time Logs _---- - j Date From To Dur S. epth. E. Depth Phase Code Subcocle T 'OM 06/20/2006 10:30 11:00 0.50 0 0 PRODS STK OTHR P Clean and clear rig floor. 11:00 12:00 1.00 0 0 PRODS DRILL PULD P PU/MU Rotary steerable tools, collar and LD to ether. Flush stack. 12:00 13:00 1.00 0 0 PRODS DRILL SFTY P PJSM. Continue flushing stack. 13:00 13:45 0.75. 0 0 PRODS DRILL OTHR P Pull WB, flush stack, set WB and LD tools. 13:45 14:15 0.50 0 56 PRODS DRILL TRIP P RIH w/bit and Rotary steerable tools, flex collar. PU MWD. 14:15 15:15 1.00 56 88 PRODS DRILL OTHR P Upload MWD. Monitor well -static. 15:15 15:45 0.50 88 356 PRODS DRILL TRIP P RIH w/ BHA, break in bearings and shallow ulse test MWD. 15:45 17:30 1.75 356 6,325 PRODS DRILL TRIP P RIH filling DP at 3,159' and 6,325' 17:30 18:15 0.75 6,325 6,325 PRODS DRILL SFTY P PJSM. Cut and Slip 72' of drill line. 18:15 18:45 0.50 6,325 6,452 PRODS DRILL TRIP P RIH, pass thru window smoothly. Break circ at 6,429'. Ream from 6,429' - 6,452' with 90 rpm, 282 GPM, 2,000 si and 1-2,000 ft-Ib of for ue. 18:45 00:00 5.25 6,452 7,003 PRODS DRILL DDRL P Drill ahead from 6,452' 7,003' tmd (3,439' tvd). ADT = 3.75 hr. PU = 120K, S0= 60K ROT= 81 K, TQ on/off = 6K/5-6K. ECDs = 10.2 ppg, Max Gas = 63 units. Concretions @ 6,565-6,572', 6,597 - 6,601', 6,754 - 6,759'. Total = 16'. 06/21/2006 00:00 12:00 12.00 7,003 8,020 PRODS DRILL DDRL P Continue drilling 7,003 - 8,020' and (3,430' tvd). PU=130K, S0= 57K, ROT= 80K, TQ on/off = 6,000/7,000 ft-Ib, Press= 2,500 psi, ECD= 10.43 ppg, Max Gas = 109 units Concretions: 7,019-28', 7,037-39', 7,049-54', 7,130-136', 7,140-145', 7,159-167', 7,182-190', 7,214-216', 7,218-220', 7,242-255', 7,258-271', 7,308-320', 7,323-346', 7,405-410', 7514-517', 7,528-534', 7,598-602'. Total= 120'. 12:00 00:00 12.00 7,003 9,227 PRODS DRILL DDRL P Continue drilling 8,020 - 9,227' and (3,432' tvd). PU=145K, S0= 57K, ROT= 85K, TQ on/off = 6,500 ft-Ib, Press= 2,650 psi, ECD= 11.06 ppg, Max Gas = 92 units Concretions: 8,202-205', 8,258-280', 8,297-312', 8,405-420', 9,085-096', 9,122-129', 9,141-145' Total=81' 06/22/2006 00:00 12:00 12.00 9,227 10,427 PRODS DRILL DDRL P Drill 6-3/4" D-lateral from 9,227-10,427' tmd (3,429' tvd) PU= 145K, S0= OK, ROT= 80K, Torque on/off = 8,000/8,500 ft-Ib, Max Gas= 224 units, ECD= 112 ppg Concretions: 9,875-90', 9,943-48', 10,047-54', 10,210-214', 10,220-223'. Total: 34' m~ w ~_-___-___ _ a v~ ~m .~sa~e ~ i z~f ~~? ~_ ~ ~ _~ Time Logs __- j Date _ _ From To Dur S epth_ E De th Phase Code Subcode T - - ~M _ _~ - - - 06/22/2006 12:00 00:00 12.00 10,427 11,314 PROD3 DRILL DDRL P Drill ahead 6-3/4" D-lateral 10,427-11,314' tmd, (3,441' tvd) Concretions: 10,632-63T, 10,870-72', 11,135-138', 11,150-163', 11,188-210', 11,218-232', 11,240-252', 11,266-279', 11,284-292', 11,298-314', Total= 108' 06/23/2006 00:00 12:00 12.00 11,314 12,050 PROD3 DRILL DDRL P Drill 6-3/4" D-lateral 11,314-12,050' tmd (3,477 tvd). ART= 9.15 hr PU= 155K, S0= OK, ROT= 80K Torque On/Off = 9,000/9,000 ft-Ib Press= 3,050 psi, ECD= 11.45 ppg Max Gas= 132 units Concretions: 11,328-345', 11,348-357', 11,659-666', 11,681-693', 11,705-708', 11,775-778', 11,831-838', 11,847-850', 11,853-867', 11,902-913', 11,926-939' Total= 73' 12:00 18:30 6.50 12,050 12,678 PROD3 DRILL DDRL P Drill 6-3/4" D-lateral 12,050-12,678' tmd (3,484' tvd). ART= 5.19 hr PU= 170K, S0= OK, ROT= 85K Torque On/Off = 9,000/10,000 ft-Ib Press= 3,300 psi, ECD= 11.80 ppg Max Gas= 70 units Concretions: Total= 0 18:30 19:15 0.75 12,678 12,678 PROD3 DRILL CIRC P Circulate weighted Hi-Vis sweep at 310 GPM, 3,375 psi with a 20% increase in cuttings returns. Survey hole at TD. 19:15 19:30 0.25 12,678 12,647 PROD3 DRILL OWFF P LD single joint, monitor well -static. 19:30 00:00 4.50 12,647 10,294 PROD3 DRILL REAM P BROOH 12, 647-10,294' at 310 GPM, 3,150-3,000 psi, 100 RPM, and 40-45 ft/min. Average torque= 8,000 ft-Ib, PU=90K. Lost 9.7 bbl while BROOH. 06/24/2006 00:00 04:30 4.50 10,294 6,429 PROD3 DRILL REAM P Continue BROOH 10,294 - 6,429' at drilling rate. Pull thru window w/o roblems. PU= 120K, S0= 35K 04:30 06:30 2.00 6,429 6,336 PROD3 DRILL CIRC P Pull inside window to 6,336', pump 30 bbl weighted sweep plus 3 btms up at 300 GPM, 100 RPM, torque= 4-5,000 ft-Ib. 06:30 09:30 3.00 6,336 10,197 PROD3 DRILL TRIP P RiH. Slide through window without problems. RIH to 8,940 washing thru tight spot to 9,000'. Continue RIH to 10,197' where slackoff wt = 0. 09:30 12:00 2.50 10,197 10,918 PROD3 DRILL REAM P Wash and ream 10,197-918' at 305 GPM, 3,000 si and 100 RPM. 12:00 12:45 0.75 10,918 12,678 PROD3 DRILL REAM P Continue wash and reaming to TD at 12,678' tmd, at 305 GPM, 3,100 psi, 100 r m amd 4,000 ft-Ib. 12:45 14:15 1.50 12,678 12,678 PROD3 DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep at 275 - 310 GPM, 2,900-3,450 psi, 140 rpm with no increase in cuttings returns. 14:15 15:00 0.75 12,678 12,678 PROD3 DRILL CIRC P Displace open hole with 298 bbl of 60/40, 8.7 ppg, SFMOBM. Chase with OBM and d 'ob. ~~ ~ ~ ~ ~~qe ~ ~~ ~7 _ _._.__ ,~ ~a __._ _._ _ ._ .._ ~ .-.._.-.-.,-.-..,2_.R_. R _. . .Time Logs Date From To Dur 5. ~ e _th __~ E_ Depth Phase Code Subcode T p - - OM - - 06/24/2006 15:00 15:15 0.25 12,678 12,650 PROD3 DRILL PULD P LD single and flow check well -okay. 15:15 20:30 5.25 12,650 359 PROD3 DRILL TRIP P Drop rabbit and POOH on elevators. Inspect Lo-TADs and Super-Sliders. Calculated displacement 73.1 bbl, actual displacement 94.1 bbl. Pulled 30K over throw h ti ht s of at 9,005'. 20:30 21:30 1.00 359 60 PROD3 DRILL PULD P LD HWDP and collars in BHA. 21:30 00:00 2.50 60 60 PROD3 DRILL OTHR P Download MWD and LD same. Function tested Blind Rams. 06/25/2006 00:00 00:30 0.50 60 0 PROD3 DRILL PULD P Continue LD MWD and BHA. 00:30 01:00 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 01:00 01:45 0.75 0 0 COMPZ CASIN( RURD P RU 4-1/2" casing equip., hold PJSM 01:45 05:15 3.50 0 6,329 COMPZ CASIN( RUNL P RIH with 141 Jts of 4-1/2", 11.6 Ib/ft, L-80, BTC-M slotted /blank liner, with 6.125 x 4.5" Hydroform centralizers, free floatin . 05:15 06:00 0.75 6,329 6,359 COMPZ CASIN( CIRC P PU/MU seal bore receptacle, HR liner runnin tool and XO. 06:00 06:15 0.25 6,359 6,359 COMPZ CASIN( PUTB P RD casing tools. 06:15 09:45 3.50 6,359 12,489 COMPZ CASIN( RUNL P RIH to 6,390'. Rotate liner at 25 RPM with 2,500 ft-Ib and 85K ROT wt. Continue RIH to 12,250' where SO wt went to zero. Floated casing to 12,489'. 09:45 10:15 0.50 12,489 12,685 COMPZ CASIN( RUNL P Rotate liner from 12,489- 12,623', PU 2 joints from shed, tagging bottom at 12,685', PU 170K, S0= OK, ROT= 95K, TQ = 8-9,000 ft-Ib at 10 RPM. 10:15 11000 0.75 12,685 12,685 COMPZ CASIN< RUNL P Set liner on depth, drop ball and pump down, seating at 645 strokes, slackoff with 50K, shear ball seat at 4,500 si. 11:00 11:15 0.25 12,685 6,371 COMPZ CASIN( OTHR P LD 2 joints of DP. 11:15 12:00 0.75 6,371 6,371 COMPZ CASINC CIRC P CBU at 6,371'. with 305 GPM, and 1,950 si. 12:00 12:15 0.25 6,371 6,371 COMPZ CASIN( OTHR P Pump dry job, monitor well -static. 12:15 14:30 2.25 6,371 0 COMPZ CASIN( OTHR P POOH, LD running tool removed one bad Lo-TAD from stand #10. Calc displacement on POOH = 51.2 bbl vs. 52.4 bbl actual. 14:30 15:00 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. 15:00 16:00 1.00 0 0 COMPZ WELCT BOPE P Pull WB, rig up testjoint and test equip, MU floor valves. Repair lockdown screw and gland nut in wellhead: _~ ~_ __ -- ___ _ ~_ __ _ _ __ ___:__. _.._... __ ~ °~'~ ~' ~~ G i ,?.7 _ ~Time Logs -- - - - - - - _ - Date From - To Dur S ~ e th E Depfh Phase -- Code Subcode - T QOM - - 06/25/2006 16:00 19:00 3.00 0 0 COMPZ WELCT BOPE P Test all valves in choke manifold, Annular preventer, top pipe rams, upper and lower IBOP valves, manual and HCR choke and kill valves, 4" floor and dart valves to 250 low and 3,000 psi high, holding 5 minutes for low and high each. Perform accumulator function test, before 3,000 psi, after closing 2,000 psi, 200 psi buildup in 44 sec, and full charge in 2 min, 46 sec. Five nitrogen bottles -average of 2,350 psi. Blow down choke manifold and lines line backu for drillin . 19:00 20:00 1.00 0 0 COMPZ WELCT BOPE P RD test equipment, install WB 20:00 20:30 0.50 0 330 COMPZ FISH PULD P PJSM, MU whipstock retrieva! BHA. 20:30 00:00 3.50 330 6,414 COMPZ FISH TRIP P RIH to retrieve whipstock. Remove Lo-TAD from stand #10. Fill pipe every 20 stds, calculated fill 46.6 bbl, actual = 39.7 bbl. Circulate and wash over whipstock slot at 250 GPM, 1,240 psi, rotating at 20 RPM, TQ= 3-4,000 ft-Ib, ROT= 97K Note: GBR and Frank's Casing took measurements on the rig for a h draulic casin stabber. 06/26/2006 00:00 04:45 4.75 6,414 6,331 COMPZ FISH FISH P Continue to attempt to hook whipstock washing from 6,409 - 6,425'. Hook whipstock twice, pull to 190K, fired jars and pulled free. POOH to 6,331'. Weight before hooking = 135K, after= 125K. 04:45 05:45 1.00 6,331 6,331 COMPZ FISH CIRC P Circulate at 6,331' with 210 GPM and 1,250 si. Monitor well -static. 05:45 09:15 3.50 6,331 59 COMPZ FISH TRIP P POOH to 59'. 09:15 11:00 1.75 59 0 COMPZ FISH PULD P LD BHA XO, Jar, Bumper Jar, 1 JT 3-1/2" HWDP, hook, whipstock, trip anchor assembly w/ No-Go Seal assembl . 11:00 11:30 0.50 0 0 COMPZ FISH OTHR P Clear and clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CASIN( CIRC P PU casing equipment and slim hole MWD. 12:00 12:30 0.50 0 0 COMPZ CASIN( RURD P RU to run hook hanger. PU / RU, power tongs, crummies and false rota tabe. 12:30 12:45 0.25 0 0 COMPZ CASIN( RURD P PJSM for PU Hook Hanger 12:45 14:45 2.00 0 31 COMPZ CASIN( PUTB P MU hook hanger assembly and MWD. U load MWD. 14:45 18:45 4.00 31 6,407 COMPZ CASIN< RUNL P Run hook hanger and No-Go on XO below seal bore at 6,530' in the B-Laf liner. POOH to above window, PU= 130K, S0= 79K. ____. _ e , ,~ ~~ ~? Time Loc~s - - _ -- - __ - - _ __ - - - Date From To Dur S. e th E. De th Phase Code 5ubcode T OM 06/26/2006 18:45 20:30 1.75 31 6,407 COMPZ CASIN < RUNL P Orient to 2 deg right, pass thru window on second attempt, RIH and hook 58.75' in on stand with 30K of down weight. Hanger oriented itself to 1 deg left. PU, turn 180 deg, RIH 67' in on stand and tag XO below the 5-1/2" receptacle joint (1,95' low). PU, turn hanger string, orienting to 19 degrees left. RIH 57.5' in on stand where hanger started taking weight and self oriented to 4 deg left. SO with 35K at 59' in on stand. Hook hanger set at 6407.44' tmd. Circulate and drop ball pumping down to ball seat. Pressure up to 2,800 psi and inflate ECP, continure pressure up to 4,500 psi and release from hanger and ECP. PU wt = 120K after, 130K before. 20:30 20:45 0.25 6,407 6,407 COMPZ CASIN( CIRC P Pump slug. Monitor well -static. 20:45 00:00 3.25 6,407 0 COMPZ CASIN( RUNL P POOH to slimhole MWD, download and LD. Displacement calculated = 52.3 bbl, Actual displacement = 50.8 bbl. 06/27/2006 00:00 00:45 0.75 15 0 COMPZ CASIN( RUNL P UD Baker Hook Hanger running tools, UD Slim hole Sperry Sun MWD, UD inner wash strin . 00:45 01:15 0.50 0 0 COMPZ CASIN( RURD P Remove all tools from rig floor, Slim Hole MWD tools to i e shed 01:15 01:30 0.25 0 0 COMPZ CASIN( RURD P Clean and Power wash rig floor and rota area. 01:30 02:30 1.00 0 0 COMPZ RIGMN' SVRG P PJSM -Slip and Cut drill line (79' cut) 02:30 03`00 0.50 0 0 COMPZ CASIN( RURD P PJSM - R/U Csg running tools 03:00 04:00 1.00 0 182 COMPZ CASIN( RNCS P M/U LEM assy per detail ,Bent Jt w/ seals, 1 jt 4.5" Tbg, 2 pup jts, LEM, Seal bore, ZXP 04:00 07:15 3.25 182 6,521 COMPZ CASIN( RNCS P TIH w/ LEM assy on DP to 6521' MD, Up wt 127k, Dn wt 77k, TOL @ 6353' MD 07:15 08:00 0.75 6,521 6,521 COMPZ CASINC CIRC P Drop Ball & Pump down @ 3 BPM, 600 psi, 125 gpm, 36 spm, Ball on seat @ 25 stks, SO to 40k & pressure up to 3000 psi, set liner top packer, continue pressure up to 4000 psi and release from LEM. 08:00 09:00 1.00 6,521. 6,420 COMPZ CASIN( RUNL P POOH T/6420' MD, CBU @ 72 spm, 250 gpm, 1550 psi, Up wt = 125k, Dn wt = 75k 09:00 . 12:00 3.00 6,420 1,145 COMPZ CASIN( RUNL P Monitor well, Pump Dry Job, POOH t/ 11.45' cleaning OBM off off Super Sliders and Lo-TADS 12:00 12:15 0.25 1,145 0 COMPZ CASIN( RUNL P Continue POOH f/1145' to Surface 12:15 12:30. 0.25 0 0 COMPZ CASIN( RURD P UD Running Tool t~z~a~~~ ~~ ~~ ~7 Time Logs Date From To Dur S eoth F nF~~th Phase ~ (,ode Suba~de T ~;C)M 06/27/2006 12:30 13:00 0.50 0 0 COMPZ RPCO ti RURD P Pull wear ring 13:00 14:00 1.00 0 0 COMPZ RPCOh RURD P Clear and Clean Rig Floor & RU to run 4.5" IBT Com letion Strin 14:00 14:15 0.25 0 0 COMPZ RPCOti SFTY P PJSM/ Hazard Assesment meeting w/ Co Rep, Toolpusher, Rig Crew & Casin Hand on runnin tubin 14:15 19:30 5.25 0 6,387 COMPZ RPCOh RCST P Run 204 jts Tubing and Jewlery, PU Wt = 82k, SO Wt = 59k 19:30 20:00 0.50 6,383 6,383 COMPZ RPCOh HOSO P Run In, Tag Up, Space out 4' from being fully inserted, come out, PU Space Out Pups & Landing Jt w/ Hanger. Mule shoe of completion @ 6382.65' -Seals 4' from fully inserted. U wt 82k, SO wt 59k 20:00 20:30 0.50 6,383 6,383 COMPZ RPCOti HOSO P Orient and Land Tubing on Hanger & RI-LDS 20:30 22:30 2.00 6,383 6,383 COMPZ RPCOh SFEQ P Sim-Ops, UD Landing Jt, Test Upper & Lower Hanger Body Seals to 5000 psi for 15 min, UD Casing tools, Clear & Clean Rig Floor, Remove Bell Nipple, Start Flushing Pits, Mud S stem, and Geo-S an w/ H2O 22:30 00:00 1.50 6,383 6,383 COMPZ RPCOh NUND P De-Energize, Drain BOPE stack & start Ni lin Down 06/28/2006 00:00 02:00 2.00 0 0 COMPZ RPCOh NUND P Nipple up tree, Test tubing bonnet and tree to 5000 si for 10 min. 02:00 02:30 0.50 0 0 COMPZ RPCOti NUND P Pull two-way check 02:30 07:00 4.50 0 0 COMPZ RPCOti PULD P PJSM - R/U mouse hole UD 4" DP from derrick 153 'ts 07:00 07:45 0.75 0 0 COMPZ RPCOti RURD P R/U Hot Oil 07:45 08:00 0.25 0 0 COMPZ RPCOh CIRC P PJSM w/ Rig crew and HOt Oil on dis lacin well with diesel. 08:00 10:00 2.00 0 0 COMPZ RPCOh FRZP P Pressure Test lines to 2000 psi, displace well with 310 BBLs diesel @ 4 BPM, 1250 psi, R/D Hot Oil. Freeze protect pumped thru sliding sleeve @ 6309' MD. Diesel in Tbg & Annulus to 6309' M D. 10:00 11:00 1.00 0 0 COMPZ RPCOh RURD P R/U Scaffolding and Lubricator 11:00 12:00 1.00 0 0 COMPZ RPCOh NUND P Set BVP, R/D Lubricator 12:00 12:30 0.50 0 0 COMPZ RPCOh NUND P UD Lubricator, install tree cap, PJSM & Hazard assesment on UD drill pipe using mousehole, also UD Lo-TADS, remove scaffoldin . 12:30 21:30 9.00 0 0 COMPZ RPCOh RURD P Some-Ops cleaning pits, R/W, Preparing for Rig Move, off Hi-Line power @ 14:00 hrs, UD 25 stands slick, 15 stands Hybrids, 50 stands DP w/ Lo-TADS Time Logs __ 'Date From To Dur__ 06/28/2006 21:30 00:00 ~ 2.50 ~=~_ epth_ E__De~th Phase Code Subco~ie_ T~C;C7M ___ __ 0 0 COMPZ RPCOI~ RURD P Blow Down.Rig, Break service lines, prepare to jack rig and move off well. *'**Note``'`** Release Rig @ 2400 hrs Midnioht 6/28/2006 -Move to 1J-156 Halliburton Company Survey Report ('nnipam: ConocoPhillipsAlaska Inr. 11atc: 7:'1;2006 Time: 09'4523 Pn~c: L I~icl~l: Kuparuk River Unit Cu -unlinatcl~l:1 Kclcrcucc: Well: 1J-170. T rue Norfh tiitc: Kuparuk 1J Pad ~'c rtical ("f~'I)I Rcli~rcncc: 1J-?70LL 109. 0 ~1c11: 1J-1 i0 Se ction ~~'~~) liclenncc: Well i0.00N.0-O OE,O OOAziI ~1'cllp:~th: 1J-170L1 Su nk} (~alculnriun'.icthod: Minimum Curvature 11b: Oracle ~ Field: Kuparuk River Unit ~ North Slope Alaska United States Map System:US State Plane Coordi nate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-170 Slot Name: Well Position: +N/-S -305.03 ft Northing: 5945614.10 ft Latitude; 70 15 43.258 N +E/-W -70.73 ft Easting : 558 721.61 ft Longitude: 149 31 31.065 W Position Uncertainty: 0.00 ft Wellpath: 1J-170L1 Drilled From: 1J-170PB1 500292331060 Tie-on Depth: 6748.08 ft Current Datum: 1 J-170L1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/23/2006 Declination: 24.08 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direction I ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 7/13/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 732.00 1J-170PB 1 gyro (50 .00-732.00) CB-GYRO-SS Camera based gyro single shot 803.23. 6748.08 1J-170P6 1 (803.23-9246.96) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6828.00 12566.31 1J-170L1 (6828.00-12566.31) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey X11) Intl \zini ~I~~'D Sp, T~~D V' ;5 1~:;~1 \lapA ~l;ipl~; lonl ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945614.10 558721.61 TIE LINE I 50.00 0.25 25.67 50.00 -59.00 0.04 0.02 5945614.14 558721.63 CB-GYRO-SS 100.00 0.25 22.52 100.00 -9.00 0.24 0.11 5945614.34 558721.72 CB-GYRO-SS i 172.00 0.58 33.07 172.00 63.00 0.69 0.37 5945614.80 558721.97 CB-GYRO-SS 267.00 0.88 313.81 266.99 157.99 1.60 0.10 5945615.70 558721.70 CB-GYRO-SS 358.00 3.08 287.40 357.93 248.93 2.82 -2.73 5945616.89 558718.86 CB-GYRO-SS 450.00 5.60 270.56 449.67 340.67 3.60 -9.58 5945617.62 . 558712.00 CB-GYRO-SS 540.00 7.50 260.08 539.08 430.08 2.63 -19.76 5945616.58 558701.83 CB-GYRO-SS 632.00 9.14 250.71 630.11 521.11 -0.82 -32.57 5945613.03 558689.05 CB-GYRO-SS 732.00 12.79 234.79 728.29 619.29 -9.83 -49.12 5945603.89 558672.57 CB-GYRO-SS 803.23 14.79 229.29 797.47 688.47 -20.31 -62.46 5945593.31 558659.32 MWD+IFR-AK-CAZ-SC 857.48 15.67 226.57 849.81 740.81 -29.86 -73.03 5945583.67 558648.83 MWD+IFR-AK-CAZ-SC i 948.06 20.33 228.41 935.93 826.93 -48.73 -93.69 5945564.65 558628.31 MWD+IFR-AK-CAZ-SC 1041.06 24.31 230.15 1021.95 912.95 -71.72 -120.48 5945541.44 558601.70 MWD+IFR-AK-CAZ-SC 1134.20 28.34 230.76 1105.41 996.41 -98.00 -152.33 5945514.92 558570.06 MWD+IFR-AK-CAZ-SC 1225.44 33.10 230.11 1183.83 1074.83. -127.70 -188.24 5945484.95 558534.39 MWD+IFR-AK-CAZ-SC 1318.35 37.47 231.40 1259.65 1150.65 -161.62 -229.82 5945450.71 558493.08 MWD+IFR-AK-CAZ-SC 1410.82 40.50 233.18 1331.52 1222.52 -197.17 -275.85 5945414.81 558447.34 MWD+IFR-AK-CAZ-SC 1504.40 42.52 233.73 1401.60 1292.60 -234.09 -325.67 5945377.50 558397.80 MWD+IFR-AK-CAZ-SC 1596.02 46.06 233.75. 1467.17 1358.17 -271.92 -377.25 5945339.27 558346.53 MWD+IFR-AK-CAZ-SC 1689.22 .45.31 233.86 1532.28 1423.28 -311.30 -431.07 5945299.47 558293.02 MWD+IFR-AK-CAZ-SC ~ 1782.35 50.09 232.99 1594.94 1485.94 -352.35 -486.36 5945258.00 558238.06 MWD+iFR-AK-CAZ-SC 1873.86 55.20- 232.89 1650.44 1541.44 -396.18 -544.38 5945213.73 558180.38 MWD+IFR-AK-CAZ-SC 1966.96 58.05 234.02 1701.66 1592.66 -442.46 -606.84 5945166.97 558118.29 MWD+IFR-AK-CAZ-SC 2061.56 61.81 234.48 1749.05 1640.05 -490.27 -673.28 5945118.64 558052.24 MWD+IFR-AK-CAZ-SC i 2153.34 66.94 235.16 1788.73 1679.73 -537.93 -740.90 5945070.46 557985.00 MWD+IFR-AK-CAZ-SC j 2245.85 68.35 235.35 1823.91 1714.91 -586.69 -811.20 5945021.16. 557915.09 MWD+IFR-AK-CAZ-SC 2340.01 66.55 234.38 1860.02 1751.02 -636.73 -882.31 5944970.57 557844.37 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~iuupan~: ConocoPhillipsAlaska Inr. Uatc: 7i13i2006 lime: 09.4523 Pa,c: Ficl~l: Kuparuk River Unit C~~-urdin;,rc(~I') Rclcrcncc: Well: 1J-170, True North ~tiitc: Kuparuk 1J Pad ~"crtir;~l ~"Il I)) Kcfcrcncc: 1J-170L1- 109-0 ~~cll: 1J-170 ~cc(iun I~~~1 Kcfcrcncc: Well f0 00N.0.00E0.00Azi) ~'.ell~rrlh: 1J-170U 5uncr Calculatfun ~Ici[roil: ilAinimum Curvature Uh: Cra~le Suncc Ill lucl ~ciw C'v~I) ti~ti'I~'ll \ ti IC;11 ~I:~p,A ~l:~~il: Trial ft deg deg ft ft ft ft ft ft 2430.35 66.09 233.38 1896.31 .1787.31 -685.49 -949.14 5944921.29 557777.93 MWD+IFR-AK-CAZ-SC 2524.20 66.73 232.33 1933.86 1824.86 -737.43 -1017.70 5944868.83 557709.79 MWD+IFR-AK-CAZ-SC 2617.29 65.63 232.42 1971.46 1862.46 -789.42 -1085.15 5944816.32 557642.76 MWD+IFR-AK-CAZ-SC 2708.83 65.47 232.71 2009.35 1900.35 -840.07 -1151.32 5944765.16 557576.99 MWD+IFR-AK-CAZ-SC 2801.61 66.32 234.48 2047.24 1938.24 -890.33 -1219.48 5944714.38 557509.23 MWD+IFR-AK-CAZ-SC 2893.74 64.53 235.05 2085.56 1976.56 -938.66 -1287.90 5944665.51 557441.19 MWD+IFR-AK-CAZ-SC 2988.02 66.31 235.05 2124.77 2015.77 -987.78 -1358.18 5944615.86 557371.31 MWD+IFR-AK-CAZ-SC 3074.18 65.18 236.36 2160.17 2051.17 -1032:04 -1423.07 5944571.09 557306.77 MWD+IFR-AK-CAZ-SC 3105.86 63.95 236.54 2173.77 2064.77 -1047.85 -1446.91 5944555.10 557283.05 MWD+IFR-AK-CAZ-SC 3200.29 64.63 235.81 2214.74 2105.74 -1095.21 -1517.59 5944507.19 557212.75 MWD+IFR-AK-CAZ-SC 3291.60 63.12 238.30 2254.95 2145.95 -1139.80 -1586.37 5944462.07 557144.33 MWD+IFR-AK-CAZ-SC 3384.37 63.59 241.70 2296.56 2187.56 -1181.25 -1658.17 5944420.07 557072.86 MWD+IFR-AK-CAZ-SC 3478.44 63.52 245.56 2338.47 2229.47 -1218.65 -1733.61 5944382.09 556997.72 MWD+IFR-AK-CAZ-SC 3572.09 64.29 249.70 2379.67 2270.67 -1250.64 -1811.37 5944349.50 556920.23 MWD+IFR-AK-CAZ-SC 3666.38 63.60 255.60 2421.12 2312.12 -1275.90 -1892.17 5944323.61 556839.63 MWD+IFR-AK-CAZ-SC 3761.00 63.46 260.73 2463.32 2354.32 -1293.26 -1975.03 5944305.60 556756.92 MWD+IFR-AK-CAZ-SC 3853.11 64.39 266.07 2503.83 2394.83 -1302.75 -2057.17 5944295.47 556674.86 MWD+IFR-AK-CAZ-SC 3946.84 67.20 273.93 2542.30 2433.30 -1302.69 -2142.56 5944294.87 556589.48 MWD+IFR-AK-CAZ-SC 4039.97 65.00 278.25 2580.05 2471.05 -1293.68 -2227.20 5944303.21 556504.78 MWD+IFR-AK-CAZ-SC 4133.23 64.70 281.87 2619.69 2510.69 -1278.94 -2310.30 5944317.30 556421.57 MWD+IFR-AK-CAZ-SC 4224.53 63.44 282.61 2659.61 2550.61 -1261.54 -2390.54 5944334.08 556341.21 MWD+IFR-AK-CAZ-SC 4319.36 66.10 283.59 2700.03 2591.03 -1242.09 -2474.08 5944352.87 556257.53 MWD+IFR-AK-CAZ-SC 4412.60 66.79 282.94 2737.29 2628.29 -1222.48 -2557.27 5944371.83 556174.19 MWD+IFR-AK-CAZ-SC 4505.54 67.18 282.40 2773.63 2664.63 -1203.72 -2640.73 5944389.94 556090.60 MWD+IFR-AK-CAZ-SC 4601.05 67.18 284.97 2810.68 2701.68 -1182.89 -2726.26 5944470.10 556004.92 MWD+IFR-AK-CAZ-SC 4690.50 66.73 288.90 2845.71 2736.71 -1158.93 -2804.98 5944433.45 555926.02. MWD+IFR-AK-CAZ-SC 4780.83 65.35 293.36 2882.40 2773.40 -1129.20 -2881.95 5944462.57 555848.83 MWD+IFR-AK-CAZ-SC 4879.54 64.12 298.89 2924.56 2815.56 -1089.93 -2962.07 5944501.21 555768.42 MWD+IFR-AK-CAZ-SC 4972.71 63.90 302.49 2965.40 2856.40 -1047.20 -3034.07. 5944543.37 555696.09 MWD+IFR-AK-CAZ-SC 5068.22 64.61 306.75 3006.90 2897.90 -998.33 -3104.84 5944591.68 555624.95 MWD+IFR-AK-CAZ-SC 5160.02 64.66 312.00 3046.25 2937.25 -945.73 -3168.93 5944643.78 555560.46 MWD+IFR-AK-CAZ-SC 5254.34 67.22 318.22 3084.73 2975.73 -884.73 -3229.63 5944704.30 555499.28 MWD+IFR-AK-CAZ-SC 5345.64 67.73 323.79 3119.73 3010.73 -819.21 -3282.67 5944769.39 555445.74 NIWD+IFR-AK-CAZ-SC 5438.98 67.21 329.57 3155.52 3046.52 -747.21 -3330.01 5944841.02 555397.85 MWD+IFR-AK-CAZ-SC 5533.31 68.47 335.37 3191.13 3082.13 -669.78 -3370.35 5944918.13 555356.91 MWD+IFR-AK-CAZ-SC 5625.93 72.12 341.26 3222.37 3113.37 -588.79 -3402.50 5944998.85 555324.13 MWD+IFR-AK-CAZ-SC 5719.45 72.25 346.61 3251.01 3142.01 -503.27 -3427.12 5945084.17 555298.84 MWD+IFR-AK-CAZ-SC 5814.69 73.89 352.76 3278.76 3169.76 -413.68 -3443.41 5945173.62 555281.86 MWD+IFR-AK-CAZ-SC 5907.49 75.91 358.77 3302.96 3193.96 -324.38 -3450.00 5945262.86 555274.58 MWD+IFR-AK-CAZ-SC 6000.27 78.27 359.79 3323.69. 3214.69 -233.96 -3451.13 5945353.26 555272.74 MWD+IFR-AK-CAZ-SC 6093.70 78.76 359.45 3342.29 3233.29 -142.40 -3451.74 5945444.80 555271.42 MWD+IFR-AK-CAZ-SC 6186.46 79.63 358.81 3359.68 3250.68 -51.30 -3453.12 5945535.88 555269.32 MWD+IFR-AK-CAZ-SC 6280.24 78.96 357.80 3377.10 3268.10 40.81 -3455.85 5945627.96 555265.88 MWD+IFR-AK-CAZ-SC 6371.85 79.47 357.84 3394.24 3285.24 130:74 -3459.27 5945717.84 555261.76 MWD+IFR-AK-CAZ-SC 6466.74 78.89 358.55 3412.05 3303.05 223.89 -3462.21 5945810.97 555258.09 MWD+IFR-AK-CAZ-SC 6558.69 79.15 0.20 3429.57 3320.57 314.15 -3463.19 5945901.20 555256.41 MWD+IFR-AK-CAZ-SC 6654.07 79.53 0.30 3447.21 3338:21 407.88 -3462.78 5945994.93 555256.09 MWD+IFR-AK-CAZ-SC 6748.08 79.92 1.52 3463.98 3354.98 500.37 -3461.31 5946087.42 555256.83 MWD+IFR-AK-CAZ-SC • 6828.00 79.96 2.08 3477.94 ' 3368.94 579.02 -3458.84 5946166.08 555258.69 MWD+IFR-AK-CAZ-SC 6962.25 84.84 8.86 3495.71 3386.71 711.36 -3446.12 5946298.50 555270.38 MWD+IFR-AK-CAZ-SC 6987.90 85.02 10.14 3497.98 3388.98 736.56 -3441.91 5946323.73 555274.40 MWD+IFR-AK-CAZ-SC 7084.56 87.25 12.19 3504.49. 3395.49 831.17 -3423.23 5946418.47 555292.33 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ('ompan~: ConocoPhillips Alaska Inc- I).uc: 7i 1 x!2006 lime: 09.4523 Pac: 3 Fic1~J: Ku paruh River Unit C u-urdinatc~R1. ) Reference: Weil_ 1J-170. True North Silt: Ku paruklJ Pad ~ crtical(l~'111 Reference: 1J-170L1.109 -0 ~~cll: iJ -170 S ection ~15~ Rcf rrcncc: Well ~O.OON.O- OOE.O OOAzi1 ~~'ell~rifh: 1J -170L1 ti un~c~ ('alculai iun ~Icthu~l: Minimum Curv 2.ture Dh: Oracle Survcc X11) incl ~iim f~ D ~~e l~ I) \;:V 1~::~1' >I;ip,A ~Ia~iE Toul ft deg deg ft ft ft ft ft ft 7181.34 90.66 14.64 3506.26 3397.26 925.27 -3400.79 5946512.73 555314.04 MWD+IFR-AK-CAZ-SC 7277.70 91.32 12.20 3504.59 3395.59 1018.98 -3378.43 5946606.60 555335.66 MWD+IFR-AK-CAZ-SC 7374.39 90.08 7.76 3503.41 3394.41 1114.17 -3361.68 5946701.92 555351.67 MWD+IFR-AK-CAZ-SC 7472.37 90.52 6.91 3502.90 3393.90 1211.35 -3349.17, 5946799.18 555363.42 MWD+IFR-AK-CAZ-SC 7568.03 89.58 7.15 3502.82 3393.82 1306.28 -3337.46 5946894.19 555374.39 MWD+IFR-AK-CAZ-SC 7665.06 89.53 7.34 3503.57 3394.57 1402.54 -3325.22 5946990.53 555385.87 MWD+IFR-AK-CAZ-SC 7762.29 89.65 7.78 3504.27 3395.27 1498.92 -3312.43 5947087.00 555397.91 MWD+IFR-AK-CAZ-SC 7860:23 89.84 7.86 3504.70 3395.70 1595.95 -3299.11 5947184.12 555410.48 MWD+IFR-AK-CAZ-SC 7953.74 90.27 6.14 3504.61 3395.61 1688.76 -3287.71 5947277.01 555421.15 MWD+IFR-AK-CAZ-SC 8050.16 89.46 3.75 3504.84 3395.84 1784.81 -3279.40 5947373.11 555428.71 MWD+IFR-AK-CAZ-SC 8147.95 89.59 1.68 3505.65 3396.65 1882.48 -3274.77 5947470.81 555432.58 MWD+IFR-AK-CAZ-SC 8243.91 88.85 359.16 3506.96 3397.96 1978.42 -3274.07 5947566.74 555432.53 MWD+IFR-AK-CAZ-SC 8339.11 88.66 359.50 3509.02 3400.02 2073.59 -3275.18 5947661.89 555430.68 MWD+IFR-AK-CAZ-SC 8436.47 90.60 0.36 3509.65 3400.65 2170.94 -3275.30 5947759.23 555429.80 MWD+IFR-AK-CAZ-SC 8532.86 89.71 0.14 3509.39 3400.39 2267.33 -3274.88 5947855.61 555429.47 MWD+IFR-AK-CAZ-SC 8628.93 89.40 1.01 3510.14 3401.14 2363.39 -3273.91 5947951.67 555429.68 MWD+IFR-AK-CAZ-SC 8728.03 90.15 359.24 3510.53 3401.53 2462.49 -3273.70 5948050.75 555429.13 MWD+IFR-AK-CAZ-SC 8825.10 92.00 356.55 3508.71 3399.71 2559.46 -3277.26 5948147.68 555424.81 MWD+IFR-AK-CAZ-SC 8921.80 89.20 353.67 3507.69 3398.69 2655.79 -3285.50 5948243.93 555415.82 MWD+IFR-AK-CAZ-SC 9018.96 88.60 352.95 3509.56 3400.56 2752.26 -3296.82 5948340.31 555403.75 MWD+IFR-AK-CAZ-SC 9114.85 89.78 358.27 3510.92 3401.92 2847.83 -3304.15 5948435.80 555395.67 MWD+IFR-AK-CAZ-SC 9211.85 90.02 359.29. 3511.08 3402.08 2944.80 -3306.22 5948532.75 555392.85 MWD+IFR-AK-CAZ-SC 9308.32 88.28 0.16 3512.52 3403.52 3041.26 -3306.68 5948629.19 555391.63 MWD+IFR-AK-CAZ-SC 9406.12 88.73. 3.84 3515.07 3406.07 3138.95 -3303.27 5948726.89 555394.28 MWD+IFR-AK-CAZ-SC 9502.25 93.13 6.46 3513.51 3404.51 3234.65 -3294.65 5948822.65 555402.16 MWD+IFR-AK-CAZ-SC 9598.81 91.31 0.78 3509.76 3400.76 3330.90 -3288.56 5948918.93 555407.49 MWD+IFR-AK-CAZ-SC 9695.27 89.14 359.45 3509.39 3400.39 3427.35 -3288.37 5949015.37 555406:93 MWD+IFR-AK-CAZ-SC 9792.49 91.88 355.82 3508.52 3399.52 3524.46 -3292.38 5949112.44 555402.17 MWD+IFR-AK-CAZ-SC 9888.94 91.81 355.84 3505.42 3396.42 3620.60 -3299.39 5949208.52 555394.41 MWD+IFR-AK-CAZ-SC 9985.63 92.10 356.49 3502.12 3393.12 3717.02 -3305.85 5949304.87 555387.19 MWD+IFR-AK-CAZ-SC 10082.14 90.75 355.50 3499.72 3390.72 3813.26 -3312.59 5949401.05 555379.71 MWD+IFR-AK-CAZ-SC 10178.70 89.89 355.99 3499.18 3390.18 3909.55 -3319.75 5949497.27 555371.79 MWD+IFR-AK-CAZ-SC 10276.10 89.03 356.83 3500.10 3391.10 4006.75 -3325.85 5949594.41 555364.94 MWD+IFR-AK-CAZ-SC 10372.35 91.14 359.99 3499.95 3390.95 4102.95 -3328.52 5949690.57 555361.52 MWD+IFR-AK-CAZ-SC 10469.31 91.32 1.14 3497.87 3388.87 4199.88 -3327.57 5949787.50 555361.72 MWD+IFR-AK-CAZ-SC 10565.82 90.32 0.71 3496.49 3387.49 4296.37 -3326.01 5949883.99 555362.52 MWD+IFR-AK-CAZ-SC 10663.91 90.58 359.56 3495.72 3386.72 4394.45 -3325.78 5949982.06 555361.99 MWD+IFR-AK-CAZ-SC 10759.22 89.77 357.12 3495.43 3386.43 4489.71 -3328.54 5950077.29 555358.48 MWD+IFR-AK-CAZ-SC 10854.19 88.66 358.29 3496.73 3387.73 4584.59 -3332.34 5950172.13 555353.94 MWD+IFR-AK-CAZ-SC 10947.50 87.17 357.79 3500.12 3391.12 4677.78 -3335.53 5950265.28 555350.03 MWD+IFR-AK-CAZ-SC 11038.99 87.80 358.23 3504.14 3395.14 4769.13 -3338.70 5950356.59 555346.14 MWD+IFR-AK-CAZ-SC 11132.98 88.67 359.02 3507.03 3398.03 4863.05 -3340.96 5950450.48 555343.15 MWD+IFR-AK-CAZ-SC 11226.04 88.17 357.93 3509.60 3400.60 4956.04 -3343.43 5950543.44 555339.95 MWD+IFR-AK-CAZ-SC 11320.00 88.91 358.44 3511.99 3402.99 5049.92 -3346.41. 5950637.29 555336.25 MWD+IFR-AK-CAZ-SC 11412.62 89.34 358.91 3513.41 3404.41 5142.50 -3348.55 5950729.84 555333.39 MWD+IFR-AK-CAZ-SC 11506.93 89.59 359.35 3514.29 3405.29 5236.80 -3349.98 5950824.11 555331.22 MWD+IFR-AK-CAZ-SC 11600.36 89.59 359.62 3514.96 3405.96 5330.22 -3350.82 5950917.52 555329.65 MWD+IFR-AK-CAZ-SC 11692.68 89.34 359.01 3515.82 3406.82 5422.53 -3351.92 5951009.81 555327.83 MWD+IFR-AK-CAZ-SC 11787.29 87.85 0.43 3518.14 3409.14 5517.11 -3352.39 5951104.37 555326.63 MWD+IFR-AK-CAZ-SC I 11879.45 87.61 359.77 3521.79 3412.79 5609.19 -3352.23 5951196.44 555326.07 MWD+IFR-AK-CAZ-SC 11972.48 87.24 359.49 3525.97 3416.97 5702.13 -3352.83 5951289.36 555324.74 MWD+IFR-AK-CAZ-SC 12064.48 87.24 0.96 3530.40 3421.40 5794.02 -3352.47 5951381.24 555324.39 MWD+IFR-AK-CAZ-SC 12160.27 88.24. 0.36 3534.18 3425.18 5889.72 -3351.36 5951476.95 555324.74 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~mnpan}: ConocoPhillips Alaska Inc Iicl~l: Kuparuk River Unit tiitc: Kuparuk iJ Pad ~~cll: 1 J-1i0 ~1cllpath: 1 J-170L1 ~unc~ ~IU iucl ~cim l~ I) ft deg deq ft 12250.23 88.04. 358.69 3537.10 12341.05 88.29 358.38 3540.01 12432.41 87.67 358.33 3543.23 12523.62 86.74 357.19 3547.67 12566.31 86.75 357.13 3550.10 12602.00 86..75 357.13 3552.12 11atr: 7113!2006 'time: 09.45:23 Pale: -I (~u-urilinsiclA1') Rcii~.rruce: Well: 1J-170, True North ~crti~~al (Il'I)) 12cfcrcncc: 1J-170L1. 109.0 ticcGim 1~~1 ftcfercncc: Well (O OON,0-OOE.O OOA~iI tiurcc~ Calculation ~Icthod: Minimum Curvature Ub: Orade 5~.1~7) ~A;S ICr1~ ~IaPA 11a~~}: I'mil ft ft ft ft rt 3428.10 5979.63 -3352.11 5951566.83 555323.30 MWD+IFR-AK-CAZ-SC 3431.01 6070.37 -3354.43 5951657.55 555320.27 MWD+IFR-AK-CAZ-SC 3434.23 6161.64 -3357.05 5951748.78 555316.94 MWD+IFR-AK-CAZ-SC 3438.67 6252.67 -3360.61 5951839.77 555312.67 MWD+IFR-AK-CAZ-SC 3441.10 6295.24 -3362.72 5951882.32 555310.22 MWD+IFR-AK-CAZ-SC 3443.12 6330.82 -3364.51 5951917.89 555308.16 .PROJECTED to TD ~, ~ , ~~~ OIIf DiSi/ Vrpa7 COI~TSERQAZ'IOr1T CO1~II-IISSIOIQ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ~J FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170L1 ConocoPhillips Alaska, Inc. Permit No: 206-063 Surface Location: 1802' FSL, 2490' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 2854' FSL, 569' FEL, Sec. 27, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-170, Permit No 206-062, API 50-029-23310-00. Injections should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ConocoPhillips Alaska Ina 1J-170L1 Permit No: 206-063 DATED this~l~' day of May, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA y f~ -~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ `` ~') ~~ PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^ Strdtigraphic Test ^ Service ^~ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2.Operator Name: ConocoPhillipsAlaska, Ina 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number. 1J-170L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12649' • ND: 3525' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2490' FEL, Sec. 35, T11 N, R10E, UM ' 7. Property Designation: ADL 25660 ~ West Sak Oil Pool Top of Productive Horizon: 2110' FSL, 674' FEL, Sec. 34, T11N, R10E, UM 8. Land Use Permit: ALK 470 13. Approximate Spud Date: 6/8/2006 Total Depth: 2854' FSL, 569' FEL, Sec. 27, T11 N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: <3 miles to KRU 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 y- 5945614 ` Zone- 4 10. KB Elevation (lielgnt above cl_!: 28' RKB feet 15. Distance to Nearest Well within Pool: 1 J-10 , 197.5' @ 5400' 1 B. Deviated wells: Kickoff depth: 6584 ft. Maximum Hole Angle: 89.6° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5~ Downhole: 1586 psig ` .Surface: 1199 psig ` 18. Casing Program S ecifications Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Wetded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 3018' 28' 28' 3018' 2145' 530 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 7681' 28' 28' 7681' 3619' 430 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 6057' 6584' 3434' 12649' 3525' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): _ ,, ~~ ~1~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis ~ Property Piat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 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 David Nugent @ 265-6862 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ `"' ~ --- Phone 't-j~; G-S 3 ~ Date ~ /~~Od P a db ha I D k Commission Use Oniy Permit to Drill ,, Number. ~.U(p' ~ ~ API Number: 50- 6Zg -z33/d ^~ Permit Approval See cover letter Date: ~ ~ or other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, g es, or gas contained in shales: 3 ®®~ ~~ ~~? ~S\" ~\~~~~ Samples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [/~ Other. Qom, H2S measures: Yes ^ N Dire tonal svy req'd: Yes [~ No ^ ~t'i dhC~~ f< K7~~o°`:a~`'(U o`r: e tl\ G ~.L.Cj•~ v ! ~`~ :~ lzS PPROVED BY THE COMMISSION DATE: ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~~ ~ ~~ ~ ~q ~ 4y S mit~i`n/Duplicate~'J/~(~//~/j~ ~~lOb g °~ w ~i f ism ' il~~~ I4/ !!!"' App~n for Permit to Drill, Well 1J-170 L1 Revision No.O Saved: 3-May-06 Permit It -West Sak Well #1J-170 L1 •~°~ r.~ +'t App/ication for Permit to Ori// Document„; ItaW+~II Mdxirnix~ Y~e~ll ~fvlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) .......................................................................................:......,........ 3 3. Blowout Prevention Equipment (nformation ......................... .:..........: . ................... '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 tnformation ..................................................... 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 ~~~~ not done 1J-170L1 PERMIT IT Page 7 of 6 Printed: 3-May-O6 Appl~n for Permit to Drill, Well 1J-170 L1 Revision No.O Saved: 3-May-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...............................................................................:................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14)...........: ................................................................._.................. 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (~ Each we// must be identified by a unique name designated by the operator and a unique APlnumber assigned by the commission under 20 AAC25.040(b). For a well with multip/e we/!branches, each branch must similar/y be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as iJ-170 Li. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item already on fr/e with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we!/ at the surface, at the top of each objective formation, and at tota/depth, referenced to governmental section lines (e) 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 Nationa/Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we// at the top of each objective formation and at total depth; Location at Surface 1,802' FSL, 2 489' FEL, Section 35 Ti1N R10E ASPZone 4NAD27Cooro'inates RKB E/evat%On 109.0' AMSL Northings: 5,945,614 ~ Eastings: 558,722 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 2,110' FSL, 674' FEL, Section 34, Ti1N, R10E ASP zone 4 NAD 27 coordinates Measured De th, RKB.• 6 584 Northings: 5,945,907 Eastings: 555,256 Total t/erticalDe th, RKB: 3,434 Total I/ertica/De th SS.• 3,325 Location at Total De th 2,854' FSL, 569' FEL Section 27 T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12, 649 - Northings: 5,951,919 Eastings• 555,307 Total l/ertica/De th, RKB.• 3,525 Total I/ertical De th, SS.• 3,416 and (D) other information required by 20 AAC25.050(b); not done 1J-170L1 PERMIT lT Page 2 of 6 Printed: 3-May-O6 Appl~n for Permit to Drill, Well 1J-170 L1 Revision No.O Saved: 3-May-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application fora Permit to Drr// (Form 10-401). must (1) include a plat, drawn to a suitable scale, showing the path of the proposed we/!bore, including a//adjacent we/Ibores within 200 feet ofany portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for at/ wet/s within 200 feet of the proposed wet/bore (A) list the names of the operators of those wel/s, to the extent that tlrase names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mai/; or (e) state that the applicant is the on/y affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fot/owing items, except far an ifem a/ready on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC25.03s, 20 AAC25.036, or 20 AAC 25.037, as appticab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-170 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 application for a Permit to Dri// must be accompanied by each of fhe fo/%wing items, except for an item a/ready on F/e with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW r (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 1,199 psi, calculated thusly: MPSP = (3,525 ft TVD)(0.45 - 0.11 psi/ft) = 1,199 psi - (B) data on potentia/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 difi`erential sticking; Please see Attachment 2: 1J-170 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri//must be accompanied by each ofthe fo/%wing items, except for an item already an file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(f); The parent wellbore, iJ-170, 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. not done 1J-170L1 PERMIT /T Page 3 of 6 /~ ~ Printed: 3-May-06 ~~E1 App~n for Permit to Drill, Well 1J-170 Jam' Revision No.O Saved: 4-May-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drit! must be accompanied by each of the following items, except for an item already on ~Je with the commr"scion 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 siofted liner, pre- perforated finer, or screen to be metalled; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top etm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 10$ / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 3,018 28 / 28 3,018 /2,145 530 sx ASLite lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 7,681 28 / 28 7,681 / 3,619 4,200' MD / 2637 TVD. Cemented w/ 430 sx Dee CRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 5,824 6,684 / 3,447 12,508 / 3,643 Slotted- no cement 4-1/2 - ~ :- - 6-3/4" B Sand 11.6 L-80 BTC 6,057 6,584 / 3,434 12,649 / 3,525 Slotted- no cement SlOtte -Lateral (1J-170 Li) _ 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,594 6,138 / 3,347 - no cement Slotted Lateral (1J-170 L2) L 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on the with the commission and identited in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by tfte commission under 20 AAC 25.035(h)(2J; No diverter system will be utilized during operations on 1J-170 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permft to Driff must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.8 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18 28 cP HTHP Fluid loss <4 0 ml/30 min . not done 1J-17~PERMIT IT Page 4 of 6 Printed: 4-May-06 Appli~ for Permit to Drill, Well 1J-170 L1 Revision No.O Saved: 3-May-06 8 150° 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. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dri//must be accompanied by each ofthe fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel% a tabulation setting out the depths ofpredicted abnormal/ygeo pressured strata as required by 20AAC25.033(/); 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/ication for a Permit to Ori// must be accompanied by each of the fot/owing items, except for an item a/ready on fi/e with the commission and identfied in the application: (10) for an exploratory or stratigraphic test we/% a seismic refraction ar refection analysis as required by 20 AAC 25.061(aJ; Not applicable: Application is not for an exploratory or stratigraphic test well. . 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/icadon fora Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (11) for swell dri/led from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating driJling vessel, an ana/ysis ofseabed conditions as required by 20 AAC 15.061(6); Not applicable: Application is not for an offshore well. " 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (12) evidence showing b5at 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 application for a Permit to Dri//must be accompanied by each of the fo/lowing items, except for an item a/reaoy on fi/e with the commission and identified in bye application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-170 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,584' MD / 3,434' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at +/- 12,649' MD / 3,525' 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. not done 1J-170L1 PERMIT IT Page 5 of 6 Printed: 3-May-06 Appl~n for Permit to Drill, Well 1J-170 L1 Revision No.O Saved: 3-May-06 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2"slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth.. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the °D" sand lateral 1J-170 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 Ori// musts be accompanied by each of the fo/lowing items, except for an item a/ready on fr/e with the commission and identified in the app/ication: (i4) a genera/ description ofhow the operator p/ans to dispose of dill/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 RAC25.080 for an annular disposa/operation in the we/%; 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 iJ 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 not done 1J-170L1 PERMIT IT n i~ ~ Page6~f6 w ~ \1Ep Printed: 3-Ma 06 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 -Slot 1J-170 1 J-170 L1 Plan: 1J-170 L1 (wp05) Proposal Report 10 April, 2006 ~periry Drilling seir~rices ORIGINAL Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170. . Wellbore: 1J-170 L1 Plan: 1J-170 L1 (wp05) 1J-170 L2 (wp05) ~ i i I L1 : BHL @ 12649ft MD, 3525ft TVD-41/2' i ' i ,'' i 1J-170 L1 T5 Toe (wp05 1J-170 Lt Td (wp05 _ 1J-170 L1 T3 (wp05 ' iJ-170 L1 T2 (wp05' '-------- 1J-170(wp05) ~ ~ CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2145.00 .3018.00 10 3/4" 10-3/4 3 3433.96 6583.88 7 5/8" 7-5/8 4 3525.00 12648.91 4 1 /2" 4-1 /2 T ~€nuLhs to 's .rc;e North Magnetic North: 24.24° Magnetic Field Strength:57562.6n Dip Angle: 80.77° Date: 12/15/2005 Model: BGGM2005 AI-LIi:iTC1 Sperry DHllitfg Services Conoc f hillps I wasi~a DD Polygait Describes a corridor 100' wide 31 1 _1 with a 50'+!-allowance E(W froth the ` proposed wellbore. _ 0 1J-170 L1 DD Poly @ 95% ~ 356° ~ o ~ tl o li v ±. ~ L1 : Begin GeoSteer in 63and 7025ft MD, 3477ft TV O Z 1J-170 L1 T1 (wp05 _ _ _ _ _ _ _ ' \ ~ ~ L1 : End Rathole Build @ 3.5°HOOft to 88.6° lint r 6626ft MD, 3440ft / ,'-,'" / ( - Lt i BOW : 6596ft MD, 3436ft TV ! ', '~~/ '___ -_-_____L1:TOW@6584ftMD,3434ftTV 1 --=------------------ ~ 350° ~tiy o°~$ ~ c ~ ~ ~ N ~ N -6250 -5625 -5000 -4375 -3750 -3125 -2500 -1875 1250 -625 0 625 1250 1875 2500 ~~~ ~ ~t(a~t ~~1250 fbin) Halliburton Energy Services - . ~ ' P~" ~ ~ C3t tOCC3 11 1~]-S Planning Report -Geographic Alaska Spelrry i7trllling Services Database: EDM2003.11SingleUserDb Local Co-ordinate Reference: Well PlanlJ-170-SIof1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True WeIL- Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 L1 Design: 1J-170 L1 (wp05) 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-170 -Slot 1J-170 Well Position +N1-S 0.00 ft Northing: 5,945,614.10 ft Latitude: 70° 15' 43.258" N +E/-W 0.00 ft Easting: 558,721.61 ft Longitude: 149° 31' 31.065" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore 1J-170 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 12/15/2005 24.2421 80.7658 57,563 Design., 1J-170 L1 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 6,583.87 Vertical Section: Depth From (TVD) +N/-S +E!-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +E!-W Rate Rate' Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 6,583.87 80.00 2.00 3,433.96 307.80 -3,464.28 0.00 0.00 0.00 0.0000 6,595.87 81.91 2.00 3,435.84 319.64 -3,463.86 15.90 15.90 0.00 0.0000 6,625.87 81.91 2.00 3,440.06 349.32 -3,462.83 0.00 0.00 0.00 0.0000 6,999.97 88.71 13.23 3,470.73 718.04 -3,413.35 3.50 1.82 3.00 59.2544 7,024.86 89.59 13.23 3,471.10 742.27 -3,407.66 3.50 3.50 -0.01 -0.0951 7,895.63 89.59 13.23 3,477.40 1,589.91 -3,208.40 0.00 0.00 0.00 0.0000 8,271.01 88.71 2.00 3,483.00 1,961.34 -3,158.74 3.00: -0.23 -2.99 -94.5273 8,488.42 89.77 355.56 3,485.89 2,178.56 -3,163.36 3.00 0.49 -2.96 -80.7095 10,481.34 89.77 355.56 3,493.93 4,165.50 -3,317.52 0.00 0.00 0.00. 0.0000 10,586.89 89.79 358.73 3,494.33 4,270.90 -3,322.77 3.00 0.02 3.00 89.6238 11,586.89 89.79 358.73 3,498.00 5,270.65 -3,344.93 0.00 0.00 0.00 0.0000 11,624.96 89.41 358.73 3,498.27 5,308.71 -3,345.78 1.00 -1.00 0.00 -179.7575 11,987.13 89.41 358.73 3,502.00 5,670.77 -3,353.82 0.00 0.00. 0.00 0.0000 12,064.32 88.64 358.73 3,503.32 5,747.93 -3,355.53 1.00 -1.00 0.00 179.9937 12,387.45 88.64 358.73 3,511.00 6,070.89 -3,362.70 0.00 0.00 0.00 0.0000 12,504.42 86.44 359.53 3,516.02 6,187.73 -3,364.47 2.00 -1.88 0.68 160.0365. 12,648.92 86.44 359.53 3,525.00 6,331.95 -3,365.66 0.00 0.00 0.00 0.0000 4/10/2006 12:12:42PM Page 2 of 6 COMPASS 2003.11 Build 50 r Cc~nacc~Philips Alaska Halliburton Energy Services Planning Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company:. ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-170 Survey Calculation Method: Wellbore: 1J-170 L1 Design: 1J-170 L1 (wp05) ~~ Sperry grilling Services Well Plan 1J-170 -Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Planned RKB @ 109.OOft (Doyon 141 (28+81 )) True Minimum Curvature Planned Survey 1J-170 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 6,583.87 80.00 2.00 3,433.96 3,324.96 307.80 -3,464.28 5,945,$94.84 555,255.37 0:00 307.80 L1 : TOW @ 6584ft M D, 3434ft TV D - 2110ft FSL 8 674ft FE L -Sec 34 - T11 N - R10E - 7 5/8" -1J-170 L1 DD Poly @ 95% 6,595.87 81.91 2.00 3,435.84 3,326.84 319.64 -3,463.86 5,945,906.69 555,255.69 15.90 319.64 L1 : BOW : 6596ft MD, 3436ft TVD 6,600.00 81.91 2.00 3,436.42 3,327.42 323.73 -3,463.72 5,945,910.78 555,255.80 0.00 323.73 6,625.87 81.91 2.00 3,440.06 3,331.06 349.32 -3,462.83 5,945,936.38 555,256.50 0.00 349.32 L1 : End Rathole Buil d @ 3.5°/100ft to 88.6° linc - 6626ft MD, 3440ft TVD 6,700.00 83.24 4.24 3,449.65 3,340.65 422.72 -3,458.82 5,946,009.79. 555,259.93 3.50 422.72. 6,800.00 85.05 7.25 3,459.85 3,350.85. 521.68 -3,448.85 5,946,108.82 555,269.13 3.50 521.68 6,900.00 86.88 10.25 3,466.88 3,357.88 620.25 -3,433.67 5,946,207.50 555,283.53 3.50 620.25 6,999.97 88.71 13.23 3,470.73 3,361.73 718.04 -3,413.35 5,946,305.43 555,303.09 3.50 718:04 7,024.86 89.59 13.23 3,471.10 3,362.10 .742.27 -3,407.66 5,946,329.71 555,308.60.... 3.50.- 742.27. L1 : Begin GeoSteer in BSand 7025ft MD, 347 1ft TVD 7,100.00 89.59 13.23 3,471.64 3,362.64 815.41 -3,390.46 5,946,402.97 555,325.22 0.00 815.41 7,200.00 89.59 13.23 3,472.36 3,363.36 912.76 -3,367.58 5,946,500.48 555,347.34 0.00 912.76 7,300.00 89.59 13.23 3,473.09 3,364.09 1,010.10 -3,344.70 5,946,597.99 555,369.46 0.00 1,010.10 7,400.00 89.59 13.23 3,473.81 3,364.81 1,107.45 -3,321.81 5,946,695.50 .555,391.58 0.00 1,107.45 7,500.00 89.59 13.23 3,474.53 3,365.53 1,204.79 -3,298.93 5,946,793.01 555,413.70 0.00 1,204.79 7,600.00 89.59. 13.23 3,475.26 3,366.26 1,302.13 -3,276.05 5,946,890.52 555,435.82 0.00 1,302.13 7,700.00 89.59 13.23 3,475.98 3,366.98 1,399.48 -3,253.16 5,946,988.03 555,457.94 0.00 1,399.48 7,800.00 89.59 13.23 3,476.71 3,367.71 1,496.82 -3,230.28 5,947,085.54 555,480.07 0.00 1,496.82 7,895.63 89.59 13.23 3,477.40 3,368.40 1,589.91 -3,208.40 5,947,178.79 555,501.22 0.00 1,589.91 7,900.00 89.58 13.10 3,477.43 3,368.43 1,594.17 -3,207.40 5,947,183.05 555,502.18 2.98 1,594.17 8,000.00 89.34 10.11 3,478.38 3,369.38 1,692.11 -3,187.29 5,947,281.14 555,521.52 3.00 1,692.11 8,100.00 89.10 7.12 3,479.74 3,370.74 1,790.96 -3,172.32 5,947,380.10 555,535.72 3.00 1,790.96 8,200.00 88.87 4.13 3,481.50 3,372.50 1,890.45 -3,162.53 5,947,479.65 555,544.74 3.00 1,890.45 8,271.01 88.71 2.00 3,483.00 3,374.00 1,961.34 -3,158.74 5,947,550.56 555,547.97 3.00 1,961.34 1J-170 L1 T 1 (wp05) 8,300.00 88.85 1.14 3,483.62, 3,374.62 1,990.31 -3,157.95 5,947,579.54 555,548.54 3.00 1,990.31 8,400.00. 89.34 358.18 3,485.20 3,376.20 2,090.29 -3,158.54 5,947,679.49 555,547.17 3.00 2,090.29 8,488.42 89.77 355.56 3,485.89 3,376.89 2,178.56 -3,163.36 5,947,767.72 555,541.66 3.00 2,178.56 8,500.00 89.77 355.56 3,485.94 3,376.94 2,190.11 -3,164.26 5,947,779:26 555,540.67 0.00. 2,190.11 8,600.00 89.77 355.56 3,486.34 3,377.34 2,289.81 -3,171.99 5,947,878.89 555,532.16 0.00 2,289.81 8,700.00 89.77 355.56 3,486.74 3,377.74 2,389.51 -3,179.73 5,947,978.51 555,523.65 0.00 2,389.51 8,800.00 89.77 355.56 3,487.15 3,378.15 2,489.21 -3,187.46 5,948,078.14 555,515.14 0.00 2,489.21 8,900.00 89.77 355.56 3,487.55 3,378.55 2,586.91 -3,195.20 5,948,177.77 555,506.63 0.00 2,588.91 9,000.00 89.77 355.56 3,487.95 3,378.95 2,688.61 -3,202.93 5,948,277.39 555,498.12 0.00 2,688.61 9,100.00 89.77 355.56 3,488.36 3,379.36 2,788.31 -3,210.67 5,948,377.02 555,489.61 0.00 2,788.31 .9,200.00 89.77 355.56 3,488.76 3,379.76 2,888.01 -3,218.40 5,948,476.65 555,481.09 0.00 2,888.01 9,300.00 89.77 355,56 3,489.16- 3,380.16 2,987.71 -3,226.14 5,948,576.27 555,472.58 0.00. 2,987.71 9,400.00 89.77 355.56 3,489.57 3,380.57 3,087.41 -3,233.87 5,948,675.90 555,464.07 0.00. 3,087.41 9,500.00 89.77 355.56 3,489.97 3,380.97 3,187.11 -3,241.61 5,948,775.53 555,455.56 0.00 3,187.11 9,600.00 89.77 355.56 3,490.37 3,381.37 3,286.81 -3,249.34 5,948,875.15 555,447.05 0.00. 3,286.81 9,700.00 89.77 355.56 3,490.78 3,381.78 3,386.51 -3,257.08 5,948,974.78 555,438.54 0.00 3,386.51 9,800.00 89.77 355.56 3,491.18 3,382.18 3,486.21 -3,264.81 5,949,074.41 555,430.02 0.00 3,486.21 9,900.00 89.77 355.56 3,491.58 3,382.58 3,585.90 -3,272.55 5,949,174.03 555,421.51 0.00 3,585.90 10,000.00. .89.77 355.56 3,491.99 3,382.99 3,685.60 -3,280.28 5,949,273.66 555,413.00 0.00 3,685.60 .10,100.00 89.77 355.56 3,492.39 3,383.39 3,785.30 -3,288.02 5,949,373.29 555,404.49 0.00 3,785.30 4/10/2006 12:12:42PM Page 3 of 6 COMPASS 2003.118u~7d 50 ~3tnl~ . v ' .,a Hal~iburton Energy Services ~ Ct3i10CCtPh1~t~33S Planning Report -Geographic Alaska Sperry 17rilling Senriices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+g1)} Project: Kuparuk River Unit.. MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Site:. Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 L1 Design: 1J-170 L1 (wp05) Planned Survey 1J-170 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/.y~ Northing.. Fasting DLSEV ' Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,200.00 89.77 355.56 3,492.79 3,383.79 3,885.00 -3,295.76 5,949,472.91 555,395.98 0.00 3,885.00 10,300.00 89.77 355.56 3,493.20 3,384.20 3,984.70 -3,303.49 5,949,572.54 555,387.47 0.00 3,984.70 10,400,00 89.77 355.56 3,493.60 3,384.60 4,084.40 -3,311.23 5,949,672.17 555,378.95 0.00. 4,084.40 10,481.34 89.77 355.56 3,493.93 3,384.93 4,165.50 -3,317.52 5,949,753.20 555,372.03 0.00 4,165.50 10,500.00 89.77 356.12 3,494.00 3,385.00 4,184.11 -3,318.87 5,949,771.80 555,370.53 2.99 4,184.11 10,586.89 89.79 358.73 3,494.33 3,385.33 4,270.90 -3,322.77 5,949,858.55 555,365.96 3.00. 4,270.90 10,600.00 89.79 358.73 3,494.38 3,385.38 4,284.01 -3,323.06 5,949,871.66 .555,365.56 0.00 4,284.01 10,700.00 89.79 358.73 3,494.75 3,385.75 4,383.98 -3,325.28 - 5,949,971.60 555,362.57 0.00 4,383.98 10,800.00 89.79 358.73 3,495.12 3,386.12 4,483.96 -3,327.49 5,950,071.55. 555,359.57 0.00 4,483.96 10,900.00 89.79 358.73 3,495.48 3,386.48 4,583.93 -3,329.71 5,950,171.49 555,356.58 0.00 4,583.93 11,000.00 89.79 358.73 3,495.85 3,386.85 4,683.91 -3,331.93 5,950,271.43 555,353.58 0.00 4,683.91 11,100.00 89.79 358.73 3,496.22 3,387.22 4,783.88 -3,334.14 5,950,371.38 555,350.59 0.00 4,783.88 11,200.00 89.79 358.73 3,496.58 3,387.58 4,883.86 -3,336.36 5,950,471.32 555,347.59 0.00 4,883.86 11,300.00 - 89.79 358.73 3,496.95 3;387.95 4,983.83 -3,338.58 5,950,571.27 555,344.59. 0.00 4;983.83 11,400.00 89.79 358.73 3,497.32 3,388.32 5,083.81 -3,340.79 5,950,671.21 555,341.60 0.00 5,083.81 11,500.00 89.79 358.73 3,497.68 3,388.68 5,183.78 -3,343.01 5,950,771.16 555,338.60 0.00 5,183.78 11,586.89 89.79 358.73 3,498.00 3,389.00 5,270.65 -3,344.93 5,950,858.00 555,336.00 0.00 5,270.65 1J-170 L1 T2 (wp05) 11,600.00 89.66 358.73 3,498.06 3,389.06 5,283.76 -3,345.22 5,950,871.10 555,335.61 1.00 5,283.76 11,624.96 89.41 358.73 3,498.27 3,389.27 5,308.71 -3,345.78 5,950,896.05 555,334.86 1.00 5,308.71 11,700.00 89.41 358.73 3,499.04 3,390.04 5,383.73 -3,347.44 5,950,971.04 555,332.61 0.00 5,383.73 11,800.00 89.41 358.73 3,500.07 3,391.07 5,483.70 -3,349.66 5,951,070.98 555,329.61 0.00 5,483.70 11,900.00 89.41 358.73 3,501.10 3,392.10 5,583.67 -3,351.88 5,951,170.92 555,326.61 0.00 5,583.67 11,987.13 89.41 358.73 3,502.00 3,393.00 5,670.77 -3,353.82 5,951,258.00 555,324.00 0.00 5,670.77 1J-170 L1 T3 (wp05) 12,000.00 89.28 358.73 3,502.15 3,393.15 5,683.64 -3,354.10 5,951,270.86 555,323.61 1.00 5,683.64 12,064.32 88.64 358.73 3,503.32 3,394.32 5,747.93 -3,355.53 5,951,335.14 555,321.69 1.00 5,747.93 12,100.00 88.64 358.73 3,504.16 3,395.16 5,783.59 -3,356.32 5,951,370.79 555,320.62 0.00 5,783.59 12,200.00 88.64 358.73 3,506.54 3,397.54 5,883.54 -3,358.54 5,951,470.71 555,317.62 0.00 5,883.54 12,300.00 88.64 358.73 3,508.92 3,399.92 5,983.49 -3,360.76 5,951,570.62 555,314.62 0.00 5,983.49 12,387.45 88.64 358.73 3,511.00 3,402.00 6,070.89 -3,362.70 5,951,658.00 555,312.00 0.00 6,070.89 1J-170 L1 T4 (wp05) 12,400.00 88.40 358.81 3,511.32 3,402.32 6,083.43 -3,362.97 5,951.,670.54 555,311.63 1.99 6,083.43 12,500.00 86.52 359.50 3,515.75 3,406.75 6,183.32 -3,364.44 5,951,770.40 555,309.38 2.00 6,183.32 12,504.42 86.44 359.53 3,516.02 3,407.02 6,187.73 -3,364.47 5,951,774.81 555,309.31 2.00 6,187.73 12,600.00 86.44 359.53 3,521.96. 3,412.96 6,283.12 -3,365.26 5,951,870.19 555,307.78 0.00 6,283.12 12,648.92 86.44 359.53 3,525.00 3,416.00 6,331.95 -3,365.66 5,951,919.00 555,307.00 0.00 6,331.95 • L1 : BHL @ 12649ft MD, 3525ft TVD : ft 2854ft FSL 8~ 569ft F EL -Sec 27 - T11 N - R10E - 4112" -1J-170 L1 T5 Toe (wp05) 4/10/200612:12:42PM Page 4 of 6 COMPASS 2003.11 Build 50 ORDINAL '~°`' Halliburton Energy Services Conocc~Phili s ' Planning Report -Geographic Alaska Sperry tlriiiing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOfl (Doyon 141(28+81)) Project:` Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) Siter Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: .Minimum Curvature Wellbore: 1J-170 L1 Design: 1J-170L1 (wp05) Geologic Targets 1J-170 L1 TVD Target Pvame +N/S +E/-W Northing Fasting (ft) _ Shape.. ft ft (ft) : (ft) 3,433.96 1J-170 L1 DD Poly @ 95% 307.80 -3,464.28 5,945,894.85 555,255.37 - Polygon Point 1 -50.00 0.39 5,945,894.85 555,205.37 Point 2 -49.59 12.23 5,945,906.69 555,205.69 Point 3 -48.55 41.92 5,945,936.38 555,206.50 Point 4 0.92 410.64 5,946,305.44 555,253.09 Point 5 6.61 434.85 5,946,329.69 555,258.59 Point 6 205.88 1,282.52 5,947,178.81 555,451.22 Point 7 255.54 1,653.93 5,947,550.56 555,497.98 Point 8 250.91 1,871.13 5,947,767.70 555,491.66 Point 9 96.76 3,858.10 5,949,753.21 555,322.03 Point 10 91.51 3,963.49 5,949,858.55 555,315.96 Point 11 69.34 4,963.24 5,950,858.00 555,286.00 Point 12 68.51 5,001.08 5,950.,895.83 555,284.87 Point 13 60.46 5,363.36 5,951,258.00. 555,274.00 Point 14 58.75 5,440.54 5,951,335.16 555,271.69 Point 15 51.58 5,763.48 5,951,658.00 555,262.00 Point 16 49.80 5,880.32 5,951,774.81 555,259.31 Point 17 48.61 6,024.54 5,951,919.00 555,257.00 Point 18 148.62 6,023.76 5,951,919.00 555,357.00 Point 19 149.81 5,879.54 5,951,774.81 555,359.31 Point 20 151.59 5,762.70 5,951,658.00. 555,362.00 Point 21 158.76 5,439.76 .5,951,335.16 555,371.69 Point 22 160.47 5,362.58 5,951,258.00 555,374.00 Point 23 168.51 5,000.30 5,950,895.83 555,384.87 Point 24 169.35 4,962.46 5,950,858.00 555,386.00 Point 25 191.51 3,962.71 5,949,858.55 555,415.96 Point 26 196.76 3,857.32 5,949,753.21 555,422.03 Point 27 350.92 1,870.35 5,947,767.70 555,591.66 Point 28 355.55 1,653.15 5,947,550.56 555,597.98 Point 29 305.88 1,281.74 5,947,178.81 555,551.22 Point 30 106.62 434.07 5,946,329.69 555,358.59 Point 31 100.93 409.86 5,946,305.44 555,353.09 Point 32 51.46 41.14 5,945,936.38 555,306.50 Point 33 50.42 11.45 5,945,906.69 555,305.69 Point 34 50.00 -0.39 5,945,894.85 555,305.37 3,498.00 1J-170 L1 T2 (wp05} 5,270.65 -3,344.93 5,950,858.00 555,336.00 - Point 3,511.00 1J-170 L1 T4 {wp05) 6,070.89 -3,362.70 5,951,658.00 555,312.00 - Point 3,502.00 1J-170 L1 T3 (wp05} 5,670.77 -3,353.82 5,951,258.00 555,324.00 - Point 3,483.00 1J-170 L1 T1 {wpOS} 1,961.34 -3,158.74 5,947,550.56 555,547.97 - Point 3,525.00 1J-170 L4 T5 Toe (wp05) 6,331.95 -3,365.66 5,951,919.00 555,307.00 - Point 4/10/2006 12:12:42PM !g Pagp[leln\{p5 of 6 COMPASS 2003.11 Build 50 y ~ ~ 4~ 3 M ~-`' Halliburton Energy Services ~~ - -~ CQr10Ct?F'h11~pS Planning Report -Geographic Alaska 5percy tarilMing Sorvlces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109:OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit M D Reference: .Planned RKB @ 109:OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True WeIG Plan 1J-170 Survey Calculation Method: Minimum Curvature. Wellbore: 1J-170 L1 Design: 1J-170 L1 (wp05) Prognosed Casing Points Measured 'Vertical Casing Hole Depth Depth. Diameter Diameter (ftl (ft) („) (..) 80.00 80.00 20 20 3,018.00 2,145.00 10-3/4 13-1 /2 6,583.88 3,433.96 7-5/8 9-7/8 12.,648.91 3,525.00 4-1/2 6-3/4 4/10/2006 12:12:42PM Page 6 of 6 ~~~;~~ COMPASS 2003.11 Build 50 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 1J-170 L1 1 J-170 L1 (wp05) Anticollision Report 10 April, 2006 l~ ~p~ri ~riing a~~rces l~ ~'~, ~~ SURVEY PROGRAM Date: 2006-04-08700:00:00 Validated: Yev Verslsn: Depth From Depth To Survey/Plan T°°I 28A0 800.00 CB-GYROSS 800.00 6553.87 MWDtIFIi-AK CA7.SC 6583.87 12648.92 tJ-170 L1 (wp05) MWD+IFR-AK-CA7,..SC 0 1J-10 ANTI-COLLISION SETTINGS iolatlon Method: MD Interval: 505tatlons Range From: 6583.87 To 12648.9187712658 Maximum Range:1462.09187712658 Reference: Plan: 1J-170 L1 (wp05) 330 300 ConocoPhillips Alaska (Kuparuk) Drilling 8 Wells Slot West Sak 1J-170 Calcula0on Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Melhod: Rules Based 30 60 90 z7o so ~m Colour To MD 240 210 120 150 o szso i250 6500 i500 6750 i750 7000 1000. 7250 1250 7500 1500 7750 1750 8000 3000 ""'-'~ '"~'^ 8250 3250 8500 180 8500 8750 8750 9000 9000. 9250 9250 9500 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] s5oo s75o 9750 1000 10000 1025 10250 1050 10500 1075 10750 1100 NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-770 Ground Level: 81.00 +NIS +EI-W Northing Easting LaOltude Longitude 0.00 0.00 5945614.10 558721.61 70°1543.258N 149°31'31.065W 180 Travelling Cylinder Azimuth (TFO+A2;I) ~°] vs Centre to Centre Separation i15 ft/in] SECTION DETAILS Sec MD Inc Azi TVD +NIS +EI-W DLeg TFace VSec Target 1 6583.87 80.00 2.00 3433.96 307.80 .9464.28 0.00 0.0000 307.80 " 2 6595.87 .81.91 2.00 3435.84 319.64 -0463.86 15.90 o.aao9 319.64 3 6625.87 81.91 2.00 3440.06 349.32 .'1462.83 0.00 0.0000 349.32 4 6999.97 88.71 13.23 3470.73 718.04 -3413.35 3.50 59.2544 ~ 778.04 5 7024.86 89.59 13.23 3471.10 742.27 -3407.66 3.50 -0.0951 742.27 6 7895.83 89.59 13.23 3477.40 1589.91 3208.40 0.00 0.0000 156,9.91 7 8271.01 88.71 2.00 3483.00 1981.34 3158.74 3.00 54.5273 1961.34 1J-170 L1 T7 (wp04) 8 8488.42 89.77 355.56 3485.89 217856 316396 3.00 50.7095 2178.56 9 10481.34 89.77 355.58 3493.93 4165.50 3317.52 OAO 0.0000 4165.50 10 10586.89 89.79 358.73 3494.33 4270.90 3322.77 3.00 89.6238 4270.90 71 11586.89 89.78 358.73 3498.00 5270.65 3344.93 0.00 0.0000 5270.65 1J-170 L7 T2 (wp04) 12 11824.96 89.41 358.73 3498.27 5308.71 ,3345.76 1.00179.7575 5308.71 13 11987.13 B9A1 358.73 3502.00 5670.77 3353.82 0.00 0.0000 5670.77 1J-770 L7 T3 (wp04) 1412084.32 88.64 358.73 3503.32 5747.93 3355.53 1.00179.9937 5747.93 15 12387A5 88.64 358.73 3511.00 6070.89 3362.70 0.00 0.0000 6070.89 1J-170 L7 T4 (wp04) 1612504.42 86.44 359.53 3516.02 8187.73 3364A7 2.00160.0365 6187.73 17 12646.92 86.44 359.53 3525.00 6331.85 3365.66 0.00 0.0000 6331A5 1J-770 L1 TS Toe (wp04) REFERENCE INFORMATION 11000 1125 11250 1150 Co-ordinate (NIE) Reference: Well Plan 1J-170 -Slot 1J-170, True North Vertlcal (TVD) Reference: Planned RKB Q 109.OOR (DOyon 141 (28+61)) 11500 1175 Section (VS) Reference: Slot-1J-170(O.OON, O.OOE) 11750 12000 Measured Depth Reference: Planned RKB Q 109.OOft (Doyon 141 (28+81)) Calculatlon Method: Minimum Curvature 12000 13000 :7 Cc~n~c hilips Alaska Company: ; ConocoPhillips Alaska (Kuparuk) .Project: - Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error. O.OOft Reference Well: ' Plan 1J-170 Well Error: O.OOft Reference Wellbore 1J-170 L1 Reference Design: iJ-170 L1 (wp05) Halliburton Energy Services !-~A~.lha a .~- Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference:.. North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Sperry Ianlling Services Well Plan 1J-170-Slot 1J-170. Planned RKB @ 109.OOft (Doyon 141 (28+81)) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Ivtinimum Curvature ' 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-170 L1 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 6,583.87 to 12,648.92ft Scan Method: Trav. Cylinder North Results Limited by: Ma>amum center-center distance of 1,462.09ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma SI urvey Tool Program Date 4/10/2006 From To (ft) (ff) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-170 (wp05) (1J-170) CB-GYRO-S5 Camera based gyro single shot 800.00 6,583.87 1J-170(wp05)(1J-170) MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSCC 6,583.87 12,648.92 1J-170 L1 (wp05) (1J-170 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 12:14:48PM Page 2 of 4 COMPASS 2003.11 Build 50 a ~ f • ~`anc~ca'h~[i~~ Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk iJ-Pad Site Error: O.OOft Reference Well: Plan 1J-170 Well Error: O.OOft Reference Wellbore 1J-170 L1 Reference Design: '' 1J-170 L1 (wp05) • Halliburton Energy Services ~~~~- Antieoiiision Report --°---- - Sperry f)riifling Services Local Co-ordinate Reference: Well Plan 7J-170-Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: ^,4inimum Curvature Output errors are at ?_ 00 sigma Database: EDM 2003.11 Single User Db Offset TVD Reference:. Reference Datum Summary Site Name Offset Weli -',Nel{bore - Desrgn Kuparuk 1J Pad 1J-10 - 1J-10 - 1J-10 1J-159 - 1J-159 - 1J-159 1J-159 - 1J-159 L1 - 1J-159 L1 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 1J-159 - 1J-159 L1 P62 - 1J-159 L1 P62 1 J-159 - 1 J-159 L2 - 1 J-159 L2 1J-159 - 1J-159 PB1 - 1J-159 P61 1J-164 - 1J-164 - 1J-164 1J-164 - 1J-164 L1 - 1J-164 L1 1J-164- 1J-164 L2- 1J-164 L2 1J-164 - 1J-164 L2 P61 - 1J-164 L2 PB1 1J-166 - 1J-166 - 1J-166 1J-166- 1J-166 L1 - 1J-166 L1 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 PB1 1J-166 - 1J-166, L2 - 1J-166 L2 1J-166 - 1J-166 L2 P61 - 1J-166 L2 PB1 1J-168 - 1J-168 -1J-168 1J-168 - 1J-168 L1 - 1J-168 L1 1J-168 - 1J-168 L2 - 1J-168 L2 1J-168- 1J-168 L2 PB1 - 1J-168 L2 PB1 Plan 1J-115 -Plan 1J-115 - 1J-115 (wp02) Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01) Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) Plan 1J-123 Kuparuk Prelim - 1J-23 E Lat - 1J-23 E Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-231 Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI Plan 1J-127 -Plan 1J-127 - 1J-127 (wp03) Plan 1J-127 -Plan 1J-127 L1 - 1J-127 L1 (wp03) Plan 1J-127 -Plan 1J-127 L2 - iJ-127 L2 (wp03) Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispos Plan 1J-156 - 1J-156 - 1J-156 (wp04) Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp04) Plan 1J-156 -1J-156 L2 - 1J-156 L2 (wp04) Plan 1J-158 - 1J-158 - 1J-158 (wp03) Plan 1J-170 -1J-170 - 1J-170 (wp05) Plan 1J-170 - 1J-170 L2 - 1J-170 L2 (wp05) WSP-04 -WSP-04 -WSP-04 WSP-05 -WSP-05 -WSP-05 WSP-20 -WSP-20 -WSP-20 Offset Centre to No-Go Allowable Measured Centre ` Distance Deviation Warning Depth Distance (ft) from Plan (ft) (ff) (ft) I Reference Measured Depth (ft) 8,181.59 5,400.00 197.50 122.63 8,293.53 5,450.00 1,154.16 129.40 8,271.01 5,400.00 1,153.46 128.43 8,271.01 5,400.00 1,153.46 129.14 8,172.92 5,250.00 1,168.12 127.54 8,172.92 5,250.00 1,168.12 126.83 12,627.68 12,900.00 1,291.40 237.06 12,647.69 12,900.00 1,437.83 243.85 12,602.13 12,850.00 1,418.06 240.06 6,589.24 6,950.00 1,310.99 123.44 9,877.94 5,721.67 458.53 179.10 6,682.85 5,099.98 888.15 114.16 6,599.97 6,599.97 0.34 2.73 7,867.31 7,850.00 132.75 987.83 83.45 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 1,027.28 -:Pass -Major Risk 1,027.70 Pass -Major Risk 1,027.00 Pass -Major Risk 1,043.94 Pass -Major Risk 1,044.65 Pass -Major Risk 1,055.92 Pass -Major Risk 1,194.47 Pass -Major Risk 1,178.55 Pass -Major Risk 1,207.13 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 289.13 Pass -Major Risk Out of range Out of range Out of range 775.11 Pass -Major Risk -2.03 FAIL -Major Risk -705.63 FAIL -Major Risk Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/200612:14:48PM Page 3 of 4 COMPASS 2003.118uild 50 ~1~~~~~~ ~a~ . ~ . ~~ . ~ ~. _ u_ _1_J-17OL~Drillin~ Hazards ~ummary (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 opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pum in out, backreamin 1J-170L1 Drilling Hazards Summary prepared by Shane Cloninger 3/20/2006 1:32 PM 20" 91.5# x 34" Insulated Conductor, K-55, set at +/. 80' 11"x 5" Vetco Gray MB 228 Wellhead tubing, Special Drift to +/. 500' MD 3.875" DB Nipple, for Possible SSSV GLM, Camco KBG-2, 4.1/2" X 1" 10-3/4", 45.5#, BTC ~~ Shoe set @ 3018' MD, 2145' TVD, 66 deg/ Tubing String 4-1/2" 12.8#, L-80, IBTM 3.958" ID, 3.833" Drift 5-1/2" X 7-518" ZXP Liner ~ Top Packer w/ Hold Seal Assembly Downs 4.75" Seal OD. GLM, Camco KBG-2, 4-1/2" X 1" CMU Sliding Sleeve, w/ 3.81" DB Nipple Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window at 6138' MD, 3347' TVD Liner Swivel 4112" 11.8# L-80 Slotted Liner Every Other Joint ~ ~~ / ~ i - ~ '` 4 112" X 7518" Seal Bores Model'B- HOOK Ha-~orr 3.68" ID 5.112" X 7.518" ZXP Liner Top Packer w! Hold Downs Lateral Entry Module fLEM~ Assembly +--- 5.1/2" X 7.518" ZXP Liner Top 'I Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID OrfenOng Pro01e Automatic Alignment of LEM Positive Latching Collet Indicates Conect Location ~ Seal Bore for Lateral Isolatlon - 3.68" ID. Access Window PosiOve Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" SeaI~OD 3.875" Seal ID Casing Sealbore Receptacle 20' Length 4-112" X Seal Assembly 4.75" Seal OD ~t)C®~1~~~1~35 West Sak 7-5/8" Injector 1J-170 Tri-Lateral Completion 'D' Sand Lateral -,/2" Bent Joint i 3.1/2" Guide Shoe 4-1/2" Liner Shoe, 11.8#, L-80 BTC Set @ 12736' MD, 3470' TVD l ..__~ ..........:.: .. ..1\ s Planned rie® NYP Baker Oil Tools >_ateral Entry M odule (~N~I VJfith Diverters a , nd Isolation . Lateral Access Diverter Lateral Isolation Diverter GS Running ToolString Installetl installetl (3.00" Lateral Orlft) (2.50" ID Mainbore Drih) 'GS' Pro81e for '•~ Coil Connector ~RunninglRetrleving ~ , (1.00' Length) :., i . Snap InlSnap Out ~ ~rBack Pressure Valve - /PosiBve Loeatlngti '- (1.80' Length) Collet r Flow-Thru Swivel ~ Laterel Isolatlon (1.25' Length) Seals H d ~/ Laterai Di vorter ;, ~~~ y raulic ~ p Diswnnect (1.50' Length) IsolatioN Mainborer~ ; . ~~ GS Spear (1.50' Length) - ~ 1. Diverter Sleeve Late I I lag ~~ . -- ra so on 6.85 a Seals Lateral Entry Module(LEM) wy~ ~4~ ~ ~., ,; B-saDd WindOW `~ 'Jars may 6e required In hig tlal;iatetl 1a5' Diverter Length 18.5' Sleeve Len th at 6584' MD, 3434' TVD ' ' or deep applications (6' approx Jeri§th)., e B Sand Lateral ~' Liner Swivel 4.1/2" 11.6# L-80 Slotted Liner Every Other Joint 3-112" Bent Joint ~~ 3.112" Guide Shoe 4-1 /2" Liner Shoe, 11.8#, L-80 BTC Seal Bores Set @ 12649' MD, 3525' TVD 3.68" ID 3.582° DB Nipple ` x~ 12".,12,6# Tebin .. ~ J ` 1. ~ ~..'.L, ... ,_.-__~--.-- 3.833"Drift \ ...,_, ~...._.. _~ w,_. n....----~.........,.,~,.__ 3.858" ID ~ ~ \4~ ~ a 5-112" X 7.5/8" ZXP •...`.~ Liner Top Packer ~ with Hold Downs ~ .~ ~`` 5.112" X 7.518" Liner Hanger/Packer Assembly at Flex Lock +/- 8684' MD Liner Hanger Casing Sealbore Receptacle, 20' Length 4-'IJl2" X 7-518" HOOK Hanger ~,,,/ Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverteror LEM: 3.88" Lateral Drift, w/diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entty Module Mainbore Drill: 3.65" Mainbore Drift, w/ Isolaton sleeve: 2.50" Seal Assembly Lateral Drift, w/ coil diverter: 3.00" 4.75" Seal OD - OD of Diverter and Sleeve: +l- 3.88" ~ 'A' Sand Undulatlno Lateral Diverter and sleeve Length:+/.19.5' a 4-1/2" 11.8# L50 Slotted j ~ Liner Every Other Joint 4.1/2" Eccentric .., /~,,,„ Guide Shoe- ~l -r 4-1 /2" Casing Shoe, 11.8#, L-80 BTC .,...: t~ ..--..."" ~ Set @ 12508' MD, 3843' TVD 7-5/8" Casing L-80, BTCM, Set at ®eakar Hughes 2006 Thle document may not ba reprodueed or tllatdbuted, In whole or In part, In any farm or @ 7881' MD, 3819' TVD (85 deg) by mymeans eleehomc or mechenltal, inclutling photowpying, reeording, or by any Information storage and retrieval system now known or herea(tw inwntad, withoue wriaen parm4elon h°m Baker aughae Inc. Weat Sak 7d/e• Td-lateral Complatlan • Infector. Ma 3, 2006 Orewn ey. I Y Maro D. Kuck 1 • • • TRANSMITTAL LETTER CHECKLIST WELL NAME 7~~~ ~ ~ ~~d ~• PTD# ZOO 'Olo 3 Development V Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing Fell ~2GC /~- /~Z~ (If last two digits in API b Permit o. 1-OG, ~ API No. so- GL~' - L33la -per. num er are .~., between 60-69) ton should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -__) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl ist ELL PERMIT CHECKLIST Field & Pcol KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-170L1 Program SER Well bore seg ^~ PTD#:2060630 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - West Sak B Sand multilateral well branch; fee waived per 20 AAC 25.005(e).- _ - . - - ----------------- 2 Lease number appropriaie_-----_-__----_--------------- ---------Yes--_ --_ Top_productiveintervalandTD_inADL02566Q.-_ -__ - - 3 Unique well-name andnumber__ _ ___________ __ _ __ ___ ___ __ Yes___ ___._._ _- _-_ ___________ ----------------------------------------- 4 Well located ina-defned-pool------------------------------ ---------Yes-_- ___KuparukRiver,West_$akOilPool-49Q150,-goyerned_byCO406B___-_______---_-.-_-.--- 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - _ _ -Yes Wefl is more_than-500 feet from as external property line. - _ - - - - _ - - - - , - _ _ _ - - - 6 Well located proper distance from_ other wells_ Yes - - - - - - - CO 4066, Rule 3; no restrictions as. to well spacing except that no_pay shall be opened in a well closer - - _ - 7 Sufficient acreage available in_drillingunit- - - - - - - - - - - - - - - - - - - - - - - - - - Yes than 50-0 feet to_anexternal-property line where ownership_ or landownership changes. _ _ --------------- 8 If_deviated,is_we_Ilboreplat_included-------------------------- ---------Yes___ ________-_--__--_---------_--__-__ - - - - 9 Operator only affected party____,------------------- --. Yes--- ---------- -------------------------------------------------------------- 10 Operator hasappropRate.bondinforce.---------- - --- -- - -- ----- Yes-- -- -- -- ----------- ----------- --- ---- --------- -- ------- - -- - 11 Permit. can be issued without conservation order_ _ - - - - Yes _ - - _ _ . _ - - --------------- Appr Date 12 Permit can be issued without administrative-approval _ - - - _ _ _ _ _ - - _ _ - - _ Yes _ _ _ - - - - - - SFD 5112!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (put1O# in-comments)-(For- Yes - - - . - -Area Injection Order No.-26 - _ . - - - - - - - - - - - - - 15 All wells_within 114_mile area of review identified (Far service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ KRl11J-10, KRl11J-168L1,1 E-1-05L1_ (toe). _ $ee close-approach diagrams and-calculations in PTD 2060620. _ - , 16 Pre-produced injector; dur-anon-ofpre-production less than- 3 months. (For service well only) - -Yes - - _ _ - _ David_ Nugent, CPAI,_5116106; This well wilf_be flowed_ back for 30 days for clean-up, _ _ . - _ _ - - - ACMP_Finding of Consistency_has been issued_for_this project_ NA_ _ _ - _ _ - ACMP determ_in_ation_n_oJonger_affects AOGCC approval!-of permitto drill._ Engineering 18 Conductor string_provided NA_ _ _ -- ------ _ _ _ . Conductor set_in motherbore,_ 1J-170 {206-062) _ - - . - - - . - - - _ - 19 Surface casing-protec-tsall-known_USDWs____________________- ____--__-NA____ -_--All aquifersex_empted,40CFR-147.1Q2-(b)(3).--______.__________ ---------------------- 20 CM_T_vol_adeguate_to circulate-on conductor& surf_csg - - - - - - - - - - - - - - - - - - - - - - NA_ - Surface casing set in 1J-170._ _ - -- -- 21 CMTyolade9uate_totie-inlongstringtosurfcsg--_-____-_-_----- ---------NA_-_- __Pr_oductioncasingset in-1J-170._-___-_____--__--__--_____-------.- ------------- 22 CMT_willcoverallknownproductivehorizon_s_-__________________ _________No_-_- ----$lotte-dlinercompletion planned._-.-_--_--__--__-._ ------------------------------ 23 Casing designs adequate far C, T, B &_permafrost_ - _ -Yes - - - - - - - Motherbore meets design.requiremenis, NA-for-slotted liner. - - - - - - - 24 Adequate tankage_or reserve pit Yes - _ - - - - -Rig is.equipped with st_eetpits. No reserve-pitplanned, All waste to approved annulus or disposal wells. - - - - - 25 If_a_re-drill,has_a_10-403 for abandonment been approved.-------_--_ __-___-- NA____ ___________________ -------------------------------------- --------------- 26 Adequate wellbo-re separation_proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes . - . _ . - -Proximity analysis performed, Nearest well segment_is 1J-170 ~ 100' tv_d below.- _ - - _ _ _ _ _ _ _ _ _ . - - - - - - - 27 Ifdiverterrequired, does it meetregulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -~ NA _~ ~,?,~~SL G\c@~~2c~~~G.~F _~?'~'~5(~fi - - - ------------------------ Appr Date 28 Otilling flujd-program schematic & equip list_adequate- - - - - - - - - - - - - - - - - Yes Maximum expected formation pressure 8.7_EMW._ Planned MW 8.8ppg.- . - - - - - - _ - - TEM 5125!2006 29 BOPEs,.dotheymeetregulation-__-____------------------- ---------Yes__- _-____________-- _---_--_----___ -- ~(~~ 30 BOPE_press rating appropriate; test to.(put prig m comments) _ . _ _ Yes - - MASP calculated at 1199 psi 3K stack arrangement and BOP test planned. Jam' 31 Choke_manifold complies wlAPt RP-53 (May 84) Yes _ - _ -- 32 Work willoccurwithoutoperationshutdown_____--_------------- ---------Yes-__ --__-______-.__ --_-. -------------- ------------------------------------- 33 Is pre&enGe-of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No- - _ _ _ _ _ _ H2S has notbeen [epor#ed on 1J pad. Rig is equipped with_sensors and alarms. - - - - - - - - - _ _ _ _ _ _ _ _ - - - 34 Mechanical_condkion of wells within AOR verifed GFo[service well only) Yes - - - - - - 1J-10_and 1J-168_s_atisfactorily cemented. Other approaches within zone. _ _ - - _ - - - - - - Geology 35 Permik can be issued w!o hydrogen_sulfidemeasures - Yes _ - _ _ . - _ None expected.- Rig has sensors and-alarms. _ - - . - - . - - - - -------------- 36 Data_presenied 4n-potential overpressure zones- - - - - - - - - - - - - - - - - - - - Yes - - _ - - _ Expected r-es.-pressure is ~8.7ppg EMW, will be drilled with 8.8 ppgoil-based mu_d, ---------- Appr Date 37 Seismic analysisofshallowgas_zones_________________________ _________NA__-- -____ SFD 5/1212006 38 Seabed conditionsurvey_(ifoff_-shore)_________________________ _________NA-_-- - __._ - ----- ------------------------------------------- 39 Contact namelphone for weekly-progress reports_[exploratorynnly] - - NA_ _ - _ Geologic Commissioner: Engineering P lic Date: Commissioner Date inner Date West Sak B sand in ector. This is one of the well branches from tri-lateral roduction well KRU 1J-170. SFD 1 P ~ / ~) 2s 1 ~ ~~-~ ~''~~~ 4-~ • • Well History Fife 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 tl~e file under APPENDIX. No special effort has been made io chronologically organize this category of information. Sperry-Sun Dri~ ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 18 13:51:41 2006 Reel Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-170 L1 API NUMBER: 500292331060 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-JUL-06 JOB DATA MWD RUN 3 MWD RUN 8 MWD RUN 10 JOB NUMBER: W-0004406587 W-0004406587 W-0004406587 LOGGING ENGINEER: P. ORTH T. GALVIN T. GALVIN OPERATOR WITNESS: M. THORNTON D. GLADDEN D. GLADDEN MWD RUN 11 JOB NUMBER: W-0004406587 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 35 11N l0E 1802 2490 109.00 81.00 OPEN HOLE CASING DRILLERS ~0~-0~3 /`/fit 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 3041.0 7.625 6828.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 6828' MD/3478'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-170 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND 22' OF RAT HOLE WERE DRILLED DURING MWD RUN 8. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,10,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 10,11 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO PROGRESS WAS MADE DURING MWD RUN 9. 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 1-3,8,10,11 REPRESENT WELL 1J-170 L1 WITH API#: 50-029-23310-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12602'MD/3552'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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 DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 3004.0 12545.0 RPM 3020.0 12552.0 RPS 3020.0 12552.0 FET 3020.0 12552.0 RPD 3020.0 12552.0 RPX 3020.0 12552.0 ROP 3050.5 12602.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3004.0 8 6828.5 10 6864.0 11 9440.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6828.0 6864.0 9440.0 12602.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log .depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type.. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR ~IWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3004 12602 7803 19197 3004 12602 RPD MWD OHMM 0.63 2000 50.3503 19065 3020 12552 RPM MWD OHMM 1.33 2000 52.5702 19065 3020 12552 RPS MWD OHMM 1.43 2000 46.7025 19065 3020 12552 RPX MWD OHMM 4.84 2000 41.5091 19065 3020 12552 FET MWD HOUR 0.17 2 80.36 1.07886 19065 3020 12552 GR MWD API 20.08 1 24.01 63.8002 19083 3004 12545 ROP MWD FT/H 0.~ 547.49 First Reading For Entire File..........3004 Last Reading For Entire File...........12602 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER 189.093 19104 050.5 12602 FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3004.0 6828.0 RPM 3020.0 6828.0 RPD 3020.0 6828.0 RPX 3020.0 6828.0 FET 3020.0 6828.0 RPS 3020.0 6828.0 ROP 3050.5 6828.0 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6828.0 TOP LOG INTERVAL (FT) 3050.0 BOTTOM LOG INTERVAL (FT) 6828.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.1 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 9.875 3041.0 • Lignosulfanate 8.90 63.0 9.3 150 5.2 3.650 70.0 2.910 89.6 3.600 70.0 3.900 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3004 6828 4916 7649 3004 6828 RPD MWD030 OHMM 0.63 2000 21.7487 7617 3020 6828 RPM MWD030 OHMM 1.33 1392.15 15.6333 7617 3020 6828 RPS MWD030 OHMM 1.43 120.17 14.9332 7617 3020 6828 RPX MWD030 OHMM 4.84 99.99 13.5673 7617 3020 6828 FET MWD030 HOUR 0.17 52.29 1.04433 7617 3020 6828 GR MWD030 API 20.08 124.01 69.1956 7649 3004 6828 ROP MWD030 FT/H 2.52 547.49 197.436 7556 3050.5 6828 First Reading For Entire File..........3004 Last Reading For Entire File...........6828 z+: l ., m,^., , l ., ,.. Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6828.5 6864.0 LOG HEADER DATA DATE LOGGED: 12-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6884.0 TOP LOG INTERVAL (FT) 6828.0 BOTTOM LOG INTERVAL (FT) 6884.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6828.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 15500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 82.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: ~ .000 ~0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6828.5 6864 6846.25 72 6828.5 6864 ROP MWD080 FT/H 0.3 20.09 6.83847 72 6828.5 6864 First Reading For Entire File..........6828.5 Last Reading For Entire File...........6864 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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. BI T RUN NUMBER: 10 DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6828.5 9383.0 FET 6828.5 9390.0 RPX 6828.5 9390.0 RPD 6828.5 9390.0 RPS 6828.5 9390.0 RPM 6828.5 9390.0 ROP 6864.5 9440.0 LO G HEADER DATA DATE LOGGED: 14-JUN- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9440.0 TOP LOG INTERVAL (FT) 6884.0 BOTTOM LOG INTERVAL (FT): 9440.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 92:0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6828.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 77.0 MUD PH: .0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame .Spacing.......... ~.......60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6828.5 9440 8134.25 5224 6828.5 9440 RPD MWD100 OHMM 13.72 1341 52.8426 5124 6828.5 9390 RPM MWD100 OHMM 14.83 207.35 54.3282 5124 6828.5 9390 RPS MWD100 OHMM 14.62 2000 53.1068 5124 6828.5 9390 RPX MWD100 OHMM 14.15 1857.93 50.8993 5124 6828.5 9390 FET MWD100 HOUR 0.2 280.36 1.44785 5124 6828.5 9390 GR MWD100 API 34.24 87.61 61.1584 5110 6828.5 9383 ROP MWD100 FT/H 0.69 294.71 185.828 5152 6864.5 9440 First Reading For Entire File..........6828.5 Last Reading For Entire File...........9440 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9383.5 12545.0 RPX 9390.5 12552.0 . RPD 9390 12552.0 RPM 9390.5 12552.0 FET 9390.5 12552.0 RPS 9390.5 12552.0 ROP 9440.5 12602.0 LOG HEADER DATA DATE LOGGED: 16-JUN- 06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12602.0 TOP LOG INTERVAL (FT) 9440.0 BOTTOM LOG INTERVAL (FT) 12602.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6828.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 16000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9383.5 12602 10992.8 6438 9383.5 12602 RPD MWD110 OHMM 6.24 2000 82.7803 6324 9390.5 12552 RPM MWD110 OHMM 5.93 2000 95.6347 6324 9390.5 12552 RPS MWD110 OHMM 6.12 2000 79.7783 6324 9390.5 12552 RPX MWD110 OHMM 5.61 2000 67.5555 6324 9390.5 12552 FET MWD110 HOUR 0.22 14.17 0.82149 6324 9390.5 12552 GR MWD110 API 22.59 1 20.98 59.409 6324 9383.5 12545 ROP MWD110 FT/H 1.52 3 93.38 183.86 6324 9440.5 12602 First Reading For Entire File..........9383.5 Last Reading For Entire File...........12602 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Scientific Technical Services Scientific Technical Services Physical EOF End Of LIS File