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Home My WebLink About204-2471. 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-Offset Producer 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 12414'feet None feet true vertical 3671' feet None feet Effective Depth measured 12414'feet 4695', 4676'feet true vertical 3671' feet 3570', 3565' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 4714' MD 3565' TVD Packers and SSSV (type, measured and true vertical depth) 4695' MD 4676' MD N/A 3570' TVD 3565' 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: 2662' 2394' Burst Collapse Production D Sand Liner 4789' 7571' Casing 3694' 4-1/2" 5267' 12383' 3670' 2632' 108'Conductor Surface Intermediate 20" 10-3/4" 75' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-247 50-029-23238-60-00 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: ADL0025648, ADL0025651 Kuparuk River Field/ West Sak Oil Pool KRU 1E-121L1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RPPG pumped down 1E-102L1 (Injector) (See details in Well Events.) Packer: Baker GBH-22 Seal Assembly Packer: ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 265-6471Staff Well Interventions Engineer 4904-8831', 9048-11966', 12150-12335' 3622-3709', 3709-3674', 3676-3671' 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 10:51 am, Aug 25, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.25 08:11:05-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne J.Lau 11/4/25 DSR-9/11/25 RBDMS JSB 082825 DTTMSTART JOBTYP SUMMARYOPS 7/28/2025 OPTIMIZE WELL PUMP FULL BORE RPPG TO MBE AT 10161' IN THE D-SAND LATERAL. PUMPED 20282.5 LBS OF DAQING RRPG . 3.8 BPM @ 1.15 PPG AT 276 JSV, AVG RATE 3.7 BPM, AVG PSI 891. DROP TO 2.6 BPM @ 1.0 PPG AT 461 JSV, AVG RATE 2.8 BPM, AVG PSI 961 INCREASE TO 3.3 BPM @ 1.06 PPG AT 505 JSV, AVG RATE 3.3 BPM, AVG PSI 957 INCREASE TO 3.8 BPM @ 1.15 PPG AT 530 JSV, AVG RATE 3.7 BPM, AVG PSI 891 INCREASE TO 4.5 BPM @ 1.375 PPG AT 619 JSV, AVG RATE 4.5 BPM, AVG PSI 923 STAGE TO FLUSH @ 662 JSV, AVG RATE 3.8 BPM, AVG PSI 906. MAX PSI 1005. WELL TO REMAIN SHUT IN FOR 48 HRS TO ALLOW RPPG TO FULLY CROSSLINK 1E-102/ 1E-121 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 4,183.0 1E-121 11/2/2008 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replace St#1 GLV 1E-121 2/17/2023 jhanse11 Notes: General & Safety Annotation End Date Last Mod By NOTE: RESTRICTION @ 4637" CTMD, COULD NOT DRIFT 2.80" 5/18/2011 ninam NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 11/6/2008 lmosbor NOTE: MULTI-LATERAL WELL - 1E-121 (B-SAND), 1E-121L1 (D-SAND) 2/6/2005 osborl NOTE: TREE CAP CONNECTION: 9"" OTIS 2/6/2005 osborl NOTE: TREE - ABB VETCO GRAY / Horz / 4-1/16"" 5M (w/PENETRATOR WIRE) 2/6/2005 osborl 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 33.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,661.9 2,393.7 45.50 L-80 BTC D SAND WINDOW 7 5/8 6.83 4,816.0 4,828.0 3,604.5 INTERMEDIATE 7 5/8 6.87 26.5 5,267.0 3,694.1 29.70 L-80 BTCM B SAND LINER 4 1/2 3.96 4,905.0 12,388.0 3,740.6 12.60 L-80 DWC/IBT L1 LINER LEM 4 1/2 3.91 4,676.3 4,947.0 3,637.2 12.60 L80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.7 Set Depth … 4,713.5 Set Depth … 3,574.5 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L80 Top Connection EUE8RD ID (in) 2.99 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) 22.7 22.7 0.10 HANGER 10.800 VETCO GRAY TUBING HANGER w/PUP 4.500 55.6 55.6 0.25 XO 4.5x3.5 4.500 3.500 516.3 516.2 4.04 NIPPLE 4.520 CAMCO 'DS' NIPPLE 2.875 2,805.3 2,508.3 36.39 GAS LIFT 5.390 XXXXXX CAMCO KBMG 2.920 4,505.7 3,514.8 69.08 GAS LIFT 5.390 Camco 3 1/2" X 1" KBMG w/ DCK-2 SOV and BEK-Latch CAMCO KBMG 2.920 4,614.4 3,548.7 74.59 NIPPLE 4.500 CAMCO 'DS' NIPPLE Camco DS 2.812 4,625.6 3,551.6 74.90 GAUGE 5.600 Baker Guardian Gauge Baker Guardia n 2.992 4,673.6 3,564.1 74.87 XO - Enlarging 4.910 3 1/2" EUE box X 4 1/2" IBTM pin Crossover 2.992 4,684.8 3,567.1 74.87 LOCATOR 5.490 4 1/2" IBTM Coupling w/ Locator Ring 3.900 4,695.4 3,569.8 74.86 SEAL ASSY 4.740 GBH-22 Seal Assembly (2 ft space out) Baker GBH-22 3.870 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) 32.0 32.0 0.14 HEAT TRACE HEAT TRACE 2/4/2009 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,805.3 2,508.3 36.39 1 GAS LIFT GLV BK-5 1 1,445.0 2/17/2023 0.188 4,505.7 3,514.8 69.08 2 GAS LIFT OV BK 1 0.0 1/26/2023 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,676.3 3,564.8 74.87 PACKER 6.550 ZXP LINER TOP PACKER 4.970 4,695.6 3,569.9 74.86 SBR 6.300 190-47 Casing Seal Bore Extension 4.750 4,760.1 3,586.7 74.86 NIPPLE 5.200 CAMCO 3.75" 'DB' Nipple 3.750 4,867.9 3,615.3 73.90 NIPPLE 4.875 BAKER 2.75" 'D' Nipple 2.750 4,905.0 3,625.8 73.60 PACKER 6.520 ZXP LINER TOP PACKER w/HRD PROFILE 4.970 4,924.0 3,631.1 74.19 NIPPLE 6.050 'RS' NIPPLE 4.875 4,956.8 3,639.7 75.20 XO BUSHING 6.070 CROSSOVER BUSHING 3.960 12,353.9 3,738.5 86.64 BUSHING 5.200 DRILLABLE PACKOFF 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,272.0 5,669.0 3,695.0 3,716.5 WS B, 1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS w/constrictor packers @ 5671', 5886', 6494', 6744', 12023', 12248' 5,886.0 6,496.0 3,726.4 3,741.7 WS B, 1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 6,745.0 12,003.0 3,749.1 3,731.4 WS B, 1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 12,258.0 12,350.0 3,733.2 3,738.2 WS B, 1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 1E-121, 8/11/2025 2:30:36 PM Vertical schematic (actual) B SAND LINER; 4,905.0- 12,388.0 IPERF; 12,258.0-12,350.0 IPERF; 6,745.0-12,003.0 IPERF; 5,886.0-6,496.0 IPERF; 5,272.0-5,669.0 INTERMEDIATE; 26.5-5,267.0 L1 LINER LEM; 4,676.3-4,947.0 D SAND WINDOW; 4,816.0- 4,828.0 D SAND LINER; 4,812.2- 12,383.0 GAUGE; 4,625.6 GAS LIFT; 4,505.7 GAS LIFT; 2,805.3 SURFACE; 30.1-2,661.9 HEAT TRACE; 32.0 NIPPLE; 516.3 CONDUCTOR; 33.0-108.0 HANGER; 22.7 KUP PROD KB-Grd (ft) 33.61 RR Date 2/6/2005 Other Elev… 1E-121 ... TD Act Btm (ftKB) 12,415.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292323800 Wellbore Status PROD Max Angle & MD Incl (°) 93.31 MD (ftKB) 11,629.07 WELLNAME WELLBORE1E-121 Annotation Last WO: End Date 2/5/2009 H2S (ppm) 160 Date 8/12/2016 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 4,183.0 1E-121L1 11/2/2008 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1E-121L1 10/23/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: RESTRICTION @ 4637" CTMD, COULD NOT DRIFT 2.80" 5/18/2011 ninam NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 11/6/2008 lmosbor NOTE: MULTI-LATERAL WELL - 1E-121 (B-SAND), 1E-121L1 (D-SAND) 2/6/2005 osborl NOTE: TREE CAP CONNECTION: 9" OTIS 2/6/2005 osborl NOTE: TREE - ABB VETCO GRAY / Horz / 4-1/16" 5M (w/PENETRATOR WIRE) 2/6/2005 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D SAND LINER 4 1/2 3.96 4,812.2 12,383.0 3,670.5 12.60 L-80 DWC/IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,335.6 3,670.7 90.76 BUSHING 5.200 BAKER DRILLABLE PACKOFF BUSHING 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,904.0 8,831.0 3,621.8 3,708.5 WS D, 1E-121 2/4/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 9,048.0 11,966.0 3,709.3 3,673.7 WS D, 1E-121 2/4/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 12,150.0 12,335.0 3,676.5 3,670.7 WS C, WS D, 1E -121 2/4/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS w/constrictors @ 8851', 9031' 11981', 12152' 1E-121L1, 8/11/2025 2:30:36 PM Vertical schematic (actual) D SAND LINER; 4,812.2- 12,383.0 IPERF; 12,150.0-12,335.0 IPERF; 9,048.0-11,966.0 IPERF; 4,904.0-8,831.0 D SAND WINDOW; 4,816.0- 4,828.0 INTERMEDIATE; 26.5-5,267.0 L1 LINER LEM; 4,676.3-4,947.0 GAUGE; 4,625.6 GAS LIFT; 4,505.7 GAS LIFT; 2,805.3 SURFACE; 30.1-2,661.9 HEAT TRACE; 32.0 NIPPLE; 516.3 CONDUCTOR; 33.0-108.0 HANGER; 22.7 KUP PROD KB-Grd (ft) 33.61 RR Date 2/6/2005 Other Elev… 1E-121L1 ... TD Act Btm (ftKB) 12,414.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292323860 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 12,143.27 WELLNAME WELLBORE1E-121 Annotation Last WO: End Date 2/5/2009 H2S (ppm) 160 Date 8/12/2016 Comment 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. ~O 4:- - a Y-'J Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 15 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ Date: LfJla-1 D7 If NO in stage 1, page(s) discrepancies were found: Organizing (done) o Two-sided ""1111111111" III R~CAN \IZ1' Color Items: o Greyscale Items: DIGITAL DATA ~iskettes No. ~ o Other, Norrype: o Poor Quality Originals: o Other: NOTES: Date 1.f I ¡;}-f 0 7 Date If/I:J- ¡ D 7 a x 30 = 00 Date: if I la-I D 7 BY: (M~) Project Proofing BY: ~ Scanning Preparation BY: (" Maria) BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed flllIllIIII II 1/11/1 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VvlP ,:IIIIIIIIIII~ 11111 m P 151 + If- = TOTAL PAGES 74- , (Count does not include cover sheet) mp 151 III 11111I111111111I YES NO 151 W(; P NO 151 11111111111I111111I "' 11111111111 1111I 151 Quality Checked "'"1111111"11111 10/6/2005 Well History File Cover Page.doc r -- STATE OF ALASKA ALA OIL AND GAS CONSERVATION C011ikSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Rug Perforations { Perforate E Other MBE Sealing Alter Casing I Pull Tubing E Stimulate - Frac f� Waiver fl Time Extension r Change Approved Program EOperat. Shutdow n r Stimulate - Other E Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p` Exploratory r- 204 -247 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service F 50 029 - 23238 - 60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25648 " `- 1E 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12414 feet Plugs (measured) none t true vertical 3671 feet Junk (measured) none Effective Depth measured 12382 feet Packer (measured) 4676, 4905 true vertical 3670 feet (true vertical) 3565, 3620 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108 108 SURFACE 2632 10.75 2662 2394 INTERMEDIATE 4789 7.625 5257 3694 D SAND LINER 7571 4.5 12383 3670 RECEIVED Perforation depth: Measured depth: 4904 -8831, 9048 - 11966, 12150 -12335 FEB Z��, True Vertical Depth: 3622 -3709, 3709 -3667, 3676 -3671 AOGCC C Tubing (size, grade, MD, and TVD) 3.5, L80, 4714 MD, 3575 TVD L 2O 't� A Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 4676 MD and 3565 TVD SCANNED APR �� PACKER - ZXP LINER TOP PACKER @ 4905 MD and 3620 TVD SSSV - CAMCO DS NIPPLE @ 516 MD and 516 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 867 1167 306 -- 211 Subsequent to operation 173 1246 509 -- 210 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory 1 - Development Si - Service E Stratigraphic E 16. Well Status after work: , Oil Ni Gas it VVDSPL f Daily Report of Well Operations XXX GSTOR fmm VVINJ r WAG 1 GINJ E SUSP E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -181 Contact John Peirce a 265 -6471 Email John .W.Peirce @conocoohillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 2/00/i3 AOMS FEB 22 2013 v "/ Form 10 -404 Revised 10 4 j / /') Submit Original Only KUP • 1 E -121 L1 ConocoPhi lips illi Well Attributes Max Angle & MD TD Alaska Inc Wellbore API/UWI Field Name Well Status Incl r) MD (ftKB) Act Btm (ft8B) 500292323860 WESTSAK PROD 93.60 12,14327 12,414.0 CCMIX '1301146 " Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 30 9/15/2010 Last WO: 2/5/2009 33.61 2/6/2005 Well Conl9:- 1g2 1 AM Schematk- Actual Annotation Depth (5KB) End Date Annotation Last Mod By End Date Last Tag: CTMD 4,183.0 11/2/2008 Rev Reason: PULL PLUG ninam 11/7/2012 Casing Strings Casing Description String 0... String ID ... Top (ft6B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd '' D SAND LINER I 4 1/2 3.958 4,812.2 12,383.0 3,670.5 I 12.60 I L-80 DWC /IBT t a Liner Details Top Depth (N0) Top Inc! Nom)... , Top (51(B) MKS) (°) Item Description Comment ID (in) # ( 4,812.2 3,600.3 74.80 HANGER BAKER MODEL B1 FLANGED HOOK HANGER 5.630 12,335.6 3,670.7 90.76 PACKOFF DRILLABLE PACKOFF BUSHING 3.960 HANGER, 23, Perforations & Slots I Shot Top (ND) Bt(5 (ND) Dens Top (ftKB) Btm (ftKB) (5KB) (5KB) Zone Date KM— Type Comment 4,904 8,831 3,621.7 3,709.0 WS D, 1E-121 2/4/2005 32.0 IPERF ALL Alternating SLOTS /BLANKS CONDUCTOR, 9,048 11,966 3,709.3 3,667.4 WS D, 1E -121 2/4/2005 32.0 IPERF ALL AItemating SLOTS/BLANKS { 12,150 12,335 3,676.1 3,670.7 WS C, WS D, 2/4/2005 32.0 IPERF ALL Altemating SLOTS/BLANKS 1E -12 " w/ constrictors @ 8851', 9031' 11981', NIPPLE, 516 12152' HEAT TRACE, Notes: General & Safety 32 I End Date Annotation 2/6/2005 NOTE: MULTI - LATERAL WELL- 1E -121 (B- SAND), 1E -121L1 (D -SAND) r 2/6/2005 NOTE: TREE CAP CONNECTION: 5' OTIS SURFACE, l 2/6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4- 1/16" 5M (w/PENETRATOR WIRE) 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 30 - 2,662 1 11/622008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 2/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV GAS LIFT, 5/18/2011 NOTE: RESTRICTION @ 4637' CTMD, COULD NOT DRIFT 2.80" 2,805 GAS LIFT, 4,506 II NIPPLE, 4,514 Mt El GAUGE, 4,626 El III IN LOCATOR, _ r/ 4,685 1 ®l SEAL ASSY, 4,695 D SAND WINDOW, 4,816 -4,628 L1 LINER LEM, 4,676-4,947 _ NTERMEDIATE. 275,267 PEF, 4,904E,831 IPERF, 9,046 - 71,966 12,150-12335 Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (81( (1 Make Model (in) Sery Type Ty On) (psi) Run Date Com... D SAND 1 2,805.3 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/4/2009 LINER, 4,812 - 12663 2 4,505.7 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 2/12/2009 TD(1E- 121L1), 72,474 DATE SUMMARY 1E-121 and 1E-121L1 Well Work Summa 10 /17 /2012`PERFORMED FLUFF ANMTUFF USING SLICK DIESEL TO TOP 0 THAT WAS SET AT 4843' CTMD. FISHED IBWT 4843' CTMD. WELL FREEZE PROTEC D. JOB COMPLETE. THIS SUNDRY WAS TO SUPPORT THE MBE WORK ON 1E-102 AND 1E-102L1. THE FLUFF AND STUFF WAS THE ONLY WELL WORK PERFORMED. . STATE OF ALASKA • ALIPA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Fbrforations r Perforate r Other r Pull B sand !so- sleeve Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r lime Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 -247 3. Address: 6. API Number: �e P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r - 50 029 - 23238 - 60 ( 0 7. Property Designation (Lease Number): 8. Well Name and Number:'' ADL 2565, 25648 ,, l.. 1E 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12414 feet Plugs (measured) none true vertical 3671 feet Junk (measured) none Effective Depth measured 12382 feet Packer (measured) no packer true vertical 3670 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108 108 SURFACE 2632 10.75 2662 2394 INTERMEDIATE 4789 7.625 5267 3694 B SAND LINER 5158 5.5 11252 3410 RECEIV E® NOV 13 2012 Perforation depth: Measured depth: 6131' - 11176' AOGCC True Vertical Depth: 3473' - 3414' F Tubing (size, grade, MD, and TVD) 3.5, L80, 4714 MD, 3575 TVD Packers & SSSV (type, MD, and TVD) ZXP LINER TOP PKR, MD= 4905 TVD= 3620 no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 92 1161 215 -- 205 Subsequent to operation 499 1432 1582 -- 241 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: - Oil p' Gas r WDSPL r Daily Report of Well Operations _ XXX GSTOR r WINJ WAG GINJ r r r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Darrell Humphrey Email n1139 cr,conocophillips.com Printed Name - obert '. Christensen Title NSK Production Engineering Specialiost Signature a � Phone: 659 -7535 Date / C✓ 1yl bs/ Z- R DMS NOV 14 2012 doly v F /C /ll�iz_ Form 10-404 Revised 12/2012 1 J ( 1 4 Submit Original Only • . • 1E-121L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/17/12 PERFORMED FLUFF AND STUFF USING SLICK DIESEL TO TOP OF IBP THAT WAS SET AT 4843' CTMD. FISHED IBP AT 4843' CTMD. WELL FREEZE PROTECTED. JOB COMPLETE. s KUP • 1E-112L1 " ConocoPhillips a Well Attributes Max Angle & MD TD .I InC Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act BUS (ftKB) _ caloaolFrwlip5 - 500292321160 WESTSAK INJ 93.68 6,415.62 11,285.0 "' CommeM H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 31.19 7/31/2004 Well Confi9: -1 E-112L1, 7/245012 10'.11'.51 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - - -- - -- Last Tag Rev Reason: Set Plug, Iso Sleeve, & Diverter ninam 7/24/2012 NI HANGER, 22 ----44446 _ 1 i.....---5. i.....—i.....---5. .— Casing Strings " Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .- String Top Thrd CONDUCTOR, ■ B - SAND LINER 5 1/2 4.950 6,094.0 11,252.0 3,410.4 15.50 L - 80 DWC 30-108 TUBING, 78 Liner Details "'-' Top Depth GAS LIFT, 4 _} (TVD) Top Inc( Nomi... 2,408 R , Top (ftKB) (ftKB) r) Item Description Comment ID (In) 6,094.0 3,467.4 79.72 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 SURFACE. 6,121.2 3,471.8 80.91 XO CROSSOVER 7' x 5.5" 5.500 30 -3,031 GAS LIFT, Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 5,320 mamlIM Top Depth 5,370 SLEEVE, TOR, (ND) Top Intl LOCATOR, 5,792 Top MB) (ftKB) ( °) Description Comment Run Date ID (In) SEALASSy, 6 3 , 4 68.7 80.03 ISO Sleeve TYPE 1 ISO SLEEVE (OAL=18.92) 7/20/2012 2.590 5,793 7,815 3,436.2 88.81 FISH LOST 3 CENTRALIZE ARMS FROM MEMORY LOGGING 8/14/2009 0.050 5,844-5.860 L L1 L0M. _ • L2 Window, TOOL IN B - SAND LEM 67 II ISO Sleeve, sleeves 9,496 3,427.1 90.16 PLUG INFLATABLE RETRIEVABLE BRIDGE PLUG 7/18/2009 0.000 6,101 L1 Window. 5,095-6,112 Perforations & Slots L2 LEM, — - -_- Shot 8MEDI822 Top (ND) Btm Dens 308626 1 1 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (° Type Comment :�-. 6,131 11,176 3,473.1 3,413.5 WS B, 1E -112L1 7/18/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends CMT SQZ 9005-9496' 7/18/09 Notes: General & Safety End Date Annotation 7/30/2004 NOTE: TRI- LATERAL WELL - 1E -112 (UNDULATING A -SAND) 1E -112L1 (B -SAND) 1E -112L2 (D -SAND) 3/1/2009 NOTE: View Schematicw /Alaska Schematic9.0 FISH, 7,815 SLOTS. 6.131- 11,176 PERF SOZ, 9,005 PLUG, 9,496 Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( Make Model (1n) Sery Type Type (in) (Pal) Run Date Com... 1 2,408.4 2,018.9 62.78 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/6/2005 2 5,320.1 3,256.1 66.39 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/302005 13-SAND LINER, 6,094-11,252 TO (1 E- 112L1), L 11,285 • • • SINE INF AILASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. aos4--'47 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E-121L1 Sundry Number: 311 -181 Dear Mr. Peirce: WANMED SLIM 1 2 2BII Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9 , i Daniel T. Seamount, Jr. 1 .// Chair DATED this / day of June, 2011. Encl. STATE OF ALASKA ALASKI AND GAS CONSERVATION COMMISSIT G� ' ii APPLICATION FOR SUNDRY APPROVALS -' 20 AAC 25.280 1. Type of Request: Abandon r Flug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r RAI Tubin r Time Extension f' Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: MBE Sealing s. _ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I✓ ' Exploratory r 204 -247 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23238 -60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E -121L1 _ 9. Property Designation (Lease Number): , 10. Field / Pool(s): ADL 25651 & 25648 Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12414 • 3671 . 12382' 3670' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108' 108' SURFACE 2632 10.75 2662' 2394' INTERMEDIATE 4789 7.625 5267' 3694' D SAND LINER 7571 4.5 12383' 3670' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4904'- 8831', 9048' - 11966', 12150' - 12335' 3622'- 3709', 3709'- 3667', 3676-3671' 3.5" L80 4714 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packers no SSSV 12. Attachments: Description Summary of Proposal pi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development 17 Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned I Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature Phone: 265 -6471 Date 5/ 25 Iii • Commission Use Only Sundry Number: 3 ` , . t S( i Conditions of approval: Notify Commission so that a representative may witness UV Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED \f /Y.<, ii10li Other: Alaska ill & Gag CiultS. C9hII1)18SiO4 el Subsequent Form Required: /O_ L�V cif , >.''+' _' - 4 I' G I APPROVED BY / i Approved by: 0 / COMMISSIONER THE COMMISSION Date: V I ` ) t Form 10 -403 RERBEAS0JUN 02 ZQ e I G I K 1 f L Submit in Duplicate • Sealing 1E-102L1 to 1E-121L1 MBE A matrix bypass event (MBE) occurred May 2010 in 1 E -102L1 (D lateral) during Viscosity ' Reducing Injection (VRI) with breakthrough to 1E-121L1 producer. A diverter was set in the D LEM at 5994' RKB and a 5 -13 -10 IPROF in 1E-102L1 found an MBE at —8900' RKB. 1E-102 has been shut -in since May 2010 due to MBE's in both the B and D laterals. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep • efficiency by remediating direct communication paths through the formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic gel polymer available in various granular mesh sizes. CrystalSeal swells to 400 times initial size in presence of water by hydrating and absorbing water. Due to swellability of CrystalSeal it is often used to fill highly conductive large voids or channels (MBE's) that readily accept very high rates of injection. Procedure: Slickline: 1) Pull DV's from GLM's at 3156' & 5453' MD; set memory T & P gauges in each of the GLM's. Coil Tubing: 2) RIH with perf gun & shoot 10' of big hole perforations in 4.5" slotted liner at 8900 - 8910' RKB to enable CrystalSeal entry past the slotted liner to the MBE. POOH with perf gun. 3) RIH w /Active -Coil until nozzle is across perf interval at 8900 - 8910' MD, then pump 40 bbls 2% KCI Pad down coil at initial rate of 0.7 bpm. Work rate to max rate allowable while taking any returns from the CT x Tbg annulus, followed by 5 bbls 2% KCI with 0.1 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.25 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, followed by 20 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) while ramping rate down to 0.7 bpm and taking returns from CT x Tbg, followed by shut -in of CT x Tubing annulus, followed by 60 bbls (target) 2% KCI with 0.4 ppg CrystalSeal (4 mm size) down coil at steady target rate of 0.7 bpm to stay below frac gradient while squeezing slurry to MBE and monitoring treating pressure at nozzle. Cycle nozzle up and down over perf interval to mitigate screen out, and to help remove any bridging buildups of CrystalSeal across perf interval. If screen out (pressure spike) is seen during pumping, stop mixing slurry and open CT x Tbg annulus to take returns to surface to halt the squeeze, followed by a swap to displacement to push remaining CrystalSeal in coil to liner. If pumping proceeds OK to target of 60 bbls, open CT x Tbg at completion of this stage and take returns, if any, to surface to halt the squeeze on the MBE, then swap to pumping displacement of 50 bbls 2% KCI down coil at 0.5 bpm to push all CrystalSeal from the coil to the liner while POOH with nozzle to D LEM at 6006' MD, followed by POOH with coil pumping 45 bbls of Diesel for FP, followed by 1 CT volume of Diesel to fully displace all 45 bbls of Diesel FP into the tubing. RD CTU. Wait at least 6 hours to let the CrystalSeal fully hydrate before returning 1E-102L1 to PWI to evaluate effectiveness of treatment in sealing the MBE. Return 1 E -102L1 to PWI slowly in step rate fashion (ie: 0.25 bpm, 0.4 bpm, 0.6 bpm) to observe post- treatment PWI rate vs. WHIP, and to evaluate if injectivity has changed as a result of treatment. � �r `' KUP 1 E -121 L1 nO (O�IFipS Sao ..t� Max Angle & MD TD ') � Well Att tCS re Feld Name Well Status Inc! ( °) (ftKB) Act Btm (ftKB) ' 500292323860 WEST SAK PROD 93.60 j D 12,143 27 12 414.0 Comment H2S(ppm) (Date Annotation End Date IKB•Crd (ft) Rig Release Date � . °• ia99= .1211, 4367AM ` SSSV NIPPLE 20 8/6/2009 Last WO 2/5/2009 I( 3361 2/62005 .... `" - AdNe M tat on Depth (ftKB) End Date Annotation Last Mod By End D t Last Tag: CTMD I 4,183 0 I 11/2/2008 I Rev Reason: GLV UPDATE Imosbor 2/4/2011 __ Casing Strings Casing Description String 0 . ing ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String String Top Thrd ' I D SAND LINER 4 1/2 1St ring I 4,812.2 I 12,383.0 I 3,670.5 12 60 1 L-80 I DWC /IBT ''.~ y v, ,e Liner. Details ,4 , Top Depth 7 ('TVD) Top Intl Nomi... - Top (ftKB) (ft") (°) Item Description Comment ID (in) a i . 4,812.2 3,600.3 74.80 HANGER BAKER MODEL B1 FLANGED HOOK HANGER 5.630 i 12,335.6 3,670.7 90.76 PACKOFF DRILLABLE PACKOFF BUSHING 3.960 !lYibIX A( T ' N ' 1iNN19M �. < - - HANGER, 23 - 5 t" Iiirrf r r_, Perforations & Slots Shot I Top(TVD) Btm(TVD) Dens Top (ftKB) Bfm (ftKB) (ftKB) (MB) Zone Date ( -. Type Comment 4,904.0 8,831.0 3,621.7 3,709.0 WS D, 1E -121 2/4/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS CONDUCTOR, 1 " ' " 9,048.0 11,966.0 3,709.3 3,667.4 WS D, 1E -121 2/42005 32.0 IPERF ALL Alternating SLOTS/BLANKS 33 12,150.0 12,335.0 3,676.1 3,670.7 WS C, WS D, 2/4/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 1E-121 w /constrictors @ 8851', 9031' 11981', NIPPLE, 516 - -- i 12152' _ -- HEATTRACE, Notes: General & Safety - 32 End Date Annotation I I 2/6/2005 NOTE: MULTI - LATERAL WELL- 1E -121 (B- SAND), 1E -121L1 (D -SAND) j '' 1 2/6/2005 NOTE: TREE CAP CONNECTION: 9" OTIS 2/6/2005 NOTE: TREE - ABB VETCO GRAY /Herz /4 -1 /16" 5M(w/PENETRATOR WIRE) SURFACE, 30 - 2,662 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/62008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 1 i t 2/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV GAS LIFT, 2,805 1 "' GAS LIFT, 4,506 filt it NIPPLE,4,614 - - ' — '_ GAUGE, 4,626 c L ,! LOCATOR, 4,685 ` SEAL ASSV, '! r 4,695 a D SAND WINDOW, - 4,8164,828 L1 LINER LEM, 4,6764,947 NTERME 27 -5,267 -5,267 IPERF, 6,904 -8,831 IPERF, 9,048 - 11,966 IPERF. 12,150- 12,335 - Mandrel Details Top Depth Top Port (ND) Inc! 00 Valve Latch SW TRO Run w'.. Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery TYP. TYp• (in) (Pal) Run Date Can... D SAND 1 2,805.3 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 2/4/2009 LINER, 4,812 - 12,383 \ 2 4,505.7 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 2/122009 TD (1E- 121L1), 12,414 • Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, March 25, 2009 9:06 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 4-246 ~~- \a \L`~~ ~~~-~-~~ Attachments: 1 E-121 Addendum to 10-404.pdf Tom, Attached is the pre/post rig work summaries and a better schematic. I only included the pre-rig work relevant to the workover. At the end of the workover, they forgot to note that the BPV was set, they simply said "secure and dress tree", so I included the Well Service Report that followed the rig workover and you can see on the second line that the valve crew was on location and pulled the BPV prior to the Slickline work. Let me know if you need any more detail. Thanks, 'Wort fiver ~Eaginee~ 'Wotk# (907) 265-6845 Cell# (907)230.8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:05 PM To: Packer, Brett B Subject: 1E-121 (204-246) Bret, I am reviewing the 404 for the recent workover on this well and have some requests. 1. At the end of the well work, a TWC is set for ND BOP and NU and test tree. It is not indicated in the operations report that the TWC was pulled for freeze protecting and a a BPV installed for move off. Were those actions accomplished? 2. Since this well is a multilateral, the "straight" drawing is a little confusing. Can you provide a simple drawing such as provided with the PTD application that illustrates the total 1 E-121 ? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 3/25/2009 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS,, „~ ~~~r~® -' ' ~ 6 20n9 ~4 1. Operations Performed: Abandon ^ Repair Well ^ Piug Perforations ^ Stimulate ^ 6t e~` ~~' '~~Of1S. Cf)mt>rtIS3~ ~ 'Perforate New Pool ^ Waiver Time Extensi n'It ra Alter Casing ^ Pull Tubing ^ ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 204-247 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23238-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 93' AMSL 1 E-121 L1 ' 8. Property Designation: ~r~~~ % ~~ 3. i Cc• t~ 10. Field/Pool(s): ADL 2 , 25648 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12414' ~ feet true vertical 3671' feet Plugs (measured) Effective Depth measured 12382' feet Junk (measured) true vertical 3670' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2634' 10-3/4" 2662' 2394' INTERMEDIATE 5239' 7-5/8" 5267' 3694' SLOTTED LINER 7571' 4.5" 12383' 3670' Perforation depth: Measured depth: slots in liner 4904'-8831', 9048'-11966', 12150'-12335'. true vertical depth: 3622'-3709', 3709'-3667', 3676'-3671' Tubing (size, grade, and measured depth) tubing in main wellbore, L-80, 4713.5' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 932 480 407 -- 264 Subsequent to operation 525 993 137 - 254 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Engineer 3/S /~ ./~ ~ Signature ~ Phone: 265-6845 Date Pre ared b Shar n All u Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~~,` t ~ ~ ~ ~~~ ~ 1~~ i~~~~~~~r~~_. Submd Original Onl fl 'Conductor, 20" X 30" Insulated, set at 80'. Tubing String 3-1/2" 9.3#, L-80, 8rd EUE 2.992" ID, 2.867" Drift 516' MD - 2.875" DS Nipple 10-3/4" 45.5# ~;~ Casing Shoe, ~\ set @ 2650' MD, 2395' TVD 15' MD -GLM, Cameo 3-112" X 1" KBMG 4506' MD -GLM, Camco 3-112" X 1" KBMG 4614' MD - 2.812" DS Nipple 4626' MD -Guardian Gauge Carrier Heat Trace Cable to 3008' MD 4675' MD - 5-1/2" X 7-818" ZXP Liner Top Packer wl Hold Downs 695' MD -Casing Sealbore Receptacle 4.75" ID Assembly 5-1 @" X 7818" ZXP Liner Top ~ - Packer with Hold Downs 'i ' ~~ _ Casing Sealbore Receptacle ~i 4.75" ID - - 3.75" DB Nipple Orienting Profile - j Automatic Alignment of LEM Positive Latching Collet _ Indicates Correet location -_ _ Seal Bore for Uteral Isolation - 3.68" ID - Access Window Poskive Lateral Access Via Thru-Tubing Diverter Seal Bore for Uteral Isolation - 3.68" ID Isolation Seal Asembly A.75" Seal OD 3.875" Seal ID 4714' MD -Bottom of Seal Assembly 4.75" Seal / OD 4760' MD - 3.75" DB Nipple RWO 09 4805' MD -Lateral Entry Module (LEM) 'D' Sand Lateral Orienting Profile D-sand Window @ 4776' MD, 4-1/2" 12.6#, LSO, IBTM, ~,/ 3587' TVD Slotted Liner I-1/2" X 7-518" ~ -~~«~ odel 'B' HOOK ' ~~ Hanger / 4867' MD - 2.75" D ubing String: 4-112" 12.6#, L-80, {TM SCC, (4.920" OD) 5-112" X 7-5/8" ZXP Liner Top Packer with Hold Downs 5-1/2" X 7-5/8" ~; Flez Lock finer Hanger I Packe Liner Hanger Assembly at ~ - 4900' MD, 3619' ND Casing Sealbore Receptacle 4.75" ID, 6.25" OD 20' Length 3-112" Bent Joint - 3-112" Guide Shoe ~° 3-1/2" Casing Shoe, 12.6#, L-80 IBTM ~ Set @ 12419' MD, 3647' TVD Pack-off Bushing 4947' MD -Bottom of Seal Assembly 4.75" Seal OD 'B' Sand Lateral 4-1/2" 12.6#, L-80, IBTM, Slotted Liner 4-112" Eccentric ~ Guide Shoe Equipment Specification 4-1 /2" X 7-518" HOOK Hanger Mainbore Drgt: 5.31" 4.63" Uteral Drik, no diverter or LEM: 7.88" Uteral Drik, wl diverter, no LEM: 3.68" LatercllMainborc Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation skeve: 2.50" Uteral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: Diverter and Sleeve Length: 4-1 /2" Casing Shoe, 12.6#, L-80 IBTM Pack-off Bushing Set @ 12426' MD, 3709' TVD 7-518" Casing Shoe, Set at @ 5085' MD, 3661' TVD, 89 deg e.aer Hugn<a zooo. role eocumem may noe b< r<p.oevicee w alambvted, m vhole o. m part m any Corm or by my means Necbonlc or mechanl<al, Including photo<opying, recording, or by any Infomudon storage antl mmeval system new anovm or hereafter Invented, vdthout vnlaen permission aom Baker Hughes Inc. DES linker Oil TOnls Lateral Entrv Module (LEMI With Diverters and Isolation Lateral Access Dlverter Lateral lsolatlon Diverter GS Running Tool String Installed Installed (3.00" Lateral Drm) (2.50" ID Mainbor e Drifry 'GS' Profile for Coil Connector JRunnfnglReMleving ti i (1.00' LengM) Snap InlSnap Out .~POSltive Locatlng~ --Back Pressure Valve Collet (1.60' LengM) Lateral lsolatlon "~"' j r Fbw-Thru Swivel Seals (1.25' Length) Lateral Dlverter ~ j Hydraulic Ramp j - n ct Disco ne \ lsolatlon/ Malntrore ' - ~ (1.50' LengM) Dlverter Sleeve ~~ GS Spear ' ~ - I Lateral lsolaton' - I LengM) (1.50 S l ( ~ fi.BS h Approx. ea s ~-=, _ OAL' ~~ -Jars may to required in highly deviated ' ' approa IengMl. or deep applications (6 Diverter LengM 18.5 Sleeve LengM 18.5 zoos west sak rsn- Wal Laee.NCempl<aon -proeu«r 2009 ~ Ian ConocoPhillips West Sak 7-5/8" Producer 1 E-121 Dual Lateral Completion As Completed • / KU P • 1 E-121 L1 t~f,~ tt CQi~1C7tpf l f1~t1~.7$ ' 1 ~ !Well Attribu _ tes ~.- _ Max A ngle & MD jTD ~ ..,,h, i, I Wellbore APVU WI (Field Name ______ _ Well Status Prod/lnj Type ',Intl (°) ( MD (ftK6) Act Btm (ftK6) __ ~ 500292323860 ',WEST SAK _ PROD 53.60 12,143 12,414 Camment H2S (ppm) (Date Annotation End Data KB-Grd (H) Rig Release Dal ~ - - - SSSV: NONL 20 ', 7/112008 (Last WO: 2/5/2009 33.61 2,'6/2005 ~ well con E 1z•L zis ~___-_ -- 5Glematic AC;u ~l ~Annotalion Depth (ft KB) iEnd Data (Annotation End Date F I~ HANGER 23 __ i CONDUCTOR, F ; 0-106 E ~ R I NIPPLE. 516 - [ ' HEAT TRACE, SURFACE, 30-2,6fi2 GAS LIFT, _ z.eos 4t GAS LIFT, -.._ 6,506 I r- l NIPPLE.as16 ~ -~ GAUGE, 6.626 F`ry'" -f SEAL Assv. - - 4,655 =_; ~._ IPERF. 4.904-8.83', IPERF,_ 12,150-12,335 D SAND LINER, 4,812-12,383 1 TD (1 E-121Lt),~ J 12,414 'Top Depih ' (ND) Top Intl' Top (HKB( (ftK6) (°) (tam Description i Comment ID (in) ', 4,812 3,600.3 74 80 HANGER jBAKER MODEL 81 FLANGED HOOK HANGER 5.630 12,336 3,670.7 90.76 PACKOFF DRILLABLE PACKOFF BUSHING 3.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc op epth, .)- _ __ ncl VD ( ~ p KKB I Top (HKB) I Des option Comment () __ Run Dat (D(in) ~ 32 320 0.50'HEAT TRACE .HEAT TRACE 24!2009 L 0.000 Perforations - -_ - Shot _- Top (ND) Btm (TVD) Dens Top (HKB) Btrn (ftK8) (ftK6) (HKB) Zone Date (sh-~ Typa Comment 4,904 8,831 3,621.7 3,709.0 WS D, 1E-121 24/2005 32.0 IPERF ALL Altemating SLOTS/BLANKS 9,1y18 11,966 3,709.3 3,667.4 WS D, 1E-121 242005 ~I 32.0 IPERF , ALL Altemating SLOTS/BLANKS 12,150 12,3351 3 876.1 3,670.7. WS C, WS D, 2/412005 32.0 IPERF ALL Altemating SLOTS/BLANKS 1 E-121 w/constrictors ~ 8851', 9031' 11981', 12152' I Notes: General 8 Safety _ __.- End Date Annotation _ _-______- 2/62005 'NOTE:MULTI-LATERAL WELL-1E-121 (BSAND). 1E-121L1 (D-SAND) 12/612005 NOI E TREE CAP CONNECTION: 9" OTIS 2/6/2005 NOTE: TREE - ABB VETCO GRAY 1 Horz 14-1/16" SM (w/PENETRATOR WIRE) 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11!6/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 2/612009 (NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 I Mandrel Details Top Depth Top - - --- ~ _ __ PoA - I i (ND) Intl OD Valve Latch Sore TRO Run P( ) Stn To HKB I (HKB) (°) Make Model (in) Serv Typa Type Gn) (psi) Run Dat Comm... 1 2,8051 2,508.4 36.39 CAMCO~KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 242009 ' 3,514.6 69.08,CAMCO;KBMG 1'GAS LIFT (DMY BK-5 2 4506 I 0.000 0.0 24/2009 _ • Well Date Event Descri lion 1E-121 8126/08 TAG AND START BAILING SAND FROM 3883' TO 3971' SLM, 200' ABOVE PUMP. JOB SUSPENDED FOR CLEAN OUT. 1E-121 8/31/08 PULLED SLIP STOP & PACKOFF FROM 4197 CTMD AFTER CLEANOUT RUN, WILL RTN IN A.M. TO PULL ESP. 1E-121 911/08 PULLED ESP FROM 4206 CTMD, SET PUMP IN DEPLOYMENT FLANGE, READY FOR S/L. 1E-121 9/5/08 PULLED 44.2' ESP PUMP FROM DEPLOYMENT FLANGE. SET CATCHER SUB @ 4247' RKB, PULLED SHEARED SOV @ 3594' RKB AND REPLACED W/ NEW 2000 PSI TBG. SHEAR VALVE. PULLED EMPTY CATCHER SUB @ 4247' RKB. NEED TO RUN NEW PUMP WHEN AVAILABLE. 1 E-121 9/14/08 (PRE-RWO) UPPER TPOT -PASSED. UPPER T PPPOT -PASSED. LOWER TPOT -PASSED. LOWER T PPPOT - PASSED. IC POT UNABLE TO TEST IC DUE TO LEAKING ALEMITE FITTING 1E-121 9/22/08 SET 4-1 /2" x 44' ESP @ 4236' WLM. SET 4-112" PACK OFF ASS'Y, TOP @ 4189' WLM (100" DAL, KOBE 35-1/2" FROM TOP, 89" TO CHECK . TESTED PACKOFF, GOOD. COMPLETE. 1 E-121 10/10/08 ATTEMPTED DRIFT TBG, ENCOUNTERED OBSTRUCTION AT /NEAR TBG HANGER @ 2' SLM. ATTEMPTED BAIL SAMPLE, NO RECOVERY. PUMPED 30 BBL HOT DSL, FAILED TO CLEAR. IN PROGRESS. 1E-121 10/11/08 IDENTIFIED OBSTRUCTION @ 2' SLM: PACKOFF ASS'Y. PULLED SAME, MISSING ELEMENT. TAGGED 3.8" x 44' ESP @ 9' SLM. READY FOR CTU. 1E-121 10/15/08 ABLE TO MOVE ESP PUMP DOWN HOLE 18' CTMD (27' FROM HANGER), HIT OBSTRUCTION AND WAS UNABLE TO GAIN ANY ADDITIONAL FOOTAGE UTILIZING HIPP TRIPPER AND PUMPING DOWN THE CTxTBG ANN. AT 4 BPM WITH HOT OIL TRUCK, PUMP MOVES FREELY UP HOLE, PUMPED OFF FISH ON BTM, TURN OVER TO SLICKLINE. Y 3 COIL PUMPED 226 BBLS DIESEL ~ HOT OIL PUMPED 75 BBLS DIESEL ~ w 1E-121 10/20!08 ENGAGED 4-1/2" x 44' ESP @ 29' WLM. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. PUMPED 45 BBL ~ a HOT DSL DOWN TBG 8 RE-ENGAGED PUMP. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. JOB SUSPENDED. 1E-121 10/26/08 LOST TOOL STRING WHILE ATTEMPTING TO KNOCK ESP PUMP DOWN HOLE @ 27' SLM .RECOVERED COMPLETE TOOL ASSY @ 382' SLM. KNOCKED PUMP DOWN HOLE FROM 403' SLM TO 2652' (""PUMP ACROSS TOP MANDREL @ 2675' RKB"`). UNABLE TO PUSH FURTHER DOWN HOLE. RAN 3" PUMP BAILER TO 2652' SLM. F/N ON PUMP CLEAN. JOB SUSPENDED UNTIL A CRANE IS AVAILABLE. 1 E-121 10128/08 PULLED TOP SECTION OF PUMP (OAL= 57"/ BTM OD FLARED OUT TO 3.875") FROM 2662' SLM. ""PUMP WAS PARTED @ THREADED SECTION ABOVE INTERNAL FINS`"`. TAG TOP OF PUMP WITH 3.70" LIB @ 4156' SLM. OBTAINED CLEAR PICTURE OF .75" ROD LOOKING UP HOLE CENTER OF TBG .JOB SUSPENDED. 1E-121 11/2/08 ATTEMPTED TO PUSH ESP DOWN HOLE, TAG @ 4183' CTMD, RATTLED ON IT WITH HIP TRIPPER AND TRIED USING JARS, WAS UNSUCSEFULL IN MOVING. CONTACTED WEST SAK ENG, HE WAS OK WITH DEPTH. LEFT WELL SHUT IN AND FREEZE PROTECTED. 1 E-121 11/6!08 GAUGED TBG TO 2.79" TO 4160' SLM. SET SLIP STOP 8 CATCHER @ 4160' SLM. PULLED SOV @ 3594' 8 DV @ 2675' RKB. SET GLV 2675', OV 3594' RKB. PULLED CATCHER 4159' SLM. COMPLETE. 1E-121 1!23/09 SET CATCHER @ 4160' SLM, PULLED OV @ 3594' RKB 8 GLV @ 2675' RKB, REPLACED W/ DVs, PULLED CATCHER @ 4160' SLM, PULLED SLIP STOP @ 4164' SLM, RDMO. DHD SHOT FLUID LEVEL (-3000'), LRS PUMPED 95 BBLS DIESEL DOWN IA VERIFYING COMMUNICATION. 1E-121 1/27109 MIRU Nordic Rig 3, set down and bermed up. RU to Kill Tank. Loaded pits w/ 8.8 ppg 6% KCL. PT kill lines @ 2 500 si. Pull BPV. Bleed down well. Kill well w KWF. ND Tree. 1E-121 1128/09 NO tree, NU BOP, open and inspect BOP's for debri from previous well, rack and tally 3 1/2" completion tbg, RU and test BOPE ull han er to floor circ hot kill fluid to clean tb LD han er. 1E-121 1/29/09 POOH LD ESP completion string, clean floor and off load equipment, RU and make first cleanout run on 3 1/2" DP. 1E-121 1130/09 RIH making second cleanout run with lateral wash tool, POOH LD BHA, MU and RIH with outer string, MU ZXP assembly, MU inner string, RIH with ZXP and LEM assembly, shallow test MWD, RIH and orient LEM. 1E-121 2/1109 RU slickline unit, RIH with caliper tool and could not pass through hook hanger, tools stacking out at 4,830', w caliper up out of hook hanger and POOH RD slickline, RIH w/ cleanout BHA and passed through hookhanger, 0 POOH LD cleanout assembly, MU milling BHA, RIH and milled through hookhanger with 4.75" and 5.25" string y mills POOH to 1 836. ~ O 1E-121 1/31109 Oriented LEM and attempted to latch hook hanger numerous times with no success, POOH LD innner and outer 3 LEM string assembly, sent seal assembly joint to Baker Machine and had 4" bend made, MU dummy run BHA ~ with seal assembly, RIH to 4,765', made numerous attempts to pass through hook hanger window but could no ~ n t a t 4 3 bo om of i d w POOH for ali r r n. ~ 1 E-121 1/31/09 PERFORM CALIPER SURVEY FROM 4831' SLM TO 4600' SLM "`JOB COMPLETE"' O 1E-121 212109 Cont POOH LD milling assembly, MU bullnose and lateral wash tools, RIH and cleanout hookhanger pumping p down drill string and IA simultaniously, POOH LD cleanout assembly, PU RIH with seal assembly dummy run, Z POOH LD seal assembly and redressed, MU inner and outer strings, RIH with LEM assembly to 3,770'. 1E-121 2/3109 Cont RIH w/ LEM, orient and locate LEM, set LEM, test IA and ZXP, POOH LD HRD running tool, prep rig floor and PU sin le in hole with 3 1 2" com letion and heat trace to 3 056'. tE-121 214109 Cont RIH to 4,712' with 3 1/2" completion, space out, MU hanger and landing joint, spot inhibited seawater, land hanger, test tbg and IA, shear SOV, LD landing jnt and remove ISO sleeve, install 2 way check, ND BOP, NU tre . 1E-121 2/5109 Freeze protect well, secure and dress tree, RDMO 5E-121. Nordic Rig #3 released from IE-121 on 02-OS-2009 @ 07:30 am. 1 E-121 2112/09 PULL BALL & ROD @ 4614' RKB, PULL SOV @ 4506' RKB, SET 1" OV (5/16" PORT) @ 4506' RKB, PULLED RHC BODY @ ~ 4614' RKB, «RHC BODY STUCK @ 492' SLM» IN PROGRESS. ~ 1E-121 2/13/09 PULLED RHC BODY FROM 'DS' NIP @ 516' RKB. ((KEY RETAINER HOUSING HAS METAL EMBEDDED INTO THE OD)) y JOB COMPLETE. O a CanocoPhillips Time Log & Summary WelNtew Web ReOOrtrng Re ~ a Well Name: 1 E-121 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/27/2009 3:00:00 AM Rig Release: 2/5/2009 7:30:00 AM Time Logs Date From To Dur S. Depth E. D~th Phase Code _ 5ubcode T (;omment 1/27/2009 24 hr summary MIRU Nordic Rig 3, set down and bermed up. RU to Kill Tank. Loaded pits w/ 8.8 ppg 6% KCL. PT kill lines 2,500 si. Pull BPV. Bleed down well. Kill well w/ KWF. ND Tree. 02:00 03:00 1.00 0 0 COMPZ MOVE OTHR P Shuffle mats to RU on from 1-170 to 1 E-121 03:00 05:30 2.50 0 0 COMPZ MOVE OTHR P Accept Nordic Rig 3 @ 0300 hrs on 1-27-09 Spot and set T mats and 40' Double RU mats. Build ramp to assist in drivin ri u on double mats. 05:30 10:30 5.00 0 0 COMPZ MOVE PSIT P Spot rig over well, berm cellar, spot tanks and mudshack, MU hardline to kill tank. 10:30 11:30 1.00 0 0 COMPZ RPCOM OTHR P Pressure test hardline at 250/2,500 si - ood test. 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD P RU lubricator to pull BPV. 12:00 14:30 2.50 0 0 COMPZ RPCOM OTHR T Pulled BPV, master valve leaking, re-set BPV. Wait on valve crew to come to location and service master valve -service master valve. 14:30 15:00 0.50 0 0 COMPZ RPCOM RURD P Pull BPV, RD lubricator, 300 psi on OA, 480 si on IA, 670 si on tb . 15:00 16:30 1.50 0 0 COMPZ RPCOM OTHR P Load ESP spooler, spool and crate of wards with crane. 16:30 18:30 2.00 0 0 COMPZ RPCOM OTHR T Thaw ice plug in cellar. 18:30 20:30 2.00 0 0 COMPZ WELCTL CIRC P Bled gas cap off IA and tbg to kill tank, pumped down tbg with 8.8ppg kill fluid one tbg volume (65bbls) at 5 bpm - 80 psi, tbg pressure increased to 1,900 psi then dumped pressure back to 90 psi, possibly shoved ESP pump part down the tubing, lined up and pumped down IA at 5 bpm -130 psi, 180 bbls 8.8ppg, never had fluid returns at kill tank, shut down pump and blew down hardline. 20:30 21:00 0.50 0 0 COMPZ WELCTL OWFF P Shut in and monitored well for 30 min, tbg pressure increased from 0 to 90 si. 21:00 22:00 1.00 0 0 COMPZ WELCTL CIRC P Pumped 65 bbls 8.8ppg kill fluid down tbg then 112 bbls down IA with no returns, shut in well. 22:00 22:30 0.50 0 0 COMPZ WELCTL OWFF P Monitored well for 30 minutes, well static. 22:30 23:00 0.50 0 0 COMPZ WELCTL OTHR P RD circ lines and installed BPV. Page 1 of 8 • 'Tme Logs Date From To Dur S. De th_ E. De th Phase Code Subcode T_ Comment 23:00 00:00 1.00 0 0 COMPZ RPCOM NUND P ND tree, RU on well head to fill hole with 50 bbls eve hour. 1 /28/2009 ND tree, NU BOP, open and inspect BOP's for debri from previous well, rack and tally 3 1/2" completion tbg, RU and test ROPE, ull han er to floor, circ hot kill fluid to clean tb , LD han er. 00:00 01:30 1.50 0 0 COMPZ RPCOM NUND P Cont ND tree, inspect and hang off in cellar, inspect lift threads, install test dart, ins ect LD studs. 01:30 04:00 2.50 0 0 COMPZ RPCOM OTHR P Install 13 5/8" BOP stack, open all ram doors and inspect ram cavities for debri from previous well, rack and tall 3 1/2" tb 04:00 07:30 3.50 0 0 COMPZ RPCOM NUND P NU 13 5/8 BOP stack with lower variables. 07:30 08:00 0.50 0 0 COMPZ RPCOM OWFF P Bleed down IA with 120 psi. Pump 50 bbl down the IA. Monitor well. 08:00 11:00 3.00 0 0 COMPZ RPCOM SFEQ P PT BOPE 250/2500 psi, with 3-1/2" and 4-1 /2" pipe. Test waived by AOGCC Rep Lou Grimaldi at 05:00 am 1-28-09 11:00 11:30 0.50 0 0 COMPZ RPCOM OWFF P Suspend BOP test, pump 50 bbl down the IA, monitor well. 11:30 14:00 2.50 0 0 COMPZ RPCOM SFEQ P Continue pressure testing BOPE. 14:00 14:30 0.50 0 0 COMPZ RPCOM OTHR P Pull test dart and BPV. 14:30 16:00 1.50 0 0 COMPZ RPCOM OTHR T Found a 2-3' section of Tech Wire laying on top of hanger, attempted to retrieve from rig floor with no luck. Set BPV. 16:00 18:00 2.00 0 0 COMPZ RPCOM NUND T ND BOP stack and lifted enough to retrieve Tech Wire. 18:00 21:00 3.00 0 0 COMPZ RPCOM NUND T NU BOP stack, pull BPV and installed 2 wa check. 21:00 21:30 0.50 0 0 COMPZ RPCOM SFEQ T Test BOP breaks at 250/2,500 psi on chart, ood test. 21:30 22:00 0.50 0 0 COMPZ RPCOM RURD P Pull 2 way check and MU landing jnt, circ hose. 22:00 22:30 0.50 0 0 COMPZ RPCOM OTHR P BOLD's, attempted to unseat hanger, pulling to 180K, wrapped well head with steam blanket to heat up well head, pulled hanger loose at 130K, pulled hanger to rig floor, up weight 87K. 22:30 23:30 1.00 0 0 COMPZ RPCOM CIRC P Flush IA with 150 bbls of 160 degree hot 8.8 ppg brine at 5 bpm, 50 psi, with no returns u the tb . 23:30 00:00 0.50 0 4,248 COMPZ RPCOM PULD P LD hanger and landing jnt. 1 /29/2009 POOH LD ESP completion string, clean floor and off load equipment, RU and make first cleanout run on 3 1/2" DP. 00:00 00:30 0.50 4,309 4,309 COMPZ RPCOM RURD P String ESP cable through overhead sheave and MU on s ooler. 00:30 05:30 5.00 4,309 2,165 COMPZ RPCOM PULD P POOH LD 4 1/2" ESP completion, filling hole with triple displacement +50 b h, from 4,248'. 05:30 06:00 0.50 2,165 2,165 COMPZ RPCOM OTHR T Repair ESP spooler. Page 2 of 8 C~ Time Logs Date From To Dur S: Depth E. De >th Phase Code Subcode_ T Comment 06:00 11:30 5.50 2,165 75 COMPZ RPCOM PULD P Continue POOH with 41/2" ESP com letion 11:30 14:00 2.50 75 0 COMPZ RPCOM PULD P Top of ESP pump located - 6' into joint #1. Break down and lay down ESP com letion. 14:00 18:00 4.00 0 0 COMPZ RPCOM OTHR P Clean floors. Set wear bushing. Off load ESP boxes. Load 3-1 /2" IBT, stra . Re-order DP in derrick. 18:00 19:30 1.50 0 463 COMPZ RPCOM TRIP P MU cleanout BHA #1. 19:30 20:30 1.00 463 4,725 COMPZ RPCOM TRIP P RIH with 3 1/2" DP to 4,725', up wei ht 88K, down wei ht 74K. 20:30 21:30 1.00 4,725 4,954 COMPZ RPCOM CIRC P Obtain parameters and wash down from 4,725' to 4,954' pumping at 3 bpm - 3,000 psi, getting no returns to surface. Washed through D-lateral hook hanger and through B-lateral ZXP liner to a total of 3 times. 21:30 00:00 2.50 4,954 0 COMPZ RPCOM TRIP P POOH from 4,954' and LD BHA. 1 /30/2009 RIH making second cleanout run with lateral wash tool, POOH LD BHA, MU and RIH with outer string, MU ZXP assembl , MU inner strip ,RIH with ZXP and LEM assembl ,shallow test MWD, RIH and orient LEM. 00:00 01:30 1.50 0 472 COMPZ RPCOM TRIP P MU cleanout BHA #2. 01:30 03:00 1.50 472 4,734 COMPZ RPCOM TRIP P RIH on 3 1/2" DP to 4,734', up weight 97K, down wei ht 74K. 03:00 04:00 1.00 4,734 4,954 COMPZ RPCOM CIRC P Obtain pump parameters and wash down to 4,954' pumping at 6 bpm - 1,700 psi down drill pipe. Washed through D-lateral hook hanger and through B-lateral ZXP liner top a total of 3 times, lined up on kill line and pumped 50 bbls down IA at 6 bpm to flush any debri down hole at hook hap er and ZXP liner to . 04:00 08:00 4.00 4,954 0 COMPZ RPCOM TRIP P Blow down top drive and POOH, LD BHA #2. 08:00 10:00 2.00 0 0 COMPZ RPCOM OTHR P Clean rig floor. Load and arrange tools for LEM run. 10:00 12:30 2.50 0 0 COMPZ RPCOM RURD P Crane on location, remove used ESP cables ool from ri floor. 12:30 14:00 1.50 0 0 COMPZ RPCOM WOEO T Needed to have plug removed from ni le to allow um in for MWD. 14:00 18:00 4.00 0 282 COMPZ RPCOM PULD P PU and MU LEM BHA with inner strip . 18:00 23:00 S.OQ 282 4,725 COMPZ RPCOM TRIP P RIH one stand and shallow test MWD, good test, cont RIH on 3 1/2" DP to 4,725' at 30 fpm, up weight 98K, down wei ht 78K. 23:00 00:00 1.00 4,725 4,819 COMPZ RPCOM CIRC P Break circ at 3 bpm - 420 psi to orient LEM with MWD, slowly washed down to 4,819'. 1/31/2009 Oriented LEM and attempted to latch hook hanger numerous times with no success, POOH LD innner and outer LEM string assembly, sent seal assembly joint to Baker Machine and had 4" bend made, MU dummy run BHA with seal assembly, RIH to 4,765', made numerous attempts to pass through hook hanger window but could not et ast 4,830' bottom of window ,POOH for cali er run. Page 3 of 8 Time Logs .Date From To Dur S. De th E. De th Phase Cade Subcode T Comment 00:00 01:30 1.50 4,819 4,830 COMPZ RPCOM OTHR P Oriented LEM and attempted to pass t hrough hook hanger numerous times with no success. 4 3/4" seal assembly not going through hook hanger window. Contacted Well Engineer and decision made to POOH - LD LEM assembl . 01:30 03:00 1.50 4,816 4,816 COMPZ RIGMNT SVRG P Blew down top drive, POOH one stand and hung off blocks, slipped and cut drill line. 03:00 08:00 5.00 4,816 282 COMPZ RPCOM TRIP T POOH with complete LEM assembly standing back 3 1/2" DP, LD inner and outer LEM assembl . 08:00 10:00 2.00 282 0 COMPZ RPCOM PULD T RD and LD LEM and MWD BHA e ui ment 10:00 15:30 5.50 0 0 COMPZ RPCOM WOEQ T Sent seal assembly to Baker to have seal assembly joint bent to aid in guiding seal assembly through to the main well bore. 15:30 17:30 2.00 0 0 COMPZ RPCOM RURD T Seal assembly back on location. Load and MU seal assembly dummy run. 17:30 20:30 3.00 0 4,765 COMPZ RPCOM TRIP T MU bentjoint Seal Assembly BHA and RIH on 3 1/2" DP to 4,765', up wei ht 95K, down wei ht 75K. 20:30 22:30 2.00 4,809 4,830 COMPZ RPCOM OTHR T Attempt to pass through hook hanger numerous times, tagged top of hook hanger at 4,809', PU and rotated 180 and worked down to 4,822'. Pulled out of hook hanger top, rotated string and slacked off past 4,822' but stacking out at 4,830' (bottom of hook hanger window) numerous times. Called Well Engineer and decision made to POOH for caliper run. 22:30 00:00 1.50 4,830 2,825 COMPZ RPCOM TRIP T Blow down top drive and POOH stand back 3 1/2" DP from 4,830' to 2,825'. 2/01/2009 RU slickline unit, RIH with caliper tool and could not pass through hook hanger, tools stacking out at 4,830', caliper up out of hook hanger and POOH RD slickline, RIH w/ cleanout BHA and passed through hookhanger, POOH LD cleanout assembly, MU milling BHA, RIH and milled through hookhanger with 4.75" and 5.25" strip mills, POOH to 1,836. 00:00 02:30 2.50 2,825 4,830 COMPZ RPCOM TRIP T Cont POOH stand back 3 1/2" DP, LD seal assembly BHA. Mule shoe had extensive ou es. 02:30 07:00 4.50 4,830 0 COMPZ RPCOM SLKL T PJSM, RU to run 2 3/4" 26 finger memory caliper on slickline, RIH to 4,830'. Unable to run deeper. POOH with slickline and PDS caliper log. RD slickline. Caliper log showed the tool trying to run into a bottle neck and then no o. 07:00 08:30 1.50 0 185 COMPZ RPCOM RURD T PU and MU 4.5" Houle run to confirm that hanger has not moved since revious clean out runs. Page 4 of 8 • Time Logs I Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:30 10:00 1.50 185 4,750 COMPZ RPCOM TRIP T RIH with 4.5" wash nozzle. 10:00 11:00 1.00 4,750 4,953 COMPZ RPCOM TRIP T BHA at 4,750'. Up wt = 97 K#, down wt = 73 K#. RIH to 4,953', no idications of taking weight. PUH to 4,813', RIH to 4,836', did not take an wei ht. 11:00 14:30 3.50 4,953 185 COMPZ RPCOM TRIP T POOH standing back 3-1 /2" DP. 14:30 15:30 1.00 185 0 COMPZ RPCOM RURD T LD wash string BHA, clean rig floor while waitin on delive of mills 15:30 19:00 3.50 0 386 COMPZ RPCOM RURD T Load milling tools, build tally, PU and MU millin BHA. 19:00 21:00 2.00 386 4,858 COMPZ RPCOM TRIP T RIH on 3 1/2" DP to 4,858' and tag up, up weight 90K, down weight 75K, rot weight 85K, off bottom torque 2,500 ft/Ibs. 21:00 22:30 1.50 4,858 4,885 COMPZ FISH MILL T Mill through hook hanger window with 4.75" and 5.25" string mills at 40 rpm, torque at 3,000 to 4,000 ft/Ibs max, pumping down IA with kill line at 3 bpm, to 4,885', did not enter ZXP, stopped rotation and worked through hook hanger twice with no roblems. 22:30 00:00 1.50 4,885 1,836 COMPZ RPCOM TRIP T POOH from 4,858' to 1,836'. 2/02/2009 Cont POOH LD milling assembly, MU bullnose and lateral wash tools, RIH and cleanout hookhanger pumping down drill string and IA simultaniously, POOH LD cleanout assembly, PU RIH with seal assembly dummy run, POOH LD seal assembl and redressed, MU inner and outer strip s, RIH with LEM assembl to 3,770'. 00:00 02:00 2.00 1,836 0 COMPZ RPCOM TRIP T Cont POOH LD milling assembly. 02:00 03:30 1.50 0 472 COMPZ RPCOM PULD T MU lateral wash tool cleanout BHA. 03:30 05:00 1.50 472 4,734 COMPZ RPCOM TRIP T RIH on 3 1/2" DP to 4,734', up weight 97K, down wei ht 74K. 05:00 05:30 0.50 4,734 4,954 COMPZ RPCOM CIRC T Obtain parameters and washed down to 4,954'. Isolated rig pumps and pumped at 6 bpm down drill pipe at 1700 psi and 6 bpm down IA simultaniously. Washed through D-lateral hook hanger and through B-lateral ZXP liner top a total of 3 times with no roblems. 05:30 08:00 2.50 4,954 470 COMPZ RPCOM TRIP T Blew down top drive and POOH with cleanout assembl . 08:00 09:30 1.50 470 0 COMPZ RPCOM PULD T DP on surface. Rig down lateral wash tool cleanout BHA. 09:30 11:00 1.50 0 470 COMPZ RPCOM PULD T MU seal assembly dummy run BHA 11:00 13:00 2.00 470 4,956 COMPZ RPCOM TRIP T RIH with seal assembly to 4,800', up wt = 97K, down wt = 73K. Pass through the hook hanger and land seal assembly into the bottom of the SBE with 10K at 4,956'. 13:00 16:00 3.00 4,956 0 COMPZ RPCOM TRIP T POOH stand back 3-1/2" DP, LD seal assembl . Page 5 of 8 s Time Logs th Phase Code Subcode D E T Comment _. - Date From To Dur S_De th e . 0 COMPZ RPCOM RURD T T Redress seal assembly, off-load 16:00 17:30 1.50 0 Baker tools, RU floor to MU LEM assembl . d MU LEM BHA with inner 17:30 19:30 2.00 0 282 COMPZ RPCOM PULD T PU an strip . 19:30 00:00 4.50 375 3,770 COMPZ RPCOM TRIP T RIH one stand and shallow test " MWD, good test, cont RIH on 3 1/2 DP to 3,770' at 30 fpm, up weight 85K, down wei ht 70K. 2/03/2009 Copt RI H w/ LE M, orient a nd locate LEM, set LEM, tes t IA and Z XP, POO H LD HRD running tool, prep rig floor an d PU sin to in hole with 3 1/ 2" com letion and heat trace to 3,056'. 00:00 01:30 1.50 3,770 4,737 COMPZ RPCOM T RIP T Cont RIH with LEM assembly on 3 ' , warm 1/2" DP from 3,770' to 4,737 u to drive and wash i e. si to - 420 t 3 b 01:30 04:30 3.00 4,737 4,946 COMPZ RPCOM HOSO P p pm Break circ a orient LEM with MWD, slowly washed down to 4,946' mule shoe depth, with LEM at 6 degrees left and passed through hook hanger with no problem. Latched in and orientation went to 47 degrees right. Re-oriented numerous times working torque out of string, landed and latched LEM at 3 degrees left of highside. Seal assembly mule shoe at 4,946' To of ZXP Packer at 4,672' 04:30 05:30 1.00 4,946 4,946 COMPZ RPCOM HOSO P Set string in slips, dropped 1.75" ball and pumped down string. Pressured up on workstring to 2,000 psi and set ZXP, neutralized pusher tool, bled off workstrin . 05:30 06:00 0.50 4,946 4,946 COMPZ WELCTL OWFF T Crew started to break off top drive for blow down and Driller noticed flow down the flow line. MU top drive and closed upper pipe rams. Had 60 psi on DP and IA max. Bled off DP and IA to 0 psi with no additional increase in ressure. 06:00 06:30 0.50 4,946 4,946 COMPZ RPCOM PRTS P Filled IA with charge pump down kill line, RU and tested ZXP x IA at 2,500 psi on chart for 5 minutes. Good test. Notified AOGCC Rep John Crisp and Well Engineer of ram closure at 6:30 AM, 2/3/2009. Page 6 of 8 Times I nns Date _ From 06:30 To 08:00 Dur 1.50 S. Depth 4,946 E. De th 4,916 Pha= COM 08:00 11:30 3.50 4,916 0 . CON 11:30 13:00 1.50 0 0 COh 13:00 14:30 1.50 0 0 COP 14:30 00:00 9.50 0 3,056 COl 2/04/2009 Cont RIH to 4,712' with 3 1/2" completion, space land hanger, test tbg and IA, shear SOV, LD lane BOP, NU tree. 00:00 06:00 6.00 3,056 4,672 CO 06:00 07:30 1.50 4,672 4,684 CC 07:30 09:00 1.50 4,713 4,713 Ct 09:00 11:00 2.00 4,713 4,713 CI 11:00 11:30 0.50 4,713 4,713 C~ T Close annular and strip up workstring 30', pulling the setting tool from the ZXP packer. No pressure increases were observed. One annular volume (167 bbl) and one drill pipe volume (37 bbl) was pumped. With the annular and drillpipe SI the well was monitored for 30 min with no pressure increase in the annulus or PZ RPCOM TRIP P POOH standing back the 3-1/2" DP. RD MWD and settin tools. PZ RPCOM BOPE P Pull wear ring. Set test plug. Test upper variable rams for 3-1 /2" at 250/2500 psi. Remove test plug. *** TEST PLUG O-RING MISSING FROM TEST PLUG WHEN PULLED TO SURFACE "*" PPZ RPCOM RURD P RU floor to run completion. 1PZ RPCOM RCST P PU and single in hole to 1,705', start heat trace and cunt RIH to 3,056' checking TEC wire and heat trace every 1,000', up weight 60K, down out, MU hanger and landing joint, spot inhibited seawater, ling jnt and remove ISO sleeve, install 2 way check, ND VIPZ RPCOM RCST P Cont PU and single in hole with 3 1/2" completion, heat trace and Tec wire from 3,056' to 4,672', checking electrical integrity every 1,000', up wei ht 75K, down wei ht 60K. MPZ RPCOM HOSO P Up wt = 75 K#, down wt = 60 K#. Sitting down 20K at 4,684', made several attempts to work through. Needed to rotate completion 90 deg 3 times before seal assembly could pass. RIH and no go at 4,717', sat down 10 K#. Load IA with fluid to surface. Pull up hole 18', drag dropped 3 K# and IA fluid level dro ed. )MPZ RPCOM HOSO P Space out completion with 2' space out. MU han er and landin 'oint. )MPZ RPCOM OTHR P Make up heat trace and TEC wire slices. Test both. )MPZ RPCOM CRIH P Pump 175 bbl of corrosion inhibited seawater (1% CRW-132) down the Page 7 of 8 • T'sme Logs Dur S. De th E. Doh Phase Code Subcode T Comment From To Date - 11:30 __ 12:30 1.00 0 0 COMPZ RPCOM HOSO P Land hanger, RILDS. Test tubing packoff assembly to 5,000 psi. USED: 9 x SS bands, 51 single channel couplings, 93 dual channel couplings, 458 x 5' clamps, 3 x 4' clamps, 3 x 3' clamps, 2 x 4' clam s. 12:30 14:30 2.00 0 0 COMPZ RPCOM DHEQ P Drop ball and rod. Test tubing to 3,000 psi / 15 min. Bleed tubing to 2,250 psi. Test IA to 3,000 psi 130 min. Bleed off IA and tubing pressure. Pressure up IA to 1,300 psi and shear out the SOV in GLM #2 at 4,505'. 14:30 15:00 0.50 0 0 COMPZ RPCOM OTHR P Set iwo way check. 15:00 21:00 6.00 0 0 COMPZ RPCOM NUND P ND BOP, remove annular and install lifting plate, re-install annular on stack and rack back on stum . 21:00 23:00 2.00 0 0 COMPZ RPCOM DHEQ P Splice Tec wire and test, test heat trace, tests ood. 23:00 00:00 1.00 0 0 COMPZ RPCOM NUND P NU tree/ 2/05/2009 Freeze protect well, secure and dress tree, RDMO 1 E-121. Nordic Ri #3 released from 1 E-121 on 02-05-2009 07:30 am. 00:00 00:30 0.50 0 0 COMPZ RPCOM NUND P Cont NU tree. Test tec wire and heat trace inte ri ood tests. 00:30 02:30 2.00 0 0 COMPZ RPCOM PRTS P Test hanger and void at 250/5,000 psi for 10 minutes, good test. RU LRS and test circ lines and tree at 250/5,000 si, ood tests. 02:30 04:30 2.00 0 0 COMPZ RPCOM FRZP P Freeze protect well with 120 bbls down IA at 3 bpm, taking returns to pits, shut down LRS and allow diesel toe ualize. 04:30 07:30 3.00 0 0 COMPZ RPCOM DMOB P Clean pits and cuttings box, blow down circ hoses, secure well and dress tree, secure pipe in derrick for rig move, Nordic Rig #3 released from 1 E-121 on 02-05-2009 07:30 am. Page 8 of 8 •121 Pre and Post. Rig Well Work Summa DATE SUMMARY 8/26/08 TAG AND START BAILING SAND FROM 3883' TO 3971' SLM, 200' ABOVE PUMP. JOB SUSPENDED FOR CLEAN OUT. 8/31/08 PULLED SLIP STOP & PACKOFF FROM 4197 CTMD AFTER CLEANOUT RUN, WILL RTN IN A.M. TO PULL ESP. 9/1/08 PULLED ESP FROM 4206 CTMD, SET PUMP IN DEPLOYMENT FLANGE, READY FOR S/L. 9/5/08 PULLED 44.2' ESP PUMP FROM DEPLOYMENT FLANGE. SET CATCHER SUB @ 4247' RKB, PULLED SHEARED SOV @ 3594' RKB AND REPLACED W/NEW 2000 PSI TBG. SHEAR VALVE. PULLED EMPTY CATCHER SUB @ 4247' RKB. NEED TO RUN NEW PUMP WHEN AVAILABLE. 9/14/08 (PRE-RWO) UPPER TPOT -PASSED. UPPER T PPPOT -PASSED. LOWER TPOT - PASSED. LOWER T PPPOT -PASSED. IC POT (UNABLE TO TEST IC DUE TO LEAKING ALEMITE FITTING) ~~ 9/22/08 SET 4-1/2 x 44 ESP @ 4236 WLM. SET 4-1/2" PACK OFF ASS'Y, TOP @ 4189' WLM (100" OAL, KOBE 35-1/2" FROM TOP, 89" TO CHECK). TESTED PACKOFF, GOOD. COMPLETE. 10/10/08 ATTEMPTED DRIFT TBG, ENCOUNTERED OBSTRUCTION AT /NEAR TBG HANGER @ 2' SLM. ATTEMPTED BAIL SAMPLE, NO RECOVERY. PUMPED 30 BBL HOT DSL, FAILED TO CLEAR. IN PROGRESS. 10/11/08 IDENTIFIED OBSTRUCTION @ 2' SLM: PACKOFF ASS'Y. PULLED SAME, MISSING ELEMENT. TAGGED 3.8" x 44' ESP @ 9' SLM. READY FOR CTU. 10/15/08 ABLE TO MOVE ESP PUMP DOWN HOLE 18' CTMD (27' FROM HANGER), HIT OBSTRUCTION AND WAS UNABLE TO GAIN ANY ADDITIONAL FOOTAGE UTILIZING HIPP TRIPPER AND PUMPING DOWN THE CTxTBG ANN. AT 4 BPM WITH HOT OIL TRUCK, PUMP MOVES FREELY UP HOLE, PUMPED OFF FISH ON BTM, TURN OVER TO SLICKLINE. COIL PUMPED 226 BBLS DIESEL HOT OIL PUMPED 75 BBLS DIESEL 10/20/08 ENGAGED 4-1/2" x 44' ESP @ 29' WLM. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. PUMPED 45 BBL HOT DSL DOWN TBG & RE-ENGAGED PUMP. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. JOB SUSPENDED. 10/26/08 LOST TOOL STRING WHILE ATTEMPTING TO KNOCK ESP PUMP DOWN HOLE @ 27' SLM .RECOVERED COMPLETE TOOL ASSY @ 382' SLM. KNOCKED PUMP DOWN HOLE FROM 403' SLM TO 2652' ('"`"PUMP ACROSS TOP MANDREL @ 2675' RKB***). ~~ UNABLE TO PUSH FURTHER DOWN HOLE. RAN 3 PUMP BAILER TO 2652' SLM. F/N ON PUMP CLEAN. JOB SUSPENDED UNTIL A CRANE IS AVAILABLE. 10/28/08 PULLED TOP SECTION OF PUMP (OAL= 57"/ BTM OD FLARED OUT TO 3.875") FROM 2662' SLM. **'`PUMP WAS PARTED @ THREADED SECTION ABOVE INTERNAL FINS*"'`. TAG TOP OF PUMP WITH 3.70" LIB @ 4156' SLM. OBTAINED CLEAR PICTURE OF .75" ROD LOOKING UP HOLE (CENTER OF TBG). JOB SUSPENDED. 11/2/08 ATTEMPTED TO PUSH ESP DOWN HOLE, TAG @ 4183' CTMD, RATTLED ON IT WITH HIP TRIPPER AND TRIED USING JARS, WAS UNSUCSEFULL IN MOVING. CONTACTED WEST SAK ENG, HE WAS OK WITH DEPTH. LEFT WELL SHUT IN AND FREEZE PROTECTED. ~~ 11/6/08 GAUGED TBG TO 2.79 TO 4160 SLM. SET SLIP STOP & CATCHER @ 4160' SLM. PULLED SOV @ 3594' & DV @ 2675' RKB. SET GLV @ 2675', OV @ 3594' RKB. PULLED CATCHER @ 4159' SLM. COMPLETE. 1/23/09 SET CATCHER @ 4160' SLM, PULLED OV @ 3594' RKB &GLV @ 2675' RKB, REPLACED W/ DVs, PULLED CATCHER @ 4160' SLM, PULLED SLIP STOP @ 4164' SLM, RDMO. DHD SHOT FLUID LEVEL (3000'), LRS PUMPED 95 BBLS DIESEL DOWN IA VERIFYING COMMUNICATION. 1/31/09 PERFORM CALIPER SURVEY FROM 4831' SLM TO 4600' SLM ""`JOB COMPLETE""" 2/12/09 PULL BALL & ROD @ 4614' RKB, PULL SOV @ 4 RHC ODY STU1CK @ 492'' SLOM») N 4506 RKB, PULLED RHC BODY @ 4614' RKB, PROGRESS. 121 Pre and Post Rig Well Work Summ~ 2/13/09 PULLED RHC BODY FROM 'DS' NIP @ 516' RKB. ((KEY RETAINER HOUSING HAS METAL EMBEDDED INTO THE OD)) JOB COMPLETE. WSR Historical -FILE COPY- 1 E-121 Job: Drilling Supoprt -Exp WO Report Date: 2/12/2009 Unit: HES SLICK LINE 759 Kennedy, Chris -CPAI, Wells Supervisor: API I UWI Field Name 5002923238 WEST SAK Well Type Original KBIRT Elevation (ft) Well Status Legal WeIlName Well Services 98.70 PROD 1 E-121 JOB: Drilling Supoprt -Exp WO _ __ _ _ _ _ --- Actual Start Date End Date Secondary Job Type Drillsite Primary Wellbore Affected 2/12/2009 06:00 2/12/2009 18:00 ZX36 GLV 1 E 1 E-121 ~_-- Project Desc Legal WeIlName ~~ Type AFE / RFE Network/1D # 1E-121 Drilling Supoprt-Exp WO -Wells 1E-121 ~ Drilling Supoprt-Exp WO 10246308 10246308 UNIT/RIG: HES SLICK LINE 759 i Rig Accept Date Rig Release Date Contractor Rig NamelNo ~ Rig Type 2/12/2009 06:00 2/12/2009 18:00 HES 759 SLICK LINE Rig Supervisor Company Title Phone Mobile Phone Work Kennedy, Chris -CPAI, Wells Supervisor CPAI Wells Supervisor 943-1097 659-7221 Comment DAILY OPERATIONS: 2/12/2009 EDITED BY: s1u759 Report Start Date Report End Date General Remarks Daily Cost Total 2/12/2009 06:00 2/12/2009 18:00 INITIAL = 0/25/100 FINAL = 50/25/300 4,152.00 Last 24hr Summary PULL BALL & ROD @ 4614' RKB, PULL SOV @ 4506' RKB, SET 1" OV (5/16" PORT) @ 4506' RKB, PULLED RHC BODY @ 4614' RKB, «RHC BODY STUCK @ 492' SLM» IN PROGRESS. Weather Temperature (°F) Wind -38 UnitSupervisor_ ____ __ __ _ __ __ __ _ _ _ __ _ - _ _ _ __ _ Supervisor Company -( ~ ~ Title ~ Mobile Phone Work DESSERAULT -HES, Service HES Service Specialist N/A 659-0233 Specialist - Time Lo _ _ __ ___ _ __ _ Start Cum Dur i ~- ~ Ti h e rs) me End Tim ( r hrs O erasion Wellbore 06:00 07:30 1.50 1.50 PU WELL FILE /CPU, CHECK W/ CWG REP, CONTACT WELLVIEW SUPPORT W/CPU ISSUES, 1E-121 CONTACT DSO, TRAVEL TO LOCATION /INSPECT, TGSM, RU CRANE FOR BPV REMOVAL. 07:30 08:30 1.00 2.50; VLV CREW ON LOCATION, RU VLV CREW LUB, PULL BPV, RD VLV CREW. 1E-121 08:30 09:15 0.75 3.25 RU .108" WIRE AND 1.875" ROLLER STEM (NEW PINS, GOOD ROLLERS) TS = 1E-121 RS,OC,S',OC,KJ,5',OC,KJ,S',QC,KJ,LSS,OC. PT W/ GAS. 09:15 ~ 11:00 ~ 1.75 ~ 5.00. RIH W/ 2.66" BELL GUIDE, 2" RB TO 4595' SLM. UNABLE TO LATCH B&R. POOH. POSSIBLE 1 E-121 11:00 1 11:45 0.75 1 5.751 RIH W/ KJ AND SAME TO 4595' SLM. LATCH 8 & R. POOH. 1 E-121 11:45 i 12:30 0.75 ! 6.50 RIH W/ 3.5" OK-1 AND 1.25" JD TO STA #2 @ 4497 SLM (4506' RKB) LATCH SOV. POOH. i 1 E-121 12:30 14:00 1.50 1 8.00 RIH W/ 3.5" OK-1 AND 1" OV (5/16" PORT) W/ BK LATCH TO 4497' SLM (4506' RKB) SET OV. POOH. 1 E-121 14:00 . 15:15 1.25 9.251 RIH W/ 3" GR TO 4603' SLM (4614' RKB) LATCH RHC BODY. HUNG UP @ 492' SLM. ATTEMPT TO ~ 1 E-121 I WORK THRU. SHEARED GR. POOH. 15:15 15:45 0.50 9.751 RIH W/ 3" GS TO 492' SLM. LATCH RHC BODY. 5 LICKS SHEARED GS. POOH. 1 E-121 15:45 16:15 0.50 i0.25~RIH W/ SAME TO 492' SLM. LATCH RHC BODY. 5 LICKS SHEARED GS. POOH. 1E-121 16:15 17:00 0.75 11.00 RIH W/ 3" GS (STEEL) TO 492' SLM. LATCH RHC BODY. HAND SPANG 50 LICKS. 10 LICKS W/ 1E-121 UNIT. SHEAR OFF. POOH. 17:00 ; 17:30 0.50 11.50jBEGIN LDFN, INSPECT AREA, CONTACT DSO, PJSM. 1E-121 17:30 18:00_ 0.50 12.00 TRAVEL TO OFFICE, END TICKET, DOWNLOAD, TURN IN PAPERWORK. 1E-121 Well Fluids _ __ _ _ __ _ Fluid _ To (bbl) Note www.peloton.com Page 111 Report Printed: 3/2512009 • ~ RE~EI~~C~ STATE OF ALASKA DEC 2 9 200i~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERgTIO~Ka Oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ Failed ESP to Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Gasiift Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Num ber: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 204-247 3. Address: Stratigrephic ^ Service ^ 6. API Number: P: O. Box 100360, Anchorage, Alaska 99510 50-029-23238-60 7. KB Elevation (tt): 9. WeII Name and Number: RKB 99' 1 E-121 L1 8. Property Designation: 10. Field/Pool(s): ALK 25651 & 25648 Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12414' feet true vertical 3671' feet Plugs (measured) Effective Depth measured 12382 feet Junk (measured) true vertical 3670 feet Casing Length Size MD TVD Burst. Collapse CONDUCTOR 108' 20" tos' 108' SURFACE 2563' 10-3/4" 2662' 2394' INTERMEDIATE 5168' 7-5/8" 5267' 3694' D SAND WINDO\ 12' 7-5/8" 4828' 3604' D SAND SLOTTE 7571' 4-1/2" 12383 3671' Perforation depth: Measured depth: 4904'-8831 ; 9048'-11966'; 12150'-12335' true vertical depth: 3622'-3709 ; 3709'-3667; 3676'-3671' ~ _; e~~~k ~~~ `~~,; ~~~' s ~C~J' Tubing (size, grade, and measured depth) 4-1/2", L-80, 4247' MD. Packers &SSSV (type & measured depth) Packer =None SSSV =None 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 644 565 54 179 182 Subsequent to operation 484 281 29 789 319 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^~ Gas^ WAG[] GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.o. Exempt N/A Contact B. Christensen/ D. Humphrey Printed Name R be . C ri tensen Title Production Engineering Specialist Signature --~ Phone: 659-7535 Date `~ ~s,~- D Form 10-404 Revised 04/2004 // ~/ r~g ~ ~ ~ ~ ubS mit Original Clnly • • 1 E-121 L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/06/08 GAUGED TBG TO 2.79" TO 4160' SLM. SET SLIP STOP & CATCHER @ 4160' SLM. PULLED SOV @ 3594' & DV @ 2675' RKB. SET GLV @ 2675', OV @ 3594' RKB. PULLED CATCHER (a~ 4159' SLM. COMPLETE. ~~ KUP ~ 1 E-121 L1 COI'lOCO~'II~~IPS Well Attributes Ahl~."'' III' Welibore API/UWI Fleltl NanKi Well Statue Protl/Inl Well Type Incl (°) MD (RNB) TD (max) (H... 500292323860 WEST SAK PROD 93.60 12,143.27 12,415.0 Comment HTS (ppm) Dale Annotation End Date KB-0rd (tI) Rig Release Date ••• Wall COnfi-1E-t21L111O20088 58 S6 AM SSSV: NONE 20 7/1/2008 LastWO: 33.61 2/6/2005 . Schematk~AcNel Annotation Depth(/tKB) End Date Annotation End Dale Last Tag: CTMD 4,183.0 11/2/2008 Rev Reason: Set Slipstop on ESP Pump remains, GLV C/O 11/7/2008 Casin Strin s String 00 SUing ID Sel DepN Sel Depm (TVD) siring Wt stung Casing Description lin) (in) Top (ftKB) (ftKB) (RKB) (Ibe/it) Grade String Top Thrd D SAND SLOTS 4 1/ 2 3.958 4,812.0 12,383.0 3,670.5 12.60 L-80 DWC/IBT Other In Hole All Jewel : Tubi n Run & Retrievable Fish etc. Top Depth CONDUCTOR 1pg Top RKB) (TVD) (RKB) Top Incl (°) Description Comment Run Data ID (In) 4,812.0 3,600.3 74.81 L1 HANGER D-SAND BAKER MODEL B2 FLANGE HOOK HANGER 2/6/2005 4.500 4,816.0 3,601.3 74.74 CSG WINDOW D-SAND WINDOW 2/4/2005 6.875 SURFACE, 4,9OS.O 3,621.9 78.16 PACKER D-SAND ZXP LINER TOP PACKER 2/4/2005 5.500 z.ss2 12,354.0 3,670.4 89.81 PACKOFF 0.SAND 4.5" BAKER DRILLABLE PACKOFF 2l4/2005 3.950 Perfora tions GAS LIFT, Shot 2.675 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (RKB) (RKB) (RNB) Zone Dete (°h... Type Comment GAS LIFT 4,904.0 8,831.0 3,621.7 3,709.O WSD,1E-121 2/4/2005 32.O IPERF ALL AItematingSLOTS/BLANKS , 3 s9a 9,048.0 11,966.0 3,709.3 3,667.4 WS D, 1E-121 7/412005 32.0 IPERF ALL AItemating SLOTS/BLANKS 12,150.0 12,335.0 3,676.1 3,670.7 WS C, WS D, 2/4/2005 32.0 IPERF ALL AItemating SLOTS/BLANKS 1 E-121 w/constrictors @8851', 9031' 11981', 12152' Notes: General 8l Safe Ena Date Annotation DISCHARGE, 4.171 2/6/ZOOS NOTE: MULTI-LATERAL WELL-1E-121 BSAND 1E-121L7 D-SAND ( - )~ ( ) suP srDP, 4,tw 2/6/2005 NOTE: TREE CAP CONNECTION: 9"" OTIS 2/6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4-1116"" SM (w/PENETRATOR WIRE) FISH (ESP). d 1es ~~ r. I E 11/212008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP , ,: .' 1 1/612 0 0 8 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT SCREEN, 4247 SEAL, 4,257 MOTOR, 4,271 GAUGE, 4,305 Canbalixer, 4,307 L1 MANGER, 4,812 CSG WINDOW, I,B16 L1~, HANGER, 4,812 D SAND WINDDW, 4 820 PACKER, 4,905 TERME0IATE. 5,287 IPERF, 4,904E,831 IPERF, 9,048-11 96fi IPERF, I 12,15012,335 PACKOFF, (, 12,354 D BANG SLOTS, 12.31)3 ~ TD 11 E~121L1), 1z.4u • • 1_~_ 03~o~~zoos DO NOT PLACE M~ ~~ ANY NEW MATERIAL UNDER THIS PAGE F:\I.aserFiche\CvrPgs_InseitslMicrofilm Marker.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Permit to Drill 2042470 Well Name/No. KUPARUK RIV U WSAK 1E-121L1 Operator CONOCOPHILLlPS ALASKA INC - .~-----------...--- MD 12414J TVD 3671/ Completion Status 1-01L Current Status 1-01L -~,..- - ----------------.-- Completion Date 2/6/2005'/ REQUIRED INFORMATION -~-_._--,,- -- --.---.--. .--~--- DATA INFORMATION Mud Log No Samples No --------- ..spud J.. 7J"" ~> API No. 50-029-23238-60-00 UIC N _.----~._~..~_..- " Directional Survey Yes -------~ Types Electric or Other Logs Run: GR/Res Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type ED ED ¡jD Digital Med/Frmt D Asc D Asc D Lis Rpt ~ lED C Lis C ).as-" t.ís 2636 12353 Open 3/16/2005 108 12414 Open 2/22/2006 2627 12413 Open 1/29/2007 Sample Set Sent Received Number Comments Electr Dataset Number Name Directional Survey Directional Survey I nd uction/Resistivity Log Log Run Interval OH/ Scale Media No Start Stop CH --.".--..-----.--- 4807 12414 Open 4807 12414 Open 2636 12353 Open 13081 13081 LIS Verification 13704 Induction/Resistivity 14459 Induction/Resistivity Well Cores/Samples Information: "-.---------------- -." --------_.----,. Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? yr¡(§) Daily History Received? 19N (J/N Formation Tops Chips Received? '~ Analysis Received? -- -- ... _.-----_.._,,- ----~-------_.," Comments: " ----- ------------ ""'-¥+N- - Received Comments --_._~------_._- 5/4/2005 IIFR 5/4/2005 MWD 3/16/2005 GR/EWR4/ABI/ROP/PWD/ GEOPILOT/MWD GR/EWR4/ABIIROP/PWD/ GEOPILOT/MWD ROP DGR EWR plus Graphics LIS Veri, FET, GR, ROP w/Graphics _n____________ it - --'-""'-""'- --.~.__._-~._'_. ----------,,,- ".- -_.-------~.. ------_.-- ------'---,' - -------.-.-'----- ------------- --------,-------'---- - ----.----.--. -----.---------,--.--..---- --,_._," ---------.-.--.- --,._----~ --------....,-- Permit to Drill 2042470 MD 12414 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Well Name/No. KUPARUK RIV U WSAK 1 E-121 L 1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23238-60-00 3671 þ,tiOO D,,, Current ~t::~~1-~ ~~M~7 2/6/2005 Completion Status 1-01L e -- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 1E-102_L1_L1 PB1_PB1_PB2, 1E-104, 1E-121_Ll. 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 u:rC- 6)04 -dO I I U 'J:C- gó4-d3'J 1E-102_L1_L1 PB1_PB1 PB2: IL/40ó IL/'-/fgr Digital Log Images: 1 CD Rom 50-029-23236-00, 60, 72, 70, 71 1E-104: U Ic...eol../-881- ~ IL[LI5'7- Digital Log Images: 1 CD Rom 50-029-23234-00 i E - f)..1 t... l 1E-121_Ll: <;)04 -;;<10 ì£ /4LIS-1J 90.t..{ -;),{"9 .¡¡ 1t:.(454 Digital Log Images: I 1 CD Rom 50-029-23238-00, 60 þ . . WELL LOG TRANSMITTAL 6). 0J1~ '- (*&) To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 [}04-841 RE: MWD Formation Evaluation Logs IE-121 + L1, /8l0~ 1310/4- 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 907-273-3500 1E-121 + L1: LAS Data & Digital Log Images: 50-029-23238-00, 60 1 CD Rom (0ôQ'Q21;tì 910 ø I ot¡? . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-121 L 1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,807.48' MD 4,816.00' MD 12,414.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1 / j Date )~¡t~).fiJ Signed irkmv~ ð1U Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 28-Apr-05 )-10 vi - )... i.-f -; . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-121 L 1 (mwd) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,807.48' MD 4,816.00' MD 12,414.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed 1LJ IJÂI Date ç 1"'1) ~ S- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 28-Apr-05 ÀO<"t-À'-17 · STATE OF ALASKA I RECEIVED AlAZ Oil AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AHtj t!é&05 Gas U Plugged D Abandoned D Suspended D WAG D 20AAC 25,105 20AAC 25,110 1a, Well Status: Oil 0 GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3, Address: WINJ D WDSPL D P. O. Box 100360, Anchorage, AK 99510-0360 4a, Location of Well (Governmental Section): Surface: At Top Productive Horizon: No, of Completions _ 973'FSL,630'FEL,Sec. 16,T11N, R10E, UM Total Depth: 2509' FNL, 1299' FWL, Sec. 15, T11N, R10E, UM 720' FNL, 1568' FEL, Sec. 10, T11 N, R10E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 549890 ' y- TPI: x- 551802 y- Total Depth: x- 554152 ,. y- 18, Directional Survey: Yes 0 No D 21, Logs Run: GRlRes 22. CASING SIZE wr, PER FT. 62.58# 45.5# 29,7# 12,6# GRADE H-40 L-80 L-80 L-80 20" 10,75" 7.625" 4.5" 5960560 ,- 5962371 5969455 / Zone- 4 Zone- 4 Zone-4 Other 5. Date Comp" Susp" or Aband.: February 6, 2005 6, Date Spudded: z.Î ÆJ;( January;.1; 2005 ,,- 'f 7. Date TD Reached: February 2, 2005 8, KB Elevation (ft): 28' RKB / 93' AMSL 9. Plug Back Depth (MD + lVD): 12382' MD / 3670' TVD 10. Total Depth (MD + lVD): - 12414' MD /3671' TVD ./ 11, Depth where SSSV set: none 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 2662' 28' 2394' 28' 5267' 28' 3694' 4812' 12383' 3600' 3670' 23. Perforations open to Production (MD + lVD of Top and Bottom Interval, Size and Number; if none, state "none"): slots in liner from 4904'-8831',9048'-11966',12150'-12335' 26, Date First Production March 17,2005 Date of Test Hours Tested 3/25/2005 12 hours Flow Tubing Casing Pressure press, 347 psi not available 27. 24. SIZE 4.5" 25. n/a PRODUCTION TEST Method of Operation (Flowing, gas lift, etc,) Production for Test Period -> Calculated 24-Hour Rate -> / 1~i1YŠ~ðIUfl: ~as Cons. Commission Development ./ h E¡g>loratory U nc orage D Service Stratigraphic Test 12. Permit to Drill Number: 204-247 13, API Number: 50-029-23238-60 14. Well Name and Number: 1E-121L1 15, Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651 & 25648 17, Land Use Permit: ADL 469 & 466 20. Thickness of feet MSL Permafrost: 'yAl~~ </8/'" 'h1þ _~ ~Ol ,. '1"Vb HOLE SIZE 13.5" 9.875" 6.75" 3353' MD ft_ 'f-y.o$. CEMENTING RECORD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) I PACKER SET 4309' swell pkrs @ 8851',9031',11981',12152' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 40" 385 sx AS I 490 sx AS Lite, 196 sx DeepCrete 293 sx DeepCrete slotted liner 45 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". OIL-BBL GAS-MCF 1709 878 OIL-BBL GAS-MCF 3304 1886 CORE DATA production shared with 1E-121 WATER-BBL CHOKE SIZE 22 176 WATER-BBL OIL GRAVITY - API (corr) IGAS-Oll RATIO 571 RBDMS BFL APR 0 4 Z005 NONE Form 10-407 Revised 12/2003 , i L CONTINUED ON REVERSE not available C9f 28. GEOLOGIC MARKERS . 29, . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". 1E-121L1 West Sak D West Sak D West Sak D 4805' 9025' 12158' 3598' 3708' 3676' N/A 30, LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed Name Randv Thomas Title: Signature '~ t ~Phone KUDaruk Drillina Team Leader ")/),èI/ðS- -z,~r bin ð Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none", Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1 E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/8/2005 00:00 - 01 :00 01 :00 - 02:30 02:30 - 05:30 1.00 MOVE 1.50 MOVE RURD MOVE MOVE MOVE 3.00 MOVE MOVE MOVE 05:30 - 08:30 3.00 WAlTON EQlP MOVE 08:30 - 12:00 3.50 MOVE MOVE MOVE 12:00 - 15:00 3.00 MOVE MOVE MOVE 15:00 - 18:00 3.00 WELCTL NUND MOVE 18:00 - 00:00 6.00 DRILL OTHR MOVE 1/9/2005 00:00 - 12:00 12.00 WAlTON WOW RIGUP 12:00 - 00:00 1/10/2005 00:00 - 12:00 12:00 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 1/11/2005 00:00 - 08:00 12.00 WAlTON WOW RIGUP 12.00 WAlTON WOW RIGUP 8,00 WAlTON WOW RIGUP 1,50 DRILL OTHR RIGUP 1.50 DRILL PULD RIGUP 1.00 WAlTON WOW RIGUP 8.00 WAlTON WOW RIGUP Disconnect Electrical Service lines and interconnects for modules, Move and stage pipe shed and other rig modules to other side of pad. Working on cleaning rig diesel tank. Used 4000 gal of fuel w/ the 1430 gal that was in tank to try and eliminate contamination in tank. Sent 5430 gal (129 bbls) to hydrocarbon recycle. RU tow bar on rig sub. Move sub off well 1 E-1 02 @ 0330 hrs. Manuever rig down the pad, around the corner, Moved approx 1/4 mile (1/2 of move distance), Slick pad, temperature +30 deg. One cat did not have enough traction to pull rig in turn at end of pad. Wait on another cat to come f/ Prudhoe f/ Peak Oilfield Services to help move the rig to 1 E-121 . Slick pad. RU 2nd cat to rig sub. Move rig to 1E-121. Spot sub overweIl1E-121@ 1100 hrs. Move and spot pit module. Spot pump module, motor module, boiler module and pipe shed. Spot Rockwasher. While spotting pipe shed, the pipe shed hit a electrician box van which was not seen, during Phase 3. Phase 3 weather came up quick @ about 1330 hrs, RU pipe skate, NU riser. Rig acceptance @ 1600 hrs 1/8/2005 on 1E-121. Phase 3 weather. Phase 3 Weather: Change out saver sub on top drive f/ 4" XT 39 to 4 1/2" IF. Adjust grabbers, serviced top drive. change floor tools to 5" Shut down rig operations due to Phase 3 weather conditions. Test Hi and Low alarms f/ LEL and H2s. Rebuild accumulator and recharge to 800 psi on top drive, Change out bolts on saver sub wear plate. Prep dog collar. Inspect drag chain in pits and rock washer. Service mud pump oil cleanouts. Check fluid level in agitators in pits room. Table top drill: Diverting shallow gas. Table top drill: H2S. Shut down rig operations due to Phase 3 weather conditions. Service top drive counter balance accumulator. Inspected drawworks chain, Serviced and greased drawworks. Install exhaust fan in mud pits. Inspect brake linkages. Soft line riser in # 5 pit. Table top drill: Diverting shallow gas. Shut down rig operations due to Phase 3 weather conditions. Inspect expansion joints on centrifical pumps. Clean snow f/ heater ducts in pipe shed. Service loader in shop, Installed washdown pump in rock washer. Repaired # 2 pump pressure digital guage. Peak cat skinner slipped and hurt right leg, leaving shop after pre job safety meeting @ 0930 hrs. Finish plumbing wash down pump in rock washer. Install 3" valves on speed head for draining after cement job. Removed snow by pipe shed and spotted Tioga. Roads and pads equipment came out and cleaned enough snow to get I around pad. Weather phase changed from phase 3 to phase 2 at 2115 hrs. Put BHA in pipe shed, Put 57 joints 5" dp, 29 joints 5" HWDP, and jars. Strap, & Caliper tools. PU ghost reamer, stabilizer and crossovers to rig floor. Shut down rig operations due to Phase 3 weather on pad. Fuel and water has been ordered to arrive. Phase 2/3 weather conditions. Rec'd one load of water f/ pits @ 0030 hrs, rec'd load of fuel @ 0100 hrs, rec'd load of water f/ pits @ 0300 hrs, rec'd load of water f/ pits @ 0515 hrs, rec'd load of water f/ pits @ 0800 hrs, mix spud mud, Printed: 2/18/2005 10:11:19AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/11/2005 08:00 - 10:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. PJSM. PUlMU 5" drillpipe (rabbit). PU 57 jts, rack back in derrick. 10:00 - 11 :00 1.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. Level rig. 11 :00 - 12:00 1.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. Transfer 19 stands 5" dp to driller's dide of derrick. (Because of weather conditions, not able to get around in field, making plans to PU 4" and rack in derrick f/later in well). 12:00 - 12:30 0,50 WAlTON SFTY RIGUP Phase 2/3 weather conditions. PJSM on picking up dp. 12:30 - 14:00 1.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. PU/MU rabbit 5" HWDP. Rack 10 stands (includes jars) on driller's side, 14:00 -16:30 2.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. Load 4" dp in pipe shed. 16:30 - 22:00 5.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. PU/MU 30 stands Weatherford 4", S-135, XT-39 dp w/ Lo-Tads installed after the double (on top of bottom single). Stand back in derrick for use later in well. Rabbit pipe to 2". 22:00 - 00:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. PUlMU 20 stands Weatherford 4", S-135, XT-39 dp. Stand back in derrick for use later in well. Rabit pipe to 2". 1/12/2005 00:00 - 02:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions, PUlMU 20 stands Weatherford 4", S-135, XT-39 dp. Stand back in derrick for use later in well. Rabit pipe to 2". 02:00 - 02:30 0.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. Perform diverter function test w/ 5" dp. Witness of test waived by AOGCC inspector John Spaulding. 02:30 - 03:45 1.25 DRILL OTHR SURFAC PU/MU BHA # 1. 03:45 - 04:15 0.50 DRILL OTHR SURFAC Orient MWD and Motor. Orient UBHO sub. 04: 15 - 05:00 0,75 DRILL SFTY SURFAC PJSM w/ Halliburton wireline and rig crew. RU slickline. 05:00 - 05:30 0.50 DRILL CIRC SURFAC Fill conductor. Check for leaks. Test pit HI/Low level alarms @ driller's console. Test mud line to 1000 psi to check f/leaks after rig move, 05:30 - 08:00 2.50 DRILL DRLG SURFAC Spud well and drill 13 1/2" hole from 108' to 151', ART 1.6 Hrs. Increased vis of spud mud too quick w/ extender. Water mud back. Drill w/ 5-7K WOB, 85 spm, 360 gpm, 50 rpm 08:00 - 09:30 1.50 DRILL OTHR SURFAC PU to 70'. Flow line plugged offw/ gravel. Clean gravel and sticks out flowline. 09:30 - 10:15 0,75 DRILL DRLG SURFAC Drilled 13 1/2" hole from 151' to 195', ART .74 hrs. Drill w/ up to 10K WOB, 85-94 spm, 360 gpm-397gpm, up to 700 psi 10:15 -11:00 0.75 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 195' (bit depth). Ran twice, failed 11 :00 - 12:00 1.00 DRILL TRIP SURFAC POOH f/195' to 70'. PUlMU 3 flex 7 3/4" NMDC's. 12:00 - 12:30 0.50 DRILL TRIP SURFAC RIH f/160' to 195', 3' fill. 12:30 - 13:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 195' (bit depth) 13:00 - 13:30 0.50 DRILL DRLG SURFAC Drilled 13 1/2" hole from 195' to 252', ART .5 hrs 13:30 - 14:15 0.75 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 251' (bit depth) 14:15-15:30 1.25 DRILL DRLG SURFAC Drilled 13 1/2" hole from 252' to 344', ART 1.45 hrs 15:30 - 16:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 343' (bit depth) 16:00 -17:30 1.50 DRILL DRLG SURFAC Drilled 13 1/2" hole from 344' to 436', ART 1.45 hrs 17:30 - 18:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 435' (bit depth) 18:00 - 00:00 6,00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 436' to 830' MD/827' TVD, ART 3,08 hrs, AST 1.6 hrs, 7-12K wob, 50 rpm's, 106 spm, 448 gpm, off btm pressure 900 psi, on btm pressure 1,000 psi, off btm torque 1 K ft-Ibs, on btm 2K ft-Ibs, PU wi 75K, SO wi 84K, Rot wi 79K 1/13/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 830' to 1921' MD/1798' TVD, ART 6.4.35hrs, AST 4,24 hrs, 7-25K wob, 50-55 rpm's, 106-145 spm, 448-613 gpm, off btm pressure 900-2000 psi, on btm pressure 1,000-2200 psi, off btm torque 1-4K ft-Ibs, on btm 2-1 OK ft-Ibs, PU wi 75-96K, SO wi 84-96K, Rot wi 96K. MW 9.3 ppg, max gas 61 units Printed: 2/18/2005 10:11:19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Sta rt: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/6/2005 Group: 6.00 DRILL DRLG SURFAC Drilled 131/2" hole per directional plan from 1921' to 2669' MD/2399' TVD, ART 3.46hrs, AST .22 hrs, 5-30K wob, 55 rpm's, 145-154 spm, 613-651 gpm, off btm pressure 2000-2300 psi, on btm pressure 2200-2500 psi, off btm torque 3-6K ft-Ibs, on btm 2-6K ft-Ibs, PU wi 96-125K, SO wi 96-98K, Rot wi 96-105K. MW 9.3 ppg, max gas 139 units. Pumped weighted (2ppg over) sweep on stand 17. Finish circ 2ppg over (11.3 ppg) weighted sweep out of hole. 20% increase in cuttings estimated @ shakers, Monitor well. Backreamf/2269' to 1089' w/55-60 rpm, 650-700 gpm, 2500 psi. UD 13 1/2" ghost reamer and (12) 5" HWDP. POOH (6) stands(includes jars)-- 5" HWDP UD Sperry BHA, download MWD. Finish UD, Break bit, drain motor. Clean rig floor. Rig up to run 10 3/4" casing. PJSM on running 103/4" surface casing. Run 1 0 3/4" casing. Weatherford Model 303 float shoe, 2 joints 45.5ppf L-80, BTC,Weatherford model 402 FC, (1) joint 45.5ppf L-80 BTC casing, first three joints baker locked, pump thru and check float equipment, continue running 103/4" 45.5 ppf L-80 BTC casing to 1240'. Break circ w/ Frank's fillup tool @ 3.5 bpm w/ 200 psi. Circ total of 110 bbls. Continue running 103/4" 45.5ppf L-80 BTC casing to 2138'. Break circ w/ Frank's fillup tool @ 3.0 bpm w/400 psi. Circ total of 60 bbls. PU wi 115k, SO wi 95K Continue running 103/4" 45.5ppf L-80 BTC casing to 2629'. PU/MU Vetco/Gray hanger and landing joint. Run in hole to land @ 2661.85'. Ran total of 64 joints. 45.5 ppf L-80 BTC. Ran total of 15 centalizers and 2 stop rings. PU wi 155k, SO wi 105k. CBU wI Frank's fillup tool, stage rate up f/1.5bpm wI 300 psi to 4 bpm wI 300psi, then 5bpm @ 350 psi. stage to 7 bpm wI 350 psi. Circ 418 bbls. PU wi 142k, SO wi 102K. Recip 9' stroke, UD Franks fillup tool. Blow down top drive. MU Dowell cement head. Continue to circ and condition mud f/ cement job, Circ @ 7 bpm wI 400 psi. PU wi 142k, SO wi 102K, Block 35K. Recip 9'. Hold PJSM wI Dowell, rig crew and vac truck drivers on cement job while continue to circ and condition mud fl cement job. Circ @ 7 bpm wI 400 psi. PU wi 142k, SO wi 102K, Block 35K. Recip 9'. Circ total of 525 bbls after Dowell cement head was applied. Total volume circ to condition mud with pipe on bottom prior to cement job 943 bbls (3.25 hrs), Mud prior to conditioning was 9,3 ppg, 270 vis, 36 PV and 60 YP. After conditioning mud 9.1 ppg, 51 vis, 20 PV, and 16 YP. 2.00 CEMENT PUMP SURFAC Dowell pump 3 bbls water, test lines to 4000 psi., follow wI 50.1 bbls CW 100 (8.3 ppg) @ 5 bpm 250 psi, follow w/ 45.8 bbls MudPush II wI red dye (10.3 ppg) @ 4 bpm 225 psi, Drop bottom plug. Dowell pump 389.1 bbls AS Lite (10.7 ppg) @ 5.6 bpm 250-370 psi, follow w/ 86.9 bbls DeepCrete tail cement (12 ppg) @ 5.6 bpm 350-600 psi, Droptop plug, 0.25 CEMENTDISP SURFAC Dowell displace w/20 bbls fresh water @ 5 bpm 150 psi then turn over to rig. 0.75 CEMENTDISP SURFAC Rig displace cement w/9.1 ppg mud @ 6,8 bpm(initial press 320 psi, final press 615 psi) till 3 bbls prior to bump plug, then slow to 3 bpm 510 psi. Bump plug @ calculated displacement (2267 strokes), 1/13/2005 12:00 - 18:00 18:00 - 18:45 0.75 DRILL CIRC SURFAC 18:45 - 21 :45 3.00 DRILL REAM SURFAC 21 :45 - 22:30 0.75 DRILL PULD SURFAC 22:30 - 23:00 0.50 DRILL TRIP SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 1/14/2005 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 01 :00 0,50 DRILL OTHR SURFAC 01 :00 - 02:00 1.00 CASE RURD SURFAC 02:00 - 02:30 0.50 CASE SFTY SURFAC 02:30 - 05:00 2,50 CASE RUNe SURFAC 05:00 - 05:30 0,50 CASE CIRC SURFAC 05:30 - 06:45 1.25 CASE RUNe SURFAC 06:45 - 07:00 0.25 CASE CIRC SURFAC 07:00 - 07:45 0.75 CASE RUNe SURFAC 07:45 - 08:00 0,25 CASE OTHR SURFAC 08:00 - 09:45 1.75 CEMENTCIRC SURFAC 09:45 - 10:15 0.50 CEMENT RURD SURFAC 10:15 -11:30 1.25 CEMENTCIRC SURFAC 11 :30 - 11 :45 0,25 CEMENTCIRC SURFAC 11 :45 -13:45 13:45 - 14:00 14:00 - 14:45 Printed: 2/18/2005 10:11:19AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 0.75 CEMENTDISP SURFAC increased pressure to 1010 psi. CIP @ 1445 hrs 1/14/2005. Had full returns on cement job. Had 102.7 bbls good 10.7 ppg cement returns to surface. 0.50 CASE DEQT SURFAC Test casing. Pressure test 10 3/4" casing to 3000 psi w/9.1 ppg mud. Hold test fl 30 min. , chart test. Bleed off, check floats, OK. Note: reciprocated casing until 87 bbls prior to bump plug, then landed on hanger wI 65k SO wt. Blocks were 35k of this wt. UD Dowell cement head. Break Dowell crossover fllanding joint. UD 10 3/4" landing joint. RID casing equipment. PJSM on N/D diverter and NU Vetco/Gray wellhead. NID Diverter System. Flush annular. NU Vetco/Gray 5k MultiBowl spool. Orient and test to 5000 psi f/1 0 min. OK, Nipple up 13 5/8" BOPE, connect choke and kill lines, install double valves on wellhead annulus. Change Top drive saver sub f/4 1/2" IF to 4" XT 39. Note: Rig Floor to Upper LOS 22.71 '(Tubing Hanger) Rig floor to Lower LOS 26.55'(7 5/8" packoff) Rig floor to tubing hanger load shoulder 24.39' Rig floor to 7 5/8" hanger load shoulder 27.33' 1.00 WELCTL NUND SURFAC Install riser and RU to test BOPE. 4.50 WELCTL BOPE SURFAC Witness of BOPE test waived by AOGCC inspector Chuck Scheve. Test annular, upper 31/2" x 6" pipe rams wI both 4" and 5" test joint, test lower pipe rams w/ 7 5/8" test joint, test blinds. Test 4" floor safety valve and IBOP, test 5" floor safety valve and IBOP. Test top drive IBOP and all kill and choke line valves and choke manifold. All tests to 250 psi low and 3500 psi high. Test accumulator. UD test plug/test joint. Run Vetco Gray wear bushing, Install drilling bales and elevators to top drive. PU 9 7/8" bit, bit breaker, ghost reamer and float sub to rig floor. PU/MU BHA #2. MU Sperry Sun Geo Pilot, 9 7/8" Security/DBS bit, nmflex pony collar, stab, PWD, stab, HCIM, ACAL, TM HOC, float sub Upload MWD/LWD tools Press test Geo Span. Blow down top drive and geo span. Make up remaining BHA. Trip in hole to 2503'. Break in bearings on Geo Pilot MU top drive to 4" DP. Circ down and tag @ 2571', drlill cmt and plugs on top of Fe @ 2576', Drill plugs, FC, cement, FS @ 2661.85', and 20' new hole to 2689'. PU wt 11 Ok, SO wt 85K, rot wt 95k. Drill w/490-600 gpm, 1200-1700 psi, 85 rpm, torq 7k 0.75 DRILL CIRC SURFAC Circulate bottoms up (196 bbls) to change out mud in hole. Circ total of 230 bbls, 9.00 ppg mw. 1.25 DRILL LOT SURFAC Stand back 1 stand, Blow down top drive. RU to perform LOT using 9,0 ppg mw and apply pressure to 848 psi. Leak off @ 510 psi wlshoe @ 2662' MD/2394' TVD, Leak off 13.1 EMW. Bleed off pressure, RID test equipment 7.25 DRILL DRLG INTRM1 RIH 1 stand, Drilled 97/8" hole per directional plan from 2689' to 3436' MD/3006' TVD, ART 4.5hrs, 2-35K wob, 60-130 rpm's, 117-108 spm, 494-456 gpm, off btm pressure 100-1150 psi, on btm pressure 100-1200 psi, off btm torque 4-12K ft-Ibs, on btm 5K ft-Ibs, PU wt 116-124K, SO wt 85-90K, Rot wt 98-104K, avg background gas 40 units Note: Had 2443 units gas while drilling @ 2700', Note: Start playing w/ parameters of geo pilot @ 3375' to try & get it working. 1/14/2005 14:00 - 14:45 14:45 - 15:15 15:15 - 18:00 2.75 CASE RURD SURFAC 18:00 - 20:30 2.50 WELCTL NUND SURFAC 20:30 - 21 :30 1.00 WELCTL NUND SURFAC 21 :30 - 00:00 2.50 WELCTL NUND SURFAC 1/15/2005 00:00 - 01 :00 01 :00 - 05:30 05:30 - 06:00 0.50 WELCTL OTHR SURFAC 06:00 - 07:00 1.00 DRILL PULD SURFAC 07:00 - 08:00 1.00 DRILL PULD SURFAC 08:00 - 09:00 1.00 DRILL OTHR SURFAC 09:00 - 09:30 0.50 DRILL OTHR SURFAC 09:30 - 10:00 0,50 DRILL PULD SURFAC 10:00 -11:15 1.25 DRILL TRIP SURFAC 11:15-14:45 3.50 DRILL DRLG SURFAC 14:45 - 15:30 15:30 - 16:45 16:45 - 00:00 Printed: 2/18/2005 10:11:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/16/2005 00:00 - 00: 15 0.25 DRILL DRLG INTRM1 RIH 1 stand, Drilled 97/8" hole per directional plan from 3436' to 3460' MOl 3025' TVD, ART .25hrs, 4K wob, 60-100 rpm's, 106 spm, 450 gpm, off btm pressure 1000 psi, on btm pressure 1070 psi, off btm torque 4K ft-Ibs, on btm 5K ft-Ibs, PU wt 124K, SO wt 90K, Rot wt 104K Note: Geo Pilot not working well. Need to build 5 deg per 100', staying flat, not hooking up. 00: 15 - 00:45 0.50 DRILL CIRC INTRM1 Monitor well, pump dry job. Blow down top drive. 00:45 - 01 :30 0.75 DRILL TRIP INTRM1 Pull 2 stands, hole tight & light swabbing, 01 :30 - 02:45 1.25 DRILL REAM INTRM1 Pump and backream wI 450 gpm f/3253-2503'. Monitor well. 02:45 - 03:30 0.75 DRILL CIRC INTRM1 Circ finish BU, max gas 140 units, Pump dry job. Change elevators to 511. 03:30 - 05:00 1.50 DRILL TRIP INTRM1 POOH f/2503' to Sperry Sun tools 05:00 - 05:30 0.50 DRILL OTHR INTRM1 Download Sperry Sun tools. 05:30 - 07:00 1.50 DRILL PULD INTRM1 UD BHA #2. Clean rollers on Geo Pilot break bit UD Geo Pilot. Hole fill 39 bbls 07:00 - 07:15 0.25 DRILL OTHR INTRM1 Clean floor. 07:15 - 08:00 0.75 DRILL PULD INTRM1 PU/MU BHA #3. Adjust motor to 1.5 deg, MU bit, PU LWDIMWD tools, orient. 08:00 - 08:45 0.75 DRILL OTHR INTRM1 Upload Spery Sun MWD/LWD tools. 08:45 - 11 :30 2.75 DRILL TRIP INTRM1 Finish MU BHA.MU 1 stand flex collars, RIH wI dp. Pulse test MWD @ 843'. Change out elevators f/5" to 4". RIH, fill pipe @ 2503, RIH to bottom. 11 :30 - 12:00 0.50 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 3460' to 3500' MOl 3053' TVD, ART .39 hrs, 10-30K wob, 80 rpm's, 120 spm, 507 gpm, off btm pressure 1550 psi, on btm pressure 1800 psi, off btm torque 5-9K ft-Ibs, on btm 8K ft-Ibs, PU wt 125K, SO wt 90K, Rot wt 105K 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 97/8" hole per directional plan from 3500' to 4609' MOl 3547' TVD, ART 3,66hrs, AST 2.87 hrs, 5-40K wob, 80-95 rpm's, 120-137 spm, 507-579 gpm, off btm pressure 1550-2000 psi, on btm pressure 1800-2200 psi, off btm torque 5-9K ft-Ibs, on btm 6-1 OK ft-Ibs, PU wt 125K, SO wt 90-85K, Rot wt 105-100K, avg background gas 30 units, max while drilling @ 3550' was 233 units. 1/17/2005 00:00 - 02:45 2.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4609' to 4941' MD/3635' TVD, ART 2.16hrs, AST 0.0 hrs, 5-35K wOb, 95 rpm's, 135 spm, 571 gpm, off btm pressure 2000 psi, on btm pressure 2150-2250 psi, off btm torque 5-9K ft-Ibs, on btm 8K ft-Ibs, PU wt 125K, SO wt 85K, Rot wt 100K, avg background gas 30 units, flow check @ 4870' gas 300 units, no flow, continue drilling @ 4931' gas increased f/300 units to 2200 units. No gain in pits. ECD's 10 ppg, 02:45 - 04:45 2.00 DRILL CIRC I NTRM 1 Circ out gas cut mud. MW in 9,2 ppg, lightest MW out 8.1 ppg. Circ BU, max gas 3466 units, once 9.2 ppg mud to surf, shut down f/10 min, monitor well, dead, CBU, Gas 150-250 units. ECD's 10 ppg. 04:45 - 08:30 3.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan and geologist from 4941' to 5270' MOl 3694' TVD, 81.24 deg., ART 1 ,69hrs, AST ,76 hrs, 25-35K wob, 95 rpm's, 135 spm, 571 gpm, off btm pressure 1950-2000 psi, on btm pressure 2150-2250 psi, off btm torque 5-9K ft-Ibs, on btm 8K ft-Ibs, PU wt 122K, SO wt 83K, Rot wt 97K, avg background gas 30 units, ECD's 10 ppg. 08:30 - 09:45 1,25 DRILL CIRC INTRM1 Circ weighted hi-vis sweep(11 ppg), monitor well. Estimated 15% cuttings return increase. 09:45 - 12:15 2.50 DRILL REAM INTRM1 Backream out of hole f/5270' to 3545' wI 570 gpm, 200-1700 psi, rot rpm 95. 12:15 -13:15 1.00 DRILL CIRC INTRM1 Circ weighted hi-vis sweep(11 ppg), wI 570 gpm, 1700 psi, 95 rpm. PU Printed: 2/18/2005 10:11:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: wt 125k, SO wt 92K, rot wt 105k. Estimated 25% cuttings return increase. Monitor well, pump out 3 stands 3545'-3266', POOH f/3266' to 2513' POOH UD 5" dp f/2513' to 750' UD Weatherford 9 7/8" ghost reamer, UD 14 joints 5" HWDP, UD jars, rack back 1 stand of 5" HWDP. UD BHA, download Sperry Sun MWD tools, break oft bit. Clear rig floor. Pull Vetco Gray Wear bushing. RU Doyon casing tools to run 7 5/8" casing. PJSM on running 75/8" 29.7 ppf, L-80, BTC-M casing. PU/MU 7 518" 29.7ppf L-80 BTCM casing. MU weatherford shoe, 2 jts, Fe, 1jt, circ thru float equip wI Frank's fillup tool. Circ 15 bbls. Held PJSM with rig crew on running 7 5/8" csg RIH with 7 5/8" 29.7#, L-80 BTCM casing. Ran jts #4-61 to 2650'. Installed centralizers as follows: One tandem 10' above shoe, bow on collar of joint #1 , two tandem on joint #2 10' fl each end, tandem on ceneter of joint #3, then every 30 to joint #10, No centralizer on joint #1 or the 20' pup above, continue wI centralizers every 30' , last centralizer 10' down fl box on joint #56. Bows run on box. Tandems run on stops. Total of 19 bows, 56 tandem, 56 stops. Circ casing @ 2650' (10 3/4" shoe @ 2,662') circ csg capacity 122 bbls. Circ 272 BBls, @ 6bpm wI 480 psi initial, 400 psi final. MW out 9,6ppg, circ till 9.3 ppg mw in and 9.3+ ppg mw out. PU wt 107K, ON wt 73K. Cont RIH with 7 5/8" 29,7#, L-80 BTCM casing f/2650' to 5,267' with no problems, ran a total of 120 jts, 7 5/8", 29.7#, L-80 BTC-M csg with 2- pup jts, total csg with float equip and hanger = 5,240' Circ and cond mud while circ btms up thru Franks fill up tool, staged pump rate up to 6.5 bpm at 500 psi, st wt up 178K, dn wt 92K LD Franks fill up tool, MU Vetco Gray hanger with Dowell cement head and landed csg in hanger with float shoe at 5,267' and float collar at 5,182' Fin circ and cond mud for cementing, conditioned mud from 9.3 ppg, 55 vis, 16 PV and 27 YP to 9.2 ppg, 45 vis, 14 PV, 13 YP, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. Dowell pumped 5 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 35 add, bbls of CW 100, Pumped 40 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 119.98 bbls, (293 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 5.2 bpm at 225 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. 0,75 CEMENTDISP INTRM1 Rig displaced cement with 9.1 ppg OBM, Bumped plug on calc displacement after pumping 238 bbls MOBM (96% pump eft.) ave 6.5 bpm while displacing cmt, Max pressure 700 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,100 psi, ck floats and held CIP at 14:00 hrs, Reciprocated pipe until 93.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 5267', Float Collar @ 5182', Calc TOC @ 2790', Had full returns thru out job, 0.25 CASE DEQT INTRM1 RU and attempted to test csg to 3,000 psi, after pumping 3.8 bbls and at 2,050 psi, pressure began to bleed down 1.00 CASE OTHR INTRM1 Closed annular and held 400 psi on csg while testing surface equipment for leaks and lines checked ok 1/17/2005 12:15 -13:15 1.00 DRILL CIRC INTRM1 13:15-15:15 2.00 DRILL TRIP INTRM1 15:15 - 17:00 1.75 DRILL TRIP INTRM1 17:00 - 18:00 1,00 DRILL TRIP INTRM1 18:00 - 20:15 2.25 DRILL TRIP INTRM1 20: 15 - 20:45 0.50 DRILL OTHR INTRM1 20:45 - 21 :15 0.50 DRILL OTHR INTRM1 21 :15 - 22:30 1.25 CASE RURD INTRM1 22:30 - 23:00 0.50 CASE SFTY INTRM1 23:00 - 00:00 1,00 CASE RUNe INTRM1 00:00 - 00:30 0.50 CASE SFTY INTRM1 00:30 - 03:45 3.25 CASE RUNC INTRM1 1/1 8/2005 03:45 - 04:30 0.75 CASE CIRC INTRM1 , 04:30 - 07:30 3.00 CASE RUNC INTRM1 07:30 - 10:30 3.00 CEMENTCIRC INTRM1 10:30 - 11 :45 1.25 CEMENT PULD INTRM1 11:45 -12:15 0.50 CEMENT CIRC INTRM1 12:15 - 13:15 1,00 CEMENT PUMP INTRM1 13:15 -14:00 14:00 - 14:15 14:15 - 15:15 Printed: 2/18/2005 10: 11: 19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/18/2005 15:15-17:30 2,25 CASE RURD INTRM1 RD cement head, LD landing jt and RD csg handling equipment, checked seals on landing jt and ck ok 17:30 - 18:30 1.00 WELCTL EQRP INTRM1 Installed 7 5/8" pack-off and tested to 5,000 psi for 10 min and ck ok 18:30 - 19:00 0.50 CASE DEQT INTRM1 Attempt to re-test csg, closed blind rams and pressured up on 7 5/8" csg to 3,000 psi, pressure bled down 1,000 psi in 3 min, no test 19:00 - 19:30 0.50 CASE OTHR INTRM1 RU on 7 5/8" x 10 3/4" annulus and flushed same with 120 bbls of water, at 2 bpm pressured up to 1,150 psi and broke down and cont to flush annulus, ave 3 bpm at 875 psi. 19:30 - 19:45 0,25 DRILL PULD INTRM1 MU Baker 7 5/8" Retrievamatic test packer 19:45 - 00:00 4.25 DRILL PULD INTRM1 RIH with Baker packer PU 24 jts of 4" HWDP and 45 jts of hybrid push pipe from pipe shed RIH to 2,104' 1/19/2005 00:00 - 02:45 2.75 DRILL PULD INTRM1 Cont RIH with Baker 7 5/8" retrieveamatic packer, RIH from 2,104' to 5,172', PU 99 jts of 4" XT-39 DP from pipe shed while RIH with packer 02:45 - 05:30 2.75 DRILL DEQT INTRM1 Set packer at 5,172' and attempted to test csg to 3,000 psi and would not test, moved packer up hole to 5,165',5,157',5,142' and 5,126' and still wouldn't test, determine packer had failed. Up wi 120k , On wi 83k 05:30 - 09:30 4,00 DRILL TRIP INTRM1 Pumped dry job and POOH to Baker packer, stood back HWDP and hybrid push pipe 09:30 - 09:45 0.25 DRILL PULD INTRM1 LD Baker packer, sent packer to Baker shop and found O-ring was cut in the piston of the packer 09:45 - 10:30 0,75 DRILL PULD INTRM1 LD 1 std of 5" HWDP from derrick 10:30 -11:00 0.50 DRILL PULD INTRM1 MU Halliburton 7 5/8" RTTS packer 11 :00 - 16:00 5.00 DRILL TRIP INTRM1 RIH with RTTS packer to 5,172', while RIH tested packer at 995' and 2,463' to 3,000 psi and packer ck ok, cont RIH to 5,172' and set packer, st wi up 120K, dn wi 83K 16:00 - 17:15 1.25 DRILL DEQT INTRM1 RU and tested 7 5/8" csg to 3,000 psi for 30 min, good test. Loss 120 psi over 30 min 17:15 - 21 :00 3.75 DRILL TRIP INTRM1 Pumped dry job and POOH, LD HES packer and cleared rig floor 21:00 - 21:15 0.25 DRILL SFTY INTRM1 Held PJSM on MU 6 3/4" BHA #4 21:15 - 00:00 2.75 DRILL PULD INTRM1 Began PU and MU 6 3/4" BHA #4, MU 6 3/4" bit #4, Geo-pilot with MWD, uploaded MWD and programmed Geo-Pilot, RIH to 87' Note: Little Red freeze protected 7 5/8" x 10 3/4" annulus with 85 bbls of diesel 1/20/2005 00:00 - 01 :30 1.50 DRILL PULD INTRM1 Fin MU 6 3/4" BHA #4, PU Flex De's, HWDP and jars RIH to 370', shallow tested MWD and Geo-Pilot 01 :30 - 04:00 2.50 DRILL TRIP INTRM1 RIH with BHA #4 from 370' to 5,037', PU an add. 12 jts of 4" DP from pipe shed while RIH 04:00 - 04:45 0.75 DRILL SFTY INTRM1 Held a stripping and well kill drill with rig crew 04:45 - 06:00 1.25 RIGMNT RSRV INTRM1 Slip and cut 85' of drilling line and serviced top drive 06:00 - 06:45 0.75 DRILL TRIP INTRM1 RIH from 5,037' to 5,179', washed down 93' and tagged plugs above float collar at 5,179' 06:45 - 11 :45 5,00 CEMENT DSHO INTRM1 Drilled out plugs and float collar at 5,182', shoe track, float shoe at 5,267' and 20' of new formation to 5,290' MOl 3,697' TVD, ART .5 hrs, 2-4K wob, 50 rpm's, 240 gpm, 1,600 psi, rot wi 85K, up wi 94K, dn wi 76K 11:45-12:15 0.50 DRILL CIRC INTRM1 Circ btms up at 5,290' evening MW in and out at 9.0 ppg MOBM, PU bit to inside of csg 12:15 -13:15 I 1.00 DRILL LOT INTRM1 RU and performed LOT to 12.8 ppg EMW with 9.0 ppg MOBM, 735 psi at 3,698' TVD 13:15 - 00:00 10.75 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable assembly from 5,290' to 6,262' MOl 3,744' TVD (972'), ART 7.7 hrs, 5-12K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wi Printed: 2/18/2005 10:11:19 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/20/2005 13:15 - 00:00 10.75 DRILL DRLG PROD 80K, up wt 102K, dn wt 70K, 9.0 ppg MOBM, clean hole ECD was 9.8 ppg, ave ECD 10.5 ppg, ave BGG 100 units, max gas 540 units 1/21/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 6,262' to 7,188' MOl 3,767' TVD (926'), ART 10,3 hrs, 3-12K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,475 psi, on btm 2,525 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 111 K, dn wt 66K, 9,0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 100-250 units, max gas 400 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 7,188' to 8,245' MOl 3,765' TVD (1,057'), ART 8,64 hrs, 3-13K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,600 psi, on btm 2,700 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 114K, dn wt 69K, 9,0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 300 units, max gas 468 units 1/22/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 8,245' to 9,611' MOl 3,777' TVD (1,366'), ART 7.86 hrs, 3-10K wob, 85 rpm's to 3,900' then 105 rpm's to 9,611',85 spm, 300 gpm, off btm pressure 2,725 psi, on btm 2,775 psi, off btm torque 7.5K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 122K, dn wt 56K, 9,0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 300 units, max gas 468 units, pumped weighted hi vis sweep at 9,147' with 10-15% increase in cuttings 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 9,611' to 10,552' MOl 3,763' TVD (941 '), ART 9.2 hrs, 3-14K wob, 105 rpm's, 85 spm, 300 gpm, off btm pressure 3,000 psi, on btm 3,075 psi, off btm torque 7.5K ft-Ibs, on btm 8K ft-Ibs, rot wi 88K, up wt 130K, dn wi 56K, 9.0 ppg MOBM, ave ECD 11.1 ppg, ave BGG 200 units, max gas 396 units pumped weighted hi vis sweep at 9,895' with 5-10% increase in cuttings back 1/23/2005 00:00 - 09:00 9,00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 10,552' to 11,076' MOl 3,752' TVD (524'), ART 6.44 hrs, 2-1 OK wob, 105-110 rpm's, 85 spm, 300 gpm, off btm pressure 3,075 psi, on btm 3,150 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wi 92K, up wt 131K, dn wt 58K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave BGG 100 units, max gas 240 units, Note: While drilling calcite stringers, would slow rotary to 70 rpm's due to tool vibration. Torque spiked to 10,000 ft-Ib, 09:00 - 09:15 0.25 DRILL OBSV PROD Monitored well-static 09:15 -15:45 6,50 DRILL WIPR PROD Began wiping hole to shoe, backreamed out of hole from 11,076' to 6,620', backreamed out at 85 rpm's with 7K ft-Ibs torque, 300 gpm at 2,700 psi, began pulling tight in shale section at 6,620' 15:45 -18:15 2.50 DRILL REAM PROD Backreamed out of hole slow due to packing off in shale section from 6,560' to 6,480', 85 rpm's with 5K ft-Ibs torque, 300 gpm at 2,200 psi 18:15 - 19:30 1.25 DRILL WIPR PROD Backreamed out of hole from 6,480' to 5,800', backreamed out at 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,200 psi, began pulling tight in upper shale section at 5,800' 19:30 - 23:30 4,00 DRILL REAM PROD Backreamed out of hole slow due to packing off in shale section from 5,800' to 5,689', 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,100 psi, would drop down thru reamed area and did not have any problems pulling thru spot 23:30 - 00:00 0.50 DRILL WIPR PROD Backreamed out of hole from 5,689' to 5,416', backreamed out at 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,000 psi, no problems backreaming in sand section, Note: lost 56 bbls of mud to hole while Printed: 2/18/2005 10: 11 : 19 AM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRilLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/23/2005 23:30 - 00:00 0.50 DRILL WIPR PROD backreaming out 1/24/2005 00:00 - 00:45 0.75 DRILL WIPR PROD Fin wiping hole to shoe by backreaming out of hole from 5,416' to 5,211' (7 5/8" Shoe @ 5,267'), Backreamed out at 85 rpm's, 300 gpm at 2,100 psi with no problems 00:45 - 01 :30 0.75 DRILL CIRC PROD Circ 2X btms up at shoe with no increase in cuttings and was clean at shakers, circ at 300 gpm at 2,100 psi and 50 rpm's 01 :30 - 02:00 0.50 RIGMNT RSRV PROD Serviced top drive and inspected XT-39 saver sub and ck ok 02:00 - 05:45 3.75 DRILL TRIP PROD RIH from 5,211' to 10,937', no problems RIH thru shale sections 05:45 - 06:30 0,75 DRILL REAM PROD Washed and reamed 139' to btm, washed from 10,937' to 11,076' 06:30 - 12:00 5,50 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 11,076' to 11,417' MOl 3,748' TVD (341'), ART 3.51 hrs, 3-14K wob, 115 rpm's, 80 rpm's thru calcite stringers, 89 spm, 317 gpm, off btm pressure 3,600 psi, on btm 3,700 psi, off btm torque 8K ft-Ibs, on btm 8.5K ft-Ibs, rot wi 97K, up wi 133K, dn wi 60K, 9,0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 50 units, max gas 111 units 12:00 - 23:15 11.25 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 11,417' to 12,415' MOl 3,742' TVD (998'), (T.D.) ART 7.41 hrs, 4-12K wob, 115 rpm's, 80 rpm's thru calcite stringers, 87 spm, 310 gpm, off btm pressure 3,975 psi, on btm 4,100 psi, off btm torque 9K ft-Ibs, on btm 8.5K ft-Ibs, had 11 K ft-Ib spikes while drlg on calcite stringers, rot wi 116K, up wi 157K, dn wi 69K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 100 units, max gas 206 units, Note pumped 35 bbl weighted hi vis sweep (2# over MW) at 12,300', ECD peaked at 12.2 ppg soon after going out bit and began having mud losses while drlg stand down and CÎrc out sweep, had a 20% increase in cuttings back from sweep and lost a total of 74 bbls of 9,0 MOBM, prior to sweep rot wi was 114K, up wi 172K, dn wi 35K, at TO had 15 stds of hybrid push pipe, 8 stds of 4" HWDP and 38 lo-tads in hole 23: 15 - 23:30 0.25 DRILL OBSV PROD Monitored well and had slight breathing due to losses 23:30 - 00:00 0.50 DRILL WIPR PROD Began wiping hole to shoe, backreamed out from 12,415' to 12,303' 1/25/2005 00:00 - 13:15 13,25 DRILL WIPR PROD ConI. wiping hole to shoe, backreamed out from 12,303' to 5,230', backreamed out at 110-115 rpm's and 315 gpm, initial pressure 3,700 psi, final 2,275 psi, pulled slowed thru shale sections due to packing off slightly, calc fill on trip out 56 bbls, actual fill 82 bbls 13:15 - 14:30 1,25 DRILL CIRC PROD Circ hole clean at shoe, pumped weighted hi vis sweep and had no increase in cuttings back from sweep, circ a total of 2x btms up and was clean at shakers, circ at 300 gpm, 2,150 psi, 80 rpm's with 4K ft-Ibs torque, st up wi 95K, dn wi 80K 14:30 - 14:45 0,25 DRILL OBSV PROD Monitored well at shoe-static 14:45-19:15 4,50 DRILL TRIP PROD RIH from 5,230' to 12,213', no problems RIH thru shale sections 19:15 - 20:00 0,75 DRILL REAM PROD Wash and reamed 202' to btm at 12,415' with no problems 20:00-22:15 2.25 DRILL CIRC PROD Pumped hi vis sweep only and circ out of hole with no increase in cuttings, circ at 290 gpm, 4,000 psi, 115 rpm's and 8K ft-Ibs off btm torque, 9.0 ppg MOBM, ECD ave 11.8 ppg, max gas at btms up 160 units then ave 35 units, obtained Geo-Pilot pressure data for Sperry Sun after circ out sweep 22: 15 - 23:45 1.50 DRILL CIRC PROD Displaced out 9,0 ppg MOBM to 9.0 ppg SFMOBM, circ at 300 gpm, 3,900 psi, 115 rpm's, 9K ft-Ibs torque, rot wi 115K, up wi 160K, dn wi 45K 23:45 - 00:00 0,25 DRILL OBSV PROD Monitored well-static, preparing to POOH 1/26/2005 00:00 - 09:00 9.00 DRILL TRIP PROD POOH wet from 12,415' to BHA at 270', no problems pulling thru shale sections 09:00 - 12:15 3.25 DRILL PULD PROD POOH and stood back flex De's, HWDP and jars, downloaded MWD Printed: 2/18/2005 10:11:19AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/26/2005 09:00 -12:15 3,25 DRILL PULD PROD and LD same with Geo-Pilot rotary steerable assembly, cleared rig floor 12:15 - 12:45 0.50 CASE RURD CMPL TN RU Doyon's 4 1/2" liner running equipment 12:45 - 13:00 0.25 CASE SFTY CMPL TN Held PJSM with rig crew, tong operator and Saker rep on running of liner 13:00 -18:30 5.50 CASE PULR CMPL TN PU and RIH with 4 1/2", 12.6#, L-80 DWC IISTM Liner per well program to 7,428' (241Jts total), ran 41/2" ROT silver bullet guide shoe with no float, ran a total of 207 jts (6,600') of 41/2" 12.6#, L-80, ISTM slotted liner, (btm 26 slotted jts are DWC), ran 34 jts (1,056') of 4 1/2", 12.6# L-80 ISTM blank liner, ran 234 - 41/2" x 61/2" spiralglide centralizers 1/jt #1 thru # 233, ran 6 constrictor packers placed on blank liner to cover shale sections. 18:30 - 19:00 0.50 CASE PULR CMPL TN MU Saker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 7,483', st wt up 84K, dn wt 66K, 19:00 - 22:30 3.50 CASE RUNL CMPL TN RIH with liner on 4" DP to 12,385', while RIH began to slack off 30-40K# at 12,270', worked liner thru tight spot from 12,270' to 12,323' then was able to cont RIH, RIH and tagged btm at 12,415', no problems thru shale sections in upper hole section, PU to 12,385' to put liner on depth, ran liner with 28 stds of 4" DP w/Lo-Tads, 8 stds HWDP w/Lo-tads, 15 stds Hybrid push pipe, st wt up 143K, dn wt 90K 22:30 - 22:45 0.25 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2 1/2 bpm at 400 psi, with ball on seat pressured up to 2,500 psi to set Flexlock hanger, slacked off 40K, cont to set packer, pressured up to 4,200 psi and set ZXP packer, no problems setting hangerl packer, set "S" sand liner with TOL @ 4,905' MOl 3,626' TVD and shoe at 12,388' MOl 3,740' TVD 22:45 - 23:00 0.25 CASE DEQT CMPL TN Tested ZXP packer to 1,000 psi for 5 min & checked ok 23:00 - 23:45 0.75 CASE CIRC CMPL TN PU out of top of liner no problems and circ btms up, circ at 300 gpm, 2000 psi, no gas at btms up, st wt up after setting liner 125K, 108K dn 23:45 - 00:00 0.25 DRILL OSSV CMPL TN Monitored well-static, preparing to POOH 1/27/2005 00:00 - 03:00 3.00 DRILL TRIP CMPL TN POOH wet and LD Saker liner running tool, cleared rig floor 03:00 - 06: 15 3.25 WINDOVVPULD PROD2 Held PJSM, PU & MU Saker 7 5/8" whipstock assembly SHA #5 and RIH to 576', MU milling assembly and LD same, PU seal assembly, locator sub, unloader sub, then PU 2-DP pup jts, 1 jt of 3 1/2" HWDP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 4 stds of hybrid push pipe to 576' 06:15 - 10:15 4.00 WINDOWTRIP PROD2 RIH with whipstock assembly from 576' to 4,674', shallow tested MWD W/RIH 10:15-11:30 1,25 WINDOVVOTHR PROD2 Made MADD pass from 4,674' to 4,758' and correlated MWD to K-13, cont to RIH orienting whipstock, RIH & tagged TOL at 4,905', logged K-13 at 250 gpm, 1,800 psi, st wt up 123K, dn wt 105K, RIH with whipstock milling assembly with 27 stds of 4" DP with Lo-tads, 8 stds of HWDP with Lo-tads and 11 stds of hybrid push pipe 11 :30 - 11 :45 0.25 WINDOWSETW PROD2 Oriented whipstock 6 deg left of high side, tagged TOL at 4,905', set whipstock and sheared off from same, top of whipstock at 4,816' 11:45 - 12:15 0.50 WINDOVVCIRC PROD2 Displaced out 9.0 ppg SFMOSM to 9,0 ppg MOSM, circ at 250 gpm, 1,800 psi, rot wt 107K, up wt 123K, dn 105K 12:15 -17:45 5.50 WINDOWSTWP PROD2 Milled window in 7 5/8" casing for "0" sand lateral, top of window at ;' 4,816', btm of window at 4,828", drilled 6 3/4" hole to 4,875' MOl 3,617' TVD (59') ADT 4,7 hrs, 1-4K wob while milling, 5-12K while drlg formation, 80-120 rpm's, 315 gpm, 2,700 psi, torque 3-7K ft-Ibs, rot wt Printed: 2/18/2005 10:11:19AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1 E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/27/2005 12:15 - 17:45 5.50 WINDOWSTWP PROD2 110K, up wi 120K, dn wt 107K, Note: Drilled extra hole to have 30' of gauged hole out of window for Geo-pilot tool 17:45 - 18:45 1.00 WINDOWCIRC PROD2 Pumped weighted hi vis sweep and circ hole clean while working mills thru window, circ at 315 gpm, 2,600 psi 18:45 - 19:00 0.25 WINDO\l\lOTHR PROD2 Monitored well-static, pumped dry job, 19:00 - 20:45 1.75 WINDOWTRIP PROD2 POOH from 4,794' to 213', stood back 4 stds hybrid push pipe 20:45 - 22:30 1.75 WINDOWPULD PROD2 LD MWD and milling assembly, upper mill out of gauge 1/32", took gauge and gauged next bit to be RIH and ck ok 22:30 - 23:30 1.00 WINDO\l\lOTHR PROD2 Pulled wear bushing and flushed out stack after milling window 23:30 - 00:00 0.50 WELCTL BOPE PROD2 RU to test BOPE 1/28/2005 00:00 - 04:00 4,00 WELCTL BOPE PROD2 Tested BOPE, rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, Note: Jeff Jones with AOGCC witnessed test 04:00 - 04:30 0.50 DRILL PULD PROD2 Pulled test plug and installed wear bushing 04:30 - 05:30 1.00 RIGMNT RSRV PROD2 Slip and cut 80' of drlg line 05:30 - 07:30 2.00 RIGMNT RSRV PROD2 Serviced top drive and changed out XT-39 saver sub 07:30 - 10:00 2.50 DRILL PULD PROD2 MU 6 3/4" BHA #6 and RIH to 371', MU 6 3/4" bit #6, Geo-pilot rotary steerable with MWD, uploaded MWD and programmed Geo-pilot, then RIH with flex dc's, HWDP and jars to 371' 10:00 - 10:45 0.75 DRILL DEQT PROD2 Shallow tested MWD and recorded ECD pressures for Sperry Sun 10:45 - 12:45 2,00 DRILL TRIP PROD2 RIH with BHA #6 from 371' to 4,763' 12:45 - 13:30 0.75 DRILL REAM PROD2 RIH from 4,763' thru window at 4,816' with pumps off, no problems, est circ and worked Geo-pilot thru window several times with no problems, washed to btm at 4,875', rot wi 85K, up wi 95K, dn wi 76K, 30-40 rpm's with 3.5K ft-Ibs torque 13:30 - 00:00 10.50 DRILL TRIP PROD2 Directionally drilled 6 3/4" hole in "0" sand lateral with Geo-Pilot rotary steerable system from 4,875' to 5,654' MOl 3,671' TVD (779'), ART 8.55 hrs, 2-14K wob, 90-110 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 3,5K ft-Ibs, on btm 4K ft-Ibs, rot wi 86K, up wi 96K, dn wi 75K, 9,0 ppg MOBM, ave ECD 10,1 ppg, ave BGG 300 units, max gas 788 units 1/29/2005 00:00 -11:15 11.25 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Geo-Pilot rotary steerable system from 5,654' to 6,577' MDI 3,696' TVD (923'), ART 9.07 hrs, 2-14K wob, 110 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,500 psi, on btm 2,550 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wi 85K, up wt 103K, dn wt 69K, 9.0 ppg MOBM, ave ECD 10.4 ppg, ave BGG 300 units, max gas 668 units 11:15 -12:15 1.00 DRILL DEQT PROD2 Trouble shoot Geo-Pilot signal, unable to get tool to respond, tool failed 12:15 -13:15 1.00 DRILL CIRC PROD2 Pumped weighted hi vis sweep at 6,577' and circ out of hole, no increase in cuttings back from sweep, circ at 300 gpm, 2,750 psi, 80 rpm's, 5K ft-Ibs torque 13:15 - 15:30 2,25 DRILL TRIP PROD2 Backreamed out of hole from 6,577' to 4,950' then pumped out hole thru window to 4,790', backreamed out at drlg rate 300 gpm, 110 rpm's 15:30 - 16:30 1.00 DRILL CIRC PROD2 Circ 2X btms up above window at 4,790' and clean at shakers, circ at 300 gpm, 2,400 psi, 80 rpm's, 4K ft-Ibs torque, rot wt 85K, up wi 95K, dn wt 76K 16:30 - 16:45 0,25 DRILL OBSV PROD2 Monitored well-static, pumped dry job 16:45 - 18:00 1.25 DRILL TRIP PROD2 POOH from 4,790' to BHA at 371' 18:00 - 20:15 2.25 DRILL PULD PROD2 POOH and stood back HWDP, jars and flex dc's, downloaded MWD, LD MWD and Geo-Pilot 20:15 - 22:30 2.25 DRILL PULD PROD2 MU 6 3/4" BHA #7 and RIH to 368', MU bit #7 with slickbore motor with I Printed: 2/18/2005 10: 11: 19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/6/2005 Group: 1/29/2005 20:15 - 22:30 2.25 DRILL PULD PROD2 1.5 deg bend and MWD, oriented and uploaded MWD, then RIH with flex dc's, HWDP and jars to 368' 22:30 - 00:00 1.50 DRILL TRIP PROD2 RIH with BHA#7 from 368' to 3,919' 1/30/2005 00:00 - 01 :30 1.50 DRILL TRIP PROD2 Fin RIH from 3,919' to btm at 6,577', no problems RIH thru window and washed 42' to btm 01 :30 - 12:00 10.50 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Slickbore motor from 6,577' to 7,186 MOl 3,712' TVD (609'), ART 6.71 hrs, AST .92 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wi 84K, up wi 105K, dn wi 68K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 100 units, max gas 415 units 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Slickbore motor from 7,186 to 8,416' MD/3,713' TVD (1,230'), ART 5.95 hrs, AST 1.82 hrs, 3-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,475 psi, on btm 2,625 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wi 84K, up wi 112K, dn wi 64K, 9,0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 100 units, max gas 562 units 1/31/2005 00:00 - 09:00 9,00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "0" sand lateral with Slickbore motor from 8,416' to 8,903' MOl 3,706' TVD (487'), ART 5.77 hrs, AST 1.13 hrs, 3-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,550 psi, on btm 2,750 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wi 84K, up wi 114K, dn wi 61 K, 9,0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 70 units, max gas 160 units 09:00 - 10:30 1.50 DRILL CIRC PROD2 Circ hole while evaluating logs for geology 10:30 - 13:45 3,25 DRILL DRLG PROD2 Drilled 6 3/4" hole from 8,903' to 9,115' MOl 3,712' TVD (212') ART .9 hrs, AST 1,02 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,650 psi, on btm pressure 2,750 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wi 84K, up wi 116K, dn wi 59K, 9,0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 100 units, unable to slide due to lack of down weight 13:45 - 15:00 1.25 DRILL WIPR PROD2 Backreamed out of hole 9 stds from 9,115' to 8,230' to reposition HWDP and pushpipe, no problems, backreamed out at 300 gpm, 2,750 psi, 95 rpm's and 6K ft-Ibs torque 15:00 - 15:45 0.75 DRILL WIPR PROD2 RIH from 8,230' to 9,071' and washed 44' to btm with no problems, rot wi 95K, up wi 124K, dn wi 72K, RIH with 8 stds HWDP with lo-tads and 1 std of hybrid push pipe 15:45 - 00:00 8.25 DRILL DRLG PROD2 Drilled 6 3/4" hole from 9,115' to 9,676' MOl 3,715' TVD (561') ART 4.26 hrs, AST 1.18 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,975 psi, on btm pressure 3,175 psi, off btm torque 7.5K ft-Ibs, on btm 7,5K ft-Ibs, rot wi 104K, up wi 133K, dn wi 77K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 100 units, max gas 286 units 2/1/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 9,676' to 10476' MD/3,690' TVD (800') ART 6,66 hrs, AST 1.38 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,975-3350 psi, on btm pressure 3,175-3450 psi, off btm torque 7,5-9.5K ft-Ibs, on btm 7.5-9.K ft-Ibs, rot wi 104-112K, up wi 133-145K, dn wi 77-82K, 9.0 ppg MOBM, ave ECD 11 ppg, ave BGG 118 units, max gas 358 units 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 10476' to 11451' MOl 3665' TVD (975') ART 4.84 hrs, AST 1,96 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 3350-3500 psi, on btm pressure 3,450-3650 psi, off btm torque 9.5-11.5K ft-Ibs, on btm 9-11 K ft-Ibs, rot wi 112-109K, up wi 145-160K, dn wi 80-60K, 9.0 ppg MOBM, ave ECD Printed: 2/18/2005 10: 11: 19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 2/1/2005 12:00 - 00:00 12.00 DRILL DRLG PROD2 11.1 ppg, ave BGG 118 units, max gas 285 units 2/2/2005 00:00 - 08:00 8.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 11451' to 12050' MD/3680' TVD (599') ART 3.31 hrs, AST 1.96 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 3500-3650 psi, on btm pressure 3650- 3825 psi, off btm torque 11.5-12K ft-Ibs, on btm 11- 11.5K ft-Ibs, rot wi 109-106K, up wi 160-166K, dn wi 65-55K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 120 units, max gas 329 units 08:00 - 08:30 0.50 DRILL CIRC PROD2 Circ and recip pipe while geologist confirs wI town. 08:30 - 14:00 5.50 DRILL DRLG PROD2 Drilled 6 3/4" hole from 12050' to 12414' MOl 3671' TVD (364') ART 1.59 hrs, AST 2.06 hrs, 2-15K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 3725 psi, on btm pressure 3800 psi, off btm torque 11 ,5-12K ft-Ibs, on btm 11-13K ft-Ibs, rot wi 105K, up wi 167, dn wi 60-55K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 95 units, max gas 256 units 14:00 - 14:15 0.25 DRILL ICIRC PROD2 Monitor well, static, circ 15 min. 14:15 - 23:30 9.25 DRILL REAM PROD2 Backreamed out from 12,414' to 4949', backreamed out at 95 rpm's and 300 gpm, initial pressure 3,725 psi, final 1900 psi, calc fill on trip out 58 bbls, actual fill 95 bbls(running solids control equip). Did not rotate or pump while pulling fl 4949'-4791'. No problems pulling through window @ 4828'-4816'. PU wI@ window, 98k. 23:30 - 00:00 0.50 DRILL CIRC PROD2 Circ and recip @ 300 gpm, 1800 psi, 100 rpm. Pump hi-vis weighted 2# I over (11.0 ppg) sweep to clean hole. 2/3/2005 00:00 - 00:30 0.50 DRILL CIRC PROD2 Circ and recip @ 300 gpm, 1800 psi, 100 rpm. Pump hi-vis weighted 2# over (11.0 ppg) sweep to clean hole. 00:30 - 00:45 0.25 DRILL OTHR PROD2 Orient to high side, slide through window wlo pumps, no problems, monitor well. 00:45 - 05:00 4.25 DRILL TRIP PROD2 Trip in hole f/4854' to 12414'. Fill pipe every 20 stands. Picked up 1 jt and 10' pup jt to tag bottom @ 12414'. No problems. 05:00 - 07:00 2.00 DRILL CIRC PROD2 Establish circulation, everything looks good, pump Hi-vis sweep @ 85 spm wI 3800 psi. 07:00 - 08:30 1.50 DRILL CIRC PROD2 Displace well to solids free oil base mud. 85 spm wI 3800 psi. 08:30 - 08:45 0.25 DRILL CIRC PROD2 Slow pump rates, monitor well, OK. 08:45 - 12:00 3.25 DRILL TRIP PROD2 POOH on elevators f/12414' to 6348'. No problems, 12:00 - 14:00 2.00 DRILL TRIP PROD2 POOH on elevators f/6348' to 365', No problems @ window, or any other place. 14:00 - 16:15 2,25 DRILL PULD PROD2 UD BHA # 7. UD 5 HWDP, jars, x-o, 3 NMDC's, download MWD/LWD, UD bit, pull MWD probe, UD logging tools and MWD, UD motor. 16:15-16:45 0.50 WINDOWPULD CMPL T2 MU Baker whipstock retieving assembly. 1 jt 3 1/2" HWDP, hook, bumper jars, oil jars, x-o 16:45 - 18:30 1.75 WINDOWTRIP CMPL T2 Trip in hole f/58' to 4784'. PU wi 124k, So wi 106K. Tagged slot on whipstock @ 4822'. 18:30 - 19:15 0,75 WINDOI/VOTHR CMPL T2 Wash slot, turn 1/4 turn four times, hooked slot, sheared un loader @ 160k, pick up to 190k. cock jars, PU to 200k, cock jars, PU to 175K, jars fired, pulling assembly free. Hole taking a little fluid, 13 bbls to fill hole. Pull 40', set stand back. 19:15 - 20:00 0.75 WINDOWCIRC CMPL T2 Circ bottoms up. wI 60 spm & 1000 psi. Hole took 8 bbls while circ. Monitor well. Static. No gas. 20:00 - 22:30 2.50 WINDOWTRIP CMPL T2 Drop 1 3/4" rabbit on wire. POOH wI Whipstock. 22:30 - 00:00 1.50 WINDOWPULD CMPL T2 UD whipstock retrieving tools BHA, UD whipstock and debris excluder sub, unloader valve, emergency shear disconnect, 7 5/8" Torquemaster retrievable BTA, double pin blanking sub, unloader valve. 2/4/2005 00:00 - 00:30 0.50 WINDOWPULD CMPL T2 Finish UD whipstock assembly, UD 1 jt 31/2" HWDP, (2) 3 1/2" dp pups, locator sub and dummy seals. Clean & clear rig floor. Printed: 211812005 10:11:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Sta rt: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/6/2005 Group: 2/4/2005 00:30 - 00:45 00:45 - 01 :00 01 :00 - 04:45 04:45 - 06:45 06:45 - 07:15 07:15 - 10:00 10:00 - 10:45 10:45 - 11 :00 0.25 CMPL TN RURD CMPL T2 0.25 CMPL TN SFTY CMPL T2 3.75 CMPLTN RUNT CMPLT2 2.00 CMPL TN RUNT CMPL T2 0.50 CMPL TN OTHR CMPL T2 2.75 CMPL TN TRIP CMPL T2 0.75 CMPL TN OTHR CMPL T2 0.25 CMPL TN CIRC CMPL T2 11 :00 - 11 :45 0.75 CMPL TN CIRC CMPL T2 11:45 - 12:00 0.25 CMPL TN OTHR CMPL T2 12:00 - 14:00 2.00 CMPL TN TRIP CMPL T2 14:00 - 14:30 0.50 CMPL TN PULD CMPL T2 14:30 - 15:30 1.00 DRILL OTHR CMPL T2 15:30 - 22:00 6.50 DRILL PULD CMPL T2 22:00 - 00:00 2.00 DRILL PULD CMPL T2 2/5/2005 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 05:45 1.00 DRILL PULD CMPL T2 2.50 DRILL PULD CMPL T2 0.50 DRILL PULD CMPL T2 1.00 RIGMNT RSRV CMPL T2 0.50 CMPL TN RUNT CMPL T2 0.25 CMPL TN SFTY CMPL T2 RU to run 41/2" 12.6#/ft L-80 IBT slotted production liner. PJSM on running 4 1/2" "0" lateral slotted liner. PU & ran 4-112" liner per program to 4839'. Ran 3-1/2" Baker guide shoe, 3-1/2" bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, ran 156 jts of 41/2" 12.6#, L-80 IBT liner to window. Went through window @ 4816'-4828' with no problems. PU wt 73K. SO wt 68k. Continue running 4-1/2" liner per program to 7541', Ran total of 244 jts (7493,66') of 4 1/2" 12.6#, L-80, IBT liner, ran 229 jts (7031.86') of slotted liner and 15 jts (461.80') of blank liner. Ran (243) 4 1/2" x 6 1/2" spiralglider centralizers, 1/jt on all of liner, except last blank. Ran a total of (4) easy Well Solutions Constrictor swell packers to be set at 12152', 11981',9031',8851'. M/U Baker Model B1 Flanged Hook Hanger & running tool. RIH 1 std 4" dp wI LoTads. Up wt 82K, On wt 63K. RIH with 4 1/2" liner on 4" DP from 7679' to 12383'. Ran liner using total of 51 stands dp (27 stands 4" weatherford dp wI Lo-Tads, 8 stands 4" weatherford HWDP wI Lo-tads, and 15 stands 4" Hybrid (4" HWDP on top then 2 joints 4 3/4" DC), then 1 stand slick 4" weatherford dp. PU wt 143K, SO wt 77K. Hook Baker Model B1 Hook hanger in window, wI top of hook hanger @ 4812', Hook and recheck several times to verify position (Hooked total of 9 times at the same depth, turning orientation 10 times to verify). With liner hooked and top of hook hanger @ 12383', pump ball @ 4bpm wI 700 psi. With ball on seat, pressure up to 2500 psi to release fl hook hanger. Bleed pressure to zero. PU wt 125k, SO wt 60k. Positive indicator of losing 16K liner weight. Pressure to 3200 psi to shear pump out sub. Circulate bottoms up @ 4813', pump 85 spm(7.2 bpm) & 1600 psi. Blow down top drive, monitor well. OK. POOH wI Weatherford 4" S-135, XT-39 dp used to run liner. Calc fill 40 bbls, actual fill 47 bbls. UD Baker Liner running tools. Clear rig floor. RU to UD 4" Weatherford DP in mouse hole. PJSM. UD 80 stands Weatherford 4", S-135, XT-39 dp fl off drillers side of derrick. Lay down using mouse hole, UD 18 stands Weatherford 4", S-135, XT-39 dp wI Lo-Tads installed after the double (on top of bottom single). Lay down using mouse hole. Note: While laying down dp fl derrick, hole took 5 bbls in 9 1/2 hours (1430 hrs to midnight) Note: All OBM has been centifuged, then weighted back up to 9.0ppg wI S-200, then stored in upright tanks on 1 E pad. UD 9 stands Weatherford 4", S-135, XT-39 dp wI Lo-Tads installed after the double (on top of bottom single). Lay down using mouse hole, UD 8 stands Weatherford 4" S-135, XT-39 HWDP wI Lo-tads installed after the double (on top of bottom single). Lay down using mouse hole. UD 15 stands Hybrid pipe( 1 joint on top of (2) Weatherford 4 3/4" Spiral DC's. Lay down using mouse hole. UD Lotads off rig floor. Clear floor. PJSM on slip and cut drilling line. Slip and cut 91' drilling line. Rig up tools to run 4 1/2" 12.6 ppf L-80 IBT-M tubing. PJSM on running 4 1/2" 12.6 ppf L-80 IBT-M tubing, to run in hole and stand back fl ESP completion. Note: Hole took 3.6 bbls in 6 hours. Printed: 2/18/2005 10:11:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: PJSM, PU/MU/RIH 132 joints 41/2" 12.6 ppf L-80 IBM tubing wI special clearance collars. Mule shoe on bottom, Run to 4105'. Circ bottoms up @ 85 SPM (7.2 bpm) wI 700 psi, 9.0 ppg Solids Free Oil Base Mud. RID circ equip. RU double stack tongs. Hole took 1 bbl while circ. POOH, Stand back (44) stands 4 1/2" 12.6 ppf L-80 IBT-M tubing fl ESP completion. Pull Vetco Gray wear bushing, Clear rig floor. RU fl ESP completion. PJSM on running 4 1/2" ESP completion. PU Centrilift's ESP motor assembly, tandem seal section with screen intake, filled motor with oil and connect ESP cable and checked same, Installed 1/4" control line for pump gauge RIH with ESP assembly to 136': PU jts # 1 & # 2,41/2",12.6#, L-80, IBTM SCC tbg and MU well discharge pressure sub Connected 1/4" control line to discharge pressure sub and checked cable continuity. RIH slow with ESP completion assembly from 136' to 752': Ran joints #3-#20,41/2" 12.6ppf L-80 IBTM with special clearance collars, PU Camco GLM KBG-2 with pups each end, ran joints running cable and installing single channel across collar clamps on every other jt and checking cable conductivity every 1,000' 1.50 CMPL TN RUNT CMPL T2 Continue RIH slow with ESP completion assembly from 752' to 1640': Ran joints #21-#49, 41/2" 12.6ppf L-80 IBTM with special clearance collars, PU Camco GLM KBG-2 with pups each end, running cable and installing cannon clamps on every other jt and checking cable conductivity every 1,000'. PU wt 60K, SO wt 56K 0.75 CMPLTN RUNT CMPLT2 RIH slow with ESP completion assembly from 1640' to 1982': Ran joints #50-#60,4 1/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. 1.75 CMPLTN RUNT CMPLT2 RIH slow with ESP completion assembly from 1982' to 2912': Ran joints #61- #90,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable, 1,25 CMPL TN RUNT CMPL T2 RIH slow with ESP completion assembly from 2912' to 3848': Ran joints #91- #120,4 1/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. 0.75 CMPL TN RUNT CMPL T2 RIH slow with ESP completion assembly from 3848' to 4254': Ran joints #121- #133,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. 0.50 CMPL TN RUNT CMPL T2 MU Vetco Gray Hanger (13 1/2" 00, 4.909 MeA top thread, full joint PxP 41/2" 12.6 ppf IBT below hanger) and Landing jt with TWC. PU wt 84K, So wt 72K. Continuity check. OK. Cut ESP Cable. Rig down sheave in derrick fl running ESP cable. Spliced ESP Cable and MU to tbg hanger, attatch band above and below splice. (Total 3 bands on landing joint). Test line, OK. RIH, landed hanger and RILDS, Land string as per detail wI Tail @ 4309'(TVD = 3433', 64,7 deg), Pump guage @ 4305'(3432' TVD, 64.77 deg), Motor @ 4271', Seal Section @ 4257'( 3412 TVD, 64,9 deg), screen intake @ 4246'( 3407' TVD, 64.9 deg), discharge pressure sub @ 4171 '( 3375' TVD,64,5 deg), GLM #1 @ 3593' MD( 3112' TVD, 54.6 deg), GLM #2 @ 2675' MD( 2403' TVD, 37.2 deg), ran a total of 133 jts (4135.78') of 41/2" 12,6#, L-80, IBTM tbg with special clearance 2/5/2005 05:45 - 08:45 3,00 CMPL TN RUNT CMPL T2 08:45 - 10:00 1.25 CMPL TN CIRC CMPL T2 10:00 - 12:15 2,25 CMPL TN TRIP CMPL T2 12:15 - 12:30 0,25 CMPL TN OTHR CMPL T2 12:30 - 14:00 1.50 CMPL TN OTHR CMPL T2 14:00 - 14:30 0.50 CMPL TN SFTY CMPL T2 14:30 - 21 :00 6.50 CMPL TN PULD CMPL T2 21:00 - 21:15 0.25 CMPL TN RUNT CMPL T2 21:15-21:45 0.50 CMPL TN OTHR CMPL T2 21 :45 - 00:00 2.25 CMPL TN RUNT CMPL T2 2/6/2005 00:00 - 01 :30 01:30 - 02:15 02: 15 - 04:00 04:00 - 05:15 05: 15 - 06:00 06:00 - 06:30 06:30 - 07:30 1.00 CMPL TN SEQT CMPL T2 07:30 - 10:30 3.00 CMPL TN OTHR CMPL T2 10:30 - 11 :15 0,75 CMPL TN SOHO CMPL T2 Printed: 2/18/2005 10:11:19 AM . . Legal Well Name: Common Well Name: Event Namè: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/6/2005 Group: 2/6/2005 10:30-11:15 0.75 CMPLTN SOHO CMPL T2 11:15 -11:30 0.25 CMPL TN SEQT CMPL T2 11 :30 - 13:00 1.50 WELCTL NUND CMPL T2 13:00 - 15:15 2.25 WELCTL NUND CMPL T2 15:15 - 17:45 2.50 CMPL TN FRZP CMPL T2 17:45 - 19:15 1,50 WELCTL OTHR CMPL T2 19:15 - 21:15 2.00 WELCTL NUND CMPL T2 21:15 - 00:00 2.75 CMPL TN OTHR CMPL T2 collars, PU wt 84K, dn wt 72K, blocks 35K of this wt. Test Vetco Gray upper and lower seals to 250 psi then 5000 psi f/10 min, N/D BOPE. NU Vetco Gray tree, test void 5000 psi f/10 min. Test tree 5000 psi 10 min. Pull TWC. Centrilift test ESP cable after tree nippled up. OK, RU to freeze protect. PJSM. Freeze protect wI little Red. Pump @ 2.1 bpm @ 825 psi. Use willis choke to hold back presssure w/pumping. Pump total 181.7 bbls diesel. Blow down lines. RU scaffolding. Vetco Gray set BPV. Install accuator valve, remove double annulus valve. Secure well. Cleaning pits, clean pollution pans, clean pan under drawworks. Change saver sub on top drive fl 4" XT-39 to 4 1/2" IF. Release Rig fl 1 E-121, Printed: 2/18/2005 10: 11: 19 AM . 1E-121 Well Events Summary . Date Summary 01/12/05 RUN GYRO TOOL ON THE RIG. 03/08/05 ATTEMPTED TO PERFORM A FCO. DUE TO PHASE TWO WEATHER CONDITIONS JOB POSTPONED. [FCO] 03/12/05 PERFORMED A MUD SWAP TO TOP OF MOTOR AT 4,242' CTMD. RETURNS 1-1 ALL DAY. FLUSHED SCREEN WITH DIESEL. WELL FREEZE PROTECTED TO 4,242' CTMD. [FCO] 03/13/05 TAGGED PUMP DRIVE SHAFT @ 4271' RKB WITH 2.25" LIB. GAUGED TBG TO 3.79" TO SAME. PULLED DV, SET 2000 PSI SOV @ 3594' RKB. IN PROGRESS. [Tag] 03/14/05 SET 44' 2" ESP PUMP @ 4271' RKB. RUN PACKOFF ASSY (OAL 103", 2.24" ID, 36" TO KOBE KNOCK OUT) TO 4227' RKB. TEST P/O & PUMP 1000 PSI, GOOD. SET 4- 1/2" SLIP STOP @ 4224' RKB. [ESP Work] . Halliburton Sperry-Sun Western North Slope ConocoPhillips 1E-121L 1 Job No. AKZZ3458622, Surveyed: 2 February, 2005 Survey Report 16 February, 2005 W) Your Ref: API 500292323860 Surface Coordinates: 5960559.83 N, 549889.88 E (700 18'10.8860" N, 149035' 45.1920" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy2115 Kelly Bushing Elevation: 98. 70ft above Mean Sea Level !5pE!ï'ï'Y-!5UI'1 DRIL.LING seRVices A Halliburton Company Halliburton Sperry-Sun Survey Report for 1 E-121 L 1 Your Ref: API 500292323860 Job No. AKZZ3458622, Surveyed: 2 February, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4807.48 74.880 43.880 3500.39 3599.09 1800.36 N 1925.96 E 5962372.94 N 551803.84 E 2462.44 Tie On Point - 4816.00 74.740 43.850 3502.62 3601.32 1806.29 N 1931.65E 5962378.91 N 551809.50 E 1.678 2470.26 Window Point 4913.34 78.750 43.850 3524.93 3623.63 1874.60 N 1997.28 E 5962447.66 N 551874.67 E 4.120 2560.43 5006.32 85.310 46.180 3537.82 3636.52 1939.65 N 2062.38 E 5962513.13 N 551939.33 E 7.479 2647.43 . 5098.53 89.620 48.490 3541.90 3640.60 2002.06 N 2130.10 E 5962575.99 N 552006.64 E 5.302 2733.21 5192.04 90.340 48.820 3541.93 3640.63 2063.83 N 2200.30 E 5962638.22 N 552076.43 E 0.847 2819.50 5285.57 88.600 48.490 3542.79 3641.49 2125.61 N 2270.51 E 5962700.47 N 552146.23 E 1.894 2905.81 5378.96 87.800 49.000 3545.73 3644.43 2187.16N 2340.68 E 5962762.48 N 552215.99 E 1.016 2991.89 5472.52 84.690 43.100 3551.86 3650.56 2251.91 N 2407.87 E 5962827.68 N 552282.74 E 7.116 3079.54 5565.90 83.410 42.750 3561.54 3660.24 2319.92 N 2471.12 E 5962896.11 N 552345.54 E 1.421 3168.39 5657.96 83.730 40.810 3571.85 3670.55 2388.13 N 2532.07 E 5962964.72 N 552406.03 E 2.123 3256.42 5751.38 84.100 39.030 3581.75 3680.45 2459.37 N 2591.67 E 5963036.36 N 552465.17 E 1.936 3346.59 5845.42 86.710 36.760 3589.29 3687.99 2533.34 N 2649.24 E 5963110.70 N 552522.24 E 3.673 3438.30 5938.70 88.120 30.210 3593.50 3692.20 2611.01 N 2700.62 E 5963188.72 N 552573.10 E 7.176 3530.64 6031.89 88.610 26.860 3596.16 3694.86 2692.84 N 2745.11 E 5963270.84 N 552617.05 E 3.632 3623.68 6126.27 89.420 24.460 3597.78 3696.48 2777.89 N 2785.97 E 5963356.16 N 552657.34 E 2.683 3718.04 6219.38 90.970 20.960 3597.46 3696.16 2863.77 N 2821.91 E 5963442.27 N 552692.71 E 4.111 3810.98 6312.86 90.650 18.380 3596.14 3694.84 2951.77 N 2853.37 E 5963530.49 N 552723.58 E 2.781 3903.87 6406.45 90.030 14.260 3595.59 3694.29 3041.57 N 2879.66 E 5963620.46 N 552749.28 E 4.452 3996.11 6499.96 89.290 9.870 3596.14 3694.84 3132.99 N 2899.20 E 5963712.00 N 552768.21 E 4.761 4086.84 6582.82 89.870 8.480 3596.75 3695.45 3214.79 N 2912.41 E 5963793.89 N 552780.88 E 1.818 4166.15 . 6677.56 87.490 11.570 3598.93 3697.63 3308.04 N 2928.90 E 5963887.24 N 552796.74 E 4.116 4257.19 6770.59 88.200 11.160 3602.43 3701.13 3399.18 N 2947.22 E 5963978.50 N 552814.46 E 0.881 4347.14 6863.87 88.510 10.980 3605.11 3703.81 3490.69 N 2965.12 E 5964070.13 N 552831.75 E 0.384 4437.23 6957.97 87.450 11.000 3608.43 3707.13 3583.00 N 2983.05 E 5964162.56 N 552849.07 E 1.127 4528.06 7051.30 88.950 12.020 3611.36 3710.06 3674.40 N 3001.66 E 5964254.09 N 552867.07 E 1.943 4618.37 7145.31 89.400 11.300 3612.71 3711.41 3766.46 N 3020.66 E 5964346.27 N 552885.46 E 0.903 4709.44 7238.77 88.860 11.120 3614.13 3712.83 3858.13 N 3038.82 E 5964438.05 N 552903.02 E 0.609 4799.80 7331.86 89.380 12.920 3615.56 3714.26 3949.16 N 3058.21 E 5964529.22 N 552921.80 E 2.012 4890.12 7421.01 88.940 12.830 3616.87 3715.57 4036.06 N 3078.07 E 5964616.24 N 552941.08 E 0.504 4976.93 7518.73 88.720 12.580 3618.86 3717.56 4131.37 N 3099.56 E 5964711.69 N 552961.93 E 0.341 5072.01 7611.61 88.990 14.910 3620.72 3719.42 4221.57 N 3121.62 E 5964802.03 N 552983.40 E 2.525 5162.75 7704.89 90.610 14.250 3621.04 3719.74 4311.84 N 3145.10 E 5964892.46 N 553006.28 E 1.875 5254.18 7798.06 89.580 14.720 3620.89 3719.59 4402.05 N 3168.40 E 5964982.82 N 553028.98 E 1.215 5345.47 7894.64 90.050 14.160 3621.20 3719.90 4495.57 N 3192.49 E 5965076.50 N 553052.44 E 0.757 5440.09 16 February, 2005 - 14:46 Page 20f5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1 E-121 L 1 Your Ref: API 500292323860 Job No. AKZZ3458622, Surveyed: 2 February, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 7991.02 91.530 12.960 3619.87 3718.57 4589.25 N 3215.08 E 5965170.33 N 553074.42 E 1.977 5534.19 8087.47 91.660 12.830 3617.19 3715.89 4683.23 N 3236.60 E 5965264.45 N 553095.31 E 0.191 5628.09 8184.73 91.420 12.080 3614.57 3713.27 4778.17 N 3257.57 E 5965359.53 N 553115.65 E 0.809 5722.61 8281.46 90.240 15.060 3613.17 3711.87 4872.18 N 3280.26 E 5965453.68 N 553137.71 E 3.313 5817.06 . 8377.59 91.220 15.030 3611.95 3710.65 4965.00 N 3305.21 E 5965546.67 N 553162.05 E 1.020 5911.42 8474.36 89.040 12.750 3611.73 3710.43 5058.93 N 3328.44 E 5965640.75 N 553184.65 E 3.260 6006.03 8570.99 91.050 14.970 3611.65 3710.35 5152.74 N 3351.58 E 5965734.71 N 553207.17 E 3.099 6100.49 8667.59 89.890 12.120 3610.86 3709.56 5246.64 N 3374.20 E 5965828.76 N 553229.17 E 3.185 6194.80 8764.56 90.300 13.540 3610.70 3709.40 5341.18 N 3395.73 E 5965923.44 N 553250.07 E 1.524 6289.22 8860.86 91.740 12.900 3608.98 3707.68 5434.91 N 3417.75 E 5966017.32 N 553271.47 E 1.636 6383.11 8956.73 89.380 11.090 3608.05 3706.75 5528.68 N 3437.67 E 5966111.21 N 553290.77 E 3.102 6476.12 9054.53 87.270 13.110 3610.91 3709.61 5624.25 N 3458.16 E 5966206.92 N 553310.62 E 2.986 6571.00 9117.37 88.710 13.210 3613.11 3711.81 5685.40 N 3472.46 E 5966268.17 N 553324.51 E 2.297 6632.23 9209.21 89.610 14.460 3614.46 3713.16 5774.57 N 3494.42 E 5966357.47 N 553345.88 E 1.677 6722.00 9299.40 89.200 13.450 3615.39 3714.09 5862.09 N 3516.17E 5966445.14 N 553367.04 E 1.209 6810.20 9391.90 88.820 13.250 3616.99 3715.69 5952.07 N 3537.52 E 5966535.26 N 553387.80 E 0.464 6900.44 9483.13 90.290 15.410 3617.70 3716.40 6040.46 N 3560.10 E 5966623.79 N 553409.79 E 2.864 6989.77 9573.77 90.200 12.480 3617.31 3716.01 6128.41 N 3581.94 E 5966711.89 N 553431.05 E 3.234 7078.40 9664.15 90.380 15.250 3616.86 3715.56 6216.15 N 3603.60 E 5966799.77 N 553452.12 E 3.071 7166.75 9754.22 91.960 14.420 3615.02 3713.72 6303.20 N 3626.65 E 5966886.97 N 553474.60 E 1.981 7255.10 9843.94 90.430 14.570 3613.14 3711.84 6390.04 N 3649.10 E 5966973.96 N 553496.47 E 1.713 7342.99 . 9937.10 91.290 15.080 3611.75 3710.45 6480.09 N 3672.94 E 5967064.16 N 553519.71 E 1.073 7434.37 10028.17 92.530 14.040 3608.71 3707.41 6568.18 N 3695.82 E 5967152.41 N 553542.00 E 1.777 7523.58 10118.79 91.040 14.160 3605.89 3704.59 6656.02 N 3717.88 E 5967240.40 N 553563.48 E 1.650 7612.21 10209.27 92.850 12.400 3602.82 3701.52 6744.03 N 3738.65 E 5967328.53 N 553583.67 E 2.789 7700.41 10306.35 92.280 12.010 3598.47 3697.17 6838.82 N 3759.16 E 5967423.46 N 553603.54 E 0.711 7794.59 10402.30 92.280 13.000 3594.66 3693.36 6932.42 N 3779.92 E 5967517.19 N 553623.68 E 1.031 7887.82 10500.48 93.480 14.070 3589.72 3688.42 7027.75 N 3802.86 E 5967612.67 N 553645.99 E 1.637 7983.56 10596.11 91.660 11.930 3585.43 3684.13 7120.82 N 3824.35 E 5967705.89 N 553666.86 E 2.936 8076.64 10693.28 91.230 10.530 3582.98 3681.68 7216.10N 3843.27 E 5967801.29 N 553685.15 E 1.507 8170.56 10790.14 91.170 13.450 3580.95 3679.65 7310.81 N 3863.38 E 5967896.14 N 553704.63 E 3.015 8264.51 10886.22 90.530 15.270 3579.53 3678.23 7403.88 N 3887.21 E 5967989.36 N 553727.84 E 2.008 8358.60 10982.81 92.660 16.620 3576.84 3675.54 7496.71 N 3913.73 E 5968082.36 N 553753.74 E 2.610 8453.66 11079.55 90.050 14.790 3574.55 3673.25 7589.80 N 3939.90 E 5968175.62 N 553779.30 E 3.295 8548.81 11176.33 91.940 17.390 3572.87 3671.57 7682.76 N 3966.72 E 5968268.76 N 553805.49 E 3.321 8644.12 16 February, 2005 - 14:46 Page 3 of5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-121L1 Your Ref: API 500292323860 Job No. AKZZ3458622, Surveyed: 2 February, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11272.81 90.730 17.630 3570.62 3669.32 7774.74 N 3995.74 E 5968360.94 N 553833.90 E 1.279 8739.51 11369.63 92.060 16.840 3568.27 3666.97 7867.19 N 4024.42 E 5968453.57 N 553861.97 E 1.598 8835.17 11465.59 90.920 17.830 3565.77 3664.47 7958.75 N 4053.00 E 5968545.32 N 553889.94 E 1.573 8930.00 11562.21 89.950 16.080 3565.04 3663.74 8051.17 N 4081.17 E 5968637.92 N 553917.50 E 2.071 9025.41 . 11657.25 89.150 15.520 3565.79 3664.49 8142.61 N 4107.05 E 5968729.54 N 553942.77 E 1.027 9118.94 11754.89 87.440 14.680 3568.69 3667.39 8236.84 N 4132.47 E 5968823.92 N 553967.57 E 1.951 9214.77 11852.41 89.460 14.780 3571.33 3670.03 8331.11 N 4157.26 E 5968918.36 N 553991.72 E 2.074 9310.37 11949.53 87.130 14.780 3574.22 3672.92 8424.97 N 4182.02 E 5969012.38 N 554015.86 E 2.399 9405.59 12041.52 87.110 14.740 3578.84 3677.54 8513.81 N 4205.43 E 5969101.38 N 554038.68 E 0.049 9495.70 12143.27 93.600 19.840 3578.21 3676.91 8610.88 N 4235.64 E 5969198.64 N 554068.25 E 8.110 9596.19 12239.73 91.540 19.330 3573.88 3672.58 8701.66 N 4267.94 E 5969289.64 N 554099.94 E 2.200 9691.94 12336.18 90.750 16.170 3571.96 3670.66 8793.49 N 4297.33 E 5969381.66 N 554128.73 E 3.376 9787.36 12371.89 89.810 18.620 3571.78 3670.48 8827.56 N 4308.01 E 5969415.80 N 554139.18 E 7.348 9822.67 ". 12414.00 89.810 18.620 3571.92 3670.62 ~ 8867.47 N 4321.45 E ' 5969455.80 N 554152.35 E 0.000 9864.43 Projected survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 26.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12414.000., The Bottom Hole Displacement is 9864.43ft., in the Direction of 25.982° (True). . 16 February, 2005 - 14:46 Page 4 of 5 DrillQuest 3.03.06.008 Western North Slope Comments Measured Depth (ft) 4807.48 4816.00 12414.00 Halliburton Sperry-Sun Survey Report for 1 E-121 L 1 Your Ref: API 500292323860 Job No. AKZZ3458622, Surveyed: 2 February, 2005 ConocoPhil/ips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3599.09 3601.32 3670.62 . 1800.36 N 1806.29 N 8867.47 N 1925.96 E 1931.65E 4321.45 E Tie On Point Window Point Projected survey Survey tool program for 1 F-121/ 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 352.00 16 February, 2005 - 14:46 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 351.99 12414.00 351.99 CB-GYRO-SS (1E-121) 3670.62 MWD+IIFR+MS+SAG (1 E-121) . Page 50f5 DrillQuest 3.03.06.008 . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs IE-121 LI, I LDWG formatted Disc with verification listing. API#: 50-029-23238-60 . cX{)(~ ;2f7 ~ J :>t)2~ March I, 2005 AK-MW-3458622 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMIIT AL LEITER TO THE A'ITENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ,¥ø /0 J cYAL . ~~!Æ~E lliF !Æ~l~~«] . ~I,~"HA OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 103360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-121Ll ConocoPhillips Alaska, Inc. Pennit No: 204-247 Surface Location: 4307' FNL, 630 FEL, SEC. 16, TIIN, RlOE, UM Bottomhole Location: 710' FNL, 1591 FEL, SEC. 10, TUN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. The pennit is for a new well bore segment of existing well KRU lE-121, Pennit No. 204-246, API No. 50-029-23238-00. Production should continue to be reported as a function of the original API number stated above. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-36 a: er). DATED this 16day of December, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. conoc#hillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com RECEIVEC¥ DEC 14 2004 December 9,2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Comm¡:¡slO¡, Anchorage Re: Application for Permit to Drill, West Sak Producer, 1E-121 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well bore, the ' upper lateral wellbore of a multilateral horizontal well in the West Sak "D" sand. The main bore of this well will be designated 1E-121 and has been permitted under a separate application, submitted on December 8, 2004. This application is for the upper lateral of that well, to be designated 1E-121Ll. The expected date that operations will begin on 1E-121L1 is January 10, 2005. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E- 121Ll. Sincerely, C~ndY~ \ ~ GKA Drilling Team Leader 20 AAC 25.005 Alaska Oil & Gas Cons. L",.¡mission ExploratoryU Development Oil ~ Anch0Mtle Zone 0 SeNice 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-121L1 6. Proposed Depth: .; 12. Field/Pool(s): MD: 12419' TVD: 3647' Kuparuk River Field 2550' FNL, 4016' FEL, Sec. 15, T11N, R10E, UM " Total Depth: 710' FNL, 1591' FEL, Sec. 10, T11N, R1OE, UM / 4b. Location of Well (State Base Plane Coordinates): ~qbDs"fá)' ¿}?$:' Þ'l 10. KB Elevation Surface: x- 549890"' y- ~ Zone- 4 (Height above GL): 28 feet 16. Deviated wells: , 17. Anticipated Pressure (see 20 AAC 25,035) Kickoff depth: 4776' ft. Maximum Hole Angle: 90.8° Max. Downhole Pressure: 1634 psig I Max. Surface Pressure: 1235 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 94# K-55 Welded 120' 28' 28' 120' 120' 260 cf ArcticCrete 10.75" 45.5# L-80 BTC 2622' 28' 28' 2650' 2395' 470 sx ASLite, 180 sx DeepCrete 7-5/8" 29.7# L-80 MBT 5057' 28' 28' 5085' 3661' 300 sx DeepCrete 4.5" 12.6# L-80 MBT 7719' 4700' 3567' 12419' 3647' slotted liner (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD . e) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1 a. Type of Work: Drill 0 Re-entry 0 RedrillU /1 b. Current Well Class: Stratigraphic Test 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Loca¡ion of Well (Governmental Section): 'f3ð7 lD3D Surface:~ FNL,~EL, Sec. 16, T11 N, R10E, UM Top of Productive Horizon: )Þ ¡?.1>.04 7. Property Designation: ALK 25651 & 25648 8. Land Use Permit: ADL 469 & 466 9. Acres in Property: 2560 Hole 40' 13.5" 9-7/8" 6.75" 19 Total Depth MD (It): PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structu ral Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size b~ BOP SketchU Diverter Sketch 0 ¡rerfOration Depth TVD (ft): Drilling Program0 Time v. Depth Plot U Seabed Report 0 Drilling Fluid Program 0 Date: 20. Attachments: Filing Fee Property Plat L o 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. REcelvr -Æ~ <) DEC 1 42004 West Sak Pool 13. Approximate Spud Date: 1/10/2005 14. Distance to Nearest Property: 4643' 15. Distance to Nearest Well within Pool: 1E-123, 41' @ 100' Shallow Hazard Analysis 0 20 MC 25,050 requirements 0 Printed Name Randy Thomas Signature ~ ~ 'v ..:> _ Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone ZGJ-'-B,o Date (Z./-, (f) 7 PreDared bv Sharon Al/suD-Drake Commission Use Only I API Number: / Permit Approval 50-Òz,9- 2.3238-&6 Date: /;J.,k"~r Samples required 0 Yes gNo Mud log required 0 Yes ~ No Hydrogen sulfide measures 0 Yes 3NO Directional survey required .N Yes 0 No ~ ,~V~~~. ~C)?E' S\<...~~~\~tMt."\.~f ~'C)~~~\-\~~~~ '==- \L-~~ Permit to Drill Number: 2()L/~ Z '-/7 Conditions of approval : "35òO \,"'7\ 'M..'''' Other: COMMISSIONER BY ORDER OF THE COMMISSION ORIGINAL Form 1 0-401 Revised 3/2003 . I See cover letter for other requirements Date: r{frlJ Submit in duplicate I' APP. for Permit to Drill, Well 1 E-121 L 1 Revision No.O December 9,2004 Permit It - West Sal( Well #1 E-121 L 1 ("D" Sand) Application for Permit to Drill Document Table of Contents 1. Well Name........... .................. ............. ...... .......... .............. ........ .............. .............. ...... 2 Requirements of 20 AAC 2S.00S (f) ......... .................................. ............ ....... ......... ................ .... ............ 2 2. Location Summary.............. .............. ...... ......... .......... .... ......... .............. .............. ...... 2 Requirements of 20 AAC 2S. 00S(c)(2). ................... .............................. ..... ..... ......... ....... ...... ................. 2 Requirements of 20 AAC 2S.0S0(b) ......... ..................................................... ........................ ................. 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 2S. 00S(c)(3) .............. ......... ....... ......... ....... .................................... ............. .... 3 4. Drilling Hazards I nforrnation ............ ................ ............. ......... ............ ............. ........ 3 Requirements of 20 AAC 2S.00S (c)( 4) ................................................ .................. ....... ................. ........ 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 2S,00S (c)(S) ............................................................ ............. ................. ........ 3 6. Casing and Cementin~1 Program ............................................................................4 Requirements of 20 AAC 2S. 00S(c)(6)............... ........................................................ ....... ..................... 4 7. Diverter System Inforrnation ................................................................................... 4 Requirements of 20 AAC 2S. 00S(c)(7)....... ....... ........... ....... ................................................. ....... ........... 4 8. Drilling Fluid Program .......... ............... ................ ............. ........... .......... ...... ............ 5 Requirements of 20 AAC 2S. OOS(c)(B)................................................................ ....... ............................ S Lateral Mud Program (MI FloPro NT).............................................................. ...... ...... .................... ....... S 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 2S.00S (c)(9) ... .................................... ..... ....... ..... ......... ..... ....................... ..... S 10. Seismic Analysis .......". ............. ........... ................ ............. ........... ........... ................. 5 Requirements of 20 AAC 2S.00S (c)(10) ........ ....... ........... ....... .............. ..... .............. .............................. S 11. Seabed Condition Anallysis...... ........... ............... .............. ........... .......... .................. 5 Requirements of 20 AAC 2S.00S (c)(11). .................. .............. ..................... ......... ............ ..................... S 12. Evidence of Bonding..... ............. ............ .............. .............. ........... .......... ................. 5 Requirements of 20 AAC 2S.00S (c)(12) ........................................... ....... ...................... .............. .......... S ORIGINAL L1 PERMIT IT RevO.doc Page 1 of 6 Printed: December 9,2004 -. . AP.n for Permit to Drill, We1l1E-121 L1 Revision No.O December 9,2004 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13)......... .............................................. ........ ..... ....... ...... ..... ..... ..... 6 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 (8 pages)...................... ............................................... ......... ........ .......... 6 Attachment 2 Drilling Hazards Summary (1 page)....... ................................... ....... ....... .............. ........... 6 Attachment 3 Well Schematic (1 pages) ............ ................................... .................. ......... ............ ......... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25. 040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. I The well for which this Application is submitted will be designated as 1E-121 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file 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 well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,760 Eastings: 549,890 FNL: 5107', FEL: 637', Section 16, TllN/R10E, UM I RKB Elevation I 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,962,329 Eastings: 551,768 FNL: 2550', FEL: 4016', Section 15, T11N/R10E UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 4776' 3587' 3488' Location at Total Depth of the "D" West Sak Sand ASP Zone 4 NAD 27 Coordinates Northings: 5,969,465 Eastings: 554,130 FNL: 710', FEL: 1591', Sec 10, TllN/R10E, UM "" Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12[419' 3647' 3548' ." and (D) other information required by 20 MC 25.050(b); ORIGINAL L 1 PERMIT IT RevO.doc Page 2 of 6 Printed: December 9,2004 · APen for Permit to Drill, Well1E-121 L 1 Revision No.O December 9,2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of tl¡e proposed well bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and descnption of the blowout prevention eqUIpment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete weIl1E-121 Ll. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encounterect 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 1E-121L1 area average 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. / 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 "D" sand formation is 1235 psi, calculated thusly: MPSP =3632 ft)(0.45 - 0.11 psi/ft) .' =1235 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. .. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dn'll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure {or conducting formation intt.'grity tests, as required under 20 AAC 25. 030(f); The parent wellbore,1E-121, 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 ORIGINAL L 1 PERMIT IT RevO.doc Page 3 of 6 Printed: December 9,2004 ---.. . APen for Permit to Drill, We1l1E-121 L1 Revision No,O December 9,2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3, APD for lE-121: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 40" 94# K55 Welded 120 28 / 28 120 / 120 Cemented to surface with 260d ArcticCRETE 10 3f4" 13 V2" 45.5# L-80 Buttress 2622' 28 / 28 2650 / 2395 Cemented to Surface with 470 sx ASLite Lead, 180 sx DeepCRETE Tail 75/8" 9 7/8" 27.9# L-80 MBT 5057' 28 / 28 5085/3661 Cement Top planned @ 2,700' MD / 2435' 1VD. Cemented w/ 300 sx DeepCRETE 4'/2" 6 3/4" 12.6# L-80 MBT 7476' 4650 / 3633 12426 / Slotted- no slotted "B" Lateral 3709 cement (4~" IF-1 J1 Slotty 63/4" 12.6# L-80 MBT 7719' 4900/3619 12419/ slotted "D" Lateral 3647 cement lE-121 L1 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. 035, unless this requirement is waived by the commission under 20 AAC 25.035(h}(2); No diverter system will be utilized during operations on lE-121 L1 ORIGINAL L 1 PERMIT IT RevO.doc Page 4 of6 Printed: December 9,2004 "- . AP.n for Permit to Drill, Well1E-121 L 1 Revision No.O December 9,2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25. 033; Drilling will be done with oil base mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Value Density (ppg) 9.0 " Yield Point 18-28 (cP) Electric Stability 650-900 Plastic 15-25 Viscoxity) pH NA API filtrate <4 (cc /30 min) **HTHP filtrate <10 (cc /30 min) Oil/lll/ater Ratio 70:30 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 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dn/I must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphie test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesse¿ an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; ORIGINAL L1 PERMIT IT RevO.doc Page 5 of 6 Printed: December 9,2004 · AP.n for Permit to Drill, Well1E-121 L 1 Revision No.O December 9,2004 Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-121 L1 is listed below. Note: Previous operations are covered under the lE-121 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4776' MD 3587' TVD, the top of the "D" sand. 2. Mill 6 3/4" window. POOH. ./ 3. Pick up 6 3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of"D" sand lateral at 12,419' MD /3647' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 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. 10. POOH and LD drill pipe 11. RU and run ESP completion on 4 V2" tubing 12. Secure well RDMO Doyon 141 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by hauling to the Prudhoe Bay Grind and Inject Facility or to lR pad in accordance with the State of Alaska Regulations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL L 1 PERMIT IT RevO.doc Page 6 of 6 Printed: December 9,2004 KOP: 300' Build at 3-5 degreesl 100' o ::0 - G) - z » r- Producer 1E-121 Slim hole Design 131/2" Hole (8.8 ppg Spud Mud) 10 3/4" Casing Hydraulics: Surface: 700-900 gpm Intermediate: 600-700 gpm Laterals: 250-300 gpm Figure on a 50 YP for surface Figure on a 35 YP for intermediate Figure on a 28 YP for laterals ..' Top of Ugnu ./ 3243MD 2921~.' ~ Top of Cement 2700" MD +~~ r:~+- liD" Sand (9.0 ppg Oil Base Mud) Window @ 4776'MD 63/4" Hole 3587'TVD 41/2" Line 12419' MD L 3647' TVD e 97/8" Hole (9.0 ppg LSND) 7 5/8" Casing 5085' MD 3661' TVD 12,426' MD 3709' 'TVD · .\ lE-121Ll Drillina Hazards Summary 6 3/4 .. Open Hole I 4 112'" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low .J' Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Lost Circulation Hole Swabbing on Trips Moderate Low 1E-121 Drilling Hazards Summary prepared by Steve Shultz 9/1/2004 4:26 PM ORtGINAL _I I ' ' . ""'h"¡t ;: I :¡¡ , MOO· Ht::: . . '"00 : :.: r:l: 6750 : .. . I - : - - - o 5250 o - to ...... ~ - +' 4500 :c t o ~ "J£' 3750 '5 o Cf) - - - - , = . :::llli~~ - '"0 t'll °4J1f{ -750 - .' - , " ì , . , Kuparuk Calculation Method: Minimum Curvature Error S~tem: ¡SCWSA Scan Method: Elliptical Conic Error Surface: Rufes Based Warning Mèthod: Trav. Cylinder North I . -3000 -1500 , , , , ¡ , , , , I ' , , , I , , -750 I '. ! - I . . . , 1E-121 VVS 8 Lat Pt .. I . ~- 1E-121 VVS BLat Pt ! '! 1E-121 VVS BLat Hee . . I ,",II";li"I'I; I 'I' 750 1500 2250 3000 3750 West(-)/East(+) (1500ftlin) , ¡ : ' E-121 VVS BLat pt 5 1E-121 WS 8 Lat Pt . I ¡ : . . ¡ ¡ ¡ ,¡I" I,;" , 5250 6000 6750 A !iJ\!:.t,lHURfth"\ t);:t\1PA¡'.;Y Engineering Err9r System: Calculation Method: Scan Method: Error Surfaca: Warning Method: KuparuK Minimum Curvature ISCWSA Trav. Cylinder North Elliptical Conic RUles Based . . Halliburton Company Anticollision Report Survey Program for Definitive Wellpath Date: 11/19/2004 Validated: No Planned From To Survey ft ft 4776.400 12419.030 Planned: Plan 1E-121 L 1 (wp06) V6 Company: ConocoPhillips Alaska Inc. FIeld: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Reference Well: Plan 1E-121 Reference WeDpath: Plan: 1E-121 L 1 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.000 ft Depth Range: 28,000 to 12419.030 ft Maximum Radius: 1439.103 ft Casing Points MD ft 4776.400 12419.030 1VD ft 3531.906 3591.907 Summary <- Site Kuparuk 18 Pad Kuparuk 18 Pad Kuparuk 18 Pad Kuparuk 18 Pad Kuparuk 18 Pad Kuparuk 18 Pad Kuparuk 1 E Pad Kuparuk 1 E Pad Kuparuk 1E Pad Kuparuk 1 E Pad Kuparuk 1 E Pad Kuparuk 1 E Pad Kuparuk 1 E Pad Kuparuk 1 E Pad Site: Well: Wellpath: Diameter in 7.625 4.500 Offset Wellpath Well 18-07 1 8-08 1 B-08A 1 B-101 18-101 1B-102 1 E-07 1E-123 1E-123 1E-123 1E-18 Plan 1E-121 Plan: 1E-102 Plan: 1E-102 Kuparuk 1 B Pad 1B-07 18-07 V1 Hole Size in 9.875 6.750 Name 75/8" 4 1/2" Date: 12/3/2004 Time: 12:38:15 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan 1E-121, True North 1E-121 98.7 Page: Reference: Er!or Model: Scan Method: Error Suñace: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 3 Toolcode Tool Name .". Wellpath 1 B-07 V1 1B-08 V1 1 B-08A V1 1B-101 V1 1B-101L 1 V1 1B-102 V1 1E-07 V1 1E-123 V2 1E-123L 1 V2 1E-123PB1 V1 1E-18 V1 Plan: 1E-121 V3 Plan: 1E-102 B Lateral V8 PI 1E-102 0 lateral V3 PI MWD MWD - Standard Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk FAIL: Minor 1/10 Pass: Major Risk Pass: Major Risk Reference Offset Seml-MajorA.xi$ . Ctr-Ctr . No-Go Allowable MD 1VD MD TVD Ref Offset TF'O+AZI . TFO-HS CasingIHæïstance· Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10503.518 3621.549 5100.000 3956,252 105.215 16.555 270.883 255.964 1399.614356,980 1042.634 Pass 10476.764 3621.963 5200.000 4020.196104.831 16.854 267.512 252,593 1347.082 353,213 993.868 Pass 10448.035 3622.407 5300.000 4083.820 104.417 17.269263.903 248,984 1299.887 348.423 951.464 Pass 10416.076 3622.902 5400.000 4147.091 103.958 17.709260.075 245.156 1258.965342.217 916.748 Pass 10384.014 3623.398 5500.000 4210.024 103.497 18.145256.017 241.098 1223.637 334.448 889.190 Pass 10352.221 3623.890 5600.000 4273.800 103.040 18,446251,724 236.805 1195.785 324.604 871.181 Pass 10319.646 3624.394 5700.000 4338.911 102.572 18,696247,247 232.328 1176.996312.877 864.120 Pass 10286.045 3624.914 5800.000 4404.517102.118 19.039242,669 227.750 1166,622 299.890 866.731 Pass 10251.198 3625.453 5900.000 4469.959101.691 19.487 238,061 223.142 1163,976285.965 878.010 Pass 10217.652 3625.972 6000,000 4535.738101.279 19.883233.439 218,520 1168.954 270,845 898.108 Pass 10189.526 3626.408 6100.000 4602.349 100,706 20.417228.367 213.991 1182.882 255.116 927.766 Pass 10160.713 3626.854 6200.000 4670.388 99,988 21,053 223.211 209,699 1206.901 239.566 967.335 Pass 10122.415 3627,448 6300.000 4739.697 99,403 21.437 219.077 205.668 1239.391 224.600 1014,791 Pass 10083.962 3628.044 6400.000 4809,791 98,852 21.799215,272 201.863 1278.546 210.564 1067.983 Pass 10046.119 3628.630 6500.000 4880,038 98,310 22,231 211,697 198.288 1323.085 197.877 1125.208 Pass 10006,827 3629.239 6600.000 4949.504 97.747 22.771 208,375 194,966 1371,655 186,911 1184.744 Pass 9965,600 3629.878 6700.000 5017.221 97.157 23.342 205.278 191,869 1422,626 177.548 1245.078 Pass Reference MD ft 10319.646 11474.955 11475.918 12154.839 12154.839 12413.959 1744.823 99.431 99.431 99.431 2996.330 99.991 2305.407 2305.407 Offset Ctr-Ctr No-Go MD Distance Area ft ft ft 5700.000 1176.996312,877 5400.000 1269.981 332.031 5400.000 1270.230331.939 6000.000 383,541 361.272 6000.000 383,541 361.272 4900.000 949.217 247.468 1800.000 103.620 63.280 100.000 40.708 4.798 100.000 40.708 4.798 100.000 40.708 4.798 3300.000 472.428 66.680 100.000 0,714 1.771 2400.000 384.367 66.353 2400.000 384.367 66.202 Allowable Deviation ft 864.120 937.951 938.291 22.269 22.269 701.749 40.340 35.911 35.911 35.911 405,748 -1.056 318.013 318.165 Rule Assigned: Inter-Site Error: Major Risk 0.000 ft OR1G1NAL . Conoc~hillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-121 Plan: 1E-121 L1 Plan: 1E-121 L1 (wp06) Standard Planning Report 03 December, 2004 . 5per'r'V-5un DRILL.ING SERVICES A HALLIBURTON COMPANY OR\G\NAL 'y-sun SEs:RVIt;f.:$ 10200 1200 :;f C ('I) 3000 < ('I) :::¡. ¡)' ~ o ('I) 3600 "- ::r t5 o <!' 4200 2: 1800 2400 " I Itmm of Window : [4778' MD, 3581' TVD)i 11m I / / - im.. ./ @ 3°/1000 (5244' MD, 3627' TVD) I··· + V i/ v~ / - I· 1/ __ / i -- ~ 'c- '-: '/ / ,/ ___~ ;.- ____ .... J '''Uti , := '" - f-- / - J.--:-:-' ~ :, "Ii,<,,: --+ :::1=' {. ;;;; ,=.= i;;;; ",'ii... 1 i'i"-l ii ;< ! :~ '-. ,,"" "'-!."" i , I I lþ.liPE 'II!]'-. I i I \! >-l i ,iN i ,r I II ~. \ '+1 9600 9000 I Vertical Section at 26,000 (1200 Win) 1200 1800 2400 ê :§ g 3000 ~ J::: '5. '" CJ 3600 m '" 1:: '" > '" ß. 4200 4800 5400 - ....... 9000 9600 I MD& 4800 5400 " 4800 5400 10200 8400 LEGEND 1E.121 (wp06) Vi0 7800 7200 6000 11-1.05 (U!I+.I ooc:~) (+)¡SB3/(-)¡S6M 00917 OOGv 009£ 000£ 0017<; omn OOll 009 009- I I I I I I I I ! I I I I I I I I I' I I I I' I I I I' I I I I' I I I I I " I I I I I I I I I OOGl _,., ~_" I OOG> I I I I I (a/U ,LB9t; 'aV\l ,9LLV) : MOPU!M ,0 WJ1sl omi> ¡¡I i---------- 7~ 009> I (OM ,t69£' OW,908V) UOO>109@ PI!ng U!58gl 00" I,"MI,œ"o.,Looo"J.;;;;::i.~~// \ " 00" 000£ /-" I \', 000£ _ 1 (OM ,17<:9£ 'íI OW ,9L09) pues-o J8ddn UI puel 0) ¡ueBuel U!B8g1 ¡ 009£ \ ~ 1 009£ @doJO 00<:17 00<:17 ê ø :§ 00917 1 (OM ,68<:9£ ' OW pues-o U! BUU88¡S-08Ð U!B8g -00917 ~ g - ~ N ~ ~ Z ~ 0 £~ ~ª ~ ~ t + o ~ Z ~ ~ N ~~ ~8 ~ ~ o - ø ~ 0099 0099 OO<:L i OOll 009L i 009l I 00179 00179 I 0006 I I 0006 ~ I ~ ¡ t ¡ 1 \ I I I ! I I ¡ I I I ¡ I) j I I I I i II 1 I I I ¡ ¡ ¡ I I ¡ I I I I I I! I \ I ¡ I I 00179 00917 OOlt 009£ 000£ OOtl 009> OOll 009 0 009- (U!I+.I Ooc:~) (+)¡SB3/(-)¡S6M \w,It<;",I~,""',1\I1Tm'" ~-;;t;:)I^fd=U; tJiH4"t~Q uns-1\~d!!!lii 000'0 000'0 M~/3+ $~IN+ MZß;Þ~i~~:~" N9::~~ftf~~ o~~~~:::11Ç Otirg~~~g~ OOL 'Ol :¡eA91 punOJÐ ~OIS 1 NOU,\fIAI¡;OdNl3:¡N;ru3d3M :P0l:taW uo!~eln:)le::) :(S>l:M) roUaJ9JðM 4tdeQ pa.mseaw :a:)Uð.I&Jð1:f (sA) uonoeg :a:)uaJ8j.9~ {aAJ.} ¡E':)WßA :~u9JaJa~ (3IN) a¡eu!pJo-o:) {gOdM) ,Z~-3¡ U"1d '811"J.30 113M . . ConocdJ'hillips Alaska Halliburton Company Planning Report spe,.,,.,v-sun DRILLING seRVices A HALLIBURTON COMPANY Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact sol ution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: Northing: 5,959,760,240ft Latitude: 700 18' 03.021" N From: Map Eastlng: 549,889,510ft Longitude: 1490 35' 45,358" W Position Uncertainty: 0,000 ft Slot Radius: 0" Grid Convergence: 0,380 0 Well Position +N/-S 0,000 ft Northing: 5,960,559,830 ft Latitude: 70018' 10,886" N +E/-W 0,000 ft Eastlng: 549,889,880 ft ,- Longitude: 1490 35' 45,192" W Position Uncertainty 0,000 ft Wellhead Elevation: ft Ground Level: 70,700ft bggm2004 11/9/2004 24,537 80.743 57,577 Audit Notes: Version: 3 Phase: PLAN Tie On Depth: 4,776.404 28.000 0,000 0,000 26,000 121312004 2:23:53PM Page 2 of 7 COMPASS 2003,11 Build 48 ORIGtNAL . . y ConocoPhillips Alaska Halliburton Company Planning Report ~ra-""""'Y-sun DRILLING ~~A\ICeS A HALLIBURTON COMPA:.~ .' 4,776,404 75,000 45,380 3,586,700 ' 1,756,830 1,890,010 0,00 0,00 0,00 0,000 4,788.404 76,908 45,380 3,589,612 1,765,006 1,898,296 15,90 15,90 0,00 0,000 4,806.404 76,908 45,380 3,593,689 1,777,321 1,910,775 0,00 0,00 0,00 0,000 5,008,344 87,005 45,380 3,621,909 1.917,587 2,052,914 5.00 5,00 0,00 360.000 5,075.021 89.005 45,381 3,624,230 1,964,390 2,100.343 3.00 3,00 0,00 0,041 5,243,929 89,005 45,381 3,627,162 2,083,010 2,220.553 0.00 0,00 0,00 0.000 5,310,606 87.005 45.380 3,629.483 2,129.813 2,267,982 3.00 -3,00 0,00 -179,959 5,487,006 87.005 45,380 3,638,700 2,253,547 2,393.369 0,00 0,00 0,00 0,000 1E-121 DLat Pt1 5,965,854 88,910 26,308 3,655,926 2,639.679 2,672,248 4,00 0.40 -3,98 -84,689 6,111.625 88,910 26,308 3,658.700 2,770.328 2,736,841 0,00 0,00 0,00 0,000 1 E-121 DLat Pt2 6,411.292 88,865 14,319 3,664.539 3,050,792 2,840,663 4,00 -0.01 -4,00 -90,328 7,075,932 88,865 14,319 3,677.700 3,694.658 3,005,010 0,00 0.00 0,00 0,000 1 E-121 DLat Pt3 7,112.433 89.427 13,379 3,678.244 3,730,093 3,013,746 3,00 1.54 -2,58 -59,169 8,257.447 89,427 13,379 3,689.700 4,843,978 3,278,674 0,00 0.00 0,00 0,000 1 E-121 DLat Pt4 8,279.268 90,081 13,361 3,689.794 4,865.207 3,283.720 3,00 3.00 -0,08 -1,584 9,757.932 90,081 13,361 3,687.700 6,303.849 3,625.409 0,00 0.00 0,00 0,000 1 E-121 DLat Pt5 9,784.879 90,888 13.409 3,687.472 6,330.063 3,631,646 3,00 2.99 0.18 3.428 10,157,293 90,888 13.409 3,681.700 6,692,281 3,717,999 0,00 0,00 0,00 0,000 1E-121 DLat Pt6 10,207.621 90,887 14,919 3,680,921 6,741,072 3,730,312 3,00 0,00 3.00 90,042 12,419.030 90,887 14,919 3,646.700 ' 8,877.680 4,299.579 0,00 0,00 0.00 0,000 1 E-121 DLat Toe 12/312004 2:23:53PM Page 3 of 7 COMPASS 2003,11 Build 48 ORIGINAL . . Conoc~illips Alaska Halliburton Company Planning Report ~r-...,...,y-sun DR" LING SERVICES A HALLIBURTON COMPANY 110,000 0.000 0.000 110,000 0,000 0,000 0,000 0,00 0,00 0,00 2,650.874 35,000 48,041 2,395,700 589,985 677.023 827,062 1.38 1,38 0,00 10314" 4,776.404 75,000 45,380 3,586,700 1,756,830 1,890,010 2,407,554 1,88 1,88 -0,13 To" Of Window - 2S50' FNL & 4016'FEL : Sect15- T11 N-R10E (4776' MD, 3587'TVD) -D-Sand - 7 5IS" WindoW To" 4,778.404 75,318 45,380 3,587,212 1,758,188 1,891,386 2,409,378 15,90 15.90 0,00 Bttm of Window : (477S' MD, 3587' TVD) 4,788.404 76,908 45,380 3.589.612 1,765,006 1,898,296 2,418,535 15,90 15,90 0.00 4,800,000 76.908 45,380 3,592.239 1,772,940 1,906.335 2,429,190 0,00 0,00 0.00 4,806.404 76.908 45,380 3,593.689 1,777.321 1,910,775 2,435,074 0,00 0,00 0.00 Begin Build @5°/100ft (4II06'MD , 3594' TVD) 5,000,000 86.588 45,380 3,621.443 1,911,735 2,046,984 2,615,595 5,00 5,00 0.00 5,008,344 87.005 45,380 3,621.909 1,917,587 2,052.914 2,623.454 5,00 5,00 0,00 Decrease Build to 3°/100ft (500S'MD , 3622' TVD) 5,075,021 89.005 45,381 3,624,230 1,964,390 2,100,343 2,686,311 3,00 3.00 0,00 Begin Tangent to Land in Upper D-Sand (5075' MD & 3624' TVD) 5,200,000 89,005 45,381 3,626,400 2,052,159 2,189,289 2,804,190 0,00 0,00 0,00 5,243,929 89,005 45,381 3,627,162 2,083,010 2,220,553 2,845,623 0,00 0,00 0,00 Drop @ 3°/100ft (5244' MD , 3627' TVD) 5,310,606 87,005 45.380 3,629.483 2,129,813 2,267,982 2,908.481 3,00 -3,00 0,00 Begin Geo-Steering in D-Sand (5311' MD, 36289' TVD) 5,353,032 87,005 45.380 3,631,700 2,159,572 2,298,138 2,948.448 0,00 0,00 0,00 C 5,400.000 87,005 45,380 3,634,154 2,192.517 2,331,524 2,992.694 0.00 0,00 0,00 5,487,006 87,005 45,380 3,638,700 2,253.547 2,393,369 3,074,658 0,00 0,00 0,00 1E-121 DLat Pt1 5,600.000 87.432 40,876 3,644,186 2,335,896 2,470,502 3,182.486 4,00 0,38 -3,99 5,800.000 88,225 32,910 3,651.775 2,495,606 2,590,377 3,378,583 4,00 0.40 -3,98 5,965,854 88,910 26.308 3,655,926 2,639,679 2,672,248 3,543,964 4,00 0.41 -3,98 6,000,000 88,910 26.308 3,656,576 2,670,282 2,687,378 3,578,103 0,00 0,00 0.00 6,111,625 88,910 26.308 3,658,700 2,770,328 2,736,841 3,689,706 0,00 0,00 0.00 1E-121 DLat Pt2 6,200,000 88,892 22.773 3,660.396 2,850,692 2,773,533 3,778,022 4,00 -0,02 -4,00 6,215,687 88,889 22.145 3,660,700 2,865,187 2,779,525 3,793,676 4,01 -0,02 -4,01 B-Sand 6,400,000 88,866 14.772 3,664,316 3,039,864 2,837,828 3,976,233 4,00 -0,01 -4,00 6,411,292 88,865 14.319 3,664,539 3,050,792 2,840,663 3,987,298 4,01 -0,01 -4,01 6,600,000 88.865 14.319 3,668.276 3,233,601 2,887.325 4,172,062 0,00 0.00 0,00 6,800,000 88,865 14,319 3,672.236 3,427,350 2,936.780 4,367,881 0,00 0.00 0,00 7,000,000 88,865 14.319 3,676,196 3,621,099 2,986.234 4,563,701 0,00 0.00 0,00 7,075,932 88.865 14,319 3,677.700 3,694,658 3,005.010 4,638,046 0,00 0.00 0,00 1E-121DLat Pt3 7,112.433 89.427 13,379 3,678,244 3,730,093 3,013.746 4,673,725 3,00 1,54 -2,58 7,200,000 89.427 13,379 3,679,120 3,815,279 3,034,007 4,759,171 0,00 0,00 0,00 7,400,000 89.427 13,379 3,681,121 4,009,842 3,080.282 4,954,329 0,00 0,00 0,00 7,600,000 89,427 13,379 3,683,122 4,204.405 3,126,557 5,149.486 0.00 0,00 0,00 7,800,000 89.427 13,379 3,685,123 4,398,967 3,172,832 5,344.644 0,00 0,00 0,00 8,000,000 89,427 13,379 3,687,124 4,593.530 3,219,107 5,539,801 0.00 0,00 0,00 8,200,000 89.427 13,379 3,689,125 4,788.092 3,265,382 5,734.958 0.00 0,00 0,00 8,257.447 89.427 13,379 3,689,700 4,843,978 3,278,674 5,791.014 0.00 0,00 0,00 1E-121 DLat Pt4 12/312004 2:23:53PM Page 4 of 7 COMPASS 2003,11 Build 48 ORIGINAL . . y ConocoPhillips Alaska Halliburton Company Planning Report c=;rDl""'l""'v-sun DRIL..L..ING seRVices A HALLIBURTON ÇOMf'A..W EDM 2003,11 Single User Db ConocoPhillips Alaska Inc, Kuparuk River Unit Kuparuk 1E Pad Plan 1E-121 Ian: 1E-121 L 1 E-121 L 1 (wp06) 8,279,268 90,081 13.361 3,689,794 4,865,207 3,283.720 5,812,307 3,00 3,00 -0,08 8,400,000 90,081 13,361 3,689,623 4,982,671 3,311.619 5,930,113 0,00 0,00 0,00 8,600,000 90,081 13,361 3,689,340 5,177,258 3,357.834 6,125,266 0,00 0,00 0.00 8,800,000 90,081 13,361 3,689.056 5,371,845 3,404.050 6,320,419 0,00 0,00 0.00 9,000,000 90,081 13,361 3,688.773 5,566.431 3,450,266 6,515,573 0,00 0,00 0,00 9,200,000 90,081 13,361 3,688.490 5,761,018 3,496.482 6,710,726 0.00 0,00 0,00 9,400,000 90,081 13,361 3,688,207 5,955,605 3,542,698 6,905,879 0.00 0,00 0,00 9,600.000 90.081 13,361 3,687,924 6,150.192 3,588,914 7,101.032 0,00 0,00 0,00 9,757,932 90.081 13.361 3,687,700 6,303,849 3,625.409 7,255,137 0,00 0.00 0,00 1E·121 DLat PIS 9,784,879 90,888 13.409 3,687.472 6,330,063 3,631.646 7,281.432 3,00 2,99 0,18 9,800,000 90.888 13.409 3,687,238 6,344,770 3,635,153 7,296,188 0,00 0.00 0,00 10,000,000 90.888 13.409 3,684,138 6,539,295 3,681.527 7,491,354 0,00 0,00 0.00 10,157,293 90.888 13,409 3,681.700 6,692.281 3,717.999 7,644,846 0,00 0,00 0.00 1E-121 DLat Pt& 10,200,000 90,887 14,690 3,681,038 6,733,705 3,728,365 7,686,622 3,00 0,00 3.00 10,207.621 90,887 14,919 3,680,921 6,741,072 3,730,312 7,694,096 3.00 0,00 3.00 1 0,400,000 90,887 14,919 3,677,944 6,926,944 3,779,835 7,882,867 0,00 0,00 0,00 10,600,000 90,887 14,919 3,674,849 7,120,179 3,831,320 8,079,114 0.00 0,00 0,00 10,800,000 90,887 14,919 3,671,754 7,313.414 3,882,804 8,275,362 0.00 0,00 0,00 11,000,000 90,887 14,919 3,668,659 7,506,649 3,934,289 8,471.610 0.00 0,00 0,00 11,200,000 90,887 14,919 3,665,564 7,699.884 3,985,773 8,667.858 0,00 0,00 0,00 11,400,000 90,887 14,919 3,662.469 7,893.119 4,037,258 8,864,106 0,00 0,00 0,00 11,600,000 90,887 14,919 3,659,374 8,086,354 4,088,742 9,060.353 0,00 0,00 0,00 11,800,000 90,887 14,919 3,656,279 8,279,589 4,140,227 9,256,601 0,00 0,00 0,00 12,000,000 90,887 14,919 3,653,184 8.472,824 4,191,711 9,452,849 0,00 0.00 0,00 12,200.000 90,887 14,919 3,650.089 8,666,059 4,243.196 9,649,097 0,00 0,00 0,00 12,400.000 90.887 14,919 3,646.994 8,859,294 4,294.680 9,845,345 0,00 0,00 0,00 12,419.030 90.887 14,919 3,646.700 8,877,680 4,299.579 9,864,017 0,00 0,00 0.00 v &HL :110' FNL & 1591' FEL ; 5ect10-T11N-R10E (12419'11II1>, 3647'1'VD). 4112 -1E-121DLat Toe 121312004 2:23:53PM Page 50f7 COMPASS 2003,11 Build 48 ORIGINAL. . . ¥ ConocoPhillips Alaska Halliburton Company Planning Report c:;rs=a""""y-5un DRILLING seRVices A HALLIBURTON COMPANY 1 E-121 DLat Pt6 0,00 0,00 3,681,700 6,692,281 3,717,999 5,967,276,000 553,563,000 70019' 16,695" N 1490 33' 56,689" W - plan hits target - Point 1 E-121 DLat Pt4 0,00 0,00 3,689.700 4.843.978 3,278,674 5,965,425,000 553,136,000 70018' 58,519" N 149034' 09,533" W - plan hits target - Point 1E-121 DLat Pt2 0,00 0,00 3,658,700 2,770.328 2,736,841 5,963,348,000 552,608.000 70018' 38,127" N 149034' 25.364" W - plan hits target - Paint 1E-121 DLat Pt5 0.00 0,00 3,687,700 6,303,849 3,625.409 5,966,887,000 553,473,000 700 19' 12,875" N 149033' 59,396" W - plan hits target - Point 1E-121 DLat Pt3 0.00 0,00 3,677,700 3,694,658 3,005.Q1 0 5,964,274,000 552,870,000 700 18' 47,217" N 149034' 17,531" W - plan hits target - Point 1 E-121 DLat Pt1 0,00 0,00 3,638,700 2,253,547 2,393,369 5,962,829.000 552,268,000 70018' 33,046" N 1490 34' 35,387" W - plan hits target - Point 1E-121 DLat Toe 0,00 0,00 3,646,700 8,877,680 4,299,579 5,969,465,000 554,130,000 70019' 38,185" N 1490 33' 39,680" W - plan - Point 110,000 110.000 20" 20 40 2,650,874 2,395.700 103/4" 1 0-3/4 13-1/2 4,776.420 3,586.704 7 5/8" Window Top 7-5/8 9-7/8 12,419,020 3,646,700 4 1/2 4-1/2 6-3/4 4,776.404 5,353,032 6,215,687 3,586,700 D-Sand 3,631,700 C 3,660,700 B-Sand 0,000 0,000 0,000 0.000 0.000 0.000 12/3/2004 2:23:53PM Page 6 of 7 COMPASS 2003.11 Build 48 ORIGINAL . . y ConocoPhillips Alaska Halliburton Company Planning Report c:;ra~Y-5un C"LLNC;S !iERVICE!5 A HALLlß{}IUON COMPANY EDM 2003,11 Single User Db ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-121 Plan: 1E-121 L1 1E-121 L 1 (wp06) 4,776.410 4,778.404 4,806.404 5,008,344 5,075.021 5,243,929 5,310,606 12,419,020 3,586,701 3,587.212 3,593.689 3,621,909 3,624,230 3,627,162 3,629.483 3,646,700 1,756.834 1,758,188 1,777,321 1,917,587 1,964,389 2,083,010 2,129,812 8,877,670 1,890.014 1,891,386 1,910,775 2,052,914 2,100,343 2,220,553 2,267,982 4,299,577 Top of Window - 2550' FNL & 4016' FEL: Sect15-T11N-R10E (4776' MD, 358ï Bttm of Window: (4778' MD, 3587' TVD) Begin Build @5°/100ft (4806'MD , 3594' TVD) Decrease Build to 3°/100ft (5008'MD ,3622' TVD) Begin Tangent to Land in Upper D-Sand (5075' MD & 3624' TVD) Drop @ 3°/10Oft (5244' MD ,3627' TVD) Begin Gee-Steering in D-Sand (5311' MD ,36289' TVD) BHL: 710' FNL & 1591' FEL: Sect10-T11N-R10E (12419' MD, 3647' TVD) 121312004 2:23:53PM Page 70f7 COMPASS 2003.11 Build 48 ORIGINAL . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /<1211 lé-/¿I L I PTD# 2D,/- 2 L/7 ¡/. Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL j (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE", Tbe permit is for a new weJlboresegment of existing weD ¡</2f(. If:: ,-/Z/ Permit No,zctI~Z¥'AP] No. So-ðZ7-:Z3238--ðò Production, sbould continue to be reponed as a function 'of tbe original API number. stated above. ' HOLE In accordance witb 20 AAC 25.005(f), all records, data and logs acquired for tbe pilot bole must be dearly differentiated 'in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:JCeption. (Company Name) assumes tbe liability of any protest to tbe spacing ,e:Jception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in DO greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught aDd ] 0' sample inter:vals tbrough target zones. " N \ "_'____n_____'______________¡ KRU1 E..121 L 1 Proposed 1-0il 2042470 SFD 12/15/2004 " Field & Pool KUPARUKRIVER,WESTSAKOIL-490150 Well Name: KUPARUKRIVUNIT1E-121L1 Program DEV Wellboreseg ~ PTD#: 2042470 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 PermiUee Qltache.cL . . . NA Multilateral well.segme.n!;fe.ewaived per 20 MC .25.005(eL . . . _ _ _ _ . _ . _ 2 LeQsenumbe.r _appropri<lte_ _ . . . . . . _ _ _ _ _ _ . _ Y~$ _ _ _ _ _ Multilateral we.lIsegmenL!op.productiye inteNatil1 ADL 025651;. TO in ADL .0256~6. . _ _ _ _ _ _ _ _ . _ . . 3 .U.nique weltn_a[11~.al1d Ol!mb.er . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . Y~$ . . . . . . . . . . . . . . . . .. ......................... _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 We.IUoc<lted ina defjne.dppol_ _ _ . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Xe$ . . _ _ KRU West 5ak _OJ Ppol, goyemed_ by.C.oI1$eNation Order No, 4066. . _ _ . _ . _ _ _ _ _ _ _ _ . . _ . 5 We.IUoc<lted prOpe.r .distance. from driJling unit.b.ound.al)'. _ _ _ Y~s . . _ _ _ _ No œstrictiol1s QS_ to well sp<lciog except th<lt no pay shaJI be ppe_ned in .awell clpser th<lo 500 feet _ _ _ . _ _ . . 6 We.IIJoc<lted proper .distance from otbe.r wells_ _ _ _ . . . . _ . . _ _ _ Y~s to _al1 e~ernQlproperty.line. _ _ _ _ . . _ . . . . 7 _S_utfjcient.<lcreQge_ayQiI<lble in_dJilJiog unjt . . _ _ . . Xe$ . _ . . . . . . _ . _ _ _ _ _ _ _ . 8 Jfdeviated, js wellbore platincJuded _ _ _ . . . . . . . .. _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xe$ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . . _ . _ _ _ _ _ _ _ _ _ . . 90-perator onl)' Qftected party. _ _ . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$. . . . _ _ _ _ _ _ _ _ _ _. _. _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ . _ . . . _ _ _ _ _ _ _ . . . 10 .0-Pßrator bas.apprppriate.b.ond inJorce. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Permitcal1beis$l!edwjtboutco_nserva.tionorder.... _ _ _ _ _ _. _ Y~$. _ _ _ _.... _..... .......... Appr Date 12 PermitQal1beis$l!edwjtboutad.ministratÎllea-pprpvaJ_ _ _. _ _ _........ .Y~s_ _ _......... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _.. _.. SFD 12/15/2004 13 Can permit be approved before 15-day wait Yes 14 We.IIJoc<lted within Qrea an.d.strata .authorized by.ll1jectipo Ord~r # (putlO# incpm[11~l1ts).(For. .NA . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ . . _ _ _ _ . . _ _ _ . _ _ . _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ 15 .AJI weIJs.witÞlnJl4.mite.are.a.of reyiew jd~otified (Fpr servjc.ewell On I)'). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre.-produced il1jector; .dur<ltjon_of pre--production I~ss thQn 3 months (For service well onJy) _ _ NA . . . _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ . 17 AÇMP.Fïnding ofCon,Si,SteI1CY has beenjssued.for.this Project. _ _ _ . . . . . . _ _ _ _ _ _ _ _ NA _ _ . . . . _ . . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . . . . . . . _ _ _ _ _ _ _ . Engineering 18 19 20 21 22 23 24 25 26 27 Appr Date 28 TEM 12/15/2004 29 1Jpv1 ~~ 32 33 34 35 36 Date 37 12/15/2004 38 39 Geology Appr SFD Geologic Commissioner: lJ1S . .C.ol1ductor stringpJovided _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . . _ _ . . . . . _ _ _ _ _ _ NA _ _ _ _ Conductor_setio [11ptherbore,_1.E-t21 .(20~:2~6). . . . . . . _ _ _ _ _ . .SurfQœcasingpJotec.ls all known USOWs _ _ _ . . _ _ . . . . . _ . _ _ _ _ _ _ _ _ _ _NA . . . . . . .A.II aq.uife.rs ex~rnpt~d,40 _CFR 1~7.1 02. (b).(3),. _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . CMT vOl adeQl!ate.to circulateoncond.uctor.& SUJfC$g . . _ _ _ _ . . _ . .NA . . _ Surface caslng ceme.nte.djn1E-121. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ CMTvoladeQuate.totie-inJongstringtosurfcsg. _...... .. _ _ _ _ _ _ _ _ _ _ _ _ _ NA .Prpdl!ction.Qasil1gse.tln1E~1.2L _ .. _ _ _ _ _ _ _ _ _ _._ CMTwil! coyer.aH koown_pro.ductiye hori¡!:ons _ _ _ _ _ _ _ _ _ _ . . _ _ No _ _ _ _ _ _ _ SlottedJille.r_completiol1 ptallned. _ _ _ . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . . .C.asil1g de.sigl1s Qd.equa.te. fpr C,T, 6&permafr_o$t _ _ _ _ _ . _ . . . . . . . . . . _ _ _ _ _Y~s _ _ _ _ _ _ _ . _ . _ . _ . . _ . . . . . _ _ _ _ _ _ _ _ _ . _ _ _ . . . . . Adequ.<ltetQnkageoJ re_serve pit _ . _ _ . . . . . . . _ . _ . . _ Y~$. _ . . _ _ _ Rig jsequippe.dwith steeLpits.. No rese.rve_pjt-planoe.d, AH waste to.apprpvedanouJl!sor disposal.w~IJ.. . . Jfa.re-drill~ hasa 10-403 fOJ <lbandonme_nt beell apPJoved _ . _ _ _ _ _ _ _ _ _ _ _ _NA _ . _ . _ _ _ _ _ _ . . . . _ _ . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . .A.dequ.<ltewellbore. separ<ltjo.n-pro-posed. . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . Y~s . . . . . . . prpJ5:imit)' an.<llysis pe.rfo(l1)e.d, Nearest .welJb.ore.is rnotÞerbore <lbout 50: tvd Þelow.. . . . . . . . . . . . . Jfdiverte.r Jequired, does jt meet reguJatioos_ _ _ . _ _ _ _ . _ _ _ _ _ . . _ _ _ _NA _ _ BOP $tack will already_b_ein plQce, _ . . . . . . . . _ . . . . _ _ _ _ _ _ _ _ _ _ . . _ .DJiUiog flujd.prQgram $chematic& eq.uipJi$tadequate_ . _ _ . . _ _ _ _ . . . . . _ _ _ _ Y~$ _ . . _ _ . _ Maximum expected fprma.tion pressure.8,6.EMW._ Plallnedmudweights _9.1_ppg in 9-7/8" hole. and9.1p-pg in.WS _BOPEs,d_o they meet reguJa.tion _ _ . . . . . _ _ _ _ . _ . . . Y~s _ . . . . . . . _ _ _ _ _ . . _ .BOPE.pre.s$ ratillg Qp-propriate;test to (put psig in _comrnents). . . _ _ _ _ Xes _ . M.A.SI=' çalculate_d_at 1235 -psi, 3500.psUest pl<loned._ BOP .stack will rneet3KJequirements witÞ P_RlBRI.A.n for DE' Choke manifold compJies w/APt R:)-53 (May 84). . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y~s _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ . Work wi!! occur withouLoperationshutdown. . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ Xes. . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ . . Js presence of H2S gas_ prob.able _ . . . . . . . _ _ No. . . . _ _ _ _ 1-125 is notreported in W5.. _ _ . _ . . . Mecba.nical.cpodjtion pf wells wi.thin.A.OR yerified (For_s_ervice .welJ only). _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ . P~rmit c.all be iS$l!ed .w/o hydrogen sUlfide measures _ .D_atapJeseoted on pote_ntial PveJpressure .ZOnes _ . .Seisrn¡c.analys.is. of shallow gaszj)lle.s _ _ _ _ _ _ . _ _ _ . _S~abed .conditipo survey.(if off-shj)re) . _ _ Contact namelphoneJorweekly prpgress.report$ [exploratol)'only] .__Xes._ ____._ _____.._ _ _ _ _ . . _ Y~$ . _ _ _ _ . Expected re$e.rvojr -pre.S$UJe i$ 8,6 ppg EMW; will_be drilled with 9.0 ppg mud. _ ~ - - - - - - - - - - - - - - - - - - - - - - - - ..... .NA NA _. .NA. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: /Z//6!1-- Engineering Commissioner: Date /yy~ ~liC ~~;,"e' Date . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . P-0 cf-~ f7 $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 01 08:29:42 2005 Ii J)Û 8 ( Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 05/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-121 L1 500292323860 ConocoPhillips, Alaska, Inc Sperry-Sun Drilling Services 01-MAR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003458622 E. QUAM D. GLADDEN MWD RUN 3 MW0003458622 E. QUAM D. GLADDEN MWD RUN 5 MW0003458622 J. MARTIN M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0003458622 J. MARTIN M. THORNTON MWD RUN 7 MW0003458622 J. MARTIN M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: 16 11 10 973 . . FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 630 98.70 70.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.750 CASING SIZE (IN) 10.750 7.625 DRILLERS DEPTH (FT) 2662.0 4816.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS LATERAL WELLBORE EXITS THE 1E-121 WELLBORE AT 4816'MD/3616'TVD, THE DEPTH OF THE TOP OF THE WHIPSTOCK. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2,3,6,7 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 6 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA(GP). RUNS 6 & 7 ALSO INCLUDED AT-BIT INCLINATION (ABI). THE PURPOSE OF MWD RUN 5 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE - ONLY SROP DATA ARE PRESENTED. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5-7 REPRESENT WELL 1E-121 L1 WITH API#:50-029-23238-60. THIS WELL RE.A.CHED A TOTAL DEPTH (TD) OF 12414' MD /3671' 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 (SEDP). 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...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2627.5 2627.5 2627.5 2627.5 2627.5 2636.5 2670.0 STOP DEPTH 12360.0 12360.0 12360.0 12360.0 12360.0 12353.0 12413.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 2 3 5 6 7 MERGED MAIN PASS. $ MERGE TOP 2627.5 3460.0 4816.5 4875.0 6577.0 MERGE BASE 3460.0 4816.0 4875.0 6577.0 12413.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Name Service Order Units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2627.5 12413.5 7520.5 19573 2627.5 12413.5 ROP MWD FT/H 0.15 781.73 189.339 19488 2670 12413.5 GR MWD API 26.7 119.87 71.6519 19434 2636.5 12353 RPX MWD OHMM 1. 33 2000 66.3485 19466 2627.5 12360 RPS MWD OHMM 1. 29 2000 57.4181 19466 2627.5 12360 RPM MWD OHMM 1. 31 2000 51.7505 19466 2627.5 12360 RPD MWD OHMM 0.97 2000 54.2525 19466 2627.5 12360 FET MWD HOUR 0.17 47.04 1. 18415 19466 2627.5 12360 First Reading For Entire File......... .2627.5 Last Reading For Entire File.......... .12413.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record..65535 File Type............ . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..05/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS RPX RPM RPD FET GR ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 2627.5 2627.5 2627.5 2627.5 2627.5 2636.5 2670.0 STOP DEPTH 3417.5 3417.5 3417.5 3417.5 3417.5 3425.0 3460.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 16~JAN-05 Insite 66.37 Memory 3460.0 2669.0 3460.0 35.0 40.9 TOOL NUMBER 061497 134760 9.875 2662.0 Water Based 9.00 50.0 8.5 300 9.0 4.500 3.750 4.000 6.000 66.0 80.5 66.0 66.0 . . TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format §pecification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2627.5 3460 3043.75 1666 2627.5 3460 ROP MWD020 FT/H 28.14 301.74 188.813 1581 2670 3460 GR MWD020 API 26.7 112.3 61.5869 1578 2636.5 3425 RPX MWD020 OHMM 1. 33 1598.15 14.1594 1581 2627.5 3417.5 RPS MWD020 OHMM 1. 29 2000 20.8786 1581 2627.5 3417.5 RPM MWD020 OHMM 1. 31 1850.01 15.6581 1581 2627.5 3417.5 RPD MWD020 OHMM 0.97 2000 73.5524 1581 2627.5 3417.5 FET MWD020 HOUR 0.17 47.04 2.97202 1581 2627.5 3417.5 First Reading For Entire File......... .2627.5 Last Reading For Entire File.......... .3460 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/03/01 . Maximum Physical Record. .65535 File Type...... . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 3418.0 3418.0 3418.0 3418.0 3418.0 3425.5 3460.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 4816.0 4816.0 4816.0 4816.0 4816.0 4816.0 4816.0 17-JAN-05 Insite 66.37 Memory 4816.0 3460.0 4816.0 45.5 81.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 061497 134760 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 9.875 2662.0 . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Water 9.10 80.0 8.5 350 5.6 Based 5.000 3.640 8.000 4.000 70.0 98.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3418 4816 4117 2797 3418 4816 ROP MWD030 FT/H 1. 35 652.56 188.15 2712 3460.5 4816 GR MWD030 API 30.67 119.87 77.4032 2782 3425.5 4816 RPX MWD030 OHMM 5.84 27.42 12.058 2797 3418 4816 RPS MWD030 OHMM 6.29 28.8 12.5205 2797 3418 4816 . . RPM MWD030 OHMM 6.72 29.37 12.5961 2797 3418 4816 RPD MWD030 OHMM 7.98 37.05 13.7263 2797 3418 4816 FET MWD030 HOUR 0.24 12.28 0.923171 2797 3418 4816 First Reading For Entire File......... .3418 Last Reading For Entire File.......... .4816 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type.......... . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 4 header data for each bit run in separate files. 5 .5000 START DEPTH 4816.5 STOP DEPTH 4875.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-JAN-05 Insite 66.37 Memory 4875.0 4816.0 4875.0 .0 .0 # . TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value................ . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 . TOOL NUMBER 6.160 4816.0 Oil Based 9.00 95.0 .0 43000 2.6 .000 .000 .000 .000 .0 102.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4816.5 4875 4845.75 118 4816.5 4875 ROP MWD050 FT/H 0.32 54.28 24.9562 118 4816.5 4875 First Reading For Entire File......... .4816.5 . . Last Reading For Entire File......... ..4875 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET GR RPX RPS RPD RPM ROP $ 5 header data for each bit run in separate files. 6 .5000 START DEPTH 4816.5 4816.5 4816.5 4816.5 4816.5 4816.5 4875.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 6525.5 6518.5 6525.5 6525.5 6525.5 6525.5 6577.0 29-JAN -05 Insite 66.37 Memory 6577.0 4875.0 6577.0 74.7 91. 0 TOOL NUMBER 135134 . EWR4 $ Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 73764 6.750 4816.0 Oil Based 9.00 80.0 .0 45000 2.0 .000 .000 .000 .000 .0 113.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 Min First Max Mean Nsam Reading 6577 5696.75 3522 4816.5 Last Name Service Unit Reading DEPT FT 6577 4816.5 . . ROP MWD060 FT/H 3.17 284.71 195.22 3404 4875.5 6577 GR MWD060 API 46.01 94.42 69.4203 3405 4816.5 6518.5 RPX MWD060 OHMM 12.48 2000 88.7876 3419 4816.5 6525.5 RPS MWD060 OHMM 15.59 176.66 73.9784 3419 4816.5 6525.5 RPM MWD060 OHMM 24.66 125.97 66.4906 3419 4816.5 6525.5 RPD MWD060 OHMM 29.13 108.09 62.8729 3419 4816.5 6525.5 FET MWD060 HOUR 0.21 26.82 1.47752 3419 4816.5 6525.5 First Reading For Entire File......... .4816.5 Last Reading For Entire File.......... .6577 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 header data for each bit run in separate files. 7 .5000 START DEPTH 6519.0 6526.0 6526.0 6526.0 6526.0 6526.0 6577.5 STOP DEPTH 12353.0 12360.0 12360.0 12360.0 12360.0 12360.0 12413.5 # . LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 02-FEB-05 Insite 66.37 Memory 12414.0 6577.0 12414.0 87.5 93.6 TOOL NUMBER 135134 73764 6.750 4816.0 oil Based 9.00 80.0 .0 45000 .0 .000 .000 .000 .000 .0 116.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel . . DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM, 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6519 12413.5 9466.25 11790 6519 12413.5 ROP MWD070 FT/H 0.15 781.73 189.634 11673 6577.5 12413.5 GR MWD070 API 39.68 111.2 72.2931 11669 6519 12353 RPX MWD070 OHMM 6.72 2000 79.858 11669 6526 12360 RPS MWD070 OHMM 9.54 2000 68.2782 11669 6526 12360 RPM MWD070 OHMM 9.62 2000 61.7069 11669 6526 12360 RPD MWD070 OHMM 10.15 2000 58.8257 11669 6526 12360 FET MWD070 HOUR 0.2 17.63 0.918511 11669 6526 12360 First Reading For Entire File......... .6519 Last Reading For Entire File.......... .12413.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .05/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name........ . . . . .LISTPE Date.................... .05/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer . . Service name............ .LISTPE Date.................... .05/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File