Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-154
c~ ~ 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. c:Q Q L/::- - L S 4- Well History File Identifier Organizing (done) D Two-sided 111111111" 11I11111 D Rescan Needed III 1111" 1111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: D Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: NOTES: BY: C Maria.-J , Date: 1 t J tal00 o Other:: Scanning Preparation BY: Ç. Maria ) I Date f I talot:, x 30 = :1 0 Date: H 1.3/ D ~ VI1P "I "111111111111 II 'YYJ , + ~ = TOTAL PAGES ~ ¡;-a (Count does not include cover sheet) V1/¡:; 151 r r . 151 Project Proofing BY: /"Maria J 151 Production Scanning 11I1111111111111111 Stage 1 Page Count from Scanned File: 5 Lf- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:1J "3/010 If NO in stage 1, page(s) discrepancies were found: YES NO 151 wvP NO BY: Stage 1 BY: Maria Date: 151 III "11111111111111 Scanning is complete at this point unless rescanning is required, ReScanned "I "111111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked III "lilt lit "It III 1 0/6/2005 Well History File Cover Page. doc STATE OF ALASKA • ALit OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r Other pi Pulled B sand !so PuII Tubing Sleeve Alter Casing r g r Perforate New Pbol r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r • 204 -154 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23220 - 60 O 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25660 1E-166L1 9. Field /Pool(s): _ Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 9423 feet Plugs (measured) None true vertical 3330 feet Junk (measured) None Effective Depth measured 9378 feet Packer (measured) true vertical 3330 feet (true vertucal) Casing Length Size MD ND Burst Collapse CONDUCTOR 78 20 108 108 SURFACE 2982 10.75 3012 2393 INTERMEDIATE 5986 7.625 6014 B -SAND LINER 4317 4.5 9380 1 3330 .AE: Id d i MAR ;?72i 11 Perforation depth: Measured depth: slots 5090' - 9340' True Vertical Depth: 3347' - 3332' ; .: _k,trs. U mmission i , 1utr Tubing (size, grade, MD, and ND) 4.5, L80, 4712 MD, 3255 TVD Packers & SSSV (type, MD, and ND) NIPPLE - CAMCO NIPPLE @ 509 MD and 509 ND PACKER - ZXP @ 4677 MD and 3244 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: SLANNE1) APR e 9 ZUIZ 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 674 168 188 635 223 Subsequent to operation 745 118 171 699 214 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Fi Service r Stratigraphic r 15. Well Status after work: Oil pi Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt none Contact Christensen / Humphrey a4 659 - 7535 Printed Name ' ob D. Christensen Title Prod Eng Specialist Z l Signature 7 /' _ Phone: 659 -7535 Date i , / RSDMS APR 0 t 2 1 / yo-r Form 10 -404 Revised 10/2010 Submit Original Only • 1E-166L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PULLED TYPE 2 ISO SLEEVE @6719' CTMD. WELL ONLINE, TURNED OVER TO 11/18/11 PRODUCTION. • KU P • 1 E -166 ConocoPhillips rt Well Attributes Max Angle & MD TD Wellborn API /UWI Field Name Well Status Inc! )°) MD (ftKB) Act Btm (ftKB) cnre 500292322000 WESTSAK PROD 100.34 6,460.04 9,602.0 "" Comment 142S (ppm) Date Annotation End Date KB (R) Rig Release Date "' _ SSSV: NIPPLE 110 7/10/2009 Last WO: 2/9/2009 35.29 9/24/2004 Welt Cont.. - 1E-166, 117302011 72216 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: PULL SLEEVE ninam 11/30/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H - 40 WELDED ,,,.,..".,., Casing Description String 0... String ID ... Top (08(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 29.8 3,012.0 2,392.3 45.50 L BTC CONDUCTOR, 8 I I - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - 70 INTERMEDIATE 75/8 6.875 26.9 6,014.0 3,500.2 29.70 L - 80 BTCM NIPPLE, 509 I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd HEAT TRACE. I' D-SAND LINER LEM 4 1/2 3.960 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM 22 ` Liner Details Top Depth 0 . (TVD) Top Inc! 90,14 . SURFACE, I Top (RKB) (ftKB) ( °) Item Description Comment ID (in) 30 -3,012 GAS LIFT, - 1... 4,676.5 3,243.5 71.59 PACKER ZXP Packer 4.970 GAS u� ' 4,695.5 3,250.0 72.05 SBE 190-47 Casing Seal Bore Extension 4.750 NIPPLE, 4,625 .�` 4,751.6 3,267.6 73.41 NIPPLE 3.75 " 'DB' Nipple 3.750 GAUGE, LOCATOR, I ! 4,788.3 3,277.7 74.31 UPPER HH Upper LEM Assembly 3.910 4,685 SEAL ASST. - 4,795.1 3,279.4 74.47 LOWER HH Lower LEM Assembly 3.990 4,694 D - SAND 5,030.7 3,335.4 78.36 SEAL ASSY Seal Assembly 3.930 WINDOW, MIR 4,799 - 6,81 1 Casing Description String 0... String ID ... Top (MB) Set Depth (I... Set Depth (TVD) ... String Wt... String ... String Top Thrd D - BAND LINER D WINDOW 41/2 3.958 4,799.0 4,811.0 3,283.4 12.60 LEM, 4,877 -5 034 Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B - SAND B LINER HH 4 1/2 3.958 5,010.1 5,345.8 3,399.0 12.60 L IBT WINDOW, 5,068-5,080 Liner Details B -SAND LINER a ' Top Depth 5,0105,346. (TVD) Top Inc! Noml... NTERMEDIATE, • 4 Top (9(8) (ftKB) ( °) Item Description Comment ID (In) 27-6,014 SLOTS, ,� 5,010.1 3,331.2 78.46 PACKER ZXP LINER TOP PACKER 6.230 6,043 SLOTS, 5,029.1 3,335.0 78.37 XO BUSHING 4.760 6,198 SLOTS, 5,029.9 3,335.2 78.36 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 638 SLOTS 1i 5,049.2 3,338.8 77.83 XO BUSHING 3.910 6.5395.629 1 SLOTS. ' 5,057.1 3,340.4 77.83 HANGER LEM ABOVE HOOK HANGER 4.020 4,822 - 9,363 SLOTS, I 5,063.1 3,341.7 77.83 HANGER LEM INSIDE HOOK HANGER 4.020 7,065 SLTS. 5,129.0 3,355.6 77.83 NIPPLE CAMCO'DB - 6' NIPPLE 3.562 7,955 SLOTS, , 5,342.5 3,398.5 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 8,559-9,104 8 -SAND )� , f( Casing Description String 0... String ID ... Top (08(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER. B WINDOW 41/2 3.958 5,068.0 5,080.0 3,345.3 12.60 5,0639.380 0 -SAND ) Casing Description String 0... String ID ... Top (ftKB) Set Depth (I... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER. A LINER 4 1/2 3.958 5,302.2 9,596.0 3,518.4 12.60 L - 80 DWC 4,796-9,402 Liner Details Top Depth (TVD) Top Inc! Nom!... Top (ftKB) (MO) 1°) Item Description Comment ID )in) 5,302.2 3,391.2 79.05 PACKER HRD ZXP LINER TOP PACKER 4.970 r 5,321.2 3,394.8 79.51 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 5,324.1 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6 3,3972 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3,4003 80.29 XO BUSHING 4.500 Tubing Strings • Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd " " TUBING 4 1/2 3.958 22.1 4,712.0 3,255.4 12.60 L80 IBTM Completion Details Top Depth (TVD) Top Inc! Noml... I Top (11K8) )r") ( ° I Item Description Comment ID (In) I 22.1 22.1 -0.14 HANGER Vetco Gray 13 1/7' x 4 1/2" Hgr w/ 4.909" MCA Top Conn. 3.900 509.1 508.5 15.85 NIPPLE Camco 4 1/2" X 3.875" "DB" Nipple 3.875 -+qtr 1 4,624.6 3,225.7 68.82 NIPPLE Camco 4 1/2" X 3.812" "DB" Nipple 3.812 I' I 4,632.0 3,228.5 69.07 GAUGE Baker Guardian Gauge w /pups 3.958 4,684.8 3,246.4 71.79 LOCATOR Locator Ring and Coupling 3.890 i r 4,693.9 3,249.5 72.01 SEAL ASSY GBH -22 Seal Assembly (2 ft space out) 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth )TVD) Top Inc! Top (MB) (RKB) ( °) Description Comment Run Date ID (In) . 22 22.0 -0.14 HEAT TRACE 2/10/2009 0.000 i i Mandrel Details i j Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run i i Stn Top (ftKB) (81413) (°) Make Model (!n) Sery Type Type (In) (psi) Run Date Com... 1 3,029.2 2,403.7 48.13 Carrico KBG-2-1R 1 GAS LIFT GLV BK 0.188 1,498.0 9/19/2009 2 4,542.7 3,194.6 66.08 Carrico KBG-2-1R 1 GAS LIFT OV BK 0.313 0.0 9/19/2009 i i i SLOTS, _ 9,352 -9,561 i i A-SAND LINER, 5,302 -9,596 TO (1E-166), 9.802 3 KU P • 1E-166 ConocoPhillips Cor 68-039 (ft) Rig Release Date "' _ 35.29 9/24/2004 Well Conag. - 1E-166 11/302011 7'.22'.16 AM Schematic - Ach el - - i Perforations & Slots Shot b Top (TVD) Btm (TVD) Dens , - . . Top (ttKB) Btm (ftKB) (ftKB) (RKB) Zone Date (s5•-- Type Comment 6,043 6,073 3,507.0 3,513.6 WS A2, 1E -166 9/24/2004 32.0 SLOTS ALL PERFS 6023' - 9561': Slotted CONDUCTOR, I linerw /constrictor packers between, 30 32 spf, 2.5 "L x.125'W in 4 I ! circumferential rows NIPPLE, 5 HEAT TRACE. I' 6,198 6,229 3,528.0 3,538.3 WS A2, 1E-166 9/24/2004 32.0 SLOTS 6,384 6,415 3,547.4 3,540.4 WS A2, 1E -166 9/24/2004 32.0 SLOTS SURFACE, 6,539 6,629 3,518.7 3,507.9 WS A2, 1E -166 9/24/2004 32.0 SLOTS 30 - 3,012 I i L 7,065 7,583 3,508.9 3,520.4 WS A2, 1E -166 9/24/2004 32.0 SLOTS GAS LIFT, 3,029 GAS LIFT, -- 7,955 8,372 3,529.6 3,524.8 WS A2, 1E -166 9/24/2004 32.0 SLOTS 4,543 8,559 9,104 3,509.0 3,498.9 WS A2, 1E-166 9/24/2004 32.0 SLOTS NIPPLE, 4,625 - GAUGE. 4,632 9,352 9,561 3,515.3 3,517.1 WS A2, 1E - 166 9/24/2004 32.0 SLOTS LOCATOR, _ SEALASSY,, _ Notes: General & Safety D-4, 694 End Date Annotation WINDOW, ! 11/17/2005 NOTE: WORKOVER TO RECONNECT ESP CABLE - NO OTHER CHANGES 4799 D - SAND LINER 2/17/2039 NOTE: WORKOVER TO CONVERT FROM ESP TO GAS LIFT LEM, 4,677 - 5,034 _.._ 2/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 B -SAND mil WINDOW, 5,068 -5,080 B -SAND LINER p ' 611, 5,010 -5.346 NTERMEDIATE, 256014 SLOTS, 6,0436,073 SLOTS, 6,1966,229 SLOTS, 62846415 tl E SLOTS, 6,5356829 SLOTS,_ 4,82 S LOTS, SLOTS,_ 7,065-7,583 LOTS, SLOTS, 7,%56372 SLOTS. " 8,559- 9,104 H H B -SAND LINER, - 5.063 -9.390 D -SAND LINER, 4,796 -9,402 1 is ., . • .. . .. N 1 1 �a ' l:111I-1 ..I.. 11 i i i i i SLOTS. _ T i L 9,352-9,561 LOTS. A-SAND LINER. D (1 T E-1%). D (1 E 9, 6 02 9,602 KUP • • 1E -166L1 Conoc ° Well Attributes Max Angle & MD TO Wellbore APIIUWI Field Name Well Status Inel ( °) MO (ftKB) Act Wm (ftKB) 500292322060 WESTSAK PROD 92.85 7,116.93 9,423.0 "'" Comment 112S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date Well Config. - 1 E -166L1 11/302011 7'.23:44 AM SSSV: NIPPLE 110 7/10/2009 Last WO: 2/9/2009 35.29 9/24/2004 Schematc Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: PULL SLEEVE ninam 11/30/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (PM) ... String Wt... String ... String Top Thrd BSAND LINER 4 1/2 3.958 5,063.1 9,379.7 3,331.2 29.70 L -80 DWC Liner Deta . . 1 .$ ftM To p Depth (T Top Incl Nomi... ----' Top (IIKB) ( RK B) (1 Item Des cription Comment ID (in) 5, 063.1 3,34 78.10 HANGER BAKER MODEL B -1 FLANGED HOOK HANGER 4.500 14 i CONDUCTOR, l y Perforation & Sl ot s 30-108 Shot To (11/13) Bt (TV Dens Top )TtKB) et m (RKB) (ftKB) (RKB Zone Date PO— Type Comment NIPPLE, 509 I 5,090 9,340 3,347.5 3,332.3 WS B, 1 E -166L1 9/17/2004 32.0 SLOTS Slotted Liner, 2.5"Lx.125"W, in 4 HEAT TRACE, circumferential rows 22 No tes: G eneral & Safety E5.:09:3:. nd Da Annotation 11/17/2005 NOTE: WORKOVER TO RECONNECT ESP CABLE - NO OTHER CHANGES 2/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 2/17/2009 NOTE: WORKOVER TO CONVERT FROM ESP TO GAS LIFT SURFACE, Al ■ 30 -3,012 GAS LIFT. e 3,029 ili IMI GAS LIFT. 4.543 IMI li N PALE 4525 I� MB 33222, 4,532 II LOCATOR, AN 4.685 MI in himirei SEAL ASSY. 6,11111k 4,694 t 1 D -SAND I WINDOW, 4,7994,811 ( I !Mk D -SAND LINER LEM. a 4,6775,034 NM 6 -SANG Mandrel Details WINDOW, Top Depth Top Port SR B -BAND (TVD) Inc! OD Valve Latch Size TIRO Run ND LINER NH, .. Stn Top (ftKB) (RKB) (1 Make Model (In) Sery Type Type ON (Psi) Run Date Corn... 5,010 1 3,029.2 2,403.7 48.13 Camco KBG 1 GAS LIFT GLV BK 0.188 1,498.0 9/19/2009 NTERMEDIATE, 27 1 2 4,542.7 3,194.6 66.08 Camco KBG - 2 - 1R 1 GAS LIFT OV BK 0.313 0.0 9/19/2009 SLOTS, 5,090 -9,340 13-SAND LINER, , N !MI 5,06 TD (1E-166L1), • 9,423 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~AY ~ ~ Z~Q~ REPORT OF SUNDRY WELL OPERA~~g, Gas Hansa ~lammission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ 1~9~~lr~gft 0. Set B Sand ISO Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Sleeve Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhllllps Alaska, InC. Development ~' Exploratory ^ 204-154 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-60 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' ~ 1 E-166L1 - 8. Property Designation: 10. Field/Pool(s): ADL 25651 & 25660 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: d 9423' T D h f t S~~i~ ' -Z ~~~ measure otal - ept ee ~ t O ~ true vertical 3330' - feet Plugs (measured) 5067 Effective Depth measured 9378' - feet Junk (measured) NONE true vertical 3330' ' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20" 1os' 108' SURFACE 2982.15' 10-3/4" 3012' 2392' INTERMEDIATE 5987' 7-5/8" 6014 3500' B-SAND LINER 4317' 4-1/2" 9380' 3331' r ~ "~`' ~` ~ ~` i ` ~` ~ y ' ~" ` ~ `~ Perforation depth: Measured depth: 5090-9340 ~~~,~,; ;,! , ~ ~ ` true vertical depth: 3347-3332 ~~~ S S~`l"~ri. ` ~~ ~~~ ~-- Tubing (size, grade, and measured depth) 4-1/2", L80, 4712' MD. C~~~C~bJT~~ ~ S Packers &SSSV (type & measured depth) NONE N/A ' ` /l~j ` SSSV= NIPPLE 53 21 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~ a1 ~ ~~ ~~~ ~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 713 497 819 996 175 Subsequent to operation 130 62 140 50 204 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0~ 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. Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date .[ "f•t2'D Form 10-404 Revised 04/2004 ~ R ~ ~ ~ ~ A ~ ~t~ Submit Original Only Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Friday, May 08, 2009 9:14 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 E-166 (204-153), et al Tom -Only the B sand was isolated on this well. I will be faxing you some tech /sales info on the ISO sleeve. As far as I know there is nothing new with these. They are the same type we have been using for some time. The tech /sales info should tell you the length. All I know at this point is that it was set at 5067' MD. Darrell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 06, 2009 5:17 PM To: NSK Prod Engr Specialist Subject: 1E-166 (204-153), et al Darrel and Bob, I am reviewing the 404 for the installation of the B sand isolation sleeve. Was only the B sand isolated or did this also isolate the A sand? Do you more specifics on the "Type 1 sleeve"? Top and bottom measured depths would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 5/19/2009 • C~ Well Date Event Descri lion 1 E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w FAILED. LDS FUNCTION TEST -PASSED. a 1E-166 2/5109 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 ar~~. ICU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit°s' with 8.8p~g seawaterJKCL, tested hardline, loaded ESP spooler, kilted well,--nstaNed BPV ND tree, insta-led test dart, NU BOP, RU and started BOP test. 1E-166 2/6!09 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-iepve; MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA ~ with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and strap in derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to Y 264' . ~ O 1E-16fi 2/7J09 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', ~ POOH, MU and RIH with LEM assembly to 4,774' ~ 1E-166 2/8/09 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, M monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3,992'. ~ 1E-166 2/9/09 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2/10109 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, mov rig off 1E Pad. 1 E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ ~ COMPLETE. ~ O a r • • 1 E-166L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/21/09 INSTALL A TYPE 1 ISOLATION SLEEVE INTO THE B-SAND LEM @ 5067' CTMD. 'Nalco Gray Hanger, 11" X 4-1 /2"'Conductor, 20" X 34"Insulated, set at 108' MD. Tubing String: 4-1 /2" 12.6#, L-80, IBTM 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4543' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R ~ ~ 4625' MD - 3.812" DB Nipple 4632' MD -Guardian Gauge Carrier MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/Hold Downs Heat TraceCable~ ~ RWO 09 to 3024' MD ~ X4696' MD -Casing Sealbore Receptacle 4.75" ID 4712' MD -Bottom of Seal Assembly 4.75" Seal OD 10-3/4" Casing Shoe, ~ .4752' MD - 3.75" DB Nipple 'D' Sand Lateral 45.5/40.5#, L-80, BTC set i @ 3012' MD, 2393' TVD .4788' MD -Lateral Entry Module (LEM) Orienting Profile ,166L2: D-sand Window at +/- 4799' MD, 72 deg 3-1/2" bent joint and guide 4-1/2" 12.6# slotted and blank liner shoe 4796' MD - 4-1 /2" X 7-5/8" Model 'B' HOOK Hanaer - - 1E-166L2: - 3-1/2" Liner Shoe @ 9402' ~, MD, 3258' TVD 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs Lateral Entrv Module (LEM) Assembly _5-1/2 X 7-5/8 ZXP Liner Top Packer w/ Hold Downs 5030' MD-Casing Sealbore Rece~ptac~le '~` Casing Sealbore .-- Receptacle - 4.75" ID j f Tubing Swivel, 4-1/2" ~/ Orienting Profile f Positive Latching Collet '- Seal Bore for Lateral Isolation - 3.68" ID .~ Access Window Positive Lateral Access Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 5063' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanaer ConocoPhillips West Sak 1 E-166 Producer Tri-Lateral Completion 5128' MD - 3.562" DB Nipple 5-112" X 7-5/8" ZXP Liner Top Packer with Hold Downs 5346' MD -Bottom of Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral Eauipment Specifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +/- 18.5' 5-1 /2" X 7-518" Flex Liner Hanger /Packer ~ - Lock / 4-1/2" 12.6# slotted and blank liner Assembly Top at ~ ~ ~ Liner Hanger +/- 5302' MD ___, 5335' MD-Casing Sealbore Receptacle Casing, 7-5/8" 29.7#, L-80, ewer H ne: xaoa, rma exvmem m,r nm ba repraavaa a, asmbaroe. m wnoH or m BTCM, Set @ +/- 6014' MD, 3502' a9 pan, m any roan or by any means Necoanic or mecbanical, inclutling pMlocopying, recording, or by any information storage TVD and rMieval system ,mw Mnovm or meaner inventM, wlnmut vainen permission bom Baker Hugbes Inc. ' MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) Orienting Profile 'B' Sand Lateral 'Jars ma or deep BAKER XIIGIIES Aakcr (al Tnols As Completed Late ral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drifq (2.50" ID Mainbore Drift) 'GS' Profile (or Coil Connector (Running/Retrieving -~ + (1.00' Length) I I Snap InlSnap Out .Back Pressure Valve ' r'Poskive Locating ~-- (7.60' Length) Collet Lateral Isolation -- r Flow-Thru Swivel Seals j (7.25' Length) f Lateral Diverter Hydraulic ~ Ramp ' ' Disconnect Isolation/ Mainbore _ (7.50' Length) Diverter Sleeve _- - GS Spear _ " • ' (1.60' Length) Lateral Isolation' i.86 ft Approx. ~ Seals L_~ ~~ OAL' Length 18.5' Sleeve Length 166L1: B-sand Window at +/- 5068' MD, 82 deg 3-1 /2" bentjoint and guide 4-1/2" 12.6# slotted and blank liner shoe ___ -r _ ~ 1E-166L1: - -_-~'~~ 3-1/2"Liner shoe@9380' MD, 3329' TVD 1E-166: 4-1 /2" Liner shoe @ 9596' MD, 3518' TVD 200a -1 E-186 TdJateral Completlon -Producer January ]0, 2009 Drawn By: Ian Toomey aeviaion th.: RWO Completed ConocoPhillips ,11,t~;1 It 1~: HEAT TRACE, GAS GAS NIPPLE. LOCATOR, !685 SEAL ASSY. O,w/ D SAND WINDOW. 0,7994,811 D~SAND LEM, ~ 67]-5.031 Sbb,~ 5,090-9,300 B-SAND LINER, 5063-9,390 TO (1E-i66L1), 9.071 KUP ~ 1 E-166L1 Well Attributes Max An le & MD TD Welltrore API/UWI Field Name 500292322060 WEST SAK Well Shtua PROD Protl/In1 Type Inc! (°) 92.85 MD (RKB) 7,117 Act Btm (RKB) 9,423 Comment SSSV: NIPPLE R23 (ppm) Data Annotation Last WO: End Data KBrird (R) 2/9/2009 35.29 Rig fteleaae Date 9/24!2004 Annotation Last Tag: Depth (/tl(B) End Dob Annotation Rev Reason: Workover, Pull RHC Ball/Rod, GLV C/O End Date 2/17/2009 Casin Strin s Casing Oeacrlptlon String 0.. BSAND LINER 4 1/2 . String ID ... 3.958 Top (RKB) Set Depth ((... Sat Depth (TVD) .. String Wt... String ... String Top Thrd 5,063 9,380 3,331.2 29.70 L-80 DWC Liner Details Top (RKB) Top Depth (TVO) (RKB) Top Inel (°) I tem Deacripib n Comment 10 (In) 5,063 3,342.4 78.10 H ANGER BAKER MODEL B-1 FLANGED HOOK HANGER 4.500 Perfora tions S Slots Top (RKB) Btm (ftKB) Top (TVD) (RKB) Btm (TVD) (RKB) Zona Date Shot Dens Ian... Type Comment 5,090 9,340 3,347.5 3,332.3 WS B, tE-166L7 9/17/2004 32.0 Slots Slotted Liner, 2.5"Lx.125'W, in 4 circumferential rows Notes: Gene ral & Safe End Data Annotation 11/17/2005 NOTE: WOR KOVER TO R ECONNECT ESP CABLE - NO OTHER CHANGES 2/1 712 0 0 9 NOTE: VIEW SCHEMATI C wlAlaska Schematic9.0 2117/2009 NOTE: WOR KOVER TO C ONVERT FROM ESP TO GAS LIFT Mandrel Details Stn Top (RI(B) Top Depth (TVD) IRKB7 Top Inc! I°) Maka Model OD (Inl Serv Valve Typa LatcR Typa Port Sizs tin) TRO Run (psi) Run Date Comm... 1 3,029 2,403.7 48.13 Camco KB G-2-1R 1 GAS LIFT GLV _- BK 0.185 1,494.0 2/1412009 21 -1.543 3.194E a,rl d ~ 'Camro KBC=2-1R 1 ~ '. GAS LIFT ' ~ pV _ 'EK I 0.3131 00 121412009 t • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, March 25, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: - 6 -1 i~ -~~~o ~ ~~y 1~~ Attachments: 1 E-166 Addendum to 10-404.pdf Tom, Attached is the pre and post rig work summaries and a better schematic. I only included the pre-rig work relevant to the workover. Let me know if you'd like more detail. Thanks, 7 Brett Packer ~DriR"ng 8C'WeU"s ry `Won~yver Engineer ~~ ~ ~ A~ ~', ~ ~° `Wo~k# (907 265-6845 CeIC# (907 230-8377 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:06 PM To: Packer, Brett B Subject: 1E-166 (204-153) Bret, I am reviewing the 404 for the recent workover on this well and have some requests. 1. Please send a copy of the pre and post rig work. 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 1E-166? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 3/25/2009 • r~ €>vs ~ `~ STATE OF ALASKA ` lV~,~e~ ,~ ~d~9 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION$r~~~ ~~ ` -=^'=' ,R., a~frurdssioln 1. Operations Pertormed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ Other ° re3 ~ Alter Casing ^ Pull Tubing Q . Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ Exploratory ^ 204-154 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-166L1 ` 8. Property Designation: 10. Field/Pool(s): ADL 25651, 25660 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 9423' • feet true vertical 3330' ~ feet Plugs (measured) Effective Depth measured 9378' feet Junk (measured) true vertical 3330' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2984' 10-3/4" 3012' 2393' INTERMEDIATE 5986' 7-5/8" 6014' 3502' SLOTTED LINER 4316' 4.5" 9379' 3330' LEM ASSEMBLY 335' 4.5" 5345' 3362' Perforation depth: Measured depth: slots from 5090'-9340' true vertical depth: 3347'-3332' Tubing (size, grade, and measured depth) tubing in main wellbore, L-80, 4712' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 509' 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 SI -- Subsequent to operation SI ' -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 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 P ack er @ 26 -6845 5 Printed Name Brett r _ ~ - ~ ~- ~ ~ ~ Title Wells Engineer 3~Sr~~ y ~~ '~" " '~/ v Signature Phone: 265-6845 Date C Pre ared b h n All u Drake 263-4612 Form 10-404 Revised 04/2006 `~'~ ~`° ' fi'. -, ,j .. ~~-*G:y ,. , ' ~ ~~t~ `~ ~F Z~~C' ~~j Submit riginal Only ~1~~~ 'Nalco Gray Hanger, 11" X 4-1/2"'Conductor, 20" X 34" Insulated, set at 108' MD. Tubing String: 4-1/2" 12.6#, L-80, IBTM 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4543' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R %~ 4625' MD - 3.812" DB Nipple ~~ ~ 4632' MD -Guardian Gauge Carrier Heat Trace Cable to 3024' MD MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs 96' MD -Casing Sealbore Receptacle 4.75" ID 4712' MD -Bottom of Seal Assembly 4.75" Seal OD 10-3/4" Casing Shoe, 45.5/40.5#, L-80, BTC set @ 3012' MD, 2393' TVD 4796' MD - 4-1 /2" X 7-5/8" Model 'B' HOOK Hanoer 4752' MD - 3.75" DB Nipple conocorni~i~ps West Sak 1 E-166 Producer Tri-Lateral Completion RWO 09 'D' Sand Lateral 4788' MD -Lateral Entry Module (LEM) Orienting Profile /166L2: D-sand Window at +/. 4799' MD, 72 deg 3-1/2" bent joint and guide ~_ 4-1/2" 12.6# slotted and blank liner / shoe 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs Lateral Entrv Module (LEM) Assembly 5-112 X 7-5/8 ZXP Liner Top Packer w/ Hold Downs Casing Sealbore .--Receptacle - 4.75" ID ~ Tubing Swivel, 4-1/2" ~ Orienting Profile f Positive Latching Collet `- Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Seal Bore for Lateral Isolation - 3.68" ID ~ Isolation Seal Asembly 4.75" Seal OD 5030' MD-Casing Sealbore Receptacle 5063' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanoer 5-1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs 5-1/2" X 7-518" Flex ~\ Liner Hanger /Packer Lock ~ Assembly Top at Liner Hanger / +/- 5302' MD 5335' MD-Casing Sealbore Receptacle e.s.. 11u91rc toot. rnlt a«vmmr mar rant es .rproa«sa n. a.:n~evne, In wnek a M pmt. ~n .nr mm, ., ev ,nv me.n..tr<non,< e, m.<n.nKa. ~«mem9 vnoro<ovrm9..r<e,em9, er I+v •nv mremnrven ae..9e and renmvM syatwn mw Yrwrm or I,ere.per,nvmtM..wawul rmnen p-rmis.ion M1om B.Fer Mug.e. Inc. 'A' Sand Undulatina Lateral Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 6014' MD, 3502' TVD. 4-112" 12.6# slotted and blank liner 1E-166: 4-1/2" Liner shoe @ 9596' MD, 3518' TVD 200d-1E-169 Trlaat<ral Cempledon -producer January ta, 2009 RWO Completed 1E-166L2: 3-1/2" Liner Shoe @ 9402' MD, 3258' TVD ' MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) `~ Orienting Profile 'B' Sand Lateral 166L1: B-sand Window at +/- 5068' MD, 82 deg 4-112" 12.6# slotted and blank liner3-1/2" bent joint and guide _ / shoe 5128' MD - 3.562" DB Nipple sat ilnw~s It.7kcr Oil Tools As Completed Later al Entrv Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter OS Running Tool String Installed Instilled (7.00" Lateral Drift) (2.50" ID Mainbore Drilq 'GS' Prorile for -coil Connector ~ I ~Running/Retrieving~ ~ i (1.00'Length) I 1 ~ Snap In/Snap Out ~6ack Pressure VaWe f Positive Locating ti ryso• Length) covet ~ I ~ Lateral Isolation - r Flow-Thro Swivel Seals (125' LengM) ~ Lateral Diverter ''~ Hydraulic ' Ramp ' Disconne<t ~ I Isolation/Mainbore 11.50' Length) llll~~~~llll r Diverter Skeve GS Spea 1.60' LengM) ~~ ~~ LMeral Isolation - : 6.65 ft Approx. Seals OAL' `i ~ -Jars may be required in highly deviated I, ~ or deep applications I6' epprox length). 18.5 Diverter Length 10.5' Sleeve LengM 1E-166L1: 3-1/2" Liner shoe @ 9380' MD, 3329' TVD Equipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.83" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.69" Diverter and Sleeve Length: +/- 18.5' 5346' MD -Bottom of Seal Assembly 4.75" Seal OD ,, KUP ~ 1 E-166L1 i,..t}n~~P~C~~~p~ ~ ~ ~ Well Attributes ~ Maz An le & M D TD „M~,.,, I W-II~r r:i Fwid :~~u" _ -,wen its[ r-dnn'7 na l-t MDl~bl ~ u t YPe Act Brm lfottl) .,, i 500292322060 WEST SAK ~ -F ,PROD 92.85 7,117 9,423 C mem H25 m (PP ) ---- Date Annotaton End Date KB-Grd Itt) Rig Release Date NIPPL SSS E '' O. 2/9 009 35.29 Last W 9/24/2004 I .~„.. ,~ ~ ~ r . Annotation Depth IrdcB) End Date - 'Annotation End Date _ _ ~ Last Tag: ~~?ev Reason: Workover, Pull RH(' Rall/Rod, GLV C/O 2117/2009 I I Casing Strings ~~as a u.-s. ~F~~~~ ~ ,~~,<i ~~ 5~~~~y io 7,~F nre, s~~ r~Nm ir. s~~i c ,.m ~ n~Fn Si~~w rn_.. ~~~<i .~,~~~~ r~,i, rn,a i • Well Date Event Descri tion 1 E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w~ FAILED. LDS FUNCTION TEST -PASSED. a 1E-166 2!5/09 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 1E-166 2!6/09 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor,. flush IA ~ with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and strap in o derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to Y 264'. 0 1E-166 2/7!09 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', ~ POOH, MU and RIH with LEM assembly to 4,774' ~ 1E-166 2/8/09 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, M monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3 992'. ~ , O 1E-166 2/9109 Locate SBE, confirm seals in place, space out, drop ballJrod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawaterJKCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2/10109 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, mov rig off 1E Pad. 1 E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ ~ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ COMPLETE. ~ N O a • Con©c©Phillips Time Log & Summary WelNtesv Web Reporting Report Well Name: 1 E-166 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/5/2009 9:00:00 AM Rig Release: 2/10/2009 3:00:00 AM Time Logs Date __ From To Dur S Depth E_._Depth_ P_ h_ase _ Code S_ ubcode T Co_ _mment 2/05/2009 24 hr summary Nordic Rig 3 accepted onto 1 E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 07:30 09:00 1.50 0 0 COMPZ RPCOM MOB P Set up double stack of rig mats. Move rig over 1 E-166 Accept Nordic Rig 3 at 9:00 am on 2-5-2009. 09:00 10:00 1.00 0 0 COMPZ RPCOM RURD P RU hardline, tiger tank and berm. 10:00 11:30 1.50 0 0 COMPZ RPCOM MPSP P PU lubricator and pull BPV. 11:30 14:00 2.50 0 0 COMPZ RPCOM RURD P Rig up to kill well. Off load fluids to pits. Test lines to 2000 psi. Crane on location, load ESP spool onto rig floor. 14:00 17:00 3.00 0 0 COMPZ RPCOM KLWL P Initial well pressures T/I/O = 80/840!150 psi. Bleed down tubing and IA. Pump 90 bbl down the tubing at 5 bpm - 80 psi, and 200 bbl down the IAat 5 bpm - 90 psi. Well is on a vacuum, shut in and monitor well. 17:00 18:00 1.00 0 0 COMPZ RPCOM OTHR P Blow down and RD circ lines, install BPV. 18:00 19:00 1.00 0 0 COMPZ RPCOM NUND P ND tree, install test dart. 19:00 22:00 3.00 0 0 COMPZ RPCOM NUND P Nk1 13 5/8" BOP. 22:00 00:00 2.00 0 0 COMPZ RPCOM BOPE P RU and test ROPE at 250/2,500 psi on chart. Witness of BOP test waived by AOGCC Rep Bob Noble on 2-5-09 at 18:00 hrs. 2/06/2009 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and stra in derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to 264'. 00:00 03:30 3.50 0 0 COMPZ RPCOM BOPE P Cont testing BOPE at 250/2,500 psi on chart. 03:30 05:30 2.00 0 0 COMPZ RPCOM OTHR P RD test equipment, pull test dart, un-chain stands of 3 1/2 in derrick and shuffle to off-side. 05:30 06:30 1.00 0 0 COMPZ RPCOM RURD P Pull BPV, install isolation sleeve, MU landin 'nt and circ hose, BOLD's. Page 1 of 4 C~ • Time Logs - _-_ _-- _ Date ____ From To Dur S_De~th E. De th Phase Cod_e___ Subcode T Comment __ _ 06:30 08:30 2.00 0 0 COMPZ RPCOM CIRC P Pull hanger to rig floor, pump 150 bbls hot sea-water/KCL down IA to clean tb and a ui ment. 08:30 13:30 5.00 4,468 0 COMPZ RPCOM PULL P Pull completion standing back 4 1/2" tbg. Spool ESP cable, pumping 50 bbls Hr for well control.- Recovered All (76) Cannon clamps, (2) Flat guards, (3) Protectolizers, and (10) Bands. Missing (1) door off a protectolizer, but screw was in place. All equipment shafts rotated freely. Oil in the Tandem Seals and Motor were all clean and clear. Cable and Motor Test good. Procedure showed we should recover 15 Bands but 5 where removed during previous operation to connect the enetrators. 13:30 15:30 2.00 0 0 COMPZ RPCOM PULL P Rig down and lay down ESP motor. 15:30 16:00 0.50 0 0 COMPZ RPCOM EQRP P Install wear Ring. 16:00 17:00 1.00 0 564 COMPZ RPCOM PULD P RU Snozzelators BHA on 3 1/2" DP. 17:00 19:00. 2.00 564 4,726 COMPZ RPCOM TRIP P RIH with Snozzelator on 3 1/2" DP to 4,726', up weight 95K, down weight 69K. 19:00 21:00 2.00 4,726 5,046 COMPZ RPCOM CIRC P Warm up top drive quill and grease washpipe, MU top drive and wash down from 4,726' to 5,046', pumping at 8 bpm - 3,000 psi down tbg, 6 bpm down IA. Had no trouble going in and out of hook han er. 21:00 21:30 0.50 5,046 5,046 COMPZ RPCOM OWFF P Blow down top drive while monitoring well, well on vac. 21:30 00:00 2.50 5,046 264 COMPZ RPCOM TRIP P POOH with cleanout assembly standing back 3 1/2" DP from 5,046' to 264'. 2/07/2009 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', POOH, MU and RIH with LEM assembl to 4,774' 00:00 01:30 1.50 264 0 COMPZ RPCOM PULD P Cont POOH LD cleanout assembly. 01:30 03:30 2.00 0 607 COMPZ RPCOM PULD P MU 4 1/2" seal assembly (4.76" seals) BHA for dumm run. 03:30 06:00 2.50 607 4,790 COMPZ RPCOM TRIP P RIH with seal assembly BHA on 3 1/2" DP to 4,790' and MU top drive, u wei ht 95K, down wei ht 70K. 06:00 07:00 1.00 4,790 5,046 COMPZ RPCOM DHEO P Made numerous attempts to pass through hook hanger but tagging up at 4,813'. Rotated and reciprocated string and finally passed through hook han er to a de th of 5,046'. 07:00 12:00 5.00 5,046 0 COMPZ RPCOM TRIP P POOH from 5,046' and LD dummy run BHA. 12:00 14:00 2.00 0 0 COMPZ RPCOM OTHR P RU crane remove ESP cable and s ool from floor 14:00 17:00 3.00 0 461 COMPZ RPCOM TRIP P Pick up LEM BHA, perform shallow MWD test GOOD. Page 2 of 4 s s Time Logs __ Date From To Dur S. De th E. De t_h Phase Code Subcod e _ T Comment 17:00 22:00 5.00 461 _ 4,774 COMPZ RPCOM _ __ TRIP _ P RIH with LEM on 3 1/2" DP, 30 FPM, filling hole @ 50 bph for well control, to 4,774', up weight 95K, down wei ht 75K. 22:00 00:00 2.00 4,774 4,774 COMPZ RPCOM DHEQ P Break circ at 3 bpm - 600 psi to orient LEM assembly to 16 degrees left of hi hside. 2/08/2009 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 1/2" as lift com letion to 3,992'. 00:00 01:00 .1.00 4,774 5,034 COMPZ RPCOM OTHR P Wash down to 5,034' mule shoe depth, passing through hook hanger with no problem, re-oriented LEM and latched ZXP at 4 degrees left of highside, un-latched with 20K over pull (115K) slacked off and latched into hook hanger again at 4 degrees left of hi hside. 01:00 02:00 1.00 5,034 5,034 COMPZ RPCOM PACK P Dropped 1 3/4" ball and pumped down string at 1 bpm, seated ball, pressured up to 2,000 psi to activate pusher tool and set ZXP, cont pressure up to 3,200 psi with test um and neutralized usher tool. 02:00 03:00 1.00 5,034 5,034 COMPZ RPCOM PRTS P Fill la with 8.8ppg sea-water/KCL, close upper pipe rams, pressure up on IA to 2,500 psi and test 7 5/8" csg x ZXP packer for 5 minutes on chart, good test. Blled off IA and pull settin tools from ZXP. 03:00 03:30 0.50 5,034 5,034 COMPZ RPCOM OWFF P Blow down top drive, monitor well for 15 minutes, fluid level in IA dropped out of sight, no indication of gas bubble. 03:30 09:30 6.00 5,034 0 COMPZ RPCOM PULD P POOH LD 3 1/2" DP filling hole with 50 b h. 09:30 10:30 1.00 0 0 COMPZ RPCOM RGRP P Slip and cut drill line. 10:30 12:00 1.50 0 0 COMPZ RPCOM RURD P RU sheaves, spools and rig floor to run 4 1/2" com letion. 12:00 00:00 12.00 0 3,992 COMPZ RPCOM RCST P MU seal assembly and gauge carrier, splice Tec wire to gauge, RIH with 4 1/2" SCC completion to 3,992', checking electrical integrity of heat trace and Tec wire every 1,000', filling hole 50 bph. Up weight 80K, down wei ht 63K. 2/09/2009 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze rotect well, allow to u-tube. 00:00 02:30 2.50 3,992 4,717. COMPZ RPCOM RCST P Cont RIH with 4 1/2" SCC gaslift completion from 3,992', locate SBE, no- o'd at 4,717', set down 10K. 02:30 03:30 1.00 4,712 4,699 COMPZ RPCOM HOSO P Loaded IA with 8.8 seawater/KCL to surface, fluid level holding. Pulled up hole 18' drag dropped 5K, fluid level dro ed out of si ht. Page 3 of 4 ~~ Time Logs Date From To Dur S: Depth E. Depth Phase Cade Subcode T Comment 03:30 04:30 1.00 4,699 4,688 COMPZ RPCOM HOSO P Space out completion with a 2' space out, MU hanger and landing 'nt. 04:30 06:00 1.50 4,688 4,688 COMPZ RPCOM OTHR P MU heat trace and Tec wire splices and tested both. (Waiting on correct enetrator! 06:00 07:30 1.50 4,688 4,688 COMPZ RPCOM CIRC P Pump 150 bbls inhibited seawater/KCL (1 % CRW-132) followed by 40 bbls clean seawater/KCL down IA. 07:30 09:00 1.50 4,688 4,712 COMPZ RPCOM HOSO P Lowered hanger down thru stack and landed. RILDS. 90K up wt 65 dwn wt. Tested tubing hanger Orings to 5000 si. 09:00 10:30 1.50 4,712 4,712 COMPZ RPCOM DHEQ P Dropped ball and rod. With annulus open, pressure test tubing to 3000 psi monitoringJA for returns. Bleed down tubing to 1750 psi. Pressure up an IA to 3000 psi for 30 min on chart. Bled pressure off IA, bled pressure off tubing. Ramp up pressure on IA and sheared SOV @ 4543' w/1300 si. 10:30 15:00 4.50 4,712 4,712 COMPZ RPCOM NUND P Back out landing jt. and wash out BOP stack. Drain stack and lay down landing jt. Remove side port isolation sleeve from hanger. Install two-way check. ND BOPE. Replace HCR valve. Lift off BOP stack. 15:00 17:00 2.00 4,712 4,712 COMPZ RPCOM DHEQ P Meggar heat trace thru penetrator. Make final connection and final electrical test on TECH wire. RD s oolers. 17:00 21:00 4.00 4,712 4,712 COMPZ RPCOM NUND P NU tree, heat trace penetrator leaked, removed tree, replaced o-ring on penetrator, installed tree, tested at 250/5,000 psi, good test, pull two wa check. 21:00 23:00 2.00 4,712 4,712 COMPZ RPCOM FRZP P PJSM with LRS personell, test manifold and circ lines at 250/2,500 psi, good test, freeze protect well with 130 bbls diesel down IA at 2 b m, 800 si ICP - 1,000 si FCP. 23:00 00:00 1.00 4,712 4,712 COMPZ RPCOM RURD P Allow well to u-tube, warm up move system, move mudshack and tanks for ri move. 2/10/2009 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1 E-166, clean out cellar box, move ri off 1 E Pad. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD P Blow down and RD circ lines, set BPV, install guages and secure tree, SITP = 0, IA = 0, OA = 180 si. 01:30 03:00 1.50 0 0 DEMOB MOVE DMOB P PJSM, back rig off well site, move mats, clean cellar box and well site. Nordic Rig 3 Released at 03:00 hrs on 2/10/2009. Page 4 of 4 • .,::. ,_.~ `° ..~._ .~ ;;.° =n -_~' ry ~~ ~:_ ..- ~~, ;:. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc ~ '-'( D~ ^~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041540 Well Name/No. KUPARUK RIV U WSAK 1E-166L1 Operator CONOCOPHILLlPS ALASKA INC )¡;4.¿ /3 J:.,f~y API No. 50-029-23220-60-00 MD 9423 ..--- TVD 3330 ----- Completion Date 9/24/2004 ".- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR ? RES Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No I ~ Directional Survey At Directional Survey ~ 13116 Induction/Resistivity 25 Blu M-Þ ~ 13116 Induction/Resistivity 25 Blu ')1/1> ~ Lis 13116 Induction/Resistivity 25 Rpt 13116 LIS Verification ~/ 13118 Induction/Resistivity 25 Blu t'-D ~C Lis 13118 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional Survey Yes ---~ (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 5068 8941 Open 1 0/13/2004 PB1 8664 9423 Open 10/13/2004 108 9423 Open 5/9/2005 Multiple Propagation Resistivity.GRrwd,mwd 108 9423 Open 5/9/2005 Multiple Propagation Resistivity, GR rwd, mwd 108 9423 Open 5/9/2005 Multiple Propagation Resistivity, GR rwd,mwd 108 9423 Open 5/9/2005 Multiple Propagation Resistivity, GR rwd, mwd 108 8941 Open 5/9/2005 Multiple Propagation Resistivity Gamma Ray/MWD/ PB1 108 8941 Open 5/9/2005 Multiple Propagation Resistivity Gamma Ray/MWD/ PB1 . . Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041540 Well Name/No. KUPARUK RIV U WSAK 1E-166L 1 Operator CONOCOPHILLlPS ALASKA INC MD 9423 TVD 3330 Completion Status 1-01L Current Status 1-01L Completion Date 9/24/2004 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ Received? Daily History Received? fbN ~/N Formation Tops Comments: ~_..__.- Compliance Reviewed By: po Date: API No. 50-029-23220-60-00 UIC N ~-----:-~~~- / l D-1l~Ç---- . . . STATE OF ALASKA . R f::!VËD WELL COMPL~~I~~IL~~ ~~~~~~v~~~~o~ RE'~~R,oc;[tM t~h Oil [2] Gas U Plugged 0 Abandoned 0 Suspended U WAG 0 ßI";'~Ht. WÅI{.ðlfS's~' CÜi,;" COnml¡S5¡~n 20AAC25,105 20AAC25,110 Developmèræ';@ZJU(3 Exploratory 0 No, of Completions _ Other SelVice 0 Stratigraphic Test 0 12, Permit to Drill Number: 1a, Well Status: GINJ 0 o WDSPL 0 WINJ 2, Operator Name: ConocoPhillips Alaska, Inc, 3. Address: p, 0, Box 100360, Anchorage, AK 99510-0360 4a, Location of Well (Govemmental Section): Surface: At Top Productive Horizon: 147' FNL, 640' FEL, Sec. 21, T11N, R10E, UM 2485' FSL, 1151' FWL, Sec. 22, T11N, R10E, UM Total Depth: 21, Logs Run: GRlRes 22. CASING SIZE WT, PER FT. 62.5# 45,5# 29.7# 12,6# 12,6# GRADE H-40 L-80 L-80 L-80 L-80 20" X 34" 10.75" 7-5/8" 4,5" 4,5" 5959440 5956805 5952509 / Zone-4 Zone- 4 Zone-4 5, Date Comp" Susp" ¡,. or Aband,: September 24,2004 204-154 I 6. Date Spudded: ", )P 13, API Number: September)';" 2004 to' ,1'Þ'f 50-029-23220-60 I 50-029-23220-70 7, Date TD Reached: 14, Well Name and Number: September 16, 2004 ~ 1E-166L1 I1E-166L1PB1 8, KB Elevation (It): 15, FieldlPool(s): 28' RKB Kuparuk River Field 9, Plug Back Depth (MD + TVD): West Sak Oil Pool 9378' MD I 333()' TVD 10, Total Depth (MD + TVD): 9423' MD I 333()' TVD / 11, Depth where SSSV set: none 19, Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3012' 28' 2393' 28' 6014' 28' 3502' 5063' 9379' 3342' 3330' 5010' 5345' 3331' 3362' 23, Perforations open to Production (MD + TVD of Top and Bottom IntelVal, Size and Number; if none, state 'none"): slots in lower 'B' liner from: 5090'-9340' MD 3347'-3332' TVD 1810' FNL, 1113' FWL, Sec, 27, T11N, R10E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 549890 ( y- TPI: x- 551704 y- Total Depth: x- 551704 y- 18. Directional SUlVey: Yes [2] NoU 26, Date First Production October 12, 2004 Date of Test Hours Tested 10/15/2004 Flow Tubing not available 27. 6 hours Casing Pressure not available Test Period --> Calculated 24-Hour Rate -> 24, SIZE 4,5" 16, Property Designation: ADL 25651 & 25660 17, Land Use Permit: ALK 469 & 470 20, Thickness of feet MSL Permafrost: 1630' MD .-r"1 ,c.J &ooh.~ S- ð(. 8 ' "" þ . 5"¡3 "TVI> AO 'Þ-I"'~ AMOUNT PULLED HOLE SIZE 13,5" 9-7/8" 6.75" CEMENTING RECORD 42" 317sxASI 520 sx AS Lite, 181 sx DeepCrete 320 sx DeepCrete slotted liner LEM assembly 41 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", Form 10-407 Revised 12/2003 NONE TUBING RECORD DEPTH SET (MD) 4470' PACKER SET 5302' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 10 WATER-BBL r - ët\¡:~~·;;·r;, :;¡'C!(;~""""~ l-i~~~ \. ; ~\'r;ø" ,.;, ¡ '.~J;¡' ! '",."1- i ¡ .....-..::::.:;_1 CONTINUED ON REVERS~~ CHOKE SIZE 33 Bean OIL GRAVITY - API (corr) not available IGAS.Oll RATIO 617 PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc,) Production shared with 1 E-166 and 1 E-166L2 Production for OIL-BBL GAS-MCF WATER-BBL 1077 736 OIL-BBl GAS-MCF 4185 2582 CORE DATA G~ /(BJJ1J5 GEOLOGIC MARKERS . 29, ... FORMATION TESTS 28, NAME MD TVD Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None", 1 E-166L 1 West Sak B 5066' 3343' N/A E!VE OCT 1 9 2004, 1E-166L1 PB1 TO 8941' 3328' Com" fmGnorage 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 McKeever @ 265-6826 Printed Name Randv Thomas Signature ~ ~ Title: rhone Kuparuk Drillina Team Leader Date ,1... ((9/0C( Prepared by Sharon AlIsùp-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 1 0-407 Revised 2/2003 ORIGINAL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: Slip and cut 104' of drlg line and serviced top drive MU 13 1/2" BHA #1, Bit, bit sub and 1-NM flex DC, tagged ice in conductor at 55' Flooded conductor checking for leaks Repaired Willis choke and Demco valve on standpipe Re-Ieveled sub over hole Cleaned out inside conductor from 55' to 108' Drilled 13 1/2" hole from 108' to 310' (202') ART 2 Hrs POOH MU 13 1/2" BHA #2 with MWD, oriented and uploaded same, RIH to 310' RU HES slickline unit for Gyro Drilled 13 1/2" hole per directional plan from 310' to 1,390' MD/1,327' rvD (1,080'), ART 2,4 hrs, AST 4.9 hrs, 20-35K wob, 50 rpm's, 450-530 gpm, 1,200 psi -1,700 psi, rot wt 90K, up wt 95K, dn wt 85K, torque Off btm -0-, on btm 4K ft-Ibs, took Gyro survey's for check shots at 375' and 560' and ck ok, RD slickline at 940' 5,25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 1,390' to 1,947' MD/1,704' TVD, (557'), ART 1,6 hrs, AST 2.0 hrs, 10-30K wob, 50 rpm's, 550 gpm, off btm pressure 1,400 psi, on btm 1,750 psi, off btm torque 2.5K ft-Ibs, on btm 4.5K ft-Ibs, rot wt 92K, up wt 100K, dn wt 85K, pumped 1 weighted hi vis sweep and had 20% increase in cuttings back Pumped out of hole from 1,947' to HWDP at 1,113', pumped out at 500 gpm at 1 ,400 psi POOH standing back HWDP and BHA #2, drained 1.8 deg bend mud motor and LD same MU BHA #3 with 1.3 deg bend motor jetted for 700 gpm, oriented MWD and RIH with HWDP then MU 13 1/2" ghost reamer, RIH to 1,119' RIH to 1,861', washed 86' to btm at 1,947' with no problems Circ btms up after trip, circ out a large amount of clay and sand Drilled 13 1/2" hole per directional plan from 1,947' to 3,020' MD/2,398' TVD, (1,073'), (Csg Pt), ART 4,2 hrs, AST ,6 hrs, 10-30K wob, 100 rpm's, 700 gpm, off btm pressure 2,300 psi, on btm 2,400 psi, off btm torque 7K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt 132K, dn wt 85K, pumped weighted hi vis sweep on last std, no gas hydrates in surface hole *** Note** After conferring with town the new surface TD was picked @ 2400' TVD +/- 8/31/2004 12:00 - 14:30 2.50 MOVE DMOB MOVE 14:30 - 17:00 2,50 MOVE MOVE MOVE 17:00 - 18:00 1.00 MOVE RURD MOVE 18:00 - 20:00 2.00 WELCTL NUND SURFAC 20:00 - 22:00 2.00 DRILL OTHR SURFAC 22:00 - 00:00 2,00 DRILL PULD SURFAC 9/1/2004 00:00 - 01 :45 1.75 DRILL PULD RIGUP 01:45 - 02:15 0.50 WELCTL BOPE RIGUP 02:15 - 03:45 1.50 RIGMNT RSRV RIGUP 03:45 - 04:30 0.75 DRILL PULD SURFAC 04:30 - 05:00 0,50 DRILL CIRC SURFAC 05:00 - 06:15 1,25 RIGMNT RGRP SURFAC 06:15 - 07:00 0.75 RIGMNT OTHR SURFAC 07:00 - 07:30 0.50 DRILL CIRC SURFAC 07:30 - 10:15 2,75 DRILL DRLG SURFAC 10:15 - 10:45 0.50 DRILL TRIP SURFAC 10:45 - 13:00 2,25 DRILL PULD SURFAC 13:00 - 13:30 0,50 LOG RURD SURFAC 13:30 - 00:00 10,50 DRILL DRLG SURFAC 9/2/2004 00:00 - 05:15 05:15 - 06:15 1.00 DRILL TRIP SURFAC 06:15 - 08:45 2,50 DRILL PULD SURFAC 08:45 - 10:15 1,50 DRILL PULD SURFAC 10:15-11:00 0.75 DRILL TRIP SURFAC 11 :00 - 12:00 1,00 DRILL CIRC SURFAC 12:00 - 19:00 7.00 DRILL DRLG SURFAC Rig down and moved rig off 1 E-126 Spot sub, rig complex's, rock washer and pipe sheds on 1E-166, moved rig 1,080' from 1 E-126 to 1 E-166 Finished rigging up service lines and completed rig acceptance check list ACCEPTED RIG @ 18:00 hrs 8/31/04 NU 21 1/4" 2M diverter and 16" line and began mixing spud mud Loaded pipe shed with 5" DP & HWDP, continued mixing spud mud and changed out saver sub on top drive PU and stood back 16 stds of 5" DP Fin PU & standing back 21 stds of 5" DP, PU & Stood back 10 stds of 5" HWDP and jars Function tested diverter, John Spaulding WAOGCC waived witnessing test Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/2/2004 9/3/2004 Fin circ out weighted hi vis sweep, circ at 700 gpm at 2,200 psi and 100 rpm's, had 35% increase in cuttings back from sweep Monitored well-static Backreamed out of hole at drlg rate from 3,020' to 1,119', at Ghost reamer and BHA #3, LD ghost reamer, no problems backreaming out POOH wet with HWDP to 200', stood back HWDP and Cleared rig floor, RU to LD BHA #3 LD BHA #3, 3-63/4" NMCSDP, short NMDC, stab, MWD, drained and LD motor, cleared rig floor Began RU to run 10 3/4" csg when hydraulics went out on top drive Trouble shoot loss of hyd. power to top drive, changed out relief valve and hyd, pump to top drive, changed out lower set of 5" pipe rams on BOP's to 7 5/8" csg rams Fin RU Doyons 10 3/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of csg MU 103/4" float shoe, 2 jts 103/4" 45,5# L~80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 1,003' Circ btms up at 1,003', circ at 2 bpm at 325 psi, st wt up 73K, dn wt 60K, circ out thick mud with sand and clay RIH with 103/4" csg to 2,007' Circ btms up at 2,007', circ at 2 bpm at 325 psi, st up wt 118K, dn wt 86K RIH with 103/4" csg, MU hanger and landed csg with float shoe at 3,012' MD/ 2,393' TVD, float collar at 2,925', no problems RIH, Ran a total of 20 jts (798') of 40.5# L-80, BTC csg above shoe track and a total 53 jts (2,177') of 45,5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 2,982', ran 52 bow spring centralizers and 21 stop rings per well plan Circ btms up thru fill up tool and began cond mud for cementing, staged pump rate up to 6 bpm at 300 psi, st wt up 155K, dn wt 100K RD Franks fill up tool and MU Dowell's cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 325 psi, reciprocating pipe with 160K up wt and 1 05K dn wt, circ and cond mud to 9.4 ppg and lower PV/yP to <15 Fin circ and conditioning mud for cementing, final MW in & out, 9.4 ppg, 44 vis, 12 PVand 15 YP, circ at 6 bpm at 325 psi, st wt up 160K dn wt 105K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ, 2.00 CEMENT PUMP SURFAC Turned over to Dowell and cemented 103/4" csg, pumped 10 bbls of CW 100 at 8,3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush,dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 412 bbls (520 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, followed with 80,5 bbls (181 sxs) of DeepCrete tail cmt at 12,0 ppg and 2.48 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full returns, shut down and dropped top plug 1.00 CEMENT DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 262 bbls of 9.4 ppg mud, displaced cmt at 6 bpm, initial circ pressure 350 psi, max pressure 700 psi, slowed rate to 3,5 bpm and bumped plug on calc displacement, pressured up to 1,400 psi, checked floats and held, CIP @ 03:20 hrs, had full returns during 19:00 - 19:30 0.50 DRILL CIRC SURFAC 19:30 - 19:45 0.25 DRILL OBSV SURFAC 19:45 - 22:30 2,75 DRILL REAM SURFAC 22:30 - 00:00 1.50 DRILL TRIP SURFAC 00:00 - 01 :45 1.75 DRILL PULD SURFAC 01 :45 - 02:30 0.75 CASE RURD SURFAC 02:30 - 12:00 9,50 RIGMNT RGRP SURFAC 12:00 - 12:45 0,75 CASE RURD SURFAC 12:45 - 13:00 0.25 CASE SFTY SURFAC 13:00 - 15:45 2.75 CASE RUNC SURFAC 15:45 - 16:15 0.50 CASE CIRC SURFAC 16:15 - 17:30 1,25 CASE RUNC SURFAC 17:30 - 18:45 1.25 CASE CIRC SURFAC 18:45 - 20:15 1,50 CASE RUNC SURFAC 20:15 - 21:30 1.25 CEMENTCIRC SURFAC 21:30 - 22:15 0.75 CEMEN1 RURD SURFAC 22:15 - 00:00 1.75 CEMENTCIRC SURFAC 9/4/2004 00:00 - 00:30 0.50 CEMENTCIRC SURFAC 00:30 - 02:30 02:30 - 03:30 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: job and had 110 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:45 hrs, 70 bbls into displacement, approx 275 bbls lead cement out of shoe RU and tested 103/4" csg to 2,500 psi for 30 min, good test RD cement head, LD landing jt and cleared rig floor ND 21 1/4" diverter, starting head and 16" diverter line NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 15 min. NU 13 3/8" BOP stack NOTE: Had 4 bbl spill at injection skid, mud was spilled into secondary containment and immediately cleaned up RU to test BOPE Began to test BOP's and door seal on blind rams leaked, re-tightened and continued to leak, remOved choke line hose and changed out door seal on off drillers side, rigged back up and refilled choke manifold and stack 4,75 WELCTL BOPE SURFAC Tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,000 psi high, annular to 250 psi low and 1,500 psi high John Spaulding W/AOGCC waived witnessing of test Installed wear bushing Began changing over top drive to 4" XT-39 DP, changed out saver sub Finished changing over top drive to 4" XT-39 DP, changed pipe grabbers and pipe guide PU 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' Circ thru 4" DP and displaced out 9.4 ppg mud in hole to re-condtioned 9.0 ppg LSND mud POOH standing back 4" DP PU an additional 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' POOH standing back 4" DP RU and LD 2 stds of 5" DP from derrick MU 9 7/8" BHA #4 with 1.1 deg bend mud motor, and MWD, oriented and uploaded MWD, RIH with HWDP and jars, MU ghost reamer RIH to 1,110' RIH with BHA #4 from 1,110' to 2,871' with 5" DP, changed over to 4" DP Circ and tested MWD, staged pump rate to 510 gpm at 1,325 psi and tool ck ok Fin displacing out 9.4 ppg mud with re-conditioned 9,0 ppg LSND mud, circ at 530 gpm at 1,500 psi, rot wt 98K, up wt 130K, dn wt 78K Drilled out plugs, float collar at 2,925', shoe jts and float shoe at 3,012', drilled 20' of new formation to 3,040' MD/2,411' TVD, drilled with 5K wob, 50 rpm's, 530 gpm at 1,500 psi Circ hole clean evening MW in and out at 9.0 ppg for LOT, circ at 530 gpm at 1,500 psi RU and performed LOT to 13,4 ppg EMW, 550 psi, 9.0 ppg mud at 2,393' TVD Drilled 9 7/8" hole per directional plan from 3,040' to 3,809' MD/2,870' TVD, (769'), ART 2,1 hrs, AST 2.6 hrs, 5-15K wob, 100 rpm's, 155 spm, 657 gpm, off btm pressure 2,250 psi, on btm 2,450 psi, off btm torque 5-12K ft-Ibs, on btm 7-1 OK ft Ibs, rot wt 103K, up wt 145K, dn wt 79K, clean hole ECD with 9,0 ppg MW = 9.4 ppg, ECD with 9,0 ppg MW 9/4/2004 02:30 - 03:30 1.00 CEMENTDISP SURFAC 03:30 - 04:15 0.75 CASE DEQT SURFAC 04:15 - 05:15 1.00 CASE RURD SURFAC 05:15 - 09:00 3,75 WELCTL NUND SURFAC 09:00 - 10:30 1,50 WELCTL NUND SURFAC 10:30 - 13:30 3.00 WELCTL NUND SURFAC 13:30 - 14:45 1,25 WELCTL BOPE SURFAC 14:45 - 17:30 2.75 WELCTL EQRP SURFAC 17:30·22:15 22:15·22:45 0.50 DRILL RIRD SURFAC 22:45 - 00:00 1,25 DRILL RIRD SURFAC 9/5/2004 00:00 - 01 :30 1,50 DRILL RIRD SURFAC 01 :30 - 03:45 2,25 DRILL PULD SURFAC 03:45 - 04:30 0.75 DRILL CIRC SURFAC 04:30 - 05:15 0,75 DRILL TRIP SURFAC 05:15 - 07:00 1.75 DRILL PULD SURFAC 07:00 - 07:30 0.50 DRILL TRIP SURFAC 07:30 - 08:00 0,50 DRILL PULD SURFAC 08:00 - 12:00 4,00 DRILL PULD SURFAC 12:00 - 13:00 1.00 DRILL TRIP SURFAC 13:00 - 13:15 0,25 DRILL DEOT SURFAC 13:15 - 13:45 0,50 DRILL CIRC SURFAC 13:45 - 15:00 1,25 CEMENT DSHO SURFAC 15:00 - 15:30 0.50 DRILL CIRC SURFAC 15:30 - 16:15 0.75 DRILL LOT SURFAC 16:15 - 00:00 7,75 DRILL DRLG INTRM1 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/512004 16:15 - 00:00 7.75 DRILL DRLG INTRM1 while drlg ave 9.65 ppg 9/6/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 3,809' to 5,023' MDI 3,331' TVD, (1,214') ART 5,2 hrs, AST 2,5 hrs, 5-30K wob, 100 rpm's, 155 spm, 655 gpm, off btm pressure 2,700 psi, on btm 3,000 psi, off btm torque 5-11K ft-Ibs, on btm 7-10Kft-lbs, rot wt 98K, upwt 145K, dn wt 76K, 9.2 ppg MW, ave ECD 10,4 ppg, max ECD 10.9 ppg, pumped weighted hi vis sweep at 4,276' and had 30% Increase In cuttings Est Top of West Sak "D" at 4,798' MDI 3,280' TVD, No BGG was seen until drilling "D" sand, Max gas from "D" sand 1 ,500 units 12:00 - 23:00 11.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 5,023' to 6,020' MDI 3,503' TVD, (997') ART 5.7 hrs, AST 1.8 hrs, 5-30K wob, 100 rpm's, 155 spm, 655 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 9K ft-Ibs, on btm 11 K ft-Ibs, rot wt 94K, up wt 135K, dn wt 72K, 9.2 ppg MW, ave ECD 10.4 ppg, max ECD 10,7 ppg, pumped 1-weighted hi vis sweep at 5,180' with 5% Increase in cuttings and 1 at 5,985' with 10% increase in cuttings Est Top of West Sak "B" at 5,067' MDI 3,343' TVD, Ave BGG while drilling 300-400 units, Max gas from "B" sand 2,700 units 23:00 - 00:00 1.00 DRILL REAM INTRM1 Backreamed out of hole at drilling rate from 6,020' to 5,494' with no problems 9m2004 00:00 - 03:30 3.50 DRILL REAM INTRM1 Backreamed out of hole from 5,494 to 4,185' at drlg rate till ghost reamer was at csg shoe, backreamed at 100 rpm's, 655 gpm at 3,000 psi, with no problems, pumped out of hole to csg shoe at 3,012' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean at 3,012' (csg shoe), circ at 575 gpm at 1,700 psi and 40 rpm's, had 5% increase in cuttings from sweep, circ 3X btms and clean at shakers, rot wt 95K, up wt 11 OK, dn wt 95K 04: 15 - 04:30 0,25 DRILL OBSV INTRM1 Monitored well-static 04:30 - 05:00 0.50 DRILL TRIP INTRM1 POOH wet from 3,012' to 2,875', hole taking proper fill, pumped dry job and changed over handling tools to 5" DP 05:00 - 06:30 1.50 DRILL PULD INTRM1 POOH LD 56 jts of 5" DP to 1,110' (BHA) 06:30 - 09:30 3,00 DRILL PULD INTRM1 POOH LD, 5" HWDP, jars and ghost reamer, downloaded MWD and LD BHA #4 09:30 - 10:00 0.50 DRILL PULD INTRM1 Pulled wear bushing, cleared rig floor 10:00 -11:45 1.75 CASE RURD INTRM1 RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool 11 :45 - 12:00 0,25 CASE SFTY INTRM1 Held PJSM on running of 7 5/8" csg 12:00 - 17:00 5.00 CASE RUNC INTRM1 RIH with 7 5/8", 29.7#, L-80, BTC-M csg to 2,100', MU 75/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ck ok, RIH with 47 add, jts along with pup jts for spacing out to 2,100' 17:00 - 18:00 1.00 CASE CIRC INTRM1 Circ a csg cap at 2,100', staged pump rate up to 3112 bpm at 275 psi, circ out thick mud, st wt up 124K, dn wt 47K 18:00 - 19:30 1.50 CASE RUNC INTRM1 RIH with 75/8" csg from 2,100' to 2,984 19:30 - 20:00 0.50 CASE CIRC INTRM1 Circ a csg cap at 10 3/4" csg shoe, staged pump rate up to 4 bpm at 350 psi, st up wt 156K, dn wt 45K 20:00 - 23:30 3.50 CASE RUNC INTRM1 Fin RIH with 75/8" csg, RIH to btm with no problems In open hole, MU hanger and landed 7 5/8" csg at 6,014' MDI 3,502' TVD with float collar at 5,927', ran a total of 140 jts 75/8",29,7#, L-80 BTC-M csg with 3-pup jts and hanger (Total 5,987') 23:30 - 00:00 0,50 CASE CIRC INTRM1 Began circ and conditioning mud for cementing, circ thru Franks fill up tool, staged pump rate up to 5 bpm at 525 psi, st wt up 175K, dn wt 77K 9/8/2004 00:00 - 00:30 0,50 CEMENTCIRC INTRM1 Fin circ btms up thru Franks fill-up tool while conditioning mud, staged pump rate to 6 bpm at 550 psi, st wt up 175K, dn wt 77K Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/812004 00:30 - 01 :00 0.50 CEMENT RURD INTRM1 LD Franks fill up tool and MU Dowell's cement head 01 :00 - 03:15 2.25 CEMENTCIRC INTRM1 Cont to circ and cond mud for cementing, circ at 6 bpm at 500 psi, st wt up 190K, dn 80K, conditioned mud from 9,3 ppg, 58 vis, 21YP, 18 PV to 9.2 ppg, 50 vis, 17 yp, 15 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ 03:15 - 04:15 1.00 CEMENT PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 20 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 128 bbls, (320 sxs) of DeepCrete cmt at 12.5 ppg, 2,26 yield with additives, ave 6 bpm at 250 psi, reciprocated pipe with full returns, shut down, washed up and dropped btm plug 04:15 - 05:15 1,00 CEMENT DISP INTRM1 Rig displaced cement with 8,8 ppg OBM, bumped plug after pumping 271.3 bbls OBM (95% pump eft.) (Calc Disp 272.5 bbls) ave 7 bpm while displacing cmt, max pressure 1,000 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 05:00 hrs, reciprocated pipe until 50 bbls of cement was around shoe when hole began getting tight and stopped reciprocating, est TOC @ 3,600' 05:15 - 06:00 0,75 CEMENTRURD INTRM1 RD cement head and LD landing jt 06:00 - 07:30 1.50 WELCTL EQRP INTRM1 Installed 7 5/8" pack-oft and tested to 5,000 psi fðr 15 min 07:30 - 08:00 0.50 DRILL PULD INTRM1 Installed wear bushing 08:00 - 08:45 0,75 DRILL RIRD INTRM1 RD 7 5/8 csg equipment, elevator bales and cleared rig floor 08:45 - 10:45 2.00 RIGMNT RSRV INTRM1 Slip & cut 65' of drlg line and serviced top drive. R/U hardline on 10-3/4" x 7-5/8" annulus. PT to 1,500 psi, OK. Pump 15 bbls water @ 1,100 psi 2 BPM. SID 800 psi. 10:45 - 12:30 1.75 DRILL PULD INTRM1 PU and stood back in derrick 9 stds 4" push pipe 12:30 - 14:15 1,75 DRILL PULD INTRM1 MU BHA #5, 4 3/4" mud motor with 1,2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 256' 14:15 - 16:30 2,25 DRILL PULD INTRM1 RIH with BHA #5 PU 4" XT-39 DP from pipe shed, RIH to 3,030' 16:30 - 17:00 0,50 DRILL DEOT INTRM1 Shallow tested MWD at 3,030',300 gpm at 1,480 psi and ck ok, st wt up 75K, dn wt 65K 17:00 -19:30 2.50 DRILL PULD INTRM1 Cont to RIH with BHA #5 PU 4" DP from pipe shed, RIH to 5,486', PU a total of 186', RIH from 5,486' to 5,926' from derrick and tagged up on plugs above float collar at 5,925' 19:30 - 20:00 0,50 DRILL CIRC INTRM1 Circ btms up for csg test evening MW in & out at 8.8 ppg, 300 gpm at 1,900 psi, st wt up 99K, dn wt 69K 20:00 - 21 :00 1,00 CASE DEOT INTRM1 RU and tested 7 5/8" csg to 2,500 psi for 30 min 21:00 - 22:15 1.25 CEMENT DSHO INTRM1 Drilled out cmt plugs, float collar at 5,925', soft cement inside shoe track, float collar at 6,014' then drilled 20' of new formation from 6,020' to 6,040' MDI 3,503' TVD, ADT .1 hrs,4-6K wob, 40-60 rpm's, 300 gpm at 2,100 psi, rot wt 80K, up wt 105K, dn wt 67K 22:15 - 23:00 0.75 DRILL CIRC INTRM1 Circ hole clean for LOT, circ at 300 gpm at 1,850 psi 23:00 - 00:00 1.00 DRILL FIT INTRM1 RU to perform LOT, pressured up on well to 1,300 psi and shut down for FIT, at 1,300 psi, 8,8 ppg mud at 3,502' = 15,9 ppg EMW FIT 9/9/2004 00:00 - 02:30 2,50 DRILL DRLG PROD Drilled 6 3/4" hole from 6,040' to 6,236' MD/3,547' TVD, (196'), ART.6 hrs, AST ,7 hrs, 10K wob, 80 rpm's, 296 gpm, oft btm pressure 1,850 psi, on btm 2,000 psi, oft btm torque 3K ft-Ibs, on btm 4K, rot wt 82K, up wt 108K, dn wt 68K NOTE: Flushed 75/8" x 10 3/4" annulus with 150 bbls fresh water then freeze protected with 100 bbls diesel 02:30 - 02:45 0,25 DRILL CIRC PROD Circ hole to est cleanhole ECD, with 8,8 ppg OBM cleanhole ECD was 10,2 ppg NOTE: While circ, determined internal scribe line correction was not Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 8/31/2004 9/24/2004 Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/9/2004 02:30 - 02:45 0.25 DRILL CIRC PROD made in the MWD tool, scribe line correction was to be 94 deg. causing well to get off directional plan. To drill ahead we would cross 1 E-35 hard line and decision was made to shut in well and set tbg plug in well 1 E-35 before drlg ahead 02:45 - 03:00 0.25 DRILL TRIP PROD POOH from 6,236' to 6,014' to 7 5/8' csg shoe 03:00 - 12:00 9.00 WAlTON EalP PROD Called out HES slickline, worked pipe and circ often inside csg while W.O, slickline, production shut down injection on 1 E-35 well and HES Slickline RIH and set plug in tbg at 11,114' 12:00 - 12:15 0,25 DRILL TRIP PROD RIH from 6,014', washed 96' to btm at 6,236' with no problems 12:15 - 18:00 5,75 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 6,236' to 6,701' MD/ 3,504' (465') ART -0-, AST 3,8 hrs, 4-15K wob, -0- rpm's, 75 spm, 318 gpm, off btm pressure 2,225 psi, on btm 2,400 psi, off btm torque 4K, on btm 6K ft-Ibs, rot wt 80K, up wt 115K, dn wt 55K, 8,8 ppg OBM, ECD while sliding 9.9 ppg 18:00 - 19:00 1,00 DRILL CIRC PROD Circ hole evaluating geological and directional options, circ at 318 gpm at 2,225 psi, found to have drilled out the top of zone, decision was made with town to drill back into zone and continue drilling, clean hole ECD while circ was 10,2 ppg with 8,8 ppg OBM 19:00 - 00:00 5.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 6,701' to 7,134' MD/ 3,511' (433') ART 1 hr, AST 1.9 hrs, 2-5K wob, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,250 psi, on btm 2,400 psi, off btm torque 4K, on btm 5K ft-Ibs, rot wt 75K, up wt 115K, dn wt 60K, 8,9 ppg OBM, Ave ECD 10.6 ppg 9/10/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 7,134' to 8,103' MD/ 3,536' TVD, (969') ART 3,6 hrs, AST 4,1 hrs, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 5K ft-Ibs, on btm 5,5K ft-Ibs, rot wt 80K, up wt 115K, dn wt 56K, 8.8 ppg OBM, aye ECD 10.4 ppg, max ECD 10,8 ppg, aye BGG 75 units, max gas 450 units 12:00 - 18:00 6,00 DRILL DRLG PROD Drilled from 8,103' to 8,680' MD/ 3,501' TVD, (577') ART 3,1 hrs, AST ,8 hr, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,475 psi, on btm 2,575 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 123K, dn wt 46K, 8,9 ppg OBM, aye ECD 10,7 ppg, max ECD 11.1 ppg, aye BGG 50 units, max gas 200, pumped wt'd hi vis sweep at 8,640' and had 25% increase in cuttings back from sweep 18:00 - 19:30 1.50 DRILL CIRC PROD Troubleshoot MWD not decoding, checked mud pumps screens and pulsation dampners and slowed data rate on MWD and tool ck'd ok, problem occured before and after pumping wt'd sweep 19:30 - 00:00 4.50 DRILL DRLG PROD Drilled from 8,680' to 9,032' MD/ 3,497' TVD, (352') ART 1,8 hrs, AST 1 hr, 2-6K wOb, 120 rpm's, 318 gpm, off btm pressure 2,550 psi, on btm 2,675 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 117K, dn wt 57K, 8.8 ppg OBM, aye ECD 10,9 ppg, max ECD 11.1 ppg, aye BGG 30 units, max gas 100 units, began PU 4" pushpipe at 8,941' 9/11/2004 00:00 - 08:45 8.75 DRILL DRLG PROD Drilled 6 3/4" hole from 9,032' to 9,602' MD/ 3,518' TVD, (570') (T.D.) ART 4.5 hrs, AST 1 hr, 2-5K wob, 120 rpm's, 318 gpm, off btm pressure 2,825 psi, on btm 3,000 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 95K, up wt 131 K, dn wt 74K, 8.8 ppg OBM, aye ECD 10,9 ppg, max ECD 11.1 ppg, aye BGG 50 units, max gas 100 units, pumped weighted hi vis sweep on last std 08:45 - 09:30 0.75 DRILL CIRC PROD Circ weighted hi vis sweep out of hole, had 15% increase in cuttings back from sweep, circ at 318 gpm, 2,825 psi at 120 rpm's 09:30 - 09:45 0,25 DRILL OBSV PROD Monitored well-static 09:45 - 16:00 6,25 DRILL REAM PROD Backreamed out of hole at drlg rate from 9,602' to 5,950', ( Csg Shoe) Printed: 10111/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/11/2004 09:45 - 16:00 6.25 DRILL REAM PROD circ at 318 gm, 100-120 rpm's, initial circ pressure 2,825 psi, final circ pressure 2,375 psi, no problems backreaming out 16:00 - 17:30 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean at 5,950', circ at 318 gpm at 2,000 psi, had 10% increase in cuttings back from sweep, circ 1.5x btms up and clean at shakers, rot wt 79K, up wt 113K, dn wt 56K, 5,5K ft-Ibs torque 17:30 -18:00 0.50 DRILL OBSV PROD Monitored well-static, dropped 1 7/8" rabbit and pumped dry job 18:00 - 21 :30 3.50 DRILL TRIP PROD POOH from 5,950' to BHA #5 at 256', SLM, no corr, retrieved rabbit 21 :30 - 23:30 2.00 DRILL PULD PROD POOH and stood back HWDP and jars, downloaded MWD, LD MWD and motor, cleaned rig floor 23:30 - 00:00 0,50 CASE RURD CMPL TN RU to run 4 1/2" liner 9/12/2004 00:00 - 00:15 0,25 CASE SFTY CMPL TN Held PJSM with rig crew on running liner 00:15 - 04:45 4,50 CASE PULR CMPL TN PU and ran 4 1/2" liner per well program, ran 4 1/2" ROT silver bullet guide shoe with no float, 125 jts, (4,237') of 41/2" 12,6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 76 jts (2,360') of blank liner and 49 jts (1,873') of slotted liner, ran 1- 4 1/2" x 6 1/4" spiralglide centralizer 1/jt to csg shoe (105 total) ran 15 restrictor packers with 30 spacer rings placed on blank liner to isolate shale sections per geology. 04:45 - 06:00 1,25 CASE PULR CMPL TN MU Baker 190-47 csg seal bore ex!, 5 1/2" x 7 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 4,298' 06:00 - 09:00 3,00 CASE RUNL CMPL TN RIH with 41/2" Liner on 5" DP to 5,900', had to screw into each std to keep from running over 09:00 - 09:15 0.25 CASE CIRC CMPL TN Circ a DP cap at 7 5/8" csg shoe, circ at 170 gpm at 250 psi, rotated liner, with pumps on rot wt 75K, up wt 77K, dn wt 73, rotated at 20 rpm's at 2-3K ft-Ibs torque, pumps off st wt up 85K, dn wt 65K 09:15 - 13:30 4.25 CASE RUNL CMPL TN RIH with liner from 5,900' to 9,596' liner setting depth with no problems in open hole, st wt up 120K, dn wt 75K 13:30 - 14:00 0,50 CASE OTHR CMPL TN Dropped 1/34" ball and pumped down to seat, pump at 2 bpm at 510 psi, with ball on seat pressured up to 3,500 psi to set Flexlock hanger, bled off the pressure, cont to set packer, worked 45K wt down and packer didn't set, rotated 20 rpm's with 3K ft-Ibs torque and set ZXP packer, set st wt down several times to ensure packer set, no other problems setting hanger/packer, set "A" sand liner with TaL @ 5,302' and shoe at 9,596', st wt up after setting liner 110K, dn wt 86K 14:00 - 14:15 0,25 CASE DEQT CMPL TN RU & tested 7 5/8" csg and ZXP packer to 1,500 psi for 10 min, good test 14:15 - 14:45 0.50 DRILL OBSV CMPL TN Monitored well-static, pumped dry job 14:45 - 18:00 3.25 DRILL TRIP CMPL TN POOH and LD Baker liner setting tool, cleared rig floor 18:00-21:45 3.75 WINDOWPULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 6 jts of 3 1/2' DP for space out and 7 5/8" Baker btm trip whipstock, milling assembly with LWDIMWD, uploaded MWD and oriented BHA #6, TIH with 4" HWDP to 1,250' 21:45-22:15 0.50 WINDOWOTHR CMPL TN Shallow tested MWD at 1,250' at 300 gpm, 1,000 psi and tool ck ok 22:15 - 00:00 1.75 WINDOwrRIP CMPLTN RIH with whipstock assembly, BHA #6 from 1,250' to 3,306' 9/13/2004 00:00 - 00:45 0,75 WINDOwrRIP CMPL TN RIH with whipstock from 3,306' to 4,626' 00:45 - 01 :15 0.50 WINDOWOTHR CMPL TN Made MADD pass from 4,626' to 4,654' and correlated MWD to K-13 sand 01 :15 - 02:00 0,75 WINDOwrRIP CMPL TN RIH with whipstock from 4,654' to 5,269' 02:00 - 02:15 0,25 WINDOWSETW CMPL TN Oriented whipstock to 15 deg left of high side, tagged TOL at 5,302', set whipstock and sheared off from same, st wt up.1 02K dn wt 71 K 02:15 - 05:15 3,00 WINDOWSTWP CMPL TN Milled window in 7 5/8" csg, top of window at 5,068', btm of window at Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/13/2004 02:15 - 05:15 3,00 WINDOWSTWP CMPL TN 5,080', drilled 6 3/4" hole to 5,100' MD (32'), 2-6K wob, 60-80 rpm's, 250-270 gpm, 1,450 psi, rot WI 75K, up WI 102K, dn WI 71 K, 6-8K ft-Ibs torque 05:15 - 06:15 1.00 WINDOWCIRC CMPL TN Circ hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ at 270 gpm at 1,450 psi, worked mills thru window with no problem 06: 15 - 06:30 0.25 WINDOWOTHR CMPL TN Monitored well-static, pumped dry job 06:30 - 10:30 4,00 WINDOWTRIP CMPL TN POOH and LD milling assembly, upper mill in gauge, cleared rig floor 10:30 - 12:30 2,00 WELCTL OTHR CMPL TN Pulled wear bushing and flushed out BOP stack, re-installed wear bushing 12:30 - 14:00 1.50 DRILL PULD PROD2 MU 6 3/4" BHA #7, 1,2 deg 4 3/4" motor, MWD/LWD/PWD, oriented and uploaded MWD, RIH to 257' 14:00 - 14:30 0,50 DRILL TRIP PROD2 RIH with BHA #7 from 257' to 2,500' 14:30 - 14:45 0,25 DRILL DEOT PROD2 Shallow tested MW D at 2,500', 297 gpm at 1 ,525 psi, tool checked ok, st WI up 67K, dn 62K 14:45 - 16:00 1,25 DRILL TRIP PROD2 RIH with BHA #7 from 2,500' to 5,017' 16:00 - 17:30 1,50 RIGMNT RSRV PROD2 Slip and cut 47' of drlg line, serviced top drive and drawworks 17:30 -17:45 0,25 DRILL CIRC PROD2 Oriented BHA and RIH thru window from 5,068' to 5,080' with no pumps or problems, washed and reamed undergauge hole from 5,082' to btm at 5,100', string up WI 90k, dn WI 70K 17:45 - 20:30 2,75 DRILL DRLG PROD2 Drilled 6 3/4" hole from 5,100' to 5,207' MDI 3,355' TVD, LWD tool failed, ART 1,2 hrs, AST .4 hrs, 5-12K wob, 90 rpm's, 70 spm, 297 gpm, off btm pressure 1,850 psi, on btm pressure 2,150 psi, off btm torque 3.5K ft-Ibs, on btm 4K, rot WI 78K, up WI 89K, dn WI 69K 20:30 - 21 :45 1,25 DRILL TRIP PROD2 Backreamed out from 5,207' to window, took several attempts then pulled BHA thru window, 21:45-22:15 0,50 DRILL CIRC PROD2 Circ btms up at 5,022',297 gpm, 1,850 psi and 80 rpms 22:15 - 22:30 0,25 DRILL OBSV PROD2 Monitored well-static, pumped dry job 22:30 - 00:00 1.50 DRILL TRIP PROD2 POOH from 5,022' to 1,846' to change out LWD tools 9/14/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD2 POOH fl 1,846' to bit. 01 :00 - 02:30 1.50 DRILL TRIP PROD2 Inspect bit, Down load MWD tools, Change out LWDI MWD tools and program same. 02:30 - 06:00 3.50 DRILL TRIP PROD2 Surface test tools, RIH & orient thru window @ 5,080'. 06:00 - 07:45 1.75 DRILL TRIP PROD2 Madd pass fl 5,105' to 5,206'. 07:45 - 00:00 16.25 DRILL DRLH PROD2 Drill 6-3/4" hole fl 5,206' to 6,888' MDI 3,357' TVD (1,682'), ART = 9.5 hrs, AST= 1.7 hrs, WOB 2/12K, RPM 80/120, 320 gpm @ 2250 psi, UP 101K, DN 63K, ROT 78K, TO 5500 Wlbs ON I 5500 Wlbs OFF, Ave, ECD's 10.4 ppg wI 8.9 ppg mud, Max gas 854 units, Ave gas 110 units. 9/15/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 6-3/4" hole fl 6,888' to 8,009' MDI 3,345' TVD (1,121'), ART= 4.8 hrs, AST= 3.0 hrs, WOB 2/1 OK, RPM 120, 320 gpm @ 2375 psi, UP 105K, DN 55K, ROT 77K, TO 6000 Wlbs ON I 6000 ft/Ibs OFF, Ave. ECD's 10,6 ppg wI 8,9 ppg mud, Max gas 178 units. 12:00 - 19:15 7.25 DRILL DRLH PROD2 Drill 6-3/4" hole fl 8,009' to 8,941' MDI 3,329' TVD (1,932'), ART = 4.0 hrs, AST = 1,5 hrs, WOB 2/6K, RPM 90/120, 320 gpm @ 2750 psi, UP 111 K, DN 51 K, ROT 75K, TO 6500 Wlbs ON I 6500 Wlbs OFF, Ave. ECD's 10.9 ppg wI 8,9 ppg mud, Max gas 207 units, 19:15 - 20:00 0.75 DRILL TRIP PROD2 Circ evaluate logs for side track, POOH to 8,658' 20:00 - 00:00 4.00 DRILL DRLH PROD2 Orient and side track to low side of hole fl 8,663' to 8,860' MDI 3,339' TVD, ART= 1.0 hrs, AST= 1,0 hrs, WOB 2/7K, RPM 90/120, 330 gpm @ 2700 psi, UP 120K, DN 45K, ROT 76K, TO 6000 Wlb ON I 6500 Wlb OFF, Ave ECD's 10.9 ppg wI 8.9 ppg mud, 9/16/2004 00:00-01:15 1,25 DRILL DRLH PROD2 Orient and side track to low side of hole fl 8,860' to 8,941' MDI 3,340' TVD, ART = 0,5 hrs, AST = 0.25 hrs, WOB 2/12K, RPM 90/120, 330 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/16/2004 00:00-01:15 1,25 DRILL DRLH PROD2 gpm @ 2750 psi, UP 11 OK, DN 57K, ROT 78K, TO 7000 ftl b ON I 6500 ftl b OFF, Ave ECD's 10.9 ppg wi 8.9 ppg mud. 01:15 - 05:30 4.25 DRILL DRLH PROD2 Drill 6-3/4" hole fl 8,941' to 9,423' MDI 3,329' TVD (482'), ART == 2,9 hrs, AST== .25 hrs, WOB 2/12K, RPM 90/120, 320 gpm @ 2900 psi, UP 119K, DN 66K, ROT 92K, TO 6500 ft/lbs ON 16500 ftl bs OFF, Ave. ECD's 11.0 ppg wi 8.9 ppg mud, Max gas 108 units, Pump Hi-vis weighted sweep on last connection. 05:30 - 06:45 1.25 DRILL CIRC PROD2 Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cuttings, 06:45 - 13:15 6.50 DRILL TRIP PROD2 Monitor well, Back ream out of hole at drilling rate- 320 gpm @ 2900 to 1850 psi, 100 RPM, Pulling rate 40/45 ft/min, No problems- hole in good shape, No problems going thru window @ 5,080' to 5,068', 13:15 - 14:30 1.25 DRILL CIRC PROD2 Pump Hi-vis sweep and circ hole clean wi 3 times btm's up at rate of 320 gpm @ 1850 psi, Monitor well, Pump dry job, 14:30 - 18:00 3,50 DRILL TRIP PROD2 POOH, Stand back HWDP, Jars, NMDC's, Lay down Bit & Motor, Down load & lay down MWD tools, Clear rig floor. 18:00-21:45 3,75 WINDOWTRIP CMPL T2 Make up Baker whipstock retrieving tools, Pick up 11 jts. 4-3/4" DC's, 1 jt HWDP, RIH to 5,073', 21 :45 - 23:30 1.75 WINDOWCIRC CMPL T2 Wash & Work whipstock retrieving tool several times and latch onto whipstock on depth @ 5,073' (whipstock slot), Jar loose wi 80K over pull. 23:30 - 00:00 0,50 WINDOWTRIP CMPL T2 Pull and stand back 1 stand drill pipe & single. 9/17/2004 00:00 - 00:30 0,50 WINDOWCIRC CMPL T2 Circ btm's up at rate of 5 bpm @ 900 psi. 00:30 - 02:30 2.00 WINDOWTRIP CMPL T2 Monitor well, POOH slow to 4,400' due to swabbing & Work pipe to make well take proper fill- well finally began taking proper fill, Pump dry job, Drop rabbit. 02:30 - 07:30 5.00 WINDOWTRIP CMPL T2 POOH, Lay down whipstock and tools, Clear rig floor. 07:30 - 12:00 4,50 CASE PULR CMPL T2 Rig & run 4-1/2"liner, Pick up Baker B1 Flanged Hook Hanger. 12:00 - 13:00 1,00 CASE RUNL CMPL T2 RIH wi liner on drill pipe to window & work thru same, Made it thru window on second try, 13:00 - 16:00 3.00 CASE RUNL CMPL T2 RIH wi liner on drill pipe with no problems, Shoe @ 9,379' 16:00 - 17:30 1.50 CASE CIRC CMPL T2 Hook hanger at bottom of window @ 5,080' wi Top of liner @ 5,063.13' and Shoe @ 9,379.68', Drop ball, Circ, ball did not seat, drop 2nd 29/32" ball, cir. Ball did not seat. Drop1-3/4" ball, Pressure up and release running tool. Reverse circ and recover ball at surface. 17:30 - 18:00 0,50 CASE CIRC CMPL T2 Rig & reverse circ out ball. 18:00 - 22:00 4.00 CMPL TN TRIP CMPL T2 Monitor well, Pump dry job, POOH & lay down liner running tools, 22:00 - 00:00 2.00 CMPL TN PCKR CMPL T2 Rig & run LEM assembly, 9/18/2004 00:00 - 05:00 5.00 CMPL TN PCKR CMPL T2 RIH wi LEM assembly to 5,345' wi top @ 5,010', Latch and pull test LEM to 10K over. 05:00 - 05:45 0.75 CMPLTN PCKR CMPL T2 Drop ball, Pressure up to 3000 psi & Set ZXP Packer, Increase pressure to 4400 psi to lease fl LEM & neutralize push tool, Close Hydril & test annulus to 1500 psi f/5 min.- OK. 05:45 - 08:15 2.50 CMPL TN CIRC CMPL T2 Stand back 1 stand, Rig & attempt to shear out ball wi 6000 psi - No good, Rig & reverse circ ball out of pipe at rate of 3,5 bpm @ 700 psi. 08:15 - 12:30 4,25 CMPLTN TRIP CMPL T2 Monitor well, Pump dry job, POOH & lay down LEM running tool. 12:30 - 17:00 4.50 WELCTL BOPE CMPL T2 Pull wear bushing, Rig & test BOPE to 250 psi low & 3000 psi High, Test witnessed by AOGCC Jhon Crisp, Install wear bushing. 17:00 - 19:00 2,00 WINDOWPULD CMPL T2 Make up 'D' Lateral whipstock & mill assembly, Orient & Make up MWD, 19:00 - 23:00 4.00 WINDOWTRIP CMPL T2 RIH slow wi whipstock assembly to 4,330'. 23:00 - 23:30 0.50 WINDOWCIRC CMPL T2 Madd pass & log fl 4,330' to 4,360', 23:30 - 00:00 0,50 WINDOWTRIP CMPL T2 Continue RIH to 4,962', Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/19/2004 00:00 - 00:15 0.25 WINDOWSETW CMPL T2 Orient whipstock 16 deg, Left, Tag top of liner wI No-Go @ 5,010' & Seals @ 5,014', Set trip anchor, Shear off fl bolt wI top of whipstock @ 4,799', 00:15 - 04:45 4.50 WINDOWSTWP CMPL T2 Mill window fl 4,799' to 4,811', Mill guage mill out window with btm. mill @ 4,830', WOM 2/4K, 80 RPM, 270 gpm @ 1750 psi, TQ 5/9,000 Wlb. 04:45 - 05:30 0,75 WINDOWCIRC CMPL T2 Pump Hi-vis weighted sweep & ream out window. 05:30 - 09:30 4,00 WINDOWTRIP CMPL T2 Monitor well, Dry pipe, POOH & Lay down mill assembly (All mills in guage). 09:30 - 10:30 1,00 WELCTL CIRC CMPL T2 Pull wear bushing, Wash out stack, Reinstall wear bushing, 10:30 - 12:00 1.50 DRILL PULD PROD3 Make up BHA #11, Orient tools, Program MWD/LWD. 12:00 - 14:00 2.00 DRILL TRIP PROD3 RIH to 2,100', Shallow test MWD tools, RIH to 4,740', 14:00 - 15:00 1,00 RIGMNT RSRV PROD3 Cut & slip drilling line 61', 15:00 - 15:30 0,50 DRILL REAM PROD3 Orient motor, Slide thru window fl 4,799' to 4,811' with no problem, Wash to 4,830', 15:30 - 00:00 8,50 DRILL DRLH PROD3 Drill 6-314" hole fl 4,830' to 5,673' MDI 3,300' TVD (843'), ART = 3,8 hrs, AST = 1,9 hrs, WOB 2/5K, RPM 90, 300 gpm @ 1800 psi, UP 98K, DN 66K, ROT 78K, Torque 4000 Wlbs ON 16500 ft/Ibs OFF, Ave. ECD's 10,0 ppg wI 8,9 ppg mud, Max gas 744 units, 9/20/2004 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drill 6-314" hole fl 5,673' to 6,608' MDI 3,290' TVD (935'), ART = 7,5 hrs, AST= 1.1 hrs, WOB 2/12K, RPM 90/120, 300 gpm @ 2000 psi, UP 102K, DN 63K, ROT 77K, Torque 6000 Wlbs ON I 6000 Wlbs OFF, Ave, ECD's 10.4 ppg wI 8,9 ppg mud, Max gas 586 units, 12:00 - 00:00 12,00 DRILL DRLH PROD3 Drill 6-3/4" hole f/6,608' to 8,075' MD/3,284' TVD (1,467'), ART = 8,6 hrs, AST= 0,5 hrs, WOB 2/6K, RPM 90/100, 310 gpm @ 2100 psi, UP 115K, DN 53K, ROT 76K, Torque 7000 Wlbs ON 17000 Wlbs OFF, Ave, ECD's 10,5 ppg wI 8,9 ppg mud, Max gas 541 units, 9/21/2004 00:00 - 03:15 3,25 DRILL DRLH PROD3 Drill 6-3/4" hole f/8,075' to 8,380' MDI 3,280' TVD (305'), ART = 2,0 hrs, AST = 0.0 hrs, WOB 2/12K, RPM 100/120, 310 gpm @ 2450 psi, UP 112K, DN 52K, ROT 76K, Torque 7000 Wlbs ON I 7000 Wlbs OFF, Ave, ECD's 10.5 ppg wI 8.9 ppg mud, Max gas 664 units. 03:15 - 04:15 1.00 RIGMNT RGRP PROD3 Change out top drive saver sub, Work pipe several times between operations. 04:15 - 16:30 12.25 DRILL DRLH PROD3 Drill 6-3/4" hole fl 8,380' to 9,417' MDI 3,258' TVD (1,037'), ART = 9,0 hrs, AST= 0.5 hrs, WOB 2/12K, RPM 100/120, 310 gpm @ 2600 psi, UP 128K, DN 55K, ROT 85K, Torque 8000 Wlbs ON 18000 ft/Ibs OFF, Ave. ECD's 10,9 ppg wI 8,9 ppg mud, Max gas 978 units, Pump Hi-vis weighted sweep on last connection. 16:30 - 17:30 1,00 DRILL CIRC PROD3 Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cutti ngs, 17:30 - 00:00 6,50 DRILL TRIP PROD3 Monitor well, Back ream out of hole at drilling rate- 310 gpm @ 2600 to 1850 psi, 100 RPM, Pulling rate 40/45 Wmin, No problems- hole in good shape, No problems going thru window @ 4,811' to 4,799'. 9/22/2004 00:00 - 01:15 1.25 DRILL CIRC PROD3 Pump Hi-vis weighted sweep, Circ hole clean w/3 times btm's up (Hole appeared clean, No noticeable increase in cuttings), 01:15 - 06:45 5,50 DRILL TRIP PROD3 Monitor well, Pull 5 stands and observe for swabbing, Pump dry job, POOH & lay down BHA (Hole took good fill). 06:45 - 09:45 3,00 WINDOWTRIP CMPL T3 Make up Baker whipstock retrieving tools, RIH to 4,805', 09:45 - 10:15 0,50 WINDOWTRIP CMPL T3 Work pipe & Hook whipstock, Pull Anchor loose wI 40K over. 10:15 - 15:00 4,75 WINDOWTRIP CMPL T3 Monitor well, Pump dry job, Drop rabbit, POOH & lay down whipstock & tools. 15:00 - 16:00 1,00 CASE RURD CMPL T3 Clear rig floor, Rig to run 4-1/2" liner, PJSM, 16:00 - 19:30 3.50 CASE PULR CMPL T3 Pick up 4-1/2", 12,6#, L-80, DWC slotted liner and pick up Baker Hook Hanger as per detail. Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/22/2004 9/23/2004 9/24/2004 3,00 CASE RUNL CMPL T3 RIH w/ liner on drill pipe (Oriented thru window first time), Ran liner to btm @ 9,402' with no problems 1.00 CASE OTHR CMPL T3 Drop 29/32" ball, Check UP wt, of 122K, DN 71 K, Hook Hanger @ 4,811' (first time down), Unhook turn 1/4 turn and bypass window 10', Turn Hook 1/4 turn and bypass window again, Turn Hook 1/4 turn and Hook Hanger 1.57' low @ 4,812,57' w/ Top of liner @ 4,795.72' & Guide Shoe @ 9,401,98', Set 36K down on Hook, Pump down ball at rate of 2 bpm @ 370 psi, Release from Hanger w/ 3500 psi, Pull up to 9,353' (Lost 14K liner weight), Rig & shear out ball w/4200 psi. Observe well, Circ btm's up at rate of 5 bpm @ 1100 psi. Monitor well, Pump dry job, POOH & lay down liner running tools, Lay down 4" drill pipe from off drillers side of derrick. Rig & pick up 138 joints 4-1/2", 12,6#, L-80, IBT Tubing for completion string. POOH and stand back 4-1/2" tubing on off drillers side. Rig & lay down remaining drill pipe and collars from drillers side of derrick. Pull wear bushing, Clear rig floor, Rig to run ESP completion string, Service top drive. PJSM, Pick up Centrilift ESP Completion, Guage, Motor, Seal section, Screen Intake, Service same w/ oil, Connect Esp cable & check same. RIH slow running cable & Installing Cannon clamps every other joint & checking cable conductivity every 1000' to 4,420', Make up hanger, Make final cable splice to wellhead penetrator. Found Penetrator connector to be incorrect tread, and correct one not in state, Wait on Orders Wrap and secure ESP Cable below tubing hanger (With out connecting to hanger), Land string as per detail w/ Tail @ 4,470', Pump guage @ 4,466', Motor @ 4,432', Seal Section @ 4,418' (64.2 deg), GLM #1 @ 3,800' MD ( 2866' TVD), GLM #2 @ 3,006' MD ( 2388' TVD) Parts used on ESP cable; 3 - Protectolizer guards= OD 5,875" 2 - Flat guards= OD 5,625" 15 - Flat stainless steel bands 76 - Cannon clamps= 6,75" 1,00 WELCTL NUND CMPL TN Lay down landing joint, Install 2 way check, Rig & flush out BOP stack w/ wash tool. 1,50 WELCTL NUND CMPL TN Nipple down BOPE, 1.50 WELCTL NUND CMPL TN Nipple up & test Vetco Gray Tree to 250 psi low and 5000 psi High, 1.50 CMPL TN FRZP CMPL TN Pull 2 way check, Rig & Freeze protect well w/ 185 bbls diesel, Pumping down 7-5/8" x 4-1/2" annulus thru Screen intake @ 4,408' with returns up 4-1/2" tubing, Had good diesel to surface. 1,00 CMPL TN OTHR CMPL TN Rig lubricator, Install BPV, Install blind flanges to wellhead, Secure well, Remove scaffolding, Record pressures of 10-3/4" x 7-5/8" = 150 psi, 7-5/8" x 4-1/2" = 225 psi, 4-1/2" tubing = 100 psi. Note; Release rig to move to 1 E-114 at 24:00 hrs 9/24/2004. 19:30 - 22:30 22:30 - 23:30 23:30 - 00:00 0,50 CASE CIRC CMPL T3 00:00 - 03:00 3,00 CASE CIRC CMPL T3 03:00 - 08:00 5,00 DRILL PULD CMPL T3 08:00 - 12:00 4.00 CMPL TN RUNT CMPL T3 12:00 - 14:30 2,50 CMPL TN TRIP CMPL T3 14:30 - 19:30 5.00 DRILL PULD CMPL T3 19:30 - 20:00 0,50 CMPL TN PULD CMPL T3 20:00 . 23:30 3.50 CMPL TN RURD CMPL T3 23:30 - 00:00 0,50 RIGMNT RSRV CMPL T3 00:00 - 03:15 3.25 CMPL TN PULD CMPL TN 03:15 - 15:00 11,75 CMPL TN RUNT CMPL TN 15:00 - 17:00 2,00 WAlTON ORDR CMPL TN 17:00 - 17:30 0,50 CMPL TN SOHO CMPL TN 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 . 23:00 23:00 - 00:00 Printed: 10/11/2004 3:38:27 PM Conoc~illips ConocoPhillips Alaslnco,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . Well bore: 166 L 1 Wellpath: MWD wI Mag-Sag <8704- 9423'> Date Printed: 11-0ct-2004 ~ot(-Ibi "~i. BAKER HUGHES INTEQ Wellbore Name 166 L 1 I Created 16-Sep-2004 I Last Revised 21-Sep-2004 Well···· Name 166 I Government ID I Last Revised 4-Feb-2004 ¡Slot. Name Slot #166 I Grid NorthinQ 5959439.6800 I Grid Easting 549889.7100 I Latitude N70 17 59,8686 I LonQitude W149 35 45.4138 Installatic:m'" Name Pad 1E ;JfÌJJ:k~ I Eastina I Northina 550528,194 I Coord Svstem Name North Alianment 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name KUDaruk River Unit I Eastina 487754.6208 I Northina 5948985,8206 I Coord Svstem Name INorth Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True . .~. Còmmeiim¡~~ lol~(o4 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99,Oft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180,00 degrees Bottom hole distance is 7163,54 Feet on azimuth 165,72 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips ConocoPhillips Alaslnco,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska . Wellbore: 166 L 1 Wellpath: MWD wI Mag-Sag <8704· 9423'> Date Printed: 11-0ct-2004 '&ii. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Section[ftl 8664,29 92,00 193.43 3339,28 6198.735 1918.21E 0.00 6198,73 551848.84 5953254.43 8704.46 90.37 191,59 3338.45 6237,945 1909,51E 6.12 6237,94 551840.40 5953215,18 8797.45 89.29 191,60 3338,73 6329,03S 1890,82E 1,16 6329,03 551822.32 5953123,97 8890,10 89.42 192.30 3339.77 6419.66S 1871.64E 0,77 6419,66 551803.74 5953033.22 8980.18 89,66 190.64 3340.49 6507.945 1853.73E 1,86 6507.94 551786.42 5952944,84 9070.43 91.26 191.27 3339.77 6596,54S 1836,58E 1,91 6596,54 551769,86 5952856,13 9160,93 91,53 189.99 3337.57 6685.465 1819.89E 1.45 6685.46 551753.76 5952767,12 9251.48 92.18 192.93 3334,63 6774,14S 1801,91E 3,32 6774,14 551736.37 5952678.32 9342,90 91,50 191,12 3331,70 6863,51S 1782,88E 2,11 6863,51 551717,93 5952588,84 9423,00 91,50 19UO 3329,60 6942,08S 1767.45E 0,02 6942.08 551703.03 5952510.18 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99,Oft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180,00 degrees Bottom hole distance is 7163,54 Feet on azimuth 165,72 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips ConocoPhillips Alaslnc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . Well bore: 166 L 1 Well path: MWD wI Mag-Sag <8704 - 9423'> Date Printed: 11-0ct-2004 r'ií. BAKER HUGHES INTEQ Comments MOUU TVDrftl Northrftl Eastrftl Comment 5120,49 3352,45 2700,07S 1804.70E Interpolated Azimuth 5153,98 3357,36 2732,82S 1809,70E Internolated Azimuth 5209,72 3362,41 2787.675 1818.09E Internolated Azimuth 8664,29 3339.28 6198.73S 1918.21E Tie-in for Sidetrack 8664,29 3339,28 6198.73S 1918.21E Surveved Tie-In Point 9423,00 3329,60 6942,08S 1767,45E Proiected Data - NO SURVEY Hole. Sections Diameter Start Start Start Start End End End Start Wellbore nnl MDrftl TVDrftl Northrftl Eastfftl MDrftl TVDrftl Northrftl Eastfftl 24,000 0,00 0,00 O,OON O.OOE 108,00 108,00 O,OON O,OOE 166 131/2 108,00 108,00 O.OON O.OOE 3020,00 2397,76 1033,61S 1153,62E 166 97/8 3020,00 2397,76 1033,618 1153,62E 6020,00 3503,13 3588,31S 1939,51E 166 63/4 5068,00 3342,93 2649,05S 1796,90E 8941,00 3328.20 6469,48S 1861.20E 166 L 1 PB1 63/4 8664,29 3339.28 6198.738 1918.21E 9423,00 3329,60 6942,088 1767,45E 166 L 1 CasinQs Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl TVDrftl Northrftl Eastfftl MDrftl TVDrftl Northrftl Eastfftl 20,0001n Conduct" 0,00 0,00 O,OON O,OOE 108,00 108,00 O,OON O,OOE 166 103/4" Casina 0.00 0,00 O.OON O.OOE 3012,00 2392,41 1029,59S 1149.22E 166 7 5/8" Casina 0,00 0,00 O.OON O,OOE 6013,93 3501,93 3572,658 1920,60E 166 4 1/2" Liner 5063,13 3341,93 2644,348 1796,18E 9379,68 3330,74 6899,59S 1775,79E 166 L1 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99,Oft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180,00 degrees Bottom hole distance is 7163,54 Feet on azimuth 165.72 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated -, ConocJ'Phillips ConocoPhillips Alaslnc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska Well bore. L 1 PB1 Well path: MWD wI Mag-Sag <5120- 8941'> Date Printed: 11-0ct-2004 :ßJ~~ I s-'I r&i. BAKIR HUGHIS INTEQ Weflbore Na'ne 166 L1 PB1 I Created 15-Sep-2004 I Last Revised 21-Sep-2004 Well Name 166 I Government ID Slõt Na'ne Slot #166 I Grid Northino 5959439,6800 I Grid Eastino 549889.7100 I Latitude N70 17 59,8686 I LonQitude W149 35 45,4138 'it,;¿;;; North 147.15S InStallatiOñ Na'ne Pad 1 E I Eastina I Northina I Coord SYStem Name 550528,194 5959591,109 AK-4 on NORTH AMERICAN DATUM 1927 Field Name Kuoaruk River Unit I Eastina 487754.6208 I Northina 5948985.8206 I Coord Svstem Name · NOrth Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True t t>~~(Ð rf All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99,00 above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180.00 degrees Bottom hole distance is 6728,77 Feet on azimuth 163,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. Conoc~illips ConocoPhillips Alaslnc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska Wellbore~ L 1 PB1 Wellpath: MWD wI Mag-Sag <5120- 8941'> Date Printed: 11-0ct-2004 r&i. BAKER HUGHES INTEQ Well path (Grid) Report MD(ft] Inc(deg] Azi(deg] TVD(ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfftl 5068.00 78,17 171,31 3342.93 2649,058 1796,90E 0.00 2649,05 551703,98 5956802.88 5120.49 80.93 171,31 3352.45 2700,078 1804.70E 5.25 2700,07 551712,11 5956751,92 5153,98 82.21 171,31 3357,36 2732,828 1809.70E 3,82 2732,82 551717,34 5956719.21 5209,72 87.39 171,31 3362.41 2787.67S 1818.09E 9.29 2787,67 551726.08 5956664.41 5247.42 90.98 172.75 3362,94 2825,008 1823,31E 10,26 2825,00 551731,56 5956627.13 5341.28 90.46 175,12 3361,76 2918,328 1833.23E 2,58 2918,32 551742,09 5956533.89 5388.41 91,75 174,09 3360.85 2965.23S 1837,66E 3,50 2965.23 551746.83 5956487.01 5434,30 92,09 172,80 3359,32 3010.79S 1842,89E 2,91 3010,79 551752,37 5956441.49 5526.46 91,38 170.49 3356,52 3101,938 1856.28E 2,62 3101,93 551766,36 5956350.45 5619,85 90,21 170.40 3355.23 3194,018 1871.78E 1.26 3194,01 551782.47 5956258.48 5713,74 89,60 170,77 3355,38 3286,638 1887,14E 0,76 3286,63 551798.44 5956165,97 5807,54 90,58 170,93 3355.24 3379.248 1902,05E 1,06 3379.24 551813,97 5956073.48 5901 ,57 91,69 169,90 3353.37 3471,948 1917,71E 1,61 3471,94 551830.23 5955980,90 5993,60 90,89 169,09 3351,30 3562.408 1934.48E 1,24 3562.40 551847.61 5955890.56 6086.80 89,95 168,59 3350,62 3653,838 1952,52E 1,14 3653,83 551866.25 5955799,25 6180,07 90,06 168,55 3350,61 3745.258 1971.00E 0.13 3745.25 551885,34 5955707.97 6273.74 89.63 168.24 3350.86 3837.018 1989.85E 0.57 3837.01 551904.79 5955616.35 6369,07 89,57 170.45 3351,53 3930,69S 2007.47E 2,32 3930,69 551923,03 5955522.80 6461.07 90.86 172,85 3351.18 4021.70S 2020.83E 2.96 4021.70 551936.99 5955431,88 6555,30 88.37 173,89 3351.82 4115.298 2031.71E 2.86 4115,29 551948.49 5955338.38 6648,09 88,62 173,77 3354.26 4207.518 2041,68E 0,30 4207,51 551959.07 5955246.23 6742.55 88.13 173.74 3356.93 4301,378 2051.95E 0.52 4301.37 551969.96 5955152.45 6836.59 89.42 173,75 3358,94 4394,838 2062.19E 1.37 4394.83 551980.83 5955059.07 6930,30 91,26 172,51 3358.39 4487,868 2073.40E 2,37 4487,86 551992.65 5954966.13 7023.67 91,11 172,17 3356.46 4580,38S 2085,84E 0.40 4580,38 552005.71 5954873.71 7116.94 92.85 174,18 3353,23 4672.92S 2096.92E 2.85 4672.92 552017.40 5954781.25 7210,24 92.52 172.96 3348,86 4765,538 2107,36E 1,35 4765,53 552028.45 5954688,72 7302.54 88,83 176,37 3347.78 4857.408 2115,93E 5.44 4857.39 552037,63 5954596.92 7396.79 87,94 176,91 3350.43 4951.448 2121.46E 1.10 4951.44 552043.78 5954502.92 7489,90 89,94 179,66 3352,16 5044.488 2124.24E 3,65 5044.48 552047,18 5954409,91 7584.44 91.99 183,90 3350.56 5138,948 2121,31 E 4.98 5138.94 552044.87 5954315.45 7677.52 90,95 187,71 3348.17 5231.498 2111,90E 4.24 5231.49 552036.08 5954222,84 7770,84 91,13 191,30 3346.48 5323,50S 2096.49E 3,85 5323,50 552021.29 5954130,74 7863,99 90,98 192.26 3344,76 5414,678 2077.48E 1.04 5414,67 552002,88 5954039.46 7957,37 89,36 191.92 3344.49 5505,988 2057.92E 1.77 5505.98 551983.93 5953948.03 8049.74 90,06 191,26 3344,95 5596.468 2039,36E 1,04 5596.46 551965,98 5953857.44 8143,07 90,03 191,10 3344,88 5688.028 2021.27E 0,17 5688,02 551948.49 5953765,77 8236,55 90.06 191.56 3344,81 5779,688 2002.90E 0.49 5779.68 551930.74 5953674,00 8330,39 89,66 190,27 3345,04 5871,82S 1985,13E 1.44 5871,82 551913.58 5953581,75 8424.47 89,82 189,54 3345.46 5964.49S 1968,95E 0,79 5964.49 551898,02 5953488.98 8517,39 91.41 192.41 3344.47 6055,70S 1951.27E 3.53 6055.70 551880,94 5953397,67 8610.48 92.42 193,24 3341.36 6146.418 1930,61E 1.40 6146.41 551860,89 5953306,83 8703.76 91,69 193,57 3338.01 6237,098 1909.00E 0.86 6237,09 551839.89 5953216.02 8796,87 92,30 193,94 3334.77 6327.488 1886.88E 0.77 6327.48 551818,36 5953125,50 8888,51 92.76 192,08 3330,72 6416,678 1866.27E 2,09 6416,67 551798,35 5953036,18 8941.00 92.76 192,08 332820 6467,948 1855.30E 0.00 6467,94 551787.72 5952984.84 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99,00 above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 180,00 degrees Bottom hole distance is 6728.77 Feet on azimuth 163,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. Conoc~illips ConocoPhillips Alaslnc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska Well bore. L 1 PB1 Well path: MWD wI Mag-Sag <5120- 8941'> Date Printed: 11-0ct-2004 "~i. BAKER HUGHES INTEQ Comments MDlftl TVDfftl Northfftl Eastfftl Comment 5120.49 3352.45 2700.075 1804.70E Interpolated Azimuth 5153,98 3357,36 2732,825 1809.70E Interoolated Azimuth 5209,72 3362.41 2787,675 1818,09E Interoolated Azimuth 8664.29 3339,28 6198.735 1918.21E Tie-in for Sidetrack 8941.00 3328,20 6467,94S 1855.30E Proiected Data - No Survev Hole Sections Diameter Start Start Start Start End End End Start Wellbore ]inl MDrftl TVDrftl Northfftl Eastfftl MDrftl TVDrftl Northfftl Eastfftl 24,000 0,00 0,00 O,OON O.OOE 108,00 108,00 O,OON O,OOE 166 131/2 108,00 108,00 O,OON O,OOE 3020,00 2397,76 1033,615 1153,62E 166 97/8 3020,00 2397,76 1033,61S 1153,62E 6020,00 3503,13 3588,315 1939,51E 166 63/4 5068.00 3342,93 2649.05S 1796,90E 8941,00 3328.20 6467,94S 1855,30E 166 L1 PB1 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDfftl TVDrftl Northrftl Eastfftl MDrftl TVDfftl Northrftl Eastfftl 20.000in Conduct< 0,00 0,00 O.OON O.OOE 108,00 108.00 O.OON O.OOE 166 103/4" Casina 0,00 0.00 O.OON O.OOE 3012.00 2392.41 1029.59S 1149.22E 166 7 5/8" Casinq 0.00 0,00 O.OON O.OOE 6013,93 3501.93 3572.655 1920.60E 166 4 1/2" Liner 5063,13 3341,93 2644.34S 1796.18E 9379.68 3330.74 6899.595 1775,79E 166 L 1 All data is in Feet unless otherwise stated Coordinates are from 510t MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99,Oft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180.00 degrees Bottom hole distance is 6728.77 Feet on azimuth 163.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ . rm-þ @ ~ ftJì (fù lW J llÙ ~lfl~ ~ . FRANK H. MURKOWSK/, GOVERNOR AI,ASHA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-166Ll ConocoPhillips Alaska, Inc. Permit No: 204-154 Surface Location: 147' FNL, 640' FEL, SEe. 21, TllN, RI0E, UM Bottomhole Location: 1809' FNL, 1077' FWL, SEe. 27, TI1N, RIOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-166, Permit No. 204-153, API No. 50-029-23220. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio~~ witness any required test. Contact the Commission's petroleum field inspector at 07) 65r-3~ 7 (pager). BY ORDER Of THE COMMISSION DATED this~day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of EnvironmentaJ Conservation w/o encl. 1a, Type of Work: Drill 0 Re-entry 0 2, Operator Name: ConocoPhillips Alaska, Inc, 3. Address: . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25,005 Redrill U 1b. Current Well Class: Stratigraphic Test 0 bY ~, ExploratoryU Development Oil ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: [!J Blanket U Single Well 11, Well Name and Number: Bond No, 59-52-180 1E-166L1 6. Proposed Depth: 12. Field/Pool(s): MD: 9463' TVD: 3320' Kuparuk River Field 7, Property Designation: P,O, Box 100360 Anchorage, AK 99510-0360 4a, Location of Well (Governmental Section): Surface: 147' FNL, 640' FEL, Sec. 21, T11N, R1OE, UM Top of Productive Horizon: ADL 25651 & 25660 8. Land Use Permit: 2494' FSL, 1149' FWL, Sec, 22, T11 N, R1OE, UM Total Depth: 1809' FNL, 1077' FWL, Sec, 27, T11N, R1OE, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 549890 16, Deviated wells: Kickoff depth: 5131,6 18. Casing Program Size Hole 42" 13,5" Casing 20"x34" 10,75" 7-5/8" 9-7/8" -+ 6,75" 4,5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20, Attachments: Filing Fee Property Plat (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD rvD ALK 469 & 470 9, Acres in Property: 2560 10, KB Elevation y- 5959440 Zone- (Height above GL): 28 P Downhole: 1582 psig Setting Depth 4 ft, Maximum Hole Angle: 91,5° Weight 94# 45,5/40,5 29,7# 12,6# Specifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC Top Bottom Length MD TVD MD 80' 28' 28' 108' 2172/691 ' 28' 28' 2891' 6088' 28' 28' 6116' 4361' 5102' 3340' 9463' TVD 108' 2300' 3516' 3320' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size I' terfOration Depth TVD (ft): Drilling Program [2) Timev. Depth PlotU Seabed Report 0 Drilling Fluid Program [2) Date: 21, Verbal Approval: Commission Representative: o BOP Sketch [2] Diverter Sketch 0 Printed Name 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader ß-r R-o.-d l' Phone:21.. )-'-"(,..1' Date ~{13/,r J k. ~ PreDared bv Sharon Al/suD-Drake Commission Use Only Permit to Drill API Number: _I Permit Approval see cover letter Number: 20 9- ),L;t:¡ 50- 02-9- 2-3 Z20-6cþ Date: for other requirements Conditions of approval: Samples required 0 Yes ~ No Mud log required 0 Yes I8J No Hyd sulfide measures 0 Yes ® No Directional survey required ~ Yes 0 No ßC)'P -\-c'.>\\,,\-t.~~c.\ ~ \'"\d G.'1S~~\üc...\c..Cr..~~~t'--~o.c..~)k, 1~3/6f Signature M1Z; Other: (U0 . ~~OO ~ (/ ~/ Form 10-401 Revised 12/2003 OR\G\NAL o.~~\ C>-~ \'..Cð . BY ORDER OF THE COMMISSION West Sak Pool 13, Approximate Spud Date: 9/13/2004 14, Distance to Nearest Property: 6357' feet 15. Distance to Nearest Well within Pool: 1 E-112L 1 , 990' @ 7500' Surface: 1160 psig Quantity of Cement c. f, or sacks (including stage data) 260 cf ArcticCrete 510 sx AS Lite, 180 sx DeepCrete 290 sx DeepCrete slotted liner +- Shallow Hazard Analysis 0 20 AAC 25,050 requirements [2) Date: Submit in Duplicate · APltion for Permit to Drill, Well 1 E-166L 1 Revision No.O Saved: 11-Aug-04 Permit It - West Sak Well #1 E-166L 1 Application for Permit to Drill Document M(lximiz. Well Vl;llu~ Table of Contents 1. Well Name ..... ..................... ....... ........ ... ...... ...... .............. ................ ........ .......... ......... 2 Requirements of 20 AAC 25.005 (f)... ........ ......... ....... ......... .... .... ..... ... ......................... ............ ..... .......... 2 2. Location Summary....... ................ ............ ..... .......... .... ......... ...................... .............. 2 Requirements of 20 AAC 25.005(c)(2) ........... ....... ........................ ......... ........................... .....................2 Requirements of 20 AAC 25. 050(b )............. ............. ........................... .............. .... .......... ..... ......... ......... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) .... ....... ...... ..... ............ ....... ......... ......... ........ ............... .... .., .... ...... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing ..Program........................................................................... 4 Requirements of 20 AAC 25.005(c)(6) ....... ........... .......... ..... ............... ....................... ............. ...... .........4 7. Diverter System Information ...................................................................................5 Requirements of 20 AAC 25.005(c)(7) ......................... ............ ........... ..... ................ ..... ........ ........ ......... 5 8. Dri II i ng FI uid Program .......... ..... ..... ............ ....... ... ..... ..... ............... ........ ....... ......... ... 5 Requirements of 20 AAC 25.005(c)(8) ...................................................................................................5 Lateral Mud Program (MI Versa Pro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis .............. ............ ......... .................. ...... ........ ... ......... ................ ....... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................6 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6 1E-166L1 PERM/T /T.doc Page 1 of 7 Printed: 11-Aug-04 · APlion for Permitto Drill, WeIl1E-166L1 Revision No.O Saved: 11-Aug-04 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attachments..... ............... ....................... .......... ............. ...................... ... .... ... ........... 7 Attachment 1 Doyon 141 West Sak 20043 ksi BOP Configuration (1 page) ....................................... 7 Attachment 2 Directional Plan (6 pages) ............................................................................................... 7 Attachment 3 Drilling Hazards Summary (1 page) ................................................................................ 7 Attachment 4 Well Schematic (1 page) ................................................................................................. 7 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 commi..:;slon under 20 MC 25.040(b). For a well with multiple well branche~ each branch must similar/y/;J: idpl]tified a unique name and API number by adding a suffix to the flame designated for the well by the operator and to the number assigned e well by the commission. ..¿: The well for which this Application is submitted will be deSignat as lE-166L1. 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 item~ except for an item already on file with the commission and Identified In the application: (2) a plat identify/ì7g the property and the property's owners and showing (A)the coordinates of tile proposed locatioll of the well at the !:>ìlrface/ at tile top of each objective formation, and at total depth referenced to govemmental sectiollline!:>~ (8) the coordinates of the proposed location of the we!1 at the surfac~ referenced to the state plane coordinate sy!>tem 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 (lE-166 Wellbore) ASP Zone 4 NAD 27 Coordinates Northings: 5,959,440 Eastings: 549,890 147' FNL, 640' FEL, Section 21, TllN, Rl0E, UM RK8 Elevation I Pad Elevation 98.4' AMSL 70.4' AMSL Location at Top of Productive Interval JWest Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,956,814 Eastings: 551,702 2494' FSL, 1149' FWL, Section 22, TllN, Rl0E, UM Measured Depth, RK8: Total Vertical Depth, RK8: Total Vertical Depth, 55: 5,101 3,340 3,241 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,952,510 Eastings: 551,668 1809' FNL, 1077' FWL, Section 27, TllN, Rl0E, UM Measured Depth, RK8: 9,463 Total Vertical Depth, RK8: 3,320 Total Vertical Depth, 55: 3,221 and (D) other Information required by 20 MC 25.050(b); 1E-166L 1 PERM/T /T.doc Page 2 of 7 Printed: 11-Aug-04 · APlon for Permit to Drill, Well 1 E-166L 1 Revision No,O Saved: 11-Aug-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatec£ 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 wellbor~ including all adjacent well bores within 200 feet of any portion of the proposed well/ Please see Attachment 1: Directional Plan and (2) for all wells witl1in 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by cettifìed mai~' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fìle with the commission and identified in the application: (3) a diagram and desCliption of the blowout prevention equipment (BOPE) as required by 20 MC 25. 03~ 20 MC 25.03fi or 20 MC 25.037, as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-166L1. For all operations the stack will be equipped with 3-1/211 to 611 variable bore rams in the uppermost ram cavity 1 blind rams in the middle cavity, and 7-5/811 rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration/l for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost ramsl the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3/000 psi on a 7-5/811 OD. 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 hazard5r including (A) the maximum downhole pressure that may be encounterec!r 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-166L1 area vary from 0.42 to 0.45 psi/ftl or 8.0 to 8.6 epg EMW (equivalent mud weight). These pressures are predicted based on actual bottom líole pressure data from the nearby West Sak well 1E-119. 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 A2 sand formation is 1,160 psi, calculated thusly: MPSP =(3,516 ft)(0.45 - 0.11 pSi/ft) =1,160 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 abnomlally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; 1E-166L1 PERMIT /T.doc Page 3 of 7 Printed: 11-Aug-04 · APlon for Permit to Drill, Well 1 E-166L 1 Revision No.O Saved: 11-Aug-04 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 Drill must be accompanied by each of the following items; except for an item already on tile with the commission and Identified in the application: (5) a description of tile procedure for conducting formation integrity tes~ as required under 20 MC 25. 030(f}; No formation integrity test will be performed in the drilling of lE-166Ll 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicatíon for a Permit to Drill must be accompanied by each of the following items; except for an item already on tile with the commission and Identitied in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment : Cement Summary Ho/e Top 8tm CsglTbg Size Weight Length MDITVD MDITVD OD (in) (in) (/bltt) Grade Connection (tt) (tt) (tt) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 /108 Cemented to surface with 260 cf ArcticCRETE 10-3/4 13-112 45.5 L-80 BTC 2172 28 / 28 2200 /1855 Cemented to 40.5 691 2200 /1855 2891/2300 Surface with 510 sx ASLite Lead, 180 sx DeepCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 6088 28 / 28 6116/ 3516 Cement Top planned @ 4300' MD I 3088' TVD. Cemented wI 290 sx DeepCRETE 4-1/2 6-3/4" A2 12.6 L-80 Grant 3719 5916 / 3481 9635 / 3509 Slotted- no slotted Sand Prideco cement Lateral (1 E- -r5WC/C 166) . 4-1/2 6-3/4" 12.6 L-80 Grant 4361 51021 3340 9463 I 3320 Slotted- no) slotted B Sand Prideco cement Lateral DWC/C (1E-166 -1.1) - 4-1/2 6-3pr' D 12.6 L-80 Grant 4634 4823/ 3275 9457 / 3250 Slotted- no slotted Sand Prideco cement Lateral (lE- DWC/C 166 L2) 1E-166L1 PERM/T /T.doc Page 4 of 7 Printed: 11-Aug-04 · APlon for Permit to Drill, We1l1E-166L 1 Revision No.O Saved: 11-Aug-04 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 item~ 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. 03~ unless this requirement is waived by the commission under 20 MC 25.035{h){2); No diverter system will be used during operations on 1E-166L1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drí!ling fluid program, including a diagram and description of the drilling flUId system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI Versa Pro Mineral Oil Base) Value 9.0 15-25 Density (ppg) Plastic Viscostiy (lb/100 sf) Yield Point (cP) A2/B/D sand laterals HTHP Fluid loss (ml/30 min @ 200psi & 150· Oil / Water Ratio Electrical Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 18-28 <4.0 80 I 20 >600 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pemllt to Drill must be accompanied by each of the following item5,- except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test welt 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. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dr/II must be accompanied by each of the following Items, except for an item already on file with the commission and Identified in the application: (iO) for an exploratory or stratigraphic test welt a seismic retraction or reflection analysis as required by 20 MC 25.061{a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1E-166L1 PERMIT IT,doc Page 5 of 7 Printed: 11-Aug-04 · API¡on for Permit to Drill, Well 1 E-166L 1 Revision No.O Saved: 11-Aug-04 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the 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 structur~ jack-up ríJZ or floating drilling vesse!r an analysis of seabed conditions as required by 20 MC 25.061(bþ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to 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 AAC 25.025 {Bonding}have been met· Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permi Drill must be accompanied by each of the following items; except for an Item already on file with the commission and' ¡fied in the appliL"lition: roposed drilling program is listed below. Please refer also to Attachment 4, Well Sche Note: Previous operations are covered under the 1E-166 Application for Permit to Drill. Run and set Baker WindowMaster whipstock system, at window point of 5,102' MD / 3,340' 1VD, the top of the B sand. Mill 6-3/4" window. POOH. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. Drill to TD of B sand lateral at 9,463' MD / 3,320' 1VD, as per directional plan. ;3- OL--\ - ,S-LJ POOH, back reaming out of lateral. POOH. \ RIH with whipstock retrieval tool. Retrieve whipstock and POOH. PU and run 4-1/2" slotted liner. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. Release hanger running tool. POOH. """"'-- --- Note: Remaining operations are covered under the 1E-166L2 Applications for Permit to Drill, and are provided here for information only. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 11. Run and set Baker Window Master whipstock system, at window point of 4,823' MD / 3,2,75' 1VD, the top of the D sand. 12. Mill 6-3/4" window. POOH. 13. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 14. Drill to TD of D sand lateral at 9,457' MD I 3,250' 1VD, as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 17. PU and run 4-1/2" slotted liner. 1E-166L1 PERMIT IT. doc Page 6 of 7 Printed: 11-Aug-04 · APlon for Permit to Drill, Well 1 E-166L 1 Revision No.O Saved: 11-Aug-04 18. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. Release hanger running tool. 19. POOH, laying down drill pipe as required. 20. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 21. Nipple down BOPE, nipple up tree and test. 22. Set BPV and move rig off. 23. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 24. Rig up wire line unit. Pull BPV 25. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in. 26. Rig up wireline. Replace gas lift valves with blank dummy valves. Run ESP through tubing. 27. Operate well with ESP. 14. 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 w!7ether t!7e 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 pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will bé disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 20043 ksi BOP Configuration (1 page) Attachment 2 Directional Plan (6 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Well Schematic (1 page) 1£-166L 1 PERM/T /T. doc Page 7 of 7 Printed: "-Aug-04 . . -Ar ~ ;:8.: -Ar -6 cL Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular _________ To be tested to 250 psi and 1,500 psi at initial .------ installation and every 14 days thereafter. ~ 5 13-5 Double Ram Upper Rams: 3-%" to 6" variables To be tested to 250 psi and 3,000 psi at initial S ? installation and every 14 days thereafter. C S ? Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~ To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. S ? ~ 13-5 Single Ram ..J L Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing, ~ Wellhead Valves tested to 3,000 psi upon assembly ~ Conocd>hillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration 13-5 BOP 3K diagram,vsd Sheet 1 of 1 prepared by Steve McKeever 8/1112004 e . y"" ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 166L 1 Well path: 166L 1 Ver#3 Date Printed: 29-Jul-2004 INTEQ Well bore Name 166L 1 Created 111-F eb-2004 Last Revised 26-Jul-2004 Name 166 Grid Eastinq 1549889,7100 Latitude N70 17 Installation Name Pad 1 E Eastinq 550528,1946 Field Name Kuparuk River Unit r Eastinq 487754,6208 I Northing 5948985.8206 I Coord System Name I North Aliq~ AK-4 on NORTH AMERICAN DATUM 1927 datu~ True I All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180,00 degrees Bottom hole distance is 7154,92 Feet on azimuth 165,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ConocJ'Phmips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska Well path Report MD[ft] Inc[deg] IAzi[deg] TVD[ft] Vertical I Depth 55 80.00 1172,00 3340,00 81,91 I 172.00 3341,89 81,91 172,00 3344.42 86,91 172.00 3354,16 89,82 172,00 3355,82 91,32 !I 172,00 3355.32 91,32 172,00 II 3354.94 89.82 I 172,00 3354.44 89,82 172.00 3354.73 89,82 172,00 3355.04 89,82 172,00 3355,35 89,82 172.00 3355,66 89.82 172,00 3355,97 89,82 I 172,00 3356,28 89,82 172.00 3356,59 89,82 172.00 3356,64 89,82 172.00 3356,90 89,82 172.00 3357.21 89,82 172,00 3357.52 89,82 172,00 3357,83 89.82 I 172,00 3358,14 89.82 1172.00 3358.45 89.82 172.00 13358,77 89,82 172.00 3359,08 5101,62 5113,62 5131.62 5231,62 5289,90 5339,90 5356.75 5406,75 5500,00 5600,00 5700,00 5800,00 5900,00 6000,00 6100,00 6116.22 6200,00 6300,00 _ 6400,00 6500,00 6600,00 6700,00 6800,00 6900,00 7000.00 7100.00 7140,93 7200,00 -2300,00 7400,00 7408,82 7500,00 7600,00 7700.00 7797,38 7800,00 7900,00 8000,00 8100,00 8200,00 8300,00 8400,00 8500,00 8600,00 8700.00 8800.00 8900.00 9000.00 9100,00 89,44 90,11 90,79 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 91.45 89,82 89,82 89,82 89,60 89,23 88,85 88.82 172. 00 172,00 172,00 173,76 176,73 179,71 179,97 182.64 185.56 188.49 191,33 191,33 191,33 191.33 191,33 191,33 191,33 191,33 19.1.33 191,33 191.33 191.33 191.33 191,33 191.33 3359,39 3359.70 3359.82 3360.12 3361,15 , 3362,82 3363,00 3364,39 3364,78 3363,99 3362,08 13362,02 3359.49 ! 3356,96 3354.44 3351,91 3349,39 3346,86 3344,33 3341.81 3339.28 3336,75 3334,23 3331,70 3329,18 3241,00 3242.89 3245.42 3255,16 3256,82 3256.33 3255.94 3255.44 3255,73 3256,04 3256.35 3256,66 3256.97 3257.28 3257,59 3257,64 3257,90 3258.21 3258.52 3258.83 3259.14 3259.46 3259,77 3260,08 3260,39 3260.70 3260,82 3261.12 3262,15 3263,82 3264.00 3265,39 3265,78 3264,99 3263,08 3263,02 3260.49 3257.96 3255.44 3252,91 3250.39 3247,86 3245,33 3242.81 3240.28 3237,75 3235,23 3232,70 3230,18 North[ft] East{ft] 5tation Position(Grid North) 2637.635 1795.44E 5956814.29 2649.365 1797,09E 5956802,57 2667,015 1799.57E 5956784,94 2765,535 1813.41E 5956686.52 2823,225 1821,52E 5956628.90 2872,735 1828,48E 5956579.44 2889.4151 1830,82E 5956562,78 2938,925 1837.78E 5956513,32 3031,265 1850,76E 5956421,07 3130,295 1864,67E 5956322,15 3229.315 1878,59E 5956223.23 3328,345 1892,51E 5956124.31 3427,375 1906.43E 5956025,39 3526.395 1920,34E 5955926.46 3625.425 1934,26E 5955827,54 3641.485 1936,52E 5955811,50 3724.455 1948.18E 5955728,62 3823.475 1962,10E 5955629,70 3922.505 1976,01 E 5955530,78 4021,525 ¡1989'93E 5955431,85 4120.555 2003,85E 5955332,93 4219.585 2017.76E 5955234.01 4318,60512031.68E 5955135.09 4417,635 2045.60E 5955036,17 4516,655 2059.52E 4615.685 2073.43E 4656.215 2079,13E 4714.825 2086.45E 4814.465 I 2094,74E 4914,395 2097.84E 4923,205 2097,86E 5014,35S 2095.78E 5114,08S 2088,63E 5213,31 S 2076.40E 5309.21 S 2059,65E 5311,78S 2059,14E 5409,80S í 2039,49E 5507.82SI2019,85E 5605.84S 2000,20E 5703.85S 1980,56E 5801,87S 1960,92E 5899,89S 1941,27E 5997,915 1921,63E 6095.93S 1901,98E 6193,955 1882,34E 6291,975 1862,69E 6389,995 1843.05E 6488,015 1823.41E 6586.03S I 1803,76E 5954937,24 5954838,32 5954797,83 5954739,28 5954639,71 5954539,81 5954531,00 . PROPOSAL LISTING Page 2 Well bore: 166L 1 Wellpath: 166L 1 Ver#3 Date Printed: 29-Jul-2004 Hi. BAKER HUGHES INTEQ ~ Station i Dogleg Vertical Station Comment I Position(Grid I [deg/1 ° 5ection[f I East) lOft] t1 I 551702.44 I 0,00 2637,63 Top Whipstock Face. Tie on I 551704,17 115,90 ~"36 Base Whipstock Face. End of Build 551706.76 ¡ 0,00 2667,01 End Milled Open hole KOP End of Hold 551721,26 I 5,00 2765,53 I 551729,75 5,00 2823.22 End of Build I 551737,04 3,00 I 2872.73 End of Build I 551739.49 0,00 12889.41 End of Hold I 551746,78 3,00, 2938,92 End of Drop I' 551760,37 0,00 3031.26 551774,94 0,00 3130.29 551789,51 0.00 3229.31 551804,09 0.00 3328,34 551818,66 0.00 3427.37 551833,23 I 0.00 3526.39 551847,80 0,00 3625.42 551850,17 0.00 I 3641.48 551862.38 0,00 3724.44 551876,95 0,00 3823.47 551891,52 0,00 3922,50 551906.10 0,00 4021,52 551920,67 0,00 14120,55 551935,24 0,00 4219,58 551949,81 0.00 4318.60 551964,39 0.00 4417.63 551978.96 lJlQQ 4516,66 551993,53 I 0,00 4615,68 0,00 4656,21 5/C Kick off Point 3,00 4714,82 I 3,00 4814.46 3,00 I 4914,39 I 3,00 4923,20 WS 1 E E2 B-MDPT#1 RVSD0621 001 3DJ Kick off Point 3.00--1QQ14.35 3,00 15114.08 I 3,00 5213,31 ----j 3,00 5309,21 End of Buildrrum I 0,00 5311,78 I 0,00 5409,80 0,00 I 5507,82 0,00 5605,84 _ 1 0,00 5703,86 0,00 5801,87 I 0,00 5899,89 ------¡ 0.00 5997,91 i 0,00 6095.93 I 0.00 6193,95 0,00 I 6291,97 0.00 I 6389.99 0.00 I 6488,01 0,00 I 6586,03 551999,50 552007,21 552016,15 552019,92 552020,00 I 5954439,86 552018,53 I 5954340,09 552012,04 I 5954240.78 552000.47 5954144.79 551984,36 5954142.21 551983,86 5954044,08 551964,87 5953945,94 551945,88 5953847,80 551926,89 5953749,66 551907,89 5953651,53 551888,90 5953553,39 551869.91 5953455.25 551850,92 5953357,11 551831,93 5953258,9-ª- 551812,94 I 5953160,84 551793,95 5953062,70 551774,96 I 5952964,56 551755,97 I 5952866.43 551736,97 -----¡ I I ----------1 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99,Oft above mean sea level) Vertical Section is from O,OON O.OOE on azimuth 180,00 degrees Bottom hole distance is 7154,92 Feet on azimuth 165,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ConocÓPhiIUps ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 e, Kuparuk River Unit,North Slope, Alaska Well MD[ft) North[ft) 9200.00 ~OO,OO 9400.00 9457.46 9463,19 91.45 91.45 91.45 91.45 91.45 TVD[ft) Vertical Depth SS 191,33 3326,65 3227.65 191,33 3324,12 3225,12 191.33 3321,60 3222,60 191.33 13320,15 3221,14 191,33 3320,00 3221,00 6684.05S 6782,06S 6880.08S 6936.40S 6942,02S East(ft) Station Position(Grid North) 1784,12E 5952768,29 1764.47E 5952670,15 1744.83E 5952572,01 1733,54E 5952515.63 1732,42E 5952510,00 . PROPOSAL LISTING Page 3 Wellbore: 166L 1 Wellpath: 166L 1 Ver#3 Date Printed: 29-Jul-2004 Station I Dogleg Vertical Station Comment Position(Grid [deg/10 Section[f East) Oft] tl 551717.98 0,00 6684.04 551698,99 0,00 6782.06 551680.00 0.00 6880,08 551669,09 0,00 16936,40 4 1/2in Liner 551668,00 0,00 6942,02 rD All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99,Oft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 180,00 degrees Bottom hole distance is 7154,92 Feet on azimuth 165,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . conoccrPhmips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 WeJlbore: 166L 1 WeJlpath: 166L 1 Ver#3 Date Printed: 29·Jul·2004 Comments MDrft1 I TVDrftJ 400,00 400.00 158333 I 145871 EastCft1 O,OOE 332 36E NorthCft1 O,OON 278 888 I Comment KOP IEOC ¡ -1 . 4206,56 3045,82 1652.09E 1809,628 8tart 200' Pump Tanç¡ent 4406,56 3136,17 1691,57E 1983,638 End 200' Pump Tanç¡ent 5101,62 3340,00 1795,44E 2637,635 Top Whipstock Face 5113,62 3341,89 1797,09E 2649,365 Base Whipstock Face - 5131.62 3344,42 1799,57E 2667,018 End Milled ODenhole. K 9463,19 I 3320,00 1732,42E 6942,02S TO OP Hole Sections Diameter ¡start Start Start I Start End End lEnd EndlnEast[ft} Wellbore [in1 MDrft1 TVDCft1 NorthrftJ EastCft1 MDrft1 TVDrftJ Northrft1 _131/2 I 0,00 0,00 O,OON O,OOE 2890,59 2299,00 922,585 1099,49E 166 97/8 2890,59 2299,00 922,585 1099,49E 6116,22 3516,00 3641,488 1936.52E 166 63/4 5101,62 3340,00 2637,63S 1795,44E 9463,19 3320,00 6942,02S 1732,42E 166L 1 Casin s ---l Name Top Top Top Shoe Shoe Shoe ¡Shoe Wellbore MDrft1 Northrftl EastCftl MDrftl TVDrftl Northrftl I EastCft1 10 3/4in Casinç¡ 0.00 O.OON O.OOE 2890,59 2299,00 922,58S I 1099,49E 166 I 7 5/8in Casinç¡ 0.00 O,OON O.OOE 6116,22 3516.00 3627,12S ¡ 1934.50E 166 4 1/2in Liner 4823.18 2369.64S 1757.77E 9457,46 3250.00 6942,02S I 1732,42E 166L2 I 4 1/2in Liner 5101.62 2637,63S 1795.44E 9463,19 3320.00 6942,02S I 1732.42E 166L1 I Taraets Name North ft Latitude Lon itude Eastin Northin WS 1 E E2 B-MDPT#1 4923.205 N70 17 11,4463 W149 34 44,2951 552020.00 5954531,00 RVSD062104 WS 1 E E2 B TOE 6942,02S 1732,42E 3320.00 N70 16 51,5923 W149 34 54,9554 551668,00 5952510,00 RVSD062104 WS 1 E E2 B-MDPT#2 4923.87S 2197,87E 3388,00 N70 17 11.4395 W149 34 41,3815 552120,00 5954531,00 RVSD010704 Survey Tool Proaram Reference I Survey Name 649141 I Planned 647695 I Planned I MDCft1 II 9463,19 5101,62 3340,00 115CW5A MWD ! I Error Model I MWD+SAG - ISCWSA - 28 Ja 03 OJH I MWD+SAG - ISCW5A - 28 Ja , 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99,Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180,00 degrees Bottom hole distance is 7154,92 Feet on azimuth 165,99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · . Baker Hughes Incorporated Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25,00 ft Depth Range: 5105,62 to 9463,18 ft Maximum Radius: 5280,00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Well path Date: 1/12/2004 Validated: No Planned From To Survey ft ft 4.00 5101,62 Planned: 1E-166 Vers#3 V18 (0) 5101.62 9463,18 Planned: 1E-166L1 Vers#3 V10 Version: Toolcode Tool Name MWD+SAG+IFR MWD+SAG+IFR MWD+SAG+IFR (AK) MWD+SAG+IFR (AK) Summary Pad 1E 112 1E-112L1 V3 7500.00 9650,00 990,39 333,04 657,36 Pass: Major Risk Pad 1 E 112 1E-112L2 V2 8035,17 10325,00 1049,63 337.45 712,18 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan 9205,61 8350,00 507,96 404.46 103.49 Pass: Major Risk Pad 1E 117 117 B-Lateral VO Plan: 9205,61 8350,00 507,96 404.43 103,52 Pass: Major Risk Pad 1E 117 117 D-Lateral VO Plan: 9205,61 8350,00 507.96 404.43 103.52 Pass: Major Risk Pad 1E 119 119 VO Plan: 1E-119 Ve 8054.47 7075,00 1010,03 341,34 668.69 Pass: Major Risk Pad 1 E 166 1E-166 V1 Plan: 1E-166 5124,99 5125,00 0,58 80,62 -80,04 FAIL: Major Risk Pad 1 E 166 1E-166L2 V1 Plan: 1E-1 5125,03 5125,00 37,75 79.43 -41,68 FAIL: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 9463,16 7825.00 1046,15 402,60 643,55 Pass: Major Risk Pad 1E 170 170 B-Lateral VO Plan: 9463,16 7825,00 1046,15 402,59 643.56 Pass: Major Risk Pad 1 E 170 170 D-Lateral VO Plan: 9463.16 7825.00 1046.15 402,59 643.56 Pass: Major Risk Pad 1E 34 1 E-34 VO 5105,62 6100,00 1000,91 154,84 846,08 Pass: Major Risk Pad 1 E 35 1 E-35 V1 6162.57 5875.00 357,86 224.31 133,55 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 6162.68 5875.00 372.40 224.82 147,58 Pass: Major Risk ConocoPhillips Alaska, Inc. Conocó'Phillips Location: North Slope, Alaska Slot: Slot #166 Field: Kuparuk River Unit Well: 166 Installation: Pad 1E Wellbore: 166L1 Created by : Planner Date pIolted: 29-Jul-2004 Plot reference is 166L 1. Ref weJlpath is 166L 1 Ver#3, Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 fJ Rig Datum to mean sea level: 99,00 It. Plot North is aligned to TRUE North. 350 340 20 330 30 320 40 310 50 300 60 290 70 280 80 100 270 '0 6~C 90 100 260 100 250 110 240 120 230 130 220 140 150 \ 200 160 \ 7500 190 180 170 % Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well . . ,lE-166L"rillina Hazard'summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Low Mitigation Strategy Stripping drills, shut-in drills, increased mud weight. Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Low Moderate 1 E-166L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 8/10/2004 12:03 PM 6' :J å -0'( ::T\ :.: ~= ~i ~ I/) .. en I» '1\:0:- en:n~ ¡¡(oS&, !~~ ~¡~ ""3::¡ .....a::!: ¡:¡. g, .... 1]1 .... Q) Q) (ñ~ ä[ ~~ "'''' ",<it ~~'" I!!~Õ:" ~!!l!':~ ~1\'~~ ~[~: Insulated Conductor Casing, 20", 94#, K55 X34",O.312"\f{f@\ - +/-10B'MD r 10-3/4",45,5#, L-SO, Special Drift, BTC \ (10542532) set @ +/- 2,S91' MO / 2,300' TVO ~ @ 50 degrees TO 13-1/2" hole Top of l,IS!nu C @3,514' ----.. MD /2,693' TVD Top of West Sak D @ 4,823' MD / 3,275' TVD ----.. Top of West Sak B @ 5,102' MD / 3,340' TVD ------. 1E·166 As Built: ASP NAD 27 Ea.tings: 549,889.71 ASP NAD 27 Northings: 5,959,439.68 Pad Elevation: 70.4' AMSL Wellhead / Tubing Head / Tree, 13-5/ (B"X4-W" 5,OOOksi Tubing String: 4-1/2",12,6 #, L- SO, IBT,AB Modiifed with Special _ ~ Clearance Couplings (4,920" ~ 00) ~ Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 9S' AMSL (1) Gas Lift Mandrels, (1062-2035) CAMCO 4-1/2" ..... / x 1" Model KBG-2, one 3 joints above ESP, one at " 2400' TVD, Electric Submersible Pump, Centrilift 41S HP motor, with FC6000 wireline ~ deployed pump, Bottom at 4,406' MO, / 3,136'TVO ¥ 166L2 0 Sand Window @ +/- ~ 4,S23' MO / 3,275' TVO, 75 . ¥ degrees . 1E-166L2: 6-%" 0 sand lateral TO @ 7 9,457' MO / 3,250' TVO ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~f~fffffff~fff~1 ~ o and B Sand Liners, 4.Y..', 12,6#, LSO, R3, OWC/C, every ;o{ 1t slotted, (0.125" x 2,5" slots, 32 per tOOt, ¡t'9% e;I'61'ó area) 1E-166L1: 6-%" B sand lateral TO@} 1I,40Y'M9 L ~.320' TVO )7"1 ~~E~§EE~§EE~EEEEEEEEEEEEEEEEEEEEEEEEEEEEEEEEEEE§[EE§~EE§~EEEI ~ . Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above, Tubing, 4-Y'" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3,562" "DB" nipple, Top of West Sak A2 @ 6,116' MD /3,516' TVD----" 7·5/S", 29,7#, L-SO, BTCM J (10527S3S) Casing set @ +/- 6,116' MO / 3,516' TVO. Set @ S1 degrees TO 9·7/S" hole ~ A2 Sand Liner, 4.11.",12,6#, LSO, R3, OWC/C, with slots over sand, blank over shales, and constrictors for isolation, (0,125" x 2,5" slots, 32 per foot, 5,9% open area) R3 Slotted = 10783557, R2 Slotted = 10790121 R3 Blank = 10794247. R2 Blank = 10790738 1 E-166: 6-%" A-Sand lateral TO @ 9,635' MO / 3,509' TVO . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME tf.~ /£-/b? ¿/ PTD# 20éj - / S' '7 ;X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) M1JLTI LATERAL x (If API Dumber last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE". The permit is for a new weUbore segment of existing weD I<A f...6 I 6 -./ b b Permit No¡o$l-/.:CfAPJ ~ð2..9 - :2.~ z..¿o Production should continue to be reponed as a function' of tbe original API number. stated above. HOLE In accordance mth 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot hole must be dearly differentiated În both name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fun compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing eneption. (Company Name) assumes the liability of any protest to tbe spacing .e:Jcep1Îon tbat may occur. AU dry ditcb sample sets submitted to the Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: 1<UPARUK RIV U WSAK 1 E-166L 1 Program DEV _ Well bore seg ~ PTD#: 2041540 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV /1-0IL GeoArea Unit On/Off Shore On Annular Disposal ~ Administration 1 Permit fee attacheø _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - -- 2 _Lease _number _appropriate _ _ _ _ _ yes - - - -- 3 _UÐlqueweltn_a[1le_a[ld lJu_mber _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -. - - ~ - - - - - - - - - - - - - - - - - - ~ 4 WelllQcated in_a_defineøpooL _ - - - - - _ _ Yes - - - - - 5 WeJUQcated properdlstance_ from driJling unitbounda(y_ - - - - - - _ Yes - - - - - - - - 6 Well JQcated proper .dlstance_ from Qther wells_ _ _ - - - - - _ _ Yes - - - - 7 Sufficient acreage_ayailable in_dJilIi[lg unjt_ - - - - Yes - - - - - - - - - - - - - 8 Ifdevi<lted. js_ weJlbQre pl<lUocJu_ded _ - - - - - Yes - - - -- 9 _Operator only affected party _ - - - - Yes - - -- - - - - - - - - - - - - - - 10 _Operator has_appropriateJ).ond inJQrçe _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ q _ _ _Yes - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - -- - - - - - - - 11 Permit c_a[l be issued wjthQut co_nserva.tion order. Yes - - -- Appr Date 12 Permitca[l be issued witho.ut ad.mioistratille.approvaJ . ..... Yes - - - - - - - -- RPC 8/16/2004 13 Can permit be approved before 15-day wait Yes . 14 Well IQcated wlthin area and.strata .authorized by l[ljectiolJ Order # (put 10# in. CO[1l[1l_e[lts>. (For. NA 15 A]I wells_within.1l4.mile.area_of reyiew idelJt!fied (For $ervjcewellonly). . _ . _ . . _ . . . . . . . .NA . -- - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- 16 Pre-produçed i[ljector; øuratiQnof pre-proøuctiooless. th<ln 3 months_ (For_service well Qn]y) . . .NA '17 AÇMP.F'indjng _of CQnsi$te[lcy.h.as bee.nJ$sued. for. this pr.oieçt .. . .NA - - - - - - - - - - - - -- - - - - - - - -- Engineering 18 .C.o[ldu.ctor string.pJQvided . . . - - - -- NA ConductorJns!a]led ill [1lotherbore. 1E.-166c _ . 19 .S.urface .c<lsiog. pJQtects alLknown USQWs . .NA &\1 aquifers ex.empted 40 em 147,102(b)(3), . 20 .CMTv.otadequ_ateto circ.utate.on.cood.uctor.& $UJtC$g . . .NA Surface castng instaUedin 1E-166, . . . . . . - - - - - - - - - 21 CMT vol. ad~qu.ate to tie-iÐJQngstri[lg to surf csg_ NA Intermedjate. casi[lg tnstalled jl! 1.E-16.6,. . . . . 22 CMTwil! coyeraJl koownpro.ductiye hQrilQn.s_ . .. No. Slottedlioer .completioo pla[lned, InteJmedjate ca.sing çement planned abo.ve aoy/all.hydroc.arbß[l,_ 23 .C_asi[lg desig[ls ad.equa.te tor CJ4 B&. permafrßst _ - - - - - - _. Yes - - - -- - - - - - - 24 AdequateJ<ll!k<lge.oJ re.serye pit - - - - Yes Rig jSßquippe.dwitl1 steelpits, . No. rese.rIle.pjtplanoed, AJI waste to an _appro\(ed .a[lou]u$or disposal wel 25 Ita.r~-ørilt has_a. 100403 fOJ abandonment beeo apPJQved . ..NA - - - - - - - -- 26 .ÄØequate.wellbore sep<lratjoÐ.proposed. . _ . . . . . . _ . . . . . . . . _ _ . . _ ..... Yes I?r~::ncir:nltY-. ~n9IY$i$ perf.o[meJj~ Clo$es_t ~P-PJQaçh i.$_A_s_30d l.ateraJ ªQ.û!..it t80'_tvd_b.elow~ 27 Jf.diveder Jeq.uired, dQes it .me~t regulations. NA BOP wtll.alreaøy be in place,. . . Appr Date 28 DJiUilJg fluid pJogram sc.hematic.& eq.uip listadequate_ _ Yes BI:IF> expected beìwe_e[l 13..0- .8,.6£MW, PlalJned MW 9,0 ppg,. . _ TEM 8/17/2004 29 .BOPEs..dßthey meet reguJatioo _ - - - - . Yes . ~\,' 30 BOPE.press ra.ti[lg <lppropriate;test to (pu.t psig tncomments). Yes MP-SP calcuJate_dat 11.60 psic Pla[loe_dB.QP test pressure 3000 psi 31 .C.hokemanjfold cQmpJies. WI API Rf'-53 (May 64) _ . .Yes - - - - - - - - - 32 WQrk wi]1 occur withoutoperation .shutdown. - - - - - - Yes - - - - - - - - - - - 33 Is prese[lce_ Qf H2S gas. probable. . . No tf2S is JJlJlikely, Rig js.equippe.dwith sen.sors alJd alarms, 34 Mecha.nicaLcoodjtio!1 ptweJls withio &08. verified (fors.ervjce we\] on.lyj. . _ .NA Geology 35 Permit call be issued w/o. hydrogen s.ulfide measures. . .. Yes 36 .D.ata.PJeselJted on. pote.ntial oveJRres.sure .zones. _ . - - - -- NA Appr Date 37 .Setsmican<llysJs. of shaJlow gas.zß[les. . . .NA - - -- RPC 8/16/2004 38 .Se<lbeøcondjtipo survey.(if off-shore) . . NA 39 . Co.n!a.ct oamelphol1eJor.weekly progress reports [exploratPly.onlyl . . . . . _ .NA Geologic Date: Engineering Date fJ'" ~~¡: Commissioner Commissioner s:ioner ÞiS f})òf~ e e 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 infonnatioo, information of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 05/05/03 AWS 01 **** TAPE HEADER LDWG 05/05/03 **** 01 *** LIS COMMENT RECORD *** . . c1Jl-/5f FfJ J II c., !!!! !!!!!!! !!!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.625 6.750 1E-166L1 500292322060 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 03-May-05 MWD RUN 6 6 S. TUFTON M. THORTON 21 llN 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 MWD RUN 7 7 F. WENDLER N. SCALES DRILLERS DEPTH (FT) 108.0 3012.0 5080.0 9423.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR . . TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 59.869" LONG: W149 DEG 35' 45.414" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 108 to 3020 feet MD (108 to 2398 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 3020 to 6020 feet MD (2398 to 3503 feet TVD). 3) Baker Hughes INTEQ run 5 utilized a 4.75" Ganuna Ray tool to set the whip stock, mill a window, and drill from 5080 to 5100 feet MD (3345 to 3349 feet TVD). 4) Baker Hughes INTEQ runs 6 & 7 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 5100 to 9423 feet MD (3345 to 3329 feet TVD). REMARKS : 1) Depth of 10 3/4" Casing Shoe - Driller: 3012 feet MD (2392 feet TVD). Depth of 10 3/4" Casing Shoe - Logger: 3012 feet MD (2392 feet TVD). 2) Top of 7 5/8" Casing Window: 5068 feet MD (3343 feet TVD). Bottom of 7 5/8" Casing Window: 5080 feet MD (3345 feet TVD). 3) The well was sidetracked at 8664 feet MD (3339 feet TVD) from the wellbore lE-166LlPB1. 4) The interval from 9393 to 9423 feet (3330 to 3329 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 81 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3012.0 STOP DEPTH 9423.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEpTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH . . $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 3 6 7 MERGE TOP 3012.0 5080.0 5176.0 MERGE BASE 5080.0 5176.0 9423.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1e-166L1 5.xtf 150 ConocoPhillips Alaska, Inc. lE-166L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROP 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 . . 28 Total Data Records: 414 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3012.000000 9423.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 457 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 2976.0 STOP DEPTH 5080.0 # 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: 06-SEP-04 MSB 18704 6.75 MPR MEMORY 6020.0 2976.0 5080.0 o 48.6 78.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR PRES MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL PRESSURE MULT. PROP. GAMMA RAY RES. TOOL NUMBER DHA 6289 1006728 6010 10083974 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.625 3012.0 # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . LSND 9.05 .0 .0 200 .0 .000 .000 .000 .000 114.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWÐ Run 3) . MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-166L1.xtf 150 ConocoPhillips Alaska, I 1E-166L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 . FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 .....------ 28 Total Data Records: 272 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2976.000000 5080.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 357 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!! I!! I!!! !!!!!!! Extract File: FILEQI2.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 3R .2500 START DEPTH 5080.0 STOP DEPTH 5176.0 # 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): 13-SEP-04 MSB 18704 4.75 MPR MEMORY 5206.0 5080.0 5176.0 . BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. GAMMA RAY PRESSURE # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: . o 78.2 80.9 TOOL NUMBER 18410 54694 10058019 1{)064654 6.750 5080.0 OBM 8.90 .0 .0 49000 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3R (MWÐ Run 6). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-166L1.xtf 150 ConocoPhillips Alaska, I 1E-166L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL GRAM RPCL GRAM RPD 0.0 0.0 . . RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= OJ Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 13 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5080.000000 5176.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 98 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: RAW MWD LDWG File Version 1.000 Extract File: FILE013.HED 4 . . header data for each bit run in separate files. 3R .2500 Curves and log BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 5176.0 STOP DEPTH 9423.0 # 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 DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY PRESSURE RES. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 16-SEP-04 MSB 18704 4.75 MPR MEMORY 9423.0 5176.0 9423.0 o 80.9 92.6 TOOL NUMBER 18410 6032 4209 10056318 6.750 5080.0 OBM 8.90 .0 .0 53000 .0 .000 .000 .000 .000 104.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3R (MWD Run 7) . MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-166L1.xtf 150 ConocoPhillips Alaska, I 1E-166Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM: 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 549 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5176.000000 9423.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 634 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/03 01 **** REEL TRAILER **** LDWG 05/05/03 AWS 01 Tape Subfile: 6 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes
