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Home My WebLink About203-078 Image ~ .~bject Well History File C"Jer 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. .;). 03 - 0'123 Well History File Identifier Organizing (done) o Two-sided 11111111I1111111111 ~can Needed I RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: Scanning Preparation ~ x 30 = o Other:: I I I if) Date: 7 I ~ () S- Isl /t11 T- . II Date: 7/lef, () ,Ç" Is! ~ IJ + d.. LJ. = TOTAL PAGES ?¡1f (Count does .not liclude cover sheet¡ A /J ¡() Date: 7 i ~ n L<Y Isl I yt r mP BY: Helen ç Maria) Project Proofing BY: Helen ~ BY: Helen ~ M;:¡ri;:¡ ) BY: Production Scanning Stage 1 Page Count from Scanned File: f5' 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / YES NO Helen ~~ Date: '1/ t ~ 'óS Isl m P If NO in stage 1 page(s) discrepancies were found: YES Nú Stage 1 BY: Helen Maria Date: 151 1111111111111111111 1111111111111111111 III Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount RECENED Alaska Oil and Gas Commission . NOV 0 ry ?e11 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ao3 -ovz Ittika OH & Gas Cons. cu ma i sSion G _ 70 . ;t ►cnorago. Commissioner Dan Seamourit: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, i E.. 13 2 1 ` tde � " Martin Walters ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26111 1 A,1 B,1 C,1 D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor! Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft _ gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 _ 1821420 _ 12" 1.00 20" 09/11/2011 _ 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C- 170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C-174 50029231400000 2030270 _ 7' 1.00 8" 09/11/2011 _ 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15.2 10/16/2011 1D-08 50029220266000 1770530 _ 5'2" 1.20 6" 5/28/2011 3.8 10/15/2011 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D -41 50029232880000 2051880 _ 16" _ N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 • • ConocoPh Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 March 07, 2011 Commissioner Dan Seamount BEGET Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 MAR 14 20 Anchorage, AK 99501 Atka O11 Gas Cofs. Com m i ssion Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1C -170, PTD 203 -078, Sundry 310 -346 surface casing repair. Please call MJ Loveland or Perry Klein at 659 -7043 if you have any questions. Sincerely, i - MJ Loveld , , <.' >,; MART 2 2 ail ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSIOP REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [ Repair well [ Plug Ftrforations [] Stimulate [ Other p Inspect & Repair Pull Tubing Pbrforate New Pool Waiver SC Alter Casing ❑ 9 � [J r Time Extension � Change Approved Program C Operat. Shutdown ❑ Perforate fl Re -enter Suspended Well C._i 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p] Exploratory C • 203 - 078 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic E Service Q se 50 029 - 23154 - 00 — 00 7. Property Designation: y 8. Well Name and Number: ADL0025649 / ADL0025638 0 1C-170 9. Field /Pool(s): • Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12230 feet Plugs (measured) None true vertical 3798 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5159, 5159, 5808 . true vertical 0 feet (true vertucal) 3549, 3549, 3739 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 110 110 PRODUCTION 5987 12 6010 3763 PRODUCTION 5862 5.5 5890 3750 SLOTTED LINER 6345 4.5 12219 3798 SLEEVE 17'4" 12" 17'4" 17'4" RCEI M ? MAR 14 ?1, Perforation depth: Measured depth: 5910 - 12185 True Vertical Depth: 3750 - 3798 Alaska Oil & 6as Cons. Commission Anchorage Tubing (size, grade, MD, and ND) 2.875, L -80, 5808 MD, 3739 ND Packers & SSSV (type, MD, and ND) Baker ZXP Liner top Pkr, MD= 5885 ND= 3750 SEAL ASSY - BAKER "GBH" 80-40 SEAL ASSY W/ LOCATOR AND 2' @ 5808 MD and 3739 ND NIPPLE - Camco 2 7/8" x 2.312" (DS) Nipple @ 513 MD and 513 ND 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data NA Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development E • Service fl 15. Well Status after work: Oil N' Gas Q WDSPL fl Daily Report of Well Operations X GSTOR r i WAG r GASINJ r WINJ r SPLUG D 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: 310 -346 Contact MJ Loveland /Perry Klein Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date 3/7/11 RBDAAS MAR 21 Ups 3. Z /• !f Submit r Original 10-404 Revised 7/2009 g Only A/% . • 1C-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/04/11 I Removed 18' 9.5" of conductor to inspect surface casing 02/05/11 UT inspection found damage to surface casing that requires repair.Notified state man Chuck Scheve opportunity to witness damage to the SC. 02/21/11 1Welded 17' 4" sleeve fabricated from 12" X 65 .500 wall pipe. I 02/23/11 Preformed MITOA to 1800 psi. T /I /O = SI(0)/350/1800. 15 min T /I /O = SI(0)/350/1750. 30 min T /I /O = 81(0)/350/1750. 45 min T /I /O = SI(0)/350/1750. 60 min T /I /O = SI(0)/350/1750. Bled OA down to 0 psi. 03/05/11 I Insulators denso wrapped the surface casing. I 03/09/11 'Installed 19' 3" of 16" X 62.5# .375" conductor. I ..: '., . Vii S � y. 1 1 i 1 4 1� '` 4 r, \`, tit t 1 :41114.' l it t � 111 I I 1 t > d^ • = y O N Id 01 N co m N N col c G7. S C3 N n- onoCoPh flips Alaska, Inc ; ` , ♦ , pis photo is copyright by i . ; _ ; • ConocoPhilliips Alaska, Inc. • • , , , ' • . nth cannot be released or , 1 , . . . ♦ ♦ ♦ ♦ �. , II , * ♦ . . & .. •ublished without express ; :.. , ` • * ' ' • • , t'� =n cQ of ; oPftillips Alaska • .. • ♦ ' • • a ♦ igg bF • d • • tr , .' .. I ',- . '‘ 14:-,t, fr g Y of i - r r Rk 4 4 , " 4 :, ' "; ..e ' .,;'..?''',:,„4 ',1 ift`',it;, ,, T,. ,,.''''',.,'''-'''''''-':,-,' 4i :":- . ' , :: :, ,:.' / z '''''' "' ' 41"' ' '-'.'f:'''' ':,-*';':,;:-'s,-,:',;';-'''--!/4.-'-`..1 'f -1 ' -:-. ' 4":' ..\. � fir ,* u t , � ar m s , r :.. { L a" STATE OF ALASKA ALASKAlAND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell Plug Perforations ~"` Stimulate ~` Other "'" Alter Casing Pull Tubing Perforate New Pool "' Waiver Time Extension Change Approved Program ~`° Operat. Shutdown ~' Perforate ~'""` Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Fxpbratory ~""'" 203-078 3. Address: Stratigraphic ~ Service .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23154-00 7. Property Desig,~atior-~ 8. Well Name and Nurrt#Zer: ADL 25649, 25638 1 C-170 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12230 feet Plugs (measured) 5928 true vertical 3798 feet Junk (measured) None Effective Depth measured 12217 feet Packer (measured) 5885 true vertical 3798 feet (true verucal) 2759 Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 16 120 120 PRODUCTION 6008 7.625 6010 3763 PRODUCTION 5862 5.5 5890 3750 SLOTTED LINER 6345 4.5 12219 3798 ` 4,. Perforation depth: Measured depth: 5910'-12185' ~ ~ ~ ~ / 2 ®~ ' ' True Vertical Depth: 3750 -3798 ' ~18~k~ ~ ~'t ~i82 Cass. Ct1it~P11SSt9(t Tubing (size, grade, MD, and TVD) 2.875", L-80, 5829 MD, 3742 TVD At1Cli>D~B~E Packers & SSSV (type, MD, and TVD) Baker ZXP liner top pkr @ 5885' MD and 3750' TVD NIPPLE - Camco 2 7/8" x 2.312" (DS) Nipple @ 513 MD and 513 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 603 349 1 -- 222 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Developm nt Service 15. Well Status after work: Oil ~`', Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG ~'"" GASINJ "` WINJ '° SPLUG 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: 310-143 contact Brett Packer ~ 265-6845 Printed Name Brett Packer Title Wells Engineer Signature ,,~~i~l "/~~_ Phone: 265-6845 Date ,~~~~// tf ABDMS .itN. ~-z 7- ~o Form 10-404 Revised 7/2009 2'7 ~ submit Original Only KUP • 1C-170 coNDUCrOR, __~ za1 m NIPPLE, 513---- - GAS LIFT, ___ _ _..__ 2.339 GAS LIFT, 5,070 Wire Protector, 5,156 ~_ TBG STOP, - _ __,_ S.t58 SLEEVE-O, 5,159 ~__ PUMP, 5,159 - wire Prorector, _ _ _ __ 5,163 xO BUSHING,- _ 5,173 SENSOR, 5,183 XO BUSHING, 5,192 S FJr1 ASSV, 5.608 P ROOUCTION, , 23-5.850 PLUG. 1.527 PRODUCTION, 28-6,010 IPERF, 9.10&12,165 sLOTrED uNER, 5.876-12.215 TD (1C-170). _ 12.230 Well Attributes Max A ' ngle & MD TD Wellbore API/UWI Field Name Well Status ( Intl (°) MD (ftK6) Act Btm (ftK61 500292315400 ( WEST SAK ( PROD I 92.35 ~ 6,949.64 12,2300 Comment H2S (ppm) Date Annotation 'End Date KB-Grd (ft) Rig Release Date SSSV~ NIPPLE ) 100 ( 6/18/2006 Last WO: 6/23,'2010 I 34.11 5/27/2003 Annotation 'Depth (ftK6) EndDate Annoation Last Mod .../End Date Last Tag: ~ ~ Rev Reason' WorKOVer, Set Pump, Op en CMU Imosbor 7/11/2010 Casing Strings Casing Description CONDUCTOR String 0... 16 String ID ... T 15.062 op (ftK6) 290 Set Depth (i... 110.0 tr ng ... , tr ng ... Set Depth ( D) ... 110.0 62.50 ` H-00 r ng r op WELDED Casing Description String 0... String ID ... T op (ftK6) Sat Depth (f... Set Depth (ND) ... iString Wt... iString ... String Top Thrtl PRODUCTION 75/8 6.875 27.8 6,010.0 3,763.3 29.70 L-80 _ BTCM Casing DOSCription String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... ,String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 235 5,889.8 3,750.1 15.50 L-80 BTC-M Casin Dascri lion 9 P IStrin 0... 9 Strin ID ... 9 Top (HKB ) Set De th f... P ( Set De th ND String Wt... String ... ( P ( ) ~~~ ~~ String Top Thrd SLOT TED LINER 4 1/2 3.958 5,873.9 12,219.0 3.798.3 I 12.60 L-80 NSCT Liner Details Top Depth i. (ND) Top Intl Nomi... To ftK6) P( (fiK6) (°) Item Descri Lion ~ Comment P _.--_._ _ ( ID (in) _ 5,873.9 3.748.3 82.54 BAKER TIE BACK SLEEVE TIE BACK 5.750 5,884.9 3, 749.5 82.78 PACKER BAKER ZXP LINER TOP PACKER w/HRD PROFILE 4.930 5,892.9 3,750.6 82.961 NIPPLE RS NIPPLE 4 880 5,895.8 3,751.0 83.02IHANGER BAKER FLEX LOCK HYDRAULIC ROT. LINER HANGER 4.860 3,7522 8322X0 BUSHING CROSSOVER BUSHING 3.910 5,905.1 3.958 12,184.61 3,797.9' 89.45 BUSHING BAKER PACKOFF BUSHING - - - Tubing Strings ----- . Tubing Description String 0... String ID ... Top (ftK6) Set Dopth (L.. Set Depth (ND) . (String Wl... Str g Sfing Top Thrd ~ UE-M 23.5 I 5,829.0 I 3,/42.2 6.50 L80 TUBING 27/8 2.441 I _ .. Completion Details _ _ _ _ _ _ __ - - Top Depth (ND) lop Intl Nomi... Top (ftK6) (fiK6) (°) Item Description 1 Comment ID (in) 23.5 23.5 -0.56 HANGER 111" Vetco Gray Gen 1 TBG Hanger 2.900 26.2 26.2 -0.55 XO -Reducing ~i4 1/2" IBT x 2 718" EUE 8rtl Cross over 2.441 5128 512.7 1.39 NIPPLE Camco 2 7/8" x 2.312" (DS) Nipple 2.312 5,157.7 3,548.3 67.15 Wire Protector Fhned Wire Protector Sub j 2.500 5,158.8 3,548.7 67.16 SLEEVE-O Baker 2 7/S" CMU w/ 2.25" "D" profile (OPENED 7212010) 2250 5,162.7 3,550.2 67.23 Wire Protector Fluted Wire Protector Sub 2.500 5,171.811 3,553.81 67.36 XO -Enlarging 2 7/8" EUE 8rd x 3 1/2" EUE 8rd Cross over 3.80" OD 2.441 5,173.3'. 3,554.4 67.39 XO BUSHING 3 1/2", 9.3tF, L-80, EUE 8rd w/ SSC z 3 1/2" Hydril 511 Pin XO joint 2.992 5,1830 3,558.1', 67.54 SENSOR Ziebel Guage/Carrier. 4-5/16" OD 2.992 5,192.3~ 'i 3561.2 ~', 68.06 XO BUSHING 3 1/2", 9.3a, L-SQ 3 1/2" Hydril 511 x EUE 8rd Pin XO pup joint 2.992 5,808.31 3,739.0 ~ 81.12 SEAL ASSV Baker "GBH" 80-4G Seal Assy w/ Locator and 2' Space out 3.000 Other) n Hole (Wirelin pumps fish etc-) valves e retrievable plugs Top Depth ~ , , _ , , (TVD) Top Intl Top (HKB) (k K6) (°) Description Comment Run Date ID (in) 5,158 3,548 4, 67.15 TBG STOP ,TUBING STOP SET ON JET PUMP 7212010 5,159 3,548.51 6217 PUMP WEATHERFORD JET PUMP (SN CP-1159) ON 2.25" i T Th d N S i Wl S i St 7/2/2010 0.000 rat taste _tta ar,.irvra _ _ i Top (FVD) Btm (TVD) ~ D s 12,185 ) 3,797.91Shot _-- -- - - Top (ft!e) Btm (ftK6) (ftK6 (NKB I Zone Date L h Type Comment WS D, 1C-170 5/27/2003 99.0 IPERF Pre-Pertorated Slottetl L ` ~~. ; ~- ~ every other joint •~- Notes: General & Safety End Date Annotation 5/19/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 6/23/2010 NOTE: 5.5" ProduMion CSG set inside 7.875" CSG to provide two barriers from Formation landrel Details __ - _._ ~TOp Depth Top Port (rVD) Intl OD Valve Latch Size n Top(ftKB) (flKe) (°) Make I Model lint Serv TYPO _TYPe_ L'ni 1 2,338.5; 2,187.8 48.01 Camco IKBMG-M 1 GAS LIFT SOV BEK 0.001 25,069.8 3,512.765.32Camco IKBMG-M I IiGAS LIFT DMY IBK-5 X0.001 I i L • ConocoPhitlps Time Log & Summary Wellvlew Web Reporting Report -- Well Name: 1C-170 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/20/2010 9:00:00 AM Rig Release: 6/23/2010 6:00:00 PM - Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 6/20/2010 24 hr Summary Move Rig From 1 D-pad to 1 C-pad. Spotted Rig Over 1 C-170. NU 11" 5M BOPE & Tested. Racked & Strap 5-1/2" Cs . 00:00 03:30 3.50 COMPZ MOVE MOB P Move Rig from 1 D-Pad To KCC, to turn Rig Around to head toward 1 C- ad 03:30 04:00 0.50 COMPZ MOVE MOB P Standby with crews while moving rig mats 04:00 07:00 3.00 COMPZ MOVE MOB P Continue Rig Move to 1C-pad. 07:00 08:30 1.50 COMPZ MOVE MOB P Stage Rig mats and load New Tree in cellar 08:30 09:00 0.50 COMPZ MOVE RURD P Move Nordic Rig 3 over 1C-170 and set down. Accept Nordic Rig 3 @ 09:00 hrs on 6-20-10 09:00 09:30 0.50 COMPZ MOVE OTHR P Spot and level rig, berm up and spot auxilia a ui ment. 09:30 10:00 0.50 COMPZ WELCTL NUND P ND 7 1/16" Master valve. Install Test lu . 10:00 10:30 0.50 COMPZ WELCTL SFTY P Held PJSM with rig crew on NU BOPE a ui ment. 10:30 12:00 1.50 COMPZ WELCTL NUND P NU 11" 5M BOPE, install riser ni le. 12:00 18:00 6.00 COMPZ WELCTL BOPE P Fill Stack, Test 11" 5M BOPE 250/ 3,000 si w/ 5,1/2", 3 1/2" and 2 7/8" Test Joints. 18:00 00:00 6.00 COMPZ RPCOM PUTB P Rack & Strap 5-1 /2" Casing 6/21!2010 Run & Landed 5-1/2" Inner Casing String. Swap LPR from 5.5" to 2-7/8" . R/S 3-1 /2' TBG & 2-7/8"TBG. 00:00 02:30 2.50 60 1,900 COMPZ RPCOM PUTB P Begin Running 5-1 /2" Inner Casing Strin . 02:30 05:30 3.00 1,900 19 COMPZ RPCOM PUTS P POOH L/D Casing to Install 1 joint of 4-1/2" L-80 IBTM Tubin . 05:30 09:00 3.50 19 2,434 COMPZ RPCOM PUTB P MU 1 jt of 4 1/2 CSG and RIH w/ 5 1/2" Completion as per well plan from 19' to 2,434'. 09:00 10:00 1.00 2,434 2,434 COMPZ RPCOM CIRC P Change hole over at 2,434' from diesel to 9.6 ppg Brine at 3 bpm @ 210 psig. Taking returns to kill tank. Blow down lines. 10:00 15:30 5.50 2,434 5,893 COMPZ RPCOM PUTS P Continue to PU and RIH w/ 5 1/2", 15.5#, L-80 BTC-M inner CSG string from 2,434' to 5,893'. 100k up wt, 75k do wt. PU to 100k, mark pipe and pu 2' and mark pipe, POOH and la down 3 'ts fors ace out. Page 1 bf 3 • Time Lo s Date From To Dur S. De th E. De th Pha a Code Subcode T Comment 15:30 16:30 1.00 5,893 5,773 COMPZ RPCOM CIRC P Change hole over from 9.6 ppg brine to sea water @ 6 bpm @ 500 psi and increase to 8 b m 530 si. 16:30 17:00 0.50 5,773 5,880 COMPZ RPCOM HOSO P PU MUand RIH w/ 6-5 1/2", 15.5#, L-80 Space out pups w/ SSC for a total of 31.03'. PU jt 144 and RIH. PU and MU 5.875" MCA landing jt. RIH to 5,880' and Close annular. 17:00 17:30 0.50 5,880 5,883 COMPZ RPCOM FRZP P Reverse in 100 bbls of freeze protect diesel @ 4 bpm @ 500 psi. Slide in hole 3' and Brian stack. 17:30 18:30 1.00 5,883 5,890 COMPZ RPCOM HOSO P Land hanger and RILDS.Drain Stack, UD Landin 't 18:30 19:30 1.00 0 0 COMPZ RPCOM PRTS P R/U Hoses.Test 5-1/2" x 7-5/8" Annular to 2500 si for 5 mins. 19:30 20:30 1.00 0 0 COMPZ RPCOM EQRP P PJSM. C/O Lower Pipe Rams from 5-1/2" to 2-7/8" Pi a Rams. 20:30 21:00 0.50 0 0 COMPZ RPCOM PRTS P PT LPR to 250/3000 osi. 21:00 00:00 3.00 0 0 COMPZ RPCOM PULD P R/S 3-1/2" TBG & 2-7/8" TBG + Load PUP Joint on ri floor. 6/22/2010 Rack & Tally 3-1/2" - 2-7/8" Tubing. Rih w/ 2-7/8" Completion with Ziebel Guage Carrier, banding every joint to Hanger. Locater @SBE & Space out. Made Up Pup jt , LND joint + Hanger & M/U Tech Cable to Hgr. Pre to Reverse Circulate corrosion inhibited SW. 00:00 02:00 2.00 0 0 COMPZ RPCOM PUTB P Continue to Rack & Tally, Load Zeibel E ui ment. 02:00 05:00 3.00 19 1,200 COMPZ RPCOM TRIP P RIH w/ 3-1/2" - 2-7/8" Completion. 05:00 06:00 1.00 1,200 660 COMPZ RPCOM TRIP T Lost Signal On Ziebel Cable. Start Tri in Out Hole to au e. 06:00 07:00 1.00 660 660 COMPZ RPCOM TRIP T Tech wire damaged at Sliding Sleeve. Re aired and reconnected. 07:00 11:30 4.50 660 3,378 COMPZ RPCOM TRIP T RIH with completion to 3378', lost si nal on Ziebel cable a ain. 11:30 14:00 2.50 3,378 660 COMPZ RPCOM TRIP T POOH again to damaged tech wire 1st GLM. 14:00 14:30 0.50 660 660 COMPZ RPCOM TRIP T Repaired tech wire connection on gauage .Install SS band around top of gauge to hold tech wire off of bottom of hole. 14:30 17:30 3.00 660 3,378 COMPZ RPCOM TRIP T RIH again w/completion banding tech wire above and below GLMs & CMU slidin sleeve. 17:30 00:00 6.50 3,378 5,831 COMPZ RPCOM TRIP P Cont in-hole from 3378' - 5831'. R/U hoses, sting into SBE w/Charge pump. Seen psi increase as seal assy enter SBE. No Go @ 5,831'. UD 3 jts, From space out. M/U Pup, LND jt + Hanger. M/U Tech Cable to Hgr and Tested. Up Wt= 65k /Down Wt=50k. Used 149 Cannon Cable Clamps & 16 SS Bands on Tech Cable. 6/23/2010 RIH & Landed 2-7/8" Completion.Complete ND BOPE. NU Tree, made final Splice of TEC wire to enetrator.Tested tree to 5K. Pull Check Valve. Freeze Protest Well. Install BPV. Secure Cellar. RDMO Page 2 of 3 L~ • Time Lo s Date From To Dur S. De th E. D th Phase Code Subcode T Comment 00:00 01:30 1.50 5,831 5,831 COMPZ RPCOM CIRC P Reverse Circulate Corrosion Inhibited SW 3 b m, 410 si. 01:30 02:30 1.00 5,831 5,831 COMPZ RPCOM PRTS P Land hanger,Up Wt= 65k / Dn Wt=50K. Test Tech Cable. RILDS. PT Han er To 5000 si for 15 mins. 02:30 03:00 0.50 5,831 5,831 COMPZ RPCOM PRTS P R/U Hoses and PT Tubing tg~QQ__ psi for 15 mins & Chart. No Return from Annulus. 03:00 03:30 0.50 5,831 5,831 COMPZ RPCOM PRTS P Bleed down Tubing to 2500 psi & PT IA to 3,500 psi & Chart on recorder for 30 mins. 03:30 04:30 1.00 5,831 5,831 COMPZ RPCOM PRTS P Bleed Down IA to Zero then bleed Tubing to Zero. Psi up on IA and shear SOV. Pull Landing Joint. Pull isolation sleeve, Set Two-Way Check. 04:30 11:30 7.00 0 0 COMPZ RPCOM NUND P ND BOP Stack. Change out rams, putting variables in bottom, 3 1/2" rams in top and replaced Annular Element. Continue ND BOP stack. 11:30 13:30 2.00 0 0 COMPZ RPCOM PRTS P NU tubing head adaptor and tree. Ensure proper orientation of tree with picture taken before ND. Pressure test tree to 250/5000 psi. Test packoff to 250/5000 psi. Pull two way check. 13:30 16:00 2.50 0 0 COMPZ RPCOM FRZP P Freeze protect the well down to 2,358 RKB by pumping 51 bbls diesel down the IA through the SOV, taking returns out the tubing. Put the tubing and IA in communication with hose and allow toe ualize. 16:00 16:30 0.50 0 0 COMPZ RPCOM MPSP P R/D Lines & Hoses. Set BPV 16:30 18:00 1.50 0 0 DEMOB MOVE DMOB P Move Rig Off Well, & Clean up Well. Ri Relased 1800 hrs- 6/23/2010 Page 3 of 3 ~1C-170 Well Events Summary DATE SUMMARY 5/11/10 30 MIN PRESSURE TEST ON 7 5/8 CASTING PASSED WITH 0 PSI LOSS. 30 MIN DD TEST PASSED WITH 0 PSI BUILD UP. 5/13!10 SET IBP IN 7.625" CASING WITH MID-ELEMENT AT 100' AND 450 PSI BELOW PLUG. PT PLUG TO 3000 PSI FOR 30 MIN, BLED PSI TO ZERO AND MONITOR FOR 30 MIN (GOOD) READY FOR WELLHEAD CREW. 5/15/10 Replaced Vetco Gray wellhead for RWO. Installed new wellhead without the tubing hanger. Shell tested swab valve and wellhead to 3000 psi. 5/18/10 STAND BY FOR WX. PULLED 4.25" IBP @ 74' SLM. READY FOR IBP. 5/21/10 PERFORMED BOPE TEST. PULLED 3.73" OD CATCHER-SUB FROM 5907' CTMD. 5/22/10 PULLED 3.69" OD WEATHERFORD 4-1/2" WRP FROM 5910' CTMD. PERFORMED MEMORY LOG FOR PRESSURE, TEMPERATURE, AND GAMMA/CCL CORRELATION FOR IBP SET (NEXT STEP). LOGGED 30-MIN STATION AT 6000.7' CTMD AND GRADIENT STOP 100' TVD HIGHER AT 5486.7 CTMD. SBHPS RESULTS: 6001'; 1484-PSI, 74-DEG F. 5487'; 1407-PSI, 73-DEG F. 5/24/10 SET 2.125" x 1.1_.06'_ BAKER IBP WITH 1.375" FISHING NECK (5500# PULL RELEASE / 1840# PUSH TO EQUALIZE) 5927.38' CTMD (CORRECTED TO CCUCOIL FLAG 5/22/10),CIRCULATED 170 BBLS 9.6 INHIB BRINE AND 107 BBLS DIESEL FREEZE ~ PROTECT.PRESSURE7ESTED IBP TO 3000 PSIG (GOOD),DRAWDOWN TO ZERO (GOOD). READY FOR RWO 6/27/10 PULLED IBP FROM 5932 CTMD, ONE RUBBER ELEMENT LEFT IN THE HOLE, WELL IS FREEZE PROTECTED, READY FOR S/L. 6/29/10 SET F-COLLAR STOP FOR CATCHER. PULLED SHEARED SOV & REPLACED W/NEW 2000# TBG SHEAR @ 2328' RKB. UNABLE TO MIT IA DUE TO CHECK VLV DN STREAM OF TIE IN & NO GATE VLV ON FRONT OF TREE. PULL F-COLLAR STOP. JOB COMPLETE 7/1/10 GAUGED TBG TO 2.285" TO 5159' RKB. EXERCISED CMU @ 5159' RKB & FLUSHED WITH 20 BBLS DIESEL. PERFORMED 30 MIN MIT-IA. '`*PASS"". IN PROGRESS. 7/2/10 PERFORMED 30 MIN MIT-IA TO 3500#. **PASS'`*. OPENED CMU @ 5159' RKB. SET WEATHERFORD JET PUMP (9-B RATIO/ SER# CP-1159/ OAL= 51") ON 2.25" C-LOCK @ 5159' RKB. SET TBG STOP @ 5158' RKB. JOB COMPLETE. r~.~a ~05A~ 1~`~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1C-170 Run Date: 5/13/2010 May 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 C-170 1 CD Rom Digital Data in LAS format, Digital Log Image file 50-029-23154-00 ^rt qq1 .I,µ~~~ ~y ~~i ~~3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr ~~ ~ ~3 -b ~~ /~~~~ ~ ~ ~~ - ~ Signed: Date: ;~„ .r., ;~ ` ~ gas. `s ~ ~±.~~~ j~ j~ • • ~~Q~C~ 0~ Q~Q~~{Q /,E.,M,.~.~o~.~. Brett Packer Wells Engineer ConocoPhillips (Alaska), Inc. _. ~ r~ ~ , ~ ;~ ~~~, .~ ~ .;m~~:,~ u P.O. Box 100360 ~ ~~'~ Anchorage, AK 99510 ~.,. Q ~~ Re: Kuparuk River Field, West Sak Oil Pool, 1 C-170 Sundry Number: 310-143 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good .cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 2~ DATED this I day of May, 2010. Daniel T. Seamount, Jr. Chair Encl. I~ STATE OF ALASKA ~~~~~ ~ 5~~2 ALASl~IL AND GAS CONSERVATION COMMISS• ~ ~~,'~ APPLICATION FOR SUNDRY APPROVALS MAY 4 4 201D 20 AAC 25.280 1. Type of Request: Abandon ~'" Rug for Redrill ~"" Perforate New Pool r" Repair well ~ ~~~ ~ Suspend ~"" Rug Perforations Perforate ~" ~~nsion Pull Tubing ~'', Operational Shutdown I"`. Re-enter Susp. Well ~°' Stimulate Alter casin g ' Other: "" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~` Exploratory I""` 203-078 r ' 3. Address: Stratigraphic ~` Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23154-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No ~ 1C-170 9. Property Designation: • 10. Field/Pool(s): ADL 25649, 25638 Kuparuk River Field /West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fl): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12230 3798 12217' 3798' 5928' Casing Length Size MD ND Burst Collapse CONDUCTOR g2 16 120' 120' SURFACE 6008 7.625 6010' 3763' LINER 3949 4.5 12219' 3798' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9108'-12185' 3789'-3798' none Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -LINER BAKER 'ZXP' PACKER W/HRD PROFILE MD= 5885 TVD= 3750 no SSSV 12. Attachments: Description Summary of Proposal ~` 13. Well Class after proposed work: Detailed Operations Program ~"';, BOP Sketch I~ Exploratory > Development ~I Service ~"'` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2010 Gas WDSPL Suspended Oil ~' 16. Verbal Approval: Date: , WINJ ~"' GINJ ~ WAG Abandoned Commission Representative: GSTOR SPLUG L 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Engineer ~ ~ Signature ~~ '~~ COL-. Phone: 265-6845 Date ~~3 /~~ C nl Sundry Number: ~11~ .., I-t Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical IntegrityTest '~°" Location Clearance Other: ~ JLaO iOSr, ~C.~O/ S~ • ~ Z soya PSG ~tiw~ i S~ C ~--~.. I Subsequent Form Required: /,(, ~/ D c./ Approved by' COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 Y ~ ~ ~~ r ~'~~ ~° Submit in Duplicate RIGINAL r~L~ -~~ 5 ~` • ~. ~ ConocoPhrll~p-s P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 29, 2010 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1C- 170 (PTD# 203-078). Well 1C-170 was drilled and completed in May 2003 as a West Sak single lateral jet pump producer. The well produced on jet pump lift for approximately 4 years until it was SI due to low bottom-hole pressure. Shortly after being SI, a Matrix Bypass Event (MBE) occurred between the offset injector 1C-174 and another producer 1C-178. The offset injector was SI until such time that the MBE could be remediated which therefore left 1C-170 unsupported. Around the same time, a discovery of severe casing corrosion in two Tarn jet-pumped wells had raised concern for the possibility of similar corrosion issues in West Sakfet-pumped wells. 1 C-170 is one of the original four West Sak single-casing jet-pumped wells along with 1C-135, 1C-178 and 1C-184. Apro-active workover on this well was done in November 2007 to pull the tubing. The well was left without tubing in the well so that casing inspection logs could be run post-rig. The tubing and casing inspections indicated that there are no corrosion issues similar to what was seen at Tarn. Nevertheless, new internal policy dictates that we must have two barriers between any energized fluid (power fluid or gas lift) and the formation. Thus, the original four West Sak single casing jet-pumped wells were shut- in until such time that an inner string of 5'h" casing can be installed within the 75/8" surface casing. The other three West Sak single casing jet-pumped wells were successfully worked over in 2008 and early 2009, but the workover on this well continued to be postponed due to lack of injector support. Finally, in May 2009, the MBE in injector 1C-174 was successfully remediated and the well brought back online, which meant 1C-170 was no longer unsupported and could then proceed with the workover, but due to the economy, we laid down the workover rig in mid-2009. The proposed workover plans include installing an inner string of 5'/" casing and re-completing the well with a 2'/8" jet-pump/gas-lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. There is currently a plug in the well, but prior to setting the plug in 2007, the SBHP measured 1073 psi at 3565' TVD which equates to 5.6 Before the upcoming workover, plans are to pull the wireline retrievable plug, obtain a current SBHP, an rye-install an inflatable bridge plug to isolate the well from the formation during the workover. Depending on the new SBHP, likely seawater or 9.6 ppg brine will be used as kill weight fluid. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ;~~ ~~ Brett Packer Wells Engineer CPAI Drilling and Wells West Sak 1 C-170 General Workover Procedure PTD 203-078 Pre-Riq Work .. 1. RU CTU, Pull catcher sub and WRP. 2. Shoot a fluid level and calculate SBHP (9.6 ppg brine currently in well) - 3. Seta 2.125" IBP in the 7%8" casing at 5928'. PT the IBP to 3000 psi, perform a drawdown test.' 4. Load the well with 9.6 ppg brine (or new KWF). RDMO CTU. 5. PT casing packoffs, function test LDS's. General Workover Procedure 1. Verify Sundry approval acquired. 2. MIRU Nordic #3. 3. Verify well is dead, NDfull-opening valve. ND Tubing head, install new casing spool and tubing head. (IBP and KWF provide two barriers) --- 4. NU BOPE. Install blanking plug. Test casing breaks below blanking plug to 3000 psi., Pressure test BOPE to 250/3000 psi 5. RIH w/ PBR seal assy and SBE on 5'/2" BTCM casing. - 6. Tag up on PBR, pull up & reverse circulate corrosion inhibited brine & freeze protect. 7. Space out and land 5'/z" casing. RILDS. PT 5'h" x 75/8" outer annulus to 2500 psi. , 8. PU & RIH w/ 2'/8" gas lift/jet-pump completion w/ downhole gauge. 9. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 2%8" completion. RILDS. PT tubing to 3000 psi. Bleed tubing to 2000 psi. Pressure test IA to 2500 psi. Ramp up IA pressure to shear the SOV. 10. Set 2-way check. ND BOPE. NU tree and pressure test to 5000 psi. , 11. Pull 2-way check, freeze protect with diesel. y 12. Set BPV and RDMO Workover rig. , Post-Riq Work 1. Pull BPV 2. RU CTU: Pull the catcher sub &IBP 3. RU Slickline: Open the CMU, set the jet pump. Set a catcher sub above the pump. Pull the SOV and replace w/ a DV. Retrieve the catcher sub. 4. Return to production. • ~t~~P`~11~ Well: 1 C-170 2010 RWO PROPOSED COMPLETION API: 500292315400 PTD: 203-078 Wellhead: Gray Horiz X-mas Tree: 3-1/8", 5K psi Lift Threads: 4.909" MCA BPV: 4" 'H' • Tubing = 2'/:', 6.5 ppf, L-80, 8rd EUE • 2.313" DS-nipple. . Baker 2'/8' CMU w/ 2.25" D profile. • Ziebel Gauge. • 3'/" EUE SCC tubing. • Baker locator w/ 17' seal assy. • Casing = 5'/",15.5 ppf, L-80, BTCM w/ SCC. • Crossover from 5'/",15.5# BTCM. • 20' SBE. • Baker 80-40 Locator w/ 10' seal assy. (4.75" OD) Directional: Max Incline: 92.4° @ 6950' Max Dogleg: 17.9° @ 7106' Conductor: 16", 62.5#, H-40 at 110' Surface Casino: 7.625", 29.7#, L-80 BTCM to 6,010' Tie-Back Liner: 5.5", 15.5#, L-80 BTCM to xxxx' Slotted Liners: D-Sand: 4.5" to 12,219' Gas Lift Mandrels: MD TVD Tvpe 2,358' 2,200' 2-7/8" KBMG, 1" 5,283' 3,595' 2-7/8" KBMG, 1" 2.25" D-profile sliding sleeve for jet pump Ziebel Downhole Gauge/Carrier. Crossover to 5.5" BTCM. 20' SBE. PBR at 5,872' MD. DB Baker ZXP Liner Top Packer at 5,885'. TD: 12,230' RKB Last Updated: 27-Apr-10 Updated by: JBP r~'.r--- ~-. SURFACE (0-6010, OD:7.625, W L29.70) SLOTTED LINER (5874-12219, OD:4.500, WC12.60) Perf (9108-12155) C~-n~c4~ttllp~ A~a~ka, tic. KRU 1 C-170 ~ U ~~L ~ ~~ ~/'~~f {!~f If/,~~~ P~oAcrive Dinqivos~ric SeAVicfs, l+vc. To: AOGCC Christine Mahnken 333 West 7th Avenue S~ite '! 00 Anchorage, Alaska 99501 (907) 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing inspection(Caliper/ MTT~ The technical data listed below is being submitted herewith. Piease acknowledge receipt by returning a signed copy af this transmittal letter to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~~w "~y ~,,~~ (~ C; ~ `~6 ~~ Anchorage, AK 99518 ~"' ~ ~~ ~ ~ ~~~,~ Fa~c (907j 245-8952 ~~ ~ ~ ~ 1) Caliper Report 13-Aug-Q~ 1 G170 (Revised],~ 1 Report / E~ 50-029-2315400 ~--= ~~ - 2) MTT 15.Jun-09 1 G170 (Revised] 1 Report 50-029-2315400 ~03 -- C~~ ~ , ~ ~ Signed : Print Name: /~33~ , ~ - Date _ _ _ , - ~ .,, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATtONAL AIRPORT RD SUITE C, ANCHORAGE, AK 9951$ PHONE: (907)245-8951 FAX: (907~245-88952 E-hWIL : ~ ~' "" WEBSITE . C:~Documents and Se[tings\Ownec~Desk[op\Trensmit_Conooo.docx . • ~ rVlemory Mu1ti-Finger Caliper & Magne~ic Thickness Toot ~ Log Result~ ~ummary ;. ~-~ ~~- $~ REVtSED 4~- ~~~~ (July 17, 200~9j Company: ConocoPhiliips Alaska, Inc. Well: 1C-170 Log Date: August 13, 2007 Field: West Sac Log No. : 9505 State: Alaska Run No.: 1 API No._ 50-029-23154-00 Pipe1 Desc.: 4.5" 12.6 Ib. 1.-80 Top Log Irrtvl1.: Surtace Pipe1 Use: Tubing Bot. Log Intvl1.: 5,711 F#. (MD) Pipe2 besc.: 7.625" 29.7 Ib BTCM Top Log InNl1.: Sur~ace Pipe2 Use: Surface Casing Bot. Log Infirll.: 5,703 Ft. (MD) (MTT only) Pipe3 Desc.; 16" 62.5 Ib W~LDED Top Log lntvl1.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl1.: 130 Ft. (MD} (MTT only) Inspection Type : Corrosive & Mechanica! Damage lnspection COMAAENTS ; This report has been revised to put the MTT data on depth with successive MTT /ogs, rather than the calipet data, and to adjust tf-e presentation of the Delta Metal Tf-ickness curve to the newer standard format fihe ca)iper Jog is tfed into the D Wipple aCi 5,249' (Driller's depth), while the MTT data is tied into the Mandrd Hanger ~ 0' Depth. This is the first log of this wel! with the 24-Arm Mufti-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of tne internat surtace of the 4.5" tubing in this well while the Magnetic Tfiic~Cness Tool responds to the total thictcness of inetal of the 4.5" tubing, 7.625" surtace casing, and 16" conductorwithin the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. Generally, intermitterrt high-frequency metal loss indications are attributed to metal loss of the tubing or inner-most string, and metal loss to outer concentric strings wili be denoted by lower frequency shifts in the average metal loss of all twelve sensors combined: In this log, the MTT was calibrated down hole (615'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" surface casing and 16" conductor pipe. tNTERPRETATtON OF CALlPER LOG RESULTS FOR 3.5" TUBING ; This log vwas run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing interval logged is in good condition with respeet to internal corrosive damage, except for a wall penetration of 22°/n recorded in joint 49 ~ 1,526'. The damage appears to be in the form of Isolated Pitting. No significant areas of internal cross-sectional wall loss or t.D. restrictions are reeorded by the caliper. ProAc6ve Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: {281) 565-1369 E-ma~l: PDS~^a~memorylog.com Prudhoe Bay Field t~fFice Phone: (907) 659-2307 Fax: {907) 659-2314 ~~3 -o~~ l~33 ~ • ~ 4.5" Tubing - MAXIMUM RECOR~ED WALL PENETRATIONS: isolated Pitting ( 229~0) Jt ~F9 t~A 1,526 Ft. (MD) No other significant wall penetrations (>19°~) are recorded. 4.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significan# areas of intemal cross-sectional wall loss (> 3%) are recarded. 4.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D restrictions are recorded. INTERPR TATtON OF MTT L~G RESUI,TS : A graph of the average metal loss ~s~essed firom the MTT data on a joint-by joint basis is included in this report. The MTT log resuits indicate metai loss to some degree throughout the intervat logged, vvith intervals of more significant metal loss indicated over the top -200' of the well and over #he interval -2,000` to ~2,500'. Detail prints of the MTT recordings over the intervals 3' -170' ar~d 1,820' - 2,180' are included in this report. The later interval was chosen to iNustrate the difference in the recordings over the interval above 2,(300' (where less metal loss is indicated) and the interva4 below 2,000' (where more significant metal loss is indicated). Throughout most of the logged interval, the correlation of the abundance of high frequ~ncy tool responses on individual sensors to the shift in the average change in overalf inetal thickness curve points to the probabitity that a majority of the metal loss indicated is a feature of the outside of the tubing. An exception to this occurs over the interval just beiow the hanger (4' -13' ) where the overafl metal change curve shows a discernable loss of inetal, but high frequency responses on the individual sensors are very fimited. ~his points to the probability that the metal loss over this interval just below the hanges is a feature of an outer casing string, rather than the tubing. The minor damage recorded by the caliper on the internal surface of the tubing does not appear to have a ' significant influence on the pattern o# metal loss indicated by AATT over the logged interval. This suppo-ts a conclusion that there is significant metal loss in this weli bore over the intervals 3' -170' and 2,q00" - 2,500' that are not assaciated with the internal surface of the tubing. ~ , Field Engineer. S. Carpenter Analysts: J. BurtonlM. Lawrence/8. Qi Witness: C. Kennedy ' ProActive Diagnostic Services, Inc. / P.O, Box 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9085 Fax: (281) 565-1369 E-mai{: PDS@memarylog.com ' Prudhoe Bay Field Office Phone: (907j 659-2307 Fax: (90~'} 659-2314 ' • ~ Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 4.5 in (14.1' - 5681.4') Well: 1 C-170 Field: West Sac Company: ConocoPhi~ips Alaska, Inc. Country: USA Survey Date: Aug 13, 2007 . A pprox. Tool De viation ^ A pprox. Borehol e Profil e 18 758 1532 2316 ~ GLM t ~ c t 3121 a~'i 0 3889 4664 CLM 2 5495 181 5681 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottorn of Su rvey = 181 I 25 : ~ _r.-r.., 50 75 a`, E ~ Z ~0 700 125 150 175 ~ ~ PDS Report Overview ~, ~d. Body Region Analysis Well: 1C-170 Survey Date: Aug 13, 2007 Field: West Sac Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Too) Size: 2.75 Country: USA No. of Fingers: 40 Anal st: B. i Tubing: Nom.OD Weight Grade & Thread Nom.l[~ Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body r metal loss body 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 185 pene. 1 133 50 1 0 0 loss 111 74 0 0 0 0 Damage Configuration ( body ) 40 30 ZU 1O 0 isolated general Iirre ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 37 37 0 0 0 0 Damage Profile (°k wall) ~ penetration body ~ metal loss body 0 SO 100 0 50 GLM 1 98 148 GLM 2 Bottom of Survey = 181 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABUI~°~TION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-170 Body Wall: 0.271 in Field: West Sac Upset WaN: 0.271 in Company: ConocoPhilips Alaska, inc. Nominal I.D.: 3.958 in Country: USA Survey Date: Aug 13, 2007 Joint No. Jt. Depih (FL) f'cn. l JF~sc~t (Ins.) Pen. gody (Ins.) 1'en. °~~ Mc~i.il I~„~ ~ Min. I.D. (Ins.) Comments Damage Profile (% wall) il 5[T~ 10Q .1 14 ~~ 0.01 -t 1 3.96 PUP 1 18 U 0.01 4 3.91 1.1 49 ~~ 0.01 5 I 3.92 PUP 2 51 t~ 0.01 ~ ' .9 3 81 U.l)1 0.02 ~ 3 3.9 4 112 U 0.03 1 u _' 3.93 5 143 U 0.03 1 U s 3.93 6 173 U 0.01 4 3.93 7 04 0 0.01 ~ 3 94 8 235 ~~ 0.01 5 I 3.94 9 2 65 ± 1 0.03 1 U ~ 3.94 10 296 ~? 0.02 7 ' 3.9 11 326 U 0.02 (> I 3.9 12 357 U 0.01 -4 _' 3.95 1 387 u 0.01 5 I 3.93 14 418 U 0.05 1~) _' 3.94 hallow ittin . 15 448 ~ 0.02 6 ' 3.94 15_1 478 U 0 O U 3.88 Ni le 16 481 U 0.01 4 .' 3,94 17 511 i) 0.01 i _' 3.92 18 541 ~~ 0.05 1' s 3.94 Shallow it~n . 19 572 ~~ 0.01 4 I 3.94 20 602 U 0.0 ti ~ 3.91 21 633 U 0.01 ~1 ' 3.91 2 665 ~) 0 01 5 I 9 23 696 (~ 0.01 i ~ 3.93 24 7 7 ~~ .01 4 1 3.94 25 758 O 0.01 i _' 3.95 26 788 U 0.02 7 ~ 3. 4 27 819 0 0.05 17 _' 3.93 Shallow itUn . 28 849 U 0 U U 0.00 29 881 (~ 0.04 1~1 I 3.93 Shallow ittin . 30 912 0 0.02 t5 Z 3.9 37 942 U 0.02 ' ' 3.93 32 974 ~~ 0.05 I ti 2 3.95 Shallow ittin . 33 1005 t~ 0.02 9 1 3.92 34 1037 ~) 0.03 10 1 3.9 35 1068 u 0.02 8 1 3.90 36 109 ~~ 0.03 i l ~' 3.92 Sh Ilow ~tUn . 37 1130 ~? 0.01 5 1 3.94 8 1 62 U 0. 3 1" 2 3.93 hallow ~ttin . 39 1192 U 0.02 E, ' 3.94 40 1223 ~? 0.04 l s I 3.95 Shallo ittin . 41 1253 ~~ 0.03 11 ' 3.92 4 1284 c~ 0.05 1 t3 I .91 Shallow itUn . 43 1316 ~~ 0.03 I I ~ 3.89 44 1348 i~ 0.01 t 3.94 45 1378 U 0.01 ~i _' 3.93 46 1 8 U .0 19 I 3.93 Shall w itUn . 47 1440 U 0.05 1~) ~ 3.93 Shall w itUn . Penetration Body Metal loss Body ~ r. Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Nipe: 4.5 in 12.6 ppf L-80 Well: 1 G170 Body Wall: 0.271 in Field: West Sac Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: Aug 13, 2007 Joint No. Jt. Depth (Ft.) I'c~i~. I l~ ~~c~t (In,.) Pen. Body (Ins.) P<~n. % Vict.~l I t~~t °~~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 48 1472 ~~ 0.04 15 ~' .91 Shal w ittin . 49 1502 l~ 0.06 '_' _' 3.93 Isolated ictin 50 1532 ~~ 0.02 ti I 3.92 51 1563 ~ ~ 0.02 ~) 3.93 5 1595 ~ ~ 0.02 <1 ~ 3.95 53 1626 t> 0.02 8 ~ 3.95 54 1657 ~) 0.03 I~ ~ ? 3.95 55 1689 0 0.02 ~~ I 3.92 56 1719 t~ 0.04 15 I 3.93 Shallow itUn . 57 1750 U 0.04 14 I 3.95 Sha low ittin . 58 17 1 11 0.02 i 1 3.93 59 1812 ~ ? 0.0 ~) _ 3.93 60 1843 (~ 0.01 4 _ 3.91 61 1874 ~~ 0.01 ~ I 3.92 62 1907 t) 0.0 t~ I 3.93 Shallow it6n . 63 1937 tt 0.04 l t _' 3.92 Shallow itUn . 64 1968 ~) 0.02 ~~ ~~ 3.93 65 1998 ~~ 0.01 4 ? 3.91 66 2030 c~ 0.01 s _' 3.91 67 062 t? 0.01 4 I 3.92 68 2094 (~ 0.01 4 I 3.92 69 212 S ~~ 0.02 t, I 3.92 70 2156 l1 0.02 ~ I .88 71 2189 t) 0.01 -~ I 3.92 7 2221 t~ 0.01 `~ I 3.95 73 2253 (~ 0.01 4 1 3.93 74 2 84 t~ 0.01 ' I 3.92 75 2316 ~~ 0.01 4 1 3.93 76 2348 ~~ 0.02 (> 1 3.93 77 2380 i~ 0.01 3 I 3.93 78 2412 ~) 0.01 5 1 3.93 79 2441 ~ 1 0.02 7 I 3.93 80 2473 ~~ 0.01 4 ' 3.93 81 2505 U 0.01 4 1 3.93 8 2537 ~1 0.02 c, 1 3.93 83 2568 t~ 0.01 -1 1 3.94 84 2600 U 0.02 7 1 3.94 85 2632 u 0.03 10 I 3.89 86 2664 ~~ 0.01 5 I 3.94 86.1 2695 ~) 0.01 5 I 3.94 PUP 86.2 2702 l~ 0 t) iJ N A GLM 1 latch ~2:30 863 2714 t~ 0.01 3 I 3.94 I'UP 87 722 t i 0.02 (> _' 3.93 88 2 752 ~~ 0.01 4 I 3.92 89 2785 ~~ 0.03 10 1 3.94 90 2815 i~ 0.03 1 1 1 3.94 91 2846 l1 0.01 i I 3.95 92 2876 U 0.03 1 U ~ 3.92 93 2907 U 0.0 8 I 3.9 94 2938 i~ 0.05 1 t3 I 3.93 Shallow ittin . Penetration Body ~ Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-170 Body Wall: 0.271 in Field: West Sac Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. fVominal I.D.: 3.958 in Country: USA Survey Date: Aug 13, 2007 Joint No. )t. Depth (Ft.) I'c•n. Up~c~t (InS.) Pen. Body (Ins.) Pen. % :'vletal I oss °~~~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 95 2968 U .02 i I 3.94 96 299 ~) 0.04 1-l I .93 Shallow 'ttin . 97 3029 ~~ 0.03 1 I 1 3.94 98 054 ~~ 0.02 6 I 3.93 99 3091 U 0.0 ti I 3.93 100 3121 ~ ~ .02 I 3.9 101 3152 i! 0.03 1I I 92 102 3182 t ~ .03 ~i 3.92 103 321 ~~ 0. 3 1 ~~ 3.93 104 3244 ~~ 0.01 4 I 3.92 105 3275 i~ 0.03 I U I 3.94 106 3306 ~ ~ 0.02 ~l I .94 107 3335 ~~ 0.03 1? I 3.92 Shallow ittin . 108 3366 U 0. 3 1' I 3.86 Shallow itUn . 109 3397 u 0.01 s I 3.91 110 3429 ~~ 0.02 7 I 3.. 11 3459 ~~ 0.02 ~~ I 3.93 112 3490 t~ 0.01 E~ ' 3.93 113 3521 ~~ 0.03 12 1 3.93 Shallow ~tb 114 3551 ~~ E~ I 3.93 115 3582 ~~ .04 13 I 3.94 Sh low it'n . 11 3613 U 0.03 1 U .92 117 364 ~~ 0.02 ~ I 3.94 118 3674 ~~ 0.03 1 1 I 3.90 Shallow itUn . 11 3704 ~~ 0.01 i 3.93 120 3735 t~ 0.04 L5 I 3.92 Shallow itUn . 1 1 3765 ~~ 0.01 5 3.93 122 3795 ~~ 0.03 11 ' 3.94 1 3827 U 0.04 1.S I 3.9 Shallow 't6 124 3858 ~~ 0.02 '~ 3.92 2 3889 u 0.03 1~~ I 3.91 126 3920 ~ ~ 0.01 -1 3.93 127 3950 ~~ 0.02 ts > 3.95 128 3980 ~~ 0.03 1 1 ~ 3.87 129 4012 U 0.03 13 _' .95 Shallow it'n . 130 4044 l) 0.03 1 1 ~ 3.91 131 4075 t) 0.02 8 I 3. 8 132 4106 (~ 0.02 ts i 3.94 133 4137 U 0. 4 1~l I 3.9 S allow itUn . 134 4169 ~~ 0.03 1 ~) 1 3.92 135 4199 ~~ 0.04 13 1 .93 Shallow 'ttin 136 4230 ~~ 0.03 1 t) 1 3.92 137 4261 l~ 0.03 11 2 3.92 hall w itun . 138 4291 (a 0.02 f3 1 3.93 139 432 U 0. 3 12 2 3. Shallow i tin 140 4353 O 0.03 I I 1 3.94 Shallow itfin . 141 4385 ~~ 0.03 12 .' 3.93 Shallow itUn . 142 4415 t~ 0.04 13 I 3.92 Shallow itUr . 14 4446 ~~ 0.03 11 I .93 144 4478 ~'~ 0.03 12 3.90 5hallow itUn . Pe~etration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-170 Body Wall: 0.271 in Field: West Sac Upset Wall: 0.271 in Company: ConocoPhinips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: Aug 13, 2007 Joint No. Jt. Depth (Ft) P~~n. l 1E,s~~t (liis.) Pen. Body (Ins.) f'cn. %, Me~tal I oss "4~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 145 4510 l) 0.02 ~) 1 3.93 146 4541 ~ 1 0 03 I 1 Z 3.93 147 4571 U 0.03 1l1 ~' 3.92 148 4602 ~> 0.02 ~~ I 3.91 149 4633 ~~ 0.03 I I I 3.91 150 4664 i~ 0.03 1 I i 3.92 151 4695 ~~ 0.01 5 ~ 3.92 152 4725 ~~ 0.02 fi 1 3.92 153 4755 ~~ 0.03 1"1 1 3.90 Shallo 't9n . 154 4786 ~~ 0.03 12 I 3.91 Shallow ittin . 155 4817 ~~ 0.03 1 U I 3.91 156 4847 ~? 0.02 ti I 3.92 157 4F378 ~ ~ 0.03 I I 3.92 158 4909 ~ i .02 ~ I 3.93 159 4940 ~~ 0.03 1 t1 ~' 3 91 159.1 4970 c) 0.01 4 I 3.91 PUP 159.2 4980 U 0 U t~ N A GLM 2 latch ~ 5:00 1593 4988 U 0.03 1 U 1 3.93 PUP 160 4997 ~~ 0.03 '~ _' 3.92 161 502 8 i t 0.03 I 1 I 3.93 162 5058 i! 0.01 -~ 1 3.92 163 5088 t~ 0.02 ~) I 3.90 164 5119 ~~ 0.01 -1 ~' 3.91 165 5150 ~~ 0.01 E~ I 3.91 16 .1 51 t1 0 t) ~.i 3.81 Siidin eve 165.2 5209 ~~ 0 l) il 3.91 Gau Carrier 166 5217 i 1 0.01 5 1 3.90 166.1 5249 t~ 0 l) r~ 3.75 D Ni le 167 5250 t~ 0.00 I ~ 3.91 168 5280 U 0.01 -3 1 3.92 169 5310 ~ 1 0.02 E~ 1 3.91 170 5341 l) 0.02 i ~ 3.91 171 5371 ~1 0.01 ~ 1 3.92 172 5402 u 0.01 3 ,! 3.92 173 5433 (~ 0.01 5 I 3.9 174 5463 i~ 0.01 ~ I 3.92 175 5495 t~ 0.02 I 3.92 176 5525 ~~ 0.01 I 3.91 177 55% ~~ 0.03 I~) I 3.92 178 5588 u 0.02 t3 3.91 179 5619 ~~ 0. 1 i 1 3 92 180 5649 l t 0 u ~~ 0.00 181 5681 U 0.0 ~ ' 3.89 ~Penetration Body Metal Loss Body Page 4 r ~ r r ~ ~r ~ ~^r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~ Well: 1C-170 Survey Date: Aug 13, 2007 Field: West Sac Tool Type: UW MfC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.6 f L-80 Anai st: B, i Cross Section for Joint 49 at depth 1525.78 ft Tool speed = 43 Nominal ID = 3.958 Nomi~al OD = 4.5 Tool deviation = 16 ° Isolated Pitting .06 ins = 22% Wall Penetration HIGH SIDE = UP • ~ Cross Sections page 1 • • Average Recorded Metal Thickness Relative to Calibration Point 4.5" Tubing / 7.625" Casing / 16" Conductor Well: 1 C-170 Field: West Sac Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: Aug 13, 2007 ^ D ecrease . In crease 1 25 18 758 50 1532 75 o= 2316 ~ ~ ~ GLM 1 = u ~ .~ Z t 0 100 3121 Q 125 3889 150 4664 GLM 2 sud~n9 siee~e 175 5495 181 5681 - 50% 0 5 0% C hange in Meta l Thick ness (% ) Bottom of Survey = 181 ~ MTT 10 Hz ~,ss ~~ o~~~ S«~~ . Tool Recordings 3' -17D' Database File: d:lwarriorldatal1c-170 20071?007 1c170.db Dataset Pathname: 1!1 Presentation Format: mtt50 Dataset Creation: Fri Sep 1413:39:d8 2007 Charted by: Depth in Feet scaled 1:120 -50 Delta Metal Thickness (%) 50 1 MTfP01 (rad) 51 0 Line Speed (ftJmin) -200 -45.2 MTTP1? (rad) 4.8 ~ea of Relative Meta l Lo ss 0 1 Tubing Jt. 1 ~ ~0 ~ ~Ita M etal Thi ckness '~ i -- ~ ~ - t---1---~ , -1 Jt. 1.1 -- - - - ~ ~ - - - - - _ t ~ 4 -, , _ _. , A arei 0 ~ pp ~ ~ ~sing Col lar ~ f -- _ App are ~~ 50 - ---- --- I a Tubing - _ . 1 Jt. 2 i { ~ f ~ ea of Re ~ lative Metal Lo ss ~ A par errt Wide Sp rea d M -~ etal a Tubing Jt 3 . - 80 ~ Metal Localized Metal ~ MTT 10 Hz ~ss Tool Recordings 1820' - 2180' PaoAerive Dlwqnosiie Se~ieq ine. Database File: d:lwarriorldatal1c-170 20071copy of 20071c170.db Dataset Pathname: 1!1 Presentation Format: mtt Dataset Creation: Fri Sep 1413:39:08 2007 Charted by: Depth in Feet scated 1:150 -50 Delta Metal Thickness (%) 50 0 MTTP01 (rad) 100 0 Line Speed (ft/min) -200 -92.3 MTTP12 (rad) 7.6 Metal Thic^kness 1840 1 Tubing Area of Relative Jt. 60 , °~ Apparerrt Metal Loss on One Side of 1860 Metal Loss on One Side of -+--~ Tubing Collar ~t.61 1880 Tubing Jt. 62 ~ 1900 ' . ~ Ap~ar?nt Metal Lnss on One Sic1? nf of Relative ~ I LI 1 L I I L I t 1~ I ~-~ ~ Area of Relativ Metal Loss~ Collar of Relativ ~440 ~ ~. =L ~ ~ _ l.~ -- - ~ - e -'~ Apparent Metal Loss on One Side of Tubin Tubing Jt. 63 1940 ~ ---- ~ j -_- ~ 1960 _ ~ r.. Tubing Jt. 64 Apparent Metal Loss on One Side of Tubing ~ e - r ~~ f Tubing Jt. 65 ~ _._r. _ ~~O Apparent Metai Loss Around Camplete Circumference ~ ; - , - -- ~ , . .~. _. .- __ _ t.~ . _ - - -- -- _ , _.. _ ~ I =r ~ ~ ,~ , ~~ ~a~o Tubing -~-, _ ~- _ , Jt. 66 - ' _:s 7 ~, -- . _ __ s .- Tubing Jt. 67 _ _ __ .~ _ -- --- - g-- -- - . -- - _ _ _ -~ ~r~n = - ' 1 ~ 1 , t 1 ' ' 1 1 , , i ~ ~ ~ ConocoPhillips Alaska, Inc. ~ KRU 1 C-170 ~ 1 G170 API: 500292315400 Well T : PROD An le TS: d TuBINC (asass, oo:a.soo. SSSV Type: NIPPLE Orig Com letion: 5/272003 Angle ~ TD: 89 deg @ 12230 ID:3.958) Annular Fluid: Last W/O: 11/17/2003 Rev Reason: REPLACE JET PUMP Reference L: 28' RKB Ref L Date: Last U ate: 12/31/2005 Last Ta : TD: 12230 ftK6 Last Ta Date: Max Hole An le: 92 d 6950 Casin Strin - ALL STRI NGS SURFACE ~~ ~ Descri tion Size To Bottom ND Wt Grade Thread ~~s2e; CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED wc:zs.zo~ ~.- SURFACE 7.625 0 6010 3763 29.70 L-80 BTCM LINER 4.500 5874 12219 3798 12.60 L-80 NSCT I Tubin Strin - TUBING I ~ Size To Bottom ND Wt Grade Thread 4.500 0 5886 3750 12.60 1-80 IBTM ~ Perforations Summar ' Interval ND Zone Status Ft SPF Dete T Comment ' BUSHING (5187-5188, 8108 - 12185 3789 - 3798 WS D 3077 99 5/27/2003 IPERF Pre-Perforeted Slotted LIf1Ef, 1" holes every other oo:s.ooo~ S EEV ~Olflt E-O L (518&5193, Ga s Lift M andr els/Velve s °D4 500~ PUMP 518&5193 St MD ND Man M~ Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ( , OD:3.812) 1 2710 2397 CAMCO KBG-2 DMY 1.0 BK 0.000 0 1/21/200 2 4982 3475 CAMCO KBG-2 DMY 1.0 BK 0.000 0 1/21/200 ~ ~ Other lu s ui . etc. - PERFORATED LINER De th ND T Descri tion ID Gauge Camer 5874 3748 Liner TIE BACK BAKER TIE BACK SLEEVE 5.750 ~szossz~o, °°.5.5°°~ 5885 3749 Liner PACKER BAKER 'ZXP' PACKER W/HRD PROFILE 4.930 5893 3750 NIP RS NIPPLE 4.880 5896 3751 HANGER BAKER FLEX LOCK HYD. ROT. LINER HANGER 4.860 5905 3752 XO CROSSOVER BUSHING HYDRLIL 3.910 N~P 12185 3798 BUSHING BAKER PACKOFF BUSHING 0.000 (5249-5250, OD:4 500) 12217 3798 SHOE 4.500 . Other lu s ui . et c. - JEVIlELRY De th ND T Desai tion ID xo 27 27 HANGER VETCO GRAY TBG HANGER 4.500 ~58~i~8~Z, 448 448 NIP CAMCO'D' NIPPLE W/NO GO PROFILE 3.875 OD:5.530) 5187 3560 BUSHING BOT PROTECTOR BUSHING 3.970 pgR 5188 3560 PUMP 3.812" JET PUMP W/DB-6 LOCK SN AR-1014, 9-B RATIO, #9 NOZZLE, #10 THROAT set 12/22/2005 0.000 (5872-5873, 51SH 3560 SLEEVE-O BOT CMU SLIDING SLEEVE - OPENED 11/21/2003 3.812 °~:s.3so) 5193 3562 BUSHING 3.970 5209 3568 Gauge Carrier BOT MODEI 925 GAUGE CARRIER 3.912 LINER 5249 3583 NIP CAMCO 'D' NIPPLE WMO GO PROFILE 3.750 ~ea~a-~22is, o 5 5871 3748 XO XO BUSHING 3.930 o :a. oo, wt:~2.so~ - 5872 3748 PBR BAKER PBR SEAL ASSEMBLY W/3 SETS OF BUILET SEAIS 4.760 ner al Note s Date Note ~ ~ 5/27/2003 TREE: ABB VetcoGray / HORZT 4 1/16" 5 M(w/penetrator wire) TREE CAP CONNECTION: 9" OTIS HANGER (589fr5905, OD:7.625) Pert (970&12185) r 1 ^ 1 ' ~ ~ . , . ~ ' • • Memory Magnetic Thfckness ToQ1 s Log Results aumm~ry -~;. Company: ConocoPhillipsAlaska, Inc. Well: 1C-170 Log Date: June 15, 2009 Field: West Sac Log No. : 10559 State: Ataska RUn NO.: 2(2"d MTT) APl NO.: 50-029-23154-00 Pipe Desc.: 7.625" 29.7 Ib L-80 BTCM Top Log In#vl.: Surface Pipe Use: SurFace Casing Bot. Lag Intvl.: 209 Ft. (MD) Pipe Desc.: 16" 62.5 Ib H-40 WELDED Top Log intvi.: Surtace Pipe Use: Conductor Pipe _ 8ot. Log Intvi.: 110 Ft. (MD) Inspection Type : Corrosive & Mechanica/ Damage Inspection ' COMMENTS : t This MTI' data is tied into the Mandrel Hanger L'cn' 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). Tubing was pulled after last time MTT ran in this well (August 13, 2007). The MTT responds to the total metal ' thickness of the 7.625" surtace casing and the 16" conductor pipe. Passes at SHz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz and 12Hz passes selected for analysis in this report. I COMPARISON TO PREVIOUS MTT LOG RESULTS : A log plot overlay of the average metal thicknesses recorded by the MTT, from surface to 210', for the current ' 10Hz pass and previous 10Hz pass (August 13, 2007} is included in this report. The previous run is logged at 45 fpm with the presence of a tubing string and the current run is logged a# 20 fpm without the tubing string in place. A relative ~mparison of the finro logs show a carrelation in indic;ations of signiftcant metal loss just ' below the hanger and just above the bottom of 16" conductor. Areas of significant metal loss indicated in the current log near 32' and 62' appear to have been masked by tubing collats in the previous log. ' INTERPRETATfON OF MTT LOG RESULTS : '~~ ' ~'"~~~~~'t'~ ~t``'`~ ` ~ ~~~~ ' The MTT log results cover the intervai from surtace to 209'. Changes in metal volutne are relative to the calibration points at 42' and 139', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 7.625p surface casing and 16" conductor pipe. ' A maximum overall metal volume loss of 20% is indicated in joint 1(4' - 22') in all four frequency passes. A iog plot overlay of the average metal thicknesses -ecorded by the MTT for the SHz, 8Hz, 10H2 and 12Hz passes is included in this report. An overall metat volume loss of up to 10~o is indicated in the 12Hz pass in ' joint 3(100' -110'), while only as much as 2% overaA metal volume loss is indicated in the 8Hz pass aver the same interval. The spread in tool response at different frequencies over this interval point to the prababitity that the metal loss over this interval is more concentrated in the surf'ace casing than the conductor ' pipe. The homogeneity of the tool response to metat losses over various frequencies in the remainder of the conductor pipe interval point to a likelihood that the metal lass over these intervals is more evenly distributed between the surface casmg and conductor pipe. Detailed log plots of the 5Hz and 12Hz passes are included in this report. , PraActive Diagncstic Services, Inc. J P.O. Sox 1369, StafFord, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.cam ' PrudhoP Bay Field Office Phone: {q0?} 659-23Q7 Fax: (90?) 659-23I.4 ~ ~3 ~ D~~ ~~ ~ Intervals of overall metal Inss indicated within the conductor pipe interval in the 5Hz pass are as follows: A 1°~ - 2Q% circumferential metal loss is recorded in the interval beiween 4' - 22'. A 1%- 9% circumferentia! metal loss is recarded in the interval between 48' - 78'. A 1°~ - 6% circumferential metal loss is recorded in the interval between 28' - 39'. A 1°10 - 2% circumferential metal loss is recorded in the interval between 904' - 105'. Intervals of overall metal loss indicated below the conductor pipe interval in the 5Hz pass are as fallows: A 1%- 3% circumferential metal loss is recorded in the interval beiween 114' - 132'. A 1%- 3% eircumferential metal loss is recorded in the interval between 158' - 174'. A 1°~ - 2% circumferential metal loss is recorded in the interval between 144' - 150'. A 1%- 2°~ circumferehtial metal loss is recorded from 206' to the end of the interval fogged. Over the interval (100' - 110'), at the bottom of the conductor, the maximum indicated overall metal loss by the four recording frequencies are as follows: 5 Hz - 3% 8 Hz-5°~ 10 Hz - 8°~ 12 Hz -10% The percent circumferential metal loss expressed in this summary is a percentage of the total metal that #he tool is responding to, wMich indudes influences from the 7.625" surtace casing and 16" conductor. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal toss indicated could be from either the 7.625" surtace casing or 16" conductor. Field Engineer. G. Etherton Analyst: HY. Yang & J_ Burtan Witness: R. Uber ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phane: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PD~ ajmemoryfog.com Prudhoe Bay Field Office Phone: (907) 659-2.i07 Fax: (90i) 659-2314 ~ Comparison to Previous N~Log Overlay 1 C-170 (Surface -210') ~.,wE o~~,~~ sER.~a, ~~. June 15, 2009 and August 13, 2007 Database File: d:lwarriorldatal1c-170 20071comparison.db Dataset Pathname: runlcomp Presentation Format: comp Dataset Creation: Wed Jul 15 09:31:07 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2007 (10Hz) (%o} 50 -50 Delta Metal Thickness ?409 (10Hz) (%) 50 ~'. i 0 ~_~-2009 (10Hz)~__~ elta Metal T (Without Tubing in Place) 2007 (10Hz)- Logged at 20 fpm With Tubing in f `~ Loyyed at 45 40 60 80 ~, 8Hz, 10Hz and 12Hz Passes Del~etal Thickness Overlay (Surface to 209') June 15, 2009 PnoAetive Oltiqnosde SeRViees, Ine. Database File: 1c-170.db Dataset Pathname: 1/1/1lmerge2 Presentation Format: comparis Dataset Creation: Wed Jun 1712:53:14 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metai Thickness 2009 (12Hz} (°!o) 50 -50 Delta Metal Thickness 2009 (10Hz) (°/a) 50 -50 Delta Metal Thickness 2009 (8Hz} (%) 50 ~ -50 Delta Metal Thickness 2009 (5Hz) (%) 50 _ ---__ --. 0 ~0 40 60 80 • 1U0 Delta Metal Thickness (1 Delta Metal Thickness (12Hz; 120 140 160 180 200 Metal of -50 Delta Metal Thickness ~009 (1~Hz) (%} -50 Delta Metal Thickness 2009 (10Hz) (%} -50 Delta Metal Thickness 2009 (8Hz) (%} -50 Delta Metal Thickness 2009 (5Hz} (%) 50 50 50 •1 C-170 Recorded Magnetic Thickn~Log Data - 5Hz Pass {Surface to 209') June 15, 2009 PnoAc~ive Dlwqnasric SeavlcES„ Inc. Database File: 1c-170.db Dataset Pathname: 5HzPass.1 Presentation Format: 1.4 scale Dataset Creation: Tue Jun 16 19:45:58 2009 by Calc Warrior 7.fl STD Cas Charted by: Depth in Feet scaled 1;150 -50 Delta Metal Thickness (°/a) 50 1.4 MTT Phase Shift - Sensor 01 (5 Hz) {rad) 11.4 Q LSPD (ft/min) 200 -7.4 MTT Phase Shrft - Sensor '12 (5Hz) (rad) 2.6 Tree ~Hanger_ Pup Jt. Metal Loss ~elta Metal Thickness ~0 Casing Jt. 1 6% Metal Loss 40 .rr~ 60 % Metal Loss Casing Jt. ~ 80 ~ C-170 Recorded Magnetic Thickn~og Data -12Hz Pass -- {Surface to 209') June 15, 2009 PROAGiIVE DIAGN06T~C SERVICESy INC. Database File: 1c-170.db Dataset Pathname: 1?HzPas.1 Presentation Format: 2.6 scale Dataset Creation: Tue Jun 16 19:50:00 ~009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (°/a) 50 2.6 MTTP~1 (rad) 12.6 0 Line Speed (ft/min) ~00 -6.2 MTfP12 (rad) 3.8 ' Tree ~I-langer~ Pup Jt. % Metal Loss 1~ Delta Metal Thickness 20 Casing Jt. 1 3Q 6% Metal Loss 4d 50 60 10% Metal Loss Casing Jt. 2 7Q 8a ~ ConocoPhillips Alaska, Inc. ~ KRU 1 C-170 ~ ~c-~~o - - ---- - API: 500292315400 Well T e: PROD An le TS: d SSSV Type: NIPPLE Orig Com letion: 5/272003 Angle @ TD: 89 deg @ 12230 SURFACE ~asoio, OD:7.625, wc:zs.~o~ Annular Ftuid: Last W/O: 11/17/2003 Rev Reason: PULI COMPLETION PRE WORKOVER Reference Lo : 28' RKB Ref L Date: Last U ate: 11/7/2007 Last Ta : TD: 12230 ftK6 Last Ta Date: Max Hole An le: 92 de 6950 Casin Stri - ALL STR INGS Descri tion Size To B m TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 6010 3763 29.70 L-80 BTCM SLOTTED LINER 4.500 5874 12219 3798 12.60 L-80 NSCT Pertoratio S m Interval TVD Zone S~tus Ft SPF Date T e Comment 9108 - 12185 3789 - 3798 WS D 3077 99 5/27/2003 IPERF Pre-Perforated Slotted Liner, 1" holes every other ~oint Other I s ui . etc . - PERFORATED LINER De th ND T e Deecri tion ID 5874 3748 TIE BACK LINER BAKER TIE BACK SLEEVE 5.750 5885 3749 PACKER LINER BAKER 'ZXP' PACKER W/HRD PROFILE 4.930 5893 3750 NIP LINER RS NIPPLE 4.880 5896 3751 HANGER LINER BAKER FLEX LOCK HYD. ROT. LINER HANGER 4.860 5905 3752 XO LINER CROSSOVER BUSHING HYDRIL 3.910 5928 3755 PLUG LINER WEATHERFORD WRP set 10/19/2007 0.000 12185 3798 BUSHING LINER BAKER PACKOFF BUSHING 0.000 12217 3798 SHOE LINER SHOE 4.500 Gener al Note s Date Note 11/4/2007 NOTE: COMPLETION PULLED FOR WORKOVER~ BAD SURF CSG FOUND; WO PUT ON HOLD il ~ i SLOTTED LINER (587412219, OD:4.500, Wt 12.60) Pert ~ (910&12185) ~ LI ~ _ _ • • e~~~ ~`_ .~ _ ..__~y. , ~' a ~ , ; ~toAcaive ~'9°uacn~us~ic ~~~evie~s, ~~c. Ta: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTTj The tschnical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this tr~nsmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Ro~rt A. Richey 130 West ir-ternational Airport Road Suite C Anct~orage, AK 99518 Fasc (307] 245-8952 1] M'TT Report 15-Jun-09 1 C-170 1 Report 50-029-2315400 2] ~~~~`~~~~~~ ,,;~~~ ,. ~:~_ ~.~~i`i 1 ~ j; ; Signed : Print Name: c~D3 ' C~ ~ ~ Date : PROACTFVE DfAGNOSTIC SERVtCES, INC., 130 W. INTERNATIONA~ AIRPORT RD SUITE ~, ANCHOR14GE, AK 98518 PHONE: (907)245-8951 F~uC: (907~245-88952 E-MAIL : . > _ : i b1fEBSfTE : , ' , ' ~ ,~- C:\Documents and Settmgs\OwnalDesktop\Transmit_Conoco.docx ~ ' 1 ' ~ t S ,~. Memvey Magnetic T1lickness Taol Log Resut~ Summar~y Company: _ ConocoPhillips Alaska, Inc. Well: 1 C-170 Log Date: June 15, 200'8 Fieid: Kuparuk Log No. : 10559 State: Alaska RUn No.: 2(2"d MTT) API NO.: 50-029-23154-OQ Pipe Desc.: 7.625° 29.7 Ib L-80 BTCM Top Lag Intvl.: Surface Pipe Use; Surface Casing Bot. Log Intvl.: 209 Ft. (MD) Pipe Desc.: 16" 62.5 Ib H-40 WELDED Top Log lntvt.: 5urface Pipe Use: Conductor F'ipe Bot. Log Intvf.: 110 Ft. (MD) Inspection Type ; Comasive 8 Mechanicat Damage 1'nspection COMMENTS : This MTT data is t7ed into the M'andre/ Har~ger ~ l?' Aepth. This is the second time this weit has been logged with the 12 Arm Ma~netic Thickness Too! {MTT}. Tubing was pulled after last time MTT ran in this weit (August 13, 2007). The MTT responds to the totai metal thickness of the 7.625" surtace casing and the 16" conductor pipe. Rasses at SHz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz and 12Mz passes selected for analysis in this report. COMPARISON TO PREVIOUS MTT LOC RESULTS : Direct comparison of the current and previous logs is not possibte due to the presenee of a tubing string in the previaus log and the absence af tubing in this log. A retative comparison of #he two logs show a correlation in indications of significant meta) loss just betaw the hanger and just above the bottom of 16" conductor. Areas of significant metal loss indicated in the current log near 32' and 62' appear to have been masked by tubing collars ~n the previous log. 1 ... - ' ~ • ll ~ i The MTT !o~ results cover the interval ftom surface to 209'. Changes in metal volume are relative to the ' cafibration pvi~s at 42' arn! 139', where the readings are assum~d to rep~sent undamaged pipe. A!1 other readings are relative to these reference points, which indude influences from the 7.625~ sutface casing and 16" conductor pipe. A maximum overatl metal volume loss of 20% +s indicated in joint 1(4' - 22') in all four frequenay passes. A ' Iog plo# overlay of the average metal thicknesses recx~rded by the MTT for the SHz, 8Hz, 10Hz and 12Hz passes is incfuded in this report. An overaA metal volume loss of up to 10°~ is indicated in the 12Hz pass in joint 3{100' -110'}, while on(y as much as 2°!0 overall metal volume loss is indicated in the 8Hz {~ss over the same interoal. The spread in #ool response at different frequencies over this interoal point to the ' probability that the metal {oss over this intervat is more concentrated in the surface casing than the conductor pipe. The homogeneity of the tooi response to metal losses over various ftequencies in the remainder of the ' conductor pipe interval point to a likelihood that the metaf loss over these iMervats is more eveNy distributed ' bet~nreen the surtace casing and candudor pipe. Detailed log plots of the 5Mz and 12Hz pass~s are included i~ this report. 'I ~ ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; {281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ ' ~O~ rQ~ ~ ' ~ ~ Intervals of overall metal loss indicated within the conductor pipe interval in the 5Hz pass are as follows: A 1%- 20°r6 circumferential meta( loss is recorded in the interval beiween 4' - 22'. A 1°k - 9% circumferential metal loss is recorded in the interval between 4$' - 78'. A 1%- 6°~ circumferential metal loss is recorded in the irrterval between 28' - 39'. A 19'0 - 2% circumferential metal loss is recorded in the interval between 104' - 105'. tntervals of overall metal loss indicated below the conductor pipe intervai in the 5Hz pass are as follows: A 1%- 3% circumferential metal loss is recorded in the interval between 114' - 132'. A 1°~ - 3% circumfere~tial metal loss is recorded in the interval beiween 158' - 174'. A 1~0 - 2°k circumferentiat metal I~s is recorded in the interval beiween 144' - 150'. A 1%- 2°~ circumferential metal loss is recorded from 206' to the end of the intenral logged. Over the interval (100' -110'), at the bottom of the conductor, the mauimum indicated overall metal loss by the four recording frequencies are as follows: ~ Hz - 3°fo 8 Hz - 5°k 10 Hz - 8% 12 Hz -10% The percent circumferential metal Ioss expressed [n this summary is a percentage of the total metat that the tool is responding to, which includes influences from the 7.625" surtace casing and 16° conductor. If all of the metal loss is speciflc to the 7.625" surtace casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicat~ed could be from either the 7.625" surface casing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: R. Ober ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX J7497 Phone: (281) or (888) 565-9085 Fax: (2S1) 565-1369 E-maii: PDSta~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~, BHz, 10Hz and 12Hz Passes Dei~letal Thickness Overlay {Surface to 209') June 15, 2009 PaoA~~lve DGq~ostie Seavic a,. INC. Database File_ 1c-170.db Dataset Pathname: 1!1!1/merge? Presentation Format: comparis Dataset Creation: Wed Jun 1712:53:14 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2009 (12Hz) (%) 50 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness 2009 (8Hz} (%} 50 -50 Delta Metal Thickness 2009 (5Hz) (%) 50 fl ~0 40 sa ao • 1Q0 Metal Metal Thickness (1 of 16" Conductor 120 140 160 180 200 -50 Delta Metal Thickness 2009 (12Hz) (%) -50 Delta Metal Thickness 2009 (10Hz) (%) -50 Delta Metal Thickness 2009 (8Hz) (%} -50 Delta Metal Thickness 2009 (5Hz} (%} ~1 C-170 Recorded Magnetic Thickn Log Data - 5Hz Pass ~ {Surface to 209') June 15, 20a9 P~aoAcrivE olwqwas.la se..dcs. ~HC. Database File: 1c-170.db Dataset Pathnarr~e: 5HzPass.1 Presentation Format: 1.4 scale Dataset Creation: Tue Jun 1619:45:58 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet sca{ed 1:150 -50 Delta Metal Thickness (%} 50 1.4 MTT Phase Shift - Sensor 01 (5 Hz) (rad) 11.4 0 LSPD (ft/min) ?00 -7.4 MTT Phase Shift - Sensor 12 (5Hz) (rad) ? 6 Tree H~ anger Pup Jt. Metal Loss ~elta Metal Thickness ~0 Casing Jt. 1 3% Metal Loss 4Q 60 ng .ft. 2 80 ~ ~ ConocoPhillips Alaska, Inc. ~ KRU 1 C-170 ~~ 1 G170 . - API: 500292315400 Well T e: PROD An le TS: d SSSV Type: NIPPLE Orig Com letion: 5/27/2003 Angle @ TD: 89 deg @ 12230 SURFACE ~°~01D' OD:7.625, wt:2s.~o~ Annular Fluid: Last W/O: 11I17/2003 Rev Reason: PULL COMPLETION PRE WORKOVER Referenae L: 28' RKB Ref L Date: Last U ate: 11/7/2007 Last Ta : TD: 12230 ftKB Last Ta Date: Mex Hole An le: 92 d 6950 Cesin Stri - ALL ST RI NG3 r' tio Size To B m T Wt Orode Threa CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 6010 3763 29.70 L-80 BTCM SLOTTED LINER 4.500 5874 12219 3798 12.60 L-80 NSCT Pertoratinns Sum a Intarval TVD Zorre S1ed~s Ft SPF ~w T e Comment 9108 - 12185 3789 - 3798 WS D 3077 99 5/27/2003 IPERF Pr~Perforated Slotted Liner, 1" holes every other oint O er i. et c. - PERFORA7ED LINER D th ND T Descri tion ID 5874 3748 TIE BACK LINER BAKER TIE BACK SLEEVE 5.750 5885 3749 PACKER LINER BAKER 'ZXP' PACKER W/HRD PROFILE 4.930 5893 3750 NIP LINER RS NIPPLE 4.880 5896 3751 HANGER LINER BAKER FLEX LOCK HYD. ROT. LINER HANGER 4.860 5905 3752 XO LINER CROSSOVER BUSHING HYDRIL 3.910 5928 3755 PLUG LINER WEATHERF~RD WRP set 10/19/2007 0.000 12185 3798 BUStiING LINER BAKER PACKOFF BUSHING 0.000 12217 3798 SHOE LINER SHOE 4.500 ner et Note s oate Noce 11l4/2007 NOTE: COMPLET ION PULLED FOR WORKOVER; BA~ SURF CSG FOUND• WO PUT ON HOLD ~ SLOT'fED IINER (587412219, OD:4.500, Wt:72.60) Parf (9108-12185) J ~ ~ Page 1 of 3 L' Maunder, Thomas E (DOA) From: Packer, J.Brett [J.Brett.Packer@conocophiNips.com] Sent: Thursday, April 10, 2008 11:07 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 C-170 (203-078) Attachments: 1C-170 Well Svc. Rpts.pdf Tom, Here's the reports you requested. Brett 4'acker ~Dri~ng ~'WelZr 4Norkover Engineeer 4Nork# 26s-6sas Celt"# 230-8377 ~~~~ MAY ~ ~ 20~~ From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Wednesday, April 09, 2008 1:10 PM To: Packer, J.Brett Subject: RE: 1C-170 (203-078) Brett, Thanks for the information. Could you please provide the well service reports for the plug setting and corrosion logging as well as any other reports you might have regarding activity on this well. Gall or message with any questions. Tom Maunder, PE AOGCC From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, April 07, 2008 11:30 AM To: Maunder, Thomas E (DOA) Subject: RE: 1C-170 (203-078) Tom, 1 C-170 was a workover that was done as a precautionary measure only. Due to the discovery of severe casing corrosion on two Tarn jet-pumped wells, the concern was raised about possible casing corrosion on our four 1 C jet-pump wells with single casing. The in-house decision was made that we will not produce these 1 C wells on jet-pump until a second string of casing can be installed due to safety concerns. 1 C-170 was and is still planned to be a two-phase workover, the first phase was to pull the tubing, cleanout the well, then leave afull-opening valve on top so that we could come in afterwards and run afull-bore casing inspection log. Following the casing inspection log, the plan was to move the rig back over the well and install an inner string of 5.5" casing and re-complete the well as a gas lift/jet pump producer. Prior to the workover, a plug was set downhole @ 5928' MD. The well passed a CMIT to 2000 psi. The rig then moved onto the well, pulled the tubing, ran in with a cleanout assembly, tested the casing again to 2500 psi, and then installed a drilling spool with full-opening valve on top. To our surprise, the tubing pulled from the well looked 4/15/2008 Page 2 of 3 • • pristine, almost brand new, and following the workover, the UCI corrosion log {run on 12/2/07) showed the casing to be in excellent shape too. Based upon this finding at 1 C, it is now a theory that the corrosion seen at Tarn is possibly due to the pigging solids of the CPF-2 injection lines since the source power fluid for the jet pumps is from the injection water. Regardless of the good results in 1 C-170, we are still planning on installing inner strings of casing in all four 1 C jet-pump wells with single casing (1 C-135, 1 C-170, 1 C-178, 1 C-184). / The reason we were holding onto the 10-404 was that we were hoping to finish the second phase of the workover ,/ and get a test on the well before submitting it. But, due to equipment lead times, it looks like we're not going to get back to that well until the early part of next year, so we decided to file the 10-404 now. Once the 2nd phase of the workover is complete, we will submit another 10-404. The SBHP in this well is 1043 psi, as taken from a downhole pressure survey on 8/11/07. This equates to 5.6 ppg and a MASP of 686 psi. We set the downhole plug to isolate the formation (and also to eliminate lost returns during the workover). The well was left with the downhole plug, 9.6 ppg brine (crystallization temp: 3° F), and 50 ft of diesel cap for freeze protection for the wellhead. The 9.6 ppg brine is sufficient for freeze protection through the permafrost, and the reason we didn't leave 2000' of diesel like normal is because we wanted a uniform fluid for the casing inspection log. The comment on the schematic "Bad surf csg found; WO put on hold" is obviously incorrect. The person who updates our schematics was apparently not aware of the scope of the workover, nor the results of the casing inspection, as the comment was made on 11/4!07 before we even ran the UCI inspection log. I hope this answers your questions regarding the plans for this well. Let me know if you need any additional information. Thanks, 3 Brett 2~acker ~Dri~ng sZ ?~Ueltr ~Norkover~Engineer zNork# 265-6845 ~'eQ# 23Q-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 04, 200$ 1:36 PM To: Packer, J.Brett Cc: Regg, James B (DOA) Subject: 1C-170 (203-078) Brett, I am sending this to you since you signed the 404 of the recent work (11/03 -11/05/07) performed on this well. Please forward as necessary. The 404 was received April 3, 2008 which is nearly 4 months after the report should have been filed. The most recent information available in our well file is the caliper survey conducted in early August 2007. It appears that the tubing was successfully pulled, rerun and the IA successfully pressure tested to 2500 psi. The tubing was again pulled from the well and operations concluded with no tubing left in the well. There is a notation on the drawing that "bad surface casing was found, wo put on hold". We would appreciate more information on this matter. Please provide details as to the workover scope and what was discovered that prompted termination of the workover operation. While a sundry notice was is not required for pull tubing operations on a WS production well, not being able to recompfete the well as normal should have been communicated to the Commission. What are the intended plans for this wets? Are there any subsurface plugs set in the wellbore? is the well freeze protected? Absent a compelling reason, kill strings are normally left in wells open to the formation when tubing is not at TD. 4/15/2008 Page 3 of 3 Your early reply will be appreciated. Tom Maunder, PE AOGCC 4/15/2008 RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~iPR 0 3 2008 REPORT OF SUNDRY WELL OPERATI~,I~,Snil 2. (`_or (`nnr (~nmmirrinn 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ OthArflChO(~ Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ~ Exploratory ^ 203-078 /, 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23154-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28'. AMSL 87' 1 C-170 • 8. Property Designation: 10. Field/Pool(s): ADL 25638, 25649 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12230' feet true vertical 3798' feet Plugs (measured) 5928' Effective Depth measured 12217' feet Junk (measured) true vertical 3798' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 92' 16" 120' 120' SURFACE 6008' 7-5/8" 6010' 3763' B-SAND LINER 3949' 4-1/2" 12219' 3798' Perforation depth: Measured depth: , 9108'-12185' true vertical depth: 3789'-3798' Tubing (size, grade, and measured depth) none, , MD. Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) ,, not applicable ~~ SAY Q ~ ~~~~ Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Group Engineer Signature ~ '~3~1w _ ~ Phone Date ~ ~~~ ~ v n n Allsu Drake 263-4612 Pre ared b Form 10-404 Revised 04/2006 ®~ ~ ~ ~ ~ A ~ ~~i1 ~ Subm~t Original Only Con©COP~illips Time Log Summary YYeltview Web RgpO+7tng - --- - - Well Name: 1C-170 Job Type: RECOMPLETION Time Lam- - - -- - - -- Date From To _D_ ur S. Deg_t_h E Depth Phase Code Subcode T COM __ 11/02/2007 12:00 00:00 12.00 MIRU MOVE RURD P Move to 1C-170 and begin rigging up. 11/03/2007 00:00 06:00 6.00 MIRU MOVE RURD P Continue to spot up and level rig. Acce ted ri 06:00 on 11/3/07. 06:00 11:00 5.00 MIRU WELC NUND P Pull BPV, confirm well is dead, re-install BPV, ND tree, inspect lift threads and install blanking plug. NU _.~__ BOPE. 11:00 18:30 7.50 MIRU WELCT ROPE P Tested annular and rams to 250/2500 psi. Tests were charted and were good tests. State witness waived by John Crisp(AOGCC) per phone call on 11 /2/07 17:40. 18:30 19:30 1.00 COMPZ RPCOti RURD P Pulled blanking plug and BPV, installed isolation sleave. Tubing and IA ressure both "0". 19:30 22:00 2.50 COMPZ RPCOh PULD P BOLDS, attempted to pull hanger, worked up to 120K, wrapped well and steamed it for 5 mins, and pulled free, u wt.60K. 22:00 00:00 2.00 COMPZ RPCOti CIRC P RU and began circulating down the tubing to clean the hole, 3.5 BPM @ 140 si.ICP. 11/04/2007 00:00 01:00 1.00 COMPZ RPCOh CIRC P Finish circulating hole clean, 300 BBLS at 3.5 BPM @ 150 psi. FCP. RD and blow down lines. 01:00 12:00 11.00 COMPZ RPCOh RCST P Lay down hanger and begin POOH standin back 4.5" tubing and pulling TEC wire and clam s. OOH. 12:00 14:00 2.00 COMPZ RPCO RURD P Clean up rig floor prep for RBIH with Baker assym. Count clamps & pins Twice. 168 Cannon clamps & 8 mid collar clamps. 343 Clamp pins. At this time we are missing one pin. Note: Baker Centrilift rep dropped pin while POOH. Will look BOP area over while in ri down mode. 14:00 21:00 7.00 COMPZ RPCOh TRIP P RIH with Baker BHA of 2 7/8" mule shoe 8' long, 7 5/8" casing scraper, 4 11/16" boot basket, 4 3/4" bumper sub, 4 3/4"jars, 5, 830' of 4 1/2" L-80 production tubing. Lightly tagged top of PBR at _ 5860'. Up wt. 56K and down wt. 38K. ~ t^'~g~r 1 cif 2~ ~..~_..~.. r~ '~ Time Los ~_- ___ Date From To Dur S De th E. D_e th Phase Code Subcode T COM _ ~ 11/04/2007 21:00 23:30 2.50 COMPZ RPCO CIRC P Reverse circulated 25 BBL Hi-Vis sweep and chased it w/ 9.6# brine. Caught samples for Corrosion Dept., no significant solids in returns, including in the sweep. ICP: 3 BPM @ 180 psi. FCP: 3.5 BPM 250 si. 23:30 00:00 0.50 COMPZ RPCOh DHEQ P RU and begin pressure testing casing to 2500 si. 11/05/2007 00:00 01:00 1.00 COMPZ RPCOh DHEQ P Completed casing pressure test to 2500 psi, test was good and chart recorded. 01:00 10:00 9.00 COMPZ RPCOh TRIP P POOH lying down. Note: ALL original completion equipment showed absolutely no corrosion signs. All jewelry also showed no corrosion. No solids in returns during reverse out sta e. 10:00 11:00 1.00 COMPZ RPCO PULD P Lay down Baker BHA and break down. Current weather conditions hase 1. 11:00 15:00 4.00 COMPZ RPCO NUND P OOH with BHA. Begin breaking down BOP & rig off well. Current weather conditions hase 2. 15:00 19:00 4.00 COMPZ RPCO NUND P NU 7 1/16" FOV on casing head, pressure tested to 1500 psi, good pressure test. Bled pressure off and released ri at 19:00 hrs. on 11/5/07. ~~ge 2 rsf 2 ,,~-~-, . ~; , C~~c~c~~'h~~lTp~ t~la~ka, InC. ~c-i~o- - - - APL 5UU2923154 SSSV Type: NIPPLE SURFACE Annular Fluid: (OE010, OD:7.625, wt:2s.7o> C~ KRU 1 C-170 - -_ _ - __ Nell T e: PROD An le a) TS: d a) Orig 5/27/2003 Angle @ TD: 89 deg @ 12230 om etion: Last W/O: 11/17/2003 Rev Reason: PULL COMPLETION PRE WORKOVER Reference Lo : 28' RKB Ref Lo Date: Last U date: 11/7/2007 Last Ta TD: 12230 ftK6 Last Tag Date• Max HoIP Angle: 92 deg (c il 695(1 CGasing String -ALL STRINGS _ -- Descn lion Srze To Bottom TVD Mlt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 6010 3763 29.70 L-80 BTCM SLOTTED LINER 4.500 5874 12219 3798 12.60 L-80 NSCT Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 9108 - 12185 3789 - 3798 WS D 3077 99 5/27!2003 IPERF Pre-Pertorated Slotted Liner, 1 "holes every other -- - _ joint - __ Other lugs, equip., etc.) - .. __.. PEF2FQRATED LINER _ . no.,rti I l Tvnn Tvn n-crnminn fn I 5874 3748 TIE BACK LINER BAKER TIE BACK SLEEVE 5.750 5885 3749 PACKER LINER BAKER'ZXP' PACKER W/HRD PROFILE 4.930 5893 3750 NIP LINER RS NIPPLE 4.880 5896 3751 HANGER LINER BAKER FLEX LOCK HYD. ROT. LINER HANGER 4.860 5905 3752 XO LINER CROSSOVER BUSHING HYDRIL 3.910 5928 3755 PLUG LINER WEATHERFORD WRP set 10/19/2007 0.000 12185 3798 BUSHING LINER BAKER PACKOFF BUSHING 0.000 I 1121 / 1 3/Y2S I JI-IUt I LINtFi 5MUt I 4.bVU I General Notes I Date I Note ._ _ - I 11!4/2007 NOTE: COMPLETION PULLED FOR WORKOVER; BAD SURF CSG FOUND; WO PUT ON HOLD SLOTTED LINER (5874-12219, OD:4.500, Wt:12.60) Pert (9108-12185) J ~ - -. - - - - WSR Historical -FILE COPY- Jab: Erosion /Corrosion Monitor y ~ Report Date: 818/2007 C®nOCOPhillips ' 1 C-170 Unit: AES WELL INTEGRITY DHD '', R}GERS - ~ESs DHD Tech: API! UWI _ Field Name -- - -- ~i 5002923154 WEST SAK Well Type Origina( KB Eleofion (ft) --Well Status _ ,,Legal We1lName Development -- - - 87.10 PROD - 1 C-170 _ ~, ,- - - ~®Sc Erosion /Corrosion Monitor - ~ ' ---- _ __ ---- T-- Actual Start Date 'End Date - r -_-_- _- Y - _ ___ _ _- Sec®dary Job T pe Drillsite Prima Wellbore Affected ry 848/2007 12:00 8/8/2007 15:00 IZXOtAnnulus Communication Evaluation 11C 1C-170 I ~ -- Project pesa -___ _ __ __ LepF WeNName jT TYl7e - I T AFE / RFE -i - Nebyoridl0 # 1C-170 Erosion /Corrosion Monitor 1 C-110 Erosion /Corrosion Monitor 10191462 ,10191462 UNIT/RiG: AES WELL INTEGRITY DHD ~ Rig Accept Date Rig R e Date ' Cont+ector Rig Name/No Rig Type 8/8/2007 12:00 ' 8/8/2007 15:00 AES DHD .WELL INTEGRITY -- - - Rig Supervisor --- -- _ - _ -T - -- -- _ (Company Ti I - - ''Phone Mobile Phone Work ROGERS -AES, DHD Tech 'AES !,DHD Tech - - -_ - -_ ', 659-0704 ',Pager 993 -- - ~- - - - ------- -- _ Comment ED BY. D RA IONS::- - --- ~ O 7 ~- - _ ~ I e B rt End D Report Bart Repo l Remarks ..----- _ - _ Gensa Daily Cost Total ~ 8/8/2007 12:00 8/8/2007 15:00 ' Initii T/I/O=SI/250/150 ', 300.00 ', Fina1T/I/O=SI/250/150 i I PRE RWO T POT'S PASSED, FUNCTION TES T LDS'S(ALL MOVED FREELY). , I Weather ..Temperature (°F) end unit Su rvisor _ Pe -__- Canpany-- ---- - -T- -.- -- Title ~ _ _... .Mobile _ Phone Work ---~~- - ---- Superwspr --- --._ - - - --- -- -- __ - -- COLEE AES, DHD Tech tAES DHD Tech 1659-0704 Pager 994 JOtaNSON -AES, DHD Tech AES bHD Tech 659-0704 Pager 908 ~I, T'trrta Log Sfert ~ Cum Dur T `-- - - - -- ---_ - - ---- __-- Time ~ End Time Qur (hrs) (hrs} operation : Weittxue ~ 12:00 1 0 ~ 3.00 3.00 Pre RWO T POT (irassed), function test LDS's (all moved freely). Initial T/I/O=SI/250/150. Backed all 1C-170 ' ', ~, LDS'S off and re-ta~qued to 450 lbs. Stung into T TP with no pressure. Pressured up to 5000 psi, 15 min ',4700 psi, 30 min 4~0 psi. Final T/I/O=SI/250/150. I __ Well. FIuMs - -~ '', -Fluid 70 (t>bl) ~ -- --. Note ___.- ----- --__.--_. _ --_._.- ~`------ - ----- ----- - ----- --.-- -----_. _._._------._ __--__------- -- 1 wvuw.peloton.com Page 1/1 Report Printed: 4/10/2008 ' WSR Historical -FILE COPY- ~°' Eros'tan ~ COrrt}51on onittx Report Date: 8fS 112'007 C®nocOPhillips ~ C-~ 70 ---~ u~t. DES s~.~~~ uE ~s Kennedy, Chris -CPAI, Wells Supervisor: -_ _ _ _-_ Af~l N UWi _ - ,Field Name .5002923154 WEST SAK Well Type ®riginal KB Elevation (ft) Well Status Legal WeIlName Development 87.10 PROD 1 C-170 JOB:: Erosion /Corrosion Monitor _ Actual Start Date End Date Secondary Job Type ' Drillsit~ Primary Wellbore Affected t~"F1i'2E~07 06:00 8/11/2007 23:00 ZX46 Open /Close Zone 1 C ' 1 C-170 _..__ - P~q~~__.__._ , __Legal WeIlName ~ -_ Tye _ _ _._ {- gFEfRFE -- NeWwrtJlD# --- - - - -- 1C-170 Erosion /Corrosion Monitor 1C-170 ',Erosion !Corrosion Monitor 10191462 10191462 -- -~- -- --- - --- _ -- - __ L..- -- l7NIT/RIG: IiES SLICK LINE?li0 -- , Rig Accept Date Rig Release Date 'Contractor ',Rig Name/No ,Rig Type 8/11/2007 06:00 8/11/2007 23:00 'HES 760 SLICK LINE 'Rig Supervisor - Company 'Title Phone Mobile ,Phone Work Kennedy, Chris -CPAI, Wells Supervisor 'CPAI 'Wells Supervisor ' 448-3101 659-7022 - - _ _ _ _ .Comment _- PRE-RIG WORK DAILY OPERATIANS: 8/11/2007 EDITED BY:; cjkenne ~ __ - Report Start Date Report End Date General Remarks Daily Cost Total 8/11/2007 06:00 8/11/2007 23:00 INITIAL T/I/0=250/150 ' 9,364.00 .FINAL T/I/O=VAC/VAC Last 24hr Summary PULLED 3.813" RC JET PUMP W/DB-6 LOCK. PERFORMED SBHPS @ 5200' RKB=1043 PSI, 71 DEG F, GRADIENT @ 4800° RKB. CLOSED CMU @ 5188' RKB & MITIA TO 3000 PSIG --PASSED. OPENED CMU, COMPLETE. Weather Temperature (°F) Wind ..SUNNY 48.0 5 MPH Unit Supervisor _ _ _ _ ~ - ~~~ __T..- ~~ny --1- -- Title ~..'~ Mo4ile ~ Phone.4'ionc ~ ' ' WILSON -HES, Service Operator HES Service Operator LN/A 655-0232 Time Log - TT - -- --- -- -- --- - - --- - - - __. Stan' Cum Dur I ` Trme End Time Dur (hrs) (ham) ( __..---_-_- .-Operation __-_ __ _.. _~ _--- _. _ -,-~ Wellbore 06:00 107:00 1.00 1.00' WEEKLY SAFETY MEETING ' 1C-170 .07:00 108:00: ~ 1.00: 2.00 TRAVEL TO CWG, DOWNLOAD COMPUTER, TRAVEL 7 O LOCATION, CONTACT DSO, INSPECT ~ 1C-170 LOCATION, TGSM. WELL. S/1, SWAB LEAKING,GAS BAD, CALL GREASE CREW., CEASE CREW E ARRIVES, SERVICES SWAB AND MASTER. I ', ~ t I 08:00 09:00 1.00 3.00 RIG UP .108 WIRE, 2 1/8" ROLLER STEM, TS=RS,OC,S',OC,KJ,5',OC,OJ'S,OC,KJ,LSS,OC. ~',1C-170 09:00 ,10:00 ~ 1.OOL 4.00 PT W/GAS, RIH W/ ClC,3', 3.80" GAUGE RING TO 5177 SLM / 51$8 RK6, LOOKS CLEAN, POOH. iC-170 10:00 12:00 2.00' 6.00 ~ RIH W/ 4 1/2" PRS TO 5178' SLM / 5188' RKB, PULLED, POOH SLOW, OOH W/ 4 1/2'°JET PUMP 1 C-170 ' ', `ASSEMBLY, ALL PACK ON JET PUMP. I 12:00 `14:30 2.50 8.5U 10 MIN. LUB STOP, RIH W/`QC,2:72" C€NT„ SOFT-SET, DUAL PANEX GAUGES, 20 MIN. STOP @ ~1C-170 I I~' k i 5190' SLM / 5200' RKB( 12:31 PM-->12:51 PNt), PUH TO 4790' SLM / 4800' RKB 15 MIN. STOP( ~ I ' 12:55PM-->1:10PM), POOH 200 FPM, 10 MIN.LUB STOP. ('' 14:30 15:45 1.25 9.751 RIH W/ UC,3.813 42-BO, FEMALE TO FEMALE XO, 3.79" GAUGE RING TO 5178' SLM, HIT DOWN, 1C-170 ~ ~, ~ 'CLOSED CMU, PASSED BY 3 TIMES, POOH, OOH PIN UN-TOUCHED, 15.45 117:15 ~ 1.5011 11:251CALL FOR VALVE CREW, {A GATE VALVE NOT HOLIJti3G, LRS CANT RIG UP, CONFER WI pSO, ' 1C-170 '.RIG UP TO IA ON OTHER SIDE( INJECTION SIDE), RIG UP, PT LRS, STARTED PUMPING DOWN IA-. ~; CAUGHT FLUID fad 30 BBL.S, INJECTED FOR 10, IA WENT ON VAC, CONFER W/CWG AND NSK ', w I 'FIELD SUPERVISOR. 17:15 19:15 2.00.. 13.25' RIH W/ OC, 3.78" CENT., 2', 4 1/2" 4260 TO 5178' SLM / 5188' RKB, SET DOWN, HIT DOWN, SAW 1C-170 ',SLEEVE MOVEMENT„ PASSED BY TAGGED D-NIPPLE, 5233' SLM / 5249' RKB, POOH, LRS BACK, ', PT TO IA, STARTED PUMPING DOWN IA COUGHT FLUID AFTER 15 BBLS PERFORM MITIA Tn ' 3000 PSIG LOST 50 PSI FIRST 15 MIN. TUBING STAYED AM .SAME, IA=2950 PSI, ' 'TU- BJ1JI1~ AME, FILLED OUT FORM. PIN UN TOUCHED. ..19:1521:00 i~ 1:75 15.00 LRS SWITCHED TO TUBING PT TO 3000 PSI, LRS ON LINE 1 BPM, RIH W! SAME TO 5178' SLM / 1C-170 I I 5188' RKB, BLEED IA TO ZERO PSI, H!T ONE OIL JAR LICK, CAME FREE FROM CMU, IA WENT ON ` 1 (STRONG VAC. POOH, PIN UN-TOUCHED ..21:00 122:00 ~ 1.00. 16.00 RDMO, PJSM, NOTIFY DSO OF WELL STATUS. 1C-170 22:00 !23:00 1:00 17.00. TRAVEL TO CWG,. DROP UNIT @ YARD, DOWNLOAD, TURN IN PAPER WORK, EN[J PICKET. 1C-170 Wet1 fluids _ 1 _ .._... Fluid -__. -~ To (bbl)_ --_ I _.. ---- -- ... _-- - =- Note _ :.. _ - DIESEL 90.0 TUBING- www.peloton.com Page 1/1 Report Printed: 4/10/2008 ', -- -~ - - - - _ - - l -- - ---- --- --_ VUSR Historical -FILE COPY- fob: E rasion t Corrosion Monitor ', ' Report Date: $I13J2~307 ', ConocoPhillips 7 c-~ 70 --p~ unit: I-IES sislcK LANE ~ Kennedy, Chris - CPAI, Welts Supervisor: Af'I / UWI Field Name - --_ _ _ - 5002923154 WEST SAK Well Type ',Original KB Elevation (ft) Well Status Legal WeIlName Development 87.10 PROD 1 C-170 __ JOS: Erosion /Contusion Monitor Actual Start Date -- ,End Date - Secondary Job Type --- ___ - _ -- - - _--- .-__- _._- --i Dril 8!13/2007 06:00 8/13/2007 19:00 I ZX70 Caliper ' 1 C --- _ ProjectDesc _ ! Lagal WeIlName.. -'- - -- ---- Type __---- IC-170 Erosion %~Corrosion Monitor - ' 1C-170 Erosion /Corrosion Monitor UNIT/R4G; HES SL[GK LINE 764 _ ' Rig Accept Date Rig Release Date I Contractor Rig Name/No Rig Type 8/13/2007 06:00 8/13/2007 19:00 HES 764 SLICK LINE - 9--~ - _ - ------ _ _-- _ -- ---- --y _ - - -- Ri Su rvisor ! Compan Title Kennedy, Chris _CPAI, Wells Supervisor ',CPAI Wells Supervisor C®mment __ ----- _ - -- - - - - ®AILY 9PERATIONS: _ 8!13!2007 EDITED BY: cjkenne Report Start Date 'Report End Date General Remarks 8113/2007 06:00 8/13/2007 19:00 ' INTIAL T/1= 25/0 'FINAL T/1= 25/0 i Primary Wellbore Affected 1 C-170 =E / RFE ~ -- NatwprlllD # JI ' Last 24hr Summary _ - - ---_ _ _. _ __ -- PERFORMED PDS (27.5' OAL) MTT /CALIPER SURVEY FROM 5705' SONDEX MEASUREMENT TO SURFACE. DATA APPEARS GOOD. Weather Temperature (°F) Wind Unit Su pervisor ~ _ ' ' - $upervtapr -:. _ .' Title..---- - Mobile - - -- Company L Ptrone ~Nork 3 ZEMBA _ -- Z25 HES, Service Operator 'HES Service Operator N/A 94 L -- Ti S ( -- T - _ .- --- --- - - - --- - --- - - - - - - - - - - ~ r C D - - tart nme FridTirtt~,Dur(Ms), um u (hrs).. Operafion Wellbore j ; 06:00 ' 06:10 0.171 - 0.17', PICK UP COMPUTER AND PAPERWORK FROM CWG, CONTACT DSO, AND TRAVEL TO 1C-PAD. _ - ' 1C-170 06:10 106:25 { , 0.2511 042~ARRIVE ON`LOCATION; INSPECT, AND`CONhUCT T6SM: ~1C-170 ~ 06:25 07:10 0.75 1.17. MIRU SLU, SPOT BLEED TANK, REPACK STUFFING BOX, MAKE UP .125 WIRE, 12' OF 2 1/8 ',1C-170 ,ROLLER STEM (2.60 WHEELS ), KJ, AND LSS (MAKE UP EXTRA SECTION OF LUBIRCATOR ), 07`.10 '07:40 i 0.50 1:67 HES EOUIPMENT READY-PDS ON LOCATION SETTING UP TOOLS AND PROGRAM, ~ 1C-170 ~ 07:40 07:55 ~ 0.251 1.92 MAKE UP PDS TOOLS TO TOOLSTRING. 11 C-170 07:55 09:23 I 1.47 3.39 RIH W! 600' SONDEX MEASUREMENT, 08:21 RIH "r0 610', 08:26 RIH TO 620', 08:33 RIH @ 140-150' 1C-170 I PER MIN. TOOLS STOPPED DUE TO DEVIATION. @ 5698' SONDEX MEASUREMENT. PUH TO !.5695' AN[1 WAIT FOR CALIPER TO OPEN. 09:23 I 11:35 2.20' 6.59''TOUL BF_GINS 1 O OPEN, 09:28 BEGIN LOGGING UP @ 40' PER MIN. TO SURFACE. IN ' 1C-170 LUBRICATOR W( TOOLS. 11:35 112:05 I 0.50'{ 6:09TOOio TO C(_O5E AND BE_EEp OFF @ 11:48. St80 WELLHEAD. 1C-170 12:05 ,12:35 0.50, 6.59 OOH W/ TOOLS, BREAK DOWN PDS TOOLS, AND STANDBY FOR DATA CHECK (( DATA NO GOOD li 1C-170 )) REPROGRAMING TOOL. 92:35 93:05 ~ 0.50; 7.09 MAKE RDS TOOLS BACK UP TO TOOLSTIRNG. 1 C-170 13:05 16:35 3.50 10.59 RIH W/ SAME. MAKE STOPS @ 600', 610' AND 620' (TOOLS STOPPED DUE TO DEVIATION) ' 1 C-170 , 'BEGIN LOGGING UP FROM 5705' SONDEX MEASUREMENT TO SURFACE (HUNG UP @ 5185 LIGHTLY TAPPED BY W/ PDS REP. ON LOCATION) AND CONTINUE TO POOH. 16:35. 117:05 ~ 0.5p; 11.09~SI60WELLHEAD,ANDBEGINRIGGINGDOWNWHILEWAITING`FORDATA. ~1C-170 i 17:05 .17:50 0.751 11.84~GOOD DATA. BEGIN RIGGING DOWN (ALL ROLLERS ACCOUNTABLE ). 1C-170 97>50 i 18:35 j 0.75 12.59 RD-CONTACT DSO-PJSM. TRAVEL TQ 1F-12 AND SPOT EQUIPMENT UP FOR THE NIGH"~. 1C-170 ~ t ARRIVE ON LOCATION, INSPECT, AND CONDUCT BRIEF TGSM. SPOT EOIJIPMEN7 UP FOR THE NIGHT". 18:35 18:55 I 0.33 12.92 TRAVEL TO CWG TO DOWNLOAD /PAPERWORK. 1,1 C-170 ~ 18:55 X19:00` ~ 0.08 13:OOENDTICKET_ -- - 1C-170 ~ 1 WeH Fluids - - ---- ---- -- - - - -- ---- ------ ---. ____- T Note Fluid. -~. ~ 70 (ba). -- -- ~ __ ~--- __. www.peloton.com Page 1/1 Report Printed: 4/10/2008 WSR Historical -FILE COPY- '~°~° I3nlllnt Su ~ - ~~ ~ . Repart t3ate: 10118127 ConocoPhilllps ~ c-~ ~o ---~ ~~: s~B-os cc~l~~ Tul3~~o czu _ - Bessette, Paul -CPAI, Wells Supervisor: API ! UWI - - - - _ Field Name - -- --- - - 500'L923154 WEST SAK YVell Type - _ _ .Original KB Elevation (ft) Well Status Legal WeIlName Development 87.10 'PROD j 1 C-170 ' upport Ex WO B D l --- ~ i E D Actu al St art DaRe - Secondary Job Type Drillsite Primary Welibore Affected ' 06:00 10/18/2007 15 00 2X72 Secure Well --101'48Y2007 1 C 1C-170 - __.. -~- PkoiectDesc - ____ -;1-_ L.eaat:W~IName.-_-- - _.--- -.--------- TXPe -.- --- ~- ~ ?. A1FE./RFE 7_,- NetworfillD# - - ----- 1 C-170 Drilling Support -Exp WO -Wells 1 C-170 Drillint Support -Exp WO ' 10194052 ! 10194 SNIT/RIG° SLB-DS COILED TUBING"CTU 5 Rig Accept Date ~ ~ ' Rig Release Date Contractor Rig Name/No Rig Type ', 90/18/2007 06:00 10/18/2007 15:00 SLB-DS CTU 5 COILED TUBING _ Rig Supervisor Company 'Title Phone Mobile 'Phone Work Bessette, Paul -CPAI, Welts Supervisor CPAI Welts Supervisor 943-1172 - - _-- ° _- ---_ - -. _1659-7022 - -- _ _ - Comment - --_ - __ __ DAILY OPEItAT10NSt - -- _- -- - --- - - --- _ _ - _ - - Y: ctu4 10/18!2007 EDITED B - -- - - _ Re ort Start Date P Report End Date Generel Remarks Daily Cost Total 10/18/2007 06:00 10/18/2007 15:00 ,Initial T/I=20/0 ' 25,942.00 '; I - ~ Final T/I=20/0 -_ _ - _ _ --- - _ _ ~ -_ - ---- i Last 24hr Summary _ __ i Perform Drift & Logging runs prior to setting WRP. Ran drift run with 3.65 Nozzle to 6000 CTMD, Ran Logging run from 4000 CTMD to 6000 CTMD. Welt is ..freeze protected & S/I. -- Weather - - - Temperature (°F) Wind Overcast - 25.0 10 mph unit Supervisor _ _ - _ - - `: .Supervisor. _ _-~-~-- Company ~ Title ' ~-. Mobile Phone Work MOORE -SLB - DS, Coil Tubing ,SLB-DS Coil Tubing Operator N/A 943-1566 Operator - _ _ _ _ - -- Time L ~--' - _ - - - - - - 5 ime Dur (krs) Time. i End T Cum Dur i - (hrs) j Operation 1 welibore 06:00 08;3 0 2.50 2.50' MIRU, Hold safety meeting, Pressure test to 4000 psi, 1 C-170 08:30 109:00 0.50 3.00`BHA is ClC, DFCV; stinger 8~ 3.65 JSN, Totaf]ength of 6.25ft. 1C-170 ;!ii -09:00 09:30 0.50 3.50' RIH for drift run, Displace tubiny with diesel down to 3700ft, 1C-170 09:30 110:30 1.00 4.50'RIH to 6000ft on drift run, POOH for logging run, 1C 170 10:30 11:00 0.50 5.00 ~ Rig up BHA with Weatherford C/C to SLB memory logging tool total length of 17.41 ft. 1 C-170 1.1.00 ~ 13:00 2.00 7.00 ~;RIH to 6000 CTMD, putted up hole stowy to log, flagged pipe @ 5925 CTM1AD, PUH to 4000 CTMD, 1C-170 I Stopped logging. i www.peloton.com Page 111 Report Printed: 4/10/2008 _ - _ WSR Historical -FILE COPY- Job: arillint Support -Exp WO Report [}ate: 1011912007 ConocoPhillips ~ c-~ 70 ~--~run~t: ~L~-as eoiLE~ -rug~n~~ cTU s '' - Bessette, Palm - CPAI, Wells Supervisor: _-- APIfUWI _ _ _ Field Name 5002923154 WEST SAK Well Type 'Original KB Elevation (ft) Well Status - Legal WeliName 'Development 87.10 'PROD 1 C-170 ', .__-_ JOB:: Drillint-Support- Exp WO Actual Start pate End Date Secondary Job Type - Drillsite Primary Wellbore Affected i4lt9/2007 06:00 10/19/2007 18:00 ZX72 Secure Well 1C 1C-170 _. __-- ~`-----_--- ~ •- - ---- Tye - `- AFE / RFE T - Network/1U # proje~ Dose legal.. WellName __ iC-170 Drilling Support -Exp WO -Wells 1C-170 ' Dnllint Support -Exp WO 10194052 10194052 ~I ' UNIT/RiGr SLB-DS COILED TUBING CTU S ----__--_- °-__- - -- _. - - - _ _ - --- - a, ', Rig Accept Date ,Rig Release Date Contractor Rig Name/No 'Rig Type 10/19/2007 06:00 ' 10/19/2007 18:00 SLB-DS CTU S COILED TUBING _ Rig Supervisor Company Title ,Phone Mobile Phone Work - -- - -_ - - - -- --- - __ - _ __ _ _ . 1_--- -- Bessette, Paul - CPAI, Wells Supervisor ', CPAI Wells Supervisor 943-1172 659-7022 '.Comment - DAILY OPfRATiONS• _ 10!19!2007 EDITED BX: ctu4 - - _ _ - _ -- - - - Dally Cost Total - ~ ' Report Start Date Report End Date General Remarks 10/19/2007 06:00 10/19/2007 18:00 .Initial T/I=0/0 ', 30,730.00 Final T/I=0/0 Last 24hr Summary _ Set WRP, RIH with 3.69 Weatherford WRP, Set @ 5928 RKB, Performed successful Tubing/IA MIT, Set 3.73 OD catcher on top of WRP. Well is Freeze protected. Weather -- -- - ---- -_ - '-Temperat20 0 F) - _ __ ~ mh ___-- _ - - _ r - - -- - Snow P I', MOOR ESLB SDSYCoiI Tubing' I S DS ~- - Company ----- Coil Tubing Operator - -_ - - !, N/A Mohae -`+~3-1566 work ~ ', -0perator L Time Log - - - - - - -- -- - - --- - - Start -- - Cum Dur Time i End Tirn_e Dur (hrs) (hrs) i OpereOon Wellbor~s 06:00 08:00 2.00 2.00 MIRU, Hold safety meeting, pressure test to 3500 psi. 1C-170 ~ 08:00 ;09:00 1.00 3.00 RIH with ClC, DFCN, Hyd Disconnect, MHA, Hyd setting todl, Setting sleeve & 4.5 WRP (3.69 rd}, Total ',9C-174 1 length of 12.62 ft. I .09:00 '09:30 0.50, 3.50 RIH to 5940, PUH 4o Corrected depth of 5928 RKB, Drop ball, pump diesel @ 1.5 BPM, CTP=1450. 1C-170 09:30 10:00 ~ 0.50 4.00 Pumped 25 diesel @ 1.5 BPM to get ball over,goose neck, decreased rate to 0.7 BPM, set WRP @ 5928 ' 1C-170 ~~ G RKB, Confirmed set with 3k DW. I 10:00 11:00 1.OO 5.00' PUH pumping 1.0 BPM diesel, taking rtns off IA to fluid pack for MIT. 1 C-170 11:00. ~ 12:00 I L00 (i.00 Perform succesful combo MIT [~ 2000 psi; lost 63#`in 30 min. 1 G170 12:00 13:00 1.00 7.00 RIH with ClC, DFCN, MHA, 4.5 G-spear 8r 3.73 Catcher sub. Total length of 7.33ft. 1 C-170 13:00 15'00 I 2.00, 9.00 Pumped off of catcher @, 5927 RKB, POOH. 1 C-170 ~ 15:00 ,18:00 3.00'',- _ 12.00'' RDMO. !,1C-170 We1F Fluids -- - ~ --- _ -- --- -- - - - - - Rwd - ----- - To (bbl) T - - -Note --- -- -- www.peloton.com Page 111 Report Printed: 4/10/2008 / WSR Historical -FILE COPY- '~ Rt~enavai ~ Rg d ~ Q~2i'2t11?7 ConocoPhillips ~ ~_~ ~o ~- ~ ~'~~~~ ~ Start;~Cs Kai -CPAs, Virels Sl.lpe~riscl~: API l l1Wl Field Name 5002923154 K S --- - -- Well Type l)riginal KB Elevation (ft) WeI Status Le al WeIlName 9 .Development 87.10 PROD -~,1 C-170 JB~: Scale Remova4 Actual Start Date End Date Secondary Job Type ~Drillsite Primary W ellbore Affected t$!~1/20U`~ 06:00 10/22/2007 03.30 ZX03 Pumping /Load Well 1C 1C-170 ~ _-- - - p Desc - - - T T Legal We1lName~_T - TYpe ~ - AFE / RFE Nehaork/ID # 1C-170 Scale Removal +1C-170Scale Removal 10197985 110197985 UNITIRtC• I,RS PUMPING 44 ~ _ _ - 1 ---- - _._ g p Rig Release Date Ri Acce t Date Rig Name/No Contractor ,Rig Type 10/21/2007 06:00 10/22/2007 03:30 'LRS 44 '..PUMPING _ _ Rig Supervisor '.Company Title Phone Mobile TPhone Work Starck, Kai -CPAI, Wells Supervisor CPAI Wells Supervisor 943-1207 X659-7032 Comment DAILY OPERATtONSs_ _1Q1211200T EDITED BY: starck ____ _____ Report Start Date Report End Date 'General Remarks 10/21(2007 06:00 10/22/2007 03:30 Initial T/IA = 0/0 Final T/IA = 0/0 Daily Cost Total 14,055.00 Last 24hr Summary ated IA with 135 Bbls. of 2500 PPM Clean Cor fluid, soaked for 7 hours and Flushed out weth hot seawater. es cau ht dunn warm u circulation came back ve clean, samples from India/ returns from flush sta a had', Freeze p otectedVtubing aBd IIA wothsdi seLeSamrpl g g p rY _ ~ 9 some hydrocarbon based materials that cleaned up as circulation continued. All samples sent to lab for analyses. Weather ~ 'Temperature (°F) Wind Lnit Supervisor Supervisor 1 ---- Title '~ Mobile - Company _ ', Phone Work _ _ ~__ MURPHY -LRS, Pump Operator .LRS Pump Operator ~N/A 659-7929 I Timi3 L _ °9 __. _ _ _ ---- -- -- - - - -- - - - - --- - ~ Start Time ~ En ~ d:Time Dur (hrs) Cum Dur (hrs) _.-------- ---_ ----- lJDera4on -° ---- - - --- ---- . Wellborn -.i , 06:00 07:00 1.00 1.00 MIRU 1C-170 07:00 109:00 i 2.00 3.W' Pt surface lines and start pumping down to taking returns from tubing. Heating SW to 1,50 Deg. 1 for 1 1C-170 ', ` I` retums. 09:00 14:30 I 5.50 8.50 150 Bbls away, increase temp to 200 deg., 1.25 BPM 1C°170 :14`.30 16`.00 ' 1.50. 10.00, 560 Bbls. away, start 2500 PPM clean core in SW at 150 deg tC-170 ~ ' 16:00 23:00 7.00 17.00 135 Bbls. Clean Cor away (695 Bbls. total), FP surface lines and shut in for soak 'I 1C-170 23:00 01 00 2:00 19.00 Start flushing IA with 290 Bbls. 150 Deg. SW 1C-170 01:00 '02:30 ~ 1.50' 20.50 FP well with 100 Bbls. diesel down IA, U-tube to tubing 1C-170 02:30.03:30 ' 1.00' ?1.50 RDMO -- --- _ _ _ 1 ~ !Well Fluids - _- _ - -_ _ -- --._ ~. To ~~) ~ - Note _ - Fluid ~ --- - -- y SEAWATER - 988.0 ', DIESEL 110.0. www.peloton.com Page 1/1 Report Printed 4/10/2008 ' WSR Historical -FILE COPY- ConocoPhillips API / UWI ___ 5002923154 Well Type Development 1 C-170 Job: t~lt~ittint Support - FF~p Repc~tt ~~te: 1 iCl? 7 u,l~~: xES s~~c~ ~~E 7 Kennetf, ~~1~~ - CP"At, Webs supervisor: Field Name .WEST SAK _ _ Original KB Elevation (tt) 'Well Status ,Legal WeIlName 87.10 I PROD ':1 C-170 J06: _ _ _Driliint Su ort, End Date Secondary Job Type Drillsite P ,f mary Wellbore Affected Actual Start Date .Exp Wp 11/27/2007 06:00 11/27/2007 13:00 7_X50 Slickline Misc (Drift, Tag etc.) 1C ' 1C-170 Project Desc - -- --legal WeNName ,1- - _ Type - - _-- ?-AFE / RFE (`-- NetworkJlD # ~ 1C-170 Drilling Support -Exp WO -Wells 1C-170 Drillint Support -Exp WO 10194052 I 10194052 UNITIRIG: HEa SLICK;GNE 760:. _ _ - --- - r-------- - _ - - ---- _- _- - --- Rig Accept Date 'Rig Release Date 'Contractor Rig Name/No ,Rig Type 11/27!200706:00 11/27/200713:00 'HES ' 760 ISLICKLINE ,Rig Supervisor 'Company ,Title 'Phone Mobile Phone Work ~ Kennedy; Chris - CPAI, Wells Supervisor ' CPAI '..Wells Supervisor ', 943-1097 y659-7022 -- -- __ - ____ 'Comment DRIFT - - --- --- _ -_ Y-- --- DAIfdYOPERATIGNS_: 11127/2007 EDITED BY c~kenne _____ __ Report Start Date 'Report End Date General Remarks Dad Cost Total 11/27/2007 06:00 11/27/2007 13:00 INITIAL T/I/0=0/0/0 ', 3,622.00 FINAL T/I/O=0/0/0 ' Last 24hr Summary DRIFTED 7-5/8" CASING W/ 6.125" OD JUNK BASKET TO 5746' SLM, COULDN'T MAKE IT FURTHER DUE TO DEVIATION, RDMO. NOTE: RECOVERED ' LOST CLAMP PIN SUSPECTED LOST DURING RIG WORK ALONG W/ ELASTOMER DEBRIS. _- _ --- - Weather --- - - - - - - -- --___ _--- iTemperature(°F) Wind (CLOUDY, COLD 10.0 ~,3 MPH --- - - - -- -----1--- -- - --- -- - ------ _. Urtit Supervisor me _ _ _ Mobile - Phone work - supervisor Camparry - - - WILSON -HES, Service Operator HES Service Operator 943 1343 659 0232 Time L_og Sian Cum Dur- _ - --- -- -- ~ - - ,.. -. .Time fnd Tune Dur (nr3).. ~ (nrs) i operason _ w_elibore J , 06:00 07:00 1.00 1.00 S OW, TRAVEL TO LOOCATOION, CONTACT DSO, NSPECTLOCATION?TGSM RAILER, DIG OUT OF 1C-170 07:00 108:30 , 1.501 2:50 RIG UP .1'L5 WIRE, 1 7(8" TS=RS,OC,S',QC,KJ,S',QC,OJ'S,OC,KJ,LSS,QC. 11C-170 08:30 11:00 ~ 2.50 5.00 PT W/ GAS, RIH W/ 6.125" JUNK BASKET, STOP FALLING @ 5500' SLM, POOH, SWITCH TO 2 1/8" ~,1C-170 'ROLLER STEM, 2.62" WHEELS, RIH TO 5746' SLM, COULDN'T FALL CONFER W/ CWG, POOH. ~ ~~ ',OOH W/ SAMPLE OF BLACK CHUNKS OF SOMETHING, OBTAINED SAMPLE TO TURN IN 19.00 (12:00`. - 1.OOI~ 6:00 RDMO, PJSM; NOTIFY DSO OF WELL STATUS.. Ii1C-170 ~ ', '.12:00 !13:00 1.001 7.00 UROP 7" LUB @ KIC SHOP, STOP @ F-WING FOR PROCEDURE T_ 1C-170 __ _ __ - - - ----- --.- T - - We11 Fluids _ _ - ! II -- -_ -~ -- Note. Www.peloton.com Page 1/1 Report Printed: 4/10/2008 '' _ - _ _~ - --_ ~ , Job: Drillint Su rt - Ex WO pp° p WSR Historical -FILE COPY- ~ y~ i Report Date: 11/29/20tf7 COIlOCO~'11~IIp5 1 C-170 Unit: SLB-Eline ELECTRIC LINE 2196 - _. _ Boehme, Brandon -CPAI, Wells Superviso r. APi / IJWI Field Name 5002923154 WEST SAK ' Well T -.. __ ype 'Original KB Elevation (ff) ',.Well Status - - _ _- Legal WeIlName Development 87.10 PROD 'i 1 C-.170_ Jt)B: Drillint Su Ort ~ ~ Exp WO __ End Date !Secondary Job Type Actual Start Date ' Drillsite TPrimary Wellbore Affected 7':06;00 11/29/2007 18 00 ZX16 Eline Log Misc 1C 1C-170 - -__-- _- -- -_- - - - r~ Legal WeIlName I Type. _.-__ - -r T _ AFE / RFE ~ Nelwotk/1!S#' -- -- - 1 C-170 Drilling Support -Exp WO -Wells 1 C-170 ,Drillint Support -Exp WO _ _ 10194052 _ ,10194052 lJ'NITJRIG: $LB-Eline ELECTRIC LINE 2196 ~ ' Rig Accept Date Rig Release Date Contractor 'Rig Name/No ,Rig Type 11/29/2007 06:00 ' 11/29/2007 18:00 SLB-Eline 2196 ELECTRIC LINE __ _ __ ----- _ ~__ _ I~ig Supervisor - 'Company -- - ',Title - -- - T- 'Phone Mobile Phone Work Boehme, Brandon -CPAI, Wells Supervisor ~~, CPAI 'Wells Supervisor 1 - _ -- -- - ~ 943-1241 ' 659-7728 -- --- __ _.._ -. __ - --- - Comment GAILY OPERATIONS: 11/29/2007 EDIT ED BY: boehmbh _ Report Start Date ,Report End Date I General Remarks ',Daily Cost Total 11/29/2007 06:00 11/29/2007 18:00 ' --- 1 I 13,281.00 -- -- - .. ~ _ - __ - -- - - _ Last 24hr Summary - - - --- - -- _ ELINE UNIT 2196. PREPARE FOR SLB TRACTOR UCI LOG /CALIPER. i -- Weather __- -Temperature (°F) ',Wind _ _ _ __ --:-~ -- ----------- -_ i '' _ lJnit 5u rvisor ___ - ~B - - ~ i i - - - _ Title ~-- ~ Supervisor (. Company -. __ _ - -Phone Work , '.. -Mobile _ --- P JOFINSON -SLB - Eline, Eline SLB-Eline Eline O erator i N/A 448-1489 'Operator ~ Time: L _ Cum Dur StarE Ope2hon ftme. tnd Qur (hrsj. (hrs) ~ Time Wellbaxe _ - _ ' . . _ __ _ _ 06 00 18 00 12.00 12.00 1C-170 ~ _ _ -_ ~ - 1Meit FPuids " - ~ - __ ___ _ _. _.,_._ _ T -_ -._--- -- Note www.peloton.com Page 1/1 Report Printed: 4/10/2008 ', WSR Historical -FILE COPY- `~°~F 13r1['rnt. SPP°~ - ~~` ~~ ' Report Qate: 't 2121207 C®n®cOPhillips ~ c-~ 7o u~,~t: SLe-E~~r~e E~.E~~R[C I_~NE ~~~s _ - __ Boehme, Brandon -CPAI, Wells Supervisor: API I UWI :Field Name ' 5002923154 'WEST SAK WeI1 Type - _ - `,Original KB Elevation (k) rWeII Status Development ' 87.10 'PROD JOB:: Drtltint upport -- --- - ---- - --- 'Actual Start Date °Exp WQ 'End Date Secondary Job Type "' `b7:3(j 12/3/2007 00:15 ZX16 Eline Log Misc - -- - -- - - ProiectDesc T4 Legal WeIlName Type 1C-170 __ 1C 1C-170 1C 170 Drilling Support -Exp WO -Wells i1 C-170- Drillint Support -Exp WO 110194052E - 10194052 to a ~I lg LECTRIC LINE 2496 _ UNIT/RIG: SLB-Eline E R' Accept Date Rig Release Date 'Contractor Rig Name/No ~I Rig Type ~ II 12/2/2007 07:30 12/3/2007 00:15 SLB-Eline 2196 (ELECTRIC LINE Ri Su ervisor p - - -- Company Title Phone Mobile Phone Work 9 p ~ li Boehme, Brandon -CPAI, Wells Su ervlsor CPAI Wells Supervisor ~ 943-1241 ~ 659-7728 Comment ---- - - -- - -- DAICYOPERATIONS: 92@/20Q7 EDITED BY: ;ELt12196 __-- _-- --- -_- _--- __-- _ ~ 'Report Stag Date ,Report End Date 'General Remarks Daly Cost Total 12/2/2007 07:30 12/3/2007 00:15 Initial: T/I/O 0/0/0 ; 35,382.17 ~ I ', '.Final: T/I/O 0/0/0 ' I - - < ~ __ _ Last 24hr Summary __ RAN A UCI CORROSION LOG FROM 5800' TO 100' IN LOW RES MODE '~ LOG AN MALLY AREA 2500' - 2720' IN HIGH RES MODE, SECTION WAS IN GOOD CONDITION --~+ THE 7 5/8" CASING IS IN GOOD CONDITION DID NOT FIND ANY SIGNIFICANT INTERNAL OR EXTERNAL CORROSION '.Weather Temperature(°F) ;end I I , __ Untt ~U~ef V 156P - - ~ - - --- - _ ~ -- - ~ Title Mobile --- -~ Supervraor Company ` Phone Work _ _--- -?---- - -k =--- -- -- JOHNSON -SLB - Eline, Eline SLB-Eline Eline O erator NIA p -- - 1448-1489 ,..Operator ' '; - ~ I Time. L _ _. -- ---- - - _ '- - - -- - - - - -- ~ ~I Cum Der Start Trne End Time Dur (hrs) (hrs) Operation _--- --- - Wellbore ' - -- - --- - - --- -- - __ _w_. 07:30 ,09:00 1.50 1.50 AT KIC, REHEAD CABLE, LOAD TOOLS 1C-170 09:00 ~11:3U' I ` 2.50 4.00', STANDBY FOR WIND TO DIE DOWN AT 1C PAR 1C-170 11:30 12:15 0.75 4.75 DRIVE TO 1C PAD, SPOT EQUIP, HOLD SAFETY MEETING 110-170 12'.15 '.13:30 1.25 6.00' WAIT FOR ROLLERS TO COME FROM PRUDHOE' 10-170 j 13:30 ',14:15 0.75 6.75 START TO RIG UP 110-170 I 14:95 15:45 1.50 8.25 WIND HAS PICKED UP TO OVER 40MPH AGAIN, STANDBY 1C-170 15:45 16:15 0.5U 8.75 FINISH RIG UP ~1C-170 16:15 1730 1.25' 10.00 RIH W/HEAD/SWIVEL/ROLLERSlEDTC/3 KJ/(ICI CART/UCI SONDE (51.1' X 5:5° MAX OD} 1C-170 ~I ' 17:30 ,18:00 I 0.50' 10.50 LOG REPEAT PASS FROM 5500 TO 5300 110-170 ' 18:00 !20:30 2.5t1; 13.00' LOG MAIN HI SPEED PASS FROM 5800 TO SURF 1C-170 , . . , . ANOMALYS 1 22x00 f 23:00 ~L 1.00` 15.50 LOG HI RES PASSES: 2710-2500, 225Q-2100- 10-170 ', '23:00 123:30 0.50 16.00 POOH 110-170 ' 23:30 iQO:OD i 0`.5U` 16.50 RIG DOWN 1C-170 ' !OO UU '00°15 0 25 16 75 DRIVE TO KCC DROP BACK IN HOLE TO MAKE HI RESOLUTION PASSES OVER 9C-170 50 CHECK HI SPEED PASS 22:00 1 50 14 20:30 1C-170 _..-- - - -__~ -- - --- _ _ 1 We1CEluids _T -- ~ _-- _ _ e - - ~ i • ~ -~a..., _~;~ ~. ,~.,... , ~. MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • Well Job # ~, 4n~ 3Ara s~ ~~~~~~~ Log Description C,- NO.4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01/25/08 26-13 11996584 PRODUCTION PROFILE ~j~- - J(> 01110/08 1 1E-112 11994598 INJECTION PROFILE v~ - ~ 01/11/08 1 1J-164L1 12005203 MEM INJECTION•PROFILE aQ~- ~ ~ U~~ 01122/08 1 2M-20 11996596 PRODUCTION PROFILE ~ - V~-( 01/22108 1 1C-170 11970605 USIT 12102107 1 2G-06 11994596 PSP MULTI-FINGER CALIPER 01/10108 1 3K-102 11994599 MDT ~ - 01114/08 1 1J-127 11994603 INJECTION PROFILE UZC. ~0(o•-bLl~- 01121/08 1 2T-21 11839639 RST 1 ~ 08/02107 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. lJ ~6 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report/ EDE 1C -170 MTT / Caliper Report 13-Aug{)7 sCANNED SEP 0 7 2007 '. 1i- dO '3--0"1 <5 I s--"3'i5c~ Signed: (~. P jJ~--'---'-_. RECEIVED Date: ~FP (\ 4 ?lHll Print Name: i~,J/1 ( ì ")h /11 C) (~I,). Lt .A kDl/t ,\Iaska Oil & Gas ()/tS. COnllf1';~IOn ^ nchnr:3g') PRoAcTIVE DIAGNOS11C SERVICES, INC., 130 W.INTERNA110NAL AIRPORT RD SUITE C, ANCHORAGE, AI< 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@.MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _CoPY- 00 ]DSANC-2OxxIZ _ Word\Distribution\Transmittal_ Sheels\TransmiUJrigínaJ.doc I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: . . Memory Multi-Finger Caliper & Magnetic Thickness Tool Log Results Summary ConocoPhillips Alaska, Inc. August 13, 2007 9505 1 4.5" 12.6 lb. L-80 Tubing 7.625" 29.7 Ib BTCM Surface Casing 16" 62.51b WELDED Conductor Pipe Well: 1C-170 Field: Kuparuk State: Alaska API No.: SO..Q29-23154-00 Top Log Intvl1.: Surface Bot. Log IntvI1.: 5,711 Ft. (MD) Top Log Intvl1.: 20 Ft (MD) (MTT only) Bot. Log Intvl1.: 5,720 Ft. (MD) (MTT only) Top Log Intvl1.: 20 Ft (MD) (MTT only) Bot. Log Intvl1.: 130 Ft. (MD) (MTT only) Inspection Type : COMMENTS: Co"osive & Mechanical Damage Inspection This log is tied into the 0 Nipple @ 5,249' (Driller's depth). This is the first log ofthis well with the 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 4.5" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal ofthe 4.5" tubing, 7.625" surface casing, and 16" conductor within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. Generally, intermittent high-frequency metal loss indications are attributed to metal loss ofthe tubing or inner-most string, and metal loss to outer concentric strings will be denoted by lower frequency shifts in the average metal loss of all twelve sensors combined. In this log, the MTT was calibrated down hole (615'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" surface casing and 16" conductor pipe. INTeRPRETA 110~ OF CALIPER LOG RESULTS FOR 3.5" TUBING: This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing interval logged is in good condition with respect to internal corrosive damage, except for a wall penetration of 22% recorded in joint 49 @ 1,526'. The damage appears to be in the form of Isolated Pitting. No significant areas of internal cross-sectional wall loss or I.D. restrictions are recorded by the caliper. 4"5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 22%) Jt 49 @ 1,526 Ft. (MD) No other significant wall penetrations (>19%) are recorded. ...,,~ ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 RECEIVED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 SEP 0 4 Z007 -\Jaska Oil & Gas Coos. Commission Anchorage I I I I I I I I I I I I I I I I I I I . . 4.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of internal cross-sectional wall loss (> 3%) are recorded. 4.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D restrictions are recorded. IN1J:~PRETATlON OF MTT LOG RESULTS: A graph of the average metal loss assessed from the MTT data on a joint-by-joint basis is included in this report. The MTT log results indicate metal loss to some degree throughout the interval logged, with intervals of more significant metal loss indicated over the top -200'3DI3Sd over the interval-2,000' to -2,SOO'. Detail prints of the MTT recordings over the intervals 20' - 170' and 1,840' - 2,200' are included in this report. The later interval was chosen to illustrate the difference in the recordings over the interval above 2,000' (where less metal loss is indicated) and the interval below 2,000' (where more significant metal loss is indicated). Throughout most of the logged interval, the correlation of the abundance of high frequency tool responses on individual sensors to the shift in the average change in overall metal thickness curve points to the probability that a majority of the metal loss indicated is a feature of the outside of the tubing. An exception to this occurs over the interval just below the hanger (21' - 30') where the overall metal change curve shows a discernable loss of metal, but high frequency responses on the individual sensors are very limited. This points to the probability that the metal loss over this interval just below the hanger is a feature of an outer casing string, rather than the tubing. The minor damage recorded by the caliper on the internal surface of the tubing does not appear to have a significant influence on the pattern of metal loss indicated by MTT over the logged interval. This supports a conclusion that there is significant metal loss in this well bore over the intervals 20' - 270' and 2,000' - 2,SOO' that are not associated with the internal surface of the tubing. I Field Engineer: S. Carpenter Analysts: J. Burton 1M. Lawrence! B. Qí Witness: C. Kennedy ProActive Diagnostic Services, Inc. í P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I Profile I 4.5 in (14.1' -5681 Weü: Field: 1 C-170 Kuparuk I Alaska, Inc. Survey USA Aug 13, 2007 I I Approx. Tool Deviation Borehole Profile 50 18 I I 25 758 I 1532 I I 75 2316 "- GLM 1 Q) E Ii ;::¡ r:: Z 100 3121 I 125 3889 I 150 4664 I GLM2 I I 175 181 o 50 5495 5681 100 Profile wall) I Tool Deviation I BoUom of Su rvey '" 181 I I I I I Well: Field: 1C-' 70 Alaska, Inc. I Country: USA I Nom.OD 4.5 ins 12.6 Grade & Thread l·80 Penetration and Metai loss I metal loss 150 I 100 I 50 o 0 to 1%, 1 to 10 10 20 to 40 to over 10% 20% 40"1" 85% 85% I I I Damage ( body ) 40 I 30 20 I 10 I o imlated general line ring hole I pass pitting corrosion corrosion corrosion ¡hIe hole I o I I I I Survey Date: Tool Type: Tool Size: No. of Fingers: 'st: Nom'!D 3.958 ins o o penetration GLM 1 GLM2 Aug 13, 2007 UW MFC 40 No. 213121 2.75 40 ß. Nom. Upset 4.5 ins len. 6.0 ins Damage Profile metal loss 50 Bottom of Survey = 1 a 1 Overview page 2 Lower len. 6.0 ins 100 I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Wall: Upset WaD: Nominal 1.0.: 4.5 in 12.6 ppf 1.-00 0.271 in 0.271 in 3.958 in Well: Field: 1 C-170 Kuparuk Alaska, inc. USA 1 3, 2007 I I I I I I Joint jt. Depth Pel Pen. Pen. ! i'Aelal Min. '^.¡:> Profile No. (ft.) ~:;~:i;t W. Comments on ,. ., (Ins.) (Ins.) 0 50 100 .1 14 ¡ 0.D1 PUP 1 18 1\01 1.1 49 i1.01 UP Elli1 0.D1 2 3 81 0 'I ~ 1.92 4 12 1f) '1.93 5 143 0.03 10 3.93 6 173 0.D1 ¿ 3.93 7 204 0.D1 394 8 235 0.0 3.94 9 265 (t 3.94 10 296 )t T '-193 11 326 ) 12 31)7 I "4 3.95 13 387 ) 3.93 14 418 ) 3.94 Shallow.....itlin<>. 15 MR 0.02 3.94 15.1 478 0 "( i.RR n NIPP¡¡:- 16 461 rii11 :; ~!J4 17 511 0.D1 7 392 18 541 0.05 1 it 3.94 Shallow.....¡tJino. 19 572 0.D1 3.94 20 602 I OO? 1ft 21 633 I 0.D1 27 665 0.D1 m 23 696 0.D1 24 727 001 25 756 7 3.95 26 788 :tltf 27 819 Shallow nitJino. 28 849 0.00 29 881 I 3.93 Shallow nittin<:r. 30 912 ( 3.95 31 942 ( 3.93 32 974 3.g5 Shallow niUina. La1005 ) 3.92 34 1037 0.03 )) I 3.94 35 1068 0.02 I 3.90 36 1099 0.03 \)$ 3.92 Shallow.....itlin<1. 37 1130 10m =HÎ if} 1162 0.01 Shal!,..,w....iuin". 39 1192 0.02 3.94 40 1223 0.04 1 3.95 . nitlina 41 1253 orn 2 3.92 II 42 1284 oh") 3.91 Shallow nittina. 43 1316 0.03 3.89 44 1i48 0.01 1.94 45 1378 ó:ñ~ 1= ; 3.93 46 1408 q 393 Shallow n¡ttincr. 47 1440 q I 3.9'1 Shallow nitlincr. Body Metal Loss Body I I JOINT TABULATION SH Wall: Upset Wall: NominaII.D.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in l-80 WeD: 1C-1 70 Field: Inc. USA Survey Aug 13, 2007 I I I I I I I I I I I I I I I I joint Jt Depth Pen. Pen. Pen. ¡"'etal Min. Profile No. (Ft) (In5.;\ ~~ W. Comments ~ wall) (Ins.) 0 50 100 48 1472 0.04 ftim~:. =- 49 I 1502 0.06 ttinll. 50 1532 0.02 ¡ 3.92 51 1563 0.02 3.93 52 15q5 n 0.02 3.9'1 53 1626 ( 0.02 3. 5 54 1657 ( 0 3. t5 55 1689 ( 3. t2 Ii 3.93 Shallow oitüml:. 3.95 Shallow oitJÎnlZ. 58 1781 j ¡ 3.93 59 1812 I ( ? 1.93 60 1843 I ( ? 3.(}1 61 1 ( 001 I 3.92 62 (- I 393 Shallow oit1it1IZ. 63 ; I~ ·tfínq. j~ 65 1998 )1 66 2030 0 1 67 2062 0.Q1 68 2094 0.ü1 I 3.92 69 212'1 0 0.02 3.92 70 2156 ( 0.02 3.88 71 2189 ( 0.Q1 i 7') gm 73 2253 0 74 2284 0 0.Q1 2 75 2316 ( 0.Q1 I 3.93 76 2348 ( 002 1 3.93 77 2380 ( 0.01 3.93 78 '412 0.D1 3.93 79 '441 3.93 80 473 3.93 81 2505 3.93 82 2537 ( ; 83 2568 ( ( 84 2600 í 85 2632 ( 10 86 2664 86.1 2695 0.D1 3.94 PUP ~ 2702 0 ~ GlM 1 lIatm @ 2:30) PUP 87 2722 ? 3.93 88 2752 3.92 89 27R5 I I 3.94 90 2815 3.94 91 2f146 3.95 92 2876 =ät 93 2907 94 2938 Shallow DiUin!;"!. rill Meta! 2 I I I I I I I PDS JOINT LA TION SH Wall: Upset Wall: NominaILD.: 4.5 in 12.6 1.-80 0.271 in 0.271 in 3.958 in Well: Field: K-1 70 Kuparuk Inc. USA Aug 13, 2007 I I Joint Jt Depth Pen. Pen. Pen. ¡'v1etal Min. " Profile No. (~~,¡:(; t ;s 1.0. Comments wall) (Ins.) (Ins.) 0 50 100 95 2968 7 I 3.94 96 2998 14 ! ~ Shallow Dítûm~. 3029 3059 3.93 3.93 3121 3.92 101 3152 0.D3 ~ 102 3182 .,gj 103 3213 104 3244 1 3.92 105 O. 3 3.94 106 3306 0.02 3.94 107 om 1 3.92 Shallow Ditlit1l1. 108 3366 Bl~ Shallow o¡tû~. 109 3397 31 110 3429 I 3.92 111 1459 1 1.93 112 3490 ( 2 3.93 113 3521 o í2 3.93 Shallow oitling 114 3551 o 3.93 115 3582 n 0.04 ¡ 3 3.94 Shallow pit1im~, 116 3h13 n 0.03 m 3.92 117 3643 n 0.02 1.94 118 'J£...,A () 0.D31 3.90 Shallow oit1ing. 119 3704 $$i' 1 ~ Shallow oitiínst. 120 3735 121 3765 I E, 122 3795 0.03 3.94 123 3827 0.04 3.95 Shallow oitlim2. 124 3858 0.02 2 3.92 125 3889 om 0 =ffl 126 3920 :0: t 127 3950 128 3980 3.87 129 4017 3.95 Shallow oiUÎng. 130 4044 0.03 1 3.91 W407"i 0.02 13 3.88 4106 ( 0.02 13 3.94 133 4137 ( 004 1 3.92 Shallow tJitliml, 134 4169 ( =;= 1 3.92 135 4199 ( ~ Shallow oitling. 136 4230 ( 137 42¡;1 Shallow oitting. 138 4291 3.93 139 4322 Ii 3.92 Shallow Pitting 140 4353 0.D3 3.94 Shallow DittinR. 141 4385 0.03 3.93 Shallow oitlil1lI. Jill 142 4415 0.04 1 3.92 Shallow oitling, 143 4446 ( 003 'I 393 144 4478 0 0.03 2 3.'10 CL_" itliml. I I I I I I I Body Metal Loss 3 I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Wall: Upset Wall: Nomina! 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in l-80 We!!: Field: Company: 1C-170 Kuparuk ConocoPhiDips Alaska, Inc. USA Aug 13, 2007 I I I I Joint Jt. Depth F'en. Pen. Pen. :'pleial Min. Damag e Profile No. (:;~~(;I .n; LD. Comments ('Yo (fns.) (Ins.) 0 50 100 145 4510 0.02 q 1 3.93 146 4541 OJ!3 1 2 3.93 147 4571 0.03 n .1 3.92 148 4602 0.02 3.91 149 4633 n 0.03 391 150 4664 n 0.03 3.92 151 4695 n 0.01 Ii 152 4725 n 0.02 I 153 47St) 0 O.03~ I Shallow niUinQ. 1'14 4786 0 0.03 Shallow nitling-. 1.'55 4817 0.03 10 156 4847 0.D2 ! B 157 4R78 ~ 158 4909 159 4940 3.91 159.1 4970 3.91 PUP 159.2 4980 1ft r.! M 2 Hatch @ S:OO\ 159.3 498fì 0.0"1 H1 1 PUP 160 4997 0.03 ) 3.92 161 0.03 'I ~.93 lh2 5058 I 0.01 ~.92 163 50Ra g:g}i4 3.90 164 '1119 [ I "I ql 165 5150 ] 1 3.91 16'1.1 'H81 0 1.A1 SHclinQ SIP"vp 165.2 S20t) 0 3.91 Gau2e Carrier 166 521 o. m 3.90 166.1 5249 0 1 i 375 D NIPPLE 167 52'>0 0.00 '.91 168 ') 0.01 4 I 3.92 169 5'nO 0.02 1 3.91 170 5341 0.02 2 3.91 171 5371 0.01 ; 3.9? 172 5402 ) 0.01 . ;> 3.92 173 5433 0.01 ít "I.Q2 174 5463 0 0.01 3.92 175 "495 0.02 3.92 176 5525 0.01 3.91 177 5556 0.03 10 3.9? 178 '>588 0.02 3.91 179 5619 0 ~ 3.97 HID 5649 (} ( 0.00 181 5681 (} 0.02 ( 1.89 Body Meta! loss Body 4 I I ------ ---.. .. .. Well: 1 C-1 70 Field: Kuparuk Alaska, Ine. USA Tubin : 4.5 ins 12.6 f L·80 depth 1 Tool '" 43 Nominal 10'" 3.958 Nominal 00 '" 4.5 Tool deviation'" 16 0 .. -.. ...... s s Survey Date: Tool Tool Size: No. of Anal st: 13,2007 UW MFC 40 No. 213121 2.75 40 B. ¡ ft Isolated .06 ins'" 22% Wall Penetration HIGH SIDE'" UP Cross Sections page 1 I I 4.5 in (18.0' - 5681 Well: Field: 1 C 170 I fne. Country: Date: USA 131 2007 I I Decrease increase I HI 25 758 I 50 1532 I 75 2316 I '- \II GLM 1 it -0 E :;¡ .5 z I ...... c 100 3121 ~ I 125 3889 I 150 4664 I GLM2 I 175 5495 181 5681 I -50'-'10 0 50"1" in Metal Thickness I Bottom of == 181 I I I I I I I I I I I I I I I I I I I I I <!as. MTT 10 .... " -1 ~ DItoq...:mic ~.,,''''' 1m:. ~;:¡. Database File: d:\warrior\data\1c-170\1 c-170. db Dataset Pathname: 1/1/1/1 Presentation Format mtt Dataset Creation: Tue 2110:26:302007 Charted in Feet scaled 1:120 1 MTTP01 (rad) 51 0 Line ":;. ... '''''I. .,_, -200 1-45.2 MTTP12 (rad) 4.8 ., 4.5 MIT Finger 02 {in} 1.5 I I I I I I I I I I I I I I I I I I ! I I I þ@ it--' '. CDHo, 20 01 ~ "} ~rea ~ \ !------Meta! is¡Ç .....-. -" - <; - '--- -.. --- . ~ tt - <- - Jt .> ~ \ - 40 - Localized Metal ò>;s Tubing &c - t I 1\ Jt. 1" 1 lubin Cc ~ -- -- -<. 1\ ~ Localized Metal Loss - J 60 J ¡ I ! I Metal '<'J Collar t <, ) I Jt r..... } f--- - -,-. --- --.- .-- . -- I 80 Tubing Coli ~. I.J t=1' I ,rea of i Metal loss .~ I '-11- ¡.....A '<:::'IL Wide Me -- tH if Jt 3 i . ) , I '1> I I I , !-- 100 ¡.....; } Wide ð___"::'" M -- - -._- I-- -- Collar ·Tul)ing Collar Ii ) - 120 Area of Relative Metal Loss Jt 4 Bottom of 10" Conductor Shift: in Base Une Due to Absence of Conductor (Some Meta! Loss to I 1!J Indicated as f-- -- -- ) 140 - !\ IU U!ll~ Coli I' k ) it I ;Æ [;a$1I1' Collar ) IUblng .- ...- I Jt. 5 . 11 ) 160 -- ---. ..- .- , _TI.: bin! Colla Eli 180 Jt 6 -10CDelta Metal Thickness (''10) PO) IUU 1 MTTP01 (rad) 51 0 Line Speed (ftlmin) -200 -45.2 MTTP12 (fad) 4.8 4.5 MIT Finger 02 (in) 1.5 I I I I I I I I I I I I I I cfas. . MTT 10 - " 1 - ~ DiA<¡-''' s,,~ 1_. "1:1'" Database File: u. lVI'''';! I IVI \Udti:O!\ Iv~! 1,...-t7r. ,.¡¡..., .. v.~~ Dataset Pathnarne: 1/1/1/1 - n<::::S<:::lilallVI! Format mtt Dataset Creation: Tue 2110:26:302007 Charted in Feet scaled 1 ~(%) 50 0 MTTP01 (rad) 100 0 Une Speed (ft/min) -200 -92.3 MTTP12 (rad) 7.6 3.7 MIT Finger 02 (in) 1.7 ... < ~I > 1850 - ~ Tubing :> Jt 60 ? ) rea of Relative : t--A '~. v.~' Meta! Loss 011 One Sic e or ¡ u[m Metal Los5- -. ") - Ii>- ') I - LJ !-- f-- ?-. ~ ¡... 1---- r-- - J 1<' -" .¡ I I> -~ A.... ... Meta! Loss on One Side of '\JIJI! '¡'¡ It Jt 61 --- -.- 1-- f-. I> ~ .. ~ ~ ) f- 1= i\ ¡.. I':> 1900 ~ -- - -- ) I - - Tubing } - - Jt 62 ! I ). arent Metal Loss ~n One S i~e!! I f-~ >.- ':!J;I--- - - of - r-r-- <'111 oss ì ..::I - .-.. > -"' .- - - 1---- . I ;;>, Þ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I :> -:~ - ~ u~ -- --tt- ~ ----:: j c~~~ of Relative 14' Meta! Los$- Metal Loss on One t3ide of T 1950 I ) --...- - Jt 63 ~I .- > ~. -' --- --- ~ '> -- r I ,....- , - Tubing Jt 64 - - > ...-._- - r---.. -:;; Meta! Loss on One Side of i::> ;;;;;¡ ). - - ... r -'t I Area of Relative '" ~ Metal Loss. ~ 1 -0( ') ff f--: - 2000 ~. -. ,.....- - I r Tubing I Jt 65 " rent Loss Around Corl: -;;;:~ ) - - ') - - -- -- - Tubing Jt 66 [._. -- í--- -- '> ~ 2050 ~ :;. .- - > " I Tubing ..It 67 :> >1 ¡ ~- I I I I I I I I I I I I I I I I I I I - 4± - - --- Jt 67 - Loss Around Com iete Cirtumferenc --- ..-- c-- 2100 r:= ..- ~- Jt 68 ::> f-- ¡....- ¡.......... > ea of Relative eta! Loss - ~ ...- - = þ Jt 69 - rea of ,.. ". aiL?r" ) -- 2150 .. '), ",",""'IV, """ Meta! f-'-- -- ::- - '> -- f--.- --. ~ Jt 70 '::> I f ¡ f-'-- - - ;,. > :> f--- ..- - = - 2200 ..II! -50 Delta Meta! Thickness (%) 50 0 MTTP01 (rad) f Line Speed (ftfmín) -200 -92.3 MTTP12 (rad) MiT Finger 02 (in) 1.7 I KRU I I I I I I I I ¡ HORZT 41/16" 5 M {w/penetrator wire) 9" OT!S I I I I HANGER I I ~rf (!lmS-121B5) I I I . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~CANNED JUL 11 2007 ~_ o1?J d-.DJ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft gal 1C-125 201-199 11" na na 4.8 6/9/2007 1C-170 203-078 23" na na 14.5 61912007 1C-174 203-027 28" na na 9 6/9/2007 1 C-178 203-041 40" na na 16 6/9/2007 1C-184 203-089 24" na na 10.4 61912007 Kuparuk Field June 9,2007 FW: ¡ C- ¡ 70 (PTD 2030780) Temporary Gaslift Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- from: Selisker, Gary R Sent: Monday, December 19, 20058:19 AM To: NSK West Sak Prod Engr; NSK Problem Well Supv Cc: CPF1 Prod Supt; Rodgers, James T; Jenkins, Lubbie Allen; Spencer, Jeffrey A Subject: RE: 1C-170 (PTD 2030780) Temporary Gaslift ¡ of3 12/19/2005 9:09 AM FW: 1 C-170 (PTD 2030780) Temporary Gaslift e e To clarify I have attached two items that reflect that 1 C-170 is within the boundaries of our SSEOR Area I. I had seen one exhibit that the picture clipped off the 1 C-l 70 well but please note the attached Power Point where we highlight 1 C-l 70 as a proposed producer. I think Mr. Maunder's point is well taken regarding the service of this well. I concur with Hai that we need to produce the water we injected out of the well and possibly some gas prior to this service converSIOn. Let me know if you have any questions or feedback. Thanks, Gary Selisker -----Original Message----- from: NSK West Sak Prod Engr Sent: Sunday, December 18, 20057:39 PM To: NSK Problem Well Supv Cc: CPFl Prod Supt; Rodgers, James T; Jenkins, Lubbie Allen; Selisker, Gary R Subject: RE: lC-170 (PTD 2030780) Temporary Gaslift Jerry, We decided to postpone the gas lift test on 1C-170 for a little while. We probably injected water into the well when the jet pump washed out. If we were to bring the well on in gaslift service right now, we would: 1) risk the chance of freezing off the well (300 bpd, 100% watercut initially, it's cold outside), and 2) need to have the well on gaslift longer (>10 days) to wait for the watercut to fall back to normal levels. SO...The current plan is to bring the well back online in jet pump service, produce out the water we injected, and then shut the well in at a future date to verify the watercut. With the holidays coming up, we probably won't do the gaslift test until mid-January. To answer Tom's question: though 1C-170 does not appear on the map in the West Sak SSEOR application, it is on the periphery and does receive support form the west from 1C-174, which was recently converted to MI injection. thanks -Hai -----Original Message----- from: NSK Problem Well Supv Sent: Thursday, December 15, 2005 3:26 PM To: NSK West Sak Prod Engr Subject: FW: 1C-170 (PTD 2030780) Temporary Gaslift Mike: Can you answer Tom's question and send back to me? Otherwise you have the OK to go with gas lift. 20f3 12/19/20059:09 AM FW: 1 C-170 (PTD 2030780) Temporary Gaslitt e Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- from: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 15, 2005 3:20 PM To: NSK Problem Well Supv Subject: Re: 1C-170 (PTD 2030780) Temporary Gaslift Jerry, You are just changing the power fluid. I would imagine that the surface pressure might actually decline using gas. Is this one of the wells in the "pilot" area?? Getting a handle on the producing characteristics of wells in that area is important. Thanks for the notice, nothing further is needed. I would appreciate your providing the test comparison information when you have acquired it. Good luck, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/15/2005 3:05 PM: Tom: 1C-170 (PTD 2030780) is a surface powered jet pump West Sak producer that Engineering would like to lift for up to 10-days on gaslift. The intent is remove the power fluid from the production liquids to get a firm grasp on water production from the well. After well testing the lift will return to the surface powered supply. There is no intent for anything other than accurate production data. We could start gaslift as early as a day or two from now, so let me know your thoughts as early as possible. Thanks for the approval ahead of time. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 30f3 12/19/2005 9:09 AM Re: 1 C-170 (PTD 2030780) Temporary GaSli~ . Subject: Re: 1 C-170 (PTD 2030780) Temporary Gaslift From: Thomas Maunder <tom _ maurrd~r@admin;state.ak. us> Date: Thu, 15 Dec 2005 15:19:40 -0900 l.'h;N$K Pröb~IïW~~l Supv <nI617@codðcophiÜms;com> ,)," Jerry, You are just changing the power fluid. I would imagine that the surface pressure might actually decline using gas. Is this one of the wells in the "pilot" area?? Getting a handle on the producing characteristics of wells in that area is important. Thanks for the notice, nothing further is needed. I would appreciate your providing the test comparison information when you have acquired it. Good luck, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/15/2005 3:05 PM: Tom: 1 C-170 (PTD 2030780) is a surface powered jet pump West Sak producer that Engineering would like to lift for up to 10-days on gaslift. The intent is remove the power fluid from the production liquids to get a firm grasp on water production from the well. After well testing the lift will return to the surface powered supply. There is no intent for anything other than accurate production data. We could start gaslift as early as a day or two from now, so let me know your thoughts as early as possible. Thanks for the approval ahead of time. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 12/15/20053:20 PM ^)J~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030180 Well Name/No. KUPARUK RIV U WSAK 1C-170 Operator CONOCOPHILLlPS ALASKA INC MD 12230 V TVD 3798./' Completion Date 5/27/2003""/ Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I j ¡ ßPt Directional Survey i ",-- ¡ ßp( Directional Survey i ED C * l...t-3 12053 I:.IS Vorifi08tion' G (2( fY\((~ ~ LIS Verification ¡ ED C Pdf 12053 Induction/Resistivity ¡ Log Log Run Scale Media No Final Final 1-3 1-3 25 25 25 Blu 25 Blu 1-3 1-3 25 25 25 Blu ¡ ~c" !~/C Pdf ¡ ~' i~ ¡ . !~. I Log 12053 Induction/Resistivity I nd uction/Resistivity I nd uction/Resistivity i -rED C ~{....i.s ¡ / ~ i~' C Pdf I¿c ~ ~I f'/HtJ~ 12054 liS Vcrificetisn LIS Verification 12054 Induction/Resistivity Pdf 12054 Induction/Resistivity I . ~ i I nd uction/Resistivity Current Status 1-01L )¡í ~¿ / '-f fIl~ ~ 3 Apf No. 50-029-23154-06-00 UIC N -- --- --------- Directional su~¿_._ .. - (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH F~¿-~ Received Comments ------- 0 7328 Open 6/18/2003 0 12230 Open 6/18/2003 120 7328 Open 6/16/2003 120 7328 Open 6/16/2003 120 7328 Open 6/16/2003 120 7328 Open 6/16/2003 120 7328 Open 6/16/2003 120 7328 Open 6/16/2003 120 12230 Open 6/16/2003 120 12230 Open 6/16/2003 120 12230 Open 6/16/2003 120 12230 Open 6/16/2003 120 12230 Open 6/16/2003 MWD MWD RWD - Multiple Propagation Resistivity, Gamma Ray - MD RWD - Multiple Propagation Resistivity, Gamma Ray - TVD RWD - Multiple Propagation Resistivity, Gamma Ray - MD RWD - Multiple Propagation Resistivity, Gamma Ray - TVD ./7 0 I tt">/ P., RWD - Multiple () ( Propagation ResistiVity, Gamma Ray - MD RWD - Multiple ,(J fl Y Propagation Resit.... hJ' Gamma Ray - TVD RWD - Multiple f ~ " Propagation Resistlvny I Gamma Ray - MD .~< I _____ ___ _ __,_.J DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030180 Well Name/No. KUPARUK RIV U WSAK 1C-170 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23154-00-00 MD _12230 ~- I TVD 3798 Completion Date 5/27/2003 I nd uction/Resistivity Completion Status 25 Blu 1-OIL 120 Current Status 1-OIL 12230 Open 6/16/2003 UIC N -----.- RWD - Multiple Propagation Resistivity, Gamma Ray - TVD ------ ------ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? f£E::> Chips Received? ~ IN Daily History Received? (L) (3N Formation Tops Analysis Received? .....y / tJ ~-------- - .-- - -- -------- --- Comments: Compliance Reviewed By: ~ Date: f ( J(j(1õ~;- ) ~~'- ( ConocJP'hillips ( Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 7,2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 C-170 (APD # 203-078) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 C-170. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, jJ, }It~ M. Moonèy Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED) JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage , \í" I ",' O D\... : \'.., · ~ ;"--' ~ . ~ ......) Q . '" Abandon Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 28' I AMSL 87' 8. Property Designation: ADL 25638, 25649 / ALK 463 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE LINER Perforation depth: ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing 0 Perforate New Pool D Perforate D Stimulate D Variance D Annular Disp. D Time Extension D D Other D Re-enter Suspended Well 4. Current Well Status: Development 0 Stratigraphic D Exploratory Service D D 5. Permit to Drill Number: 203-078 I 6. API Number: 50-029-23154-00 9. Well Name and Number: 1 C-170 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 12230' feet true vertical 3798' feet measured 7328' feet true vertical 3770' feet Length Size MD 110' 16" 120' 5923' 7-5/8" 6010' 6345' 4-1/2" 12219' Plugs (measured) Junk (measured) TVD Burst Collapse 120' 3763' 3798' Measured depth: pre-perforated liner 9108' - 12185' true vertical depth: 3789' - 3798' RECEIVED JAN 1 3 2004 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5886' MD. Packers & SSSV (type & measured depth) Baker 'ZXP' pkr @ 5885' SSSV= 448' 12. Stimulation or cement squeeze summary: Alaska Oil & Gas Cons. Commission Anchorage Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation 1806 3210 120 395 Subsequent to operation 972 306 57 314 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Dan Venhaus @ 263-4372 ~114; Fd"If~2/2003 JAM 15 . Contact Printed Name Signature Title Phone Wells Group Team leader Date 1//)'2.-10;(1 Prepared bv Sharon AII;(;b-Drake 263-4612 OR'G1NÞ\L~ SUBMIT IN DUPLICATE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( ConocoPhillips Alaska Operations Summary Report 1 C-170 1 C-170 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S Date Sub From - To Hours Code Code Phase 11/13/2003 10:00 - 16:00 6.00 MOVE RURD MOVE 16:00 - 18:00 2.00 MOVE MOVE MOVE 18:00 - 00:00 6.00 MOVE RURD MOVE 11/14/2003 00:00 - 03:00 03:00 - 04:00 04:00 - 09:30 09:30 - 09:45 09:45 - 10:30 10:30 - 12:00 3.00 WELLSR NUND DECOMP 1.00 WELLSR NUND DECOMP 5.50 WELCTL KILL DECOMP 0.25 WELLSR PLGM DECOMP 0.75 WELLSR SFTY DECOMP 1.50 WELCTL NUND DECOMP 12:00 - 16:30 4.50 WELCTL NUND DECOMP 16:30 - 17:30 1.00 WELCTL SFTY DECOMP 17:30 - 18:00 0.50 WELCTL NUND DECOMP 18:00 - 00:00 6.00 WELCTL BOPE DECOMP 11/15/2003 00:00 - 02:00 2.00 WELCTL BOPE DECOMP 02:00 - 03:00 1.00 WELLSR PLGM DECOMP 03:00 - 12:00 9.00 FISH PULL DECOMP 12:00 - 13:30 13:30 - 17:30 17:30 - 18:00 18:00 - 19:30 1.50 FISH PULD DECOMP 4.00 CMPL TN OTHR CMPL TN 0.50 CMPL TN PULD CMPL TN 1.50 CMPL TN RUNT CMPL TN Page 1 of 3 Start: 11/13/2003 Rig Release: 11/17/2003 Rig Number: Spud Date: 5/14/2003 End: 11/17/2003 Group: Description of Operations Rig released from 1 D-129. Prep to move rig. Scope down derrick and layover. Separate modules and move rig oft well. Pick up herculite material and clean up location. Prep to move oft location. Road rig from 1 D to 1 C pad. Position mats around wellhead. Layout herculite around wellhead for carrier sub. Move carrier over well. Mate up pit module and pipe shed. RU lines and power cables between modules. Raise and scope up derrick. Accept rig at 0000 on 11/14/03. Prep to pull BPV. APC hardline crew prep to install HP lines to well. 02:30 Little Red on loc for well kill. Continue to rig up to flow back tanks, w/pt. Bleed gas oft tubing and IA. Begin circulating KWF down tubing while taking returns up the IA. ISIWHP = 700# Dwn hole gauge reading 1,070#. Pumping 5 BPM @ 300#. LA. press = 100#. Pump 175 BBLS dwn tubing swap over to I.A. Pump 300 BBLS dwn IA. 260 BBLS @ 5 BPM 40 BBLS @ 2 BPM 140 DEG. Tubing on vac. IA. on vac. During kill on LA. no returns to surface from tubing. Set BPV in hanger. Pre-Spud meeting with night crew. Discuss HSE issues and workover plan/objectives. Check Baker downhole gauge. 1150 psi/76 deg F. ND Wellhead. Slight gas pressure behind swagelock fitting for Baker I-wire. Tighten up fitting. Secure tree in cellar. Install test dart in hanger for BOP test. Shoot fluid level on annulus. FL @ 1138'. NU mud cross and DSA. MU annular preventer on double gate BOP. NU BOP stack and riser. Pre-Spud meeting with day crew. Discuss HSE issues and workover plan/objectives. Install turnbuckles on BOP and secure. Test BOP and choke equipment to 25013500 psi. Continue BOP test. Pull BPV. Prep to pull tubing. Pull hanger to floor, disconnect downhole gauge. Begin to pull production tubing. Strap pipe while pooh. Tubing is in good shape. Some of the pipe is hard to break out. Periodically take readings on I-wire. Gauge still working. POOH to sliding sleeve assembly. LD sliding sleeve assembly. Remove gauge from gauge carrier. Gauge and I-wire are still functioning properly. These will be re-run. LD gauge carrier assembly. Stand back last stand. BO 3.75" nipple. Pull seal assembly to rig floor and inspect. Top 2 seals have marks on them. Bottom seal is missing an o-ring. Decide to run new seal assembly. Seal assembly has a 5-1/2" New VAM pin x 4-1/2" box. We do not have another XO with these threads. Call for GBR to send someone over to Kuparuk from Deadhorse to buck off the XO and pup. They will MU these items on the new seal assembly. Load contingency tubing in pipe shed and drift. Count all Cannon Clamps. Recovered 189 cross coupling and 8 mid joint Cannon Clamps. Same number as was run in the well. Top oft pits with fresh water and mix 3% KCL. Move corrosion inhibitor tote inside pits to warm up. Service rig. Seal assembly back on location. PU new Baker seal assembly wI V AM x IBT XO and pup in top. RIH with seal assembly. RIH wI 10 stands tubing. Average torque value for 1st 10 stands is Printed: 12/8/2003 11: 12:03 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ConocoPhillipsAlaska Operations Summary Report Page 2 of 3 1 C-170 1 C-170 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S Start: 11/13/2003 Rig Release: 11/17/2003 Rig Number: Spud Date: 5/14/2003 End: 11/17/2003 Group: Date Sub From - To Hours Code Code Phase Description of Operations 11115/2003 18:00 - 19:30 19:30 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 11/16/2003 00:00 - 06:00 06:00 - 10:00 10:00 - 11 :30 11 :30 - 12:45 12:45 - 14:45 14:45 - 17:15 17:15 - 18:15 18:15 - 18:45 18:45 - 00:00 1.50 CMPL TN RUNT CMPL TN 3100 ft-Ibs. Use this for all other make ups. MU 3.75" DB Nipple on top of stand 10. MU stand 11 and run btm joint in hole. 1.50 CMPL TN PULD CMPL TN MU Baker Guardian gauge carrier assembly with pups on both sides. Install gauge and test. MU Baker sliding sleeve assembly with pups on both sides. Sleeve is in closed position. 0.50 CMPL TN PULD CMPL TN MU Camco gaslift mandrel with a 2,500# SOV @ 4,995'. Check BHP with Baker centry gauge. Press = 0 Continue to run completion clamping Sentry gauge control wire with Cannon clamps on all collars. 2.50 CMPL TN RUNT CMPL TN RIH w/4.5" production tubing. Checking BHP every 10 stands. Drifting pipe w/3.853" drift. 6.00 CMPL TN RUNT CMPL TN RIH with 4.5" completion. Drifting pipe up to 500' w/3.853" rabbit. Install GLM #1 @ 2.724'. Install Camco 3.875" D nipple @ 497'. All pipe and jewelry has been drifted. Utilizing Cannon clamps for the Baker Tec-I wire. Starting to have difficulties drifting pipe with the 3.92" rabbit begin steaming pipe to assist the drift. 4.00 CMPL TN RUNT CMPL TN Continue RIH. LD bottom joint from stand #91. Would not drift. MU new joint on top of top joint from stand #91. LD both joints from stand #93. MU 2 new joints. 186 total joints in string. 1.50 CMPL TN SOHO CMPL TN PU 2 joints and RIH to check space out. See seals go into seal bore on weight indicator. Set down with 2.5' in on 2nd joint. POOH with 3 joints. MU 2.11' pup joint in string. MU top joint and RIH. PU landing joint. MU TIW valve and hose. MU Vetco Gray hanger with pup attached. 1.25 CMPL TN CIRC CMPL TN RU to pump corrosion inhibited 3% KCL water. Check downhole gauge pressure - 1060 psi. Pump 40 bbls corrosion inhibited fluid followed by 85 bbls 3% KCL water. Pump fluid with charge pump. Annular preventer open. SD pump. downhole gauge reading 1150 psi indicating some fluid had U-tubed to the tubing. 2.00 CMPL TN SOHO CMPL TN While fluid level is dropping in lA, dress I-wire through tubing hanger. MU swagelock fittings on top and bottom of hanger. Install cross coupling clamp across collar between hanger pup and top joint. Used a total of 167 single channel cross coupling Cannon clamps and 8 mid joint single channel Cannon clamps. Downhole gauge reading 1090 psi. Pump 15 bbls 3% KCL down IA to push corrosion inhibited fluid downhole. After pumping gauge reading 1140 psi. Let fluid swap until downhole gauge reads 1100 psi. Corrosion inhibitor should be at least 400' above sliding sleeve. RIH wI hanger on landing joint and land in wellhead. Downhole gauge reading 1100 psi. RILDS. 1 LDS will not go in. 2.50 CMPL TN SOHO CMPL TN Send Vetco Gray to look for another LDS and tap. Vetco Gray back on location in 30 min. Remove LDS. Starting thread bad in wellhead. Tap thread. Run in new LDS. Clean up rig floor and start prepping for rig move. 1.00 CMPL TN DEQT CMPL TN Line up to pressure test annulus. Downhole gauge reading 1080 psi on the tubing side. Pump 28 bbls 3% KCL water to fill annulus with charge pump. Pressure up with pump to 250 psi. Downhole gauge did not change - 1080 psi. Bleed off pressure to remove any trapped air. Pressure up to 2000 psi. Downhole gauge still reading 1080 psi tubing pressure. Shear out valve sheared open and IA pressure dropped to 0 psi. Downhole gauge jumped to 1110 psi. Did not get a 15 min test. Slickline can test IA after the SOV is replaced with a DV. 0.50 WELLSR PLGM CMPL TN Pull landing joint. Pull isolation sleeve. Run BPV. 5.25 WELCTL NUND CMPL TN ND BOP stack. Break stack into 4 pieces for move to 15' center well Printed: 12/8/2003 11: 12:03 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11/16/2003 18:45 - 00:00 11/17/2003 00:00 - 04:00 04:00 - 05:00 05:00 - 06:00 ( ( ConocoPhillips Alaska Operations Summary Report Page 3013 1 C-170 1 C-170 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S Sub Hours Code Code Phase Start: 11/13/2003 Rig Release: 11/17/2003 Rig Number: Spud Date: 5/14/2003 End: 11/17/2003 Group: Description of Operations 5.25 WELCTL NUND CMPL TN spacing on 1 D pad. 4.00 CMPL TN NUND CMPL TN Finnish breaking dwn BOP. Install ABB Vetco Gray 5M 4 1/16" tree. Pressure test packoff to 5,000#. Pull BPV and install Two way check. Pt Tree to 250# low pressure, 5,000# High pressure, Witnessed by Rock. Check Bottom Hole gauge- Pressure = 1 ,080# Aprox 10# greater than beginning of workover. 1.00 WELLSR FRZP CMPL TN Freeze protect IA and tubing to 2,700'. SIWHP & FinallA pressure = 0 PSI. Thaw out panic line. Continue to prep for rig dwn. 1.00 MOVE RURD DEMOB Release rig at 06:00 Continue rig prep for move to 10-12 Printed: 12/8/2003 11: 12:03 AM TUBING (G-5886, 00:4.500, 10:3.958) BUSHING (5187-5188, 00:6.000) PUMP (5188-5193, 00:3.812) (' ConocoPhillips Alaska, Inc. ~ II II·.··":···:.···:·::· ~¡ ,\ II . . t Ð "8 1C-170 ( KRU PROD 5/27/2003 11/17/2003 12230 ftKB 92 deÇ1 (â1 6950 Bottom TVD 110 110 6010 3763 12219 3798 Wt 62.50 29.70 12.60 1C-170 Well Type: Orig Completion: Last W/O: Ref Loç¡ Date: TD: Max Hole Angle: Angle (â1 TS: deg ~ Angle (â2 TD: 89 deg (â2 12230 Rev Reason: Reset Pump Last Update: 121712003 API: 500292315400 SSSV Type: NIPPLE Annular Fluid: Reference Loç¡: 28' RKB Last Tag: Last Tag Date: Casing Strinq - ALL STRINGS Description CONDUCTOR SURFACE LINER Tubing String - TUBING Size I Top 4.500 0 Peñorations Summary Interval TVD 9108 - 12185 3789 - 3798 Size 16.000 7.625 4.500 Top o o 5874 TVD 3750 Wt 12.60 Grade L-80 Bottom 5886 Grade H-40 L-80 L-80 Thread WELDED BTCM NSCT Thread IBTM Zone Status Ft SPF Date Type Comment WS D 3077 99 5/27/2003 IPERF Pre-Perforated Slotted Liner, 1" holes every other joint Gas LiftMandrelslValves St MD TVD Man Man Type Mfr 2710 2397 CAMCO KBG-2 2 4982 3475 CAMCO KBG-2 Other(pIUgs,eqUJp;;etc¡).-::.JEWEL.RY Depth TVD Type 27 27 HANGER 448 448 NIP 5187 3560 BUSHING 5188 3560 PUMP 5188 3560 SLEEVE-O 5193 3562 BUSHING 5209 3568 Gauge BOT MODEL 925 GAUGE CARRIER Carrier NIP XO PBR V Mfr V Type VOD Latch Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 Description Date Run 11/21/2003 11/21/2003 Vlv Cmnt VETCO GRAY TBG HANGER CAMCO 'D' NIPPLE WINO GO PROFILE BOT PROTECTOR BUSHING RE-DRESSED 3.812" JET PUMP W/DB-6 LOCK set 12/6/2003 BOT CMU SLIDING SLEEVE - OPENED 11/21/2003 5249 5871 5872 3583 3748 3748 CAMCO 'D' NIPPLE WINO GO PROFILE XO BUSHING BAKER SEAL ASSEMBLY Depth TVD Type Description 5874 3748 Liner TIE BAKER TIE BACK SLEEVE BACK XO 5885 3749 Liner BAKER 'ZXP' PACKER W/HRD PROFILE PACKER (5871-5872, 5893 3750 NIP RS NIPPLE 00:5.530) 5896 3751 HANGER BAKER FLEX LOCK HYD. ROT. LINER HANGER 5905 3752 XO CROSSOVER BUSHING HYDRLlL 12185 3798 BUSHING BAKER PACKOFF BUSHING 12217 3798 SHOE LINER (5874-12219, 00:4.500, Wt:12.60) ~~:~J,I " -·1 ...- ==:' !!== ~.'.~ Date Note 5/27/2003 TREE: ABB VetcoGray I HORZT 41/16" 5 M (wlpenetrator wire) TREE CAP CONNECTION: 9" OTIS ID 4.500 3.875 3.970 0.000 3.812 3.970 3.912 SEALS 3.750 3.930 4.760 ID 5.750 4.930 4.880 4.860 3.910 0.000 4.500 ( { Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc~hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 October 8, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-170 and 1 C-170PB1 (APD # 203-078) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-170 and 1 C-170PB 1. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, \~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ECE1VE I,f'l1lg,·C· ~'\.',.'''''...! 1:1'1,' 1"" e Il.. ~ l~ U' Alaska Oil & Gas Co : . !is, Comml'" ·"N' ..... ' " '¡ . fl'" Anchorage .. 'I. n r:¿ , ~, '. -)' 1... \......../, 1 I, ! \,. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMrvh~,310N WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged U Abandoned 0 Suspended U WAG D 20AAC 25.105 20AAC 25.110 1a. Well Status: Oil 0 GINJ D 2. Operator Name: WINJ 0 ConocoPhillips Alaska, Inc. 3. Address: Gas U WDSPl D No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a. location of Well (Governmental Section): Surface: 1414' FNL, 1063' FWL, Sec. 12, T11N, R1OE, UM At Top Productive Horizon: Total Depth: 981' FSL, 1677' FEL, Sec. 2, T11N, R10E, UM 1816' FSL, 2045' FWL, Sec. 35, T12N, R10E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 562068 . y- TPI: x- 559308 y- Total Depth: x- 557697 . y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. 62.5# 29.7# 12.6# 16" 7.625" 4.5" GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 120' Surface 6010' 5873' 12219' 5968824 . 5971196 5977298 . 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): pre-perforated liner from 91081 to 12185' MD 26. Date First Production October 5, 2003 Date of Test Hours Tested 10n/2003 7-1/3 hours Flow Tubing Casing Pressure press. 528 psi 997 27. Test Period --> Calculated 24-Hour Rate -> Zone-4 Zone-4 Zone-4 Other 5. Date Comp., Susp., or Aband.: May 27,2003 . 6. Date Spudded: May 14, 2003 7. Date TD Reached: May 24, 2003 8. KB Elevation (ft): 28' / 87' AMSL 9. Plug Back Depth (MD + TVD): 7328' MD I 3770' TVD 10. Total Depth (MD + TVD): 12230' MD I 3798' TVD 11. Depth where SSSV set: Land Nipple @ 504' 19. Water Depth, if Offshore: N/A feet MSL HOLE SIZE 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 203-078 / 13. API Number: 50-029-23154-00 14. Well Name and Number: 1 C-170 /1 C-170PB1 15. FieldlPool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25638, 25649 17. land Use Permit: ALK 463 20. Thickness of Permafrost: 2666' MD 42" 172 sx ArcticCrete CEMENTING RECORD AMOUNT PUllED '. ~. ,'~~' ,"' ~ i'ß'·····'''· \.- '~, '" ," . . .-....,..-. - " " :,..".. ,~ , - . ,,,. ."... CONTINUEO Ô RRErGT N A L 420 bbls AS III Lite, 56 bbls Class G Neat 9.875" 6.75" pre-perforated liner 24. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 5886' PACKER SET (MD) 5885' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A CHOKE SIZE 31 Oil GRAVITY - API (corr) GAS-Oil RATIO 1932 not available 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". ,.., R E C E ~ \/ E OJ PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) gas lift oil Production for Oll-BBl GAS-MCF 738 1356 Oll-BBl GAS-MCF 2334 4509 CORE DATA ocr 2'~ 7nrn NONE W A TER-BBl 10 W A TER-BBl 33 f~C"~''1~ "ì~ 6 >'Þ~]-: ìr~:\ u ~ ~t Lt. tJ~" Æ\\Qska Œ' & Gas Cons. Commissicm Anchon;lge LP Submit in duplicate ReDNtS BFl Form 10-407 Revised 2/2003 29. ( FORMATION TESTS 28. GEOLOGIC MARKER~ TVD Include and briefly summarize test results. List intelVals tested, and attach detailed supporting data as necessary. It no tests were conducted, state "None" . MD NAME 1 C-170 West Sak D 3753' 5912' 1C-170PB1 TD 3770' 7328' N/A REC' ." rr"·"·" ~' , . Ir- ~ ',~ .l r" :r~". . .' L-ª VrCL\J 16 1~laska Oil Et G C as ons. Commission AlldlOr~~p 30. LIST OF ATTACHMENTS summary of Daily operations, Directional survey 31. I herebY certlly that jþe foregoing is true and correct 10 jþe best 01 my knowledge. Contact: Steve Shultz 263-4620 Printed Na~ ,,"",,~.~as. . Signature \ ~- ~.. \ \ \'\.Å '¡,- . Title: Kuparuk DrillinQ Team Leader PhOQ~ '2.-.l:, I) "-'0 ->0 Date \D la (.0 > Prepared by Sharon Allsup-Drake General: This form is designed for submitting a compiete and correct well completion report and log on all types 01 landS and leases in Alaska. \NSTRUCT\ONS Item 1a: Classification of SeNice wells: Gas injection, water injection. water-Altemating-Gas Injection. salt water dISPosal. water supply lor injection. observation. or Other. Mulllple completion is defined as a well prodUCing lrom more than one pool with production from each pool completely segregated. Each segregafed pool is a completion. Item 4b: TPI (Top of Producing Interval). lIem B: the Kelly Bushing ele,ation in feet abour mean low low water. Use same as relerence 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. lIem 23: If this well is completed for separate production from more than one inteNal (multiple completion), so state in item 1. and in item 23 shoW the producing inteNals lor only the inteNal reported in item 26. (submit a separate lorm for each additional inteNalto 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" . UR\G\NAL Form 10-407 Revised 2/2003 ConocoPhillips Alaska Page 1 of 4 Operations Summary Report Legal Well Name: 1 C-170 Common Well Name: 1 C-170 Spud Date: 5/14/2003 Event Name: ROT - DRILLING Start: 5/14/2003 End: 5/27/2003 Contractor Name: n1334@ppco.com Rig Release: 5/27/2003 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 5/14/2003 00:00 - 02:00 2.00 MOVE MOVE MOVE Move pipe shed and modules down the pad. 02:00 - 03:00 1.00 MOVE MOVE MOVE Lay herculite and matting boards-move sub down the pad. 03:00 - 04:00 1.00 MOVE MOVE MOVE Move sub over well #1C-170 from 1C-19-level and shim same 04:00 - 06:00 2.00 MOVE MOVE MOVE Spot modules and pipe shed-rig up service lines 06:00 - 07:30 1.50 MOVE MOVE MOVE Spot rock washer and tioga heater-berm same. 07:30 - 09:00 1.50 MOVE RURD MOVE Complete rig check list and take on water. (Rig accepted @ 09:00 hrs. 5/14/03) 09:00 - 11 :30 2.50 MOVE RURD RIGUP Nippled up diverter system and mixing spud mud. 11:30-13:15 1.75 MOVE RURD RIGUP Nipple riser and rig floor equipment-load 5" dp in shed-load hwdp in shed-strap same-make up cement lines-contiue mixing spud mud. 13:15 - 15:00 1.75 MOVE RURD RIGUP Pick up 63 joints. 5" dp and stand in derrick 15:00 - 17:00 2.00 MOVE RURD RIGUP Pick up 25 joints of 5" hwdp-jars and 4 jts. hwdp-stand in derrick 17:00 - 18:30 1.50 MOVE OTHR SURFAC BHA #1 pick up motor-bit-xo-2 short nmcsdp-mwd-ubho sub-orient-program mwd. 18:30 - 18:45 0.25 MOVE SFTY SURFAC Test diverter system and accumulator. (Pre spud meeting) (Witness diverter test Waived by John Crisp AOGCC) 18:45 - 19:00 0.25 MOVE OTHR SURFAC Flood conductor and check for leaks 19:00 - 00:00 5.00 DRILL DRLG SURFAC Spud-tag up @ 120'-Drlg from 120' to 444', ART 3.2 hrs RPM:60, SPM:130, PP:1700# 5/15/2003 00:00 - 21 :30 21.50 DRILL DRLG SURFAC Drlg. 97/8" surface hole from 444' to 2747'. (TVD 2414') ART 9.6 AST 5.7 PUW 98k SOW 90k RW 93k TO on 3k off 1.5k SPM 130 PP 1850 GPM 550. 21 :30 - 23:00 1.50 DRILL CIRC SURFAC Circ. & condition @ 80 rpm-550 gpm X 4. Observe well-pump pill-blow down top drive. 23:00 - 00:00 1.00 DRILL TRIP SURFAC POH -hole swabbing-backream out of hole 60 rpm-500 gpm 5/16/2003 00:00 - 01 :00 1.00 DRILL TRIP SURFAC Back ream out of hole to 1080' 124 spm 60 rpm. 01 :00 - 03:00 2.00 DRILL PULD SURFAC POH wI BHA to surface-lay down bit-motor-mwd & pony collars. 03:00 - 04:30 1.50 DRILL PULD SURFAC Make up bha #2-autotrack-mwd-upload mwd-make up bha to 1061'. 04:30 - 06:00 1.50 DRILL TRIP SURFAC RIH to 2650'-hole in good condition. 06:00 - 06:30 0.50 DRILL REAM SURFAC Wash & ream last stand to bottom @ 2747'-check shot survey. 06:30 - 00:00 17.50 DRILL DRLG SURFAC Drlg. 97/8" surface hole from 2747' to 4215'. TVD (3107') PUW 125k SOW 82k RW 100k TO on 6/7k off 7k ART 10.1 hrs. SPM 132 PP 1850. 5/17/2003 00:00 - 00:00 24.00 DRILL DRLG SURFAC Drlg. 97/8" surface hole from 4215' to 5793' (TVD 3737') PUW 131 k SOW 95k RW 11 Ok TO 8/1 Ok on 8k off ART 16.2 hrs. RPM 140 SPM 132 GPM 560 PP 2150# . 5/18/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC Drlg. 97/8" surface hole from 5793' to 6020'. ART 4.8 hrs. PUW 140k SOW 97 RW 111 k TQ on 9k off 8k 06:00 - 06:30 0.50 DRILL OTHR SURFAC Check shot survey & downlink autotrak. 06:30 - 08:00 1.50 DRILL CIRC SURFAC Circ. 20 bbl. hi-vis weighted sweep @ 600 gpm 2500#. 08:00 - 10:00 2.00 DRILL WIPR SURFAC Flow check & poh to 2732'. Hole in good condition. 10:00 - 11 :30 1.50 DRILL WIPR SURFAC Flow check & rih to 6020'. 11 :30 - 14:30 3.00 DRILL CIRC SURFAC Circ. 20 bbl. hi-vis weighted sweep 600 gpm 2500# 140 rpm-observe well. 14:30 - 19:15 4.75 DRILL PULD SURFAC POH laying down 162 jts. 5" dp-rih w/7 stands 5" dp & lay down same. 19:15 - 21:45 2.50 DRILL PULD SURFAC Lay down bha & down load mwd. 21 :45 - 22:00 0.25 DRILL PULD SURFAC Pick up hanger wI landing jt. & dummy run wI hanger. 22:00 - 00:00 2.00 CASE RUNC SURFAC PJSM-Rig up & run 7 5/8" 29.7# L-80 BTCM Csg. 5/19/2003 00:00 - 05:30 5.50 CASE RUNC SURFAC Continue running A total of 140 jt's of 75/8" 29.6# L-80 BTC-M csg wI Shoe set @ 6010' MD 3763' TVD Float collar @ 5920'. Note! Fill each jt wI Franks tool, Circ pipe volume @ 3000'. M/U Vetco 19 1/2" OD X 7.625" hgr and landed 28.23' below rorary table. 05:30 - 09:30 4.00 CASE CIRC SURFAC RId Franks tool. Mlu Dowell cement head. Circuale and condition Hole Printed: 10/6/2003 2:41 :27 PM çqnocoPþillip~ AIFlskfl ·QpËu-atiqns$Lu11rnClryRèport· Legal Well Name: Common Well Name: Eve nt Name: Contractor Name: Rig Name: 1 C-170 1 C-170 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/14/2003 Rig Release: 5/27/2003 Rig Number: Spud Date: 5/14/2003 End: 5/27/2003 Group: Da.te From... To Hours Code ð6Je. 5/19/2003 05:30 - 09:30 4.00 CASE CIRC SURFAC 09:30 - 09:45 0.25 CEMENT SFTY SURFAC 09:45 - 12:00 2.25 CEMENT PUMP SURFAC 5/20/2003 12:00 - 13:00 1.00 CEMENT PUMP SURFAC 13:00 - 14:00 1.00 CEMENT RURD SURFAC 14:00 - 15:00 1.00 CEMENT RURD SURFAC 15:00 - 16:00 1.00 WELCTL NUND SURFAC 16:00 - 17:00 1.00 WELCTL NUND SURFAC 17:00 - 19:00 2.00 WELCTL NUND SURFAC 19:00 - 19:30 0.50 WELCTL NUND SURFAC 19:30 - 22:30 3.00 WELCTL BOPE SURFAC 22:30 - 23:00 0.50 WELCTL EORP SURFAC 23:00 - 23:30 0.50 WELCTL BOPE SURFAC 23:30 - 00:00 0.50 WELCTL BOPE SURFAC 00:00 - 01 :00 1.00 DRILL OTHR SURFAC 01 :00 - 02:00 1.00 DRILL OTHR SURFAC 02:00 - 03:00 1.00 DRILL OTHR SURFAC 03:00 - 12:00 9.00 DRILL PULD SURFAC 12:00 - 12:15 0.25 DRILL CIRC SURFAC 12:15 - 15:00 2.75 DRILL TRIP SURFAC 15:00 - 16:15 1.25 DRILL PULD SURFAC 16:15 - 16:30 0.25 DRILL CIRC SURFAC 16:30 - 17:00 0.50 DRILL TRIP SURFAC 17:00 - 19:00 2.00 DRILL PULD SURFAC 19:00 - 00:00 5.00 DRILL PULD SURFAC 00:00 - 00:30 0.50 CEMENT CI RC SURFAC 00:30 - 01 :00 0.50 CEMENTCIRC SURFAC 01 :00 - 02:00 1.00 CEMENTOTHR SURFAC 02:00 - 04:00 2.00 CEMENT DSHO SURFAC 04:00 - 05:00 1.00 CEMENTCIRC SURFAC 05:00 - 05:30 0.50 CEMENT FIT SURFAC 05:30 - 00:00 18.50 DRILL DRLH PROD 5/21/2003 5/22/2003 00:00 - 03:30 3.50 DRILL DRLH PROD 03:30 - 04:00 0.50 DRILL CIRC PROD 04:00 - 04:30 0.50 DRILL OTHR PROD 04:30 - 09:30 5.00 DRILL DRLH PROD 09:30 - 00:00 14.50 DRILL DRLH PROD 5/23/2003 00:00 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 05:00 0.50 DRILL 2.50 DRILL 1.00 DRILL 1.00 DRILL CIRC PROD REAM PROD CIRC PROD OTHR PROD and mud. Reciporcate pipe 20'. Break circ @ 3 bpm and slowly increase rate up 7 bpm 500 psi. up wt 195k dn wt 90k PJSM with dowell, APC and drilling crew. On cementing and fluid moviment. Pumped 10 bbl CW1 00, test lines to 3500 psi, pump 50 bbl mud push 10.5#, drop btm plug, pump 420 bbI10.7# lead slurry, 56 bbI15.8# tail, drop top plug, 20 bbl water. Swap over to rig. Displace with rig, plug bumped @2497 stks. CIP 1237hrs. Pressure up to 1250 for 5 min, bleed off to check floats, floats held. Rig down cmt equip and landing joint. Flush diverter system. LD csg elev.lbails. ND diverter. Install well head. NU BOPE. Set test plug RU to test BOPE. Test BOP 250 low, 5000 high (Annular 250/3500). C/O btm pipe rams. C/O saver sub. Test lower pipe rams 250 low, 5000 high, 5 min. Remove test plug, install wear ring, RILDS. Change saver sub & pipe handling equipment to 4". Slip & cut 72' drlg. line. Clear floor & prep lo-tads for pick up. RIH picking up 180 jts. 4" dp & position lo-tads on every third jt. Circ. capacity of 4" dp. POH stand back 60 stands la-tad drill pipe. RIH picking up 27 jts. 4" hwdp-swdp. Circ. capacity of hwdp. POH stand back 9 stands push pipe. Make up BHA #3 orient-program mwd & shallow test @ 251'. RIH picking up 174 jts. 4" dp to 5860'. Break circ. & tag collar @ 5920'. CBU 70 spm 1700#. Test 7 5/8" csg. 3000# 30 mins. chart same. Drill collar-cement-shoe & 20' new hole from 6020 to 6040'. Displace well wI 9.2# flo-pro mud. Perform FIT to 12.5# EMW Chart same. Drlg. horizontal hole from6040' to 7190'. TVD 3778'. PUW 108k SOW 73k RW 87k TO 5k on 5k off WOB 2-7k RPM 80 SPM 60 GPM 254 PP 1380. MW 9.2 VIS 62 SPR #2 20 spm @ 450 30 spm @ 610. AST 3.9 ART 7.3 . Drlg. horizontal hole from 7190' to 7328'. (TVD 3770'). Angle to high-drilled into shale. (ART .8 AST 1.9 ADT 2.7) Survey on bottom-circulate. Pump out to 7094'-initialize mwd for sidetrack. Drlg. sidetrack from 7094' to 7328'. Drlg. horizontal hole from 7328' to 9029' TVD 3790'. (ART 9.8 AST 2.0 ADT 11.8) PUW 113k SOW 68k RW 87k TO on 7k off 6k WOB 3nk RPM 85 SPM 70 GPM 297 PP 1800# SPR #1 20 spm 630# 30 spm 780# MW 9.2# Circ.-rotate & reciprocate 70 rpm 1750# Back ream to shoe @ 6010' @ full drlg. rates. Pump sweep surface to surface 70 spm 1400#. Service rig & top drive-Slip & cut drlg. line. Printed: 10/6/2003 2:41 :27 PM ·. CÓhOCoPtl11lipsAlaska Q¡p~rå~iºns..~uml11arY.·6eport.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-170 1 C-170 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/14/2003 Rig Release: 5/27/2003 Rig Number: Spud Date: 5/14/2003 End: 5/27/2003 Group: [)åte FrOm - Tþ Hours· .> COde Sub Cbde 5/23/2003 05:00 - 06:30 1.50 DRILL TRIP PROD 06:30 - 07:00 0.50 DRILL CIRC PROD 07:00 - 00:00 17.00 DRILL DRLH PROD 5/24/2003 00:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 14:00 6.00 DRILL 1.00 DRILL 0.50 DRILL 6.50 DRILL DRLH PROD TRIP PROD TRI P PROD DRLH PROD 14:00 - 15:00 1.00 DRILL CIRC PROD 15:00 - 15:15 0.25 DRILL OBSV PROD 15:15 - 23:00 7.75 DRILL REAM PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 5/25/2003 00:00 - 00:30 0.50 DRILL CIRC PROD 00:30 - 01 :30 1.00 DRILL CIRC PROD 01 :30 - 03:30 2.00 DRILL TRIP PROD 03:30 - 04:30 1.00 DRILL PULD PROD 04:30 - 05:00 0.50 DRILL OTHR PROD 05:00 - 05:30 0.50 DRILL PULD PROD 05:30 - 10:30 5.00 CASE PULR CMPL TN 10:30 - 16:00 5.50 CASE RUNL CMPL TN 16:00 - 16:30 0.50 CASE CIRC CMPL TN 16:30 - 16:45 0.25 CASE OTHR CMPL TN 16:45 - 17:00 0.25 CASE MIT CMPL TN 17:00 - 18:00 1.00 CASE CIRC CMPL TN 18:00 - 00:00 6.00 CASE OTHR CMPL TN 5/26/2003 00:00 - 00:30 0.50 CASE OTHR CMPL TN 00:30 - 01 :00 0.50 CASE OTHR CMPL TN 01 :00 - 07:30 6.50 CASE OTHR CMPL TN 07:30 - 08:00 0.50 CASE OTHR CMPL TN 08:00 - 08:30 0.50 CASE OTHR CMPL TN 08:30 - 22:30 14.00 CMPL TN RUNT CMPL TN 22:30 - 23:30 1.00 CMPLTN CIRC CMPL TN 23:30 - 00:00 0.50 CMPL TN OTHR CMPL TN 5/27/2003 00:00 - 01 :15 1.25 CMPL TN RUNT CMPL TN 01:15-02:15 1.00 CMPL TN RUNT CMPL TN 02:15 - 02:45 0.50 CMPL TN RURD CMPL TN 02:45 - 03:30 0.75 CMPLTN DEOT CMPL TN 03:30 - 05:00 1.50 CMPL TN RURD CMPL TN 05:00 - 06:00 1.00 CMPL TN RURD CMPL TN 06:00 - 06:30 0.50 CMPL TN SEOT CMPL TN 06:30 - 08:00 1.50 CMPL TN FRZP CMPL TN . . . Descriþtion ot Operation~ RIH to bottom @ 9029'. Hole in good condition. Circ.-rotate & reciprocate 70 spm 1700#. Drlg. horizontal hole from 9029' to 10964'. (TVD 3795) ART 8.1 AST .5 ADT 8.6 PUW 122k SOW 58k RW 87k TO on 8k off 8k WOB 3-4k RPM 100 SPM 70 GPM 297 PP 1900# SPR #2 20 spm 620# 30 spm 790# MW 9.2 Vis 58 MBT 1.2 Drlg. horizontal hole from 10964' to 11536'. Back ream out to 10580' to pick up push pipe. RIH wI push pipe to 11536'. Drlg. 6 3/4" horizontal hole from 11536' to 12230' TO. (TVD3798') Mud wt. gas cut to 8.0# while drlg. ART 5.9 AST .7 ADT 6.9 PUW 144k SOW 57k RW 101k TO on 9.7k off 8.8k WOB 3-4k RPM 110 SPM 70 GPM 297 PP 2300# MW 9.2 VIS 60 MBT 1.25. Circ. condition hole for liner. Observe well-drop 1 3/4" hollow drift in dp. Back ream out to shoe @ 6010 @ drlg. rate (SLM) Pump hi-vis sweep-circ. csg. clean-rotate & reciprocate 73 spm 1500#. Continue circ. sweep @ shoe. 72 spm 1500#. Pump & spot 231 bbls. lub pill in csg. & pump pill. Flow check & poh (SLM) No corrections. Lay down BHA collars & jars. Down load mwd. Continue lay down bha-mwd-motor & bit. Rig up to run liner-pick up & make up 100 jts. 4.5" 12.6# L-80 nsct perforated liner & 105 jts. 4.5" 12.6# L-80 nsct solid liner-make up hanger assy. PUW 87k SOW 68k. RIH wI liner on 4" dp & hwdp to 12230'-tag bottom. Drop & pump ball to seat. Set liner hanger wI 1800#-release hr tool wI 3000#. (set liner shoe @ 12219'.) Test liner top to 500# 5 mins. CBU-observe well & pump pill. Lay down 4" dp-hwdp- & 52 lo-tads. Make service breaks & lay down liner running tool. RIH w/2 stands push pipe & lay down same-recovered 3 drifts. RIH wI 60 stands 4" dp & lay down same. Pull wear ring. Lay down bundles of lo-tads & clear floor. PJSM-Rig up tbg. handling equipment & gauge carrier line, pick up & run 186 jts. 4.5" 12.6# L-80 IBT tbg. & acessaries as per program-sting into pbr. PUW 84k SOW 70k Pull out of pbr & displace well wI 400 bbls. 9.2# brine. Lay down 2 jts. 4.5" tbg. Space out (add pups 7.70', 3.67', 3.71') 15.08' total **Note** Pups will be located 1 full jt below hanger. M/U hanger & land tbg - RILDS UD landing jt - Install BPV Pressure test 7.625" X 4.5" annulus to 2500 psi f/15 min "OK" NID BOPs N/U Tree - Test hanger void to 5000 psi f/1 0 min "OK" Pull BPV - Install TWC - Test tree to 5000 psi "OK" - Pull TWC R/U Hot Oil - Shear RP valve @ 3100 psi - Pump 90 bbls diesel freeze protect down annulus - PR 2.25 bpm @ 1200 psi Printed: 10/6/2003 2:41 :27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ··Date Fröm"Tó 1 C-170 1 C-170 ROT - DRILLING n1334@ppco.com Doyon 141 HoUrs Code ¿ouJe Start: 5/14/2003 Rig Release: 5/27/2003 Rig Number: Spud Date: 5/14/2003 End: 5/27/2003 Group: Phåse DesëriþtionofOpt3rations 5/27/2003 08:00 - 09:00 09:00 - 10:00 1.00 CMPL TN FRZP CMPL TN Put Tbg & Annulus in comminucation and let U-tube 1.00 CMPL TN RURD CMPL TN Set BPV - Secure well - 200 psi on Tbg & Ann ** NOTE** Relaese Rig 10:00 AM hrs 5/27/2003 Printed: 10/6/2003 2:41 :27 PM ) ) ConocoPhillips Alaska, Inc. Pad lC 170 slot #170 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD w/IFR <7106-12230'> svy6904 Date printed Date created Last revised 12-Jun-2003 23-May-2003 25-May-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot locat~on is n70 19 31.273,w149 29 48.080 Slot Grid coordinates are N 5968823.698, E 562068.540' Slot local coordinates are 1413.26 S 1063.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhillips Alaska, Inc. Pad 1C,170 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees Azimuth Degrees 0.00 120.00 193.76 287.79 379.56 473.02 563.09 652.28 744.25 834.78 925.12 1015.52 1108.60 1199.91 1293.34 1386.07 1478.95 1571.24 1663.10 1756.00 1850.24 1942.55 2035.16 2128.24 2220.69 2314.37 2406.13 2499.62 2593.19 2685.71 2774.26 2867.86 2960.80 3052.83 3145.92 3239.77 3332.44 3425.36 3518.11 3610.49 3703.09 3796.03 3889.61 3981.15 4075.38 4167.89 4261.01 4353.20 4446.66 4539.10 7.50 7.55 8.93 9.81 10.99 13 .16 16.62 19.98 23.17 26.45 30.59 33.03 36.30 38.94 43.75 47.10 50.57 54.91 59.20 61.42 60.91 61.95 62.87 61.83 61.80 61.85 61.60 61.68 62.18 62.41 62.06 62.11 60.9'7 62.00 61.48 60.98 61. 41 61.07 60.97 61.16 0.00 0.00 0.43 0.75 1. 08 0.00 0.00 104.94 101.70 95.46 True Vert Depth 0.00 120.00 193.76 287.78 379.54 472.98 563.02 652.19 744.03 834.17 923.83 1013.45 1105.57 1195.66 1287.56 1378.23 1467.98 1555.60 1641.01 1725.33 1808.12 1886.57 1962.74 2036.47 2105.86 2171.60 2231.99 2288.58 2339.46 2385.28 2427.99 2472.75 2515.80 2558.51 2602.48 2646.80 2690.72 2734.90 2778.54 2821.50 2864.65 2908.16 2952.76 2996.46 3041. 07 3085.61 3130.48 3174.83 3220.11 3264.84 ) SURVEY LISTING Page 1 Your ref MWD w/IFR <7106-12230'> Last revised : 25-May-2003 R E C TAN G U L A R Dogleg COO R DIN ATE S Deg/100ft O.OON O.OON 0.07S 0.29S 0.49S 0.77S 0.38S 1.51N 6.14N 14.48N 25.49N 37.31N 50.48N 64.94N 81. 43N 100.43N 123.41N 150.68N 181.75N 216.68N 256.00N 297.27N 339.90N 383.34N 427.73N 474.70N 522.27N 572.43N 624.46N 678.27N 731.88N 790.01N 848.62N 907.32N 965.47N 1021. 88N 1073.86N 1118.85N 1159.22N 1197.10N 1230.50N 1261.04N 1291. 95N 1322.56N 1354.46N 1388.27N 1424.94N 1461.79N 1498.75N 1535.35N O.OOE O.OOE 0.27E 1.21E 2.66E 4.78E 6.73E 7.90E 8.38E 8.01E 7.17E 6.56E 4.79E 1.36E 2.14W 6.03W 12.37W 22.13W 35.33W 52.58W 74.44W 100 . 16W 131.04W 167.61W 209.52W 256.90W 306.97W 361.90W 420.69W 480.38W 536.44W 594.56W 652.43W 709.00W 766.87W 827.37W 890.24W 958.43W 1029.62W 1102.09W 11 7 6 . 89W 1253.13W 1329.36W 1403.75W 1480.37W 1554.05W 1626.95W 1698.88W 1771.80W 1843.95W 0.00 0.00 0.58 0.34 0.38 0.00 0.00 -0.13 -0.56 -1.10 Vert Sect G RID Easting COO R D S Northing 5968823.70 5968823.70 5968823.63 5968823.42 5968823.23 5968822.97 5968823.37 5968825.27 5968829.90 5968838.24 5968849.25 5968861.06 5968874.21 5968888.64 5968905.10 5968924.06 5968946.99 5968974.18 5969005.14 5969039.93 5969079.06 5969120.11 5969162.49 5969205.62 5969249.67 5969296.25 5969343.41 5969393.11 5969444.66 5969497.97 5969551.12 5969608.77 5969666.91 5969725.14 5969782.81 5969838.72 5969890.18 5969934.62 5969974.40 5970011.68 5970044.48 5970074.39 5970104.68 5970134.67 5970165.95 5970199.16 5970235.22 5970271.49 5970307.86 5970343.86 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 9535.39 on azimuth 333.18 degrees from wellhead. Vertical section is from wellhead on azimuth 346.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1. 54 1. 21 1. 79 4.06 6.54 98.89 53.04 17.32 0.88 355.38 355.88 358.20 347.39 345.95 349.86 347.25 342.45 338.52 335.65 332.01 329.98 326.27 322.08 317.85 315.56 313.98 313.12 311.71 311. 33 312.71 314.75 315.25 315.48 316.64 313.64 312.35 306.81 300.03 299.08 296.11 292.02 291.63 292.52 292.21 293.00 296.31 297.09 297.17 296.59 297.20 0.50 1. 24 1. 20 2.61 2.79 -1.86 -1.94 -0.37 4.02 12.22 1. 06 0.34 2.22 1. 00 1. 47 23.12 34.76 47.97 62.83 79.68 2.41 3.95 3.88 3.66 3.89 99.06 122.89 151.68 184.98 222.97 4.51 3.39 4.37 3.97 5.45 266.30 312.43 361.08 411.85 464.79 3.77 3.85 4.79 4.60 2.73 521.51 579.44 641.02 705.32 771.56 2.10 1. 21 1. 01 1. 59 2.84 836.77 906.84 977.33 1047.59 1117.63 1. 21 5.27 6.42 1. 05 2.86 1186.60 1251. 79 1311.45 1367.30 1421.02 3.93 0.37 1. 48 1. 16 0.92 1470.95 1518.41 1566.24 1613.34 1662.23 3.18 0.87 0.38 0.55 0.61 1712.29 1764.93 1817.54 1870.48 1922.89 562068.54 562068.54 562068.81 562069.75 562071.20 562073.32 562075.28 562076.43 562076.87 562076.43 562075.51 562074.80 562072.92 562069.37 562065.74 562061.70 562055.17 562045.19 562031.74 562014.21 561992.03 561965.97 561934.76 561897.83 561855.57 561807.81 561757.37 561702.03 561642.83 561582.70 561526.22 561467.64 561409.29 561352.26 561293.92 561232.97 561169.69 561101.14 561029.63 560956.86 560881.80 560805.33 560728.84 560654.22 560577.35 560503.40 560430.22 560358.00 560284.78 560212.35 ) ConocoPhillips Alaska, Inc. Pad 1C,170 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 4631. 52 4724.79 4816.81 4910.21 5002.49 5096.86 5189.59 5282.23 5375.46 5468.24 5558.91 5652.91 5746.05 5840.16 5932.41 5974.26 6089.30 6132.94 6182.69 6236.16 6275.29 6321. 25 6369.07 6412.45 6465.99 6504.46 6563.17 6609.13 6659.34 6694.55 6755.45 6800.17 6851.81 6898.36 6949.63 6993.35 7046.74 7094.00 7106.16 7142.64 7193.56 7238.02 7334.80 7433.61 7530.73 7626.82 7723.13 7820.08 7882.80 7916.47 61.22 61.10 60.94 62.66 64.37 65.84 67.64 69.07 70.12 72.14 74.61 75.32 79.11 81. 81 83.82 84.04 85.17 87.70 89.35 90.25 91.44 90.55 90.83 91.04 90.61 89.88 91.66 89.72 88.06 87.69 88.86 89.91 88.37 87.24 92.35 91.85 89.29 89.03 86.86 86.84 87.73 90.43 90.68 89.54 88.92 88.40 88.22 89.45 90.92 90.77 Azimuth Degrees 296.56 296.29 298.16 302.35 304.28 309.04 312.30 314.56 317.80 321. 56 324.28 326.32 329.58 333.69 336.54 335.88 335.89 338.74 340.58 343.08 343.06 345.31 346.12 345.97 345.56 346.68 347.81 348.07 348.65 348.53 348.43 347.83 345.57 343.85 346.33 347.65 346.54 347.36 347.21 345.97 346.34 346.28 346.54 346.19 346.91 345.86 345.07 344.90 345.01 345.75 True Vert Depth 3309.38 3354.37 3398.95 3443.10 3484.26 3524.00 3560.63 3594.80 3627.31 3657.33 3683.27 3707.66 3728.27 3743.88 3755.41 3759.84 3770.66 3773.37 3774.65 3774.84 3774.26 3773.46 3772.89 3772.18 3771.41 3771.24 3770.45 3769.90 3770.87 3772 .18 3774.01 3774.49 3775.27 3777.05 3777.23 3775.63 3775.10 3775.79 3776.23 3778.24 3780.65 3781.36 3780.42 3780.23 3781. 54 3783.79 3786.63 3788.60 3788.40 3787.90 ) SURVEY LISTING Page 2 Your ref MWD w/IFR <7106-12230'> Last revised : 25-May-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/100ft Sect 1571.96N 1608.32N 1645.15N 1686.63N 1731. 99N 1783.10N 1838.62N 1897.82N 1960.86N 2027.79N 2097.09N 2171.72N 2248.70N 2330.34N 2413.36N 2451.44N 2555.97N 2596.15N 2642.78N 2693.58N 2731.01N 2775.22N 2821.56N 2863.65N 2915.54N 2952.89N 3010.14N 3055.08N 3104.24N 3138.73N 3198.38N 3242.14N 3292.39N 3337.25N 3386.78N 3429.34N 3481.38N 3527.41N 3539.26N 3574.70N 3624.08N 3667.27N 3761. 33N 3857.36N 3951. 80N 4045.17N 4138.35N 4231.97N 4292.54N 4325.11N 1916.18W 1989.34W 2060.92W 2131.98W 2200.99W 2269.62W 2334.21W 2396.73W 2457.22W 2514.00W 2566.36W 2618.04W 2666.21W 2710.27W 2748.78W 2765.56W 2812.36W 2829.15W 2846.43W 2863.11W 2874.50W 2887.02W 2898.82W 2909.28W 2922.45W 2931.67W 2944.63W 2954.24W 2964.36W 2971. 32W 2983.48W 2992.68W 3004.56W 3016.82W 3030.01W 3039.84W 3051.77W 3062.44W 3065.11W 3073.56W 3085.73W 3096.25W 3118.99W 3142.28W 3164.87W 3187.48W 3211. 64W 3236.75W 3253.03W 3261. 53W 0.61 0.28 1. 79 4.36 2.63 1975.33 2027.74 2080.24 2137.14 2197.35 G RID COO R D S Easting Northing 560139.83 560066.38 559994.51 559923.12 559853.75 559784.72 559719.68 559656.69 559595.70 559538.38 559485.46 559433.18 559384.40 559339.67 559300.50 559283.40 559235.77 559218.65 559200.99 559183.91 559172.21 559159.33 559147.16 559136.35 559122.77 559113.24 559099.82 559089.85 559079.32 559072.08 559059.44 559049.89 559037.61 559024.98 559011.39 559001.21 558988.87 558977.82 558975.05 558966.32 558953.75 558942.88 558919.38 558895.30 558871.95 558848.58 558823.67 558797.80 558781.03 558772.27 5970379.88 5970415.64 5970451.88 5970492.77 5970537.58 5970588.12 5970643.11 5970701.79 5970764.33 5970830.79 5970899.66 5970973.86 5971050.43 5971131.71 5971214.40 5971252.34 5971356.48 5971396.51 5971443.00 5971493.65 5971530.99 5971575.09 5971621.32 5971663.33 5971715.10 5971752.37 5971809.51 5971854.37 5971903.44 5971937.87 5971997.41 5972041.09 5972091.23 5972136.00 5972185.41 5972227.89 5972279.82 5972325.76 5972337.59 5972372.95 5972422.23 5972465.32 5972559.19 5972655.01 5972749.26 5972842.43 5972935.41 5973028.81 5973089.24 5973121.74 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 9535.39 on azimuth 333.18 degrees from wellhead. Vertical section is from wellhead on azimuth 346.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 4.83 3.77 2.74 3.45 4.41 2263.04 2332.09 2404.23 2479.63 2557.95 3.96 2.23 5.31 5.17 3.76 2637.55 2722.18 2808.26 2897.92 2987.63 1. 65 0.98 8.72 4.97 4.97 3028.57 3141.13 3184.12 3233.49 3286.78 3.04 5.26 1. 79 0.59 1.11 3325.83 3371.75 3419.56 3462.93 3516.46 3.48 3.59 4.26 3.50 1.10 3554.93 3613.62 3659.56 3709.74 3744.90 1. 93 2.70 5.30 4.42 11.08 3805.74 3850.43 3902.06 3948.55 3999.79 3.23 5.23 1. 81 17.87 3.39 4043.47 4096.85 4144.11 4156.26 4192.68 1. 89 6.07 0.37 1. 21 0.98 4243.54 4287.99 4384.77 4483.58 4580.69 1. 22 0.84 1. 28 2.35 2.24 4676.75 4773.00 4869.89 4932.59 4966.25 ) ') ConocoPhillips Alaskal Inc. SURVEY LISTING Page 3 Pad lC,170 Your ref MWD w/IFR <7106-12230'> Kuparuk River Unit, North Slope, Alaska Last revised : 25-May-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 8014 . 52 91.11 344.87 3786.29 4419.95N 3286.39W 0.96 5064.26 558746.64 5973216.36 8110.25 91.38 344.25 3784.21 45l2.20N 3311.87W 0.71 5159.91 558720.41 5973308.39 8157.69 91.12 344.80 3783.18 4557.91N 3324.53W 1. 28 5207.31 558707.39 5973353.99 8208.24 90.09 344.75 3782.64 4606.68N 3337.80W 2.04 5257.83 558693.72 5973402.65 8256.77 88.92 345.46 3783.06 4653.58N 3350.28W 2.82 5306.35 558680.87 5973449.44 8304.34 88.83 345.48 3783.99 4699.62N 3362.21W 0.19 5353.90 558668.56 5973495.38 8401.69 89.44 345.84 3785.46 4793.92N 3386.32W 0.73 5451. 23 558643.69 5973589.47 8498.61 89.05 344.79 3786.74 4887.67N 3410.88W 1.16 5548.11 558618.36 5973683.01 8595.10 88.92 344.80 3788.45 4980.76N 3436.19W 0.14 5644.55 558592.31 5973775.89 8691.68 88.62 346.35 3790.52 5074.27N 3460.24W 1. 63 5741.09 558567.50 5973869.19 8787.87 89.75 346.32 3791.89 5167.73N 3482.96W 1.18 5837.27 558544.02 5973962.45 8884.88 90.59 345.78 3791.60 5261.88N 3506.35W 1. 03 5934.27 558519.87 5974056.39 8981.29 90.81 345.38 3790.43 5355.24N 3530.35W 0.47 6030.66 558495.11 5974149.55 9078.73 90.86 346.29 3789.01 5449.71N 3554.20W 0.94 6128.08 558470.50 5974243.81 9174.61 90.25 345.99 3788.08 5542.79N 3577.16W 0.71 6223.95 558446.78 5974336.70 9271.63 88.71 347.60 3788.96 5637.24N 3599.32W 2.30 6320.96 558423.85 5974430.95 9368.32 89.05 346.38 3790.85 5731.43N 3621.09W 1. 31 6417.63 558401.33 5974524.95 9466.34 90.83 345.05 3790.95 5826.41N 3645.27W 2.27 6515.63 558376.37 5974619.72 9562.82 90.37 346.95 3789.94 5920.01N 3668.61W 2.03 6612.10 558352.28 5974713.13 9658.60 90.19 348.13 3789.47 6013.54N 3689.27W 1. 25 6707.86 558330.86 5974806.47 9755.45 89.78 347.74 3789.50 6l08.25N 3709.52W 0.58 6804.68 558309.85 5974901.00 9852.05 89.78 347.54 3789.87 6202.61N 3730.19W 0.21 6901. 26 558288.40 5974995.18 9949.44 88.56 348.06 3791.28 6297.78N 3750.77W 1. 36 6998.62 558267.05 5975090.18 10046.17 88.92 346.68 3793.41 6392.15N 3771.92W 1. 47 7095.31 558245.14 5975184.36 10142.42 89.51 347.30 3794.73 6485.92N 3793.58W 0.89 7191.55 558222.72 5975277.94 10239.09 89.54 346.75 3795.53 6580.12N 3815.29W 0.57 7288.21 558200.25 5975371.95 10336.75 90.00 347.10 3795.92 6675.24N 3837.38W 0.59 7385.87 558177.39 5975466.89 10432.96 90.06 346.75 3795.87 6768.96N 3859.15W 0.37 7482.07 558154.87 5975560.41 10529.57 89.88 346.84 3795.92 6863.01N 3881.21W 0.21 7578.68 558132.03 5975654.28 10626.78 89.85 346.37 3796.15 6957.58N 3903.73W 0.48 7675.89 558108.75 5975748.65 10723.03 90.06 347.54 3796.22 7051.34N 3925.46W 1. 24 7772 .14 558086.26 5975842.22 10820.36 90.15 346.15 3796.05 7146.12N 3947.61W 1. 43 7869.46 558063.35 5975936.80 10916.49 90.40 346.01 3795.58 7239.42N 3970.74W 0.30 7965.59 558039.47 5976029.91 11012.80 90.06 345.28 3795.20 7332.72N 3994.61W 0.84 8061. 89 558014.83 5976123.00 11111.17 90.34 344.88 3794.85 7427.78N 4019.94W 0.50 8160.22 557988.74 5976217.84 11203.04 90.43 346.86 3794.24 7516.86N 4042.37W 2.16 8252.08 557965.59 5976306.73 11301.18 90.28 346.50 3793.63 7612.36N 4064.98W 0.40 8350.22 557942.21 5976402.03 11396.80 89.57 345.51 3793.75 7705.14N 4088.10W 1. 27 8445.83 557918.33 5976494.61 11489.22 89.20 346.51 3794.75 7794.81N 4110.44W 1.15 8538.24 557895.26 5976584.09 11536.69 89.17 347.73 3795.42 7841.08N 4121.02W 2.57 8585.70 557884.31 5976630.27 11633.21 90.06 347.38 3796.07 7935.33N 4141.82W 0.99 8682.20 557862.74 5976724.34 11730.51 90.49 346.86 3795.60 8030.18N 4163.51W 0.69 8779.50 557840.29 5976819.00 11827.01 90.43 345.29 3794.83 8123.84N 4186.73W 1. 63 8875.99 557816.31 5976912.45 11923.97 88.70 344.26 3795.56 8217.39N 4212.19W 2.08 8972.90 557790.09 5977005.78 12020.16 89.91 344.32 3796.73 8309.98N 4238.23W 1. 26 9069.00 557763.30 5977098.15 12116.03 89.45 342.00 3797.27 8401.73N 4266.01W 2.47 9164.70 557734.78 5977189.66 12181.50 89.45 341.73 3797.89 8463.94N 4286.38W 0.41 9229.95 557713.90 5977251.70 12230.00 89.45 341.73 3798.36 8509.99N 4301. 59W 0.00 9278.28 557698.33 5977297.63 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 9535.39 on azimuth 333.18 degrees from wellhead. Vertical section is from wellhead on azimuth 346.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. Pad 1C,170 Kuparuk River Unit, North Slope, Alaska NO PROPOSAL ) SURVEY LISTING Page 4 Your ref MWD w/IFR <7106-12230'> Last revised : 25-May-2003 ) ) ConocoPhillips Alaskal Inc. Pad 1C 170PB1 slot #170 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD w/IFR <0-7328'> svy6901 Date printed Date created Last revised 12-Jun-2003 15-May-2003 25-May-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.273,w149 29 48.080 Slot Grid coordinates are N 5968823.698, E 562068.540 Slot local coordinates are 1413.26 S 1063.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhillips Alaska, Inc. Pad lC,170PBl Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 0.00 120.00 193.76 287.79 379.56 473.02 563.09 652.28 744.25 834.78 925.12 1015.52 1108.60 1199.91 1293.34 1386.07 1478.95 1571.24 1663.10 1756.00 1850.24 1942.55 2035.16 2128.24 2220.69 2314.37 2406.13 2499.62 2593.19 2685.71 2774.26 2867.86 2960.80 3052.83 3145.92 3239.77 3332.44 3425.36 3518.11 3610.49 3703.09 3796.03 3889.61 3981.15 4075.38 4167.89 4261.01 4353.20 4446.66 4539.10 7.50 7.55 8.93 9.81 10.99 13.16 16.62 19.98 23.17 26.45 30.59 33.03 36.30 38.94 43.75 47.10 50.57 54.91 59.20 61.42 60.91 61.95 62.87 61.83 61. 80 61.85 61.60 61. 68 62.18 62.41 62.06 62.11 60.97 62.00 61.48 60.98 61.41 61.07 60.97 61.16 Azimuth Degrees 0.00 0.00 0.43 0.75 1. 08 0.00 0.00 104.94 101.70 95.46 True Vert Depth 0.00 120.00 193.76 287.78 379.54 472.98 563.02 652.19 744.03 834.17 923.83 1013.45 1105.57 1195.66 1287.56 1378.23 1467.98 1555.60 1641.01 1725.33 1808.12 1886.57 1962.74 2036.47 2105.86 2171. 60 2231.99 2288.58 2339.46 2385.28 2427.99 2472.75 2515.80 2558.51 2602.48 2646.80 2690.72 2734.90 2778.54 2821. 50 2864.65 2908.16 2952.76 2996.46 3041. 07 3085.61 3130.48 3174.83 3220.11 3264.84 R E C TAN G U L A R COO R 0 I N ATE S O.OON O.OON 0.07S 0.29S 0.495 0.77S 0.38S 1.51N 6.14N 14.48N 25.49N 37.31N 50.48N 64.94N 81. 43N 100.43N 123.41N 150.68N 181.75N 216.68N 256.00N 297.27N 339.90N 383.34N 427.73N 474.70N 522.27N 572.43N 624.46N 678.27N 731. 88N 790.01N 848.62N 907.32N 965 . 47N 1021. 88N 1073.86N 1118.85N 1159.22N 1197.10N 1230.50N 1261.04N 1291.95N 1322.56N 1354.46N 1388.27N 1424.94N 1461.79N 1498.75N 1535.35N O.OOE O.OOE 0.27E 1. 21E 2.66E 4.78E 6.73E 7.90E 8.38E 8.01E 7.17E 6.56E 4.79E 1.36E 2.14W 6.03W 12.37W 22.13W 35.33W 52.58W 74.44W 1 0 0 . 1 6W 131. 04W 167.61W 209.52W 256.90W 306.97W 361.90W 420.69W 480.38W 536.44W 594.56W 652.43W 709.00W 766.87W 827.37W 890.24W 958.43W 1029.62W 1102.09W 11 7 6 . 89W 1253.13W 1329.36W 1403.75W 1480.37W 1554.05W 1626.95W 1698.88W 1771.80W 1843.95W ) SURVEY LISTING Page 1 Your ref MWD w/IFR <0-7328'> Last revised 25-May-2003 Dogleg Deg/lOOft 0.00 0.00 0.58 0.34 0.38 0.00 0.00 -0.13 -0.56 -1.10 Vert Sect G RID Easting COO R 0 S Northing 5968823.70 5968823.70 5968823.63 5968823.42 5968823.23 5968822.97 5968823.37 5968825.27 5968829.90 5968838.24 5968849.25 5968861.06 5968874.21 5968888.64 5968905.10 5968924.06 5968946.99 5968974.18 5969005.14 5969039.93 5969079.06 5969120.11 5969162.49 5969205.62 5969249.67 5969296.25 5969343.41 5969393.11 5969444.66 5969497.97 5969551.12 5969608.77 5969666.91 5969725.14 5969782.81 5969838.72 5969890.18 5969934.62 5969974.40 5970011.68 5970044.48 5970074.39 5970104.68 5970134.67 5970165.95 5970199.16 5970235.22 5970271.49 5970307.86 5970343.86 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 4878.97 on azimuth 320.33 degrees from wellhead. Vertical section is from wellhead on azimuth 346.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1. 54 1. 21 1. 79 4. 06 6.54 98.89 53.04 17.32 0.88 355.38 355.88 358.20 347.39 345.95 349.86 347.25 342.45 338.52 335.65 332.01 329.98 326.27 322.08 317.85 315.56 313.98 313.12 311.71 311 . 33 312.71 314.75 315.25 315.48 316.64 313.64 312.35 306.81 300.03 299.08 296.11 292.02 291.63 292.52 292.21 293.00 296.31 297.09 297.17 296.59 297.20 0.50 1. 24 1. 20 2.61 2.79 -1.86 -1.94 -0.37 4.02 12.22 1. 06 0.34 2.22 1. 00 1. 47 23.12 34.76 47.97 62.83 79.68 2.41 3.95 3.88 3.66 3.89 99.06 122.89 151.68 184.98 222. 97 4.51 3.39 4.37 3.97 5.45 266.30 312.43 361.08 411.85 464.79 3.77 3.85 4.79 4.60 2.73 521.51 579.44 641.02 705.32 771.56 2.10 1. 21 1. 01 1. 59 2.84 836.77 906.84 977.33 1047.59 1117.63 1. 21 5.27 6.42 1. 05 2.86 1186.60 1251.79 1311.45 1367.30 1421.02 3.93 0.37 1. 48 1.16 0.92 1470.95 1518.41 1566.24 1613.34 1662.23 3.18 0.87 0.38 0.55 0.61 1712.29 1764.93 1817.54 1870.48 1922.89 562068.54 562068.54 562068.81 562069.75 562071.20 562073.32 562075.28 562076.43 562076.87 562076.43 562075.51 562074.80 562072.92 562069.37 562065.74 562061.70 562055.17 562045.19 562031.74 562014.21 561992.03 561965.97 561934.76 561897.83 561855.57 561807.81 561757.37 561702.03 561642.83 561582.70 561526.22 561467.64 561409.29 561352.26 561293.92 561232.97 561169.69 561101.14 561029.63 560956.86 560881.80 560805.33 560728.84 560654.22 560577.35 560503.40 560430.22 560358.00 560284.78 560212.35 ) ) ConocoPhillips Alaska, Inc. SURVEY LISTING Page 2 Pad lC,170PBl Your ref MWD w/IFR <0-7328'> Kuparuk River Unit, North Slope, Alaska Last revised : 25-May-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/l00ft Sect Easting Northing 4631. 52 61.22 296.56 3309.38 1571 . 96N 1916.18W 0.61 1975.33 560139.83 5970379.88 4724.79 61.10 296.29 3354.37 1608.32N 1989.34W 0.28 2027.74 560066.38 5970415.64 4816.81 60.94 298.16 3398.95 1645.15N 2060.92W 1. 79 2080.24 559994.51 5970451.88 4910.21 62.66 302.35 3443.10 1686.63N 2131.98W 4.36 2137.14 559923.12 5970492.77 5002.49 64.37 304.28 3484.26 1731.99N 2200.99W 2.63 2197.35 559853.75 5970537.58 5096.86 65.84 309.04 3524.00 1783.10N 2269.62W 4.83 2263.04 559784.72 5970588.12 5189.59 67.64 312.30 3560.63 1838.62N 2334.21W 3.77 2332.09 559719.68 5970643.11 5282.23 69.07 314.56 3594.80 1897.82N 2396.73W 2.74 2404.23 559656.69 5970701.79 5375.46 70.12 317.80 3627.31 1960.86N 2457.22W 3.45 2479.63 559595.70 5970764.33 5468.24 72 .14 321.56 3657.33 2027.79N 2514.00W 4.41 2557.95 559538.38 5970830.79 5558.91 74.61 324.28 3683.27 2097.09N 2566.36W 3.96 2637.55 559485.46 5970899.66 5652.91 75.32 326.32 3707.66 2171.72N 2618.04W 2.23 2722.18 559433.18 5970973.86 5746.05 79.11 329.58 3728.27 2248.70N 2666.21W 5.31 2808.26 559384.40 5971050.43 5840.16 81. 81 333.69 3743.88 2330.34N 2710.27W 5.17 2897.92 559339.67 5971131.71 5932.41 83.82 336.54 3755.41 24l3.36N 2748.78W 3.76 2987.63 559300.50 5971214.40 5974.26 84.04 335.88 3759.84 2451.44N 2765.56W 1. 65 3028.57 559283.40 5971252.34 6089.30 85.17 335.89 3770.66 2555.97N 2812.36W 0.98 3141.13 559235.77 5971356.48 6132.94 87.70 338.74 3773.37 2596.15N 2829.15W 8.72 3184.12 559218.65 5971396.51 6182.69 89.35 340.58 3774.65 2642.78N 2846.43W 4.97 3233.49 559200.99 5971443.00 6236.16 90.25 343.08 3774.84 2693.58N 2863.11W 4.97 3286.78 559183.91 5971493.65 6275.29 91. 44 343.06 3774.26 2731.01N 2874.50W 3.04 3325.83 559172.21 5971530.99 6321.25 90.55 345.31 3773.46 2775.22N 2887.02W 5.26 3371.75 559159.33 5971575.09 6369.07 90.83 346.12 3772.89 2821.56N 2898.82W 1. 79 3419.56 559147.16 5971621.32 6412.45 91.04 345.97 3772 .18 2863.65N 2909.28W 0.59 3462.93 559136.35 5971663.33 6465.99 90.61 345.56 3771.41 2915.54N 2922.45W 1.11 3516.46 559122.77 5971715.10 6504.46 89.88 346.68 3771.24 2952.89N 2931.67W 3.48 3554.93 559113.24 5971752.37 6563.17 91.66 347.81 3770.45 3010.14N 2944.63W 3.59 3613.62 559099.82 5971809.51 6609.13 89.72 348.07 3769.90 3055.08N 2954.24W 4.26 3659.56 559089.85 5971854.37 6659.34 88.06 348.65 3770.87 3104.24N 2964 . 36W 3.50 3709.74 559079.32 5971903.44 6694.55 87.69 348.53 3772.18 3138.73N 2971 . 32W 1.10 3744.90 559072.08 5971937.87 6755.45 88.86 348.43 3774.01 3198.38N 2983.48W 1. 93 3805.74 559059.44 5971997.41 6800.17 89.91 347.83 3774.49 3242.14N 2992.68W 2.70 3850.43 559049.89 5972041.09 6851.81 88.37 345.57 3775.27 3292 . 39N 3004.56W 5.30 3902.06 559037.61 5972091.23 6898.36 87.24 343.85 3777.05 3337.25N 3016.82W 4.42 3948.55 559024.98 5972136.00 6949.63 92.35 346.33 3777.23 3386.78N 3030.01W 11.08 3999.79 559011.39 5972185.41 6993.35 91. 85 347.65 3775.63 3429.34N 3039.84W 3.23 4043.47 559001.21 5972227.89 7046.74 89.29 346.54 3775.10 3481.38N 3051. 77W 5.23 4096.85 558988.87 5972279.82 7095.38 89.02 347.38 3775.82 3528.76N 3062.74W 1. 81 4145.49 558977.51 5972327.10 7143.52 92.55 347.93 3775.16 3575.77N 3073.03W 7.42 4193.61 558966.84 5972374.03 7239.57 92.06 347.30 3771. 30 3669.51N 3093.61W 0.83 4289.56 558945.50 5972467.59 7263.47 90.80 346.00 3770.70 3692.76N 3099.13W 7.57 4313.45 558939.79 5972490.78 7328.00 90.80 346.00 3769.80 3755.36N 3114.74W 0.00 4377.97 558923.67 5972553.26 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 4878.97 on azimuth 320.33 degrees from wellhead. Vertical section is from wellhead on azimuth 346.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. Pad lC,170PBl Kuparuk River Unit, North Slope, Alaska SURVEY LISTING Page 3 Your ref MWD w/IFR <0-7328'> Last revised : 25-May-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 7328.00 3769.80 3755.36N 31l4.74W Projected Data - NO SURVEY Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS V9 D-TOE RVSD 10 557750.000,5977300.000,0.0000 WS V9 D-HEEL RVSD 10 559196.000,5971477.000,2.0000 3823.10 3777.10 8511.95N 2676.82N 4249.89W 2851.15W 17-Feb-2003 17-Feb-2003 ) Transmittal Form ) &03 -û '121 '&1. BAKER HUGHES To: Anchorage GEOScience Center INTEQ AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie 1 Reference: 1 C-170 Contains the following: . h-.. cÞ:./ 1 LDWG Compact Disc )9- (Includes Graphic Image filts) 1 LDWG lister summary \ 000\ 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log f~ .CEIVEO~ JUN 1 6 2003 Alaska au 8. Gaa· Corm. Cmnmf.l.~n Anchofa-g-e LAC Job#: 472460 Date: June 16,2003 Sent By: Glen Horel Received BY~~~~\...i~'- ~ '''''~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -~~~\~\ (~ r···-~---'~---'-"-"-·-_·~-~ l._~~~~~~~_T~~~J .... .'.... . ;';';'~.:~:: ::,:.:;';'.' ~;........ .. ~ .' IlK: .~_ ) ~-f ~-'. ð ~~~ h ~ ~,.Ã,,~ E ~, ln1~ Jìj ~ ..~ ,jL ) ALASKA OIL AND GAS CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit lC-170 ConocoPhillips (Alaska), Inc. Permit No: 203-078 Surface Location: 1413' FNL, 1063' FWL, Sec. 12, TIIN, RI0E, UM Bottomhole Location: 3462' FNL, 2098' FWL, Sec. 35, TI2N, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law froIn other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the COl11mission 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 Comn1ission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sin. cerely, ¡p ~ ~ ðLµQ~'1-J{/L Randy &t1edrich Commissio ner BY ORDER OF THE COMMISSION DATED this+ day of May, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ) l y ConocoPhillips Conoco/Phillips, Inc. Post Office Box 100360 Anchorage, Alaska 99510 April 28, 2003 Ms. Sara Palin Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill: 1 C-170 Surface Location: Target Location: Bottom Hole Location: 1413' FNL, 1063' FWL, Sec 12 T11N, R10E, UM 4017' FNL, 3493' FWL, Sec 2, T11 N, R10E, UM 3462' FNL, 2098' FWL, Sec 35, T12N, R10E, UM Dear Commissioner: Conoco/Phillips Alaska, Inc. hereby applies for a "Permit to Drill" to drill 1 C-170 as a producer well. The well will be drilled and completed using Doyon #141. Please utilize documents on file for this rig. The following logs are to be run on this well: GR/Res. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1 C, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25,070) Sharon Allsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20AAC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Steve Shultz at (907) 263-4620. Sincerely, ~~~- R. Thomas Kuparuk Drilling Superintendent RECE\VED APR 2 8 'L003 Comm\ss\on 0·\ & Gas Cons. A\aska \ ~nchorage ORIG\r~AL ,) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) 1a. Type of Work: Drill0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill U 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1413' FNL, 1063' FWL, Sec. 12, T11N, R1OE, UM Top of Productive Horizon: 4017' FNL, 3493' FWL, Sec. 2, T11 N, R10E, UM Total Depth: 3462' FNL, 2098' FWL, Sec. 35, T12N, R1OE, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562068 16. Deviated wells: Kickoff depth: 350 18. Casing Program Size y- 5968824 ft. Maximum Hole Angle: Specifications Grade Coupling H-40 Weld L -80 BTC-M L-80 NSCT Hole Casing 42" 16" 9.875" 7.625" 6.75" 4.5" Weight 62.5# 29.7# 12.6# 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): Length Size 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 PERMIT TO DRILL 20 AAC 25.005 Äb,\ Exploratory U Development Oil ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1C-170 6. Proposed Depth: 12. Field/Pool(s): MD: 12184' TVD: 3823' Kuparuk River Field 7. Property Designatiq,c.~"ì/I ApL- Þz.~""'T iW J'l Ã'tI!t'25638 j>i1 8. Land Use Permit: ADL 463 9. Acres in Property: 2560 10. KB Elevation Zone- 4 (Height above GL): 87' AMSL feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1600 psig Setting Depth 89.6° Top Bottom Length MD TVD MD TVD 82' 28' 28' 110' 110' 5947' 28' 28' 5975' 3766' 6387' 5825' 3745' 12184' 3823' West Sak Pool 13. Approximate Spud Date: 5/15/2003 14. Distance to Nearest Property: 3462' 15. Distance to Nearest Well within Pool: 1C-174, 18' @ 790' / Max. Surface Pressure: 1250 psig Quantity of Cement c. f. or sacks (including stage data) Pre-Installed 596 sx Class G & 220 sx Class G pre-perforated liner (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD Perforation Depth TVD (ft): Drilling Program ~ Seabed Report 0 Time v. Depth Plot 0 Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature R. Thomas ~ ~ "- 4 \~ \ Permit to Drill 7-03-078 Number: Conditions of approval : TVD Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Steve Shultz 263-4620 Title Kuparuk Drilling Team Leader Phone Date C( r'Z:i (0 'J PreDared bv Sharon Al/suD-Drake Other: 'bSCJ'O ,,<: \. ~'\.Il'-.-\. ~~ \M... ~'CJV~ ~ \- ~ Commission Use Only API Number: ., Permit Approval i 50- DZ'1 .2-?J 1St..( -CJC:y Date: 5/) ô'3 Samples required [ J Yes ~o Mud log ~qUir d Hydrogen sulfide measures 0 Yes ~ No Directional survey required Approved by: fL-,~) ßU<6d'1- L___ --C... Form 10-401 Revised 3/2003 · COMMISSIONER J R"ll t'- r" ~ ~~. j ~ BY ORDER OF THE COMMISSION ~ , II '.~ See cover letter for other requirements l~~IYED APR 2 8 2003 Alaska Oil & Gas Cons. Commission Date AnC,~¡ø7' I 0 J Submit in duplicate Dri.c _.J1d Complete Procedure West Sak Well #lC-170 4 1/2" Producer ''''ell Plan Summary Horizontal Locations Location at Surface 11413' FNL, 1063' FWL, See 12, TllN, Rl0E, UM NGS Coordinates Northings: 5,968.823.8 Eastings: 562,068.40 RKB Elevation Pad Elevation 89.3' AMSL 59.2' AMSL Location at Top of 4309' FNL, 3590' FWL, See 2, TllN, Rl0E, UM Productive Interval (West ~ak "0" ~ancL) NGS Coordinates Measured Depth, RKB: 5875 Northings: 5,971,186 Eastings: 559,295 Total Vertical Depth, RKB: 3755 Total VerticAl Depth, SC;: 3668 . nc:ation :at T:argpt #1 NGS Coordinates Northings: 5,971,477 14017' FNI , 3493' FWI , Sf'C.?, T11N, R10F, UM Measured Depth, RKB: Eastings: 559,196 Total Vertical Depth, RKR: Total Vertical Depth, 55: 6183 3777 3690 Location at Total Depth (T:argpt #7) NGS Coordinates Northings: 5,977,300 Eastings: 557,750 13462' FNL, 2098' FWL, See 35, T12N, Rl0E, UM Measured Depth, RKB: Total Vertical Dppth, RKB: Total Vertical Depth, 55: :1/ 184 38)3 3736 Formation Markers and Directional Waypoints Measured Hole Angle True Vertical True Vertical Formation Tops Depth (RKB Degrees Depth (RKB feet) Depth (55 feet) fppt) noyon #141 RKB 0 0 0 -89 KOP 350 0 350 )63 Rase Permafrost 1,839 33 1,786 1,699 Top K-15 ) ,550 60 ) ,)73 ) ,186 Top UQnu C 4,313 60 3,158 3,071 Top Ugnu R 4,864 6) 3,433 3,346 K13 5,383 71 3,64) 3,555 Top of the West Sak 5,875 82 3,755 3,668 7 5/8" Casing pt, 5,975 85 3,766 3,679 1 st West Sak Tarqet (heel) 6,183 90 3,777 3,690 2nd West Sak Tarqet, Well TD (toe) 12,184 90 3,823 3,736 JR:J:; ßL ,\ PHilliPS. .Jaska, Inc. A Subsidiary of PHILLlPSPETROLEUM COMPANY '). Drill and Complete Procedure West Sak Well #1C-170 Horizontal Producer Casing/Tubing Program Hole 1 Casing Csg/Tbg ~i,.p 00 Wt/Ft C::radp 97/8" OH 7 5/8" 29.7# L-80 6 314" OH 4-1/7" 17.6# 1-80 Top Btm Conn. ~ pngth MQ/TVO MQ/TVO BTCM 5,947' Su rface 5,975' / 3,766' NSCT 6,387' 5,875'/3,745' 17 ,184' / 3,873' Tubular Dimensions and Strengths OD Wt Conn. Cplg OD ID Drift Collapse Burst Tensile Yield (in) ( ppt) Grade Type (inches) (inches) (inches) (psi) (psi) (kips) 4-1/2" 12.6 L-80 NSCT 5.00 4.000 3.875 6,350 7,780 267 Logging/Formation Evaluation Program Open Hole 9 7/8" Open Hole 6 3/4" MWD/Directional LWD ( GR / RES) MWD/Directional LWD ( GR / RES) Mud Program Spud to Base of Base of Permafros to From Surface Shoe to Pprm¡lfrost Tot;ll np.pth of ,t;lIrf;lCP Tot;ll f}p.pth of WP/l Initial Value Final Value Initial Value Final Value Horizontal Interval Opnsity (.....,g) 8.5 9.7 9.7 9.7 9.7 Funnel Viscosity 150-200 150-200 150 75 45-60 (spconcls) Yield Point (cP) 30-60 30-60 20-40 15-30 18-26 Plastic Viscostiy 8-15 11-22 15- 30 15- 30 5-11 (111/:100 sf) 10 second Gel 10-30 10-25 10-25 10-25 4-7 Strength (lb/100 sf) 10 minute Gel 25-55 25-55 20-40 20-40 6-14 Strength (lb/100 ~f) pH 8-9 8-9 8-9 8-9 8.5-9.7 API Filtr::ltp (cc) 8-15 <8 <8 <8 <6 MRT <70 <70 <70 <70 <5 ~Iicls (0/0) 5-8 5-8 5-8 6-11 3-8 Steve Sh u Itz . J tn·· - ~ "1\ ~ L 1i ,~ ~.~ ~ I . i~" Page 2 of 5 ., PHilliPS. }aska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY '} Drill and Complete Procedure West Sak Well #lC-170 Horizontal Producer Bit Program Hole Size Type Model Jets Depths Flow A V's DP AV's DC's Maximum Section Feet Rate Feet/Min Feet/Min Revs GPM Surface 9 7/8" Smith FGXI 14,14,14,12C 0-5975' 600- 180 282 600K 700 Horizontal 6 314" Secu rity MDT52 16,16,16 5,975'- 250- 250 320 NA Production 12,184' 300 Cementing Program Holp. Catp.gory Surface Casing ~i.7pJOp.pth 7 5/8"/5975'MD Volump. 40 bbls 50 bbls 454 bbls (596.0 sks) 46 bbls (220 sks) Typp. of Cp.mp.nt CW pre-flush Mud pllsh XI I F'éld Slurry (AS I ite) Class "G" Cement 50% D124 Extender 3.5% D44 Accelerator 0.4% D46 Antifoam 30% D53 Thixotrop 1.5% D79 Extender 1. 5% S 1 Accelerator Tail Slurry Class "G" Cement 0.45% D65 Dispersant 0.3% M117 2.0 gps D600G 0.1% D135 0.1% D135 0.2% D47 3.0% D174 Propp.rtip.~ Density 8.4 ppg Density 10.2 ppg Density 10.7 ppg Yield 4.28 fe/sk 350% excess in permafrost 35% excess from bottom of permafrost to 4975' Density 15.80 ppg Yield 1.17 ft3/ sk 20% excess from 4975' to 5975' Well Objectives and Area History This AFC provides funds to drill, case and complete an producing well through the D Sand This well is to be a horizontal producer and as such will be drilled in the "D" sand with minimal directional changes as possible. The majority of the directional work will take place in the surface hole with several turns, builds and tangent sections prior to reaching casing point for the 7 5/8" casing. The horizontal section will drop about 46 feet structurally from heel to toe but additional directional work should be minimal. The total horizontal length will be approximately 6,300' heading east and down dip in the "D" sand. Two mine¡¡- ~r~t~~sn~hrst faults (10' throws) may intersect the Steve Shultz .., . ÎJ ~ ~ ~ :J ... J " , ~ Page 3 of 5 PHilliPS. Jaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY ), Drill and Complete Procedure West Sak Well #lC-170 Horizontal Producer southern third of the well path. Distinct fault cuts are not observed, but a graben-like flexure occurs near the landing. At it's deepest point, the base of the "D" sand appears to be over 75 feet above the locally interpreted "D" Sand oil-water-contact (3845 sstvd) Reservoir Pressure and Well Control The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 PPQ EMW (equivalent mud weight). Since lC-170 is to be drilled into the same fault block as lC-174 (just recently drilled), bottom hole pressures have been taken from 170 with an estimated 1600 psi at 3500' TVD. This requires a minimum of 8.8 ppg mud to drill this well and with a 75 psi safety margin the total mud weight will be +/- 9.2 ppg. There shouldn't be a risk of over pressure. The maximum anticipated surface pressure would be 1250 psi assuming a gas gradient of .1 psi/ft. The surface hole will be drilled to TD with a 21-1/4" annular preventer and a 21-1/4" diverter spool with 16" side outlet and diverter line nippled up. After casing is run, the diverter will be nippled down and a 13-5/8", 5000 psi three ram BOP stack will be nippled up and tested to drill the production interval. Previous West Sak wells and current Kuparuk wells penetrate the West Sak sands using only a diverter, without problems. There is, however, a remote chance that the well could flow during drilling and that it will be necessary to divert flow. Unexpected flow could result from gas hydrates or from higher-than-expected formation pressures. These risks, and the mitigation and response plans are detailed in the Attachment "lC-170 Detail Risk Information". Prior to spud this information should be reviewed at a safety meeting with all involved hands. Additionally, the appropriate diverter drills should be held by each of the crews. Close Crossing and Offset Well Interception Risks Positional uncertainty calculations were performed on the proposed lC-170 wellbore using worst case 3D elliptical error models. Based on these calculations the following close approaches (existing wells having center lines which may lie less than 100 feet from the centerline of the proposed well bore) are anticipated. For more information see attached Baker Inteq Directional Plan. lC-17 lC-76 lC-174 lC-18 lC-?7 Close Crossing DeDth - MD 1746 1070 790 683 1300 Center to Center Separation at Close Crossing Depth Existing Well Name 47 8? 18 84 38 *AII of these wells have passed the "Major Risk" criteria for close approach issues with the exception of lC-174 and 1(-17. lC-174 passes minor risk and at present has not been placed on injection. 1(-17 has been risked based at 1- 200 and passed. As an added precaution a plug will be set in 1(-17 and the tubing beld down prior to the spudding of 1(-170 Waste Drilling Fluids Disposal Incidental fluids generated from drilling operations may be hauled to the nearest permitted disposal well or may be pumped down the surface / production casing annulus of a permitted, existing well on Drill Site- HCA request to the AOGCC will be made that lC-19 be approved for annular injection. Cement rinse water is not to be injected down the dedicated disposal well but should be recycled or held for an open annulus. Any annuli used should be left with a non-freezing fluid during any extended shut down (in excess of four hours) of pumping operations. The West Sak 1(- 170 surface casing by production tubing annulus should be filled with diesel and/or non-freezing brine after setting Steve Shultz ) H ¡ C 1/ " J L Page 4 of 5 '\ PHilliPS, .laska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY '\ Drill and Complete Procedure West Sak Well #lC-170 Horizontal Producer the 4-1/2" tubing string and prior to the drilling rig moving off of the well. Possible Class II disposal wells are 1R-18 and 3R-11. All fluids hauled from lC-170 will be properly documented and manifested. Procedure for lC-170 1. MIRU Doyon #141 .Q~. ~('-;> ~ 2. NU..æPË and test '\)\~(t~'.' (,A"J... 3. MU 9.785" bit and 6 3/4" BHA, drill surface hole to 5,975'MD/3,7661VD. 4. CBU and POOH .. <..~I 5. RU and run 7 5/8" casing to TD, cement in plac;..... Ñ ~ \ba\? c ~ ~...,. \- ~ r.;;[- 6. MU 6 3/4" bit with 4 3/4" BHA, RIH to float collar 7. Drill out float and shoe, then 20 feet of new hole, perform FIT, change hole over to MI flo-pro 8. Drill 6 3/4" lateral to +/-12,184'MD/38231VD, CBU, POOH 9. RU and run 4V2" pre-perforated liner to TO 10. Set hanger and liner top packer, release, POOH 11. RU and run 4 112" jet pump completion 12. NO BOPE, release rig 13. RDMO Doyon #141 Steve Shultz J 1 f.'. .l'. ì r. ." .' ..-1..... I . . \ \ . I' Ii ~~I ø 4,i ./', ; r):!IS Page 5 of 5 \\ J '~ 1 C-170 Detailed Risk Information Broach of Conductor: There is a chance that the conductor on 1 C-170 may broach. Therefore the cellar area should be continuously monitored during the drilling of the surface hole section. If broaching occurs, stop drilling immediately~ Contact the AOGCC field inspector, the drilling Engineer, and the Phillips Drilling Team Leader and infonn them of the broach. We have taken the added precaution of setting the conductor at 120' on this well rather then 80' that has been standard in the past. Therefore, the added depth should help to preclude any broaching of the conductor. Gas Hydrates: The shallow gas phenomenon referred to as gas hydrates have been encountered on wells drilled from 1 C pad. Gas hydrates are fonned over time as gas from deeper source rock migrates to shallower depths. As the migrating gas entered the pennafrost zone, the gas became entrained in water crystals and freezes in place over time. During drilling operations, the warm fluid from surface circulating systems increases the temperature in the near-well bore area, thus thawing the entraining water crystals and releasing the entrained gas into the well bore, often in significant quantities. When gas hydrates are encountered, large volumes of intennittent gas expand near the surface, resulting in large bubbles of escaping gas. These bubbles may push fluid over the bell nipple. The gas may continue to expand and escape the well bore until either the thaw "bulb" is extensive enough that no further thawing takes place or surface casing is run and cemented. The following steps have been shown to be successful in minimizing (though not necessarily eliminating) the effects of gas hydrates upon drilling operations: 1. Control Drilling. This will limit the amount of cuttings into the well bore and assist in reducing the size of the instantaneous gas breakout. 2. Reduced Pump Rates. Slower pump rates may assist in reducing the amount of hydrate entrained cuttings brought to surface in "slugs" and thereby reduce the instantaneous effects of hydrate gas breakout. Reduced pump rates should always coincide with reduced ROP's in order to avoid overloading the well bore with cuttings and increasing the risk of stuck pipe. 3. Reduced Drilling Fluid Temperature. Keeping the temperature as low as possible will reduce the rate of thaw of the hydrates. The most effective way to reduce the temperature is to insure all fluid and make-up water additions are as cold as possible. 4. Additions ofDrilTreat. Experience in other hydrate prone areas of the North Slope indicates DrilTreat (lecithin) may provide hydrate breakout inhibition. Should hydrates be encountered the mud system should be treated with DrilTreat. \~ ) 5. Kelly Down Circulation. Circulating every Kelly down for 3-5 minutes prior to making the next connection will aid in hoe cleaning and reducing cutting/hydrate load in the wellbore. 6. Reduced Fluid Viscosity. Although this practice has shown to be beneficial in other hydrate-prone areas, the decision to reduce viscosity must with consideration given to the benefits of higher viscosity, such as additional hole cleaning, especially where shallow sand and gravel problems may be encountered. Typical viscosity reductions are in the 50-90 sec./qt. range to realize benefits but may not be advisable if sand/gravel problems are encountered. Runnine: Sand and Gravels: Running sands and gravels have been an historical problem in wells drilled on several pads in the GSA. These running intervals may result in substantial circulating and hole cleaning time and cost, as well as substantial risk of stuck drill pipe and lor casing. The following guidelines are recommended for drilling these intervals: 1. Maintain the fluid viscosity at the minimum values specified in the Detailed Mud Program. Be prepared to raise the viscosity to higher values if problems persist. Do not let the viscosity fall below specified values. 2. If running sand and gravel problems persist, pump intennittent densified sweeps, of 40-60 bbls in size while in the build or vertical section of the hole. Density of the sweeps should be 2-5 ppg above existing system weight. Viscosify these sweeps with addition of gel and Barofibre. 3. To maximize hole cleaning, rotate the drill string at the maximum rate while sweeping the hole. 4. Increase the mud weight to the maximum recommended weight to assist in holding sand/gravel back. Wellbore Washout: A number of wells in the lCllD area have experienced significant hole erosion and washout in the surface interval as evidenced by the high excess cement volumes pumped and subsequent low return volume. Because optimized Jet Impact Force is not necessary for maximum ROP in the surface interval, larger nozzles will not adversely affect ROP yet at the same time will allow for significantly increased flow rates and improved hole cleaning. Reservoir Overpressurization Contine:encies: It is possible, though highly unlikely, that higher that predicted reservoir pressures might be encountered during the drilling of lC-170. The consequences such an encounter could be extremely serious. Therefore, the following guidelines have been established. Any deviations from the guideline should be discussed with Drilling Team Leader, Engineering Supervisor or Operation Drilling Engineer before hand. 'Ii · Hold a Pre-spud meeting with all crews including Drillsite Operators and Simultaneous Operations Coordinator. a. Discuss diverter line orientation. b. Identify essential/non-essential personnel (Co-man, Tool Pusher, driller, Derrick Hand, Pit Watcher, Mud Engineer) c. Establish roles and responsibilities of essential personnel while on diverter. d. Review muster areas. · Conduct a pre-reservoir meeting a. Review essential/non-essential personnel b. Review roles and responsibilities of essential personnel while on diverter. c. Review muster areas. d. Conduct a Diverter Actuation Drill prior to penetrating the D-Sand · After penetrating each sand (maximum 5' penetration) and before drilling ahead: a. Shut down and check for flow (monitor well a minimum of 10 minutes before drilling ahead). · Ensure adequate stock of LCM materials on location to address possible losses while pumping higher weight mud if required. · If well flows while circulating at maximum rate, increase mud weight as required while continuing to circulate at maximum rate. · If unable to control well. a. Put well on diverter. b. Evacuate all non-essential personnel to predetermined muster areas. c. Continue to circulate fluid, at maximum rate, while attempting to increase mud weight d. If all available mud has been pumped and well is still out of control, begin pumping water until other kill methods con be employed. Prior to penetrating the reservoir, alert the APC dispatch office and insure that they are aware that all vacuum trucks may be place in water hauling service if need be. As a last resort, use injection water header on pad as water source. Ensure beforehand that hoses, piping and valves are available for rapid rig up to the water injection header, that an available tie-in spot is available, and that the pad operator is aware of the situation. Note: The Company man should review the Drilling Emergency Response Plan prior to penetrating the reservoir (print a copy of the manual and have it on hand should the need arise). The Emergency Response Plan is on the Web and can be located by logging onto the PAl Home Page and following the steps listed below: Kuparuk / PAl Drilling / Safety / Emergency Response / PAl Drilling Emergency Response Plan / Emergency Management Plan Manual. ') '} Hole Swabbin2: Hole swabbing may occur while tripping out of the well bore. Mud parameters should be carefully monitored and maintained per the mud plan during drilling operation to prevent bit balling as well as other factors that may contribute to swabbing. Hole fill volumes should be carefully calculated and monitored, and if there is any concerns whatsoever that the hole has not taken sufficient fluid, the drill string should be tripped back to bottom and circulated. If need be, the string should be circulated out of the hole. All tripping practices should confonn to the Phillips Alaska Drilling Policy. Stuck Pipe: Due to the long length of the lateral in the D sand, there is a risk that the drill string or liner may become differentially stuck. This risk will be minimized by maintaining the mud parameters as planned, using the down hole annular pressure tool to monitor the bottom hole pressure and comparing it to the reservoir pressure, good hole cleaning practices (flow rate and rotation), continual pipe movement, and close monitoring of the fluid weight. In the event that tight hole is observed and backreaming is opted for, the drill string should be ran back in to a depth where working and rotating the pipe is free and clear if possible. Upon commencing backreaming, the flowrate and RPM should be at the same rates as when the hole was originally drilled. Keeping the RPM and circulation at a very low rate while backreaming will only build a cuttings bed above the bit and eventually could lead to stuck pipe. Created by bmlchael For: S Shultz Dote plotted: 22.-Apr-2DD3 Plot Reference is 1C-17D Version '1. Coordinates are in feet reference slot '170. True Vertical Depths are roference Est. RKB~87'. - !!!.L-W!!!!! ~ õN,EO ) ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 170 Field: Kuparuk River Unit Location: North Slope, Alaska <- West (feet) 5400 4950 4500 4050 3600 3150 2700 2250 Liner TO LOCATION: 1818' FSL, 2099' FWL SEC. 35, T12N, R10E 1800 '> .../ ConocoPhi II ips 1350 900 450 313.19 AZIMUTH 3911! (TO TARGET) ***Plane of Proposal*** , <f TRUE TARGET LOCATION: 1263' FSL, 1787' FEL SEC. 2, T11N. R10E Top Ugnu C Top 1Jgnu B Begin Final Bld/Trn Top Ugnu C .eSt¡ '<0 4.~ ESTIMATED SURFACE LOCATION: 1413' FNL, 1062' FWL SEC. 12, T11 N, R10E ,. R~)· /"'1 .~ ~ ~ l¡L:1'ði ,;j f i 't!.Æ Begin Turn Õ'''' -I? « EOC '2' Tap K-15 Top T-3 Base Permafrost Build/Turn 4/100 N Build/Turn :5/100 <: KOP t\l o 450 - 8550 -8100 - 7650 - 7200 - 6750 - 6300 - 5850 - 5400 - 4950 ^ I - 4500 Z 0 ::¡. ::r - 4050 --- -to, CD CD - 3600 -+- '---"" - 3150 - 2700 - 2250 - 1800 -1350 - 900 - 450 - 0 /,...-....- r~-., 800 - ,.-.... +- Q) Q) 1200 - - --- .£ +- 1600 - c.. Q) 0 0 2000 - () :¡:: I- Q) 2400 - > Q) :J 2800 - l- t- I V 3200 - 3600 - 4000 - 4400 ConocoPhillips Alaska, Inc. ~ ConocoPhillips Created by bmichael For: S Shultz Dote plotted : 22-Apr-2003 Plot Reference is lC-170 VersÎon /11. Coordinates ore in feet reference slot #170. True Verticol Depths ore reference Est. RKB=BT. ...... --- INTEQ Structure : Pad 1 C Well : 170 Field : Kuparuk River Unit Location: North Slope, Alaska o - I Estimated RKB Elev: 87' 400 - --~ øc:~t_ KOP .. 2.00 .. 4.00 ,,6.00 DLS: 2.00 deg per 100 ft " 8.00 Build/Turn 3/100 12.43 15.06 DLS: 3.00 deg per 100 ft 1 ~å~il Build/Turn 4/100 24.09 27.62 DLS: 4.00 deg per 100 ft 31.26 Base Permafrost 34.97 42.53 Top T-3 50.20 57.94 Top K-15 EOC .~-cooo 313.19 AZIMUTH 3911' (TO TARGET) ***Plane of Proposal*** (-~~J ..:-;~!~ a::: C) Begin Turn 59.71 59.76 EOC DLS: 4.00 deg per 100 ft TANGENT ANGLE 59.92 DEG <;) / ~oc, 1<.. cP'f-o::il'o, ~ '\ <} ~e<;;' G y..e,e <;¡\'ò ~9J ~s . Top Ugnu C Begin Final Bld/Trn Top Ugnu B Top Ugnu C K13 ,\oç,,\ q TD - 4 1/2 Liner ~ TARGET ANGLE 89.56 DEG o 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 Vertical Section (feet) -> Azimuth 313.19 with reference 0.00 N, 0.00 E from slot #170 400 BOO ) ConocoPhillips Alaska, Inc. Pad 1C,170 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1477.95 1500.00 1600.00 1700.00 1800.00 1839.46 1900.00 2000.00 2099.76 2100.00 2200.00 2300.00 2400.00 2500.00 2549.58 2550.96 3000.00 3202.00 3300.00 3400.00 3500.00 3565.12 4000.00 4313.26 4500.00 4758.48 4800.00 4864.44 4900.00 4956.95 5000.00 5100.00 5200.00 5300.00 5382.98 5400.00 5500.00 5600.00 5700.00 6.00 8.00 10.00 12.43 15.06 17.81 20.00 20.71 24.09 27.62 31. 26 32.71 34.97 38.73 42.52 42.53 46.35 50.20 54.06 57.94 59.87 59.92 59.92 59.92 59.71 59.65 59.76 59.92 59.92 59.92 59.92 59.92 60.54 61.54 62.12 63.08 63.83 65.65 67.56 69.57 71.29 71.65 73.80 76.00 78.26 0.00 0.00 0.00 2.00 4.00 2.00 2.00 2.00 352.88 346.80 342.53 340.00 338.51 332.85 328.54 325.15 324.00 322.40 320.13 318.21 318.20 316.53 315.07 313.76 312.57 312.02 312.00 312.00 312.00 307.47 302.84 298.21 295.20 295.20 295.20 295.20 295.20 296.97 299.69 301.16 303.49 305.22 309.16 312.99 316.71 319.72 320.33 323.86 327.32 330.71 2.00 2.00 2.00 2.00 2.00 0.00 500.00 600.00 699.98 799.84 . \, } PROPOSAL LISTING Page 1 Your ref 1C-170 Version #1 Last revised : 22-Apr-2003 R E C TAN G U L A R COO R DIN ATE S Dogleg Vert Deg/100ft Sect 0.00 N 0.00 N 0.00 N 1.74 N 6.97 N 15.68 N 27.86 N 43.50 N 62.86 N 86.19 N 113.43 N 137.33 N 144.51 N 179.13 N 217.08 N 258.16 N 275.19 N 302.18 N 348.91 N 398.01 N 398.13 N 449.60 N 503.08 N 558.29 N 614.98 N 643.55 N 644.34 N 904.34 N 1021.31 N 1075.44 N 1125.12 N 1168.95 N 1194.25 N 1354.46 N 1469.87 N 1538.67 N 1633.90 N 1649.75 N 1676.51 N 1692.38 N 1719.42 N 1741.15 N 1795.82 N 1856.12 N 1921.76 N 1980.06 N 1992.42 N 2067.76 N 2147.40 N 2230.97 N 0.00 E 0.00 E 0.00 E 0.06 E 0.24 E 0.55 E 0.97 E 1.52 E 0.49 E 3.81 W 11. 37 W 19.51 W 22.23 W 38.02 W 59.44 W 86.38 W 98.50 W 118.70 W 156.25 W 198.73 W 198.84 W 246.28 W 298.32 W 354.71 W 415.19 W 446.59 W 447.48 W 736.24 W 866.14 W 931. 25 W 1001. 80 W 1076.15 W 1126.44 W 1466.93 W 1712.19 W 1858.40 W 2060.78 W 2093.14 W 2142.76 W 2169.79 W 2212.51 W 2244.30 W 2316.31 W 2385.46 W 2451.42 W 2503.51 W 2513.87 W 2572.51 W 2627.04 W 2677.21 W 0.00 0.00 0.00 2.00 2.00 0.00 0.00 0.00 KOP 1.15 4.60 899.45 998.70 1097.47 1195.56 1292.69 1388.60 1462.34 1483.01 1575.46 1665.45 1752.53 1786.00 1836.28 1916.29 1992.00 1992.18 2063.57 2130.11 2191.48 2247.39 2273.00 2273.69 2498.75 2600.00 2649.29 2699.80 2750.26 2782.99 3000.98 3158.00 3251.61 3381.17 3401.79 3433.00 3449.79 3476.00 3495.24 3537.93 3577.65 3614.20 3642.00 3647.41 3677.11 3703.17 3725.45 2.00 2.00 2.00 3.00 3.00 10.34 18.36 28.66 Build/Turn 3/100 42.67 61.77 3.00 3.00 4.00 4.00 4.00 85.93 108.22 Build/Turn 4/100 115.12 150.33 191. 92 4.00 4.00 4.00 4.00 4.00 239.68 260.17 Base Permafrost 293.37 352.73 417.31 Top T-3 4.00 4.00 4.00 4.00 4.00 417.47 487.29 561.83 640.74 723.62 4.00 4.00 0.00 0.00 4.00 766.07 Top K-15 767.27 EOC 1155.75 1330.51 Begin Turn 1415.03 4.00 4.00 4.00 0.00 0.00 1500.47 1584.67 1638.65 EOC 1996.54 2254.34 Top Ugnu C 0.00 0.00 4.00 4.00 4.00 2408.03 2620.75 Begin Final Bld/Trn 2655.19 2709.68 Top Ugnu B 2740.25 4.00 4.00 4.00 4.00 4.00 2789.90 Top Ugnu C 2827.95 2917.87 3009.56 3102.58 4.00 4.00 4.00 4.00 4.00 3180.45 K13 3196.47 3290.78 3385.05 3478.82 All data is in feet unless otherwise stated. Coordinates from slot #170 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 9513.81 on azimuth 333.47 degrees from wellhead. Total Dogleg for wellpath is 135.79 degrees. Vertical section is from wellhead on azimuth 313.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ i:~ tl," j '<li';' I ".'\:!o'J ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,170 Your ref 1C-170 Version #1 Kuparuk River Unit,North Slope, Alaska Last revised : 22-Apr-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R DIN A T E S Deg/100ft Sect 5800.00 80.55 334.04 3743.84 2318.04 N 2722.76 W 4.00 3571.64 5874.75 82.28 336.51 3755.00 2385.17 N 2753.67 W 4.00 3640.12 Top West Sak D 5900.00 82.87 337.33 3758.26 2408.21 N 2763.49 W 4.00 3663.04 5974.75 84.63 339.77 3766.40 2477.36 N 2790.65 W 4.00 3730.18 7 5/8 CSG 6000.00 85.22 340.59 3768.64 2501. 02 N 2799.18 W 4.00 3752.59 6100.00 87.58 343.83 3774.92 2596.04 N 2829.66 W 4.00 3839.85 6183.52 89.56 346.52 3777.00 2676.74 N 2851. 02 W 4.00 3910.66 WS V9 Heel Tgt - EOC 6183.54 89.56 346.52 3777.00 2676.76 N 2851. 03 W 4.00 3910.68 WS V9 D-HEEL RVSD 10 APR 03 6500.00 89.56 346.52 3779.43 2984.49 N 2924.79 W 0.00 4175.09 7000.00 89.56 346.52 3783.26 3470.70 N 3041.34 W 0.00 4592.86 7500.00 89.56 346.52 3787.09 3956.91 N 3157.89 W 0.00 5010.63 8000.00 89.56 346.52 3790.92 4443.12 N 3274.44 W 0.00 5428.40 8500.00 89.56 346.52 3794.76 4929.33 N 3391.00 W 0.00 5846.16 9000.00 89.56 346.52 3798.59 5415.55 N 3507.55 W 0.00 6263.93 9500.00 89.56 346.52 3802.42 5901.76 N 3624.10 W 0.00 6681.70 10000.00 89.56 346.52 3806.26 6387.97 N 3740.65 W 0.00 7099.47 10500.00 89.56 346.52 3810.09 6874.18 N 3857.20 W 0.00 7517.24 11000.00 89.56 346.52 3813.92 7360.39 N 3973.75 W 0.00 7935.01 11500.00 89.56 346.52 3817.76 7846.60 N 4090.30 W 0.00 8352.78 12000.00 89.56 346.52 3821.59 8332.81 N 4206.85 W 0.00 8770.55 12184.13 89.56 346.52 3823.00 8511.87 N 4249.77 W 0.00 8924.39 TD - 4 1/2" Liner 12184.15 89.56 346.52 3823.00 8511.88 N 4249.77 W 0.01 8924.41 WS V9 D-TOE RVSD 10 APR 03 All data is in feet unless otherwise stated. Coordinates from slot #170 and TVD from Est. RKB=87, (87.00 Ft above mean sea level). Bottom hole distance is 9513.81 on azimuth 333.47 degrees from wellhead. Total Dogleg for wellpath is 135.79 degrees. Vertical section is from wellhead on azimuth 313.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ OI~1 r .-"". r ;\r~ ( . .. \ ~~: ': ,\ J ~: r~ ': 1 ;'"_' ': . ~~ 1,1 \""'..I'"~ ~ ':11 'tit tw . __;:air. .....~' '. ~~ . ""-l..,' 'I: 'v . \ ) ConocoPhillips Alaska, Inc. Pad lC,170 Kuparuk River Unit,North Slope, Alaska MD TVD Rectangular Coords. ') PROPOSAL LISTING Page 3 Your ref 1C-170 Version #1 Last revised : 22-Apr-2003 Comments in wellpath -------------------- -------------------- Comment ----------------------------------------------------------------------------------------------------------- 600.00 1100.00 1477.95 1839.46 2099.76 2549.58 2550.96 3202.00 3565.12 4313.26 4758.48 4864.44 4956.95 5382.98 5874.75 5974.75 6183.52 6183.54 12184.13 12184.15 600.00 1097.47 1462.34 1786.00 1992.00 2273.00 2273.69 2600.00 2782.99 3158.00 3381.17 3433.00 3476.00 3642.00 3755.00 3766.40 3777.00 3777.00 3823.00 3823.00 Top MD Top TVD 0.00 N 43.50 N 137.33 N 275.19 N 398.01 N 643.55 N 644.34 N 1021. 31 N 1194.25N 1469.87 N 1633.90 N 1676.51 N 1719.42 N 1980.06 N 2385.17 N 2477.36 N 2676.74 N 2676.76 N 8511.87 N 8511.88 N 0.00 E 1.52 E 19.51 W 98.50 W 198.73 W 446.59 W 447.48 W 866.14 W 1126.44 W 1712.19 W 2060.78 W 2142.76 W 2212.51 W 2503.51 W 2753.67 W 2790.65 W 2851. 02 W 2851. 03 W 4249.77 W 4249.77 W 0.00 0.00 O.OON O.OON Rectangular Coords. O.OOE 12184.10 O.OOE 5974.75 3823.00 3766.40 8511.84N 2477.36N Rectangular Coords. 4249.76W 2790.65W KOP Build/Turn 3/100 Build/Turn 4/100 Base Permafrost Top T-3 Top K-15 EOC Begin Turn EOC Top Ugnu C Begin Final Bld/Trn Top Ugnu B Top Ugnu C K13 Top West Sak D 7 5/8 CSG WS V9 Heel Tgt - EOC WS V9 D-HEEL RVSD 10 APR 03 TD - 4 1/2" Liner WS V9 D-TOE RVSD 10 APR 03 Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD Casing ----------------------------------------------------------------------------------------------------------- Target name 0.00 0.00 Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location 3777.00 3823.00 2676.76N 8511.88N Rectangular Coordinates 2851.03W 4249.77W T.V.D. 4 1/2" Liner 7 5/8" Casing Revised ----------------------------------------------------------------------------------------------------------- 17-Feb-2003 17-Feb-2003 WS V9 D-HEEL RVSD 10 559196.000,5971477.000,2.0000 WS V9 D-TOE RVSD 10 557750.000,5977300.000,0.0000 OR':/'''~ , .~; " ., ~ 1 ',¡ / /11 '. . '\ Ù:III ú ~ \;,"1 'Q -r~ -",,-. -1 ~ ~~ -} :'!--£-.;.., .,....- .~ ~~~ ~ -~~ r-- Created by bmichael For: S Shultz I Date plotted: 22-Apr-2D03 I I Plot Reference is 1 C-170 Version # 1. I Coordinates ore in feet reference slot # 170. 1rue Vertical Depths ore reference Est. RKB=87'. -£ INTt:Q === ----- Point ----- KOP Build/Turn 3/100 Build/Turn 4/100 Base Permafrost Top T-3 Top K-15 EOC Begin Turn EOC Top Ugnu C Begin Final Bld/Trn Top Ugnu B Top Ugnu C K13 Top West Sok 0 7 5/8 CSG WS V9 Heel Tgt - EOC 8( TO - 4 1/2 Liner I ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well: 170 Field : Kuparuk River Unit Location: North Slope, Alaska PROF~LE COMMENT DATA MO 600.00 1100.00 1477.95 1 839.46 2099.76 2549.58 2550.96 3202.00 3565.12 4313.26 4758.48 4864.44 4956.95 5382.98 5874.75 5974.75 6183.52 12184.13 Inc 0.00 10.00 20.00 32.71 42.52 59.87 59.92 59.92 59.92 59.92 59.92 61.54 63.08 71.29 82.28 84.63 89.56 89.56 Oir 2.00 2.00 340.00 324.00 318.21 312.02 312.00 312.00 295.20 295.20 295.20 299.69 303.49 319.72 336.51 339.77 346.52 346.52 NO 600.00 1097 A7 1462.34 1786.00 1992.00 2273.00 2273.69 2600.00 2782.99 3158.00 3381 . 1 7 3433.00 3476.00 3642.00 3755.00 3766.40 3777.00 3823.00 No rt h 0.00 43.50 137.33 275.19 398.01 643.55 644.34 1021.31 1194.25 1469.87 1 633.90 1 676.51 1719.42 1980.06 2385.17 2477.36 2676.74 8511.87 East 0.00 1.52 -19.51 -98.50 -198.73 -446.59 -447.48 -866.14 -1 1 26.44 -1712.19 -2060.78 -2142.76 -2212.51 -2503.51 -2753.67 -2790.65 -2851.02 -4249.77 ~ CcnoccPhillips === V. Sect 0.00 28.66 108.22 260.17 417.31 766.07 767.27 1330.51 1638.65 2254.34 2620.75 2709.68 2789.90 3180.45 3640.12 3730.18 3910.66 8924.39 ~ Oe9/100 0.00 2.00 3.00 4.00 4.00 4.00 4.00 0.00 4.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 ---/ ~ ~~~~ BAKiR ~~~ 1C-170 Version #1 Cl.(~ asured Angle Azimuth ND-RKB TVD )epth deg deg ft Subse 0.00 0 00 2.00 0 00 -87 500.00 0.00 2.00 500.00 413 600.00 0.00 2.00 600.00 513 700.00 2.00 2.00 699.98 612 800.00 4.00 2.00 799.84 712 900.00 6.00 2.00 899.45 812 000.00 8.00 2.00 998.70 911 100.00 10.00 2A0 1097.47 1010 200.00 12.43 352.88 1195 56 1108 300.00 15.06 346.80 ~292 69 1205 4 00.00 17.81 342.5 3 1388.6 0 1301 477.95 20.00 340.00 1462 34 1375 500.00 20.71 338.51 1483.01 1396 600.00 24.09 332.85 1575.46 1488 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 89.56 346.52 2130.11 2191.48 2247.39 2699.80 2750.26 3158.00 3251.61 3381.17 3401.79 3433.00 3449J9 3476.00 349524 3537.93 3577.65 361420 3642.00 3647.41 3677.11 3703.17 3725.45 3743.84 3755.00 3758.26 3766.40 3768.64 3774.92 3777.00 3777.00 3779.43 378326 3787.09 3790.92 3794.76 3802.42 380626 3817 3821 Alaska State Plane Zone 4 NAD 27 Coordinates X Y a ft ft 562069.17 5968851.I 562069.58 5968867.; 562068 40 5968886.i 562063.91 5968909.! 56205613 5968937.i 562047.80 5968960.! 562045.02 5968968.i 562028.94 5969002.: 56200722 5969040.: 561979.96 5969081. 561967.70 5969098. 56194728 5969124.! 561909.36 5969171.: 561866 47 5969220. 561866 37 5969220.: 561818.52 5969271.' 561766.05 5969324.: 561709.21 5969379. 56164829 5969435.: 561616.65 5969463.~ 56161576 5969464.. 561324.92 5969722. 561194.09 5969837.'. 561128.54 5969891: 561057.60 5969940.i 560982.90 5969983. 560932.41 5970008. 560590.67 5970166. 560344.50 5970279. 56019775 5970347. 559994.62 5970440. 559962.13 5970456.. 559912.30 5970482. 559885.15 5970498. 55984221 5970524.' 55981025 5970546, 559737.81 5970600. 559668.18 5970660. 55960169 5970725. 559549.14 5970783. 559538.67 5970795. 559479.43 5970870. 55942426 5970949. 559373.42 5971032. 559327.16 5971119. 559295.71 5971186. 559285.71 5971209. 559257.99 5971278. 55924927 5971301. 559218.02 5971396. 559196.00 5971476. 559196.00 5971477. 559119.74 5971784. 558999.25 5972269. 558878.76 5972754. 558758.28 5973239. 558637.79 5973724. 558517.30 5974210. 558396.81 5974695. 558276.33 5975180. 558155.84 5975665. 558035.35 5976150. 557914 86 5976636. 557794.37 5977121. i~ N/-S E/-W ft ft 0.00 0.00 0.00 0.00 0.00 0.00 1.74 0.06 6.97 0.24 15.68 0.55 27.86 0.97 43.50 1.52 62.86 0.49 86.19 -3.81 113.43 -11.37 137.33 -19.51 144 51 -2223 179.13 -38.02 217.08 -59.44 258.16 -86 38 275.19 -98 50 302.18 -118.70 348-91 -15625 398.01 -198.73 398.13 -198.84 449.60 -24628 503.08 -298.32 558.29 -354.71 614.98 -415.19 643.55 -446.59 644.34 -447.48 904 34 -73624 1021.31 -866.14 1075.44 -931.25 1125.12 -1001.80 1168.95 -1076.15 119425 -1126.44 1354.46 -1466.93 1469.87 -1712.19 1538.67 -1858.40 1633.90 -2060.78 1649.75 -2093.14 1676.51 -2142.76 1692.38 -2169.79 1719.42 -2212.51 1741-15 -2244.30 1795.82 -2316.31 1856.12 -2385.46 1921 J6 -2451 A2 1980.06 -2503.51 1992 42 -2513.87 2067J6 -2572.51 2147.40 -2627.04 2230.~7 -267721 2318 04 -2722.76 2385.17 -2753.67 2408 21 -2763.49 2477 36 -2790.65 250102 -2799.18 2596 04 -2829.66 2676.74 -2851.02 267676 -285t03 2984.49 -2924.79 3470.70 -3041.34 3956.91 -3157.89 444312 -3274-44 4929.33 -3391.00 5415.55 -3507.55 5901 J6 -3624.10 6387 97 -3740.65 687418 -385720 7360.39 -3973.75 7846.G0 -4090.30 8332.81 -4206.85 VSect. Plane =313.19° 2. 3. 3. 3. 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4 4. 4. 4. 4. 4. 0. 0. 0.00 0.00 0.00 Vert.Sec ft 0.00 0.00 0.00 1.15 4.60 10.34 18.36 28.66 42.67 61.77 85.93 10822 115.12 150.33 191.92 239.68 260.17 293.37 352.73 417.31 417.47 48729 561.83 640.74 723.62 766-07 76727 1155.75 1330.51 1415.03 1500.47 1584.67 1638.65 1996.54 2254.34 2408.03 2620.75 2655.19 2709.68 274025 2789.90 2827.95 2917.87 3009.56 3102.58 3180.45 3196.47 3290.78 3385.05 3478.82 3571.64 3640.12 3663.04 3730.18 3752.59 3839.85 3910.66 3910.68 4175.09 4592.86 5010.63 5428 40 5846.16 6263.93 6681.70 7099 47 751724 ~~r~~~~~~1 ~ u 70 12184.15 89.56 346.52 3823.00 3736.00 557750.00 5977300.00 8511 88 -4249.77 0.00 8924.41 ~~,~~i~~1,~L ~ ConocoPhillips Alaska, Inc.', , ~. ~ ~'! P'itv~ ~~ c.~a«a ey emimo~i For: S Shultz ~~ ^ = Fa Structure : Pad 1C Well : 170 ~~_ ~_-- _'~ ~=_ Date ploHed : 22-Apr-2003 '~, ~ aio~ rs~r~re~e ~s ic-no vo~~o~ /i. i ~~, Field : Kuparuk River Unit Location : Norfh Slope, Alaska I, cowe~~wies arc ~~ reec rets~e~s sio~ yi ~a. ~ r"„ v,rertoai oapae a.a mterence Est. RI~-87'.I ~ i I I <- West (feet~ '-_= 56D 520 480 440 400 360 320 280 240 200 760 120 80 40 0 40 80 ~~o '~ 'n ~ 720 ~ \ ~ 2300 \ ~ 1600 3200 2400 ~ 680 ~~~\ 1900 ~ 6a0 ` ~• ~ 31 , ~ Q , 1500\ ~ \ ~ / '~ /, aoo 1900 `` ~ y 2200 ~,~ 1800 ~ ~j~00 ~( 1800 ~ ~ ~~ % 560 ~ \ y 1400 y 1800 ~ \ ~~ 2900 ~/~ ~ ~( 1700 520 ~~ ~ `,~ 2100 / ~ 480 ~ }' z~~~00 'B 1300 1700 `\` ~ ~p~ ~ y , ~~1600 ~ ' \ 4aD ~ / / ' ~ , I ~ , y ' ~ooo ~ ' ~ ,2~~ k, . 2~~~ ~ 4~~ ~~ R ~ ~ 600 3600 V~ ~ ~ 1500 / ' ~ ~ ` ~ ^ ~ n. ;~ 2100 ~ i~ ~~00 ~ 360 Z ~ ~ ~ ' ~l 100 ~~ ~ 1500 ~ 2600 }~ ~ ~,~ 11900 ~ ~ 1400 # ~~ O ~ ~ ~~ ~ ~ ~ : ` . ~ ~ ~ 320 ~ 3 0~ ` ` ~ ~ 1700 '" ~ ~ 1400 2500` ` (D - ~ ~ ~ ~9D0 500~ ;~ 800 ~ 1500 0 1 _ 14 1300 x '~ - ` 2so ~ ~ ~ ~~~ t2~0 ~~~0p a 800 ` ~_"-. s- - 04 w 000 ~ ~ ~~160U -~1J00 r ~ ~ ~ 8 _ oo _ ,~ 00 \` ~00 ~ ~ -- .~ ~2400 ~,~ 1700 ~ ~.._--...rt 1800 240 ~ b i ~ao ~~@~ ~, zoo ~, ~ , aoo ~z soo ~,~ 1900 00 ifi~Q~~ ~~~~~ 3300 ~. ~ ~~ ~ ~~ ~ ~ 1900 ~~ `~ ~ i ~ 2300 t 1600 ~ ., ~ 200 Q ~ ~,,s~ ~~~~ ,oa~~488 ~, ~" ~ ;,,;oa ~, ,~ ~,,,~aa 1300, * 1800 j ~ ~ 1500 ' ~ eo 1100 ~ ~~ 900 x ~\ ~} ~~_ ,~ 800 ~ 1400 ~ ~ ~, r 2200 ~ -! ~ 100~J ~ ,~'1 t~DO ' 130 ~ ~ ~~ I 1200 0 ~ ~ ~~ 700 ~~ ~ , ,,, 3 ~ u~ 170 ~ : ~ 1400 '~ ` 1 300 1000 ~ 900 ~ 2100 1000 i x ~ ~ 1 ~ 1300 ~~ , ~0 ~1200 i * 1300 i ""' l 2000 ~ 900 ~ * 1 100 *~'a 80 900 9Gi * A 500 ~~1 100 $00 ~, 1200 , ~ 52 0 3200 3 50 1200 ~ f+~~~*- - \ ,~00 ~' \ .: ~ ~14~900 ~ 19~ ~ 1100 • 1000 i ~1200 '~ r.1000 ~ 1000 i *g~A800 \ A 300 ,r 40 17 - o ~ ~r 1 100 ~ 700 - _ ~~3ao, 600 ' J a 900 . * 300 f 800 ~ ~. ~3ee 800• e . ~aa ~ ~'~OOe ~300 ~ 1000 O 800 ~00 ~ ~ 900 - ~~- - - 1.~ ~1 800 2400 . 2300 40 ~~6 "e Y Q~LgI 700 ~ ' '~~~ ~~~~;~~~L eo ~ "~' J ~~_ .~ ~J ~.a..,,, ~.. ~ ~~ ~ ~ Created by bmichael FOC: S ShU11,2 Dote plotted : 22-Apr-2003 Plot Reference is 1C-170 Version ~1. Coortlinates are in feet reference slol ~170. ~True Vertical Depths a re(erence Est. RKB=87'. ~ I~IOtES I INTf.Q ConocoPhillips A~aska, Inc. Structure : Pad 1C Well : 170 Field : Kuparuk River Unit Location : Norfh Slope, Alaska ~ -. CcncccPhillips <- West (feet) 3600 3450 3300 3150 3000 2850 2700 2550 2400 2250 2100 1950 1800 1650 1500 1350 1200 1050 900 750 600 450 300 2550 2400 2250 2100 1950 `J 1800 n i 1650 Z O ~ 1500 ~ -~, ~ • N 1350 ~ ~ 1200 1050 900 750 600 ~ ~ ConocoPhillips Alaska, Inc. _ _ _ C ~~~~~~~IIII=-_ ca~aa ny em~~nasi For. S Shultz Structure : Pad 1 C Well : 170 =____ _=__ _ _= Date pbtted : 22-Apr-2003 , ~ aioa a<re.~~a ~s ic-no ve~~o„ /i. Field : Kuparuk River Unit Location : North Slope, Alaska coore~oaeea are ~~ reac .erera~oa sio~ ~no. ~ . Trve Vertical Depths are reference Est. RK0=87'. ~ I iYii~Zi -~ I ~ <- West (feet) 5600 5200 4800 4400 4000 3600 3200 2800 2440 20D0 1600 1200 8800 174 170 ~ ~~ I 8400 11 1 \ 1 ~ 1 ssoo aooo ~ ~ ' ~ ~ ~ ~ 7600 ~ ~ 6000 ~ ~ ~ ~ , ~zoo ~ ~ ~ » ~ 6800 s5oo ` ssoo ~ sooo ` ~ ~ 64D0 5500 ~~ ~ ~ 6D00 ~ 5000 ~ \~5000 ,~ 7000 ~ n WS 1~ o0 0 ~~ seoo ~ ~~ooo ~ ~ ~2000 ~ , ssoo 5200 ° ~ Q 4g00 3 \ ~ ~ i ~ ~~ , ~ 48D0 -~+ ~ ' ` 6000 ~ ~ ~ ~ ' 4400 , 4000 ~ ~ •~ ~, 5500 ~~ ~ ~ \~ 4000 ~ ~ 1 ~ ~ ~ ~` Y 5000 3600 ` ~ ~y 3500 ~ ~ ~ ~ ~ 3200 ~ \ ~II \\ ,~ ~~ 4500 ~ \ ~ \ ~ ~, 3000 2800 .~ 6500 \ ~ ~ 4000 ~ ~~~~~, 3500 ~~ i8 , - - - ,~3000~ \~ 6000 t~ 7 r 4000 ~'r ~500 ~ 2400 +~ 350Qi! ~ ~ ~ \ ~. 35pp \ . ~~ »3000 `~ i~ 3500 .\ ~ ~5500 ~ ~0 ~` ~ 6000 '~ 2500 ~~ . 2000 ~ 30 0 ~ 3000 ~ ` ~500. 550~ ~` ~~~ ~~ ~ 5000 ~ ~y ' Target ~~ ~vd. -7526`4~3i~~07 41 W~, ~ \' 2500"~.~ ~ ie O ~ 7600 , ~\ ~ ~ L~S'b'1S) ~/ 8 ~ /) ' ''4 '.. ,o~ n ''O \~r:/ 1200 ~~~~6~~~~~ ~ ! ConocoPhillips Alaska, Inc. _ ~' ~~~• •- ~ c,~em cy emknoai For: S Shultz Structure : Pad 1 C Well : 170 ~~+~~~L' •'~II~~~ Data plotteE : 22-Apr-2003 I - Plot Reference ts ic-no v~rs~a~ bi. I Field : Kuparuk River Unit Location : Norfh Slope, Alaska ~~. Coordinates arc in feet rcference ebt /170. 'True Vartical Dapths ara re/erenee Eet. RKB-87'. ~~ C~~S 1~ TRUE NORTH Q Q ,~ ~ ~~ 350 ~ ~-{-j=' ~ o0 340 ', -~'~ 20 330 2~~ 30 . 320 ~ ~ soo 40 ,~ , ~~ ' , ~ ~~ ~~3 0 3300~ ~~ ~jQ , % __,_ _ __ * ,~oa ,6 *~,. 150~ 310 ~ ~ ~ ~ -~ 2900 ~ , ~ 3~ ;;' ~~ 0 0 - 60 ~,,s _--' , , 90~. ; . = 70 290 / o ~ ~ ,~ , ioo `, ~ 6 0 ~s o , o ~ 280 y ~ ~oo ` 80 3 ' ,~4 * ' ~ ~--*300 ,~ 30Q-._ _- ~ 1 700 .........,~ \~ 270 2 0 1 C~~~1 ~0 1 0`3 3 0'~ 90 1 0 1 0 1 0 ~a soo - , __, + ; ~oa ~ 9 0 , „oo \30.70 '300 ,~ rOg 1'S ,~ ~ 260 , zs, soo 9 60 „ ~ 100 30 ~ ~\ 700 j 250 ~~ ~ 90 00 ~ , '~ 1 10 ~~ ~ , - ~ I 3p _ ~ ~;'~ ~ ~4 1700 - ~ ' ~ 240 `~~ -'-t~o _ i__i ~- ~" . ° ~, ~'" ~o0 1 20 , 310 p ~ ~0 230 ~300 ' ~ 130 300 ~~~~ ~ ~ a 1 0 ,~~00~20 '~ ~%~ioo % ~ 140 y , ; 300 2 0 ' ti~'" ~, 300 21 0 -' ~ soo 1 5~ x~o *"~oo ~~`o 00 ~ ~ oi soo ~ ,~ 300 ~- ' ~ ~~oo ~ 60 ' 300 ,ti5' ~>~A~oo • 1 9 1 7 ~soo ~ " ~~e /~ 900 j7B "0.' '~ / a/ $'09 S~~ h ~ c~ ~/ ry^ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well f` ~ ' P ~ ~i~:;~~ay~ ) j ) - Baker Hughes Incorporh"ed Anticollision Report Company: ConocoPhillipsAlaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1 C Reference Well: 170 Reference Wellpath: 1C-170 Vers#1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 100.00 ft Depth Range: 0.00 to 12184.15 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 3/7/2003 Validated: No Planned From To Survey ft ft 0.00 800.00 Planned: 1C-170 Vers#1 V22 800.00 12184.15 Planned: 1C-170 Vers#1 V22 Casing Points MD ft 5974.75 12184.15 TVD ft 3766.40 3823.00 75/8" Casing 4 1 /2" Liner Diameter in 7.625 5.500 Hole Size in 9.875 6.750 Name Summary <--------...;,---------- Offset Wellpath ----------------> Site Well Wellpath Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C 1C-01 V2 1 C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1 C-07 VO 1 C-08 VO 1 C-09 va 1C-10 VO 1C-102 V5 1C-102L 1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1 C-1 09L 1 VO 1C-111 VO 1 C-11 VO 1C-113 VO Plan: 1C-113 1C-117 VO 1 C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 V1 1C-15 V1 Plan: 1C-15L 1 1C-16 VO 1C-17 VO 1C-172 Vers#O.g V4 Pia 1C-174 V24 1C-178 BLat Vers# 2.b 1C-178 D Lat Vers# 2.b 1 C-18 VO 1C-184 VersO.e V1 Plan 1C-190 V8 1C-19 Vers#1a V1 Plan: 01 02 03 04 05 06 07 08 09 10 102 102 104 104 104 109 109 111 11 113 117 119 121 12 123 125 127 131 13 133 135 14 15 16 17 172 174 178 178 18 184 190 19 Date: 4/22/2003 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Version: 6 TooIcode Good_gyro MWD+SAG+IFR Reference MD ft 684.34 686.10 592.98 689.80 790.29 994.16 3384.74 1 926.16 2054.01 589.74 5665.33 5665.33 584.48 584.48 584.48 3019.91 3019.91 185.00 2605.08 0.00 584.97 285.00 285.00 1746.14 285.00 284.98 284.98 185.00 2055.01 584.94 192.98 483.06 482.26 1069.76 7598.80 5683.19 790.04 789.43 883.28 683.08 599.98 199.80 599.98 Or"·· ...... ,.. 1-1' i ~: i i Offset MD ft 700.00 700.00 600.00 700.00 800.00 1000.00 3100.00 1800.00 2000.00 600.00 5400.00 5400.00 600.00 600.00 600.00 2800.00 2800.00 200.00 2200.00 0.00 600.00 300.00 300.00 1800.00 300.00 300.00 300.00 200.00 2100.00 600.00 200.00 500.00 500.00 1100.00 6600.00 6100.00 800.00 800.00 900.00 700.00 600.00 200.00 600.00 Reference: Error Model: Scan Method: Error Surface: Time: 08:34:56 Page: Well: 170, True North Wellhead(8T) 87.0 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Good Gyro MWD+SAG+IFR (AK) Ctr-Ctr No-Go Distance Area ft ft 428.74 11.49 311.2611.52 198.84 9.99 102.7611.58 101.59 13.22 187.94 17.37 164.51 117.71 339.19 39.96 480.87 56.22 396.11 9.97 496.61 295.44 496.61 295.44 437.94 10.19 437.94 10.19 437.94 10.19 167.90 122.03 167.90 122.03 350.42 3.42 502.37 91.07 331 .44 299.13 285.83 276.46 47.46 269.96 267.40 266.97 275.23 108.77 278.04 296.87 176.25 283.02 82.40 194.63 242.17 18.01 139.61 145.05 84.31 281.15 400.57 360.79 ff "',,01:1 10.20 5.04 4.93 44.82 4.84 5.21 5.15 3.48 52.03 9.82 3.63 9.31 8.93 24.89 80.38 261.72 7.33 14.68 16.74 11.33 11.27 3.67 11.29 Allowable Deviation ft 417.25 299.74 188.85 91.18 88.37 170.60 66.46 299.47 424.97 386.15 263.49 263.49 427.76 427.76 427.76 48.83 48.83 347.00 442.05 288.93 280.78 271.53 8.25 265.12 262.20 261.83 271.75 68.75 268.25 293.25 167.00 274.09 58.59 114.44 12.25 11.14 124.98 128.35 72.98 269.88 396.90 349.50 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk No Offset Stations Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Minor 1/200 Pass: Major Risk Pass: Minor Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ) ~ ¡ ) , Baker Hughes Incorporat.ed Anticollision Report Date: 4/22/2003 Time: 08:34:56 Company: ConòcoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1C Reference Well: 170 Reference Wellpath: 1 C-170 Vers#1 Page: 2 Co;.ordinatl~(NE) Reference: Well: 170. True North Vertical (TVD) Reference: Wellhead(87') 87.0 Db: Oracle Summary <7--~---~--------· Offset Wellpath ---------~--> Site Well Wellpath Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C 22 23 23 24 25 26 27 WS-1 WS-24 1C-22 V3 1 C-23A V2 1 C-23PB1 V1 1C-24 VO 1 C-25 VO 1 C-26 V2 1 C-27 V1 WS1 V1 WS-24 VO Reference MD ft 400.18 491 .50 491.50 395.98 491.98 391.99 491.56 9330.65 Offset MD ft 400.00 500.00 500.00 400.00 500.00 400.00 500.00 3800.00 Ctr-Ctr No-Go Distance Area ft ft 320.99 7.07 327.20 8.79 327.20 8.79 343.83 7.97 383.74 8.35 400.40 6.71 421.35 8.96 1453.83 262.92 'l I.~.:~r Allowable Deviation ft 313.92 318.42 318.42 335.87 375.39 393.69 412.44 1190.92 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range ) ') Baker Hughes Incorpora..ed Error Ellipse Survey Report Company: Field: Site: Well: Well path: ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 C 170 1C-170 Vers#1 Date: 4/22/2003 Time: 08:37:06 Page: Co-ordinate(NE) Reference: Well: 170, True North Vertical (TVD) Reference: Wellhead(87') 87.0 Section (\'S) Reference: Well (0.00N,0.00E,333.47Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 1C North Slope, Alaska Site Position: Northing: 5970228.13 ft Latitude: 70 19 45.173 N From: Map Easting: 560993.64 ft Longitude: 149 30 19.124 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 60.50 ft Grid Convergence: 0.24 deg Well: 170 Slot Name: Well Position: +N/-S -1413.19 ft Northing: 5968823.76 ft Latitude: 70 19 31.274 N +E/-W 1063.43 ft Easting : 562068.42 ft Longitude: 149 29 48.084 W Position Uncertainty: 0.00 ft Wellpath: 1 C-170 Vers#1 Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Wellhead(87') Height 87.00 ft Above System Datum: Mean Sea level Magnetic Data: 3/7/2003 Declination: 25.50 deg Field Strength: 57501 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 333.47 Survey Program for Definitive Wellpath Date: 3/7/2003 Validated: No Version: 6 Planned From To Survey Toolcode Tool Name ft ft 0.00 800.00 Planned: 1C-170 Vers#1 V22 Good_gyro Good Gyro 800.00 12184.15 Planned: 1C-170 Vers#1 V22 MWD+SAG+IFR MWD+SAG+IFR (AK) Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside----> Lateral-----> Magn. Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias of Bias Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100.00 0.00 0.00 100.00 0.05 0.00 0.05 0.00 0.00 0.05 0.05 0.00 Good_gyro 200.00 0.00 0.00 200.00 0.12 0.00 0.12 0.00 0.00 0.12 0.12 0.00 Good_gyro 300.00 0.00 0.00 300.00 0.18 0.00 0.18 0.00 0.00 0.18 0.18 0.00 Good_gyro 400.00 0.00 0.00 400.00 0.25 0.00 0.25 0.00 0.00 0.25 0.25 0.00 Good_gyro 500.00 0.00 0.00 500.00 0.32 0.00 0.32 0.00 0.28 0.00 0.00 0.32 0.32 0.00 Good_gyro 600.00 0.00 0.00 600.00 0.39 0.00 0.39 0.00 0.35 0.00 0.00 0.39 0.39 0.00 Good_gyro 700.00 2.00 2.00 699.98 0.45 0.00 0.46 0.00 0.41 0.00 0.00 0.46 0.46 45.00 Good_gyro 800.00 4.00 2.00 799.84 0.52 0.00 0.53 0.00 0.48 0.00 0.00 0.53 0.53 45.00 Good_gyro 900.00 6.00 2.00 899.45 0.55 0.00 0.57 0.00 3.04 0.10 0.10 0.60 0.57 93.04 MWD+SAG+I FR 1000.00 8.00 2.00 998.70 0.69 -0.01 0.81 0.00 3.04 0.13 0.13 0.81 0.78 173.09 MWD+SAG+IFR 1100.00 10.00 2.00 1097.47 0.92 -0.01 1.21 0.00 3.04 0.15 0.15 1.21 1.02 178.72 MWD+SAG+IFR 1200.00 12.43 352.88 1195.56 1.16 -0.02 1.68 0.00 3.04 0.18 0.18 1.68 1.28 178.61 MWD+SAG+IFR 1300.00 15.06 346.80 1292.69 1.41 -0.03 2.24 0.01 3.03 0.21 0.22 2.25 1.55 175.76 MWD+SAG+I FR 1400.00 17.81 342.53 1388.60 1.70 -0.04 2.95 0.01 3.02 0.25 0.25 2.97 1.84 172.04 MWD+SAG+IFR 1477.95 20.00 340.00 1462.34 1.93 -0.05 3.59 0.01 3.01 0.27 0.28 3.63 2.08 169.42 MWD+SAG+IFR 1500.00 20.71 338.51 1483.01 2.00 -0.05 3.78 0.01 2.99 0.28 0.29 3.82 2.16 168.89 MWD+SAG+IFR 1600.00 24.09 332.85 1575.46 2.33 -0.07 4.72 0.02 2.99 0.32 0.32 4.80 2.43 165.13 MWD+SAG+IFR 1700.00 27.62 328.54 1665.45 2.67 -0.09 5.86 0.02 2.98 0.35 0.36 5.98 2.74 161.50 MWD+SAG+IFR 1800.00 31.26 325.15 1752.53 3.01 -0.12 7.22 0.03 2.96 0.39 0.41 7.37 3.06 158.02 MWD+SAG+IFR 1900.00 34.97 322.40 1836.28 3.35 -0.15 8.81 0.03 2.96 0.43 0.45 8.99 3.39 154.86 MWD+SAG+IFR \ 1 : j t:·~ ) ') Baker Hughes Incorpora..ed Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 4/22/2003 Time: 08:37:06 . Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) ·Reference: Well:. 170, True North Site: Pad 1 C Vertical (TVD) Reference: Wellhead(8T) 87.0 Well: 170 Section (VS) Reference: Well (O;OON ,0.00E,333.4 7 Azi) Well path: 1C-170 Vers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside--~-> Lateral..-----> VertiCal.;.;:"--> Magn. Semi';'major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2000.00 38.73 320.13 1916.29 3.67 -0.18 10.62 0.04 2.97 0.47 0.49 10.83 3.71 152.05 MWD+SAG+IFR 2100.00 42.53 318.20 1992.18 3.98 -0.21 12.67 0.04 3.01 0.50 0.53 12.90 4.02 149.58 MWD+SAG+IFR 2200.00 46.35 316.53 2063.57 4.28 -0.24 14.93 0.05 3.08 0.53 0.58 15.19 4.33 147.42 MWD+SAG+IFR 2300.00 50.20 315.07 2130.11 4.56 -0.28 17.40 0.05 3.19 0.57 0.62 17.67 4.63 145.52 MWD+SAG+IFR 2400.00 54.06 313.76 2191.48 4.82 -0.32 20.03 0.06 3.34 0.60 0.66 20.33 4.91 143.85 MWD+SAG+IFR 2500.00 57.94 312.57 2247.39 5.06 -0.36 22.82 0.07 3.53 0.62 0.70 23.14 5.17 142.37 MWD+SAG+IFR 2550.96 59.92 312.00 2273.69 5.17 -0.38 24.28 0.07 3.63 0.63 0.72 24.61 5.31 141.69 MWD+SAG+IFR 2600.00 59.92 312.00 2298.27 5.35 -0.38 25.73 0.07 3.76 0.65 0.74 26.04 5.42 141.09 MWD+SAG+IFR 2700.00 59.92 312.00 2348.39 5.72 -0.38 28.69 0.07 4.07 0.67 0.78 28.96 5.62 140.05 MWD+SAG+IFR 2800.00 59.92 312.00 2398.51 6.10 -0.38 31.66 0.07 4.39 0.70 0.83 31.91 5.81 139.21 MWD+SAG+IFR 2900.00 59.92 312.00 2448.63 6.49 -0.38 34.66 0.07 4.72 0.72 0.87 34.87 6.01 138.52 MWD+SAG+IFR 3000.00 59.92 312.00 2498.75 6.88 -0.38 37.66 0.07 5.06 0.75 0.92 37.86 6.20 137.94 MWD+SAG+IFR 3100.00 59.92 312.00 2548.87 7.27 -0.38 40.67 0.07 5.40 0.77 0.97 40.85 6.40 137.45 MWD+SAG+IFR 3200.00 59.92 312.00 2599.00 7.67 -0.38 43.70 0.07 5.75 0.80 1.02 43.86 6.60 137.03 MWD+SAG+IFR 3202.00 59.92 312.00 2600.00 7.68 -0.38 43.76 0.07 5.75 0.80 1.02 43.92 6.60 137.02 MWD+SAG+IFR 3300.00 59.71 307.47 2649.29 8.49 -0.38 45.96 0.12 6.03 0.83 1.07 46.53 6.75 136.58 MWD+SAG+IFR 3400.00 59.65 302.84 2699.80 9.54 -0.39 47.63 0.18 6.27 0.86 1.13 48.88 6.87 135.96 MWD+SAG+IFR 3500.00 59.76 298.21 2750.26 10.83 -0.40 49.05 0.24 6.52 0.89 1.18 51.24 7.04 135.16 MWD+SAG+IFR 3565.12 59.92 295.20 2782.99 11.76 -0.41 49.84 0.27 6.69 0.91 1.22 52.76 7.18 134.55 MWD+SAG+IFR 3600.00 59.92 295.20 2800.47 11.84 -0.41 50.81 0.27 6.80 0.92 1.24 53.68 7.26 134.18 MWD+SAG+IFR 3700.00 59.92 295.20 2850.60 12.13 -0.41 53.90 0.27 7.15 0.95 1.29 56.59 7.49 133.12 MWD+SAG+IFR 3800.00 59.92 295.20 2900.72 12.42 -0.41 56.98 0.27 7.50 0.98 1.35 59.53 7.71 132.17 MWD+SAG+IFR 3900.00 59.92 295.20 2950.85 12.72 -0.41 60.07 0.27 7.86 1.01 1.41 62.49 7.94 131.31 MWD+SAG+IFR 4000.00 59.92 295.20 3000.98 13.03 -0.41 63.17 0.27 8.21 1.05 1.47 65.46 8.15 130.52 MWD+SAG+IFR 4100.00 59.92 295.20 3051 .1 0 13.34 -0.41 66.26 0.27 8.57 1.08 1.54 68.44 8.37 129.81 MWD+SAG+IFR 4200.00 59.92 295.20 3101.23 13.66 -0.41 69.36 0.27 8.93 1.12 1.60 71.43 8.59 129.16 MWD+SAG+IFR 4300.00 59.92 295.20 3151.35 13.99 -0.41 72.45 0.27 9.29 1.15 1.67 74.44 8.80 128.56 MWD+SAG+IFR 4400.00 59.92 295.20 3201.48 14.32 -0.41 75.55 0.27 9.65 1.19 1.74 77.45 9.01 128.00 MWD+SAG+IFR 4500.00 59.92 295.20 3251.61 14.66 -0.41 78.65 0.27 10.02 1.22 1.81 80.47 9.23 127.49 MWD+SAG+IFR 4600.00 59.92 295.20 3301.73 15.00 -0.41 81.76 0.27 10.38 1.26 1.88 83.50 9.44 127.02 MWD+SAG+IFR 4700.00 59.92 295.20 3351.86 15.35 -0.41 84.86 0.27 10.75 1.30 1.95 86.54 9.65 126.58 MWD+SAG+IFR 4758.48 59.92 295.20 3381.17 15.56 -0.41 86.67 0.27 10.96 1.32 2.00 88.31 9.77 126.34 MWD+SAG+IFR 4800.00 60.54 296.97 3401.79 15.00 -0.42 88.36 0.23 11.09 1.34 2.03 89.50 9.85 126.19 MWD+SAG+IFR 4900.00 62.12 301.16 3449.79 14.18 -0.47 91.90 0.12 11.34 1.37 2.10 92.22 10.03 125.96 MWD+SAG+IFR 5000.00 63.83 305.22 3495.24 14.15 -0.53 94.97 0.00 11.60 1.41 2.17 94.98 10.19 125.86 MWD+SAG+IFR 5100.00 65.65 309.16 3537.93 14.70 -0.60 97.61 -0.12 11.89 1.44 2.25 97.76 10.33 125.88 MWD+SAG+IFR 5200.00 67.56 312.99 3577.64 15.57 -0.68 99.80 -0.23 12.19 1.47 2.32 100.54 10.44 126.00 MWD+SAG+IFR 5300.00 69.57 316.71 3614.20 16.50 -0.76 101.58 -0.35 12.50 1.50 2.39 103.29 10.53 126.23 MWD+SAG+IFR 5400.00 71.65 320.33 3647.41 17.32 -0.85 102.96 -0.47 12.84 1.52 2.46 105.98 10.61 126.53 MWD+SAG+IFR 5500.00 73.80 323.86 3677.11 17.92 -0.95 103.93 -0.58 13.19 1.54 2.52 108.61 10.69 126.91 MWD+SAG+IFR 5600.00 76.00 327.32 3703.17 18.23 -1.05 104.52 -0.70 13.55 1.56 2.58 111.13 10.78 127.35 MWD+SAG+IFR 5700.00 78.26 330.71 3725.45 18.24 -1.14 104.72 -0.81 13.92 1.57 2.64 113.56 10.90 127.84 MWD+SAG+IFR 5800.00 80.55 334.04 3743.84 17.96 -1.24 104.53 -0.93 14.30 1.59 2.69 115.86 11.08 128.37 MWD+SAG+IFR 5900.00 82.87 337.33 3758.26 17.45 -1.34 103.97 -1.04 14.69 1.59 2.74 118.04 11.35 128.94 MWD+SAG+IFR 6000.00 85.22 340.59 3768.64 16.82 -1 .43 103.03 -1.15 15.09 1.60 2.78 120.08 11.74 129.53 MWD+SAG+IFR 6100.00 87.58 343.83 3774.92 16.23 -1.52 101.72 -1.26 15.50 1.60 2.82 121.97 12.27 130.14 MWD+SAG+IFR 6183.54 89.56 346.52 3777.00 15.94 -1.59 100.33 -1.35 15.84 1.61 2.85 123.45 12.83 130.66 MWD+SAG+IFR 6200.00 89.56 346.52 3777.13 16.01 -1.59 100.71 -1.35 15.91 1.61 2.86 123.75 12.93 130.77 MWD+SAG+IFR 6300.00 89.56 346.52 3777.89 16.45 -1.59 103.24 -1.35 16.35 1.61 2.90 125.76 13.47 131.47 MWD+SAG+IFR 6400.00 89.56 346.52 3778.66 16.90 -1.59 105.79 -1.35 16.80 1.61 2.93 127.80 14.02 132.15 MWD+SAG+IFR 6500.00 89.56 346.52 3779.43 17.35 -1.59 108.36 -1.35 17.25 1.61 2.97 129.88 14.58 132.82 MWD+SAG+IFR 6600.00 89.56 346.52 3780.19 17.80 -1.59 110.94 -1.35 17.70 1.61 3.00 131.98 15.15 133.48 MWD+SAG+IFR 6700.00 89.56 346.52 3780.96 18.25 -1.59 113.54 -1.35 18.15 1.61 3.04 134.11 15.73 134.12 MWD+SAG+IFR J ~i 4 ~"..,. JI '; ~ ») Baker Hughes Incorporal-ed Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 4/22/2003 Time: 08:37:06 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 170, True North Site: Pad 1 C Vertical (TV D) Reference: Wellhead(87') 87.0 Well: 170 Section (\'8) Reference: Well (0.00N,O.00E,333.47Azi) \Vellpath: 1C-170 Vers#1 8urve)' Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside----> Lateral-------> Vertical-----> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 6800.00 89.56 346.52 3781.73 18.70 -1.59 116.16 -1.35 18.60 1.61 3.08 136.26 16.30 134.75 MWD+SAG+IFR 6900.00 89.56 346.52 3782.49 19.15 -1.59 118.79 -1.35 19.05 1.61 3.12 138.45 16.86 135.36 MWD+SAG+IFR 7000.00 89.56 346.52 3783.26 19.60 -1.59 121.44 -1.35 19.50 1.61 3.15 140.66 17.42 135.95 MWD+SAG+IFR 7100.00 89.56 346.52 3784.03 20.05 -1.59 124.10 -1.35 19.95 1.61 3.19 142.89 17.97 136.54 MWD+SAG+IFR 7200.00 89.56 346.52 3784.79 20.50 -1.59 126.77 -1.35 20.41 1.61 3.23 145.15 18.51137.11 MWD+SAG+IFR 7300.00 89.56 346.52 3785.56 20.95 -1.59 129.45 -1.35 20.86 1.61 3.27 147.43 19.04 137.66 MWD+SAG+IFR 7400.00 89.56 346.52 3786.33 21.41 -1.59 132. 14 -1.35 21.31 1.61 3.31 149.74 19.56 138.20 MWD+SAG+IFR 7500.00 89.56 346.52 3787.09 21.86 -1.59 134.84 -1.35 21.77 1.61 3.35 152.06 20.06 138.72 MWD+SAG+IFR 7600.00 89.56 346.52 3787.86 22.31 -1.59 137.55 -1.35 22.22 1.61 3.39 154.41 20.56 139.24 MWD+SAG+IFR 7700.00 89.56 346.52 3788.63 22.77 -1.59 140.27 -1.35 22.67 1.61 3.43 156.77 21.04 139.73 MWD+SAG+IFR 7800.00 89.56 346.52 3789.39 23.22 -1.59 143.00 -1.35 23.13 1.61 3.47 159.16 21.51 140.22 MWD+SAG+IFR 7900.00 89.56 346.52 3790.16 23.68 -1.59 145.74 -1.35 23.58 1.61 3.51 161.56 21.96 140.69 MWD+SAG+IFR 8000.00 89.56 346.52 3790.92 24.13 -1.59 148.48 -1.35 24.04 1.61 3.55 163.98 22.41 141.15 MWD+SAG+IFR 8100.00 89.56 346.52 3791.69 24.59 -1.59 151.23 -1.35 24.49 1.61 3.59 166.42 22.84 141.60 MWD+SAG+IFR 8200.00 89.56 346.52 3792.46 25.04 -1.59 153.99 -1.35 24.95 1.61 3.64 168.87 23.26 142.04 MWD+SAG+IFR 8300.00 89.56 346.52 3793.22 25.50 -1.59 156.75 -1.35 25.41 1.61 3.68 171.34 23.67 142.46 MWD+SAG+IFR 8400.00 89.56 346.52 3793.99 25.96 -1.59 159.52 -1.35 25.86 1.61 3.72 173.82 24.07 142.87 MWD+SAG+IFR 8500.00 89.56 346.52 3794.76 26.41 -1.59 162.30 -1.35 26.32 1.61 3.76 176.32 24.46 143.27 MWD+SAG+IFR 8600.00 89.56 346.52 3795.52 26.87 -1.59 165.08 -1.35 26.78 1.61 3.81 178.83 24.83 143.66 MWD+SAG+IFR 8700.00 89.56 346.52 3796.29 27.32 -1.59 167.86 -1.35 27.23 1.61 3.85 181.36 25.20 144.04 MWD+SAG+IFR 8800.00 89.56 346.52 3797.06 27.78 -1.59 170.65 -1.35 27.69 1.62 3.89 183.90 25.55 144.41 MWD+SAG+IFR 8900.00 89.56 346.52 3797.82 28.24 -1.59 173.44 -1.35 28.15 1.62 3.94 186.45 25.90 144.77 MWD+SAG+IFR 9000.00 89.56 346.52 3798.59 28.70 -1.59 176.24 -1.35 28.60 1.62 3.98 189.01 26.24 145.13 MWD+SAG+IFR 9100.00 89.56 346.52 3799.36 29.15 -1.59 179.05 -1.35 29.06 1.62 4.02 191.58 26.56 145.47 MWD+SAG+IFR 9200.00 89.56 346.52 3800.12 29.61 -1.59 181.85 -1.35 29.52 1.62 4.07 194.16 26.88 145.80 MWD+SAG+IFR 9300.00 89.56 346.52 3800.89 30.07 -1.59 184.66 -1.35 29.98 1.62 4.11 196.76 27.19 146.12 MWD+SAG+IFR 9400.00 89.56 346.52 3801.66 30.53 -1.59 187.48 -1.35 30.44 1.62 4.16 199.36 27.49 146.44 MWD+SAG+IFR 9500.00 89.56 346.52 3802.42 30.98 -1.59 190.30 -1.35 30.89 1.62 4.20 201.98 27.78 146.74 MWD+SAG+IFR 9600.00 89.56 346.52 3803.19 31 .44 -1.59 193.12 -1.35 31.35 1.62 4.25 204.60 28.07 147.04 MWD+SAG+IFR 9700.00 89.56 346.52 3803.96 31.90 -1.59 195.94 -1.35 31.81 1.62 4.29 207.23 28.35 147.33 MWD+SAG+IFR 9800.00 89.56 346.52 3804.72 32.36 -1.59 198.77 -1.35 32.27 1.62 4.34 209.87 28.62 147.62 MWD+SAG+IFR 9900.00 89.56 346.52 3805.49 32.82 -1.59 201.60 -1.35 32.73 1.62 4.38 212.52 28.88 147.89 MWD+SAG+IFR 10000.00 89.56 346.52 3806.26 33.28 -1.59 204.43 -1.35 33.19 1.62 4.43 215.18 29.14 148.16 MWD+SAG+IFR 10100.00 89.56 346.52 3807.02 33.73 -1.59 207.27 -1.35 33.64 1.62 4.47 217.84 29.39 148.43 MWD+SAG+IFR 10200.00 89.56 346.52 3807.79 34.19 -1.59 210.11 -1.35 34.10 1.62 4.52 220.51 29.63 148.68 MWD+SAG+IFR 10300.00 89.56 346.52 3808.56 34.65 -1.59 212.95 -1.35 34.56 1.62 4.57 223.19 29.87 148.93 MWD+SAG+IFR 10400.00 89.56 346.52 3809.32 35.11 -1.59 215.79 -1.35 35.02 1.62 4.61 225.87 30.10 149.18 MWD+SAG+IFR 10500.00 89.56 346.52 3810.09 35.57 -1.59 218.64 -1.35 35.48 1.62 4.66 228.56 30.33 149.41 MWD+SAG+IFR 10600.00 89.56 346.52 3810.86 36.03 -1.59 221.48 -1.35 35.94 1.62 4.70 231.26 30.55 149.65 MWD+SAG+IFR 10700.00 89.56 346.52 3811.62 36.49 -1.59 224.33 -1.35 36.40 1.62 4.75 233.97 30.76 149.87 MWD+SAG+IFR 10800.00 89.56 346.52 3812.39 36.95 -1.59 227.18 -1.35 36.86 1.62 4.80 236.68 30.97 150.09 MWD+SAG+IFR 10900.00 89.56 346.52 3813.16 37.41 -1.59 230.04 -1.35 37.32 1.62 4.84 239.39 31.18 150.31 MWD+SAG+IFR 11000.00 89.56 346.52 3813.92 37.87 -1.59 232.89 -1.35 37.78 1.62 4.89 242.11 31.38 150.52 MWD+SAG+IFR 11100.00 89.56 346.52 3814.69 38.33 -1.59 235.75 -1.35 38.24 1.62 4.94 244.84 31.57 150.73 MWD+SAG+IFR 11200.00 89.56 346.52 3815.46 38.79 -1.59 238.61 -1.35 38.70 1.62 4.99 247.57 31.77 150.93 MWD+SAG+IFR 11300.00 89.56 346.52 3816.22 39.25 -1.59 241.47 -1.35 39.16 1.63 5.03 250.30 31.95 151.12 MWD+SAG+IFR 11400.00 89.56 346.52 3816.99 39.71 -1.59 244.33 -1.35 39.62 1.63 5.08 253.05 32.13 151.32 MWD+SAG+IFR 11500.00 89.56 346.52 3817.76 40.17 -1.59 247.20 -1.35 40.08 1.63 5.13 255.79 32.31 151.50 MWD+SAG+IFR 11600.00 89.56 346.52 3818.52 40.63 -1.59 250.06 -1.35 40.54 1.63 5.17 258.54 32.49 151.69 MWD+SAG+IFR 11700.00 89.56 346.52 3819.29 41.09 -1.59 252.93 -1.35 41.00 1.63 5.22 261.29 32.66 151.87 MWD+SAG+IFR 11800.00 89.56 346.52 3820.06 41.55 -1.59 255.80 -1.35 41 .46 1.63 5.27 264.05 32.83 152.04 MWD+SAG+IFR 11900.00 89.56 346.52 3820.82 42.01 -1.59 258.67 -1.35 41.92 1.63 5.32 266.81 32.99 152.21 MWD+SAG+IFR OR/0""f ~ ~ì' .' ; I \,.,.).¡ . ' I . '" ) ) Baker Hughes Incorporaled Error Ellipse Survey Report Company: ConocoPhillipsAlaska, Inc. Field: Kuparuk River Unit Site: Pad·1 C Well: . 170 Wellpath: 1C-170 Vers#1 Date: 4/22/2003 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Sectìon (VS) Reference: Survey Cålculatìon Method: Time: 08:37:06 Page: 4 Well: 170, True North Wellhead(8T) 87.0 Well (0.00N,O.00E,333.47Azi) Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside---~ MD Inel Azim TVD Unc. Bias ft deg deg ft ft ft 12000.00 89.56 346.52 3821.59 42.47 -1.59 12100.00 89.56 346.52 3822.35 42.93 -1.59 12184.15 89.56 346.52 3823.00 43.31 -1.59 Lateral---~---> Unc. Bias ft it 261.54 -1.35 264.41 -1.35 266.83 -1.35 Vertical----> Unc. Bias ft ft 42.38 1.63 42.84 1.63 43.22 1.63 Magn~ Semi-major Semi:-minor ofBiasUnc. Unc~ AZÏlnuthToo) ft ft ft deg 5.37 269.58 33.15 152.38 MWD+SAG+IFR 5.41 272.35 33.31 152.54 MWD+SAG+IFR 5.45 274.68 33.44 152.68 MWD+SAG+IFR J f';~\ ~ -\ . l ¡;,\"I' \\'·.1 ; 11' ',." ~ . I~.I 0..".,:.. 0 ) ) ConocoPhillips Alaska, Inc. Pad lC 170 slot #170 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref lC-170 Version #1 Our ref prop5390 License Date printed 22 -Apr-2003 Date created 18-Feb-2003 Last revised 22-Apr-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.274,w149 29 48.084 Slot Grid coordinates are N 5968823.764, E 562068.419 Slot local coordinates are 1413.19 S 1063.43 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North oal (~¡; ¡ 1: L Onfr'~ """f í~ ¡; ",' ~ .. !, f""'il ~ I .~ i ,I î ~.:' 8 AA ·1 ~",1 1 ..;''' "'= All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from Est. RKB=87, (87.00 Ft above mean sea level). Bottom hole distance is 9513.81 on azimuth 333.47 degrees from wellhead. Total Dogleg for wellpath is 135.79 degrees. Vertical section is from wellhead on azimuth 313 .19 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C, 170 Your ref 1C-170 Version #1 Kuparuk River Uni t, North Slope, Alaska Last revised : 22-Apr-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 0.00 0.00 2.00 0.00 o .OON O.OOE 562068.42 5968823.76 n70 19 31.27 w149 29 48.08 500.00 0.00 2.00 500.00 o .OON O.OOE 562068.42 5968823.76 n70 19 31.27 w149 29 48.08 600.00 0.00 2.00 600.00 o .OON O.OOE 562068.42 5968823.76 n70 19 31.27 w149 29 48.08 700.00 2.00 2.00 699.98 1.74N 0.06E 562068.47 5968825.51 n70 19 31.29 w149 29 48.08 800.00 4.00 2.00 799.84 6.97N 0.24E 562068.61 5968830.74 n70 19 31.34 w149 29 48.08 900.00 6.00 2.00 899.45 15.68N 0.55E 562068.84 5968839.45 n70 19 31. 43 w149 29 48.07 1000.00 8.00 2.00 998.70 27.86N 0.97E 562069.17 5968851.63 n70 19 31. 55 w149 29 48.05 1100.00 10.00 2.00 1097.47 43 .50N 1.52E 562069.58 5968867.27 n70 19 31.70 w149 29 48.04 1200.00 12.43 352.88 1195.56 62.86N 0.49E 562068.40 5968886.62 n70 19 31.89 w149 29 48.07 1300.00 15.06 346.80 1292.69 86.19N 3.81W 562063.91 5968909.91 n70 19 32.12 w149 29 48.19 1400.00 17.81 342 . 53 1388.60 113 .43N 11 .3 7W 562056.13 5968937.09 n70 19 32.39 w149 29 48.41 1477.95 20.00 340.00 1462.34 137.33N 19.51W 562047.80 5968960.92 n70 19 32.62 w149 29 48.65 1500.00 20.71 338.51 1483.01 144.51N 22.23W 562045.02 5968968.07 n70 19 32.69 w149 29 48.73 1600.00 24.09 332.85 1575.46 179.13N 38.02W 562028.94 5969002.57 n70 19 33.04 w149 29 49.19 1700.00 27.62 328.54 1665.45 217.08N 59.44W 562007.22 5969040.33 n70 19 33.41 w149 29 49.82 1800.00 31.26 325.15 1752 . 53 258.16N 86.38W 561979.96 5969081.19 n70 19 33.81 w149 29 50.60 1839.46 32.71 324.00 1786.00 275.19N 98.50W 561967.70 5969098.12 n70 19 33.98 w149 29 50.96 1900.00 34.97 322.40 1836.28 302.18N 118.70W 561947.28 5969124.94 n70 19 34.25 w149 29 51. 55 2000.00 38.73 320 . 13 1916.29 348.91N 156.25W 561909.36 5969171.36 n70 19 34.71 w149 29 52.64 2099.76 42.52 318.21 1992.00 398.01N 198.73W 561866.47 5969220.11 n70 19 35.19 w149 29 53.88 2100.00 42.53 318.20 1992.18 398.13N 198.84W 561866.37 5969220.23 n70 19 35.19 w149 29 53.89 2200.00 46.35 316.53 2063.57 449.60N 246.28W 561818.52 5969271.31 n70 19 35.70 w149 29 55.27 2300.00 50.20 315.07 2130.11 503.08N 298.32W 561766.05 5969324.35 n70 19 36.22 w149 29 56.79 2400.00 54.06 313 .76 2191.48 558.29N 354.71W 561709.21 5969379.10 n70 19 36.76 w149 29 58.44 2500.00 57.94 312 . 57 2247.39 614.98N 415.19W 561648.29 5969435.29 n70 19 37.32 w149 30 00.20 2549.58 59.87 312.02 2273.00 643.55N 446.59W 561616.65 5969463.60 n70 19 37.60 w149 30 01.12 2550.96 59.92 312.00 2273.69 644.34N 447.48W 561615.76 5969464.39 n70 19 37.61 w149 30 01.14 3000.00 59.92 312.00 2498.75 904.34N 736.24W 561324.92 5969722.01 n70 19 40.17 w149 30 09.57 3202.00 59.92 312.00 2600.00 1021.31N 866.14W 561194.09 5969837.90 n70 19 41.32 w149 30 13.36 3300.00 59.71 307.47 2649.29 1075.44N 931.25W 561128.54 5969891.49 n70 19 41.85 w149 30 15.27 3400.00 59.65 302.84 2699.80 1125.12N 1001.80W 561057.60 5969940.60 n70 19 42.34 w149 30 17.32 3500.00 59.76 298.21 2750.26 1168.95N 1076.15W 560982.90 5969983.82 n70 19 42.77 w149 30 19.50 3565.12 59.92 295.20 2782.99 1194.25N 1126.44W 560932.41 5970008.70 n70 19 43.02 w149 30 20.96 4000.00 59.92 295.20 3000.98 1354.46N 1466.93W 560590.67 5970166.13 n70 19 44.60 w149 30 30.90 4313.26 59.92 295.20 3158.00 1469.87N 1712.19W 560344.50 5970279.53 n70 19 45.73 w149 30 38.06 4500.00 59.92 295.20 3251. 61 1538.67N 1858.40W 560197.75 5970347.13 n70 19 46.41 w149 30 42.33 4758.48 59.92 295.20 3381.17 1633.90N 2060.78W 559994.62 5970440.70 n70 19 47.34 w149 30 48.24 4800.00 60.54 296.97 3401. 79 1649.75N 2093.14W 559962.13 5970456.28 n70 19 47.50 w149 30 49.19 4864.44 61.54 299.69 3433.00 1676.51N 2142.76W 559912.30 5970482.64 n70 19 47.76 w149 30 50.64 4900.00 62.12 301.16 3449.79 1692.38N 2169.79W 559885.15 5970498.29 n70 19 47.92 w149 30 51.42 4956.95 63.08 303.49 3476.00 1719.42N 2212.51W 559842.21 5970524.98 n70 19 48.18 w149 30 52.67 5000.00 63.83 305.22 3495.24 1741.15N 2244.30W 559810.25 5970546.45 n70 19 48.40 w149 30 53.60 5100.00 65.65 309.16 3537.93 1795.82N 2316.31W 559737.81 5970600.52 n70 19 48.94 w149 30 55.70 5200.00 67.56 312 . 99 3577.65 1856.12N 2385.46W 559668.18 5970660.26 n70 19 49.53 w149 30 57.72 5300.00 69.57 316.71 3614.20 1921.76N 2451.42W 559601.69 5970725.35 n70 19 50.17 w149 30 59.65 5382.98 71.29 319.72 3642.00 1980.06N 2503.51W 559549.14 5970783.22 n70 19 50.75 w149 31 01.17 5400.00 71.65 320.33 3647.41 1992.42N 2513.87W 559538.67 5970795.50 n70 19 50.87 w149 31 01.47 5500.00 73.80 323.86 3677.11 2067.76N 2572.51W 559479.43 5970870.35 n70 19 51.61 w149 31 03.18 5600.00 76.00 327.32 3703.17 2147.40N 2627.04W 559424.26 5970949.54 n70 19 52.39 w149 31 04.78 5700.00 78.26 330.71 3725.45 2230.97N 2677.21W 559373.42 5971032.68 n70 19 53.21 w149 31 06.24 ) ) OR g(~"I " '\ ~ 11 ' ' : .; t !', J: I c; g ''f r:i , 'W All data in feet unless otherwise stated, Calculation uses minimum curvature method. Coordinates from slot #170 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 9513.81 on azimuth 333.47 degrees from wellhead, Total Dogleg for wellpath is 135.79 degrees, Vertical section is from wellhead on azimuth 313.19 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad lC, 170 Your ref lC-170 Version #1 Kuparuk River Unit, North Slope, Alaska Last revised : 22-Apr-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Eas t ing Northing COO R DIN ATE S 5800.00 80.55 334.04 3743,84 2318.04N 2722.76W 559327.16 5971119.38 n70 19 54.07 w149 31 07,57 5874.75 82.28 336.51 3755,00 2385.17N 2753.67W 559295.71 5971186.24 n70 19 54.73 w149 31 08.48 5900.00 82.87 337.33 3758.26 2408.21N 2763.49W 559285.71 5971209.20 n70 19 54.96 w149 31 08.76 5974.75 84.63 339.77 3766.40 2477.36N 2790.65W 559257.99 5971278.12 n70 19 55.64 w149 31 09.56 6000.00 85.22 340.59 3768.64 2501.02N 2799.18W 559249.27 5971301. 71 n70 19 55.87 w149 31 09.81 6100.00 87.58 343.83 3774.92 2596.04N 2829.66W 559218.02 5971396.46 n70 19 56.80 w149 31 10.70 6183.52 89.56 346.52 3777.00 2676.74N 2851.02W 559196.00 5971476.98 n70 19 57.60 w149 31 11.32 6183.54 89.56 346.52 3777.00 2676.76N 2851.03W 559196.00 5971477.00 n70 19 57.60 w149 31 11.32 6500.00 89.56 346.52 3779.43 2984.49N 2924.79W 559119.74 5971784.09 n70 20 00.62 w149 31 13.48 7000.00 89.56 346.52 3783.26 3470.70N 3041.34W 558999.25 5972269.29 n70 20 05.41 w149 31 16.88 7500.00 89.56 346.52 3787.09 3956.91N 3157.89W 558878.76 5972754.50 n70 20 10.19 w149 31 20.29 8000.00 89.56 346.52 3790.92 4443.12N 3274.44W 558758.28 5973239.70 n70 20 14.97 w149 31 23.70 8500.00 89.56 346.52 3794.76 4929.33N 3391. OOW 558637.79 5973724.90 n70 20 19.75 w149 31 27.11 9000.00 89.56 346.52 3798.59 5415.55N 3507.55W 558517.30 5974210.10 n70 20 24.53 w149 31 30.52 9500.00 89.56 346.52 3802.42 5901.76N 3624.10W 558396.81 5974695.30 n70 20 29.31 w149 31 33.93 10000.00 89.56 346.52 3806.26 6387.97N 3740.65W 558276.33 5975180.50 n70 20 34.09 w149 31 37.34 10500.00 89.56 346.52 3810.09 6874.18N 3857.20W 558155.84 5975665.70 n70 20 38.88 w149 31 40.75 11000.00 89.56 346.52 3813.92 7360.39N 3973.75W 558035.35 5976150.90 n70 20 43.66 w149 31 44.16 11500.00 89.56 346.52 3817.76 7846.60N 4090.30W 557914.86 5976636.10 n70 20 48.44 w149 31 47.57 12000.00 89.56 346.52 3821.59 8332.81N 4206.85W 557794.37 5977121.31 n70 20 53.22 w149 31 50.98 12184.13 89.56 346.52 3823.00 8511.87N 4249.77W 557750.00 5977299.99 n70 20 54.98 w149 31 52.24 12184.15 89.56 346.52 3823.00 8511.88N 4249.77W 557750.00 5977300.00 n70 20 54.98 w149 31 52.24 li f : : I -~ r '" O j~! .(1 . i""'! ,il Ii >.: " ~ ~ :~(.,.~ 2851.03W 17-Feb-2003 4249.77W 17-Feb-2003 2676.76N 8511.88N WS V9 D-HEEL RVSD 10 559196.000,5971477.000,2.0000 3777.00 WS V9 D-TOE RVSD 10 557750.000,5977300.000,0.0000 3823.00 - - - - - -- -- - - --- - - - - - - - -- - - -- ----- - - - --- - - ---- - --- - ------- --- -- - ----- - - ----------- - -- - - - ---- ------ - - -- -- - ---- Revised Rectangular Coordinates T.V.D. Geographic Location Target name -- -------- - -- - ---- --- --- -- ------- - --- -------------- ------- --- -- ------- - --- Targets associated with this wellpath 4249.76W 4 1/2" Liner 2790.65W 7 5/8" Casing 8511.84N 2477.36N O.OOE 12184.10 3823.00 O.OOE 5974.75 3766.40 O.OON o .OON 0.00 0.00 0.00 0.00 ----------------------------------------------------------------------------------------------------------- 600.00 600.00 O.OON O.OOE KOP 1100.00 1097.47 43.50N 1. 52E Build/Turn 3/100 1477.95 1462.34 137.33N 19.51W Build/Turn 4/100 1839.46 1786.00 275.19N 98.50W Base Permafrost 2099.76 1992.00 398.01N 198.73W Top T-3 2549.58 2273.00 643.55N 446.59W Top K-15 2550.96 2273.69 644.34N 447.48W EOC 3202.00 2600.00 1021.31N 866.14W Beg in Turn 3565.12 2782.99 1194.25N 1126.44W EOC 4313 .26 3158.00 1469.87N 1712.19W Top Ugnu C 4758.48 3381.17 1633.90N 2060.78W Begin Final Bld/Trn 4864.44 3433.00 1676.51N 2142.76W Top Ugnu B 4956.95 3476.00 1719.42N 2212.51W Top Ugnu C 5382.98 3642.00 1980.06N 2503.51W K13 5874.75 3755.00 2385.17N 2753.67W Top West Sak D 5974.75 3766.40 2477.36N 2790.65W 7 5/8 CSG 6183.52 3777.00 2676.74N 2851. 02W WS V9 Heel Tgt - EOC 6183.54 3777.00 2676.76N 2851. 03W WS V9 D-HEEL RVSD 10 APR 03 12184.13 3823.00 8511.87N 4249.77W TD - 4 1/2" Liner 12184.15 3823.00 8511.88N 4249.77W WS V9 D-TOE RVSD 10 APR 03 Casing positions in string 'A' ----- --- --- ------- ------ --- --- ----- --- -------- --- ----- --- --- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD ----- --- - --- -------- -----'--------------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref 1C-170 Version #1 Last revised : 22-Apr-2003 ConocoPhillips Alaska, Inc. Pad 1C, 170 Kuparuk River Unit,North Slope, Alaska ') ) ) ') ConocoPhillips Alaska, Inc. Pad 1C 170 slot #170 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref 1C-170 Version #1 Our ref prop5390 License Date printed 22-Apr-2003 Date created 18-Feb-2003 Last revised 22-Apr-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.274,w149 29 48.084 Slot Grid coordinates are N 5968823.764, E 562068.419 Slot local coordinates are 1413.19 S 1063.43 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North O r~ t I .' I. """.".i;~ i ~""" r ~ 'j ~: ~\ /1 , ~ - RECEIVED APR 2 8 2003 Alaska Oil & Gas Cons. Commission Anchorage ~ ï s. K. AllSUP-DRAKE 1 038 ~,...? I,; PHilliPS PETROLEUM COMPANY '-_ (I lWc~g~J~Ä~. 501. . . . .. . DATE Ar. r;! ~ UOJ'41311 ~. I ¡ I :;~~~¡;~E /) .5-rrrefFfl.-Æ<:;fA (fl-CY¡CC / I $ (00. 00 ~ I _ .. r--/Jt.b~~!~~r-ð(IDØ UULLA~ tÐ ~~::' f I.,',· ~ CHASE Chase Manhattan Bank USA, N.A. VaJiLUP T 5000 Dollars t.,~..~_"-_'..'.'..'.' . .., ~~~""._~,_",u", ! /Î ~ (f.~_-.' I MEMO (G-lJQ , A. .II~r¡7?·~ ~ i 1:0 ~ . .00 ¡.... ....: 2.80000 L, 27 25 7"·.038 ~ ~;'~~?----<f:~- o-__-_.t'--_~"-_.:_=?;--'-~fZt~--~:~:'""'.~."'-::--~,"--3~.-_:=-"tf,";'?:~':~:>:;-'~~'::'':'''_''''~_'':'':.~?~~-ó';¡;~~~~:~;''~'7_~~·.".::)'"~.--:p''-,-~_~~~r4':-:~.:--:¿"t;-~~-~~ _-::"~:-r~,,,-;:-_--·.:j~ß>;;f._~.'(~ -¡.~-~.",-~_'.~~~f'~~_~-'.'-¡;"'< _.-_-,,_.~ ~~...,r;off~7~-"':;'F_~""· 1¡ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME I<RLl IC-- (70 ~3-D7B PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) paOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to, be reported 'as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~ã~ç.~~~.~~!~::~H'~~~~'~Ir.; Company_"C_Qt~tO_C_Q~tlJlLl.e_S_8J,hSJ~8JJ~tC______ Well Name: KUE8RI..U{BIY_lLWSAK___:tÇ:.1.IQ_._._''_''__ Program QEY Well bore seg D PTD#: 2030780 Field & Pool J~.W~.8.RUJi..Hl\LEBO-WE.$.J_SA~_QLL.:_~t9_0j_50 Initial ClassfType __DE-\LLt:QLL- GeoArea _R9.Q Unit jJJ_5_0_ On/Off Shore QD__ Annular Disposal D Administration 11 p~unitfe~ attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ , ' , _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ . _ _ . . , . _ _ . _ _ _ _ _ . . 12 _Leas~m,Jmb~rpppropriat~_ _". ,,_ _. _ _ _ _ _ No_ _ _" _" _ _AOL0256.49contains"s~.:face-'oc_andtopprod.int~rva.l;TD.isinADL025638." __ l~ ~~~~:;:~n;~:ßd-:~~e~U;~:~{ - - - - - - - - : : - : : : : - - - - - - - - - - - - - - - - - - - - - - : ~:: : : : : : - : - - - - - - - - - - - : : : : - : : - : : : - : : - - - - - - - - - - - - - - - - - - - - - : : - - - : - - - - - - - - - - - - - - - - 115 WeJI Jo'cated prpp~r distance from. drilling unitbpundary _ _ _ _ _ _ . . Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . , _ _ . _ _ _ _ _ _ _ _ _ 6 WeJI Jo_cat~d prpp~r distance_ from. QtheJ wells. _ _ _ _ _ _ _ , _ , , _ _ _ . _ Y~s . _ _ . _ . _ ,,_ _ . _ _ , _ . , _ _ _ _ _ _ _ _ _ _ . _ _ , , , _ . _ . . _ _ _ _ , _ . . _ _ _ _ . _ _ ' , , _ _ , , , , , , _ _ , _ _ _ _ _ 7 _Sufficient pçreage "available i_n.dril.\iDQ. unit. _ _ , , _ , , _ _ _ _ . _ _ _ _ . _ . _ _ _ _ ' _ _ _ Yes . . _ _ _ _ _ . _ _ _ . . . _ . . , _ _ _ _ _ _ _ . . _ . . . _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ . , . _ _ ' _ 8 Jf.deviated, is.wellboJe plaUnc!uç.led _ _ _ _ _ _ _ _ _ ' _ _ _ _ _ , _ _ Yes _ _ _ . _ _ _ _ _ . , , _ _ , , _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 9 Qperpto[ only i:!ffeçted pa.rty. _ _ _ _ _ _ . _ ' , _ ' , . _ _ _ _ _ _ _ _ _ . _ _ _ ' , ' , , , , _ _ , , _ Yes" , , . , , _ , , . , . _ . , . . , , . , _ _ _ , , , , . _ , _ , _ . ' _ _ _ _ , , , . . ' _ . , , , , _ _ , _ 1 0 .oper.ator bas.appropriate.b.ond in .fQrce_ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ . . _ . . . . . . . Yes _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ _ . _ _ . . _ . . _ . _ _ _ _ _ . . . . _ . _ _ _ 11 P~unit,cpo be issu_ed witho"ut conS~l"\{ation Qrd~r _ . _ ' _ _ _ , _ _ _ _ _ . _ _ , ' , ' , _ _ , _ _ _ . Yes _ _ _ , _ _ _ _ _ _ _ . _ _ . . . . _ . _ _ _ _ _ _ _ , _ _ _ _ _ ' , . . _ _ _ . _ _ . ' _ ' _ _ , , . _ _ _ , . .. _ _ _ , _ , , _ Appr Date 12 P~rmitcPo be issu.ed witho"ut admini$tr:ativ.e.approvaJ _ , , , , _ _ _ _ ,,_ _ ' _ ' , , , _ , _ Yes" , , . - - - - - - - - - - - - - - - , - - - - - - - - - - - . - - . . - - . - - - - - - - - . - . . - . . - - . , - - - - . - - ' - ' - - - - - - - SFD 5/6/2003 13 Can permit be approved before 15-day wait Yes (' 14 WeJIJo"catedwithinareaand_strataauthQrizectby.lojectioDQrder# (putlO# in.cpmmeotS).(For. NA..".. _"" _ _. _.. _..... _... _ _.... _..... _ _. _. _ _ _. _ _.. _... _...." _..""". _. _. _.. _."" 15 All wells.within.1l4_llJile_are.a.ofreyiew ideotified (For:s.ervjce welJon.IYL. _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ _ _. _.... _.. _ _ _ _ _ _.. _ _. _.. _ _. _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _. _ _ _ _.. __ 16 Pre.-produced_ injector~ ç.I\,!ratjo.n.of pre-proç.l\'!c.tiOD less.than.3. mon.ths.(For.seryiçe well_Qn!y) . . NA. . . . . . . , . , _ . . _ , . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ . . . . . _ . _ _ _ _ _ . _ . . _ . . . _ _ . _ . . _ _ . . . . _ . . . _ _ _ _ _ . _ . 17 ACMP.F.in.ding "of CQnsisteocy.hps been ,is"suedJor.tbis prpject . _ ' . . . . . _ . . . . . . _ . . . NA. . . . , _ _ . , . , . _ . . . . _ . _ . . . . _ . . . _ _ . . . . _ . . . . _ _ . . . _ . . . _ _ . . .. . . . . . . . . _ . . . .. ".""". _ . Engineering 18 .c.poduçtor $tr:in-9.Pfovided _ . . . .. .. . _ , . . . . . . _ . . . . . . . . _ . , . . . _ . . . . . . . . . . Yes _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . _ . . . . . . . . . . . . _ . . _ . . . . . . . . . . . _ _ _ 19 .S.ur:face.cas,ing.PJQtects.all.known_USDWs...".. _.".. _. _....". _ _"" _.".. _ _ NA....... .AllaquifeJsex.empted4QCfR147,1.02.(b)_(3.L _""" _.. _. _". _.".. _ _.. _ _...... _." _...""" 20 .CMT.vPl.a.dequ.ate.to ci(cul.ate.on _con.d.uetor.& $u.rf.CSg . . . . . . . . . . _ . _ _ _ . . . . _ . . _ . Yes. . . . . . . $u.rf"aç~ ça$ing is.the.on!y"casilJg. , _ . . _ . . . . . . . .. . . _ _ _ _ . _ , _ _ .. , . . . .. . . . .. . .. , .. _ . . . _ . . _ . , 21 .CMJ.vpl.a.dequ.ate.to tie-in .long stri[1g to.s!,1I1 C$.g. . . .. _ . . _ . . . . . . . . _ . . , . . . . . .. . . NA . . . . _ . . ODly 1 casing .stri[1g plçll1ned.. . . . . . . . . . .. . . . . . . . . . . . . . _ . . . . . . . . . . . . . . _ . . . . . , _ .. .. . . 22 .CMJ.wiHçoyer.a!l!<l1own"produc.tiyeborilQn$.. _...."".............. _...".. _" N.o...." _.. .$lottedJio~r.pta[1Ded.. _ _. _..... _. _.................. _....................."..... 23 .C_asiog de.sigos ad_equat~ for: C, To B .&.p.ermafr.pst. . . , ' _ ' . . . . . . . . .. . . . _ . , _ . ' , _ .Yes. . _ . . . . . . . . . . . _ . . _ . , . . . . . . . . _ , . . . , . . , . _ . . . _ . _ , . . . . . . . _ . . . . . . . . . . . ." _ _ _ _ . _ _ _ 24 Aoequate.tankage.one.serye pit. . . . . _ ~ . . . . . , . _ . . . . . . _ . . . . . _ . , . . . ' . . . Yes. . . .. . . . Big .e.quippe.d.wittl steel.pits. . No.re$e.rv.e.pjtpta(lDe.d.. Prig waste to.a[1 ppprov.ed ponulus.pr Class.lI.weJI.. _ . . _ . 25 _If,a.re-orill, bi:!s.a. 1.0:4.03 fOJ aba.ndonm.ent be~o approved , _ . . . . . . . . _ . . .. . , , . . . . _ NA .. . _ . . . . . . . . . . . . . . , . . . . . " . . _ . . . . . . . .. " . . . .. . _ . .. .. . . . . . . . . . . . . . . . . . . _ . . . . . , . _ . . . 26 Aoequate _V(ellQ,ore_ s.eparç¡tion p(op9seO. _ . _ .. . .. _ _ _ . .. _ _ _ . " . . .. . _ _ _ _ _ _ .. _ _ _ . _ .Yes _ _ _ _ _ . . I?rp~imity_ c.alclJlatjo.n p~r:forl)1ed. _ Welts jd"entjfieçl. _ Gyros po.s$ible.. . . _ _ .. _ . _ _ _ . _ _ . _ _ _ _ . . _ . _ _ . . . _ 27 .If.diver:t~r f~q.!Jir~d. do.e$ it m.eet.reguJa.tiOl1s. . . .. . . . . . . . . . . . . . . . . .. .. . . . . . . . . . Y~$ . _ . . . . . _ . . . . . . . . " . . . _ . _ . . _ . . . . . _ . .. . . . . _ . , _ _ ' _ . . _ . . .. _ . . . . . . . . . . . . . . . . . _ . , . . . Appr Date 28 .DrilJilJg. fluid.prQgra.m sc.hemati.c..& ~qJJip Jist.adequate. . . . . _ .. . .. .. . . . . . _ . . . . . . _ . . Yes. . . . . . . Maximum expected BH~ 8.8.. Plann.ed mud weigbt.9,2, , . _ . , . .. . .. _ , , _ . . . . . . . . _ . . . . . . . , _ _ . . . TEM 4/29/2003 29 .BOP!=s,.do _they .m.eet.reguJation _ . . . . . .. _ . . . . . _ ' _ . _ _ . . _ _ . . . . . . . . . . . . . _ Yes. ,,- . . . . . . . . . . . . . . . - .- . . . . . . - . . . . . . . . . . . . .. . . . . . . - .. . . .. . . . . , - . . . , . , , , . . - .. . . , - , f 30 .BO'p!=_pre_s$ratiogapp(opriate;.t~stt'p.(putpsigin.coml)1ent$)........... _........ _ .Ye$. _.... .MAS~calc.u!ate.d.at12"50p$i.. 350.0.psi.s.u{ficien.t.~pc.o.li!<ely.t.p.testto.50QO.psj.......... _... _...".. __ 31 .C.hoke"ma"nifold compHes_ w/API.RP-53. (May 84). . . _ . . . . . . . . . _ . . . _ . . . . . . . _ . . .Yes. ." . . .. . . . . . . . . . _ . . . .. . . . . _ . . . . . . . . . .. . . . . . . . . . . . . . . . _ . . _ . _ . . . . _ . . . .. . . _ . .. _ . " _ _ . 32 Work. will occur withollt.operation .sbutdown. . _ . . .. ' . . _ . _ . . . . . . . . ." . . , _ , ' . . . Yes. _ . _ . . . . . . . . . . . . . . . . . . _ . . . . _ . .. . , . .. _ .. . . . . . . . _ . . . . . . . . _ . . , . . , . . . ' . . , , . " _ . 33 Js.pres"etlce.oJH2$gas.prQb.able.".. _........... _.."........."........ _ N.o.."... _ .Mudsho\,!ldpreclud.e.H2.S.o.nJig.. Rig.iseq.uipped.with_sensprs.andalar:ms,... _........ _. _..." _.... 34 Meçha"ni,cal.c:)I)djti..o[1 Pf. w~.lIs with,in AOR v~rified. (For. service weU only) , , , , , _ , _ . . _ , . . NA , . . . . , , ' . ' , ' , , , _ , , . ' . , , . , . . , , , , . .. , . .. , , , , , _ _ ' '" ,,_ _ _ . . . . . . _ . _ . . . . , . , , ' . , . . . . ---_._--,------- ------- Appr SFD Date 5/6/2003 35 Permit,cpo be i.ssu_ed w!o_ hydr.og~n..s.uIJide measures. . . _ _ . . _ . . . . , _ . , _ . . . . . . _ _ Yes. . , . . . . ~o tl2$ is .koownjn West.S_a~ OU,..but rjg.i$ equipped. with_seos.ors!aJarms & .H2$ readiJy_s.cav.engeJ a\la_ilabJ~. " . _ 36 .D"at.a.pJ~sel1ted. on. p_ote_ntial O\lerpres.sureZOnes" ' , , _ , , . . . . . . . , . , . .. . ' _ . , . ' , , Yes" _ , . . . . Expected_ rese_r\(ojr pressure is 8..2,,- ,,8,8_ppg !=MW.. , . . . . . . . . . . . .. .. _ , , , , , , , , , , . ' , . . _ _ , , , _ . 37 Seismi,c.analysjs.Qf sha.llow gas.zooe.s. .. . _ . . . .. . . . _ . . . .. _ _ . ' _ . . _ , , . , , _ , . _ ". NA . . . . . . _ ' . _ , . _ , , _ _ . , ' . ' _ , _ . , . , . , ' _ . . . . .. . . . . . . . . . . . . . . , . , , ' , ' , , . 38 .SeaQ,eO .conditiOIJ su.l"\{ey .(if off-shore) . . . . . _ , , , . . .. . .. .. . _ . . _ . . . . . . . . . . .. . . . NA _ . _ . . . . . . . . . . . . . . _ _ . . . . _ _ . . . . _ . . .. . . . . . . . . . . . . .. . . . . . . ." . . . _ . . . . . _ . . . .. _ . 39 . Co.ntaçt nam.elphoneJor .weekly. progress.reports [e~plorªtory .0[1ly). , , . _ _ , , . , . . . . . . . NA , , , , , , ' , , ' , . , _ . . . . . _ . . , _ _ . _ , . . , . . . . _ , , , , . , , , _ ' , , , ' , . _ . . . . . . . _ , , .. . , , , , . . . _ _ . Geology Geologic Commissioner: Date: ~ Oß/ð7';63 Engineering Commissioner: Date Public Commissioner Date ) ) Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ()03 ~olfš' ) I) oS-vI **** REEL HEADER **** LDWG 03/06/12 AWS 01 **** TAPE HEADER **** LDWG 03/06/12 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA LDWG File Version 1.000 Extract File: LISTAPE.HED lC-170PB1 500292315470 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 12-June-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 F. WENDLER D. WESTER MWD RUN 2 2 G. SUTING D. HElM MWD RUN 3 3 G. SUTING D. HElM # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11N 10E 87.00 59.00 RECEIVED # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) JUN 1 6 2003 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 6.750 7.625 6010.0 7328.0 Aiaska 0;'; & Gas Cons. Commieeion Ancnorane '" # REMARKS: PER CONOCOPHILLIPS ALASKA REQUEST, THE GAMMA RAY ~~'Dv~\~ 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILE001.HED *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 82 records... Tape Subfile: 1 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 19' 31.274" LONG: W149 DEG 29' 48.084" LOG MEASURED FROM D.F. AT 87.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized NaviTrak Directional only services from 120 - 2748 feet MD (120 - 2415' TVD). (2) Baker Hughes INTEQ run 2 utilized AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity services from 2748 - 6020 feet MD (2415 - 3764' TVD). (3) Baker Hughes INTEQ run 3 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 6020 - 7328 feet MD (2415 - 3770' TVD). REMARKS: (1) Commenced LWD logging at 2665 feet MD (2375' TVD) (2) Depth of 7 5/8" Casing Shoe - Logger: 6014 feet MD (3764' TVD) Depth of 7 5/8" Casing Shoe - Driller: 6010 feet MD (3763' TVD) Please note that due to the change in Resistivity tools, from RNT to MPR, that the presentation goes from 2 resistivity curves to 4 resistivity curves at 6010 feet MD (3763' TVD). (3) Gamma ray readings are suppressed at the beginning of run 3 as it was recorded behind casing from 5990 - 6012 feet MD (3761 - 3764' TVD) (4) The 6 3/4" hole section was drilled to 7328 feet MD (3780' TVD) when it was decided to perform an open hole sidetrack at 7094 feet MD (3776' TVD). (5) The interval from 7301 to 7328 feet MD (3781-3780 TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) ) FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 2665.0 STOP DEPTH 7328.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2665.0 6020.0 MERGE BASE 6020.0 7328.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. The data curves RPM & RPX are empty (null) above 6010' MD due to the change in resistivity tools. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc170pbl 5.xtf 150 - ConocoPhillips Alaska, Inc. lC-170PBl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN 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 ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME MSB 18704 6 . 75 ATK MEMORY 6020.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 18-MAY-03 STOP DEPTH 5988.0 START DEPTH 2665.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 2 !! !!! ! ! !! !! !! !!! !!! LDWG File Version 1.000 ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 379 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 2665.000000 7328.000000 0.500000 334 Total Data Records: Tape depth ID: F 8 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 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 ) 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 RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVI. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ) 2665.0 5988.0 o 59.0 84.0 TOOL NUMBER SHE 17834 RNT 20046 RNT 20046 9.875 .0 Spud Mud 9.15 .0 .0 400 .0 .000 .000 .000 .000 98.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT (AutoTrak) MWD run 1 was directional only. Therefore no data is presented for run 1. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1c170pb1.xtf LCC 150 CN ConocoPhillips Alaska, I WN FN COUN STAT 1C-170PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 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 8 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 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 475 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2665.000000 5988.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 567 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes 85.0 .0 .0 .0 .000 .000 .000 .000 Flo Pro NT 9.25 .0 .0 35000 .0 6.750 6010.0 TOOL NUMBER SDS 27093 MPR 1023 SRIG 60365 85.2 92.4 MSB 18704 4.75 MPR MEMORY 7328.0 5988.0 7301.0 o 22-MAY-03 NEUTRON TOOL MATRIX: # 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: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # # 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: STOP DEPTH 7328.0 START DEPTH 5988.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SU:M:MARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 3 .2500 3 ! !!! !!! !!! !!! !!! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** ) ) ) # MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # .0 o BIT RUN 3 (MWD Run 3) . GR/MPR CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc170pbl.xtf 150 ConocoPhillips Alaska, I lC-170PBl 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 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 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 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHl1M 4 4 3 RPSL MWD 68 1 OHl1M 4 4 4 RPCH MWD 68 1 OHl1M 4 4 5 RPSH MWD 68 1 OHl1M 4 4 6 RACL MWD 68 1 OHl1M 4 4 7 RASL MWD 68 1 OHl1M 4 4 8 RACH MWD 68 1 OHl1M 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 283 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5988.000000 7328.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 382 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/06/12 01 **** REEL TRAILER **** LDWG 03/06/12 AWS 01 ) Tape Subfile: 5 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes ) âÔ3-07-P( ) )À-()~) **** REEL HEADER **** LDWG 03/06/12 AWS 01 **** TAPE HEADER **** LDWG 03/06/12 01 *** LIS COMMENT RECORD *** !!!! ! ! !!!!!! ! ! ! !! !! 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 lC-170 500292315400 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 12-June-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 F. WENDLER D. WESTER MWD RUN 2 2 G. SUTING D. HEIM MWD RUN 3 3 S. DRAKE D. HEIM # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 IIN 10E RECEIVED JUN 1 6 2003 87.00 59.00 Al88ka 0i1 & Gas Cons. Commiseicn Andlorage # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 6.750 7.625 6010.0 12230.0 # REMARKS: PER CONOCOPHILLIPS ALASKA REQUEST, THE GAMMA RAY ~~' .' r\ ~ ~\\"\,~ 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILE001.HED *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 82 records... Tape Subfile: 1 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 19' 31.274" LONG: W149 DEG 29' 48.084" LOG MEASURED FROM D.F. AT 87.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized NaviTrak Directional only services from 120 - 2748 feet MD (120 - 2415' TVD). (2) Baker Hughes INTEQ run 2 utilized AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity services from 2748 - 6020 feet MD (2415 - 3764' TVD). (3) Baker Hughes INTEQ run 3 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 6020 - 12230 feet MD (2415 - 3798' TVD). REMARKS: (1) Commenced LWD logging at 2665 feet MD (2375' TVD) (2) Depth of 7 5/8" Casing Shoe - Logger: 6014 feet MD (3764' TVD) Depth of 7 5/8" Casing Shoe - Driller: 6010 feet MD (3763' TVD) Please note that due to the change in Resistivity tools, from RNT to MPR, that the presentation goes from 2 resistivity curves to 4 resistivity curves at 6010 feet MD (3763' TVD). (3) Gamma ray readings are suppressed at the beginning of run 3 as it was recorded behind casing from 5990 - 6012 feet MD (3761 - 3764' TVD) (4) An open hole sidetrack was performed in the 6 3/4" hole section at 7094 feet MD (3776' TVD) off the original wellbore of 1C-170PB1. (5) The interval from 12203 to 12230 feet MD (3798-3798 TVD) was not logged due to sensor-bit offset at TD. $ ) ) FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 2665.0 STOP DEPTH 12230.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2665.0 6020.0 MERGE BASE 6020.0 12230.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. The data curves RPM & RPX are empty (null) above 6010' MD due to the change in resistivity tools. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc-170 5.xtf 150 ConocoPhillips Alaska, Inc. lC-170 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN 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 ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE # 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME MSB 18704 6 . 75 ATK MEMORY 6020.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 18-MAY-03 STOP DEPTH 5988.0 START DEPTH 2665.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 2 ! ! !! ! !! !!!! !!!!!! !! LDWG File Version 1.000 !!!! !! !!!! ! !! ! !! !!! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 729 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2665.000000 12230.000000 0.500000 684 Total Data Records: Tape depth ID: F 8 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 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 ) ) ') 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 RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVI. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ) 2665.0 5988.0 o 59.0 84.0 TOOL NUMBER SHE 17834 RNT 20046 RNT 20046 9.875 .0 Spud Mud 9.15 .0 .0 400 .0 .000 .000 .000 .000 98.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/RNT (AutoTrak) MWD run 1 was directional only. Therefore no data is presented for run 1. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MN"EM VALU -------------------------------- WDFN lc-170.xtf LCC 150 CN ConocoPhillips Alaska, I ) ) WN FN COUN STAT 1C-170 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 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 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OH!'1M: 4 4 3 RPCH MWD 68 1 OH!'1M: 4 4 4 RACL MWD 68 1 OID1M 4 4 5 RACH MWD 68 1 OH!'1M: 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 475 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2665.000000 5988.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 3 567 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes 88.0 .0 .0 .0 .000 .000 .000 .000 Flo Pro NT 9.25 .0 .0 32000 .0 6.750 6010.0 TOOL NUMBER SDS 27093 MPR 1023 SRIG 60365 84.0 92.4 MSB 18704 4.75 MPR MEMORY 12230.0 5988.0 12203.0 o 24-MAY-03 NEUTRON TOOL MATRIX: # 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: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # # 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: STOP DEPTH 12230.0 START DEPTH 5988.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 3 .2500 3 ! !!! !! !! !!!! ! !! ! !!! LDWG File Version 1.000 ! !!! !!!!!!!! ! !! ! !!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** ) ) # MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 .0 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o REMARKS: # BIT RUN 3 (MWD Run 3) . GR/MPR CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc-170.xtf 150 ConocoPhillips Alaska, I lC-170 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 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] :> '\I ) Number of frames per record is: 19 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 12 Curves: Name Tool CQde 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 OHl1M 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1315 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5988.000000 12230.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1414 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/06/12 01 **** REEL TRAILER **** LDWG 03/06/12 AWS 01 ¡ '. ) Tape Subfile: 5 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes