Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
207-143
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-10_16030_KRU_1J-174_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16030 KRU 1J-174 50-029-22374-00 Production Profile 10-May-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 207-143 T40437 5/21/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.21 12:31:46 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS n 1116. X.0"9 \4 L. L�# MAY 2 9 2019 11 rN r" 1-%C` 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E] Oper`a ion3"sti d n ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Slratigraphic❑ Exploratory ❑ Service ❑ 207-143 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23374-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU U-174 ADL 25660, ADL 25661, ADL 25663, ADL 385172 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 19,708 feet Plugs measured None feel true vertical 3,157 feet Junk measured None feet Effective Depth measured 9,706 feet Packer measured 11,358 feet true vertical 2,930 feet true vertical 3,128 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 feet 20 120' MD 120' TVD SURFACE 3,971 feet 13 3/8 " 4,021' MD 2272' TVD Production 3,886 feet 10 3/4 " 3,927' MD 2249' TVD PRODUCTION 12,040 feet 95/81, 12,080' MD 3206' TVD B -SAND LINER 8,240 feet 5 1/2 " 19,657' MD 3156' TVD Perforation depth: Measured depth: 12245-19568 feet True Vertical depth: 3216-3155 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 11,358' MD 3,128' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER MLZXP Liner HangerPckr 11,307' MD 3,121' TVD SSSV - NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 69 238 11 800 160 Subsequent to operation: 210 771 36 800 160 14. Attachments (required Fer20 AAC 25.070,25o71, 825.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development EI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil [2] Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 319-006 Contact Name: James Hayes Authorized Name: James Hayes Contact Email: James.C.Hayes@cop.com Authorized Title: Sr. Wells Engineeer �7 � �,/��,-f Date: Contact Phone: (907) 265-6927 � IZ %//Y Authorized Signature: � Form 10-404 Revised 4/2017' 6/�//9 Ll/,l� RBDMS!K'VMAY 3 0 2019 Submit Original Only KUP PROD WELLNAME 1J-174 WELLBORE 1J-174 le" r'� h �" COIl000P1)ll)Ps Well Attributes Max Angle & MD TO Dead Name WellboreAPWWI WeI1Wre5btuz MDIk"Bj AllSun(PON Alaska, Inc L2 9'9 WEST SAK 50029233)400 PROD 2.99 t9 D8.18 19,]08.0 Comment H26(Pann) 10 Gare Mnroanrn Ertl Oa,e nDG,tl tn) Rg Release Date 11/8/2014 Last WO'. 9)8)2012 4441 12131/2007 MULTIPLEIAIERALb- 1J174,a2a'N19NXl32AM Last Tag VarOule[MmvtictabY) Annoboor mori am EMD.. Wellnore Last Mod By UNITS, 1J-1]4 lumosoor Last Rev Reason Annabtion EM Deh wwarPo 1 Last Med By Rev Real Set OV B Run Catcher Is,11..019 11-114 jearbaig Casing Strings Ceaereso,iptlor Cape) ID (mI ToptrcKB) CONDUCTOR 20 19.12 449 Sel ceptn lM1Ka) get Dapm (NO1.. 120.0 1200 wuLen p... Gryfe 94.00 H-00 ropmread Welded Casing Den-ripts. OD lin) IO pnPMKB) Sat Depth(tIKB) $M Depth(TVO)... mise p... Gree Top Tnread SURFACE 13318 12.41 49.5 4,020.5 2,212.5 68.00 LSO BTC LONDLCTOR:44N200 Casing Dewrlptianpn) TOP(lNB) PRODUCTION 9518 883 40.4 Set Oepto(NDB) last Leon (I 12,080.0 3,205.9 -Iver (I...GrM n a 4000 L-80 To p TMW BTCM 10.7519625' a,Ae-3MT D0533.3 AmJVFLN-DIxM;3es Csslryl Description OD (is) 10 (n) Topbson BSAND LINER 5112 4.95 11,4166 last DUAIN DUKE) set pep. lrvOl... 19,656.5 3.156.3 WaLan p.,.Gbde 15.50 L-80 Top TMea4 BTC -m 3250aedea-Ale AmuLr Fuel -D.;9AS Liner Details 3.250.0:M9201e NominallD T<uq-Maese.2.325a Toptran Top(1VD)MR) Topli Ibm Des Lom lin) 11,4166 3,134.6 05 HANGER BAK R L LINER HAN ER PA KER-Langth 7000 above Collet Unable 11,429.4 3,1362 07 PACKER BAKER MLZXP LINER HANGER PACKER 7000 11,4378 3,137,2 82W HANGER BAKER R -EX LOCK HANGER SECTION ]000 11,443.1 3,137.8 82. X BUSHING R H ]"Hyd X5-1 'Hyd 4.920 563 11,444.5 3,138.0 82.] SBE BAKER SEAL BORE EXTENSION 4350 19,5684 3,1543 9.U % Reducing CROSSOVER 5.V x45 39M sURFeVE 49.a4.nMs desire Desenpnan oDanl ID On) Top ll<KB) SelDrym(PIKE) sa Depm"i wNLenp._Grnae Top Thnad Seal Bore Diveder 41/2 3.94 11,3832 11454.] 3.1392 12.60 L-80 IBT Tubing Strings Tubi,q NIC II Sti,np Ma... RW020194.5" 4112 to Nn) 39fi top ifti 38.5 Set Depth(n.. 11,358.D 5e DAN RVD)(.. 3,12]6 Wt(IM 12.60 Grade L-80 Top Con,-. )BTM MnWar FNq-balb'ebr9,sT' 32wonss0.¢4rmnala Mm4er GmN-sevabn&sel Tubing Completion a2W a\1$3.04QM019 Completion Details Top RVD) TopinG Nomiml TopplNea MIKE) I') Ihm Des Com to (let MS 38.5 0.00 Hanger GE 412'MB-228 W/HOri2orms Tree 3900 533.3 5312 10.60 Nipple- 412'X3.81' DB6Ntpple S#3655-5PT#101]48544 3813 DB 0 9.713.3 2, 8 83.97 HE Rock 412' ROC 150 Gauge Mandrel S#102816493 3954 Gauge 11,263.5 J, 116.1 82.8] LOcaar Baker Locator Sub (Spaced out T from No -Go) 3.880 Tuarp-MnM'N:$1a..7 11,266.9 3,118.5 82.88 PER Polished Baker Modified PBR win Scoop Guide P#H0243317AI 4,750 Be. Receplack) 11,306.6 3.1214 1 Ise 99 Packer Baker Premier Production Packer S#H184638405 3.900 mmn n,2ms 11,333.7 3,1247 8.08 1 Nipple -335"DB 4112'X3]5" DISK Nipple with DFCV SUT031041 PT#1343751 3]50 PER (PIXnhN am Rzgd'e1: 11,3..9 11,350.6 3,1 J 1oor Boy Ram Poorboy RAM top Dcamr6.15'Pe1lMration WLEG 3950 Top LOwWr WI i WLEG Reae, II... Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Pba OGOV11,3.7 NkWs17S Da; n,341.7 TapiPBIroplrv0l DUKE) tom Run DM ID (In) 11,333] 3.124] 830fi DFCV .2 'La 0.000 Perforations & Slots Pw Bq Ram Rp Im'mr W/ WLEG;11.391.6 Bhol oenz ToPRVa Etm OVD) (snots. TopiPKB) M.(Wa) again DINI LInki Oab I Type Co. .0 LINER; 11,3s4 12,2450 14,5820 3216.0 3,198.1 WS B. 1b 1]4 52 12/100] 32.0 SLOTS lotted liner, .'x.1 -A tB.bHa cimumkrential rovrslX, S' - centers staggered 18 deg, nonelotted ends 14,5840 19,568.11 3,198.1 3,1543 WS B. 11174 12/152007 32.0 SLOTS tte Iner,.1 5",4 circumkren5al row4,8,3 centers staggered 18 deg, nonsloved ends Mandrel Inserts m & an • TOPrIVD) Valve Loob podbka N TopIKKB) MB)MW Model OO pn) Sery Type Type (in) TRO Run (pap Run Des I Can • 2,325.6 1,816.3 Camw KBMG 1 OV BK 0.313 00 511112019 2 4,25. 2.322.9 Camw KBMG i GLV BK 0.1813 1,4]5.0 5)3)2019 EeM arca DNmar 11 2- 4 11,1 .] 3,10].] Camco KBMG 1 '1DMY 1., 1 1 I,u.na Notes: General & Safety 1t'a''7 End Dale Annobnan 122 OOJNOTE:MULTI-IATERAL WELL IJ -174(8 -SAND), 1J -174L1(0 -SAND) 61 1 OB NOTE: View 6chema6c W Alaska Schemauds 0 4212012 NOTE: CROSSOVER IN CASING @ 3527' 2R 13 INUTE: INNER CASING LOCKDOWN SCREWS SEIZED PRODUCTION 1075?9.DOE .4-12w0.o SLOT.', 1324s.614,592,0� �I ROM 14`A4.619,589.0- SS DINER: 11,4166 19.Yb5 Operations Summary (with Timelog Depths) IJ -174 Rig: NORDIC 1 Job: RECOMPLETION Time Log stan Depth Start Time End Time our(hr) Phase Op Code Activit' Code Time P -T -x Operation (flKB) End Depth(ftKB) 4110/2019 4/11/2019 18.00 DEMOB MOVE DMOB P Remove Weatherford casing tongs 06:00 00:00 from rig with crane. Load out misc. equipment to 1J. Pull dg off of well and stage on CD3. 4/11/2019 4/11/2019 6.00 DEMOB MOVE DMOB P Continue removing speed head 00:00 06:00 adapter from stack. Removed tarps from cellar doors. Secure well. Clean up matting boards and herculite from around well. 4/11/2019 4/1112019 12.00 MIRU MOVE MOB P Move rig off pad, onto ice road, move 06:00 18:00 rig 8.3 miles T/ equipment pad. 4/1112019 4112/2019 6.00 MIRU MOVE MOB T Stage up on equipment pad and wail 18:00 00:00 on weather and work on moving system hydraulics. 4/12/2019 4/13/2019 24.00 MIRU MOVE MOB T Wait on phase 3 weather to clear, 00:00 00:00 work on rig hydraulic system, change out card in control box, adjust hyd. pressures, dean and inspect hyd valves. 4/13/2019 4/13/2019 6.00 MIRU MOVE MOB P Move from equipment pad to wide 00:00 06:00 spot in the road before the re -supply road to mile 13.7 4113/2019 411312019 13.00 MIRU MOVE MOB T Wait on snow removal on ice road. 06:00 19:00 Perform maintenance on rig equipment with hydraulic tech. 4/13/2019 4/14/2019 5.00 MIRU MOVE MOB P Move from entrance of re -supply road 19:00 00:00 to ice road gaurd shack at 18.3 miles. 4/14/2019 4/14/2019 12.00 MIRU MOVE MOB P Move rig from start of Resupply road 00:00 12:00 T/ Colville river, cross river, move rig to 12 mile hile. 4/14/2019 4/15/2019 12.00 MIRU MOVE MOB P Move rig F/ 12mile hill to 2 mile hile, 12:00 00:00 problem getting up all hills and inclines, pull rig up 2 mile hill with Cats and continue to 2L pad with cats pull rig due to slick road surface. 4/15/2019 4116/2019 24.00 MIRU MOVE MOB P Wait on equip. to clear mats of Colville 00:00 00:00 river and get equip ahead of rig, wait on ice road equip to demobe ahead of dg for change out. Continue moving towards 1J at mile 51. 4/16/2019 4/16/2019 15.50 MIRU MOVE MOB P Continnue Moving Rig f/ CD3 to 1J 00:00 15:30 pad stopping for crew change and to let traffic by. 4/16/2019 4/16/2019 6.00 MIRU MOVE RGRP T Blew rear drillers side lire, C/O Tire, 15:30 21:30 with loader support and peak lire repair rep. 4/16/2019 4/17/2019 2.50 MIRU MOVE MOB P Continue moving to !J Pad off spine 21:30 00:00 road 1/4 mi f/ 1J pad at midnight 4117/2019 4/17/2019 1.00 MIRU MOVE MOB P Continue moving V 1J pad 00:00 01:00 4117/2019 4/17/2019 5.00 MIRU MOVE MOB P Lay mats and herculite around cellar, 01:00 06:00 drop single gate and 4/17/2019 4/17/2019 2.50 MIRU MOVE MOB P Spot sub on mats 06:00 08:30 4/17/2019 4/17/2019 2.50 MIRU MOVE MOB P Install mud cross and crossover spool 08:30 11:00 on stack 4/17/2019 4/17/2019 1.00 MIRU MOVE MOB P Spot sub over well 11:00 12:00 4/1712019 4/17/2019 6.00 MIRU MOVE MOB P Level rig, spot cuttings box, install 12:00 18:00 berming around Cellar, Accept rig @ 1800 hrs Page 116 Report Printed: 5/29/2019 Operations Summary (with Timelog Depths) 1J-174 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operebw (fiK6) End Depth (WB) 4/17/2019 4/17/2019 5.50 MIRU MOVE RURD P R/U squeeze mainfold, and circulating 18:00 23:30 lines, R/U and pull BPV with Lubricator, Lubricator wouldnl ft through rotary table had to get it in cellar with loader, R/U circulating lines to tubing and IA, Blow down to tiger tank verify clear 4/17/2019 4/18/2019 0.50 MIRU WELCTL KLWL P Bleed gas cap from tubing and IA 23:30 00:00 4/18/2019 4/18/2019 1.00 MIRU WELCTL KLWL P Bleed gas cap from tubing and IA 00:00 01:00 4/18/2019 4/18/2019 4.50 MIRU WELCTL KLWL P Bullhead 150 Bbls down tubing, 590 01:00 05:30 Bbls down IA. Bleed gas cap off. 4/18/2019 4/18/2019 1.50 MIRU WELCTL OWFF P Observe well for flow for 30 Min - no 05:30 07:00 flow. DHD took fluid shot 1164'. Second fluid shot 30 min later 1212'. Third fluid shot 30 min after that 1212'. RD circulating equipment. 4/18/2019 4/18/2019 4.50 MIRU WELCTL MPSP P Set HP BPV with test dart. Attempt to 07:00 11:30 pressure test from above - no test. Pulled dart and BPV. Gas venting from tubing, vented IA to tiger tank for 15 min. Filled hole through IAwith 15 Bbls. Redressed sealing elements on BPV. Reset HP BPV with test dart. Pressure test from above to 1000 PSI - good test. Fill hole with 15 Blois. 4/18/2019 4/18/2019 2.50 MIRU WHDBOP NUND P NO tree. Inspect hanger threads. 11:30 14:00 4/18/2019 4/18/2019 8.00 MIRU WHDBOP NUND P NU slack with double gate and 14:00 22:00 annular. Hook up choke and kill hoses. Install flow nipple, DHD took fluid shot 1212' 4/18/2019 4/18/2019 1.00 MIRU WHDBOP MPSP P Bleed gas off tubing Pull BPV, set H 22:00 23:00 style w/ test dart 4/18/2019 4/19/2019 1.00 MIRU WHDBOP NUND P Remove bell nipple extend riser, set 23:00 00:00 1 blanking plug and MIN test it. 4/19/2019 4/19/2019 2.00 MIRU WHDBOP NUND P Continue remove bell nipple extend 00:00 02:00 riser, set blanking plug and M/U test it. Install test joint. Fill stack. Attempt shell test. Kill HCR flange was leaking. Tighten flange 4/19/2019 4/19/2019 17.00 MIRU WHDBOP BOPE P Test Bop's to 250/2500 for 5 Min each. 02:00 19:00 Test PVT system, gas alarms and accumulator draw down. Witness waived by AOGCC rep Adam Earl. VBR's failed initial test, Inspect rams looked to be in good shape clean and tighten bonet bolts, reinstall and tighten door bolts Fluid shot taken at 8:00 - 1110' Again at 16:30 - 1152' Filling the hole every hour with 10 Bbls of 3% KCL. 4/19/2019 4/19/2019 3.00 MIRU WHDBOP BOPE T Retest rams w/ 3.5" test joint door 19:00 22:00 hinge leaking hydraulic fluid, bleed down, drain stack, open ram doors clean and retighen doors leak stopped 4/19/2019 4/19/2019 1.50 MIRU WHDBOP BOPE P Test BOPE's wl 3.5" and 4.5" test 22:00 23:30 joints on VBR's it 250/2500 psi 4/19/2019 4/20/2019 0.50 MIRU WHDBOP RURD P RID Test Equipment, 23:30 00:00 4/20/2019 4/20/2019 1.50 COMPZN RPCOMP RURD P RU to LD 4 1/2" completion with ESP 9,719.0 9,719.0 00:00 01:30 1 1 1 1 1 cable. Page 216 Report Printed: 5129/2019 Operations Summary (with Timelog Depths) 1J-174 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (ftKB) 4/20/2019 4/20/2019 1.00 COMPZN RPCOMP MPSP P Pull blanking plug and H BPV. 9,719.0 9,719.0 01:30 02:30 4/20/2019 4/20/2019 2.00 COMPZN RPCOMP PULL P Pull hanger to dg floor and LD. 9,719.0 9,640.0 02:30 04:30 Hanger pulled free at 160K over block weight. 4/20/2019 4/20/2019 1.00 COMPZN RPCOMP RURD P RU Summit ESP cable sheave, 9,640.0 9,640.0 04:30 05:30 elephant trunk and pull cable through sheave. 4/20/2019 4/20/2019 12.00 COMPZN RPCOMP PULL P LD 4 1/2" IBTM completion with ESP 9,640.0 5,050.0 05:30 17:30 cable. Fluid shot at 7:30 -1188' Again at 16:30 - 1182' 4/20/2019 4/20/2019 1.50 COMPZN RPCOMP RURD P Change out ESP Cable Spool w/ 5,050.0 5,050.0 17:30 19:00 loader 4/20/2019 4/21/2019 5.00 COMPZN RPCOMP PULL P Pull out of the hole w/ 4.5" Completion 5,050.0 3,196.0 19:00 00:00 spooling up ESP cable f/ 5050' t/ 3196 4121/2019 4/21/2019 9.00 COMPZN RPCOMP PULL P Continue POOH w/ 45' Completion 3,196.0 0.0 00:00 09:00 spooling up ESP cable F/ 3196'T/ surface. Lay down ESP assembly. All 315 canon clamps and 3 protectolizers were recovered. 4/21/2019 4121/2019 5.00 COMPZN WELLPR RURD P Rig down Summit ESP sheave and 0.0 0.0 09:00 14:00 spooling unit. Clean and clear rig floor. Remove remaining tubing and jewelry from the pipe shed. 4/21/2019 412112019 1.50 COMPZN WELLPR RURD P Set wear bushing 0.0 0.0 14:00 15:30 4/21/2019 4/2112019 0.50 COMPZN WELLPR SFTY P PJSM with dg crew on installing kelly 0.0 0.0 15:30 16:00 shuck and making up kelly. 4/21/2019 4122/2019 8.00 COMPZN WELLPR RURD P PIU Kelly shuck, install plate and 0.0 0.0 16:00 00:00 make modifications to kelly shuck mounting bracket, M/U kelly and kelly bushinig, M/U upper Kelly valve,M/U Kelly swivel and goose nec, loading and straping 200 jts of 3.5" Dp in shed 4/22/2019 4/22/2019 7.00 COMPZN WELLPR KURD P Continue P/U Kelly shuck, install plate 0.0 0.0 00:00 07:00 and make modifications to Kelly shuck mounting bracket, M/U kelly and Kelly bushing, M/U upper kelly valve,M/U Kelly swivel and goose neck, loading and strapping 200 jts of 3.5" Dp in shed 4/22/2019 4/22/2019 2.00 COMPZN WELLPR RURD P RU to RIH with BHA. Re -size slips 0.0 0.0 07:00 09:00 and dog collar. 4/22/2019 4/22/2019 3.00 COMPZN WELLPR BHAH P MU and RIH with BHA#1 cleanout 0.0 45.0 09:00 12:00 1 assembly T/ 45' 4/22/2019 4/22/2019 3.50 COMPZN WELLPR PULD P PUDP and RIH T/ 1976' 45.0 1,976-0- 12:00 15:30 4122/2019 4/22/2019 0.50 COMPZN WELLPR CIRC P Pump tubing volume plus to ensure 1,976.0 1,976.0 15:30 16:00 circulation through jetting tool. 2 BPM 575 PSI, 3 BPM 2025 PSI. Saw pressure spikes at 2 BPM up to 1200 PSI and then back down to 575 PSI. 4/22/2019 4/22/2019 2.00 COMPZN WELLPR PULD P Continue RIH w/ Cleam Out Assy f/ 1,976.0 3,450.0 16:00 18:00 1976't/ 3450' 4/22/2019 4/22/2019 2.00 COMPZN WELLPR CIRC P Pump tubing volume 2 bpm 2500 psi 3,450.0 3,450.0 18:00 20:00 vary pump rate to clearjetting tool pump 55 bbls, Driller observe torque value on M/U gauge was different that previously used upon further inspection Drill pipe ran in hole had not been torqued to specs. Page 3/6 Report Printed: 612 912 01 9 Operations Summary (with Timelog Depths) U-174 Rig: NORDIC 1 Job: RECOMPLETION Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 4/22/2019 4/22/2019 2.00 COMPZN WELLPR RURD T Prep stabbing box and derrick board 3,450.0 3,450.0 20:00 22:00 to stand back pipe. 4/22/2019 4/23/2019 2.00 COMPZN WELLPR TRIP T POOH Racking back stands in derrick 3,450.0 1,662.0 22:00 00:00 f/ 3450' U 1662' 4/23/2019 4/23/2019 1.00 COMPZN RPCOMP TRIP T Trip OOH F/1678 to BHA 1,662.0 0.0 0000 01:00 4/23/2019 4/23/2019 3.00 COMPZN RPCOMP BHAH T C/O BHA "Shnozzelator' for better 0.0 0.0 01:00 0400 pump rates. L/D COP nozzles for BOT Nozzle. 4/23/2019 4/23/2019 4.00 COMPZN RPCOMP TRIP T Trip in hole from surface to 3571' 0.0 3,571.0 04:00 0800 Nordic RKB with 3-1/2" 13.3# DP 4/23/2019 4/23/2019 5.50 COMPZN RPCOMP PULD P Continue RIH with 3-1/2" 13.3# DP 3,571.0 6,400.0 08:00 13:30 and Nozzle BHA 4/23/2019 4/23/2019 0.50 COMPZN RPCOMP CIRC P RU head pin and load hole with 20 6,400.0 6,400.0 13:30 14:00 BBL'S of brine, while processing drill pipe. 4/23/2019 4/23/2019 8.00 COMPZN RPCOMP PULD P Continue to process an additional 165 6,400.0 6,400.0 14:00 22:00 its of OF, while working on Kelly 4/23/2019 4/23/2019 1.00 COMPZN RPCOMP RURD P R/D Kelly stab back in shuck 6,400.0 6,400.0 22:00 23:00 4/23/2019 4/24/2019 1.00 COMPZN RPCOMP PULD P Continue RIH f/ 6400 U 7200' P/U 3.5" 6,400.0 7,200.0 23:00 00:00 DP f/ shed 4/24/2019 4/24/2019 7.50 COMPZN RPCOMP PULD P Continue RIH with 3-1/2" DP to 8912' 7,200.0 8,912.0 00:00 0730 KB PU=64K/DN=34K 4/24/2019 4/24/2019 1.00 COMPZN RPCOMP CIRC P Pump 75 BBL's down the DP at 2BPM 8,912.0 8,912.0 07:30 0830 4/24/2019 4/24/2019 2.50 COMPZN RPCOMP PULD P Continue to RIH with 3-1/2" DP to 8,912.0 11,328.0 08:30 11:00 11,358' PU=73K, 4/24/2019 4/24/2019 2.50 COMPZN RPCOMP CIRC P Pump 100 BBL's down DP at 2BPM 11,328.0 11,358.0 11:00 1330 and 350 BBL's down Casing by DP at 5 BPM. 4/24/2019 4/25/2019 10.50 COMPZN RPCOMP PULD P POOH laying down OF. PU=73 11,358.0 4,416.0 1330 0000 SOW=35 f/ 11 358' U 4416' 4/25/2019 4/25/2019 6.00 COMPZN RPCOMP PULD P Lay down 3-1/2" DP from 4416'to 47' 4,416.0 47.0 0000 0600 4/25/2019 4/25/2019 1.50 COMPZN RPCOMP BHAH P Lay down BHA Clear BHA off floor 47.0 0.0 0600 0730 4/25/2019 4/25/2019 1.00 COMPZN RPCOMP RURD P P/U bowl protector R&R tool and 0.0 0.0 0730 0830 landing joint pull bowl protector. L/D same. 4/25/2019 4/25/2019 3.50 COMPZN RPCOMP RURD P RD from running DP and set up to run 0.0 0.0 0830 1200 tubing load jewlery into pipe shed off load service tools from rig floor. P/U tubing hanger and power tongs and rig up in-kind. 4/25/2019 4/25/2019 4.50 COMPZN RPCOMP RURD P Bring hanger and test plug to rig floor, 0.0 0.0 1200 1630 R/U Power tongs, break down spooling unit bring through hatch in pipe shed, reassemble spooler on rig floor. 4/25/2019 4/26/2019 7.50 COMPZN RPCOMP RURD P Load tubing in shed drift strap and 0.0 0.0 16:30 0000 tally, slip and cut drilling line 85', get BOP test equipment ready 4/26/2019 4/26/2019 8.50 COMPZN RPCOMP RURD P Finish loading pipe shed and strapping 0.0 0.0 00:00 0830 4-1/2" completion. Service Rig simultaneously. Page 416 Report Printed: 5/29/2019 Operations Summary (with Timelog Depths) U-174 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Actively Code T,me P -T -X Operation (WS) End Depth (RKB) 4/26/2019 4126/2019 5.50 COMPZN WHDBOP BHAH P PJSM for testing BOPE, test BOPE 0.0 0.0 08:30 14:00 test witness waived by Matt Herrera. Tests 1. Shell test UPR, CMV#4,5,9,14 MM #3, Kill line valve, FOSV 2. Kill HCR, CM#3,7,10,12, 15, 18 3. UPR, Kill Manual, CM #2.6, 11 4. UPR, Kill manual, CM#6, 11, 1, 16, 19 5, UPR, Kill manual, CM# 19, 17 6. UPR, Kill Manual, Choke HCR 7. UPR, Kill line manual Choke line manual 8. Annular, ISOP 9. BR, CM#1, 6, 11, 19 10, CM#8, 13, manual choke 11. Hydraulic Choke, 12. DDT 200 psi recovery =33 seconds 1900 psi recovery=141 seconds 4/26/2019 4/26/2019 0.75 COMPZN WHDBOP RURD P R/D test Equipment Blow down lines 0.0 0.0 14:00 14:45 4/26/2019 4/26/2019 0.75 COMPZN RPCOMP RURD P R/U to run 4.5" Completion, hang 0.0 0.0 14:45 15:30 sheave in derrick 4/26/2019 4/26/2019 0.50 COMPZN RPCOMP SFTY P PJSM to Run completion 0.0 0.0 15:30 16:00 4/26/2019 4/27/2019 8.00 COMPZN RPCOMP PUTB P Pick up completion and start RIH f/ 0.0 4,467.0 16:00 00:00 surface t/ 4467' 4/27/2019 4/27/2019 5.00 COMPZN RPCOMP PUTB P Cont RIH with 4-1/2" Completion from 4,467.0 8,009.0 00:00 0500 4467' to 8009' 4/27/2019 4/27/2019 7.00 COMPZN RPCOMP RURD P Load pipe shed with 85 jt's of 4-1/2" 8,009.0 8,009.0 05:00 12:00 12.6# L-80 IBT mod tubing. Strap and drift to 3.883" 4/27/2019 4/27/2019 6.00 COMPZN RPCOMP PUTB P Con't to RIH with 4-1/2" 12.6# L-80 8,009.0 11,358.0 12:00 18:00 IBT TBG from 8009' RKB to 11358' SOW 24k, Observe Beall Assy Shear going into Liner Top 15k SO wt 4/27/2019 4/27/2019 2.00 COMPZN RPCOMP PACK P M/U Circ hose and Head pin, Space 11,358.0 11,268.0 18:00 20:00 out and set packer hold 3000 psi f/ 15 min on chart, Bleed tubing t/ 2000 psi P/U and shear PBR w/ 70k Hook Load. Packer top 11 306'top of PBR 11268' 4/27/2019 4/28/2019 4.00 COMPZN RPCOMP CIRC P P/U 10' Seals out Circulate Seawater 11,268.0 11,254.0 20:00 00:00 w/ 3% KCL @ 3 bpm 100 bbis to returns, Circ out crude cap to cuttings tank and tiger tank, Swap U Cl Brine f/ trucks Continue Circulating 3 bpm 250 psi t/ tiger tank 338 bbls Crude returned @ 2400 hm 4/28/2019 4/28/2019 5.00 COMPZN RPCOMP CIRC P Circulate Consion inhibited seawater 11,254.0 11,254.0 00:00 05:00 down tubing up IA to kill tank/cuttings tank. 4/28/2019 4/28/2019 1.00 COMPZN RPCOMP PULD P Lay down A's 283-284 mu space out 11,254.0 11,190.0 05:00 06:00 joints, 4/28/2019 4/28/2019 3.50 COMPZN RPCOMP THGR P PJSM Landing completion. 11,190.0 11,358.0 06:00 09:30 Make up tubing hanger, terminate gauge wire at hanger lest termination at bottom of hanger body to 5000 psi for 10 minutes. Drain stack, blow down choke and kill lines, Land tubing hanger PU=46K SOW=22K. Land Tbg Hgr RILDS, and test to 5000 psi for 10 minutes. Page 616 Report Printed: 512912019 Operations Summary (with Timelog Depths) IJ -174 Rig: NORDIC 1 Job: RECOMPLETION Time Log Sh rl Depth start Time End Tme our (hr) Phase op Code AcKvity Code Time P -T -X Operation (t1KB) End Depth (f KB) 4/28/2019 4/28/2019 2.50 COMPZN RPCOMP RURD P RU hoses to squeeze manifold for 11,358.0 11,358.0 09:30 12:00 testing tubing and IA. 4/28/2019 4/28/2019 2.00 COMPZN RPCOMP THGR P Pressure test tubing to 3000 psi for 5 11,358.0 0.0 12:00 14:00 minutes, bleed back to 2000 psi. Pressure test IA to 3000 psi for 30 minutes, Bleed tubing to 0 psi sheared SOV. Verified that SOV was sheared. Pull landing joint and lay down. 4/28/2019 4/28/2019 1.00 COMPZN WHDBOP MPSP P Set BPV lest from IA to 1000 psi for 5 0.0 0.0 14:00 15:00 minutes. 4/28/2019 4/28/2019 3.00 COMPZN WHDBOP EQRP P Replace LDS on Tubing Head, 0.0 0.0 15:00 18:00 simultaneously crane spooler off rig floor clear dg of all equip,not required for next well. prep to ND BOPE. 428/2019 4/29/2019 6.00 COMPZN WHDBOP NUND P N/D stack and N/U Adaptor and tree 0.0 0.0 18:00 00:00 4/29/2019 4/29/2019 1.00 COMPZN WHDBOP NUND P Continue N/U tree, terminate tech wire 0.0 0.0 00:00 01:00 1 and test void t/ 5000 psi f/ 10 min 4/29/2019 4/29/2019 2.00 COMPZN WHDBOP MPSP P Pull BPV set TWC, test tree t/ 5000 0.0 0.0 01:00 03:00 psi f/ 5 min 4/29/2019 4/29/2019 4.50 COMPZN WELLPR FRZP P R/U and freeze protect well w/ 248 0.0 0.0 03:00 07:30 bbls diesel w/ LRS, Put tubing and IA in communication and allow to Utube 4/29/2019 4/29/2019 0.50 COMPZN WELLPR NUND P Set BPV, secure wellhead, RDMO Rig 0.0 07:30 0800 released @ 0800 hrs Page 6/6 ReportPrinted: 5/29/2019 vry &7 - iy 3 Loepp, Victoria T (DOA) From: Hayes, James C <lames.C.Hayes@conocophillips.com> Sent: Friday, March 22, 2019 8:06 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: KRU 1J-174(PTD 207-143, Sundry 319-006) Sundry Change Request Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yes we will have a set of 2-7/8" x 5" VBR's which will cover the 4'/:" tubing and 3 %" drill pipe that we will be using on this well. There isn't any risk of having to run casing on this well. However if something were to happen I recognize that we will have to secure the well, change out the rams, and retest BOP'S. Is this what you were looking for? Thanks, James Hayes C: +1918.914.9609 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, March 22, 2019 7:49 AM To: Hayes, James C <James.C.Hayes @conocophilli ps.com> Subject: [EXTERNAL]RE: KRU 1J-174(PTD 207-143, Sundry 319-006) Sundry Change Request James, Will you be running a set of VBRs that will cover all pipe sizes being handled? Please verify. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppCd) alaska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoria Loeao@alaska aov From: Loepp, Victoria T (DOA) Sent: Thursday, March 21, 2019 12:14 PM To:'Hayes, James C' <James.C.Haves@conocophillips.com> Subject: KRU 1J-174(PTD 207-143, Sundry 319-006) Sundry Change Request THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Hayes Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-174 Permit to Drill Number: 207-143 Sundry Number: 319-006 Dear Mr. Hayes: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k o. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this �day of February, 2019. SCANNED tt3 9 51U19 RECEIVE® STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 9 2019 APPLICATION FOR SUNDRY APPROVALS A®�x�'C° 20 PAC 25.280 i 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑Q Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 91v-11/ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development (] . Stratigraphic Service El❑ 207-143 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-029-23374-00.iL>C� 7. If perforating: 8. Well Name and Number: y, What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J-174 Will planned perforations require a spacing exception? Yes ❑ No E 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 025661, 025660, 025663, 385172 Kuparuk River Field / Kypawk Ryer oil Pool J�� . iy 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,708' 3,157' 9,706' 2,930 575 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 120' 120' Surface 3,971' 13-3/8" 4,021' 2,273' Production 3,886' 10-3/4" 3,927' 2,249' Production 8,153' 9-5/8" 12,081' 3,205' B -Sand Liner 8,151' 5-1/2" 19,656' 3,156' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,245'-19,568' 3,216'-3,155' 4-1/2" L-80 9,721' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary , Wellbore schematic L� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Z Service ❑ 14. Estimated Date for/ 15. Well Status after proposed work: d Commencing Operations: 3/1 19 {f -j `� / OIL ❑✓ WINJ E]WDSPL E] Suspended EJ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Hayes Contact Name: James Hayes Authorized Title: Sr. Wells Engineer Contact Email: 'ameS.C.ha e5 CO .COm Contact Phone: 265-6927 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I , D © U Plug Integrity ❑ BOP Test L"J Mechanical Integrity Test ❑ Location Clearance ❑ Other: BoP *'r57- ,rirt Y/ v`R P re- li! pl f7' r tr 5f -Yo Z.SO O P s r 9 Post Initial Injection MIT Req'd? Yes ❑ No L^_I/ Spacing Exception Required? Yes ❑ No Lg Subsequent Form Required: 40 ¢ APPROVED BY ] 9 Approved by:Z�aka�� COMMISSIONER THE COMMISSION Date: 67 r Farm 10-403 Revised 4/201 2� Approved application 0,R l GIn IN I�tLatRof p EB 0 5 ttac me is in Form and rj pp pp' pproval. �yAttac�,,m�emsin Duplicate ti ,0" 11149/r 'SSD %!O-/% ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 18 December 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Weak Producer 1J- 174 (PTD# 207-143). Well IJ -174 was originally drilled in November of 2007 with Doyon 15 as a dual lateral Wes Sak producer. This well was put on ESP but became sanded out and damaged the motor in 2009. A new ESP was installed and the well continued to produce until the ESP went down in 2015. The well was then converted to gas lift and has been producing in this fashion since. Once over the well the old tubing & ESP will be pulled. The 7" packoffs need to be replace and there are a few lock down pins that seized up and will need to be drill out. After that a planned cleanout run will be performed all the way down to the packer set depth in anticipation of sand in the production casing. Finally the completion string will be made up, ran in hole, spaced out and hung off. If you have any questions or require any further information, please contact me at 265-6927. Sincerely, James Hayes Sr. Wells Engineer CPAI Drilling and Wells IJ -174 RWO Procedure Kuparuk Producer PTD #207-143 Pre -Rig Work 1. Obtain SBHP 2. Install BPV. Rig Work MIRU / 3. MIRU on 2E-17. (Nabors 7ES) +' 4. Attempt to circulate 8.4 ppg seawater (Returns not expected due to low pore pressure) 5. Run fluid check shot to confirm well is static 6. Verify well is dead. 7. Primary barrier: 8.4 ppg seawater 8. Secondary barrier: Upper Packoffs 9. NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. (SM BOP stack: Annular, 2-7/8" x 5" VBR, Blind, Mud Cross, 2-7/8" x 5" VBR) Well Prep 10. Pull & rack back existing 4 Y" tubing 11. LD ESP & motor 12. RIH & set storm packer 13. Replace packoffs and lock -down pins 14. Pull storm packer 15. RIH w/ tubing and drill pipe; wash down to packer set depth 16. POOH LDtubulars 17. Prep for completion run Run 4 %" Completion 18. MU Completion string per tally 19. Correlate packer set depth 20. Drop ball & rod and set packer 21. Shear out of PBR & determine space out 22. Space out and hang off tubing string 23. PT tubing to 3000 psi for 5 minutes. 24. PT inner annulus to 2500 psi for 30 minutes on chart. NO BOP, NU Tree 25. Shear out SOV with pressure differential. 26. NO BOPE. NU tree. PT tree. 27. Pull BPV. Freeze protect well. 28. RDMO. Page 1 of 1 U-174 Proposed Schematic 20" 94# H-40 shoe @ 120' RKB 3-3/8" 68# L-80 hoe @ 4,021" RKB 10-3/4" 73.2# L-80 & 9-5/8" 40# L-80 shoe @ 12,080' RKB B -Sand Slots 12,245'- 19,568' RKB B -Sand Lateral 5-1/2" 15.5# L-80 shoe @ 19,656' RKB PROPOSED COMPLETION 4-1/2" 12.6# L-80 TXP Tubing to surface 4.5" X -Nipple 3.813" ID (IBTM) 4-1/2" Camco KBMG gas lift mandrels @ TBD 4.5" x 9-5/8" Premier Packer @ -11,200' RKB 4.5" X -Nipple 3.813" ID (IBTM) WLEG D -Sand Slots 11,485'- 19,644' RKB D -Sand Lateral 4-1/2" 11.6# L-80 shoe @ 19,689' RKB Wellhead /Tubing 1 Trea: 13.318" x &11X', 5,000 psl Insulated Conductor: N" 94# K-55x34"0.312WT+I-80' ConocoPhiIIips 2007 West Sak Producer with Rotating self -Aligning Multilateral (RA MTM) System 3927. MD- 101712#, LA0, Dual lateral Completion BTC Casing Crossover 1J-174 HB DLP 2208' MD -GLM, Cameo, &112" x 1" AS Si KBMG,set 67deg COMPLETED 101T MD -13-318" Casing Shoe, 68A, L-80, BTC, We' INC, ndeg Inc Tubing String 4413" 12.8%, LAD IBTM 0.950" ID, 3.833" Dim 11]55MD, X D6M" asks Hanger 5.960'talera1Drllllg 3,6M" Malntore Can In Epuipment Specifications 7" X 9-5/8" RAM Junction Mainbore Drift: 3.88' Literal Orilt: S.W RFM Hang.rGeal Bore0u,n nef 00: BATS" Overall Length of RAM Juncfion: 38 ] M Seal Bore Divenef Running Tool: FJO RAM Hanger Running Tool: Hi 4.1/2" Lateral Entry Module LEM 00: 6.99- Mainbore Dn8 We Dlveners: 3.88' Mainbore Drill wl In.ki on Divertec 2.50" Latera!Drn WI"FB"Divertec 3.68' OD of everars: 3Ar 9617' MD - B000m of Motor Centralizer 11366' MD -Di Casing E1dt, 3126' WD, 83 deg inc 'D'Sand Lateral Bl1ein HHyEn1531 antl BTC, L -BO ankantl 5btletl Gner BAKER HUGHES Baker Oil Tools With Diverters and Isolation Llac rall➢DilLWpLE4ll "'FB"Dre Lnlea on onn c pzsemhJr _ "c z ,f-� Pxwr�mr Poelrlre Ylcnmp C¢IW 1145'MO-MLHB M4Nee Cpmcl Loull¢a PmtluYbn Archm aaap,yuSnep Oul 4-112•118rl an1531 en OeePmnle a,nw L¢¢arF C¢p¢1 I_ Mcp rd LLLLln ]areralobener L 'B'Sand Lateml ngwl MSeela698mdy Rmnp Upp¢rsuupursee, LL 4AS'SUI OD sea, epn.1 Lei 3.8'75"ID Stl3"ISSN, Nyen15]I ace BTC, LA0 bdaIINADv¢ner /ank ane 51o8etl Liner 4.Vr orange PeelM Sh. Sa IN6nap Om heLxNnp LdIN uhry lwhl,on m,um,wppnsutlil'ar� La.ersadr lseela¢RPM _ see pBBperpzvl be runnMgantl Wll,n9 tllwrMs ses evlewewrsrhrl Guitle Shoe S.00"oD 12080' MD - 9-518" Casing Shoe, 40.0k, L-80 BTC , 3205' WD, 85 deg Inc ®Be4r NyMa ]7.0.10 v Eccumenl my nd he reproYucM ¢r JgMOulea. In Me4 w In pyr, In aq I¢m, ¢r b/ naeMlrmkermecnanlu4lncYHlrypl,¢lampylnq r¢ortllnA<raYaaY lnlermarbnakrye antl rtlMnlayarem nwe 4nwvn orNreerbr menrN, wlll,eurvn111en pLvrnlwbnlrom Ba4r Xuyra lnc. 19658' MD -6112" Casing Shoe, 15.50, L40 BTCM , 3156' WD 19889' MD -4112" Casing Shoe, 11.60, L-80 BTC, 11415 MD-3.Mi Da Hippie 3059'TVD 111610 W uo 3133' Tin), Bl deg Dih(SENO) v1b;5R"Sal Bores 1145'MO-MLHB PmtluYbn Archm 4-112•118rl an1531 en IBTM Tubing 1140 MD -Bohm 'B'Sand Lateml MSeela698mdy 1148'MO-Tx8&H"M 4AS'SUI OD Uner Hanger Pecker 3.8'75"ID Stl3"ISSN, Nyen15]I ace BTC, LA0 /ank ane 51o8etl Liner 4.Vr orange PeelM Sh. 12080' MD - 9-518" Casing Shoe, 40.0k, L-80 BTC , 3205' WD, 85 deg Inc ®Be4r NyMa ]7.0.10 v Eccumenl my nd he reproYucM ¢r JgMOulea. In Me4 w In pyr, In aq I¢m, ¢r b/ naeMlrmkermecnanlu4lncYHlrypl,¢lampylnq r¢ortllnA<raYaaY lnlermarbnakrye antl rtlMnlayarem nwe 4nwvn orNreerbr menrN, wlll,eurvn111en pLvrnlwbnlrom Ba4r Xuyra lnc. 19658' MD -6112" Casing Shoe, 15.50, L40 BTCM , 3156' WD KUP PROD WELLNAME IJ -174 WELLBORE 1J -174L1 }������ 01111"'TSA, ell Attributes Maz Angie&MD TD ConocbMilhpsNama wnn.,. APImwI xnnore sum. mm MD lnxm An mMel Aaska.11x. 500292337460 GROG 4.42 1194954 19,)50.0 NONE 110 - 111182014 adullydE'TE.- 1117kv ta11A1e msDPM Last Tag Vull[Lttlwn&m (xiwn Annotation ..PMMKIN Do Da@ w.neure .at Moa 91 Last Tea 1J-1)dL1 ImosOol Last Rev Reason ......._...................__.......__.. _...... NANGEA: ]1.a II Annotation End Data Wellbore LaaI Mod By Rev Reasen'. GLV CIO, PULL ESPNACKOEEI3LIPSTOP .......r'5 III-LJdLI I tenant Casing Strings leant, oeaonpaon oo pn) ID nnl Tn Inxal sm ceplM1 mx01 sm oapu tiv01... widen IL.. cmdz To Tnread D -SAND LINER 41rz 3.96 11355.4 19,6845 3.0566 11.60 L-80 BTC Liner Details Nn COASUGTOfl: J4.NaTp iePlydtal oPIrVDI-a T.Plnolfl Rm Oaa Tap" I-a Cont fn1110 11,355.4 3,12]3 83,11 HANGER RAM LINER HANGER 6."160 11,383.0 3,126.2 83.13 HANGER RAM LINER HANGER 6.000 Perforations & Slots EWMANDREL Zb 7 Sind : TOP frvo) e nn(Tvol lanoum Toprate l eanows) �Me) in.., Lt.. Zana oau I TWe cam 11485.0 11,686.0 3.140.9 3,159.8 WS D. IJ- 12272007 32.0 SLOTS Slotted liner, 2.5-x.125'.4 174L1umferen it.1 rowaM.3- centerssall.ind18dee, non -sloped ends 11768.0 12,878.0 3,163.0 1,122.3 WS D. IJ- 12272007 320 SLOTS Slotted liner, 2.5-x.125",4 174Li umlemrsialndeaal 3' centers staggered 10 deg, non-Sloned ends 12.880.0 18.W4.0 &1223 3,0587 WS 0, 1,E 12272007 32.0 SLOTS Slaved liner, 2.5"x.125',4 174LI circumferential reeds, 3' centers staggered 18 deg. SURFACE: 4454.0205 non.slonedends Notes: General &safety "? .,avANOREL'.s rad a ria., 12282007 NOTE: MULTI -LATERAL WELL IJ -174 (S -SAND). IJ -1740 (D -SAND) 6212008 Nd,E: .ew ScnernddoelAlaska Sohemataig.0 2112013 INOUE INNER CASINGLOCKDOWN SCREWB SEIZED ESPMNAREL 95519 peCXPAGE', P.fi31.0 INTAIi'. 9.615.] Naiads SEAL:S�fi.l MDTOR; RTpO GAUGE:9.7168 cavase', 9.,69 %zOoucnox 101rria1S: 4d.slzdddd sLOTS, 11.4a5011,Essp SLOTS I4]�.p12,97ep� a.d. Izesee819... 6GAND UN£R: 11,vS, 19.5 CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV U WSAK 11-174 (207-143) KUPARUK RIVER, WEST SAK OIL Monthly Production Rates 1,000,000 J_- 100,000 0 O a 10,000 LL v o -_ m H cr O o N 1,000 fa v C7 LL O a 0 v 100 n 0 O s H 10 1 Jan -2005 t(mcf):, --------- ----- Jan-2010 Jan -2015 1,000,000 m v 100,000 D O v m 10,000 0 3 S 0 1,000 tD O 100 rD !D 0 0 10 1 Jan -2020 SPREADSHEET_Prod-1 nject_Curves_W ell_V117_2071430_KRU_1J-174_20190110.x1sx 1/10/2019 STATE OF ALASKA • r ALA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n I-- Performed: Suspend r Perforate r Other Stimulate re Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well Other: ESP to Gaslift 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 207-143 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23374-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025661;ADL025660;ADL025663;ADL385172 WSAK 1J-174 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19708 feet Plugs(measured) None true vertical 3157 feet Junk(measured) None Effective Depth measured 19568 feet Packer(measured) None true vertical 3155 feet (true vertical) Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20 120 120 SURFACE 3971 13.375 4021 2273 SEAL BORE DIVERTER 72 9.625 11455 3139 PRODUCTION 12040 10.75 12080 3206 B-SAND LINER 8240 9.625 19657 3156 Perforation depth: Measured depth: Slots: 12245- 14582; 14584- 19568 NC V E , True Vertical Depth: 3216-3198; 3198-3155 Tubing(size,grade, MD,and TVD) 4.5, L-80, 9721 MD,2932 TVD SCANNED JAN 2 9 2016 Packers&SSSV(type,MD,and TVD) SSSV= None Packer= None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 561 264 18 170 _ 159 Subsequent to operation 1090 1353 30 564 165 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email n1139@conocophillips.com Printed Name R.,+ert D. Christensen Title NSK Production Engineering Specialist Signature / /ja..tgil Phone:659-7535 Date I �-- !t/l 5 `,-r-t- ,Z/z�I S-/ �-- RBDM$-'uv 18 2015 Form 10-404 Revised 5/2015 At /714 Submit Original Only • • • 1J-174 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/25/15 Successfully set Packoff Assembly(9,656' RKB) and pressure tested. Flowed fluids to surface via ESP. Slipstop set(9,654' RKB). 11/06/15 RECOVERED SLIPSTOP FROM 9654' RKB, RECOVERED PACKOFF ASSEMBLY FROM 9656' RKB, RETURN IN AM TO PULL ESP, JOB IN PROGRESS. 11/07/15 PULL ESP FROM 9661' RKB WITH 1 JARLICK, PULL TO SURFACE AND VERIFY WE HAVE IT WITH SWAB AND MASTER VALVES, RIH TO PUMP OFF OF ESP AT 1100' CTMD, WELL F/P TO 3000' CTMD, READY FOR SLICKLINE. 11/08/15 (AC EVAL) GAS MITIA PASSED 11/09/15 RECOVER 39' ESP PUMP @ 2550' SLM, SET CATCHER @ 2850' SLM, PULLED SOV @ 2403' RKB, SET GLV @ SAME, PULLED CATCHER SUB @ 2850' SLM. 11/10/15 Open well to Gaslifted Production IP - KUP PROD 1J-174 " ConocoPhillips 0Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/DWI Field Name Wellbore Status Incl(`) MD(ftKB) Act Btrn(ftKB) al 500292337400 WEST SAK PROD 92.99 19,278.18 19,708.0 ... .w� Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date MULTIPLE LATERALS-1J-174,11/11/20153;04;34 PM SSSV:NONE 10 11/8/2014 Last WO: 9/8/2012 44.41 12/31/2007 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:GLV C/O,PULL lehallf 11/11/2015 HANGER;22.8 i I Casing Strings ESP/tPACKOFFISLIPSTOP Casing Description IOD(in( ID(in) Top(ftKB) Set Depth(fIKB) Set Depth(TVD)... WtJLen(I...Grade Top Thread CONDUCTOR 20 19.124 44.4 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 133/8 12.415 49.5 4,020.5 2272.5 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread .AaAJCONDUCTOR;44A-120 0.414 pi PRODUCTION PROD DescriptionOD(i n) ID(in) 40.4 12,080.0 3,205.9 40.00 L-80 BTCM 10.75"x9.625" in C B-SAND LINER 5 1/2 4.950 Top(ftKB) Set Depth(ftKB) Sot Depth(TVD)...WVLen(I...Grade Top Thread 11,416.5 19 656.5 3,156.3 15.50 L-80 BTC-m ESP MANDREL;2,402.6 - Liner Details ,- Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Inel 7) Item Des Com (in) 11,416.5 3,134.6 83.05 HANGER BAKER MLZXP LINER HANGER PACKER-Length 7.000 above collet profile 11,429.4 3,1362 83.02 PACKER BAKER MLZXP LINER HANGER PACKER 7.000 11,437.8 3,137.2 82.99 HANGER BAKER FLEX LOCK HANGER SECTION 7.000 11,443.1 3,137.8 82.98 XO BUSHING CROSSOVER BUSHING 7"Hyd 563 X 5-1/2"Hyd 4.920 563 11,444.5 3,138.0 82.97 SBE BAKER SEAL BORE EXTENSION 4.750 SURFACE;49.5-4,020.5 19,568.4 3,154.7 89.03 XO Reducing CROSSOVER 5.5"x 4.5 3.958 Casing Destriplion OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVDI... WtlLen(I...Grade Tap Thread 4 Seal Bore Diverter 41/2 3.940 11,383.2 11,454.7 3,139.3 12.60 L-80 IBT ESP MANDREL;4 487 4 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection ESP TUBING 41/2 3.958 22.8 9,720.8 2.931.6 12.60 L-80 IBTM W0 2012 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 22.8 22.8 0.00 HANGER VETCO GREY HANGER w/FULL JT BELOW 4.500 9,633.9 2,922.4 84.03 DISCHARGE UNIQUE PRESSURE DISCHARGE SUB 111 9,675.7 2,926.8 83.92 INTAKE TTC RECEIVER/XO w/PERFORATED INTAKE ESP MANDREL;9,550.9 ! 9,6862 2,927.9 83.93 SEAL TANDEM SEAL SECTION 9,700.0 2,929.4 83.95 MOTOR EAP MOTOR 526 SP1,210 HP,2380V-53A 9,716.7 2,9312 83.97 GAUGE A-WELL I-PUMP SENSOR 9,718.8 2,931.4 83.98 Centralizer MOTOR CENTRALIZER 4.000 DISCHARGE;9,633.9 _1la Perforations&Slots I Shot Dens f( Top(ND) BM(ND) (shotsH , ` Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I) Type Com INTAKE;9,675.7 12,245.0 14,582.0 3,216.0 3,198.1 WS B,1J-174 12/15/2007 32.0 SLOTS Slotted liner, SEAL;9,686.2 2.5"x.125",4 _ circumferential rows/ft, MOTOR;9,700.0 _ 3"centers staggered 18 GAUGE;9,716.7 .a., deg,non-slotted ends Cenlraizer 9,718.8 : 14,584.0 19,568.0 3,198.1 3,154.7 WS B,1J-174 12/15/2007 32.0 SLOTS Slotted liner, 2.5"x.125",4 circumferential rows/ft, 3"centers staggered 18 D-SAND LINER;11,355.4- i deg,non-slotted ends 19,889.5 Mandrel Inserts St ali on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type _ (in) (psi) Run Date Com 1 2,402.6 1,842.0 CAMCO KBMG 1 ESP GLV BK 0.156 1,418.0 11/9/2015 20005 2 4,487.4 2,352.8 CAMCO KBMG i 1 ESP DMY BK 0.000 0.0 9/5/2012 3 9,550.9 2,914.1 CAMCO KBMG 1 ESP DMY BK 0.000 0.0 9/5/2012 i ' Notes:General&Safety 1_1 F=i End Date Annotation 12/28/2007 NOTE:MULTI-LATERAL WELL 1J-174(B-SAND),1J-174L1(D-SAND) 1 ® t°t 6/21/2008 NOTE:View Schematic w/Alaska Schematic9.0 ' 4/21/2012 NOTE:CROSSOVER IN CASING @ 3527' 2/1/2013 NOTE:INNER CASING LOCKDOWN SCREWS SEIZED i 1171i Seal Bore Diverter;11,383.2- 11,454.7 PRODUCTION 10.75-x9.625'; • A 40A-12,080.0 SLOTS;12,245.0-14,582.0 SLOTS;14,584.0-19,588.0 B-SAND LINER;11,416.5- 1 19,656.5 • • p7-7, 207- - /4_3 Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, October 28, 2015 1:35 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L(DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler; Simek,Jill; NSK West Sak Prod Engr Subject: KRU 1J-174 (PTD 207-143) Report of failed ESP motor Attachments: 11-174 schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged SCANNED l'1AY 1 .i li Victoria, Guy West Sak producer 1J-174(PTD 207-143) has a failed ESP motor that will require a RWO for repair. The failure is due to a downhole short in the motor. It is ConocoPhillips intention to put the well on production with gas lift while awaiting the RWO. GLV's will be installed in the GLM's and the pump intake will be used as the lowest gas lifting point. Is a 10-404 for the change sufficient or do we need a 10-403? Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions? CHOKE - FTP FTT IAP THIO Plot - 1J-174 OAP 500 _ 400 300 • - 200 --- _ �11 v 100 — 0 29-Jul-15 11-Aug-15 24-Aug-15 06-Sep-15 19-Sep-15 02-Oct-15 15-Oct-15 Date 1 g 41, KUP PROD410 1J-174 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore AP1/b1M Field Name Wellbore Status Ind F) MD(ftKB) Act Sem(11x8) Car1n[oRatkps 500292337400 WEST SAX PROD 92-99 19,278.18 19,708.0 •"- Comment Comment H2S(ppm) Date Annotation End bate KBGrd(ft) Rig Release Date MULTIPLE LATERALS-1J-174,8/7/2014745:29 AM SSSV:NONE Last WO: 9/8/2012 44.41 12/31/2007 Verbcel schematic(actual) -'Annotation Depth(ftKB) End bate Annotation Last Mod By End bate Last Tag: Rev Reason:GLV C/O,REPLACE hipshkf 8/7/2014 HANGER;228 .�� ESP/PACKOFF/SLIPSTOP . Casing Strings Casings ription OD(in) Ib(in) -Top IRKS) Sef Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 CONDUCTOR 20 19.124 44.4 120.0 120.0 94.00 9-40 Welded 'I toeing Description OD(in) ID(in) Top(9199) Set Depth(MKS) Set Depth(TVD)...Millen(I...Grade Top Thread SURFACE 133/8 12.415 49.5 4,020.5 2,272.5 68.00 L-80 BTC Casing Description00(in) Ib(in) Top(ftKB) Set Depth(1908) Set Depth()VD)...WttLen(I...Grade Top Thread ...c....,./CONDUCTOR:444-120.0 - - PRODUCTION 95/8 8.835 40.4 12,080.0 3,205.9 40.00 1-80 BTCM 10.75"x9.625" Casing Description OD(in) ID(In) Top(ftKB) Set Depth(11(8) 'Set Depth(TVD)...W)/Len(I...Grade Top Thread ESP MANDREL 2,402.8 t clFa' B-SAND LINER 51/2 4.950 11,416.5 19,656.5 3,156.3 15.50 L-80 BTC-m Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(") Item Des Com (in) 11,416.5 3,134.6 83.05 HANGER BAKER MLZXP LINER HANGER PACKER-Length 7.000 I i above collet profile 1 11,429.4 3,136.2 83.02 PACKER BAKER MLZXP LINER HANGER PACKER 7.000 11,437.8 3,137.2 82.99 HANGER BAKER FLEX LOCK HANGER SECTION 7.000 11443.1 3,1378 82.98 XO BUSHING CROSSOVER BUSHING 7"Hyd 563 X 5-1rr Hyd 4.920 563 11,444.5 3,138.0 82.97 SBE BAKER SEAL BORE EXTENSION 4.750 SURFACE;49.54,020.5 l 19,568.4 3,154.7 89.03 XO Reducing CROSSOVER 5.5"0 4.5 3.958 Casing Description OD ON ID(in) -Top(8KB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ESP MANDREL;4,487.4 L0--- Seal Bore Diverter 41/2 3.940 11,383.2 11,454.7 3,139.3 12.60 L-80 IBT Tubing Strings Tubing Description String Ma...ID(in) Top(18(8) Set Depth(ft...Set Depth(ND)(...WL(lbft-) Grade Top Connection ESP TUBING 41/2 3.958 22.8 9,720.8 2,931.6 12.60 L-80 IBTM WO 2012 • Completion Details Nominal ID Top(11198) Top(ND)(MB) Top Ind(") Item Des Com (in) 22.8 22.8 0.00 HANGER VETCO GREY HANGER w/FULL JT BELOW 4.500 • 9,633.9 2,922.4 84.03 DISCHARGE UNIQUE PRESSURE DISCHARGE SUB ESP MANDREL,5,5500 9,675.7 2,926.8 83.92 INTAKE TTC RECEIVER/XO w/PERFORATED INTAKE 9,686.2 2,927.9 83.93 SEAL TANDEM SEAL SECTION 9,700.0 2,929.4 83.95 MOTOR 'EAP MOTOR 526 SP1,210 HP,2380V-53A DISCHARGE;9,833.9 9,716.7 2,931.2 83.97 GAUGE A-WELL I-PUMP SENSOR 9,718.8 2,931.4 83.98 Centralizer MOTOR CENTRALIZER 4,000 Perforations&Slots SLIPSTOP;9854.0 Shot PACKOFF;88E410 Dens Top(TVD) Btrn(TVD) (shofslf Top(ftKB) Btm(ftKB) (MKS) (9K13) Zone Date t) Type Corn 12,245.0 14,582.0 3,216.0 3,198.1 WS B,1J-174 12/15/2007 32.0 SLOTS Slotted liner, ESP;9881.0 INTAKE;9,875.71 2.5"x.125",4 circumferential rows/ft, SEAL;9,988.2 3"centers staggered 18 MOTOR;9,700.0 deg,non-slotted ends GAUGE;9,718.7 14,584.0 19,568.0 3,198.1 3,154.7 WS B,11-174 12/15/2007 320 SLOTS Slotted liner, Cenhar,9718.8 2.5"x.125",4 circumferential rows/ft, 3"centers staggered 18 deg,non-slotted ends DSAND LINER 11,355.4- 1 I Mandrel Inserts 19,899.5 St ati C on Top(TVD) Valve Latch Port Size TRO Run o No Top(ftKS) MKS) Make Model OD(in) Sets Type Type (in) (psi) Run Date to 1 2,402.6 1,842.0 CAMCO KBMG 1 ESP SOV BK 0.000 0.0 8/4/2014 2 0 0 0 1` r1 2 4,487.4 2,352.8 CAMCO KBMG 1 ESP DMY BK 0.000 0.0 9/5/2012 'A f 61/ 3 9,550.9 2,914.1 CAMCO KBMG 1 ESP 'DMY BK 0.000 0.0 9/5/2012 IE Notes:General&Safety --Al. c=- End Date Annotation 12/28/2007 NOTE:MULTI-LATERAL WELL 1J-174(B-SAND),1J-174L1(D-SAND) 621/2008 NOTE:View Schematic w/Alaska Schematic9.0 ti 4/21/2012 NOTE:CROSSOVER IN CASING @ 3527' : - 2/1/2013 NOTE:INNER CASING LOCKDOWN SCREWS SEIZED Seel core Diverter;11,383.2- 114547 I • PRODUCTION 10.75'x9.625'; 40.4-12,090.0 SLOTS;12,2450-14,5820 SLOTS;14,584.0-19,5680 i -I 1- BSA ND LINER;11,418.5- I tame- • • Image Project UVell History File Cover Page XMVLE 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. l.e' ~ - 1 ~~ Well History File Identifier Organizing (done> Two-sided III II'III II III II III ^ Rescan Needed III II~III II II III III RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria .~-- Project Proofing BY: Maria Scanning Preparation BY: aria Production Scanning Stage 1 Page Count from Scanned File: ~~ J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES _ BY: Maria Date:' ~ ~ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. Isl P iuimiumiuii m~, NO /s/ NO 111 .liiumimumii R.=~a~~ed miuuimaiiu BY: Maria Date: /s/ Comments about this file: DIGI AL DATA Diskettes, No.3 ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: + ~„~ =TOTAL PAGES (Count does not include cover sheet ,t/~ /~ /s/ '~ r Date: Date: ~ ~ `j / / _~ x 30 =~ Date: ~ ~~~~~ a ,.«e~~ed iuumiiiiuiiiu 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AL A OIL AND GAS CONSERVATION COWISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 17 Plug Perforations r Perforate r Other r Alter Casing r PUII Tubing f;"4' Stimulate - Frac r Waiver E Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 207 -143 3. Address: 6. API Number: - Stratigraphic f'-` Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 23374 - -c? 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25660, 25663, 385172 . 1J - 174 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ... none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19708 feet Plugs (measured) None true vertical 3157 feet Junk (measured) None Effective Depth measured 19612 feet Packer (measured) 11429 true vertical 3155 feet (true vertical) 3136 Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 20 120 120' SURFACE 3971 13.375 4021 2270 PRODUCTION 3886 10.75 3927 2249 PRODUCTION 8153 9.625 12081 3205 RECEIVED B -SAND LINER 8151 5.5 19568 3155 B -SAND LINER 88 4.5 19656 3155 SEP 2 5 2012 Perforation depth: Measured depth: 12245'- 14582', 14584' - 19568' SCANNED NNECI A 2013 AO r' True Vertical Depth: 3216-3198', 3198' -3155' SW� Tubing (size, grade, MD, and TVD) 4.5, L - 80, 9721 MD, 2932 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER MLZXP LINER HANGER PACKER @ 11429.MD and 3136 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ]ri r Service r Stratigraphic 16. Well Status after work: ' Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ian Toomey e 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature -----"---- - Phone: 263 -4773 Date 1 2 4,,, 4z. ....-- .....-___—_ R D q: Z6-n---- Form 10-404 RevIVeld *2 1. Submit Original Only _ / y ,i KUP • 1J -174 ConocoPhilhips 01 Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inci (°) MD (ftKB) Act Btm (ftKB) 500292337400 WEST SAK PROD 92.99 19,278.18 19,708.0 conoaiimitsps `"" Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well Config'. MULTIPLE LATERALS -1J-174 9/14/201212:23:54 PM SSSV: NONE 0 9/25/2011 Last WO: 9/8/2012 44.41 12/31/2007 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: GLV C/O ninam 9/14/2012 HANGER, 23 f , Casing Strings ' : � Casing Description String 0... String ID ... Top (ROB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 44.4 120.0 120.0 94.00 H Welded 4'�. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 17' , ' " SURFACE 133/8 12.415 49.5 4,020.5 2,272.8 68.00 L - 80 BTC �.' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 95/8 8.835 40.4 12,080.0 3,206.1 40.00 L -80 BTCM 10.75 "x9.625" CONDUCTOR, 44120 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd B -SAND LINER 5 1/2 4.950 11,416.5 19,656.5 3,156.3 15.50 L -80 BTC -m Liner Details ESP Top Depth MANDREL, IIIM (ND) Top Incl Nomi... 2,403 , Top (ftKB) (ftKB) ( Item Description Comment ID (in) ,.r. 11,416.5 HANGER BAKER MLZXP LINER HANGER PACKER - Length above collet profile 7.000 , 11,429.4 PACKER BAKER MLZXP LINER HANGER PACKER 7.000 11,437.8 HANGER BAKER FLEX LOCK HANGER SECTION 7.000 J X BUSHING CROSSOVER BUSHING 7' Hyd 563 X 5-1/2' 563 4.920 Hyd O US G y Y 11,444.5 SBE BAKER SEAL BORE EXTENSION 4.750 19,568.4 3,154.7 89.03 XO Reducing CROSSOVER 5.5" x 4.5 3.958 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... String Wt... String ... String Top Thrd Seal Bore Diverter 1 4 1/2 I 3.940 I 11,383.2 I 11,454.7 I Set Depth (TVD) ... I 12.60 J L -80 I IBT SURFACE, Tubing Strings 50.4,021 __ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ini. TUBING 41/2 3.958 22.8 9,720.8 12.60 L -80 IBTM ESP Completion Details MANDREL, 4,467 Top Depth (ND) Top Inc] Nomi... -.... Top (ftKB) (ftKB) (0) Item Description Comment ID (in) 22.8 22.8 0.00 HANGER VETCO GREY HANGER w/ FULL JT BELOW 4.500 9,633.9 2,922.5 84.03 DISCHARGE UNIQUE PRESSURE DISCHARGE SUB / 1 9,675.7 INTAKE TTC RECEIVER/XO w/ PERFORATED INTAKE 9,686.2 SEAL TANDEM SEAL SECTION 9,700.0 MOTOR EAP MOTOR 526 SP1, 210 HP, 2380V -53A 9,716.7 GAUGE A -WELL I -PUMP SENSOR 9,718.8 Centralizer MOTOR CENTRALIZER ESP MANDREL Perforations & Slots 9,551 IIIIII Shot Top (ND) Btm (ND) Dens ® Top (RKB) Btm (RKB) (ftKB) (ftKB) Zone Date (sh.° Type Comment DISCHARGE, 9,634 ® 12,245 14,582 WS B, 1J -174 12/15/2007 32.0 SLOTS Slotted liner, 2.5 "x .125" , 4 INTAKE, 9,676 MEM circumferential rows/ft, 3" centers SEAL, 9.666 MOTOR, 9,700 staggered 18 deg, non - slotted ends GAUGE, 9,717 Centralizer, MN 14,584 19,568 3,154.7 WS B, 1J -174 12/15/2007 32.0 SLOTS Slotted liner, 2.5 "x .125" , 4 9,719 circumferential rows/ft, 3" centers Seal Bore ONener, - - - staggered 18 deg, non ends 11,363 - 11,455 PRODUCTION = Notes:. General & Safety 10.74' - 12. 06', 4 60 End Date Annotation 9 62 SLOTS, � 12/28/2007 NOTE: MULTI - LATERAL WELL 1J - 174 (B SAND), 1J - 174L1 (D - SAND) 12,245 - 14,582 {I SLOTS, 6/21/2008 NOTE: View Schematic w/ Alaska Schematic9.0 14,58419,588 e - SAND 4/21/2012 NOTE: CROSSOVER IN CASING @ 3527' LINER. I 11,417 - 19.656 D-SAND LIN6R, 11.355- 19,689 ., ate' ■ Mandrel Details Top Depth Top Port (TVD) 1001 OD Valve Latch Size TRO Run Stn Top (ftKB) (R Fl Make Model (in) Sew Type Type ON (psi) Run Date Cont.. 2,402.6 CAMCO KBMG 1 ESP SOV BK 0.000 9/13/2012 2 4,487.4 2,352.7 83.52 CAMCO KBMG 1 ESP DMY BK 0.000 9/5/2012 3 9,550.9 2,914.3 84.99 CAMCO KBMG 1 ESP DMY BK 0.000 9/5/2012 ■ ■ I l I ■ • TD (1J-174), f 19,708 • • anac ©Phillips Time Log & Summary We!/view Web Reporting Report Well Name: 1J - 174 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 8/30/2012 9:00:00 AM Rig Release: 9/8/2012 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase ' Code Subcode T Comment 08/30/2012 24 hr Summary Moved rig over well 1J-174, rig accepted @ 9:00 hours. Rigged up to kill well. Bled gas off well to tank. Bullheaded 140 bbls down tubing and 590 bbls IA. Monitor well and perform fluid level shot, fluid @ 3177' MD. 00:00 00:15 0.25 MIRU MOVE SFTY P Hold PJSM, HRW and HRC on moving rig. 00:15 02:00 1.75 MIRU MOVE MOB P Spot pipeshed and pwer pack down pad. 02:00 03:00 1.00 MIRU MOVE MOB P Spot sub over Well 1J -174. 03:00 04:30 1.50 MIRU MOVE MOB P Set pits, pump room, motor room and boiler room in place. 04:30 05:30 1.00 MIRU MOVE MOB P Set rock washer and pipeshed in place. 05:30 09:00 3.50 MIRU MOVE RURD P Work on rig acceptance check list. SIMOPS, pick up tools and trash. 09:00 12:00 3.00 MIRU WHDBO RURD P Load pipeshed w/ 302 joints of XT -39 drill pipe. Take on 580 bbls of sea water w/ 3 % KCL. SIMOPS, @ 10am rig up hard line to tiger tank and scaffolding. 12:00 12:30 0.50 MIRU WHDBO RURD P PJSM, Rig up pressure gauge on tubing. R/U lines in cellar to bleed gas. Take returns to tiger tank. 12:30 14:00 1.50 MIRU WHDBO OTHR P Pick up lubricator and pull BPV, tubing and IA had 750 PSI on them. 14:00 15:00 1.00 MIRU WELCTI PRTS P Rig up and test lines to tiger tank to 1500 PSI. 15:00 19:00 4.00 MIRU WELCTLOPNW P PJSM, bleed gas off well to tiger tank. Tubing and IA both had 750 PSI and bled down to 75 PSI, shut well in. Observed a gain of 52 bbls to tiger tank. 19:00 21:30 2.50 MIRU WELCTLCIRC P PJSM, Bullhead well. Pump 75 bbls of 120° sea water w/ 3% KCL followed by 75 bbls of 80° sea water w/ 3 %KCL down tubing @ 5 BPM= 200 PSI. Shut down and swap over to IA. Pump 315 bbls of 120° sea water w/ 3% KCL followed by 275 bbls of 80 ° seawater w/ 3 % KCL. Stage pump rate to 6 BPM= 675 PSI. Pumped a total of 140 bbl down tubing and 590 bbls down IA. 21:30 21:45 0.25 MIRU WELCTL RURD P Shut down pumps, observed 275 PSI on IA and tubing. Held PJSM, line up to tiger tank to bleed off gas to tank. 21:45 22:30 0.75 MIRU WELCTL OPNW P Bleed pressure off tubing and IA to 0 PSI. Page 1 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 MIRU WELCTL OWFF P Monitor well w/ tubing and IA fully open to tiger tank. No gain observed in tank. 23:00 23:15 0.25 MIRU WELCTL OWFF P Shut in choke for 10 min to ensure well dose not build pressure. No pressure observed. 23:15 00:00 0.75 MIRU WELCTL OTHR P Rig up and shoot fluid level . Fluid level @ 3177 MD 08/31/2012 Nippled down tree and nipple up BOPE. Installed installation plate on tubing hanger. Tested BOPE t/ 250/3500 PSI. w/ 4" and 4 -1/2" test joint. Bob Noble of AGOCC witnessed BOP test. 00:00 01:00 1.00 MIRU WELCTL OPNW P PJSM, IA =50 PSI and tubing =0 PSI. Bled a small amount of gas off to tank. Monitor pressures. 01:00 01:15 0.25 MIRU WHDBOOTHR P Check pressure. IA =0 PSI and tubing =0 PSI. Set BPV as per Vetco rep. 01:15 02:00 0.75 MIRU WHDBO RURD P Take down scaffolding around tree. 02:00 03:30 1.50 MIRU WHDBO NUND P Nipple down Vetco tree. Set blanking plug and check all lock down nuts as per Vetco rep. 03:30 06:00 2.50 MIRU WHDBO NUND P Nipple up BOP stack and choke line. SIMOPS, P/U and M/U floor valves, scud launcher and test joint. 06:00 06:30 0.50 MIRU WHDBO RURD P Charge accumulator unit. 06:30 07:00 0.50 MIRU WELCTL OPNW P Bleed pressure off IA to tiger tank. 07:00 08:15 1.25 MIRU WHDBO RURD P Rig up to test BOPE. 08:15 09:30 1.25 MIRU WHDBO NUND T Bell riser leaking, take apart and fix leak. 09:30 10:45 1.25 MIRU WHDBO BOPE T Attempt to test stack, blinds rams leaking. Take apart and fix leak. 10:45 11:15 0.50 MIRU WHDBO BOPE T Test top pipe rams, observed leak on lower rams. Tighten bolts to fix leak. 11:15 18:00 6.75 MIRU WHDBO BOPE P Test BOPE w/ 4" test joint to 250/3500 PSI f/ 5 min each. Test #1: Top pipe rams, CV 1,12,13,14 b be and manual kill. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test le‘ #3: Lower IBOP. Test #4: Dart valve, 4" Demco, CV 5,7, and 8. Test #5: Floor valve, CV 4,6,and 2. Test #6: HCR kill. Test#7: Manual choke. 18:00 20:30 2.50 MIRU WHDBO NUND X PJSM. Blanking plug leaking. Decision made to break stack and install installation plate. The installation plate ensures that the leaking pack -off can be pulled. Re- installed blanking plug and nipple stack back up. Page 2 of 9 Time Logs • • Date From To Dur _ S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:15 0.75 MIRU WHDBO BOPE P Cont. to test BOPE t/ 250/3500 PSI w/ 4" test joint. Test #8: Annular and break in stack. Accumulator test: System pressure= 3000 PSI, 200 PSI attained after 26 sec, full pressure attained after 162 sec. Nitrogen bottle average= 2050 PSI. 21:15 21:45 0.50 MIRU WHDBO RURD P Pick up tools from beaver slide. 21:45 23:30 1.75 MIRU WHDBO BOPE P Rig up 4 -1/2" test joint. Test annular and top pipe rams with 4 -1/2" test joint to 250/3500 PSI. 23:30 00:00 0.50 MIRU WHDBO BOPE P Rig down test joint. Rig up and test blind rams, CV 3 and 10 t/ 250/3500 PSI. 09/01/2012 Completed BOP test t/ 250/3500 PSI. M/U landing joint and pull hanger to rig floor. POOH laying down 4 -1/2" tubing w/ ESP control line. Laid down 309 joints of 4 -1/2" tubing , 3 GLMs, 161 cannon clamps, 3 protectolizers, 14 flat bands and 2 flat guards. 00:00 01:00 1.00 MIRU WHDBO BOPE P Cont to test BOPE. Test CV #10 , #3 and blinds to 250/3500 PSI. Record on chart recorder. 01:00 01:15 0.25 MIRU WHDBO RURD P Rig down test equipment and blow down choke. 01:15 02:00 0.75 COMPZ RPCOM OTHR P PJSM, pull blanking plug and BPV. 02:00 02:30 0.50 COMPZ RPCOM RURD P Rig up tubing equipment. 02:30 03:00 0.50 9,617 9,617 COMPZ RPCOM RURD P Make up landing joint. BOLDS and pick up centralift tools. 03:00 05:00 2.00 9,617 9,617 COMPZ RPCOM RURD P PJSM. Rig up Centralift tools and hang sheave in derrick. 05:00 06:15 1.25 9,617 9,617 COMPZ RPCOM THGR P Pull hanger to rig floor" Hanger pulled @ 215K. Fill hole with 30 bbls of fluid. Monitor well. 06:15 07:30 1.25 9,617 9,617 COMPZ RPCOM PULL P Terminate ESP cable. Lay down hanger and make up floor safety valve. 07:30 12:00 4.50 9,617 7,960 COMPZ RPCOM PULL P PJSM, UD 4 -1/2" IBMT tubing w/ ESP cable, P /U= 105K. UD 56 joints, 2 SS bands and 30 cannon clamps. Fill hole w/ tripple displacement every 15 joints. 12:00 16:15 4.25 7,960 5,037 COMPZ RPCOM PULL P PJSM, cont. to lay down 4 -1/2" tubing w/ ESP cable f/ 7960' MD t/ 5037' MD. 16:15 17:45 1.50 5,037 5,037 COMPZ RPCOM RURD P PJSM, change out spool on ESP control line spooler. 17:45 00:00 6.25 5,037 118 COMPZ RPCOM PULL P Cont to lay down 4 -1/2" tubing f/ 5037' MD t/ 118' MD. Laid down three GLMs and discharge sub. Tripple displacement every 15 joints= 147 bbls. 09/02/2012 R/D Centralift equipment. Test lower rams w/ 4" and 4 -1/2" test joint to 250/3500 PSI. M/U clean out BHA. RIH picking up drill pipe t/ 9607' MD. Stand back 19 stands and cont. RIH picking up pipe t/ 9607' MD. Start washing down, no down weight. Pump seawater w/ SAFELUBE down annulus. Page 3 of 9 Time Logs • Date From To Dur S. Deoth E. Death Phase Code Subcode T ` Comment 00:00 01:15 1.25 118 0 COMPZ RPCOM PULL P PJSM, Break and L/D Centralift screen & pump assembly. Recovered 161 cannon clamps, 14 SS bands, 2 flat bars and 3 protectolizers. Total 309 joints of 4 -1/2" tubing and 3 GLMs. 01:15 03:30 2.25 0 0 COMPZ RPCOM RURD P PJSM, R/D Centralift equipment, sheave and elephant trunk. 03:30 04:30 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor. 04:30 05:00 0.50 0 0 COMPZ WELLPF OTHR P Break pup joint off GLM to be used in clean out BHA. 05:00 06:45 1.75 0 0 COMPZ WHDBO BOPE P Rig up and test lower pipe VBR rams w/ 4" and 4 -1/2" test joints to 250/3500 PSI. Record on chart. 06:45 07:30 0.75 0 0 COMPZ WELLPF OTHR P Set 9" ID wear bushing. 07:30 08:00 0.50 0 0 COMPZ WELLPF PULD P Pick up Baker tools. 08:00 09:00 1.00 0 0 COMPZ WELLPF PULD P PJSM, Rig up casing tongs and M/U BHA #1, clean BHA w/ casing_ scaraper. 09:00 12:00 3.00 0 0 COMPZ RIGMNT SVRG P Service rig and work on MP2s. 12:00 12:45 0.75 0 76 COMPZ WELLPF PULD P PJSM, pick up BHA. 12:45 21:30 8.75 76 9,607 COMPZ WELLPF PULD P Single in the hole from pipe shed f/76' MD t/ 9607' MD. Lossing down weght — 7500' MD. 21:30 23:00 1.50 9,607 9,607 COMPZ WELLPF TRIP P POOH and stand back 19 stands t/ 7847' MD. Single in w/ the remaining drill pipe in the pipe shed. 23:00 00:00 1.00 9,607 9,702 COMPZ WELLPF WASH P Wash down f/ 9607' MD t/ 9702' MD @ 10 BPM =2200 PSI, 100% loss to hole. 10 RPM w/ 6K Tq. P /U =125K, S /O =OK, ROT =70K (Have to rotate to go down) Losses for tour= 719 bbls. X9/03/2012 Wash down to 9797' MD. Unable to get down, lack of down wait. Pump 700 bbls of slick brine in annulus. Well start foaming, shut annular and bled foam from SAFELUBE out to tiger tank. Cont. to wash down t/ 11363' MD. POOH t/ 8190' MD and set strom packer 54' below table. Attempt to BOLDS to change pack -off. Lost 2937 bbls today. 00:00 00:30 0.50 9,702 9,797 COMPZ WELLPF WASH P PJSM, Cont to wash f /9702' MD t/ 9797' MD. Pump @ 3.5 BPM= 80 PSI. Rotate @ 20 RPM= 6K Tq. 00:30 00:45 0.25 9,797 9,702 COMPZ WELLPF TRIP P Unable to get pipe down hole at a acceptable rate due to not have any down weight. Pumped away —250 bbls washing down one stand. POOH t/ 9702' MD to spot slick brine w/ SAFELUBE in the annulus. P /U =130K, S /O =OK. 00:45 02:15 1.50 9,702 9,702 COMPZ WELLPF COND P Fill pits and re -stock brine supply at rig. Add .3% SAFELUBE to active pits and Vac trucks. 02:15 05:00 2.75 9,702 9,702 COMPZ WELLPF CIRC P PJSM, Pump 700 bbls of 8.6 ppg brine w/ .3% SAFELUBE down annulus @ 5 BPM =50 PSI. Page 4of9 • • Time Logs Date From To Dur S. Depth E. Depth Phase - Code Subcode T ' Comment 05:00 05:45 0.75 9,702 9,702 COMPZ WELLPF OWFF P Monitor well. Well started foaming @ surface due to the SAFELUBE addition. Closed annular preventer to prevent a mess due to the foaming. SICP =70, 0 PSI on drill pipe. Bled foam in casing to tiger tank down to 0 PSI. 05:45 06:00 0.25 9,702 9,702 COMPZ WELLPF OWFF P Monitor well at tiger tank, static. Shut in casing at IA, pressure increased to 10 PSI. with 0 PSI on drill pipe. 06:00 06:30 0.50 9,702 9,702 COMPZ WELLPF OWFF P Open IA to tiger tank, bled foam off to 0 PSI. Monitor for 30min, static. 06:30 10:30 4.00 9,702 10,929 COMPZ WELLPF WASH P Wash f/ 9702' MD t/ 10929' MD @ 8 BPM =1900 PSI. ROT @ 30 RPM w/ 8 K Tq, 10 -12 K WOB. 10:30 12:00 1.50 10,929 10,929 COMPZ WELLPF COND P Re -stock rig brine supply and fill pits with 8.6 ppg brine. * Lost 2209 bbls of brine for tour. P /U= 125K, S /O =OK, ROT= 75K. 12:00 13:00 1.00 10,929 10,929 COMPZ WELLPF COND P Cont t/ take on brine in pits. 13:00 14:15 1.25 10,929 11,308 COMPZ WELLPF WASH P Wash down f/ 10929' MD U 11308'_ MD. Pump @ 8 BPM =1750 PSI. P/U =130 K, S /O= OK. ROT= 75K, TQ= 8 -10K. 14:15 15:00 0.75 11,308 11,363 COMPZ WELLPF WASH P Wash down f/ 11308' MD t/ 11363' MD, 25' inside RAM hanger. Pump @ 9 bpm= 2400 PSI, ROT @ 30 RPM w/ 9K Tq. Set down and torqued up to 10K and stalled rotary. P/U several times, no progress. Decision made to POOH. 15:00 16:45 1.75 11,363 8,190 COMPZ WELLPF TRIP P PJSM, POOH f/ 11360' MD t/ 8190' MD. P /U =107K, S /O =45K. 16:45 17:00 0.25 8,190 8,190 COMPZ WELLPFSFTY X Hold PJSM on picking up storm packer. 17:00 19:00 2.00 8,190 8,190 COMPZ WELLPF PULD X Pick up tools from beaver slide. Pull wear bushing and M/U strom packer. RIH and set strom packer 54' below table as per Baker. P /U= 107K, S /O= 45K. 19:00 19:45 0.75 8,190 8,190 COMPZ WHDBO PRTS X Rig up and pressure test strom packer to 1500 PSI on chart for 10 mins., draw down test to 0 PSI. 19:45 20:15 0.50 8,190 8,190 COMPZ WHDBO PULD X Lay down 2 single and running tool. 20:15 20:30 0.25 8,190 8,190 COMPZ WHDBO SFTY X Hold PJSM on pulling pack -off. 20:30 00:00 3.50 8,190 8,190 COMPZ WHDBO RTWH XT Attempt to back out lock down. One of the lock down pins was damaged prior to the rig getting on the well. The pin will not back out. SIMOPS, change out ESP spool. * Losses for tour= 764 bbls. 09/04/2012 Continue Attempting to pull lock down, Unsuccessful, release from storm packer POOH w/ scraper f/ 8190' 00:00 00:30 0.50 8,190 8,190 COMPZ WELLPF OTHR XT Continue attempting t/ back out pack off lock down, No Go. Page 5 of 9 1 Time Logs • Date From To Dur S. Depth E. Depth Phase - Code Subcode T Comment 00:30 02:00 1.50 8,190 8,190 COMPZ WELLPF OTHR XT Work on mp2, insp #2 mud, install steam lines out t/ cuttings box. 02:00 03:30 1.50 8,190 8,190 COMPZ WELLPF SLPC XT Slip & cut drill line, adjust brakes, service draworks. 03:30 12:00 8.50 8,190 8,190 COMPZ WELLPF OTHR XT Load pipe shed w/ 4.5 tbg, simops work on top drive stand jump 12:00 14:00 2.00 8,190 8,190 COMPZ WELLPF OTHR XT R/U & pressure test lines t/1000 psi to bleed tank , close annular preventer, line up to choke house w/ choke closed, p/u release storm packer, pump 30 bbls through kill line, bleed off pressure every hour. 14:00 17:00 3.00 8,190 8,190 COMPZ WELLPF OTHR XT Load pipe shed w/ 4.5 liner rabbit and strap 17:00 18:00 1.00 8,190 8,190 COMPZ WELLPFOTHR XT Attempt t/ inject JR -2 packing t/ pressure test pack off w/ no success 18:00 18:45 0.75 8,190 8,190 COMPZ WELLPFOTHR XT Pull storm packer 18:45 19:30 0.75 8,190 8,190 COMPZ WELLPFOTHR XT Clean & clear rig floor 19:30 22:00 2.50 8,190 8,190 COMPZ WELLPFOTHR XT P/U tools f /slide and r/u to set wear ring, set wear ring RILD's, pooh, running tool hanging up in ram cavities, R/D wear bushing running tool. 22:00 00:00 2.00 8,190 3,380 COMPZ WELLPF TRIP P Pooh f/ 8190' t/ 3380' Losses for Tour= 158 bbls, OA pressure @ 23:30 hrs= 175 psi X9/05/2012 RIH with Baker Retrivamatic Packer to 11,336' MD set and test casing (Good) POOH UD 4" dp, UD Baker Packer and clear rig floor. 00:00 01:00 1.00 3,380 76 COMPZ WELLPF TRIP P Continue Pooh w/ scraper run t/ 76' 01:00 02:00 1.00 76 0 COMPZ WELLPF PULD P UD BHA comp. 02:00 02:45 0.75 0 0 COMPZ WELLPF OTHR P Clean & Clear rig floor P/U bha Compents for next run. 02:45 03:15 0.50 0 0 COMPZ WELLPF PULD P M/U BHA test packer 03:15 07:30 4.25 0 9,454 COMPZ WELLPF TRIP P RIH w/ test packer t/ 9454' 07:30 09:30 2.00 9,454 10,201 COMPZ WELLPF TRIP P Single in hole from shed w/ 15 jts weight pipe 9 jt 5" drill collars for push pipe, 09:30 10:00 0.50 10,201 11,336 COMPZ WELLPF TRIP P Continue tripping in the hole f/ derrick t/ 11336' set test packer 10:00 12:15 2.25 11,336 11,336 COMPZ WELLPF OTHR P Fill annulus w/ 8.6ppg brine e,43- 4 e,43- 12:15 13:00 0.75 11,336 11,336 COMPZ WELLPF PRTS P Pressure test casing U 1500 psi f/ 30 min charted 13:00 13:15 0.25 11,336 11,335 COMPZ WELLPFOTHR P Release Packer 13:15 22:00 8.75 11,335 0 COMPZ WELLPF TRIP P Pooh laying down dp w/ test packer f/ 11336' 22:00 22:15 0.25 0 0 COMPZ WELLPF PULD P Break down Packer and lay on rig floor. 22:15 22:45 0.50 0 0 COMPZ WELLPF TRIP P M/U Mule shoe and RIH with 8 stand from Derrick 22:45 23:00 0.25 0 0 COMPZ WELLPF PULD P PJSM, and lay down Packer using the Beaver Slide. Page 6 of 9 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 0 0 COMPZ WELLPF TRIP P Continue laying down drill) pipe in shed. 23:30 00:00 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. Total losses for the tour= 306 bbls. 09/06/2012 M/U ESP assembly run in the hole t/ 1017', R/U wireline wait on centrilift, pump wrong size, Run in hole test t/ 1000 psi, run completion to 2290' MD. 00:00 00:30 0.50 0 0 COMPZ WELLPF OTHR P Pull Wear ring 00:30 01:45 1.25 0 0 COMPZ WELLPF RURD P Rig up centrilift equipment & tools 01:45 05:45 4.00 0 0 COMPZ WELLPF PULD P P/U centrilift assembly, fill motor w/ oil, R/U sheave string up ESP cable. 05:45 07:45 2.00 0 0 COMPZ WELLPF OTHR P Attach control lines t/ assembly, test same. 07:45 10:00 2.25 0 1,017 COMPZ WELLPF RCST P RIH w/ 4.5 completion & ESP Assembly t/ 1017' 10:00 11:00 1.00 1,017 1,017 COMPZ WELLPF RURD P R/U wireline t/ run centrilift pump 11:00 14:15 3.25 1,017 1,017 COMPZ WELLPFOTHR T Pump wrong size wait on Centrilift to mobilize right pump to location. Losses for tour= 58.7 bbls. 14:15 14:30 0.25 1,017 1,017 COMPZ WELLPF RURD P R/U slick line 14:30 17:15 2.75 1,017 1,017 COMPZ WELLPFSLKL P RIH w/ slick line set ESP pump, Pooh, RIH w, packoff, Pooh. 17:15 18:15 1.00 1,017 1,017 COMPZ WELLPF PRTS P R/U & test tubing t/ 1000psi f/ 15 min. 18:15 19:00 0.75 1,017 1,017 COMPZ WELLPFSLKL P RIH w/ slip stop on slick line, POOH, R/D slick line 19:00 20:30 1.50 1,017 1,017 COMPZ WELLPFOTHR P Bring more cannon clamps to rig floor, refuel and start generator for ESP coil unit. 20:30 20:45 0.25 1,017 1,017 COMPZ WELLPFSFTY P PJSM on RIH with ESP Completion while testing ESP power cable. 20:45 22:45 2.00 1,017 2,013 COMPZ WELLPF RCST P RIH with 4.5" ESP Completion F/ 1017' T/ 2013' Install cannon clamps every jt. Test power cable good. Topped off TBG with KCL Brine. 22:45 00:00 1.25 2,013 2,290 COMPZ WELLPF RCST P Continue RIH with 4.5" ESP Completion F/ 2013' T/ 2290' MD. Losses for tour= 85 bbls. 09/07/2012 Continue RIH w/ completion & ESP cable t/ 7734' splice cable, RIH & land hanger @ 9722', Rig up and test 2 -way, trouble testing with landing ; oint. (Cutting o- rings) 00:00 09:00 9.00 2,290 7,734 COMPZ WELLPF RCST P Continue RIH w/ 4.5 completion w/ ESP line t/ 7734' testing line every 1000'. 09:00 12:30 3.50 7,734 7,734 COMPZ WELLPF OTHR P Change out spool & splice ESP cable together. 12:30 15:45 3.25 7,734 9,700 COMPZ WELLPF RCST P Continue RIH w/ 4.5 completion w/ ESP cable t/ 9700' 15:45 19:15 3.50 9,700 9,700 COMPZ WELLPFOTHR P M/U hanger, install penetrator, cut line splice ESP cable to hanger. 19:15 20:00 0.75 9,700 9,700 COMPZ WELLPFOTHR P Test ESP cable. (Good) 20:00 21:00 1.00 9,700 9,720 COMPZ WELLPF RCST P Land Hanger and RILDS and test hanger void 21:00 21:45 0.75 9,720 9,720 COMPZ WELLPF OTHR P R/U DHD and shoot two check shots, Fluid level @ 950' . Page7of9 . Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 21:45 22:15 0.50 9,720 9,720 COMPZ WELLPF OTHR P Test hanger bushing and void to 5000 psi and held for 5 mins each (Good) 22:15 22:45 0.50 9,720 9,720 COMPZ WELLPF OTHR P UD landing joint, set 2 -way check valve. 22:45 23:00 0.25 9,720 9,720 COMPZ WELLPF OTHR P M/U head pin to landing joint, P/U and change seals on isolation sleave, M/U to hanger. 23:00 00:00 1.00 9,720 9,720 COMPZ WELLPF OTHR P R/U test equipment and attempt to test 2 -way, after several attempts no success leaking. 09/08/2012 Redressed isolation sleeve seals and determined that 2 -way check not holding, pull 2 -way and replace, test to 1000 psi for 5 min (Good) N/D BOP, N/U adapter flange & tree test same, freeze protect well, set BPV and secure well. R/D for move to 1J -162. 00:00 01:30 1.50 9,720 9,720 COMPZ WELLPF OTHR T Pull landing jt. fill stack with H20, CLOSE BLIND RAMS & ATTEMPT T/ TEST TWC through choke, unsuccessful, bleed & blow down 01:30 04:00 2.50 9,720 9,722 COMPZ WELLPF OTHR T P/U landing joint and redress seals on isolation sleeve & pack seals with JR2 to protect seals for install, Attempt test agian, (No sucuess) observed leak through side port. 04:00 06:00 2.00 9,722 9,722 COMPZ WELLPF OTHR T UD test joint and pull two -way check, replace 2 -way check valve, R/U again and retest to 1000 psi (Good) Record same 06:00 08:00 2.00 9,722 0 COMPZ WHDBO NUND P PJSM, N/D BOPE. 08:00 08:30 0.50 0 0 COMPZ WHDBO OTHR P Check ESP cable and motor integrity 08:30 10:30 2.00 0 0 COMPZ WHDBO NUND P N/U adapter and tree. 10:30 11:00 0.50 0 0 COMPZ WHDBO OTHR P Test hanger void, adapter flange and lock downs to 5000 psi and hold for 10 min. 11:00 12:00 1.00 0 0 COMPZ WHDBO OTHR P R/U and test tree to 5000 psi for 10 min. (Good) 12:00 12:15 0.25 0 0 COMPZ WHDBO OTHR P R/D test equipment and pull 2 -way check. 12:15 12:45 0.50 0 0 COMPZ WHDBO OTHR P R/U to freeze protect well, Test monitor on ESP (Good) 12:45 13:15 0.50 0 0 COMPZ WHDBO DMOB P Stow skate rail and iron roughneck 13:15 14:00 0.75 0 0 COMPZ WHDBO OTHR P R/U Little Red, PJSM, PT lines to 2000 psi and checl for leaks. (Good) 14:00 15:30 1.50 0 0 COMPZ WHDBO OTHR P Freeze protect with 40 bbls diesel down tbg and 140 down IA, with 100 psi ICP and 0 FCP while blowing down steam lines. 15:30 16:15 0.75 0 0 COMPZ WHDBO OTHR P Observed well on vac with 0 psi on both sides, blow down and R/D circulating lines, blow down water lines and disconnect power lines. 16:15 16:45 0.50 0 0 COMPZ WHDBOOTHR P Set BPV and remove double annulus valve, install blanking flanges and secure tree. 16:45 17:45 1.00 0 0 COMPZ MOVE MOB P Remove all interconnects Page 8 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:00 0.25 0 0 COMPZ MOVE MOB P Lift stairways and landings, jack pipe sheds and boiler complexes. Rig released @ 18:00 hrs 9 -8 -2012 Page 9 of 9 • ~~~: ~~ z ~.. ~~~ _ , ~ ~. ~~ ~ ~~ 4 ~ ~ ~ ~ k~Y ~ ~ s~ ~ ~ ~, ~ ~• ~,. > '~ xw_ ~ . 9 ~~ ~ _. ~ .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary tntemet Files\OLK9\Microfilm_Marker.doc • • Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-137 (206-108) and 1J-174 (207-143) Attachments: 1J-174 Multi-lat RAM.pdf; 1J-137 Multi-lat drawing.pdf; Centrilift Y-Tool Schematic Draft.pdf Tom, I didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1 J-174 ~~`~ - ~ ~'~. 3~ ~ ~ ~ ~~ \'~~ ~...~,.. ~.~~ - ~ ~t"'~~ The completion shown is correct, except for the depths of the ESP and GLM's. 1 J-137 The completion shown is completely wrong. It now has an LEM installed and a Y-block ESP completion downsized to 3-1/2" tubing. ~ Brett ~acf~r ~Dri[l"ing e~'WelCs 4Norfqver~ngineer 'Work# (907~ 265-6845 : ,. ~~~~~ ~ ~v y~ ~ ~ ~~~, J ~~~ Cell# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: 1J-137 (206-108) and 1J-174 (207-143) Brett, I am reviewing the 404s for the recent workovers on these multi-lateral wells. Would you please provide drawings that show the well in a"horizontal formaY' such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontal drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. Thanks in advance. Tom Maunder, PE AOGCC 9/30/2009 Wellhead / Tubing I Tree: 13-318" x 4712", 5,000 psi ~~ Insulated Condudor: 20" 94# K-55 x 34" 0.312 WT +~- 80' ~onocoPhi I I i ps 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMT"") System 392T MD • 10-314" 73.2#, ~-ao, Dual lateral Completion BTC Casing Crossover 1 J-174 H B D L P , 2208' MD - GLM, Camco, 4112" x t" MJ ~- KBMC,set67deg COMPLETED I 4013' MD - 73-318" Casing Shoe, 68#, L-80, BTC, 2270' ND, 76 deg inc 9617' MD - Bottom of Motor Centralizer CentraliR 418 HP KMHG Tubing String 4-1/2" 12.6q, L~O, IBTM 3.958" ID. 7.837" Drift 11J55' MD -7" %9-SIB" RAM Hanger 5.960" Lahral DrMt 10 ~ 3.688" Mainbore Drilf ID 11366' MD - D-Sand Casing Exit, 3128' ND, 83 deg inc 'D' Sand Lateral ~ ~ 4713" 17.6#. Hydril 521 and BTC, L$0 Blank and Slotted Liner i112" Guide Shce, 6.00" OD Fpuinment S~ecifications 7" X 9-5/8" RAM Junction Mainbore Drift: 3.68" Lateral UriH: S.EO" RAM Hange~ISeal 8ore Diverter OD: 8.775" Overall Length of RAM Junction: J8.3 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD~ 4-112" Lateral Entry Module LEM OD: 6.99" Mainbore Drik wlo DiveNers: 1.68" Mainbore Drift w/ Isolation Diverter: 2.50" Lateral Dritt wl "FB" Diverter. J.68" OD ol Diverters: ).68" 19669' MD - 41/2" Casing Shoe, 11.61l, L-80 BTC, _ 11415' MD - 3.562" DB Nlppk 3056~ ND --... . i J773' ND. 84 deg 71360' MD - 4Y." z 9318" RAM Seal Bore ~ Diverter (SBD) with 3.88" Seal Bore 11 E25' MD - MLHR Production Anchor 4-112" 126N Hydril 521 and/ IBTM Tubfng ,oe~,~MO-ao~om ~g~ Sand Lateral / f Seal Assembly 174t6'MD-)"%9-5/B"ML27~ ~ 4.75"SeaIOD Liner Hanger Pxker 3.875" ID .~,~~Z•. ~5,5~/, Hytlril 521 and BTC. LAO Blank antl Slotted Liner q_~~Z" Oronge Pxletl Shoe 17444' MD - Sealbore Receptacle s.75" ID B X~U6~NE5 Bnkcr ()il TooLs With Dive rters and Isolation ~ Lateral Ac cess "F8" Diverhr ~lerallsolatioNlNe :TWv Ilns lalkd'nLEMI ~natal~~EM1 9d9" ML TorqueMazler Facke~ Poal~ive Wtchirg Colkt ( Intlicahs Correct Location Snap InlSnap Out Orlenting Protik Vosilive Laca~ing Collel ~n~m~n~nig~~~or~~mm ~m~.aio~~e~~e. ~a~e..ii.ow~a~ RAMWng~~) Ramp ~pper5eals xal eo~e ror wre.a~ I~olalion Diverter 3.68" ID Snap InSnap Out Posttlve Lxatinq Colkt Lateral Access wnaow . ~ mowe...«erv.~.emn«..:w m~,-r~a~yo~..n..~ ~ ____ u~e,.~i:ovno~ ~ow~rseab ~ ~ '"_ ._'__.~_..... ~ 19656' MD - 5-t12" Casing Shoe, 15.5#, L-80 BTCM , 3156' ND 12080' MD - 9-518" Casing Shce, 40.0#, L-80 BTC , 3205' ND, 85 deg inc m eaxer Huqnea zooe. rnis a«umM~ m,y ~o~ ee ~eo~oe~ea o~ a~:nromea, m wnok o. m pan, in any ~orm or by °"9'ro` any means electronic or mec~anical, inclutling D~~~VYing, recordirg, o~ by any inlormatbn atorage aM 200] WeslSak Wal Laleral Compklion -iroJUcer reUiaval syatem now k~wwn or hereaXer viventetl, withoN writtm permnsion Irom Baker Hughes IM. I~ May 18. 2008 ~~~~ ~Y Dave Bjork r~~~ Z ~ • .~~~~u • STATE OF ALASKA ~~~~; ~: ~ro9 ALASKA OIL AND GAS CONSERVATION COMMISSION- 3~85~8 Oil ~'~aS ~Ot13° GptTlfiljSS1011 REPORT OF SUNDRY WELL OPERATIONS Alnchorage 1. Operations Pertormed: Abandon ^ Repair Well Q . Plug Pertorations ^ Stimulate ^ .Other ^ Alter Casing ^ Pull Tubing Q 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 ^ 207-143 / ° 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23374-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 121', GL 81' AMSL 1 J-174 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25660, 25663, 385172 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19708' feet true vertical 3157' feet Plugs (measured) Effective Depth measured 19612' feet Junk (measured) true vertical 3155' feet 4.5" Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3973' 13.375" 4014' 2270' INTERMEDIATE 3886' 10.75" 3927' 2249' INTERMEDIATE 8153' 9.625" 12081' 3205' SLOTTED LINER 8151' S.5" 19568' 3155' BLANK LINER 88' 4.5" 19656' 3156' Perforation depth: Measured depth: slotted liner from 12245'- 14582', 14584'-19568' true vertical depth: 3216'-3198', 3198'-3155' ~a~yq ~gll9 ^~ ~ p / I/~ `(~; 4. Nx ;":r+}I~j~'I ;VI C.~'`~P ~ L~ab?~ Tubing (size, grade, and measured depth) 4.5", L-80, 9654' MD. Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cements ueeze summa q ry' V".SC,~,~~ ~ ~ ~ ~ ~~ t7 Intervals treated (measured) '~ not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 987 355 35 -- 221 Subsequent to operation 1386 136 898 -- 232 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 Signature `~+~j~ `~ Title Phone: 265-6845 Wells Engineer ~///Z ~ /~ g Date (/ l C ` ar Sh n Allsu Drake 263-4612 Form 10-404 Revised 04/2006 1 17-1 '~' ~. ~f :_c: ~ Submit Orig~ina~ljOnly ,r i~~" ~ X71 • ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 28, 2009 9:02 AM To: 'Packer, Brett B' Subject: RE: 1J-137 (206-108) and 1J-174 (207-143) Brett, OK, so are the BOT drawings in the process of being updated? For me and other users not so intimately involved with these wells, the straight drawings are somewhat confusing to use. I look forward to your reply. Tom From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-137 (206-108) and 1J-174 (207-143) Tom, I didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1 J-174 The completion shown is correct, except for the depths of the ESP and GLM's. 1 J-137 The completion shown is completely wrong. It now has an LEM installed and a Y-block ESP completion downsized to 3-1/2" tubing. ,~ Brett Backer Drilling eZ `WeQs 'Won~yver~ngineer 'Work# (907) 265-6845 Cell'# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: iJ-137 (206-108) and iJ-174 (207-143) Brett, I am reviewing the 404s for the recent workovers on these multi-lateral wells. Would you please provide drawings that show the well in a "horizontal format" such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontal drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. 4/29/2009 Wellhead I Tubing I Tree: 13-316" x 4112", 5,000 psi `~ Insulated Conductor: 20" 94# K-55x34" 0.312 WT+/-80' ~onoeoPhillips AS MU6XE5 2007 West Sak Producer COMPLETED Baker OilTool6 with Rotating self-Aligning Multilateral (RAMT"") System 2394'MD-GLM, Camco, 4112"x1"KBMG Dual lateral Completion 3927' MD - 10-314" 73.2#, L-80, 1 J -174 H B D L P j BTC Casing Crossover 448T MD -GLM, Camco, 4112" z 1" KBMG W O _09 9505' MD -GLM, Camco, 4112" x 1" KBMG 4013' MD - 13-316" Casing ~ Shoe, 68#, L-80, BTC, 2270' .. g58T MD-A-Well Discharge Pressure Sub ND, 76 deg inc 9711' MD -Bottom of Motor Centralizer CentraliR 418 HP KMH Tubing String 41/2" 12.6#, L-00, IBTM 3.958" ID. 3.833" Drift 11366' MD - D-Sand Casing Exit, 3126' ND, 63 deg inc rpa Sand Lateral 11355 MD - T' X 9-518" RAM Hanger 5.960" Lateral Drift ID 4112" 11.6p, Hydrll 521 and BTC, L-00 3.688" Mainbore Drift ID J Bknk and Slotted liner 7" X 9-518" RAM Junction Mainbore Drift: 3.66" Lateral Drill: 5.60" RAM HangerlSeal Bore Diverter OD: 6.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 41f2" Lateral Entry Module LEM OD: 6.99" Mainbore Drill wlo Diverters: 3.68" Mainbore Drift w/ Isolation Diverter: 2.50" Lateral DriN wl "FB" Diverter: 3.68" OD of Diverters: 3.68" 'M Lateral Acc ess "FB" D'varter Lateral Isolalbnanlectlon 1 lmbly naae allea m LEMI nnat.n4LEM1 9AR" ML TorqueMaster Packer Pos6lve t.archb9 CoNet Indicates Correct Location Snap lNSnap OUt ~ Posllive Locallrg Colbt Orientb9 Profile Iamamaac Axpnm.m al LEM ,n Lateral Diverter Lateral lsolatbn kaM ea,gen Ramp Upper Seah Seal Bore for Lateral Iaohtbn Diverter snap ln5nap oat 1se° m Poalnye LDD.urm collet ~ Lateral Access Wlntlow ~ I { k~ ~ IP.ovw«POSawe Yhral a«na vv I-sleral leobtbn i ~y rauiubkq dwnen J Lower Seah q (seah inside RAM ` 1 Seal Bore Dheden S Spear used for running and pu8ing diverters 5-112" Guide Shce, 6.00" OD 19669' MD - 4112" Casing Shoe, 11.6#, L~0 BTC, _ 11415 MD - 3.562" DB Nlppk 3056' ND ~ 3133' ND, M deg 11360' MD - d-Yx" x 9-5/8" RAM Seal Bore / Diverter (SBD) with 3.68" Seal Bore 11425 MD - MLHR Protluctlon Arrehor 4112" 12.6# Hydrll 521 an IBTM Tubin ~ ~ _ ~~ 454'MD-Bottom 11 pp rp' Sand Lateral o f Seal Assembly 11416' MD - 7" X 9-518" ML21fP 4.75" Seal OD Liner Harper Packer 3.875" ID 5-112" 15.5#, Hydril 521 antl BTC, LAO Blank and Slotted Liner 4112" Orange Peeletl Shce 11444' MD - Sealbore ,~" Receptacle _ 4.7s° ID ~ 19656' MD - 5-1 /2" Casing Shce, 15.5#, I L-BO BTCM , 3156' TVD 12060' MD - 9-5/6" Casin , B , 85 deg ine ®Baker Hughea 2008. This document may not be reproduced or dlalnbuted, in whole or m part, In any form or by Dxp ~' any means electronic or mechankal, kncl,Ming pMtocopying. recordbq, er by any Information storage and 1007 west Sak Dual Lateral ComDlellon •producer rehbval system ,ww known or hereaner invented, without wrltlen permiaabn Imm Baker Hughes Inc. ~~~ March 16, 2009 m'~~ tan Toomey vlalan ea. 1 • • `-~. KUP • 1J-174 ~ CQIIQCQIrI il~~IpS `~ Well Attributes Max Angle 8 MD STD ° Ale,,:~_r. itr._ Welibore APVUWI Field Name ( ) MD (kKB) .Act Btrn (kKB) Well Status Prod/Inj Type Intl ( _ / 500292337400 WEST SAK . ~ PRODUCING, 9299 19,278.18 19,7080 ~ G ment M2S (ppm) KB-Grd (ft) Rig Release Dab Data An ration ,End Date 1 ll M LT PLE T M SSSV: NONE 17 17/2005632 ~ ` 0 ~ 1/1/2009 La St WO. ~ 3/1$12009 44.41 12/31!2007 e CO )g MU I E AL J _, _ _ Sche_rnatic Actu ( ) 4, 4/ .46 A A tati n Depth kK8 End Date al.. Annoation End Date 9 Last 7a I ~ I Rev Reason ESP WORKOVER ~ 4/17!2009 a ~Casin Strin s ^ , Casing Description _ Str ng O.. Shang ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd CONDUCTOR 20 19.124 44.4 120.0 120.0 94.00 H-00 Welded -:, Casing Description String 0... String ID ... Top (kKB) Set Depth (t... Set Depth (ND) ... String WI... String ... String Top Thrd HANGER, % 'SURFACE 13 3/8 12.415 49.5 4,020.5 2 272 8 68.00 L-80 BTC ;:: ~ Casing Description %String 0... String ID ... Top (ftKB) Set Depth (t... Sef Dopth (ND) ... String Wt... String ._ String Top Thrd 9NTERMEDIATE I 9 5/8 8.835 40 4 12,080.0 3 206.1 40.00 L-80 BTCM Casing Description ~~.String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR. µ.t2p B-SAND LINER ~ 5 1/2 4.950 11 416.5 19,656.5 3,156.3 15.50 L-80 BTC-m Liner Details Top Dep[h ESP iNDI Top Intl MANDREL, - Top (kKB) iklce) (°) Item Dascripllo n Comment ID (in 2.39a ~~. 11,416.5 HANGER Baker 7" X 9-5/8" MLZXP Liner Hngr Pkr-Length above collet profile 7.OC 111,429.4 I PACKER Baker 7" X 9-5/8" MLZXP Liner Hanger Packer O.D. 8 44"/ LD. 7.00" 7.OC j 11,437.8 'HANGER Baker "Flex-Lock" Hanger Section O.D. 8 31" ! LD. 7.00" 7.OC ~ 11,443.1 XO BUSHING Crossover Bushing 7" Hyd 563 X 5-1/2" Hyd 563 O.D. 7.65" / LD. 4.92" 4.92 11.444.5 SBE I Baker "Seal Bore Extension" O.D. 6.25" / LD. 4.75" 4.75 ~~ Str g2 '~Str ~~~ Strin9 ~~~String Top Thrd Set Depth(ND)... Str ~~~ ~~ TO ( se Seal Bore Diverter ' ~ 3.940 i _ 12. 0 l L-80 IBT 11454.7 I i I 3601 ( Tubing Strings - Tubing Descr ption String 0... String ID ... Top (kKB) Sat Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE, 50-a,021 - ESP Completion 41/2 3.958 35.9 9,713.0 1260 L80 IBTM Com letion De Top Depth tails ESP MANDREL, dp6] -- (ND) kK8) Top_ (ftKB) ( Top Intl (°) Item Descriptio n Comment ID (in ~' 35.9 35.9 0.00 HANGER Vetco-Gray 11"x 4 1/2" Hanger w/ Lull p below w/ 4.909" Top coon. 4.SC I 9,587.3 2,917.7 8425 ESP Unique Pressure discharge sub 3.95 "! DISCHARGE ' 9,662.2 2,925.4 83.90 ESP INTAKE _- -_ TTC XO Coupline perforated intake 3.83 ~- I 9,671.8 SEAL Upper Seal Section ~ OAC 9,678.7 SEAL Lower Seal Section O.OC 9,685.6 ESP MOTOR O.OC ESP Motor 418 HP, KMH 2610V/98A I 9.708.0 GAUGE . A-Well I Pumo Sensor O.OC Esa n,nu mran~er I owe ~enueuce~ .~ MANDREL. s.sos Other In Hole reline retrievab I eQu s, valves, um s, fish, etc- - _ _ Top Depth (TVD) Top Intl '~ Top (kK6) (kKB) (°) Description Comment Run Date ID (i °SP 9 632 2922 3 84.04 PUMP ASSY SET 45" ESP PUMP (42.05' TOTAL LENGTH) SET 4.5" 3/17/2009 0.0 DISCHARGE. 9,587 IDBD PACK OFF ON TOP OF ESP. SET SLIPSTOP PUMP ASSY. -~ r __- 9,632 ` ESP INTAKE. Pel'I OratlOrlS ~ SIOtS . ~ 9.662 - _ _ S of SEAL, 9,6]2 SEAL. 9,fi75 e ToP (TVD) Bim (TVD) ~ D n ' I ESP MOTOR. (ftKB) (ftKB) Zona Date ash... Type Commend Top (ftKB) Btm (kK8) ~ \ 9.686 ~ 582 WS B, 1J-174 12/15/2007 32.0 SLOTS Slotted liner, 25"x .125" , 4 12,245 14 GAUGE, 9,]08 Cemralaer , circumferential rows/([, 3" centers s n t staggered 18 deg, non-slotted ends seal Bore Dlvener tt 3sa rt ass l - ---- - '- ----_-- 14,584, 19,568 3,154.7 WS B, 1J-174 12/15/2007 32.0 SLOTS Slotted liner, 25"z .125" , 4 TERMEDwTE. - - a;-: clrcumterenttal rows/ft, 3" centers 1 so-r2ASO sLOrs. sta eyed 18 d gg eg, non-slotted ends 12,265-16,562 I - - - -- - -- ' sLOrs. '~, Notes: General & Safety tasad~rsssa B-SAND _ _ End Date I Annotation LINER. '12/28/2007 NOIE~ MULTI-LATERAL WELL 1J-174 (8-SAND), 1J-174L7 (D-SAND) '. I Mandrel D ' etails Top Depth Top i - - - _-~~ _ _ Port ', _ - - - _ ' (TVD) Intl I OD Valve Latch Size !TRO Run ''„ SIn Top (kK8) (ftKB) (°) I Maka Model (in) Serv ~ TYPe Type (inl (Pail Run Date 1 2,393.8 CAMCO KBMG 1 ESP SOV BK-5 O.000I 0.0 3/27/2009 CAMCO KBMG 1 ESP DMY BK 5 0.000 0.0 3!16/2009 3 9,504.8 2,912.2 86.74 CAMCO KBMG _ 1 ESP .DMY BK 5 0.000 0.0 3/16/2009 _~I I® rD(u-nat. _ 1 ts.]os r Time Log & Summary ConocoPhiilips ~~e~,,.,z.,. ~~~ ~epa~,~g Report Well Name: 1J-174 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/14!2009 1:00:00 AM Rig Release: 3/18/2009 3:00:00 PM - - -- Time Lomas _ Date Frorn To Dur S. Depth E Depth Phase Code _ Subcode T Comment 3/14/2009 2a hr Summary Move in mats. Move rig in and set down. Accepted Nordic Rig 3 @ 0100 hrs on 3-14-09. Berm up and load its w/ 8.6 KWF. Pull BPV. Kill well. Install BPV, ND Tree and NU BOPE, Test BOPE. 00:00 02:00 2.00 COMPZ MOVE MOB P Relocate double mats from 1J-137 to 1J-174 and set. Move in Nordic rig 3 and set down. Acce ted Nordic ri 3 0100 hrs on ~ ~~~~~~~~~ 3-14-09. 02:00 06:30 4.50 COMPZ RPCOM OTHR P Berm up, Spot tanks, mud shack and highline trailer. Load pits 8.6 ppg 6% KCL water. ~ZU to Lubricate out BPV -BPV leakin alon w/ Master and swab valve-Call out valve sho to rease tree valves. RU lubricator ull BPV. 06:30 09:30 3.00 COMPZ WELCTI KLWL T RU circ. lines and attempt to PT, valves and hoses to kill tanks frozen. Applied heater to thaw lines and valves. Re laced two valves. 09:30 10:00 0.50 COMPZ WELCTI KLWL P Pressure test lines to 250/2500 psi. Opened well, IA press - 690 Tbg 490 psi. Bled IA down to 240 psi and Tbg to 340 psi. Start well kill by pumping dwn IA taking returns out tubing. Pumped 35 bbls with no returns. 2BPM w/ICP 390 and 420 FCP. 10:00 15:00 5.00 COMPZ WELCTI KLWL P Switched to pump down tubing to flush w/150 bbls 4 BPM @ 520 psi IA, 70 psi tubing. Switched to pump down IA. Pumped 4 BPM @ICP 530 psi, Increased rate to 5 BPM 400 psi. Pumped 670 bbls. Shut down monitor well, after 15 min IA 460 si. 15:00 15:30 0.50 COMPZ WELCTI KLWL P Pumped down tubing w/no returns, 2 BPM w/60 psi. 202 bbls. Shut down, monitor well, tbg 0 IA ,after 15 min IA had slight blow and 10 psi. Pumped 50 bbls down IA @ 6 BPM w/60 psi. Shut down monitor well. Well dead. Tb 0 IA 0 15:30 17:30 2.00 COMPZ WELCTI NUND P Set BPV. ND tree. Pumping 25 bbls down IA ever hour. Break off Bonnet and load out various valves. 17:30 20:30 3.00 COMPZ WELCTI NUND P NU BOPE _~ s ~ ~ ~~rge 'i €~f r1 Time Logs i _ _ _ _ _ Date_ From To Dur S Depth E. Depth Pha e Code Subcode T Comment ___ __ I 20:30 00:00 3.50 COMPZ WELCTI BOPE P RU to Test BOPE @ 250/2,500 psi - Test BOPE 24 hr Notice was given to AOGCC @ 0800 hrs on 3-13-09 and Waived by Lou Grimaldi 0655 hrs on 3-14-09. 3/15/2009 Continue. do Test BOPE @ 250/2,500 psi. Circulate well w/ Hot viscosified Sea water w/ 6% KCL. BOLDS and POOH w/ 4 1/2 ESP Com letion. ' 00:00 03:30 3.50 COMPZ WELCTI BOPE P Continue to Test BOPE @ 250/2,500 psi Draw down: 3,000 psi, 1,600 psi after - 200 psi in 29 sec., 3,000 psi in 2 minutes, 25 seconds. Nitrogen bottles - 4 @ 2,275 psi. 24 hr Notice was given to AOGCC @ 0800 hrs on 3-13-09 and Waived by Lou Grimaldi 0655 hrs on 3-14-09. 03:30 04:00 0.50 COMPZ WELCTL OTHR P Pull test dart. 04:00 06:00 2.00 COMPZ WELCTI CIRC P Notify Security and 1J Pad operator for venting of gas on 1J-174. Blow air thru kill to kill tank -clear. Open IA to Choke manifold - 160 psi, begin to bleed off and Pump 110 bbls thru BPV @ 2 bpm @ psi. To clear an as below BPV. 06:00 06:30 0.50 COMPZ RPCOM PULL P Pull BPV. MU landin ~t. BOLDS 06:30 08:00 1.50 COMPZ RPCOM OTHR P Load pits. Monitor well while MU top drive. 08:00 08:30 0.50 COMPZ RPCOM PULL P Unset hanger free w/87K, PU 4', Pump 150 bbls down tubing @ 8 BPM w/50 si. 08:30 10:00 . 1.50 COMPZ RPCOM CIRC P BD top drive and kill line out to kill tank. Pump 520 Bbls hot 6% KCL water down IA @ 9 BPM w/100 psi . Shut down well on vac. 10:00 11:00 1.00 COMPZ RPCOM PULL P Pull hanger to rig floor. Disconnect from Penetrator, break out tubing hanger and landing jt, LD. Change out elevators. String cable over sheave. 11:00 22:30 11.50 9,088 100 COMPZ RPCOM PULL P k dri in and stra in 4 1/2' tubin ,removing all jewelry, and spooling up the ESP cable. Pum in 40 bbls er hr. 22:30 00:00 1.50 100 0 COMPZ RPCOM PULD P Disconnect ESP cable. Pull sample from ESP Components. Found S lice to motor lead damaged and Motor B-Phase was shorted out to round. COMPZ RPCOM 1~~ 2 at a r~ Time Logs _ _ _ _ 'Date From To Dur S Depth E. Depth Phase Code Subcod_e__ T Commen_t____ __ __ 3/16/2009 24 hr Summary Prep Pipe shed, Change over to DP equip., RIH w/ DP and slip and cut Drill line. Standby for Cold weather variance on crane, Make other arrangements, POOH laying down DP. Changeover to RIH w/ 4 1/2 ESP Com letion. MU ESP motor ass and Seal sections and service. 00:00 00:30 0.50 COMPZ RPCOM PULD P Break down ESP components and lay down the same. 164 - Cannon X Cplg clamps 8 -Stainless Steel Bands 3 - Protectolizers 2 -Flat uards 00:30 01:30 1.00 COMPZ RPCOM OTHR P Change over to DP Equipment and re i e shed. 01:30 03:00 1.50 0 5,816 COMPZ RPCOM TRIP P MU Bull nose and RIH w/ 3 1/2 DP to 5,816' 03:00 04:30 1.50 5,816 5,816 COMPZ RPCOM SVRG P Slip and cut 84' Drill line and service ri . 04:30 05:30 1.00 5,816 5,816 COMPZ RPCOM OTHR P Strap and Tally new completion e ui ment 05:30 09:00. 3.50 5,816 COMPZ RPCOM OTHR T Standby with kill string in the hole for Crane verification to swap out ESP Cables ool 09:00 15:00 6.00 5,816 0 COMPZ RPCOM TRIP P POOH laying down 3 1/2" DP in pipe shed. Cannot unload pipeshed until weather warms up enough for the loader to work. 15:00 16:30 1.50 0 0 COMPZ RPCOM OTHR P RU ground spooler and loaded with new 9800' cable and applied Tioga heater to warm up. Removed old ESP a ui ment. Load new um . 16:30 21:00 4.50 0 0 COMPZ RPCOM RCST P PU erforated xover intake and two ~ts of 4 1/2" RIH. RU slickline. RIH w/109 sta a P35 ESP um .Set pump. Set packoff on to of um and PT to 1000 si. and chart for 15 min. Set slipstop. RD slickline. MU Discharge sub and crutch, Stand back in derrick 21:00 23:00 2.00 0 40 COMPZ RPCOM PULD P PU_and MU Centralizer A-Well I-Pump Sensor, Motor, Lower Seal section and Upper seal section and service the same. 23:00 00:00 1.00 40 40 COMPZ RPCOM PJSM, Start MLE over Sheave and connect Motor Lead to motor. 3/17/2009 Continue RIH w/ 4 1/2 ESP Completion to 9,700' and make final splice. Land Hanger and RILDS. ®e. ~ .~ #~~~ ~ of ~ Time Loas Date__ From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 40 90 COMPZ RPCOM RCST P RIH on Perf X-O Assy and 1 jt, install x-cplg clamp @MLE Splice. Meg motor: 17 Pi, 19 Pd, 35.24 Ti, 43.34 Tm, .057 Vx, .046 Vv, .7 Ph / Ph, 5G Ph/Grd. Plug in Cable : 16 Pi, 16 Pd, 58.64 Ti, 55.58 Tm, .107 Vx, .066 Vv, 3.052 Ph/Ph, 1 G PhlGrd. MLE: 2G Pi. 1st Jt: 16 Pi, 17 Pd, 60.08 Ti, 57.74 Tm, .087 Vx, :051 Vv, 3.052 Ph/Ph, 1G Ph/Grd. 02:30 13:00 10.50 90 8,664 COMPZ RPCOM RCST P MU and RIH w/ 2nd Jt, GLM# 3 assy, followed b 26 more 'ts. Meg Line. Continue to RIH w/ 4 1/2 ESP completion from derrick and Meg ESP Cable eve 1,000' 13:00 18:30 5.50 8,664 8,664 COMPZ RPCOM RCST T Stop RIH due to discharge pressure not reading while cable testing. - Trouble shoot downhole discharge gauge. - Contact town, plan to pull completion and change out gauge. - Picked up spare gauge. Spare gauge would not test. Gauge looked like it was previously used. - Tested Centrilift surface box on 1J-137 and obtained good readings. - Pulled gauge from old 1 J-174 completion. Gauge did not test. -Contacted town, plan to com lete the well with no discharge pressure since no replacement gau a was available. 18:30 20:00 1.50 8,664 9,645 COMPZ RPCOM RCST P , Continue to RIH f/ 8,664' w/ 4 1/2 ESP Com letion to 9 645'. PU and MU TBG hanger and landing jt. S ace out for Finals lice. 20:00 23:30 3.50 9,645 9,645 COMPZ RPCOM OTHR P Make final splice and test cable. Connect to Penetrator and meg again. Meg readings - Pi = 1,076 psi, Pd = 57 psi, Ti = 60.62, Tm = 58.64, Vx = .079, Vy = .071, Ph / Ph = 3.052, Ph/grd = 1G Used: 19 SS Bands, 162 x-cplg clamps, 2 flat guards, 3 Protectrolizers 23:30 00:00 0.50 9,645 9,713 COMPZ RPCOM HOSO P Land hanger w/ tail 9,713' 93k u . wt, 45k do wt. RILDS 3/18/2009 Test upper and lower seal. Set BPV. ND BOP and NU Tree. Test Tree ,Pull BPV. Freeze Protect well. Secure and dress Tree. Remove ESP spool and Spooling unit from rig floor. Move rig from over 1J-174. Move mats and clean cellar. RDMO, towards 3H Pad. 00:00 00:30 0.50 9,713 COMPZ RPCOM DHEQ P Test upper and lower seals on han er 5,000 si. ~~zg~; ~ ~fl; ~ n ~~ Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment I 00:30 01:00 0.50 COMPZ RPCOM MPSP P Set BPV 01:00 04:30 3.50 COMPZ RPCOM NUND P PJSM, ND BOP and set back. 04:30 05:00 0.50 COMPZ RPCOM NUND P NU Bonnet. 05:00 05:30 0.50 COMPZ RPCOM DHEQ P Conduct Final Meg of ESP Cable and ESP pump components. Pi = 1,011 psi, Pd = 58 psi, Ti = 62.96, Tm = 60.62, Vx = .063, Vy = .085, Ph/Ph = 3.0, Ph/Grd = 1G. 05:30 07:30 2.00 COMPZ RPCOM NUND P NU Tree. 07:30 09:00 1.50 COMPZ RPCOM DHEQ P Pull BPV set TWC PT tree 250/5000 si ull TWC 09:00 11:00 2.00 COMPZ RPCOM FRZP P PJSM w/ hot oil, test lines 2500 psi. Freeze protect well with 40 bbl of diesel down the tubing and 170 bbl of diesel down the IA. 11:00 14:00 3.00 COMPZ RPCOM RURD P Set BPV. Secure tree, stage mats for ram off well. 14:00 15:00 1.00 COMPZ RPCOM RLOC P PJSM. Move rig off well. Clean up cellar box, move T-mats, clean well site. Release Nordic Ri 3 15:00 hrs on 3-18-09 _ ~~ i ~.._..__.. - _ ~_ ~'~e 5 ~; 5 -1J-174 (PTD 207-143) Report of failed ESP Page 1 of 1 Maunder, Thomas E (DC)A) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, February 22, 2009 7:51 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem We11 Supv; NSK West Sak Prod Engr Subject: 1J-174 (PTD 207-143) Report of failed ESP Attachments: 1J-174 schematic.pdf; 1J-174 90 day TIO plot.jpg Tom, West Sak ESP producer 1 J-174 (PTp 207-143) experienced an ESP failure on 02/18/09 due to a down hote short. The plan forward is to convert the well temporarily to gas tilt similar to the 03/17/08 report. The welt will be on gas lift service until the ESP can be repaired with a RWO. A 10-404 will be submitted to document the change of ar#ificial lift method from ESP to gas lift for both 1J-174 and 1J-174L1. The paperwork will be submitted following the conversion work and gas lift service has begun. Attached is a schematic and a 90 day TIO plot. «1 J-174 schematic.pdf» «1 J-174 90 day TIO plot. jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 4/28/2009 ConotoPhillips Ai~ska, Inc f._°~ ~ a a°xti1r~_s r CONDUCTOR. 40-120 ESP MANDREL, -- 2,451 SURFACE. 504.021 ESP MANDREL. a.so7 ESP MANDREL - 9.622 • INTAKE. 9,64/ PUMP. 9.641 ESP MOTOR, 9667 _ SENSOR. 4~ 9.701 HANGER, t YS a se I ea Daanar. 11 aeall.ass NTERMEOIATE, 40 12.080 Sbned Linar. 12.24514.582 S ' sbnea Oror, ~ 1 1458419,586 e-SAN D LINER. -- 1161]-19.658 D-SAND 'i LINER, 11,35519.889 ~~~ ~ ~ _ _ a ~ ~.~: _-_. ~I_ ~~ ,,,11~ ~r,: ~: ro (u170. ~ ~ 19,708 • KUP 1 J-174_ Attributes a APIIUW I Fieltl Name Maz Angle 8 MD TD Well Status Drad/lnj Type Incl (°) MD (RKBI Act Btm (RKB) 12337400 WEST SAK PROD 9299 19,278.18 nt N23 (ppm) Drte Annotation End Date KB-0b IRI Rig ReNase DRe NONE 0 7/112008 Last WO'. 412812008 44 41 121312007 - - , Depth (RKBI ErM Drte ion Annotrtion End Date g Rev Reason SET ESP PUMP ASSY. SLIPSTOP. PACKOFF f_g Stria Deacnptlon Strilq 0... String ID ... Top (RKB) Set Depth (f Set Depth (ND) ... St g WI... St i g String Top Thrd JCTOR 20 19.124 40.0 120.0 120.0 94.00 Hd0 Welded , Descdplion String 0... String ID ... ToP I~B1 Set Depth (f... Set Dapth INDI ~~~ String Wt... SMng ... String Top ThM •• ,CE 13 3/8 12.415 49.5 4,020.5 2,272.4 68.00 L$0 BTC - -- Descdptbn String 0... String ID .. ~TOD (TN(BI ~Srt Depth IT... Set Depth (ND) Stnrq Wt... Stnrp .. String Top Thrd MEDIATE 9 5l8 8.835 40.4 12,080.0 3,205.3 40.00 L$0 BTCM -- Descnptlon String 0... String ID ... Top (RKB) Set Depth It... Set Depth (ND) ... St Ing Wt... St ng .. String Top ThN D LINER 5 1l2 4.950 11 416.5 19 656.5 3,156.3 15.50 L$0, __BTGm J I Details __. Top Depth . _-_. _. ... ~ __.- - ' (ND) Top Incl i ~B) (RKBI (°) Rem DSwriptlo n Comment ID in 1 I 7 L a ~ 4~ 3,136.1 PACKER 82.8 D. 7 00" 7.000 D. 8.44 I Baker 7" X 9-5l8" MLZXP Liner Hanger Packer O 7.8~ 3,137 1 82.88 HANGER Baker "Flex-Lock" Hanger Section O.D. 8.31" I LD. 7.00" 7.000] 3.1 ~ 3,137.8 62.88X0 BUSHING Crossover Bushing 7" Hyd 563 X 5-1/2"Hyd 563 O.f) 7.65"I LD. 4.92" ~~ 4.920 ~ 1.5 3,136.0 82.88 SBE I Baker "Seal Bore Extension" O.D. 6.25" / LD. 4 75" 4.750 ~ Des dptf String O . Str ng ID . -- Top (RKB) Set Depth (f Set Depth (ND) .. St Ing Wl . St Ing String Top Thrd are Drvener 4 12 3 940 11 360.1 11 454 7 - 3 139.2 _ 12.60 _ L$0 IBT 1fg3trings Descnpnon SMng O.. Strng ID Top (RKBI Set Depth If. Sat Depth (ND) .. St g Wt String String Top Th d ompletion 4 V2 3.958 35.9 9,7052 2,929.9 12.60 L$0 IBTM.. i -~ pletion Det Top Depth ails _-- - -_ ---_ __ -___._ IND) Top Incl (g) (RKBI (°1 hemDascrlptl on Comm_erlt _ _ _ 10(inl_ 5.9 35.9 -0.17 HANGER VETCO GRAY HANGER 3.958 4.0 2.923.5 83.99 INTAKE TTC XO Cplg Perforated Intake T3.958 3B~ 2,924.5 83.94~SEAL Tandem Seal Section, GS83D8 _ ~ 0.000- 7.4 2,925.8 ~ 83.SS~ESP MOTOR ESP Motor 418 HP, KMH 2610V 198A 0.000- 1.1 ~ 2,929.5 83.92 SENSOR ~A-Well I Pump Sensor - 0.000 7 ~~ aO~OI R'30~r~FNTRAI I]FR Mnlnr (:nnirAli~Pf ~.D~~ SLIP STOP TOP @9641' set Bun (ND) cans (RKBI Zone Drta (ah... Typs Commerrt -._ -- 3,198.OWSB,1J-174 ~12I152007~ 32.0 Slotted Slotted liner, 2.5'"x.125",4 Liner circumferential rowslft, 3" centers staggered 18 deq non-stoned ends 3,154) WS 8, 1J-174 121752007 32.0 Slotted Sloped liner 2 5 x .125" , 4 Liner circumferential rowslft, 3" centers staggered 18 deg non-slotted ends DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071430 Well Name/No. KUPARUK RIV U WSAK 1J-174 Operator CONOCOPHILLIPS ALASKA INC MD 19708 TVD 3157 REQUIRED INFORMATION Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Informat ion: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name t/€D D Asc ___ __ __ Directional Survey ~tpt Directional Survey ~D D Asc Directional Survey 4Rpt Directional Survey ~ D D Asc Directional Survey // I ~Rpt Directional Survey I, ~ LIS Verification (~D C Lis 16225"~Induction/Resistivity LIS Verification ~D C Lis 16226r/Induction/Resistivity k~Kpt LIS Verification (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments ~.ED C Lis 16227 Induction/Resistivity a'Log Induction/Resistivity 25 Col ~/L~og Induction/Resistivity 25 Col y[og Induction/Resistivity 25 Col /Log Induction/Resistivity 25 Col Compietion Date 12/30/2007 Completion Status 1-OIL Current Status 1-OIL UIC N 40 19708 Open 3/7/2008 40 19708 Open 3/7/2008 40 15308 Open 3/7/2008 PB 1 40 15308 Open 3/7/2008 PB 1 40 18141 Open 3/7/2008 PB 2 40 18141 Open 3/7/2008 PB 2 3994 19708 Open 5/7/2008 LIS Veri, GR, RPX, RPM, RPS, RPD, FET, ROP 3994 19708 Open 5/7/2008 LIS Veri, GR, RPX, RPM, RPS, RPD, FET, ROP 3994 15274 Open 5/7/2008 P61 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP 3994 15274 Open 5/7/2008 P61 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP 3994 18141 Open 5/7/2008 PB2 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP 3994 18141 Open 5/7/2008 PB2 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP 120 19708 Open 5/7/2008 MD ROP, DGR, EWR 120 3156 Open 5/7/2008 TVD ROP, DGR, EWR 120 15308 Open 5/7/2008 P61 MD ROP, DGR, EWR 120 18141 Open 5/7/2008 PB2 MD ROP, DGR, EWR API No. 50-029-23374-00-00 DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071430 Well Name/No. KUPARUK RIV U WSAK 1J-174 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23374-00-00 MD 19708 TVD 3157 Completion Date 1 213 0/2 0 0 7 Completion Status 1-OIL Current Status 1-OIL UIC N .ED C 16232 See Notes 0 0 5/7/2008 EWR in TVD and MD on EMF, CGM and PDF / graphics ~ED C 16233 See Notes 0 0 5/7/2008 P61 EWR in TVD and MD on EMF, CGM and PDF graphics rBD C 16234~See Notes 0 0 5/7/2008 P62 EWR in TVD and MD i on EMF, CGM and PDF graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~I Chips Received? 1~1~ Analysis Y / l~ Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~/ N Date: ~~noeoP hellips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ao~- r~-3 -~-~7y- 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 if needed 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. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. 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 Perry Klein at 907-659-7043, if you have any questions. 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 Fietd n~+e Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11/7/2008 1 E-16$ 204-200 15" NA 15" NA 3.4 11/7/2008 1E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-12a 207-070 15" NA 15" NA 3.4 11/7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1 J-152' 206-016 3' NA 3' NA 19.55 11 /17/2008 1 J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1 J-166 205-198 12" NA 12" NA 8.5 11 /7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11R/2008 ~~~~~D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUN 4 ~ 2008 REPORT OF SUNDRY WELL OPERgTIi & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Ot er 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 ^ 207-143 / ' 3. Address: Stratigrephic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23374-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 121', GL 81' AMSL 1J-174 8. Property Designation: 10. Field/Pool(s): 25661; 25660; 25663, 385172 Kuparuk River Field /West Sak Oil Pool . 11. Present Well Condition Summary: Total Depth measured 19708' feet true vertical 3157' feet Plugs (measured) Effective Depth measured 19612' feet Junk (measured) true vertical 3155' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3973' 13.375" 4014' 2270' INTERMEDIATE 3886' 10.75" 3927' 2249' INTERMEDIATE 8153' 9.625" 12081' 3205' SLOTTED LINER 8151' 5.5" 19568' 3155' BLANK LINER 88' 4.5" 19656' 3156' Perforation depth: Measured depth: slotted liner from 1224 5'-14582', 14584'-19568' true vertical depth: 3216'-3198', 3198'-3155' Tubing (size, grade, and measured depth) 4.5", L-80, 9705' MD. Packers &SSSV (type & measured depth) B-LAT LINER BAKER MLZXP PKR @ 11417' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2561 not available 75 -- 306 Subsequent to operation 1364 250 120 - 248 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: Oi10 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 Signature -~'~ ~~^ '~ Title Phone: 265-6845 Wells Group Engineer ` (~i Date ~ / ~ /® d Pre a Sh n Allsu Dra a 263-4612 Form 10-404 Revised 04/2006 U R I ~ ~ N A L Submit Ori mal Only /` k~"t f ~~' KRU 1 J-174 Conn~~rP~ill~p)s ,A1a~ca,1»c. 1J-174 - - API: 500292337400 Well? e: PROD An Ie TS: de assNS 1 SSSV Type: NONE Orig 12/30/2007 Angle @ TD: 90 deg @ 19708 ( oo:a.5oo, - Com letion: ID:3.958) Annular Fluid: Last W/O: Rev Reason: TBG PUNCH, GLV .: C/O i Reference Lo : 41' RKB Ref L Date: Last U date: 4/1/2008 Last Ta TD: 19708 ftKB Lest Tag [late _ - - : Max Hole Angle - 93 deg n 19278 Casinp String -ALL STRINGS ___ - ___~ Descn fon Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 4013 2271 68.00 L-80 BTC INTERMEDIATE 10.750 0 3927 2250 73.20 L-80 BTCM INTERMEDIATE 9.625 3927 12080 3206 40.00 L-80 BTCM D-SAND LINER TOP 4.500 11355 11366 3129 11.60 L-80 BTC/HYD 521 D-SAND WINDOW 9.625 11366 11367 3129 0.00 B-SAND SLOTTED LINER 5.500 11416 19568 3155 15.50 L-80 BTC/HYD 521 B-SAND LINER - 4.500 19568 19656 3156 11.60 L-80 BTCM _ sEA~ Tubin String -TUBING - - -- (9575-9581, Size To P _ 4.500 i 0 _ _ _ _Bottom TVD Wt Grade Thread i 9619 i 2921 i 12.60 i L-80 ~ IBTM ~_ - Perforations Summa Interval TVD - ___ Zone Status Ft SPF Date T Comment 12245 - 14582 3216 - 3198 WS B 2337 32 12/15/2007 Slots Slotted liner, 2.5'k .125" , 4 circumferential rows/ft, 3" centers staggered 1 8 deg, non-slotted ends 14584 - 19568 3198 - 3155 WS B 4984 32 12/15/2007 Slots Slotted liner, 2.5'k .125" , 4 circumferential rows/ft, 3" HANGER 't 1355.71360, centers staggered 1 8 deg, OD:6.625) non lotted ends Gas Lift Mattdrels/Vatve s St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt DAAND WINDOW 1 2209 1773 CAMCO KBMG DMY 1.0 BK-5 0.000 0 3/_2.6/2008 at3ss-71367, .Other (plugs, equip., etc.~ _COMPLETION De h TVD T e _ Descn ion ID 36 36 HANGER VETCO GRAY TUBING HANGER 3.938 8633 2815 TBG 2' TUBING PUNCH TO ALLOW CIRCULATION FOR FUTURE JOB 3.940 PUNCH 3/24/2008 9474 2906 SUB UNIQUE DISCHARGE SUB 0.000 9529 2912 PUMP 4 1/2 (48.73' OAL) TTC ESP ,SET 41/2 D&D PACKOFF ASSEMBLY ( 0.000 100" OAL-36" FROM F.N. TO KOBE-83" FROM F.N. TO CHECK) @ 47' SLM. 41/2 SLIP STOP 40' SLM set 12/28/2007 9557 2915 XO Screen TTC CROSSOVER w/SCREEN INTAKE 0.000 ~, 9568 2916 SEAL UPPER TANDEM SEAL SECTION GS63D6 FER HL SSCV SB/SB PFSA 0.000 CL5 9575 2916 SEAL LOWER TANDEM SEAL SECTION GS63D6 FER HL SSCV SB/SB PFSA 0.000 CL5 9581 2917 MOTOR BAKER KMH 418 HP MOTOR 0.000 9615 2921 GAUGE WEATHERFORD A-WELL GAUGE 0.000 xo eushing - -- ~ ' 9617 2921 Centralizer MOTOR CENTRALIZER 0.000 t7aa3-t7aaa, r. ' ' ^~ ^' 11355 3127 HANGER D-SAND RAM HANGERABOVE/BELOWCOLLET 3.940 oD:7s5o) ~ ^ ? 11360 3128 Seal bore D-SAND LINER SEAL BORE DIVERTER f/RAM HANGER to BELOW 3.940 Diverter COLLET PROFILE --- Other (plugs,_ equip., etc.) - B-SAND LINER DETAIL __ - - De h TVD T e Descri ion ID p~ 11417 3135 PACKER B-SAND LINER BAKER MLZXP LINER HANGER -ABOVE COLLET 7.000 7zzas7as6z) = PROFILE = 11429 3136 PACKER B-SAND LINER BAKER MLZXP LINER HANGER 7.000 11438 3137 HANGER B-SAND LINER BAKER FLEX-LOCK HANGER 7.000 11443 3138 XO Bushing B-SAND LINER CROSSOVER BUSHING 4.920 11444 3138 SBE B-SAND LINER BAKER SEAL BORE EXTENSION 4.750 Pert - 19568 3155 XO B-SAND LINER CROSSOVER 5.5" TO 4.5" 4.500 7as6a-7sss6) - _ .General Notes - _ -_ - ~I - Date Note = 2/28/200 NOTE: MULTI-LATERAL WELL 1J-174 B-SAND , 1J-174L1 D-SAND • C .' Time Logs Date From To Dur S__De th E. Depth Phase Code Subcode T COM 04/18/2008 17:00 20:00 3.00 COMPZ WELCT OTHR P No Press on tbg. Bleed gas cap from IA. Initial ress = 60 si. 20:00 20:30 0.50 COMPZ RPCOb OTHR P Shoot Fluid Level @ 300' 20:30 22:00 1.50 COMPZ RPCOb WOEO T Wait on Generator for spooler -found problem during pre-trip check -fix and sent out. 22:00 22:30 0.50 9,583 9,551 COMPZ RPCOh OTHR P BOLDS, Unseat hanger @ 100k and ull to ri floor. U wt 105k 22:30 23:00 0.50 9,551 9,520 COMPZ RPCOti PULD P Lay down landing joint and hanger 'oint. 23:00 00:00 1.00 9,520 9,426 COMPZ RPCOh TRIP P Pooh and stand back 4 1!2 completion: string w/ 100k up wt. Stand back 1 stand and thread ESP cable over sheave to spooling unit outside rig floor throu h Ele hant trunk. 04/19/2008 00:00 09:30 9.50 9,426 3,228 COMPZ RPCOh PULD P Continue to Pooh w/ ESP Completion, drifting tbg to 3.833" and strapping. Changing collar seals as pulled. Fill hole with 3 x's tb dis lacement. Found sand in tbg starting @ 3,228' out of the hole. Sand up various de ths. Difficul driftin . 09:30 11:00 1.50 3,228 3,228 COMPZ RPCOh PULD P PJSM, C/O ESP spools. 11:00 16:00 5.00 3,228 950 COMPZ RPCOI~ PULD P Flow check, resume POH, standing bk 4-1/2 tbg. Cont POH to perfed tbca 't. Ins ect. First shot indentations. No holes. Second shot with holes. 16:00 17:00 1.00 950 950 COMPZ RPCOh RURD P LD perf jt, arrange floor /ground area for slickline. 17:00 19:30 2.50 950 950 COMPZ RPCO SLKL P Held PJSM, Rih and attempt to pull slip stop and pack off. Unable to get to desired depth due to sand. RD slickline. 19:30 00:00 4.50 950 103 COMPZ RPCOh PULD P Pooh laying down sanded up 4 1/2 tbg and 't w/ sli sto and ack off. 04/20/2008 00:00 01:00 1.00 103 COMPZ RPCOh OTHR P Disconnect ESP Cable and pull TCC Pum . 01:00 03:30 2.50 COMPZ RPCOI~ OTHR P k o moto and pull oil sam les. To section was locked u . 03:30 04:30 1.00 0 COMPZ RPCOh OTHR P Meg motors and lay down them down. 12 of 17 Stainless steel bands were recovered, along w/ 274 x-cplg clamps, 3 protectorlizers, 2 flat uards. 04:30 05:30 1.00 COMPZ RPCOti OTHR P clean and clear rig floor of sand. 05:30 06:30 1.00 COMPZ RPCOh OTHR P RD ESP equip, clear floor. 06:30 08:00 1.50 COMPZ WELCT EORP P Flush BOP stack in prep for packoff re lacement. 08:00 14:30 6.50 COMPZ RPCO OTHR P PJSM, Bleed OA while load pipe shed with 3-1/2 DP workstring, prep same. Initial ress OA 125 si. Will not bleed dn. Total 20 bbls diesel taken durng__ bleed. Multi le shut ins with 125 si. Page 2 ssf 6 • Time Lo s ' Date From To Dur 5 D th E. De th Ph e Code Subcode T COM 04/20/2008 14:30 16:00 1.50 COMPZ WELC OTHR P PJSM, Pump seawater do OA, arrest press. 140 bbls needed to stop flow. Bleed to "0" si. 16:00 21:00 5.00 COMPZ WELCT EQRP P PJSM, R/U,Attempt to Back out the lower lock down screws and found 1 that was barely functional. Also found 1 that was not functional at all. Call B. Packer WO Eng. and reviewed the o tions and decided to attempt to ack void w/ lastic for seal. 21:00 21:30 0.50 COMPZ RPC06 SFEO P PT to 4,800 psi for 30 minutes w/ plastic. Call B. Packer WO Eng. and Ves Cash w/ Vetco Gray and inform them that we were able to test and that his met their approval. The decision was also made to paint the Lower Lock down screws that were non functional RED. 21:30 22:00 0.50 COMPZ RPCOti OTHR P Release from the 13 3/8 x 10 3/4 Pack off ass and la down ullin tool. 22:00 00:00 2.00 COMPZ RPCOh FRZP P Held PJSM w/ LRS. RU and PT LRS pump lines @ 2,000 psi. Pump 142 bbls of diesel to freeze rotect the 13 3/8 x 10 3/4 OA @ 2 bpm @ 1,425 psi max. Final SIP was 750 si OA. 04/21/2008 00:00 00:30 0.50 COMPZ RPCO OTHR P Set wear ring 00:30 01:30 1.00 0 211 COMPZ RPCO PULD P PU and MU 8.5" RCJB assy. 01:30 06:00 4.50 211 2,172 COMPZ RPCO TRIP P PU and Rih w/ 31/2 DP drifting the same w/ 61 jts. Arrange 4 1/2 tbg in derrick and prepare to stand back 20 stands. 06:00 07:30 1.50 2,172 298 COMPZ RPCOh TRIP P Pooh w/ 20 stands 3 1/2 DP. 07:30 20:00 12.50 298 8,570 COMPZ RPCOh TRIP P Continue to Rih w/ 31/2 DP drifting the same f/ 298', Pumping DP Vol. every 1,000'. Begin taki_n_g_wt (a7 8,570'. 95k u wt, 50k do wt. 20:00 20:30 0.50 8,570 7,595 COMPZ RPCOti TRIP P Pooh w/ 9 stands to 7,595'. 20:30 22:00 1.50 7,595 8,536 COMPZ RPCO TRIP P Continue to Rih w/ 31/2 DP drifting the same f/ 7,595' to 8,536', 22:00 00:00 2.00 8,536 9,214 COMPZ RPCO CIRC P Pump ball down @ 4 bpm @ 500 psi. When ball seated pressure increased to 650 psi, increased PR to 6 bpm @ 2,500 psi. Begin washing down f/ 8,570' to 9,214' w/ no returns as of midnight. 100k up wt; 50k do wt; 75k Rot wt 04/22/2008 00:00 05:00 5.00 COMPZ RPCOh TRIP P Continue to wash down frorr~y„ 1Q, tn• 10 049' .Circulating @ 6 bpm @ 2,500 psi. Encountered leak in wash i eon to drive. 05:00 06:30 1.50 COMPZ RIGMN RGRP T PJSM, Replace wash pipe /packing ass . Page 3 of & • Time Logs Date From To Dur S. De th E. D th Phase Code Su6code T COM 04/22/2008 06:30 11:30 5.00 COMPZ RPCOh TRIP P Resume RIH, wash /ream sands from 9-5/8 csg to top of RAM hgr 11350 ft. Taking wt. Must wash entire interval. 5 - 6 bpm, 2600 psi. Intermittent returns while conventional and reverse circ. 11:30 15:30 4.00 COMPZ RPCO CIRC P Re-cip rotate pipe with light sweeps. Sands to surface intermittent) . 15:30 22:00 6.50 COMPZ RPCO TRIP P PJSM, POH 3-1/2 DP from 11,350' to 200'. 22:00 23:30 1.50 COMPZ RPCOh PULD P UD BHA &cleanout reverse circjunk basket. Recovered 5 small metal feces. 23:30 00:00 0.50 COMPZ RPCOh OTHR P Unload RCJB, load tools and prep for runnin 2-7/8" cleanout ass . 04/23/2008 00:00 01:00 1.00 COMPZ RPCOh TRIP P Prep for cleanout run, PU 2-7/8" Muleshoe 01:00 03:00 2.00 COMPZ RPCOCV TRIP P Single in 66 joints 2-7/8", 10.4 Ib/ft, S-135 drill i e w/ muleshoe. 03:00 06:00 3.00 COMPZ RPCOh TRIP P Cont RIH 2-7/8 DP to 3280 ft. Take wt no further ro ress. 06:00 09:00 3.00 COMPZ RPCO CIRC P Mix /pump "Safe Lube" tubed seawater, reduce wall friction. 09:00 09:30 0.50 COMPZ RPCO RURD P Break top drive, blow do lines. 09:30 10:30 1.00 COMPZ RPCOti TRIP P Re ain mov ment con RIH. Wa h / rotate all stands do to 9065 ft. 10:30 12:00 1.50 COMPZ RPCOh CIRC P Reverse circ annulus volume. No returns. Attempt reverse /strip through bag. Pressures too high at 2800 psi. Will not fall through annular. Element smoking /high heat. Open annular, re for conv. circ. 12:00 19:00 7.00 COMPZ RPCO TRIP P Resume wash /rot (up 100, dn45, rot ,_ 85, 8.5 bpm - 2500 psi) 90% returns. 9065 - 13000 ft. 19:00 00:00 5.00 COMPZ RPCOh CIRC P Attem t to reverse circ. w/ no returns. Recip & Circ. down DP at 8.5 bpm, 2600 psi, 50 rpm's. Up wt: 105K, Dwn wt: 45K, Rot wt: 75K. Reverse / conventional circ equal time periods for balance while add SafeLube to system, seeing 70% returns. 1708 bbls lost toda . 04/24/2008 00:00 15:30 15.50 13,000 0 COMPZ RPCO TRIP P POOH laying down 3-1 /2 DP. LD 2-7/8 PAC. Fill with tri le dis lacement. 15:30 16:30 1.00 0 COMPZ RPCO RURD P PJSM, clear floor, RU for 4-1/2 ESP com letion. Pull wear rin . 16:30 19:00 2.50 COMPZ RPCOh RURD P Arrange pipeshed, load jewelry and tubin 19:00 21:00 2.00 COMPZ RPCOh PULD P PJSM, RU ESP cable sheave, string MLE over sheave to the rig floor. MU intake & 2 'ts tubin . 21:00 23:30 2.50 COMPZ RPCO SLKL P PJSM, RU slickline, set pump, set packoff & test to 1500 psi for 15 min. RDMO slickline. F~~~ 4 of & Time Logs Date From To Dur S. De th E. De th PhaSe Code Subcode T COM 04/24/2008 23:30 00:00 0.50 COMPZ RPCOh PULD P PU A-Well discharge sub, attach to tubin ,stand back in derrick. 04/25/2008 00:00 03:30 3.50 COMPZ RPCOh RCST P PU motor. Attach A-Well I-Pump sensor and 6" centralizer to bottom. Service motor. Lower into hole. PU tandem seal section and attach to motor. Co. man witnessed free rotation of shaft and proper oil filling of motor and seal sections. Attach MLE and connect capillary tube to A-Well sensor. 03:30 04:30 1.00 COMPZ RPCOh RCST P PU perforated intake and pump section and attach to seal section. Installed total of 3 protectolizers and 12 stainless steel bands on motor & seal section. Connect capillary tube to dischar a ressure sub. 04:30 06:00 1.50 COMPZ RPCO RCST P PU single jt of tbg, install GLM #3 and begin running stands from derrick installing x-coupling clamps on the first 6 joints above the GLM and then. on eve other'oint. 06:00 08:00 2.00 COMPZ RIGMN OTHR T Re air dams ed armour on ESP cable discovered at 650 ft. As yet undetermined source of damage. Possible dama a before delive to ri . 08:00 15:00 7.00 COMPZ RPCO RCST P Resume RIH 4-1/2 ESP completion F/650' -- 5091'. Megger ESP cable every 1000 ft and record P/U and S/O wts. At 3068 ft: PU wt = 57K, S/O wt = 55K, at 5091 ft P/U wt = 75K, S/O wt = 52K. 35K blocks 15:00 17:00 2.00 COMPZ RIGMN OTHR T Accidentally set slips set on ESP cable. crimped cable. Splice ESP. 17:00 22:30 5.50 COMPZ RPCO RCST P Resume RIH 4-1 /2 ESP completion F/ 5091' -- 8745'. Begin fill tbg /annulus at 10 0 ft intervals. Incom lete fill throu h ort. P/U wt = 93K, S/O wt = 45K. 35K blocks 22:30 00:00 1.50 COMPZ RPCOh RCST P RIH 4-1/2 ESP completion F/ 8745' -- 9300'. 04/26/2008 00:00 00:45 0.75 COMPZ RPCOti RCST P Finish RIH w/ ESP completion. ESP final de th 9705 ft RKB. 154 coupling clamps, 14 stainless bands ran in well. 00:45 02:30 1.75 COMPZ RPCO RCST P Clean rig floor, megger ESP cable--tested good. Tested A-Well au e-failed! ~~a{~e5esf~ Time Logs Date From To Dur 5. De th E. De th Ph se Code Subcode T COM 04/26/2008 02:30 03:30 1.00 COMPZ RPCO OTHR NP Discussed w/ Weatherford, indicated the gauge tested good at previous test at 8800 ft in the hole. Could possibly be a problem in the last 900 ft, but unlikely since the ESP cable tested OK. He indicated that the test box seems to be ok and it is most likely the gauge. Contacted Eric Hollar & Neil Spenceley for their preference on whether to pull the completion and replace the gauge. Both were in agreement that it is worth it to acquire the pressure data. Decision was made to ull com letion. 03:30 05:00 1.50 COMPZ RIGMN SVRG P Slip & Cut drill line. Weatherford called back indicating that the problem might be with their test box. They tested their test box on another well with the same results. They are heading back to their shop to get a new transceiver. 05:00 08:00 3.00 COMPZ RPCO WOEO T Take delive new A-Well transceiver re-test. Test successful. 08:00 14:30 6.50 COMPZ RPCO HOSO P MU tbg hgr/landing jt. connect penetrators, test upper hgr connections /elect terminals. Land . . _._ h r, confirm ali nment, RILDs. 14:30 15:00 0.50 COMPZ RPCO DHEO P Test tbg hgr /all seals 5000 psi 15 min. Test successful. No re-tests. 15:00 16:30 1.50 COMPZ RPCOti RURD P LD Idg jt, flush BOPE, blow do lines. 16:30 21:30 5.00 COMPZ WELCT NUND P PJ M ND BOP . c/o lower pipe rams to 2-3/8" for next well, Inspect annular element, break cap on annular. Annular element tore w/ large rubber pieces missing while trying to reverse circulate and stri throu h annular. 21:30 00:00 2.50 COMPZ WELCT Test ESP cable, NU tree, test packoff 04!27/2008 00:00 02:00 2.00 COMPZ RPCOh SFEO P Replace tubing pressure port needle valve and broken pressure gauge. Fill tree w/diesel. Test tree to 5000 psi for 10 min. RU lubricator and pull two wa check. 02:00 04:30 2.50 COMPZ RPCOh FRZP P PJSM, Freeze protect well w/ 35 bbls diesel down the tubing at 2 bpm 500 PSI and 190 bbls diesel down the IA at 5 bpm. Connect tbg /annulus, allow "U" tube. Press check well. "O" psi tb X annulus. Install BPV. 04:30 08:00 3.50 COMPZ MOVE DMOB P Clean cellar, prep for rig move. Clean pits, RD, break do all components. Secure for move. NORDIC RIG 3 RELEASED THIS DATE 4/27/08 0800 H P~ye ~ oaf ~5 • 1 J-174 Pre and Post Rig Summary DATE SUMMARY 1/24/08 SET SLIPSTOP CATCHER.CHANGE SHEARED SOV WITH 2000# TBG SOV IN STA #1 @ 2209' RKB.PULL SLIPSTOP CATCHER. JOB COMPLETE. 3/19/08 Travel from slb camp to 1J-pad.miru coil unit.perform bop test.Return in AM to continue with FCO. 3/20/08 UNABLE TO REACH TOP OF SLIP STOP DUE TO COIL LIMIT LOCKUP.RETURN WITH ANOTHER UNIT WITH PIPE STRAIGHTENER OR A DIFFERENT SIZE COIL.JOB INCOMPLETE. 3/22/08 MADE ANOTHER ATTEMPT TO REACH SLIP STOP WITH COIL WHILE PUMPING DIESEL MIXED WITH LUBE VIS.WAS ABLE TO MAKE ANOTHER 1200' BEFORE REACHING LOCKUP ON COIL LIMIT @ 8025' CTMD.RDMO AND LET iCOIL UNIT PERFORM TUBING PUNCH. 3/23/08 SHOT 2' PERF INTERVAL IN TUBING AT DEEPEST POSSIBLE DEPTH OF 8633'- 8635' MD. GOOD INDICATION GUNS FIRED. HOWEVER UNABLE TO INJECT INTO FORMATION AFTERWARDS, POOH TO CHECK GUNS, ALL SHOT FIRED, WILL RERUN PERF GUNS WITH HEAVIER CHARGES IN AM. NOTIFIED DSO OF DEPARTURE. 3/24/08 SHOT 2' PERF INTERVAL IN 4.5" TUBING AT 8633'-8635' MD. GOOD INDICATION GUNS FIRED. ABLE TO INJECT THROUGH PERF'S @ .75 BPM @ 650 PSI. POOH. ALL SHOTS FIRED. NOTIFIED DSO OF WELL STATUS. JOB COMPLETE. 3/26/08 SET CATCHER SUB @ 2213' SLM. PULLED UNSHEARED DCK AND SET DV @ 2209' RKB. PULLED CATCHER. PERFORMED INJECTIVITY TEST DOWN TBG: 1.5 BPM @ 150 PSI. READY FOR BPV. 3/29/08 T POT (PASSED), T PPPOT (PASSED), IC POT (FAILED), IC PPPOT (FAILED), FUNCTION TEST LDS'S 4/30/08 SET 1" SOV (2000# TBG SHEAR) @ 2450' RKB, PULLED CATCHER @ 2498' WLM, COMPLETE. s WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Conan. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-174+L1+PB1+PB2 AK-MW-5275614 Apri129, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-174+L1+PB1+PB2 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23374-00,60,70,71 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23374-00,60 Digital Log Images: 1 CD Rom 50-029-233 74-00,60,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date ~ ~ ~ ~ _ _ ~~- ~3 r~~3~ ~~233 1 La3~f ~o~ -~4~j Signed: /~3S WELL LOG TRANSMITTAL Ta: State of Alaska Apri125, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-174 PB2 AK-MW-527561 1 LDWG formatted CD Rom with verification listing. API#: 50-029-233 74-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 -.~ Date: ,~ ~ ~, ,° 2~a--1~3 Signed: G ~l~~ `~ WELL LOG TRANSMITTAL To: State of Alaska Apri125, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-174 PB1 AK-MW-527561 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-23 3 74-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _. Date: = ~; Signed: off--~~f 3 ~~~2 ~ WELL LOG TRANSMITTAL To: State of Alaska Apri125, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-174 AK-MW-527561 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 74-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 =~ __ . <,~ Zvi ~`.~' ., ~ '+3 ~i~ ~: a is ~J~a Date: Signed: ~o~ ~y3 ~i~~5~ West Sak packerless ESP produ~ 1J-174 (PTD 2071430) report of failed ESP Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 21, 2008 1:27 PM To: 'NSK Problem Well Supv ; Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: RE: West Sak packerless ESP producer 1J-174 (PTD 2071430) report of failed ESP Brent, Please submit a 10-404 to document the change of artificial lift method from ESP to gas lift. This would be consistent with how paperwork for similar ESP failures has been handled. I understand this is a temporary situation with plans to repair the well with a rig intervention in the near future. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, March 17, 2008 2:35 PM To; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: West Sak packerless ESP producer 1J-174 (PTD 2071430) report of failed ESP Tom & Jim, West Sak packerless ESP producer 1J-174 (PTD 2071430) experienced an ESP failure on 03/14/08. The TIO prior to the pump failure was 221/220/175. The plan forward is to pull the pump with Coiled tubing, install a GLV in the gas lift mandrel @2209' ,and use the pump intake as the lower gas lift point . It is ConocoPhillips intention to produce with gas lift until a RWO can fix the failed ESP. Attached is a schematic and a 56 day TIO plot since the well was initially brought on production on 02/21/08. «1J-174 schematic.pdh> «1J-174 56 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/21 /2008 West Sak packerless ESP produc~J-174 (PTD 2071430) report of failed~P Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Monday, March 17, 2008 2:35 PM ~ ~lu?~ti8 To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~ ` Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: West Sak packerless ESP producer 1J-174 (PTD 2071430) report of failed ESP Attachments: 1J-174 schematic.pdf; 1J-174 56 day TIO plot.jpg Tom & Jim, West Sak packerless ESP producer 1J-174 (PTD 2071430) experienced an ESP failure on 03/14/08. The TIO prior to the pump failure was 221/220/175. The plan forward is to pull the pump with Coiled tubing, install a GLV in the gas lift mandrel @2209' ,and use the pump intake as the lower gas lift point . It is ConocoPhillips intention to produce with gas lift until a RWO can fix the failed ESP. Attached is a schematic and a 56 day TIO plot since the well was initially brought on production on 02/21/08. «1J-174 schematic.pdf» «1J-174 56 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/19/2008 ~~~l~3 • i M [~ .fir rr ~ ti ~ .--i O N Q Q+ • ~ .~,_~ ~ KRU 1J-174 Gtan~o+~c~~'h~lt~~s A,~ask~,~nc`" 1 J-174 -- - API' DUU29Z3374UU Wetl T e: PROD An le a) r5: de a) TUBING - ~ SSSV T e: NONE Ori Com lebon: 12/30/2007 An le TD: 90 de 19708 (U-~19. Annular Fluid: Last W/O: Rev Reason: GLV C/O OD:4.500, ID 3 958 G , >. Reference Lo 41' RKB Ref Lo Date: Last U date: 1/28/2008 : . ) ~`.... ... _;, ~ ."...... Last Tag: TD: 19708 ftKB D-SAND WINDOW (11366-11367, OD:9.625) t; ,~. i aad' ~~ ~~~ 1~ r; ~ '.~~,j XO Bushing [-;, (11443-11444, ®,~?; ~ ~~ OD:7.650) - - - Last Tat} Date: 1 I Max HIP Anttla 193 r1er~ n 1Q27R I I Casino 5trinn - AI I STRINC;S Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 4013 2271 68.00 L-80 BTC INTERMEDIATE 10.750 0 3927 2250 73.20 L-80 BTCM INTERMEDIATE 9.625 3927 12080 3206 40.00 L-80 BTCM D-SAND LINER TOP 4.500 11355 11366 3129 11.60 L-80 BTC/HYD 521 D-SAND WINDOW 9.625 11366 11367 3129 0.00 B-SAND SLOTTED LINER 5.500 11416 19568 3155 15.50 L-80 BTC/HYD 521 B LAND LINER 4 Fnn 10R~R 1gg56 3158 11 RO L-Rn Br(`n~ Tubing String -TUBING _ , F - ,, Nt _ Grade _ _ Thread Size T- Bottom TVD b i~ ;i,l _i,~ ~, Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 12245 - 14582 3216 - 3198 WS B 2337 32 12/15/2007 Slots Slotted liner, 2.5"x .125" , 4 circumferential rows/ft, 3" centers staggered 18 deg, non-slotted ends 14584 - 19568 3198 - 3155 WS B 4984 32 12/15/2007 Slots Slotted liner, 2.5"x .125" , 4 circumferential rows/ft, 3" centers staggered 18 deg, nnn_clnHCrl onric Gas Lift MandrelsNalves St MD TVD I Man Mfr Man Type I v Mfr V Type I V 6D I Latch Port TRO Date Run I Cmnt 1 2209 1773 CAMCO __KBMG SOV 1.0 BK-5 0.000 0 1/24/2008 Other (plugs, equip., etc_.) -COMPLETION DB h TVD T e Descri lion 7-~ ID 36 36 HANGER VETCO GRAY TUBING HANGER 3.938 9474 2906 SUB UNIQUE DISCHARGE SUB 0.000 9529 2912 PUMP 4 1/2 (48.73' OAL) TTC ESP ,SET 4 1/2 D&D PACKOFF ASSEMBLY (100" OAL-36" FROM F.N. TO KOBE-83" FROM F.N. TO CHECK) @ 47' SLM. 4 1!2 SLIP STOP 40' SLM set 12/28!2007 0.000 9557 2915 XO Screen TTC CROSSOVER w/SCREEN INTAKE 0.000 9568 2916 SEAL UPPER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB PFSA CLS 0.000 9575 2916 SEAL LOWER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB PFSA CLS 0.000 9581 2917 MOTOR BAKER KMH 418 HP MOTOR 0.000 9615 2921 GAUGE WEATHERFORD A-WELL GAUGE 0.000 9617 2921 Centralizer MOTOR CENTRALIZER 0.000 11355 3127 HANGER D-SAND RAM HANGER ABOVE/BELOW COLLET 3.940 11360 3128 Seal bore Diverter D-SAND LINER SEAL BORE DIVERTER f/RAM HANGER to BELOW COLLET PROFILE 3.940 Other ( De h plugs, equip., etc.) - B-SAND LINER DETAIL TVD T e Descri tton ID 11417 3135 PACKER B-SAND LINER BAKER MLZXP LINER HANGER -ABOVE COLLET PROFILE 7.000 11429 3136 PACKER B-SAND LINER BAKER MLZXP LINER HANGER 7.000 11438 3137 HANGER B-SAND LINER BAKER FLEX-LOCK HANGER 7.000 11443 3138 XO Bushina B-SAND LINER CROSSOVER BUSHING 4.920 79568 I 31SS I XO I B-SAND LINER CROSSOVER 5.5" TO 4.5" ~ 4.500 -- - General Notes 12-Feb-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-174 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 17,660.08' MD Window /Kickoff Survey: 17,700.00' MD (if applicable) Projected Survey: 19,708.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Si ned ~~~ ~~ ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ ~? • r~t3 • 12-Feb-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-174 PB1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 15,308.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~~,5~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • • 12-Feb-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-174 PB2 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 15,090.45' MD Window /Kickoff Survey: 15,140.00' MD (if applicable) Projected Survey: 18,141.39' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date `~ l~o~.~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~-~~~ ConocoPhillips • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 R 1~~ "~/ January 15, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-174 and 1 J-174L1 Dear Commissioner: JAN 2 ~ ~9~~ Alaska Ail ~ G~i~ ~~~. +C~tt~i~si~w? Anchcr~~e ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1J-174 1J-174L1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, t ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~iv~ JAN 2 2 2008 WELL COMPLETION OR RECOMPLETION REPQ~$I~ d+1~CDs ~~pmm+~~nr~ 1a. Well Status: Oil ^ ~ Gas Plugged ^ Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 . GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class:An~~{~f8~~ Development ^ s Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 30, 2007 12. Permit to Drill Number: 207-143 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~, November 16, 2007 13. API Number: 50-029-23374-00 ' 4a. Location of Well (Governmental Section): Surface: 1724' FSL, 2471' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: December 11, 2007 ~ 14. Well Name and Number: 1J-174 • Top of Productive Horizon: 431' FSL, 56' FWL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 121.5' RKB ~ Ground (ft MSL): 81' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 1918' FNL, 187' FWL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 19612' MD / 3155' TVD West Sak Oil Pool ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558741 s y- 5945537 ~° Zone- 4 10. Total Depth (MD + ND): i 19708' MD / 3157' TVD ~ 16. Property Designation: ALK 25661, 25660, 25663, 385172 TPI: x- 550767 y- 5938906 Zone- 4 Total Depth: x- 550965 ~ - 5931279 ~ Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471, 2177, 472, 2181 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permaftost (ND~: approx. 1530' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 41' 120' 41' 120' 42" 338 sx AS 1 13.375" 68# L-80 41' 4014' 41' 2270' 16" 740 sx AS, 245 sx LiteCRETE 10.75" x 73.2# L-80 41' 3927' 41' 2249' 12.25" 853 sx LiteCRETE 9.625" 40# L-80 3928' 12081' 2250' 3205' 12.25" included above 5.5" 15.5# L-80 11417' 19568' 3135' 3155' 8.5" slotted liner 4.5" 11.6# L-80 19568' 19656' 3155' 3156' 8.5" slotted liner 23. Open to production or injection? Yes ^ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9619' 11417' slotted /blank liner from 11463'-19656' MD slotted liner from 12245'-14582' MD and 14584'-19568' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) shares production with 1J-174L1 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No ^ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. U~....._...J.i i ~~ ~6. NONE • 4 !~ • 30~> V~R'FiEta ~ ~ ~ „ )': ~_ ..._ . A . _.. _. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE -~ ~~~: ~~~ ~ ~ ~aoa 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ^/ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1744' 1530' '` needed, and submit detailed test information per 20 AAC 25.071. T3 1932' 1638' K15 2683' 1924' Ugnu C 7232' 2658' Ugnu B 8690' 2821' Ungu A 9140' 2870' K13 10253' 2989' West Sak D 11276' 3118' West Sak B 12070' 3205' West Sak A 19078' 3157 N/A 1 J-174PB1 TD 15308' 3188' 1 J-174PB2 TD 18141' 3181' Formation at total depth: West Sak B ~~ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Name Rand Thomas Title: Drilling Team Leader Date t ~!_Sla ~ Signature ~ ~ Phone `L6 S 6 g 3 c7 INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and. a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 r~i~~' Cona-c+~~'hillps ~laska,lnc: 1 J-174 - --- -- APL 5A0292337400 Well T e: PROD TUBING SSSV Type: NONE Orig (o-eels, oD:a.SOO, Com letion: ID:3.958) ~ ?' .~'- Annular Fluid: Last W/O: __ PUMP (9529-9581, OD:3.800) xo screen (9557-9568, OD:5.130) SEAL (9568-9575, OD:5.130) SEAL (9575-9581, OD:5.130) HANGER ;11355-11360, OD:6.625) DSAND WINDOW ;11366-11367, OD:9.625) KRU 1 J-174 I Last Tag Date' I I Max Hole Angle: 10 deg n I I _ I Casing String -ALL STRIM1_[GS Iflncwr:Minn ~~~ C:sn I Tnn I OnHnrw I T\/fl I 1AR I !]rsrln I ThrnnA I CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 4013 4013 68.00 L-80 BTC INTERMEDIATE 10.750 0 3927 3927 73.20 L-80 BTCM INTERMEDIATE 9.625 3927 12080 12080 40.00 L-80 BTCM D-SAND LINER TOP 4.500 11355 11366 11366 11.60 L-80 BTC/HYD 521 D-SAND WINDOW 9.625 11366 11367 11367 0.00 B-SAND SLOTTED LINER 5.500 11416 19568 19568 15.50 L-80 BTC/HYD 521 1 ti-JHNU LINtK I 4.hUU I lybb25 I lYbb6 I lyb5b I l LbU I L-25U 1 tSII:M I Tubing String TUBING Size To Bottom TVD Wt Gratle Threatl - 4.500 0 9619 9619 12.60 L-80 IBTM __ Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 12245 - 14582 12245 - 14582 2337 32 12/15/2007 Slots Slotted liner, 2.5'k .125" , 4 circumferential rows/ft, 3" centers staggered 18 deg, non-slotted ends 14584 - 19568 14584 - 19568 4984 32 12/15/2007 Slots Slotted liner, 2.5'k .125" , 4 circumferential rows/ft, 3" centers staggered 18 deg, non-slotted ends -- Gas Lift Mandre15N21tyes ~ac mu I vu man mTr man I ype v rvlrr v I ype v vv ~accn ron i nv ua:e nun vrv~ Cmnt 1 2209 2209 CAMCO hBMG SOV 1.0 BK 5 0.000 0 1?/28I2007 Other lugs, equip., etc.1 - COMPLETLON De h TVD T e Descn Uon ID 36 36 HANGER VETCO GRAY TUBING HANGER 3.938 9474 9474 SUB UNIQUE DISCHARGE SUB 0.000 9529 9529 PUMP 4 1/2 (48.73' OAL) TTC ESP @ 95' SLM. SET 4 1/2 D&D PACKOFF ASSEMBLY (100" OAL-36" FROM F.N. TO KOBE-83" FROM F.N. TO CHECK 47' SLM. 4 1/2 SLIP STOP 40' SLM set 12/28/2007 0.000 9557 9557 XO Screen TTC CROSSOVER w/SCREEN INTAKE 0.000 9568 9568 SEAL UPPER TANDEM SEAL SECTION GSB3D6 FER HL SSCV SB/SB PFSA CL5 0.000 9575 9575 SEAL LOWER TANDEM SEAL SECTION GSB3DB FER HL SSCV SB/SB PFSA CL5 0.000 9581 9581 MOTOR BAKER KMH 418 HP MOTOR 0.000 9615 9615 GAUGE WEATHERFORD A-WELL GAUGE 0.000 9617 9617 Centralizer MOTOR CENTRALIZER 0.000 11355 11355 HANGER D-SAND RAM HANGER ABOVE/BELOW COLLET 3.940 11360 ~ 11360 Seal bore Diverter P tC D-SAND LINER SEAL BORE DIVERTER f/RAM HANGER to BELOW COLLET PROFILE , ~ 3.940 , D T D L t A 1 1417 4 1 PACKER ER BAKER MLZXP LINER HANGER -ABOVE COLLET B-S ND N PROFILE 7.000 11429 11429 PACKER B-SAND LINER BAKER MLZXP LINER HANGER 7.000 11438 11438 HANGER B-SAND LINER BAKER FLEX-LOCK HANGER 7.000 11443 11443 XO Bushing B-SAND LINER CROSSOVER BUSHING 4.920 11444 11444 SBE B-SAND LINER BAKER SEAL BORE EXTENSION 4.750 19568 19568 XO B-SAND LINER CROSSOVER 5 5" TO 4 5" 4.500 ~~ XO Bushing :11443-11444, c...;.~ `. OD:7.650) _~~ Pert ;12245-14582) General Notes Date Note Pert = 2/28/200 NOTE: MULTI-LATERAL WELL 1J-174 B-SAND , 1J-174L1 D-SAND lasaa-lsssa) Con©caPhiips Time Log Summary Wei7uiew Web RepoKtng i Well Name: 1 J-174 Job Type: DRILLING ORIGINAL Time Logs Date From . To_ _ _ _D_ ur S. De th E DeptlZ Phase Code Subcode T COM 11/15/2007 00:00 06:00 6.00 120 120 MIRU MOVE DMOB P Skid rig floor, PU stomper feet, install -drag links, and move rig off 1J-178 well. 06:00 09:15 3.25 120 120 MIRU .MOVE MOB P PJSM, spot sub over 1J-174, spot its. 09:15 10:15 1.00 120 120 MIRU MOVE PSIT P PJSM, cantilever rig floor over conductor, lower feet. Spread Herculite for Rock washer, and spot matting boards for mud pit loading dock. 10:15 12:00 1.75 120 120 MIRU MOVE PSIT P Hook up module interconnects for mud, water, steam and air. Pin up Beaver slide and berm around same. RU flowline. 12:00 14:30 2.50 120 120 MIRU MOVE PSIT P Spot Rock washer and cuttings tanks and berm same. NOTE: Rig acre ted at 14:30 hrs, 11-15-2007 14:30 18:00 3.50 120 120 MIRU MOVE RURD P Nipple up Diverter line, Riser and flowline. Load brand new 5", 19.5 Ib/ft, S-135, NC50 DP in pipe shed. RU fill-up line, secure Riser. Hookup Koomey unit. Start taking on Spud mud at 16:15 hrs. 18:00 19:00 1.00 120 120 MIRU MOVE RURD P Continue to NU diverter. 19:00 20:45 1.75 120 120 MIRU MOVE RURD P Finish loading pipe shed with 192 joints of new 5" DP and continue taking on Spud mud to pits. Charge Koome unit. 20:45 21:45 1.00 120 120 MIRU MOVE OTHR P Service Top Drive, continue loading DP in shed and takin on S ud mud. 21:45 00:00 2.25 120 120 MIRU DRILL PULD P PJSM. PU/MU 5" DP from pipe shed, rabbiting with 3.1"drift. Dope box threads and shoulder. Make up slowly to 25,600 ft-Ib monitoring for steady MU torque. Break out, clean and inspect pin threads for galling. Re-makeup DP to 30,000 ft-Ib and stand back. 11/16/2007 00:00 06:30 6.50 0 0 MIRU DRILL PULD P Continue to PU and break-in new 5", 19.5 Ib/ft, S-135, NC50 DP, stand back in derrick and clear ri floor. 06:30 07:15 0.75 0 0 MIRU DRILL PULD P Pull BHA equipment to rig floor. _~.__ ~'~y~ ~ raf 37 ~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/16/2007 07:15 08:00 0.75 0 0 MIRU WELCT BOPE P Perform Diverter test: 26 seconds to close Hydril, 14 seconds for knife valve opening. Koomey pressure = 1,800 psi after Hydril closing, build back up by 200 psi after 39 seconds, full build up after 2:21 minutes. Full system = 2,200 si er bottle. 08:00 09:00 1.00 0 0 MIRU DRILL PULD P PU/RU slickline equipment for Gyro surve s. 09:00 10:00 1.00 0 0 SURFA DRILL PULD P PU BHA. Build first stand with HWDP and Jars, stand back same. PU.MU Motor and bit, ad'ust ako. 10:00 10:45 0.75 0 0 SURFA DRILL PULD P PU MWD, Evader Electro-Mag Directional collar, Index and Antenna sub. U load same. 10:45 11:30 0.75 0 0 SURFA DRILL PULD P Continue to PU BHA -Float sub, Non-Ma Flex DCs, HWDP. 11:30 11:45 0.25 0 0 SURFA DRILL OTHR P Flood conductor and surface lines. Test to 1,000 psi and then 3,000 psi. Check for leaks -okay. RIH and tag cement at 107'. 11:45 12:00 0.25 0 0 SURFA DRILL OTHR P Drill cement from 107-120'. 12:00 13:45 1.75 0 196 SURFA DRILL DRLG P Drill ahead new formation to 196'. RU and run G ro surve . 13:45 14:15 0.50 196 196 SURFA DRILL TRIP P POOH to 1 std of HWDP, PU Flex DC and ~ars, RIH. 14:15 18:00 3.75 196 409 SURFA DRILL DRLG P Drill new hole to 409' running Gyro eve stand. 18:00 00:00 6.00 409 800 SURFA DRILL DRLG P Drill ahead to 800' TMD (790' TVD). 11!17/2007 00:00 06:00 6.00 800 1,239 SURFA DRILL DRLG P Drill ahead from 800'to 1,239'tmd 1,176' tvd . 06:00 12:00 6.00 1,239 1,689 SURFA DRILL DRLG P Drill from 1,239' to 1,689' tmd (1,501' tvd . 12:00 18:00 6.00 1,689 2,260 SURFA DRILL DRLG P Drill from 1,689' to 2,260' tmd (1,794' tvd 18:00 00:00 6.00 2,260 2,671 SURFA DRILL DRLG P Drill from 2,260' to 2,671' tmd (1,912' tvd 11!18/2007 00:00 06:00 6.00 2,671 3,074 SURFA DRILL DRLG P Drill from 2,671' to 3,074' TMD (2,023' TVD 06:00 12:00 6.00 3,074 3,458 SURFA DRILL DRLG P Drill from 3,074' to 3,548' TMD (2,147' TVD 12:00 17:15 5.25 3,458 4,030 SURFA DRILL DRLG P Drill from 3,548' to 4,030' TMD (2,274' TVD 17:15 18:00 0.75 4,030 3,900 SURFA DRILL REAM P BROOH slowly while CBU 3X from TD to 3,900' at 895 GPM, 2,775 psi and 50 RPM. 18:00 00:00 6.00 3,900 1,500 SURFA DRILL REAM P BROOH from 3,900' to 1,500' TMD. Flow reduced to 600 GPM while BROOH throu h the ermafrost. Pala 2 of 37 r~ Time Logs Da e From To Dur S De th E De th Ph e Code Subcode T COM 11/19/2007 00:00 02:00 2.00 1,500 600 SURFA DRILL REAM P Continue BROOH from 1,407' to 600' TMD. No overpull or tight spots while BROOH. BROOH at 600 gpm and 5' per min from 900' to 600'. Estimated 100% increase in clay cuttings initially and decreasing to normal cutting returns by 600' tmd (3x bottoms up over that de th interval . 02:00 02:15 0.25 600 360 SURFA DRILL TRIP P POOH on elevators from 600' to 360' tmd with hole takin ro er fill. 02:15 04:30 2.25 360 0 SURFA DRILL PULD P Download EM MWD tool. Stand back one stand, LD 2 jts of HWDP + Jars of HWDP. Stand back Flex DC, break out bit, LD MWD and motor assembl . 04:30 05:00 0.50 0 0 SURFA DRILL PULD P Finish LD MWD and motor, clear and clean ri floor. 05:00 08:00 3.00 0 0 SURFA CASIN RURD P RU casing equipment 08:00 08:15 0.25 0 0 SURFA CASIN SFTY P PJSM for running 13-3/8" casing. 08:15 12:00 3.75 0 1,784 SURFA CASIN RNCS P PU/MU floatjoints and threadlock same. Check floats. Run 43 joints of 13-3/8", 68 Ib/ft, L-80, BTC R2 casing, using the Fill-up tool on every joint and "topping ofP' every 5 joint. Record up and down wei hts eve 10 'oints. 12:00 13:00 1.00 1,784 2,625 SURFA CASINC RNCS P Continue running csg to joint 63 at 2,625' tmd with proper displacement. CBU staging flowrate up to 7 BPM, 410 psi with no mud losses. SO weight before = 128K, SO weight after = 140K. 13:00 16:00 3.00 2,625 4,020 SURFA CASIN RNCS P Continue runnin casin to 4,020' (2,272') without problems while taking ro er dis lacement. 16:00 20:30 4.50 4,020 4,020 SURFA CASIN CIRC P Circulate and condition mud, staging pumps up to, 7 BPM without fluid losses and reci rocatin i strokes. Initial PU Wt = 285K, Final PU Wt = 260K, Initial SO Wt =Final SO Wt = 155K. P~g~ 3 ~sf 37 Time Lo s Date From To Dur S. De th E. De th Ph se Code Subcode T COM 11/20/2007 08:15 10:00 1.75 4,012 4,012 SURFA CEME TRIP T PU & RIH with 1"hydrill. Tagged at 170'. Pressure up to 480 psi to clear i e. 10:00 10:45 0.75 4,012 4,012 SURFA CEME~ CIRC T Circulate 35 bbls of water, 2 annular volumes, at Z bbl/min. 10:45 11:15 0.50 4,012 4,012 SURFA CEME~ OTHR T Pump 2 bbls of lead water followed by 48.1 bbls (60 sxs) of 10.7 ppb cement at 2.0 bbls/min 228 si. 11:15 12:00 0.75 4,012 4,012 SURFA CEME~ RURD T RD cement equipment, blow down lines, flush & LD hydrill. Marked all h drill used, sendin out for cleanin . 12:00 14:30 2.50 4,012 4,012 SURFA CASIN NUND T Prepare conductor for wellhead adapter. Weld adapter in place. Vetco rep present. Sim ops- clean & clear rig floor, RD casing elevators and long bails. Install link tilt yoke w/new bushings, install short bails and 5"drill i e elevators. 14:30 15:45 1.25 4,012 4,012 SURFA CASlN( RPTH T Weld patch in conductor. PJSM on moving drill pipe. Move 22 stands of 5" drill pipe from drillers side to off dirllers side old drill i e . 15:45 21:45 6.00 4,012 4,012 SURFA DRILL PULD P Install mouse hole in rotary table and PU 126 joints fo drill pipe from pipe shed. Drift to 2.88". PU 1 joint HWDP for cut & slip drilling line. Pull mouse hole. 21:45 23:30 1.75 4,012 4,012 SURFA RIGMN SVRG P PJSM -cut & slip drilling line. Hang blocks, cut & slip 130' of drilling line. Inspect brakes and deadman. Greased drawworks. Sim ops -test well head ada ter, 5000 si for 10 min. 23:30 00:00 0.50 4,012 SURFA CASIN NUND P Nipple up well head 11/21/2007 00:00 00:45 0.75 0 0 SURFA CASIN NUND P Continue nippling up well head. Test to 5000 si for 10 minutes 00:45 07:30 6.75 0 0 SURFA CASIN RURD P Nipple up BOPE, fill stack, RU chart recorder, fill choke, line up manifold, double check gland nuts and annulus valve. 07:30 11:30 4.00 0 0 SURFA WELCT ROPE P Test BOPE, 250 low, 3000 high.Draw down test start @ 3050 psi, draw down to 1550, 200 psi increase - 50 seconds. Full charge 3 min 16 sec. Bob Noble State wavied witness. 11:30 12:00 0.50 0 0 SURFA DRILL RURD P Rig down from BOP test & set wear ri n 12:00 14:30 2.50 0 361 SURFA DRILL PULD P PJSM, PU BHA #2, MU bit and Geo ilot. Download MWD 14:30 16:30 2.00 361 3,887 SURFA DRILL TRIP P TIH with BHA #2. Hole took proper displacement. Shallow pulse test @ 3870 ' M D, 930 m. 16:30 17:30 1.00 3,887 3,883 SURFA DRILL CIRC P Circulate and condition for casing test. Circulate 649 bbls at 940 gpm, 2210 si. 35 r m. TQ=9-10k, Rot Wt=120k. ~~g~ 5 of 37 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/21/2007 17:30 19:00 1.50 3,883 3,883 SURFA DRILL OTHR P Blow down top drive, Rig up for casing test. Test 13-3/8 to 3000 psi for 30 min. Final pressure 2990 psi. Good test. Bleed off pressure and rig down test a ui ment. 19:00 19:15 0.25 3,883 3,920 SURFA DRILL TRIP P TIH. Tag float equipment at 3930' MD 19:15 21:15 2.00 3,920 3,930 SURFA CEME COCF P Drill float equipment. 700 gpm, 1350 psi, RPM= 72, TQ=9-12k, W06=2-10k. 21:15 21:30 0.25 3,930 3,930 SURFA CEME TRIP P Pull up to 3887 and replace air boot on flow line. Run back to bottom and resume drillin shoe track. 21:30 22:30 1.00 3,930 4,030 SURFA CEME DRLG P Drill shoe track, float shoe . 22:30 23:00 0.50 4,030 4,050 SURFA DRILL DDRL P DRill 20' of new hole for LOT. Start swap of mud system to LSND after drilling float shoe. 710 gpm, 1300 psi, TW=9-12K, WOB=2-10k 23:00 00:00 1.00 4,050 4,050 SURFA DRILL CIRC P Circulate hole clean for LOT. Pumping at 1000 gpm, 1840 psi. Baseline ECDs=9.24 ppg EMW. Take slow um rates 11/22/2007 00:00 01:00 1.00 4,050 4,050 SURFA DRILL LOT P Rig up and perform LOT. Open HCR kill line and close top pipe rams. Perform LOT at 2270 TVD with 9.0 ppg LSND mud. Pumped 4 bbls. Formation broke over at 490 psi, com uter calculated EMW=13.2 Initial shut-in pressure 800 psi, final 550 psi. Recorded pressure for 10 min. Bleed off ressure and ri down. 01:00 06:00 5.00 4,050 4,455 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Bit Hrs=3.11, Jar Hrs=3.11, Max Gas=50 units 06:00 12:00 6.00 4,455 5,033 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Bit Hrs=6.96, Jar Hrs=6.96, Max Gas=51 units 12:00 18:00 6.00 5,033 5,693 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Bit Hrs=10.90, Jar Hrs=10.90, Max Gas=68 units. Take slow um rates 18:00 00:00 6.00 5,693 6,005 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. ROP ranging from 5 fph - 200fph starting at 5750' MD, approx. 2495 TVD. Vary drilling parameters with no consistent improvement. Contniue to drill ahead. Bit Hrs=15.63, Jar Hrs=15.63, Max Gas=100 units 11/23/2007 00:00 06:00 6.00 6,005 6,455 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Bit Hrs=19.94, Jar Hrs=19.94, Max Gas=75 units. Take slow um rates 06:00 07:30 1.50 6,455 6,645 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Bit Hrs=20.82, Jar Hrs=20.82, Max Gas=50 units. Take slow um rates P~c~e 6 cal 37 Time Logs Da e From To Dur 5 De th E. De th Phase Code Subcod T COM 11/23/2007 07:30 09:30 2.00 6,645 6,645 INTRM1 DRILL CIRC T Phase 3 weather was decalred at 06:00. Prepare to pull back to shoe. Pump weighted, hi-vis sweep. No significant increase in cuttings. Circulate 3 bottoms up at 1050 gpm, 2300 si, 120 m. 09:30 14:45 5.25 6,645 3,982 INTRM1 DRILL REAM T Attempt to pull on elevators, hole swabbing. Back ream at slow speed, um in 1050 m, 2800 si, 100 m 14:45 16:00 1.25 3,982 3,982 INTRM1 DRILL CIRC T Circulate 3 bottoms up pumping 1050 gpm, 2800 psi, 120 rpm. No si nificant increase in cuttin s. 16:00 20:00 4.00 3,982 3,982 INTRM1 DRILL OWFF T Monitor well -static. Blow down top drive. Installed floor valve in open position on top of string. Cease o erations due o w r. 20:00 22:00 2.00 3,982 5,880 INTRM1 DRILL TRIP T Phase 2 weather declared at 1800. Resume operations. Trip in hole on elevators. Fill pipe every 15 stands, record PU/SO wei hts. 22:00 00:00 2.00 5,880 6,645 INTRM1 DRILL REAM T Stacking out. Wash and ream in hole. Vary rotary speed and pump rates as needed to ream to bottom. 11/24/2007 00:00 06:00 6.00 6,645 7,351 INTRMI DRILL DDRL P Drill 12-1 /4" intermediate hole. 06:00 12:00 6.00 7,351 8,167 INTRM1 DRILL DDRL P Drill 12-1 /4" intermediate hole. 12:00 16:15 4.25 8,167 8,739 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. 16:15 19:45 3.50 8,739 8,739 INTRM1 DRILL DDRL T Pony rod on pump #1 broke. Circulate and rotate while making repairs. 510 m. 1090 si, 100 r m. 19:45 00:00. 4.25 8,739 9,215 INTRM1 DRILL DDRL P Drilt 12-1/4" intermediate hole. 11/25/2007 00:00 06:00 6.00 9,215 10,160 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. 06:00 12:00 6.00 10,160 10,867 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Pumped 11.3 ppg, 200 vis sweep at 10450' MD, increased cuttings at shakers 12:00 18:00 6.00 10,867 11,430 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. Pumped 11.0 ppg, 190 vis sweep at 10950' MD, no significant cuttings increase 18:00 00:00 6.00 11,430 11,974 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. 11!26/2007 00:00 02:00 2.00 11,974 12,089 INTRM1 DRILL DDRL P Drill 12-14" intermediate hole to TD. 12089' MD, 3206' TVD 02:00 03:45 1.75 12,089 12,072 INTRM1 DRILL CIRC P Pump 40 bbl hi-vis sweep plus 3 bottoms up. Pumping at 850 gpm and rotating at 150 rpm. Shakers loaded up at first bottoms up and saw no significant cuttings increase when swee returned. ~'~€~a 7 of 37 ~: Time Lags ____ Da e From To Dur S. De th E. De th Phase Coe Su code T COM 11/26/2007 03:45 06:00 2.25 12,072 11,800 INTRM1 DRILL REAM P Back ream out of hole at 1.5 fpm for 2 bottoms up. Pumping at 1030 gpm and rotatin at 150 r m. 06:00 12:00 6.00 11,800 9,313 INTRM1 DRILL REAM P Back ream out of hole at 25 fpm. Pumping 1050 gpm and rotating 150 rpm. Slowed to 5-10 fpm when cuttings increase seen at shakers. No over ull or swabbin observed. 12:00 18:00 6.00 9,313 6,930 INTRM1 DRILL REAM P Back ream out of hole at 25 fpm. Pumping 1050 gpm and rotating 150 rpm. Slowed to 3-5 fpm when cuttings increase seen at shakers. No overpull or swabbin observed. 18:00 00:00 6.00 6,930 4,074 INTRM1 DRILL REAM P Back ream out of hole at 25 fpm. Pumping 1050 gpm and rotating 150 m. 11/27/2007 00:00 00:15 0.25 4,074 3,979 INTRM1 DRILL REAM P Back ream 13-3/8" to casing shoe at 20 fpm. Pumping 1050 gpm and rotatin 120 r m. 00:15 02:15 2.00 3,979 3,979 INTRM1 DRILL CIRC P Pump 60 bbl 8.8 ppg low-vis followed by 60 bbl 9.3 ppg hi-vis sweep. Pumping at 1050 gpm, rotating at 120 rpm, reciprocating pipe 90'. Sweeps brought back a good load of cuttings. Circulated a total of 5 bottoms u . 02:15 02:30 0.25 3,979 3,979 INTRM1 DRILL CIRC P Spot 105 bb16% steel Tube pill 02:30 02:45 0.25 3,979 3,408 INTRM1 DRILL TRIP P POOH on elevators. Monitor hole fill usin tri tank. 02:45 03:00 .0.25 3,408 3,408 INTRM1 DRILL OWFF P Monitor well -static. Pump 30 bbl 10.7 d 'ob. 03:00 05:00 2.00 3,408 358 INTRMI DRILL TRIP P POOH on elevators. Record PU & SO eve xx stands 05:00 05:15 0.25 358 358 INTRM1 DRILL SFTY P PJSM -laying down BHA. 05:15 08:15 3.00 358 0 INTRM1 DRILL PULD P Lay down BHA #2. Download MWD. 08:15 08:45 0.50 0 0 INTRM1 DRILL PULD P Clear and clean rig floor 08:45 13:00 4.25 0 0 INTRM1 CASIN RURD P Pull wear ring, change top rams to 10-3/4". Rig up and test 10-3/4" rams, low 250 psi, high 3000 psi. Rig down test equipment. Ri u 9-5/8" casin a ui ment 13:00 13:30 0.50 0 0 INTRMI CASIN SFTY P PJSM -running 9-5/8" casing 13:30 14:30 1.00 0 338 INTRM1 CASIN RNCS P Run 8 joints 9-5/8" casing. Drop bail to close Davis-Lynch auto-fill float collar. Pressure in stages 250 psi, 500 psi & 700 si. 14:30 20:15 5.75 338 3,992 INTRM1 CASIN RNCS P Run 94 joints 9-5/8" casing to shoe. 20:15 21:30 1.25 3,992 3,992 INTRM1 CASINC CIRC P Circulate bottoms up at shoe. 21:30 22:45 1.25 3,992 5,150 INTRM1 CASIN RNCS P Run 30 joints 9-5l8" casing to shoe. P~cJe $ of 37 ~I Time Logs l~atP Frnm Tn four S f~enth F f)enth Phases Curia Suhr•.ndP T CnM 11/27/2007 22:45 00:00 .1.25 5,150 5,150 INTRM1 CASINC CIRC P Circulate bottoms up. Stage pumps to 5 b m. 11/28/2007 00:00 02:00 2.00 5,150 7,000 INTRM1 CASIN( RNCS P Run 48 joints 9-5/8" casing. 02:00 04:00 2.00 7,000 7,000 INTRM1 CASIN CIRC P Circulate bottoms staging up to 5 b m, 310 si 04:00 05:00 1.00 7,000 8,140 INTRM1 CASIN RNCS P Run 29 joints 9-5/8" casing. 05:00 05:45 0.75 8,140 8,152 INTRM1 CASIN RURD P Rig down 9-5/8" handling equipment. Make u 10-3/4" cross over. 05:45 06:30 0.75 8,152 -8,152 INTRM1 CASIN CIRC P Circulate while removing 9-5/8" handlin a ui ment from ri floor. 06:30 08:15 1.75 8,152 9,150 INTRM1 CASIN RNCS P Run 25 joints 10-3/4" casing. 08:15 10:00 1.75 9,150 9,150 INTRM1 CASINC CIRC P Circulate bottoms staging up to 5 b m, 370 si 10:00 12:00 2.00 9,150 10,615 INTRM1 CASIN RNCS P Run 36 joints 10-3l4" casing. 12:00 13:45 1.75 10,615 10,615 INTRM1 CASIN CIRC P Circulate bottoms staging up to 5 bpm, 500 psi. After circulations PU=300k, S0=150k 13:45 16:15 2.50 10,615 12,079 INTRM1 CASINC RNCS P Run 36 joints 10-3/4" casing to TD. Calculated displacement=222.5 bbls, actual dis198 bbls, lost 24.5 bbls. At TD PU=360k, S0=140k. 16:15 20:00 3.75 12,079 12,079 INTRM1 CASIN CIRC P Circluate and condition mud for cement ~ob. Circulate at 5 bpm, 500 psi. reciprocate pipe 20'. PU=360k, S0=145k 20:00 20:30 0.50 12,079 12,079 INTRMI CEME PULD P Pick up and make up cement head. 20:30 21:30 1.00 12,079 12,079 INTRMI CEME CIRC P Circluate and condition mud for cement job. Circulate at 5 bpm, 500 psi. reciprocate pipe 20'. PU=360k, S0=145k 21:30 21:45 0.25 12,079 12,079 iNTRM1 CEME SFTY P PJSM -cementing intermediate 1st sta e 21:45 23:15 1.50 12,079 12,079 INTRM1 CEME OTHR P Pump 10 bbls CW100, shut down and test lines to 3000 psi. Pump remaining 90 bbls CW100. Pump 100 bbl Mud Push. Stop and break cement head, load 10*-3/4" x 9-5/8" Davis-Lynch Plu . 23:15 00:00 0.75 12,079 12,079 INTRM1 CEME PULD P Mix and pump 172.5 bbls (12.5 ppg) cement @ 5 BPM.w/ Dowell. Drop Plu and kickout w/ 10 bbls H2O 11/29/2007 00:00 03:30 3.50 12,079 12,079 INTRMI CEME DISP P Displace cement using rig pumps at 5 bpm, 250 psi. Reduce rate to 3 bpm while passing the stage collar. Return to 5 bpm. At 100 bbls from bumping plug slowed to 3 bpm until bumping. Bumped plug at 7830 stks. Pressure up to 920 psi, 500 psi over final pump pressure. Held for 2 min. Bleed off pressure and checks floats, floats held. Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 11/29/2007 03:30 06:00 2.50 12,079 12,079 INTRM1 CEME CIRC P Pressure up to 2470 psi to open hydraulic stage collar. Collar opened and pressure dropped to 475 psi. Begin circulating at 5 bpm. Appeared to be seeing losses and slowed rate to 3 bpm, 410 psi. Returns stabilized. Saw Mud Push followed by clabbered u mud returns to surface. 06:00 08:00 2.00 12,079 12,079 INTRM1 CEME •CIRC P Increase rate to 5 bpm 360 psi for second bottoms up. Saw more clabbered up mud at surface. Circulated until good mud was all the wa around.. 08:00 08:30 0.50 12,079 12,079 INTRM1 CEME SFTY P PJSM - 2nd stage cement job. 08:30 09:00 0.50 12,079 12,079 INTRM1 CEME PULD P Stopped circulation, bleed off pressure. Break open cement head and load second lu . 09:00 10:45 1.75 12,079 12,079 INTRM1 CEME OTHR P Pump 10 bbls CW100, shut down and pressure test lines to 3000 psi. Pump remaining 90 bbls CW100. Pump 100 bbi Mud Push. Mix and pump 166 bbls (12.5 ppg) cement @ 5 BPM. Drop Plu and kickout with 10 bbls of water. 10:45 13:45 3.00 12,079 12,079 INTRM1 CEME DISP P Displace cement using rig pumps at 5 bpm, 250 psi. Saw CW100 and mud push at surface 4750 - 5990 stks into displacement. At 100 bbls from bumping plug slowed to 3 bpm, 1050 psi until bumping. Bumped plug at 5990 stks. Pressure up to 1750, then 2780 psi to close stage collar. Held pressure for 10 min. Bleed off pressure and check for flow back - no flow. 13:45 14:00 0.25 12,079 12,079 INTRM1 CEME RURD P Flush stack and rig up to flush annulus. 14:00 20:45 6.75 12,079 12,079 INTRM1 CEME CIRC P Flush 13-3/8" x 10-3/4 annulus with 177 bbls of water at 1.5 bpm, 990 psi and 175 bbls of diesel at 1.5 bpm, 1050 psi. Monitor annulus pressure. Sim ops -load pipe shed with new 5" drill pipe, clean pits, change out expansion boot at suction boot on mud pump #1, check precharge on ulsation dam eners. 20:45 22:00 1.25 12,079 12,079 INTRM1 DRILL OTHR P Continue loading pipe shed with new 5"drill i e and cleanin its. 22:00 22:15 0.25 12,079 12,079 INTRM1 DRILL SFTY P PJSM - bullheading into 13-3/8" x 10-3/4 annulus usin ri um s. 22:15 00:00 1.75 12,079 12,079 INTRM1 WELC OTHR P Load LSND mud into pits and bullhead into 13-3/8" x 10-3/4 annulus using rig pumps. Pumping 1.5 bpm. Shut in and monitor pressure. Bleed back, open annular reventer and observe well. P~c~~ 1 ~ of 37 Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 11/30/2007 _ 00:00 _ 01:30 1.50 0 0 INTRM1 WELCT OTHR NP Bullhead 175 bbls mud into 13-3/8" x 10-3/4 annulus using rig pumps. Pumping 1.5 bpm, 860 psi. Shut in and monitor pressure for 15 min, final ressure 655 si. 01:30 02:30 1.00 0 0 INTRM1 WELC OWFF NP Bleed 12 bbls from annulus to trip tank. 02:30 03:15 0.75 0 0 INTRM1 WELC OWFF NP Begin exhale test. Shut in and monitor ressure. Pressured built to 40 si. 03:15 04:00 0.75 0 0 INTRM1 WELCT OWFF NP Open annulus and bleed back into trip tank. Flowin a roximatel 1.8 b h 04:00 04:45 0.75 0 0 INTRMI WELC OWFF NP Shut in and monitor pressure. Pressured built to 20 si. 04:45 05:45 1.00 0 0 INTRM1 WELCT OWFF NP Open annulus and bleed back into trip tank. Flowin a roximatel .8 b h 05:45 06:45 1.00 0 0 INTRM1 WELCT OWFF NP Shut in and monitor pressure. Pressured built to 19 si. 06:45 07:15 0.50 0 0 INTRM1 WELC OTHR NP Bleed off pressure, open annular reventer and drain stack. 07:15 09:00 1.75 0 0 INTRM1 WELCT OWFF NP Monitor well at lower annulus valve - static. 09:00 09:45 0.75 0 0 INTRM1 CASIN( RURD P Blow down cement line, kill line and close HCR kill. 09:45 11:30 1.75 0 0 INTRM1 CASIN NUND P Nipple down stack. Set emergency sli s with 350k on wei ht indicator. 11:30 16:30 5.00 0 0 INTRM1 CASIN NUND P Cut 10-3/4 73.2 ppf casing using casing cutter and install packoff. Lay -down cut'oint, clean and clear ri floor 16:30 17:30 1.00 0 0 INTRM1 CASIN NUND P Set stack down. Rig up and test bottom flange of well head adapter. Test for 15 min at 5000 psi -good test. 17:30 18:00 0.50 0 0 INTRM1 WELCT NUND P Change top rams from 10-3/4" to 3-1 /2" - 6" VBRs. 18:00 23:15 5.25 0 INTRM1 WELC NUND P Continue changing rams, Open all doors and inspect for cement. Change out door seal on DS upper pipe rams. Close ram doors, R/U flowline, hole fill line and tunbuckles. 23:15 23:30 0.25 INTRMI WELCT SFTY P PJSM for testing BOPE, Blind rams closed. 23:30 00:00 0.50 INTRM1 WELCT BOPE P P/U 5" Test joint, Set test plug, fill stack w/ H2O, R/U test equipment. Take on OBM in its. 12/01/2007 00:00 03:00 .3.00 0 0 INTRM1 WELCT BOPE P Test BOPE, 250 low. 3000 high.Draw down test start @ 3000 psi, draw down to 1500, 200 psi increase - 48 seconds. Full charge 3 min 28 sec. AOGCC Rep Chuck Sheve waived witness of test. 03:00 03:30 0.50 0 0 INTRMI DRILL RURD P Rig down BOPE test equipment. Blow down equipment and set wear ring. MS Totco Server down. Mobilized Quadco re from Anchora e. 03:30 03:45 0.25 0 0 INTRM1 DRILL PULD P PJSM -Pick up BHA #3. Page I "i of 37 Time Logs Date From To Dur S De th E. De th Ph se Code Subcode T COM 12/01/2007 03:45 04:45 1.00 0 42 INTRM1 DRILL PULD P Pick up and make up BHA. 04:45 06:00 1.25 42 42 INTRM1 DRILL DHEQ P Up load MWD. Monitor hole via trip tank 06:00 06:45 0.75 42 440 INTRM1 DRILL PULD P Pick up remaining BHA plus jars and 5 'ts of HWDP 06:45 07:15 0.50 440 440 INTRM1 DRILL DHEQ P Shallow pulse test MWD and GeoPilot. 07:15 08:30 1.25 440 2,440 INTRM1 DRILL TRIP P Blow down top drive and run in hole with 22 stands of "old" drill pipe from derrick 08:30 09:00 0.50 2,440 2,440 INTRM1 DRILL RURD P Blow down top drive and hang blocks 09:00 09:15 0.25 2,440 2,440 INTRM1 DRILL SFTY P PJSM -Cut and Slip drilling line. 09:15 12:45 3.50 2,440 2,440 INTRM1 RIGMN' SVRG P Cut and slip 111' of drilling line, inspect brake bands, dead man and crown-o-matic. Change out saver sub, service top drive, crown and drawworks. 12:45 21:00 8.25 2,440 7,681 INTRM1 DRILL TRIP P Single in hole with new drill pipe. Drift to 3.0". Make and break every connection twice. Fill pipe at 4635' and 6535' MD Break in geo-pilot seals at 6535' MD. Pumping 500 gpm, 1500 psi and rotatin 25 m. 21:00 21:15 0.25 7,681 7,791 INTRM1 DRILL PULD P Pick up Centurion Circulating Sub, ball catcher and 2 'ts of drill i e. 21:15 21:45 0.50 7,791 7,886 INTRM1 DRILL CIRC P Fill pipe, break in seals on geo-pilot. Compare pressures before and after picking up circulating sub. Pressures ood. 21:45 00:00 2.25 7,886 8,929 INTRMI DRILL TRIP P Single in hole with new drill pipe. Drift to 3.0". Make and break every connection twice. 12/02/2007 00:00 00:45 0.75 8,929 8,929 INTRM1 CASINC DHEQ P Rig up to test casing before drilling sta a collar. Stage collar at 8990' MD. Test casin to 2000 for 10 min. - ood test. Ri down test a ui ment. 00:45 01:00 0.25 8,929 8,990 INTRM1 DRILL TRlP P Rotate and ~~ in ole to clear cement stringers above stage collar. PU=200k, S0=80k, Rotating wei ht=140k. 01:00 06:00 5.00 8,990 9,024 INTRM1 CEME DRLG P Drill Davis-Lynch plug and stage collar. Rotating 60 rpm, pumping 560 gpm, torque -18k. Drilling plug was slow. After drilling plug saw erattic torque as the aluminum in the stage collar was drilled. 06:00 06:15 0.25 9,024 9,119 INTRM1 DRILL TRIP P Rotate and wash in hole to clear any cement stringers below stage collar. PU=200k, S0=80k, Rotating wei ht=140k. Fagg 1~ of 37 C Time Logs _ Date From To Dur S. D th E. De th Phase Code Subcode T COM 12/02/2007 06:15 06:45 0.50 9,119 9,119 INTRM1 DRILL OTHR P Blow down top drive 06:45 07:30 0.75 9,119 9,405 INTRM1 DRILL TRIP P Trip in hole on elevators. PU=200k, S0=78k. vtt~--S~ 07:30. 12:00 4.50 9,405 11,501 INTRM1 DRILL TRIP P Lost down weight: Rotate and ~ in hole, PU=220k, S0=0k, Rotating wei ht=150k. 12:00 12:30 0.50 11,501 11,879 INTRM1 DRILL TRIP P No down weight. Rotate and wash in hole, rotating 35 rpm, pumping 147 gpm, torque 17k, pump pressure 650 psi, rotating weight 135k. PU=220k, S0=0k, Rotatin wei ht=145k. 12:30 13:15 0.75 11,879 11,879 INTRM1 DRILL CIRC P Circulate and condition mud. Rotating 30 rpm, pumping 700 gpm, torque 19k, pump pressure 3220 psi, rotating wei ht 135k. 13:15 13:45 0.50 11,879 11,879 INTRMI DRILL RURD P Blow down top drive and rig up casing test a ui ment. 13:45 14:45 1.00 11,879 11,879 INTRM1 CASIN DHEQ P Test casing to 3500 psi for 30 min - ood test. Ri sown test a ui ment. 14:45 15:00 0.25 11,879 11,898 INTRM1 DRILL TRIP P No down weight. Rotate and wash in hole until tagging up on float equipment. Rotating 70 rpm, pumping 145 gpm, torque 19k, pump pressure 630 psi, rotating weight 135k. PU=200k, S0=0k, Rotating wei ht=150k. 15:00 17:00 2.00 11,898 11,903 INTRM1 DRILL DRLG P Drill plug and float equipment. Rotating 90 rpm, pumping 560 gpm, torque 26k, pump pressure 2290 psi, rotating weight 135k. Begin displacing to OBM at 15:15 hrs. Pump 50 bbl 8.8 ppg, 250 vis sweep/spacer. Displace with 8.4 ppg, 74 vis OBM 17:00 17:30 0.50 11,903 11,903 INTRM1 DRILL CIRC P Chain down brake and finsh displacing to OBM. 17:30 00:00 6:50 11,903 12,078 INTRM1 CEME~ DRLG P Continue drilling float equipment and shoe track. Rotating 75 rpm, pumping 510 gpm, torque 13-16k, pump pressure 2450 psi, PU=185k, S0=105k, Rotatin wei ht=148k. 12/03/2007 00:00 04:45 4.75 12,078 12,089 INTRM1 CEME~ DRLG P Drilling float shoe. Vary drilling parameters in attempt to drill up shoe. Rotating 40-100 rpm, pumping 100-600 gpm, WOB 10-40k, torque 10-20k, pump pressure 2450 psi, PU=185k, S0=105k, Rotating wei ht=148k. 04:45 05:00 0.25 12,089 12,110 INTRM1 DRILL DDRL P Drilled 21' of new hole for LOT 05:00 05:15 0.25 12,110 12,069 INTRMI DRILL REAM P Back ream until backup in shoe. P~~~ 13 of 37 ~~ Time Logs Date From To Dur S D th E. D th Ph se Code Subcod~ T COM 12/03/2007 05:15 06:30 1.25 12,069 12,069 INTRMI DRILL LOT P Ri u and erform LOT. Open HCR kill line and close top pipe rams. Perform LOT at 3208 TVD with 8.5 ppg OBM mud. Pumped 11.1 bbls. Formation broke over at 895 psi, com uter calculated EMW=14.1 e. Initial shut-in pressure 700 psi, final pressure after 10 min 650 psi. Bleed off pressure and rig down and blow down lines. 06:30 07:00 0.50 12,069 12,110 INTRM1 DRILL LOT P LOT was recorded using MWD/PWD. RIH and wait for survey and pressure data from MWD. PWD recorded max pressure 2482 psi and final pressure 1990 si. 07:00 07:30 0.50 12,110 12,110 PROD1 DRILL DHEQ P Establish baseline PWD, pumping 650 gpm, rotating 120 rpm, pressure 3300. Clean hole ECD 10.76 e. 07:30 12:00 4.50 12,110 12,403 PROD1 DRILL DDRL P Drili 8-1/2" B- Lateral, ECDs = 10.76. 12:00 18:00 6.00 12,403 13,005 PROD1 DRILL DDRL P Drill 8-1l2" B- Lateral, ECDs = 11.04. 18:00 00:00 6.00 13,005 13,523 PROD1 DRILL DDRL P Drill 8-1/2" B- Lateral, ECDs = 11.25 12/04/2007 00:00 06:00 6.00 13,523 14,069 PROD1 DRILL DDRL P Directional drill "B" lateral from 13523' to 14069'; Avg ROP 131 FPH, 635 GPM 3700 PSI, ECD = 11.5 06:00 12:00 6.00 14,069 14,693 PROD1 DRILL DDRL P Directional drill "B" lateral from 14069' to 14693'; Avg ROP 192 FPH, 635 GPM 3870 PSI, ECD = 11.55 12:00 16:30 4.50 14,693 15,128 PROD1 DRILL DDRL P Directional drill "B" lateral from 14693' to 15128° Avg ROP 181 FPH, 625 GPM 3890 PSI, ECD = 11.75 16:30 18:00 1.50 15,128 15,253 PROD1 DRILL DDRL P Directional drill "B" lateral from 15128' to 15253'; Avg ROP 151 FPH, 625 GPM 3830 PSI, ECD = 11.45 18:00 19:30 1.50 15;253 15,308 PROD1 DRILL DDRL P Directional drill "B" lateral from 15253' to 15308'; Avg ROP 81 FPH, 650 GPM 4100 PSI, ECD = 11.6 19:30 22:00 2.50 15,308 15,100 PROD1 DRILL OTHR T Troubleshoot communication problems between MWD and Geo-Pilot, Excessive Dogleg (Concretions were drilled from 15140' to 15147' and 15159' to 15165'. Build Between 15,164' to 15,194' was 7.557 Degrees per 100'; Reboot MWD Computers, Change choke in Geo-Pilot Skid, and POOH to 15,100'. Communication between BHA Components was restored! Reset and Operating Normall . 22:00 22:30 0.50 15,100 15,128 PROD1 DRILL KOST T Troughing for Side Track from 15100' to 15128'. 22:30 22:45 0.25 15,128 15,140 PROD1 DRILL DDRL T Directional drill "B" lateral from 15128' to 15140' ; 630 GPM @ 3550 PSI; ECD = 11.2 1~~~ 1~ csf 3? Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/07/2007 05:15 06:00 0.75 12,065 12,065 PROD1 DRILL OTHR T Dropped Ball to Open CCV, Pumped Ball Down String @ 3 BPM 330 PSI; After Ball Seated CCV Opened at 2000 PSI; Then Circulated 3 BPM @ 100 PSI to Veri Valve Position 06:00 07:00 1.00 12,065 12,065 PROD1 DRILL CIRC T Circulated 4 X Bottoms Up Thru CCV @ 931 GPM @ 1610 PSI While Workin Pi eat 40 RPM 07:00 07:30 0.50 12,065 12,065 PROD1 DRILL OTHR T Dropped Ball & Pumped Down @ 3 BPM to Close CCV; CCV Closed @ 1750 PSI, Bled Pressure to 0 Then Verified CCV Position by Pumping 3 BPM @ 380 PSI, Pressure Increase of 280 PSI. CCV Closed. 07:30 08:45 1.25 12,065 10,516 PROD1 DRILL TRIP T Pump Out of Hole f/ 12,065' - 10516' MD; 600 GPM @ 2850 PSI; Monitor Hole Fill Via Active S stem 08:45 09:00 0.25 10,516 10,516 PROD1 DRILL OWFF T Monitor Well; Well Not Flowing Static 09:00 11:30 2.50 10,516 7,742 PROD1 DRILL TRIP T POOH f/ 10516' - 10231' MD; Monitoring Hole Via Trip Tank; Hole Swabbing; Pumped Out of Hole f/ 10231' - 7742' MD, 600 GPM @ 2430 PSI; Monitor Hole Via Active S stem 11:30 11:45 0.25 7,742 7,727 PROD1 DRILL PULD T UD CCV f/ 7742' - 7727' MD; Recoverd Two 2 1/8" balls from Ball Catcher 11:45 15:30 3.75 7,727 4,730 PROD1 DRILL TRIP T Cont'd Pump Out of Hole f/ 7727' - 4730' MD; 600 GPM @ 2400 - 1740 PSI; P/U 180 - 160K, S/O 95 - 100K, 15:30 17:00 1.50 4,730 348 PROD1 DRILL TRIP T POOH on Elevators f/ 4730' - 348' MD Monitor Well Via Tri Tank 17:00 18:00 1.00 348 45 PROD1 DRILL PULD T UD BHA #3 f/ 348' - 45' MD; Download MWD E ui ment 45' MD 18:00 19:15 1.25 45 0 PROD1 DRILL PULD T UD BHA #3 (MWD, Geo pilot & Bit) **Closed Btind Rams** 19:15 22:15 3.00 0 78 PROD1 DRILL PULD T P/U BHA #4 as Follows: Bit, Geo-Pilot, NMDC, MWD Gama/Res/PWD, Smart Stab, HCIM, TM, Float Sub 22:15 22:45 0.50 78 78 PROD1 DRILL OTHR T Upload /Test MWD (Ck Good)'* Began Table Top Stripping Drill in Dog House** 22:45 23:15 0.50 78 78 PROD1 DRILL SFTY P Finished Table Top Stripping Drill 23:15 00:00 0.75 78 356 PROD1 DRILL PULD T Cont'd P/U BHA #4 as Follows: 3 - NMDC's, Jars, 5 - HWDP 12/08/2007 00:00 00:15 0.25 356 356 PROD1 DRILL OTHR T Finish Shallow Test of MWD Tools 00:15 02:00 1.75 356 356 PROD1 RIGMN OTHR P Cut & Slip Drill Line, Blow Down Top Drive, & Ad~ust Brakes 02:00 02:30 0.50 356 1,084 PROD1 DRILL TRIP T RIH f/ 355' -1084' MD 02:30 03:15 0.75 1,084 1,084 PROD1 DRILL OTHR T Shallow Test of Geo-Pilot -- Test Failed; Not Enoough Weight on Geo-Pilot Housin to En a e Clutch 03:15 04:45 1.50 1,084 3,370 PROD1 DRILL TRIP T RIH f/ 1084' - 3370' MD f~~~g~ 1ti of 37 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/08/2007 04:45 05:00 0.25 3,370 3,370 PROD1 DRILL OTHR T Test MWD &Geo-Pilot -Test Passed 05:00 07:00 2.00 3,370 7,746 PROD1 DRILL TRIP T RIH f/ 3370' - 7746' MD; Fill Pipe & Acquire Torque /Drag Data Every 10 Stds f/ Std # 40; Monitor Displacement via Trip Tank; Fill Pipe & Break In Seals on Geo-Pilot @ 7681' MD at 480 GPM & 1660 PSI, 30 RPM 07:00 07:15 0.25 7,746 7,761 PROD1 DRILL PULD T P/U CCV & RIH f/ 7746' - 7761' MD 07:15 09:00 1.75 7,761 12,073 PROD1 DRILL TRIP T RIH f/ 7761' - 12073' MD; Fill Pipe & Break In Seals On Geo-Pilot @ 7854' & 12042' MD Flow Rate 480 GPM & 1660 / 2120 PSI, 30 RPM, 10 - 12K Off-Bottom Tor ue 09:00 09:15 0.25 12,073 12,073 PROD1 RIGMN SFTY P PJSM Replace Saver Sub 09:15 10:30 1.25 12,073 12,073 PROD1 RIGMN RGRP P Change 4 1/2" Saver Sub; Freeze Protect Inner-Annulus w/ 130 BBL @ 1.5 BPM Diesel Using Little Red Hot Oil 10:30 11:30 1.00 12,073 12,073 PROD1 DRILL SFTY P Conducted Stripping Drill (Tabletop) 11:30 12:00 0.50 12,073 12,101 PROD1 DRILL TRIP T RIH f/ 12073' - 12101' MD; Ran Out of Down Wei ht 12:00 17:45 5.75 12,101 17,660 PROD1 DRILL TRIP T Wash & Rotate In hole f/ 12101' - 17660' MD; 189 GPM @ 830 PSI; Torque 22 - 23K; P/U 230, S/O 72, Rot 150; Calc Gain 149 BBL Actual Gain 141 BBL; Cont. to Record Torque & Dra Data Eve 10 Stds 17:45 18:00 0.25 17,660 17,686 PROD1 DRILL OTHR T Because of drilling out of zone (out the bottom @ 18070'), a sidtrack was planned. Troughed for Side Track f/17660' - 17686; Stopped for MWD Malfunction 18:00 22:45 4.75 17,686 17,686 PROD1 DRILL DHEQ T Trouble Shoot MWD Tools; Pulsing Intermittently, Operated Normally for 3 - 20 Minutes then Stopped; Cycle Repeated 10 -15 Times; T/S Comprised of Varying Flow Rate and C clin Pum s with Same Results 22:45 00:00 1.25 17,686 17,056 PROD1 DRILL REAM T Pumped Out of Hole f! 17686' - 17056' MD; 575 GPM 3800 PSI 12/09/2007 00:00 06:00 6.00 17,056 12,450 PROD1 DRILL REAM T Backream out of the hole f/ 17056' - 12450' MD; Pumping 580GPM w/ 3800-2800 PSI, Rotating 120 rpm w/ 17-14k ft Ibs of torque. PU wt 225-200k, SO wt 0-98k. Monitor well on the active muds stem. 06:00 12:00 6.00 12,450 7,761 PROD1 DRILL TRIP T Pump out of the hole f/ 12450' - 7761' MD; Pumping 600 GPM w/ 2800-2450 PSI, PU wt 200-165k, SO wt 98- 110k. Monitor well on the active mud s stem. 12:00 12:15 0.25 7,761 7,746 PROD1 DRILL PULD T Lay down Centurian circulating valve. P~~ 17 of 37 Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T COM 12/09/2007 12:15 12:30 0.25 7,746 7,746 PROD1 DRILL DHEQ T Pulse test Sperry Sun MWD. Pum in 600 m w/ 2420 si. 12:30 14:15 1.75 7,746 5,809 PROD1 DRILL TRIP T Continue pumping out of the hole f/ 7746' - 5809' MD; Pumping 600 GPM w/ 2450- 2030 PSI, PU wt 165k, SO wt 110k. Monitor well on the active muds stem. 14:15 15:15 1.00 5,809 5,333 PROD1 DRILL TRIP T Pull out of the hole on elevators f/ 5809' - 5333' MD. Monitor well on the trip tank. PU wt 165-160k, SO wt 110-105k. 15:15 15:30 0.25 .5,333 5,333 PROD1 DRILL OWFF T Monitor well, static. 15:30 15:45 0.25 5,333 5,333 PROD1 DRILL CIRC T Pump a 20 bbl dry job. Mud weight 10.5 ppg. Pumping 380 gpm w/ 900 si. Blow down the to drive. 15:45 17:00 1.25 5,333 352 PROD1 DRILL TRIP T Continue to pull out of the hole on elevators f/ 5333' - 352' MD. Monitor well on the trip tank. Note: Calculated fill for trip is148 bbls, actual 155.5 bbls. 17:00 17:15 0.25 352 59 PROD1 DRILL PULD T Lay down BHA # 4. 17:15 18:00 0.75 59 59 PROD1 DRILL OTHR T Downlaod Sperry Sun MWD. 18:00 18:30 0.50 59 0 PROD1 DRILL PULD T Continue to lay down BHA # 4. 18:30 19:15 0.75 0 59 PROD1 DRILL PULD T Pickup/makeup BHA #5. 19:15 20:15 1.00 59 59 PROD1 DRILL OTHR T Upload Sperry Sun MWD. Results of low survey current on the GeoPilot. Decision to chan a out the GeoPilot. 20:15 21:15 1.00 59 0 PROD1 DRILL PULD T Lay down Sperry Sun Geopilot (ser # TL070). Pickup/Makeup Sperry Sun GeoPilot (ser # TL150). Note: Functioned blind rams. 21:15 21:45 0.50 59 59 PROD1 DRILL OTHR T Upload Sperry Sun MWD. 21:45 22:15 0.50 0 200 PROD1 DRILL PULD T Continue to pickup/makeup BHA #5. 22:15 22:30 0.25 200 200 PROD1 DRILL OTHR T Shallow pulse test Sperry Sum MWD. Pumping 400 gpm w/ 620 psi. Good test. 22:30 22:45 0.25 200 355 PROD1 DRILL PULD T Continue to PU/MU BHA #5. 22:45 00:00 125 355 2,750 PROD1 DRILL TRIP T Install air slips. Trip in the hole w/ BHA #5 f/ 355' - 2750' Fill Pipe Every 25 Stds. 12/10/2007 00:00 01:00 1.00 2,750 5,140 PROD1 DRILL TRIP T RIH f/ 2750' - 5140' MD; Fill Pipe Eve 25 Stds. 01:00 01:15 0.25 5,140 5,140 PROD1 DRILL DHEQ T Shallow Test MWD & Geo-Pilot 50 GPM @ 620 PSI, 50 RPM, P/U 124K, S/O 110K- Tested Good 01:15 02:15 1.00 5,140 7,515 PROD1 DRILL TRIP T RIH f/ 5140' - 7515' MD; Fill Pipe Eve 25 Stds i'~ge 93 of 37 • ~ Time Logs Date From To D r S. De th E. De th Phase Code Subcode T COM 12/10/2007 02:15 02:30 0.25 7,515 7,515 PROD1 DRILL DHEQ T Pulse Test MWD -Good; Circ rates Before P/U CCV 500 GPM @ 1850 PSI 02:30 02:45 0.25 7,515 7,820 PROD1 DRILL TRIP T RIH f/ 7515' - 7820' MD & P/U CCV 02:45 03:00 0.25 7,820 7,820 PROD1 DRILL CIRC T Circ Rate Through CCV 500 GPM @ 1950 PSI; P/U 160K, S/O 110K 03:00 03:45 0.75 7,820 9,913 PROD1 DRILL TRIP T RIH f/ 7820' - 9913' MD 03:45 04:00 0.25 9,913 9,913 PROD1 DRILL DHEQ T Pulse Test MWD -- Good; 500 GPM 2210 PSI 04:00 05:00 1.00 9,913 12,010 PROD1 DRILL TRIP T RIH f/.9913' -12010' MD 05:00 05:15 0.25 12,010 12,010 PROD1 RIGMN' SFTY P PJSM to Change Saver Sub 05:15 06:45 1.50 12,010 12,010 PROD1 RIGMN' SVRG P Change 4-1/2" Saver Sub. 06:45 07:30 0.75 12,010 12,010 PROD1 RIGMN SVRG P Service rig. 07:30 08:00 0.50 12,010 12,580 PROD1 DRILL TRIP T Trip in the hole on elevators. Ran out of down wei ht. 08:00 14:30 6.50 12,580 17,660 PROD1 DRILL REAM T Ream in the hole. Rotate 50 rpm w/ 15-19k ft Ib of torque. Pumping 190 m w/ 610 si. 14:30 15:15 0.75 17,660 17,700 PROD1 STK KOST T Because of drilling out of zone (out the bottom) @ 18070', a sidterack was planned. Troughing for the sidetrack f/ 17660 to 17700'. 15:15 18:00 2.75 17,700 18,000 PROD1 DRILL DDRL T Directional drill "B" lateral. 18:00 19:30 1.50 18,000 18,141 PROD1 DRILL DDRL T Directional drill "B" lateral. 19:30 00:00 4.50 18,141 18,492 PROD1 DRILL DDRL P Directional drill "B" lateral. 12/11!2007 00:00 06:00 6.00 18,492 19,023 PROD1 DRILL DDRL P Ddrl "B" Lateral f/ 18492' - 19023' MD; 465 GPM 2740 PSI 06:00 12:00 6.00 19,023 19,498 PROD1 DRILL DDRL P Ddrl "B" lateral f/ 19203' - 19498' MD; 550 GPM 3650 PSI 12:00 15:00 3.00 19,498 19,708 PROD1 DRILL DDRL P Ddrl "B" Lateral f/ 19498' - 19708' Mf~2._ (TD ; TVD = 3156' 550 GPM @ 3730 PSI 15:00 18:00 3.00 19,708 18,664 PROD1 DRILL REAM P BROOH f/ 19708 - 18664' MD; 550 GPM 3500 PSI 18:00 00:00 6.00 18,664 14,647 PROD1 DRILL REAM P BROOH f! 18664' - 14647' MD; 580 GPM 3650 PSI 12/12/2007 00:00 03:45 3.75 14,647 12,076 PROD1 DRILL REAM P Cont'd BROOH f/ 14647' - 12076' MD; RPM 120, 600 GPM @ 3100 PSI, P/U 185, S/O 110, ROT 142 03:45 06:30 2.75 12,076 12,076 PROD1 DRILL CIRC P Circ & Cond Mud @ 12076 MD; 600 GPM @ 3100 PSI; Pump 43 BBL 10.1 PPG / 240 VIS Sweep w/ No Si nificant Cuttin s Increase 06:30 07:00 0.50 12,076 12,076 PROD1 DRILL OWFF P Monitor Well For Flow 07:00 09:00 2.00 12,076 12,076 PROD1 RIGMN SVRG P Cut & Slip Drill Line, Service Top Drive, Service Ri j s-~- Page 19 t~f 37 C~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 12/12/2007 09:00 11:00 2.00 12,076 10,646 PROD1 DRILL TRIP P Pump Out-of-Hole f/ 12076' - 10646' MD; 500 GPM @ 2200PSI; P/U 203, S/O 95, Rot 142; Torque 13 -15 @ 30 RPM 11:00 11:30 0.50 10,646 10,646 PROD1 DRILL PULD P P/U Baker 8 11/16" String Mill & 2 each 4 1 /2" Reg X 4 1 /2" I F Cross-Ovens 11:30 12:30 1.00 10,646 12,366 PROD1 DRILL TRIP P RIH f/ 10646' - 12366' MD; Filling Pipe Every 25 Stds; Monitor Displacement on Tri Tank 12:30 18:00 5.50 12,366 16,557 PROD1 DRILL REAM P Pump & Rotate in Hole f/ 12366' - 16557' MD; 216 GPM @ 1000 PSI; 70 RPM, Torque 18 K, P/U 220, S/O 0, Rot 142 18:00 21:15 .3.25 16,557 19,602 PROD1 DRILL REAM P Wash & Ream f. 16557' - 19602' MD; 216 GPm @ 1000 PSI; P/U 220, S/O 0, Rot 142; No obstructions from Either Side Track 21:15 22:00 0.75 19,602 19,708 PROD1 DRILL MILL P Work 8 11/16" Mill Through Stage Collar f/ Bit Depth 19602' - 19708' MD at 1.5 - 2 FPM; 540 GPM @ 3800 PSI; P/U 220, S/O 0, Rot 142 22:00 00:00 2.00 19,708 19,708 PROD1 DRILL CIRC P Circ & Cond Mud; Prior to Sweep 540 GPM @ 3800 PSI, ECD = 12.04; Pump 42 Bbl 8.7 PPG, 240 Vis Swee to Clean Hole 12/13/2007 00:00 00:45 0.75 19,708 19,708 PROD1 DRILL CIRC P Continue to Circulate Mud @ 19708' MD; 540 GPM @ 3800 PSI; 120 RPM, Torque 21; ECD 12.04; Pump 42 Bbi High Vis Sweep Resulting in Moderate Cuttings Increase. Circulated a total of 2120 bbls, which was the sweep to surface(1352 bbls) plus two open hole volumes. 00:45 01:00 0.25 19,708 19,708 PROD1 DRILL OWFF P Monitor Well for Flow- static. Obtain SPR's. 01:00 02:00 1.00 19,708 19,708 PROD1 DRILL OTHR P Drop 2 1/8" Ball & Pump at 3 BPM to Open CCV; Ball Seated @ 1154 Strokes; Valve Actuated at 2000 PSI 02:00 04:45 2.75 19,708 19,708 PROD1 DRILL CIRC P Cirulate 5 Bottoms-UpThrough CCV @ 11913' MD; Stage Pumps Up f/ 650 - 930GPM watching pit volume and flow percent as Follows: 650 GPM @ 2380 PSI, 700 GPM @ 2700 PSI, 750 GPM @ 3040 PSI, after one bottom's up, stage up to 800 GPM @ 3250 PSI, 850 GPM @ 3600 PSI, 900 GPM @ 3930 PSI, and 930 GPM @ 4100 PSI just prior to two bottom's up (1134 bbls pumped). Continue to circulate without losses for a totatl of 5 bottom's up (3310 total bbls pumped with the valve o ened . Page 2D of ~"T • C~ I Time Logs 1 ~ _Da e From To Dur S D th E De th Ph e Code Subcode 7 COM _ _ 12/13/2007 04:45 05:30 0.75 19,708 19,708 PROD1 DRILL OTHR P Drop a 2-1 /8" Ball & Pump at 3 BPM to Close CCV; Ball Seated @ 1105 Strokes; Verify Valve Position by Pressure Increase. MWD detection obtained. ECD's 11.85ppg w/ 540 m. 05:30 05:45 0.25 19,708 19,708 PROD1 DRILL OWFF P Monitor Well for Flow- static. 05:45 07:45 2.00 19,708 19,708 PROD1 DRILL OTHR P Displace Well Fluid f 8.4 ppg MOBM to 8.8 ppg SFOBM w/ 1% tube 776 , 59 VIS, @ 19708' MD; Pumping 500 GPM @ 3320 PSI, Rotating 60 RPM, Torque While Reciprocating = 20K; While Not Reciprocating Torque Increases to 26K and Top Drive Stalls. Reciprocating 80' f/ 19708' to 19628'. Working string mill across the stage collar in the hole 8991 to 8993'. 07:45 08:00 0.25 19,708 19,708 PROD1 DRILL CIRC P Obtain SPR's. 08:00 08:15 0.25 19,708 19,698 PROD1 DRILL PULD P Install air slips. Lay down a single of 5" drill pipe. PU wt 270k. No down wei ht. 08:15 08:30 0.25 19,698 19,696 PROD1 DRILL OWFF P Monitor Well for Flow- static. 08:30 14:15 5.75 19,698 12,083 PROD1 DRILL TRIP P Pull out of the hole on elevators. Record PU and SO data per rig en ineer. SLM. 14:15 14:45 0.50 12,083 12,083 PROD1 DRILL OWFF P Drop a 2.31" OD rabbit w/ 120' of slicktine. Monitor Well for Flow- static. 14:45 15:30 0.75 12,083 10,648 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Record PU and SO data per ri en ineer. SLM. 15:30 .16:00 0.50 10,648 10,648 PROD1 DRILL PULD P Lay down the Baker 8-11/16" sting mill, and two crossovers subs. Guage mill to be 8-11!16". 16:00 17:30 1.50 10,648 7,746 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Record PU and SO data per ri en ineer. SLM. 17:30 18:00 0.50 7,746 7,731 PROD1 DRILL PULD P Lay down the Centurain Circulating valve and ball catcher. Removed the two 2-1 /8" balls, then screwed the ball catcher back together onto the valve and for ue u . 18:00 21:45 3.75 7,731 355 PROD1 DRILL TRIP P POOH on Elevators f/ 7746' - 355' MD; Hole Took 55 Bbls Over Calculated Fill, Calculated 164 bbls, Actual 219 bbls; Take Torque & Drag Every 10 Stds. SLM. 21:45 23:15 1.50 355 0 PROD1 DRILL PULD P Down Load MWD, Stand Back DC's, Jars, & HWDP, Lay Down MWD, Geo-Pilot, & Break Out Bit 23:15 00:00 0.75 0 0 COMPZ RPCOh PULD P P/U and Rig Up GBR Liner Running Tools, Clean & Clear Ri Floor Gage ~1 of 37 Time Logs Date From To Dur 5 De th E. De th Ph Code Subcode T COM 12/14/2007 00:00 00:30 0.50 0 0 COMPZ RPCOh PULD P _ Cont'd to R/U GBR Caing Tools and Clear Rig Floor. Monitored well on the trip tank. 1 BPH loss. Functioned blind rams while out of the hole. 00:30 01:00 0.50 0 0 COMPZ RPCOti SFTY P PJSM on running 5-1/2", 15.5 ppf, L-80, slot/blank, BTC and Hydril 521 Liner 01:00 09:30 8.50 0 8,189 COMPZ RPCOh RCST P RIH w/ 195 Jts "B" Lateral Liner Per Detail f/ 0' - 8189' MD; Hole Took Proper Displacement (48 Bbls). Record PU and SO data per Rig en leer. 09:30 09:45 0.25 8,189 8,189 COMPZ RPCO SFTY P PJSM w/ BOT, CPAI, Doyon, & Sperry on M/U of MLZXP Packer, MWD, and Orientation 09:45 11:15 1.50 8,189 8,345 COMPZ RPCOh PULD P P/U Baker Tools and Organize Rig Floor, M/U and Orient MWD and Packer 11:15 11:30 0.25 8,345 8,345 COMPZ RPCO DHEQ P Shallow Pu-se Test MWD; 105 GPM 600 PSI 11:30 12:30 1.00 8,345 8,345 COMPZ RPCO PULD P Clear Rig Foor of Baker Tools & Protectors, Blow Down Top Drive, Move HWDP, Break Out XO's on Floor Valves 12:30 17:15 4.75 8,345 12,089 COMPZ RPCO TRIP P Continue to RIH w/ 5-1/2" 15.5 ppf L-80 slot/blank "B" Lateral Liner Per Detail fl 8345' - 12089' MD; Hole Took Proper Displacement (48 Bbls). Record PU, SO, Rotating weight, Rotating torque data per Rig engineer. Ran out of down wt @ 10915'. Started rotating in the hole w! 40-50 rpm, initial torque of 10500 ft Ibs of torque. Monitor dis lacement on the tri tank. 17:15 17:30 0.25 12,089 12,089 COMPZ RPCO DHEQ P Test MWD prior to exiting 9-5/8" casin shoe; 105 GPM 620 PSI 17:30 18:00 0.50 12,089 12,800 COMPZ RPCO TRIP P Continue to rotate in the hole w/ 5-1/2" 15.5 ppf L-80 slot/blank "B" Lateral Liner Per Detail f/ 12089' - 12800' MD; Record PU, SO, Rotating weight, Rotating torque data per Rig engineer (every 5 stands). Monitor dis lacement on the tri tank. 18:00 00:00 6.00 12,800 17,482 COMPZ RPCOh TRIP P Continue to rotate in the hole w! 5-1/2" 15.5 ppf L-80 sloUblank "B" Lateral Liner Per Detail f/ 12800 - 17482' MD; Record PU, SO, Rotating weight, Rotating torque data per Rig engineer (every 5 stands). Monitor dis lacement on the tri tank. t'~H~£ ~~ Cs~ ~~ Ttme Logs _ Da e From To Dur S. De th E. De th Phase Code Su bcode T COM 12/15/2007 00:00 02:30 2.50 17,482 19,639 COMPZ RPCOh _ TRIP P Continue to rotate in the hole w/ the 5-1/2" 15.5 ppf L-80 slot/blank "B" Lateral Liner Per Detail f/ 17482 - 19639' MD; Record PU, SO, Rotating weight, Rotating torque data per Rig engineer (every 5 stands). Monitor displacement on the trip tank. PU wt 240k, SO wt while rotating and traveling down 40'/min 115k, Rotating weight 142k. Rotating 40-50 rpm w/ 21 k ft Ibs of torque. Note: Total fluid lost while running the liner and drill pipe was 9.5 bbls. Layed down the top single of stand # 116. Len th of the 'oint was 31.69'. 02:30 02:45 0.25 19,639 19,708 COMPZ RPCO TRIP P Continue to rotate in the hole w/ 5-1/2" 15.5 ppf L-80 slot/blank "B" Lateral Liner Per Detail f/ 19639 - 19708' (TD) . Ta bottom. PU wt 240k SO wt while rotating and traveling down 40'/min 115k, Rotating weight 142k. Rotating 40-50 r m w/ 21 k ft Ibs of for ue. 02:45 03:45 1.00 19,708 19,652 COMPZ RPCOh OTHR P Pickup 5', shut down rotary, then start pumping 90 gpm (21 spm) w/ 520 psi. Obtain MWD survey. Begin letting torque out of the string (6-1/2 turns). Work pipe back up the hole, during which MWD showed 41 left of high side. Apply another 1/2 turn right, work pipe to aquire a final of 26 Left for the orientation of the MLZXP packer on depth of 11412.61', collet depth 11425.44', and shoe depth of 19652.55'. 03:45 04:00 0.25 19,652 19,652 COMPZ RPCOti OTHR P Shut down pumps, break off the top drive and dro a 1-3/4" ball. 04:00 05:30 1.50 19,652 19,652 COMPZ RPCOh CIRC P Pump the Baker 1-3/4" ball to seat (197 bbl string capacity, 1962 strokes). Pumping 90 gpm (21 spm) w/ 620 psi. Sperry Sun MWD showing 26 left of high side entire time. Ball was on seat after pumping 1637 strokes 167.4 bbls . 05:30 05:45 0.25 19,652 19,652 COMPZ RPCO PACK P While holding 170k on the weight indicator, pressure string to 2200 psi. to set the flexlock liner hanger, slack off to block weight, continue to pressure up to 2500 psi to activate the pusher tool and set the MLZXP liner top packer. Continue to pressure up to 3000 psi to release the running tool. Continue to pressure up to 4100 psi to neutralize the pusher tool. Bleed off the ressure. ~ ~ Pay 2~ off 3T n • Time Logs _ 'Date From To Dur S De th E. De th Phase Code Subcode T COM 12/15/2007 05:45 06:15 0.50 19,652 19,652 COMPZ RPCOh DHEQ P Pick up to verify release of liner . PU wt 220k (loss of 20k PU weight). Line up to pump down the kill line with the top pipe rams closed (3-1/2" x6"), to test the MLZXP packer f/ 5 minutes to 2500 si. Chart the test. Lost 30 psi. Good test. Bleed pressure, open rams. Note: A pre job safety meeting was held for displacement f/ 8.8 ppg SFOBM w/ 1 % 776 tube to 8.4 ppg MOBM while testin the aaker. 06:15 06:30 0.25 19,652 11,395 COMPZ RPCOh TRIP P Pull and stand and set back, then pull 71' of next stand out of the hole. Circulatin sub ositioned 11365'. 06:30 08:45 2.25 11,395 11,395 COMPZ RPCO CIRC P Line up, then displace well f/ 8.8 ppg SFOBM w/ 1% tube 776 to 8.4 ppg MOBM. Pumping 10.5 bpm (105 spm) w/ 1360 psi initial,. 1260 final psi. 8.4 MOBM to surface after pumping 8000 strokes 803 bbls . 08:45 10:00 1.25 11,395 10,400 COMPZ RPCOh TRIP P POOH f/ 11365' - 10400' MD on Elevators; Hole Swabbing -Hole Took 30 Bbls to Fill vs. Calculated 12 Bbls for 15 Stands; P/U 220, S/O 0 10:00 11:15 1.25 10,400 9,500 COMPZ RPCOh TRIP P Pump Out-of-Hole f/ 10400' - 9500' MD; 197 GPM @ 360 PSI; P!U 200, S/O 0 11:15 18:00 6.75 9,500 11 COMPZ RPCO TRIP P POOH on Elevators f/ 9500' - 11' MD; Monitor Hole On Trip Tank; Hole Took 101 Bbls to Fill Vs. 76 Calculated for Entire 95 Stand Trip. Record PU and SO wt's er Ri en leer. 18:00 19:30 1.50 11 0 COMPZ RPCOh PULD P UD MWD, Baker Liner Running Tools 19:30 20:00 0.50 0 0 COMPZ RPCOh OTHR P Clean & Clear Rig Floor; Clear BOT S ecific Tools 20:00 21:00 1.00 0 0 COMPZ WELCT OTHR P Pull Wear Ring, Set Test Plug, P/U Test Joint, & R/U to Test BOPE. 21:00 00:00 3.00 0 0 COMPZ WELC BOPE P Test Annular Preventer w! 4-1/2" test joint, Blind Rams, Upper Pipe Rams (3-1/2" x 6" variables) and Associated Valves to 250 (Low) - 3500 (High), hold each test f/ 5 minutes, chart test.; AOGCC Witness Waived by John Cris . 12/16/2007 00:00 00:15 0.25 0 0 COMPZ WELC BOPS P Cont' ue ~ Test of Koomey; Start = 3100 PSI, After closing = 1500 PSI, 35 Seconds f/ 200 PSI Increase, 3 Minutes 3 Seconds = Full Charge (3100 PSI); 2400 PSI on 5 Bottle Average; Gas Alarms Tested Good 00:15 01:15 1.00 0 0 COMPZ WELCT OTHR P Rig Down Test Equipment & Pull Test Plug; Lay Down Test Joint & Set Wear Rin ;Blow Down Kill & Choke Lines ~'~g~ 2~ s~f 37 • • ~, Time Logs Date From To Dur S. De th E: C?e th Phase Code Subcode T COM 12/16/2007 01:15 02:00 0.75 0 0 PROD2 DRILL PULD P Bring Baker Tools f/ Outside to Rig Floor & Invento 02:00 02:15 0.25 0 0 PROD2 STK OTHR P PJSM for P/U and M/U Whipstock and Millin Ass . 02:15 03:45 1.50 0 0 PROD2 STK PULD P Make Up Lower and Upper Mills and Lay Down; P/U & M/U Whipstock Ass 03:45 06:00 2.25 0 0 PROD2 STK OTHR P Orient Whipstock face to MLZXP Anchor. Whipstock face is 10.82 degrees to the right of the anchor lug. This anchor will index into the MLZXP packer which was oriented to 26 deg left. (Tool circumference was 7.32", offset was 0.22"). P/U Milling Assy, and 1 Jt. HWDP and M/U to Whipstock Assy; P/U MWD and M/U to Mill & Whipstock Orient MWD to the whipstock face. MWD to whipstock offset was 100.26 deg. The whipstock was to the right of MWD by 100.27 deg. (Circumference of tool was 6.75", offset was 1.88" 06:00 06:45 0.75 0 0 PROD2 STK OTHR P Upload MWD Software 06:45 07:30 0.75 0 251 PROD2 STK PULD P P/U Remainder of BHA #6 (which is the whi stock assembl 07:30 08:00 0.50 251 535 PROD2 STK TRIP P Trip in the hole 3 stands of 5"drill pipe 08:00 08:15 0.25 535 565 PROD2 STK CIRC P Make a top drive connection on stand #4, then shallow test MWD. Pumping 600 gpm w/ 1190 psi, OK. Blow down the to drive. 08:15 17:15 9.00 565 10,242 PROD2 STK TRIP P Trip in the hole w/the Baker whipstock, (BHA #6). PU 5" HWDP from the pipe shed/MU/RIH from 9831'. Note; Pipe stopped at 10-3/4" x 9-5/8" Crossover @ 3,928' and had to work thru same -also pipe stopped several times at different depths on the way in the hole to bottom working thru each one. 17:15 18:30 1.25 10,242 10,305 PROD2 STK OTHR P MAD pass f/ 10242' to 10305' anchor depth, MWD Gamma depth"s 10109' to 10172'. Pumping 595 gpm w/ 2960 si. Runnin seed 3' ft/min 180'/hr). 18:30 19:30 1.00 10,305 11,394 PROD2 STK TRIP P Continue to trip in the hole w/the Baker whipstock, (BHA #6). Picking up a total of 45 jts of 5" drill pipe from the i e shed. €'age 2~ ~~ 37 l~ • Time Logs _ Date From To Dur S_ . Deptfi E. D th Ph s Code Subco e T 'COM 12/16/2007 19:30 20:00 0.50 11,394 11,432 PROD2 STK OTHR P Make a top drive connection on stand # 119 (11394.72' in the hole). Pumping 498 gpm w/ 2600 psi. Orient whipstock face from 59 right of highside, turning to the right to aquire a 34 deg left. Working pipe about 30' f/ anchor depth of 11387' to 11395'. Working string to 34 Left. PU wt 215-220k, SO wt 118-120k. Slack off 20k (100k on weight indicator) w/ 38' in on stand #119 (Collet depth of 11432.72'). Pickup with no overpull (PU wt 215k). MWD showing whi stock face to be 26 left. 20:00 22:00 2.00 11,432 11,432 PROD2 STK OTHR T Attempt latch in, again with no overpull. Turn string to orient whipstock face to 14-17 left of highside. Attempt several times to engage collet into MLZXP profile, set as much as 40k with no overpull observed PU wt 210-215k .. 22:00 22:30 0.50 11,432 11,394 PROD2 STK OTHR T Pull stand # 119 out of the hole. Open the kill line, shut the annular and presure up to 500 psi after pumping 21 strokes (2.1 bbls). Holding pressure, OK. Bleed off ressure. 22:30 22:45 0.25 11,394 11,394 PROD2 STK CIRC T Obtain Slow pump rates. 22:45 23:45 1.00 11,394 10,500 PROD2 STK TRIP T Tri out of the hole to see if whipstock . is still attatched to the mills. Hole takin ro er fiA. 23:45 00:00 0.25 10,500 10,500 PROD2 STK OWFF T Monitor well- static. 12/17/2007 00:00 00:15 0.25 10,500 10,500 PROD2 STK CIRC T Pump a dry job, blow down the top drive, blow down the kill line. 00:15 03:30 3.25 10,500 77 PROD2 STK TRIP T Pull out of the hole on elevators. Hole took ro er dis lacement. 03:30 03:45 0.25 188 90 PROD2 STK PULD T Download Sperry Sun MWD. 03:45 04:15 0.50 90 0 PROD2 STK PULD T Lay down mills of the milling assembl . No whi stock. 04:15 04:45 0.50 0 0 PROD2 STK OTHR T Clean and clear rig floor. 04:45 05:00 0.25 0 50 PROD2 STK PULD T MU BHA #7 (Whipstock retrieval hook .Orient MWD w/ the hook. 05:00 05:45 0.75 50 50 PROD2 STK PULD T Upload Sperry Sun MWD. 05:45 06:15 0.50 50 330 PROD2 STK TRIP T Continue to MU BHA #7, then run a stand of 5" d . 06:15 06:30 0.25 330 330 PROD2 RIGMN' SFTY P Pre job safety meeting on slipping and cuttin drillin line. 06:30 07:15 0.75 330 330 PROD2 RIGMN SVRG P Slip and cut 142' of 1-3/8"drilling line. 07:15 07:45 0.50 330 330 PROD2 RIGMN' SVRG P Service the rig. Greasing drawworks, top drive. Organize floor after slip and cut. ~~ Paca ~ti of 3? a • Time Logs _ Date From To Dur S. De th E De th Phase Code Subcode T COM 12/17/2007 07:45 08:15 0.50 330 1,400 PROD2 STK TRIP T Continue trip in the hole w/ BHA #7 whi stock retrieval assembl 08:15 08:30 0.25 1,400 1,400 PROD2 STK CIRC T Fill pipe. Test MWD pumping 608 gpm w/ 1780 si. Blow down the to drive. 08:30 14:00 5.50 1,400 11,318 PROD2 STK TRIP T Continue trip in the hole w/ BHA #7 whi stock retrieval assembl 14:00 15:15 1.25 11,318 11,318 PROD2 STK OTHR T Make a top drive connection. Pumping 500 gpm w/ 2950 psi. Tagged up at the top of the whipstock (11366'), Pickup and rotate string a turn, slack off and engaged slot of whipstock @ 11372', set down 10k. Picked up 15k overpull to verify that the whipstock assembly anchor was in the collet profile of the MLZXP pacer f/the "B" lateral. Repeat pull test several times, same results. Observed MWD reading of 24 left of highside while hooking the whipstock (MLZXP is oriented 26 left of highside, whipstock is oriented 15 left of highside). Slacked off and released from whipstock, then picked up to 11318'. Pumps off : PU wt 220k, SO wt 135k. Pumps on: PU wt 205k, SO wt 130k. 15:15 15:30 0.25 11,318 11,318 PROD2 STK OWFF T Monitorwell-static. 15:30 15:45 0.25 11,318 11,040 PROD2 STK TRIP T Pull out of the hole. Hole taking proper dis lacement. 15:45 16:00 0.25 11,040 11,040 PROD2 STK OWFF T Monitor well- static. Pump a dry job. Blow down the to drive. 16:00 21:15 5.25 11,040 171 PROD2 STK TRIP T Pull out of the hole w/ BHA #7 whi stock retrieval hook . 21:15 21:30 0.25 171 171 PROD2 STK OWFF T Monitor well- static. Remove stripping rubbers. 21:30 22:00 0.50 171 90 PROD2 STK PULD T Lay down two joints of 5" HWDP, jars and bum er sub. 22:00 22:45 0.75 90 90 PROD2 STK OTHR T Download Sperry Sun MWD 22:45 23:30 0.75 90 0 PROD2 STK PULD T Continue to laydown BHA #7 (MWD, float sub, one joint of 5" HWDP, Baker retrievi hook . 23:30 23:45 0.25 0 0 PROD2 STK OTHR T Pre job safety meeting on PU/MU BHA #8. 23:45 00:00 0.25 0 66 PROD2 STK PULD T PU Baker mills, one joint of 5" HWDP, float sub and bum r sub. 12/18/2007 00:00 00:15 0.25 66 125 PROD2 STK PULD T Continue to PU/MU BHA #8: 2 jts of 5" HWDP 00:15 00:30 0.25 125 125 PROD2 STK OTHR P Function top set of pipe rams, bottom set of pipe rams, Annular, HCR kill line and HCR on the choke line. Blind rams were functioned when out of the hole. 00:30 07:15 6.75 125 11,366 PROD2 STK TRIP T RIH w/ BHA #8 (8-5/8" Milling assembly). Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. P~g~ 27 of 37 l • Time Logs __ Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 12/18/2007 07:15 08:00 0.75 11,366 11,366 PROD2 STK MILL P Obtain Slow Pump Rates and Dry tag top of whipstock @ 11370' MD due to compression, PU 215k, SO 140k, Rotatin 178k. 08:00 12:00 4.00 11,366 11,383 PROD2 STK MILL P Mill window for D-lateral. 12:00 13:00 1.00 11,383 11,404 PROD2 STK CIRC P Pump 40 bbl sweep then drill 21' of new hole. 13:00 14:45 1.75 11,404 11,404 PROD2 STK CIRC P Circulate and pump 40 bbl sweep. Slack off and dry tag bottom. No obstructions observed going in or out of window. 14:45 15:00 0.25 11,404 11,404 PROD2 STK OWFF P Monitor well -static. 15:00 19:45 4.75 11,404 174 PROD2 STK TRIP P POOH 5 stands. Hole took proper fill. Pump dry job, blow down top drive, continue POOH. 19:45 20:00 0.25 174 174 PROD2 STK OWFF P Monitor well -static. 20:00 21:00 1.00 174 0 PROD2 STK PULD P Lay down milling BHA. Gaged mills, window mill 8.50", lower string mill 8.375", u er strip mill 8.625" 21:00 21:45 0.75 0 0 PROD2 DRILL PULD P Clear and clean rig floor. 21:45 23:45 2.00 0 0 PROD2 DRILL CIRC P Pick up stack washer and flush stack, pumping 900 gpm, reciprocating from 15' to 70', rotating 30 rpm. Cycled HCR kill, choke, annular preventor, upper and lower pipe rams. Lay down stack washer. 23:45 00:00 0.25 0 0 PROD2 DRILL SFTY P PJSM -Changing saver sub 12/19/2007 00:00 01:15 1.25 0 0 PROD2 DRILL OTHR P Change out saver sub. Clear and clean ri floor 01:15 01:30 0.25 0 0 PROD2 DRILL SFTY P PJSM -Pick up BHA #9 01:30 04:00 2.50 0 350 PROD2 DRILL PULD P Pick up BHA #9, bit, geo-pilot, MWD, TM HOC & float sub. Upload MWD. Pick up flex collars, jars, bumper sub and HWDP. 04:00 04:45 0.75 350 350 PROD2 DRILL PULD P Shallow pulse test MWD w/480 gpm, 950 psi, 30 rpm -test good. Blow down to drive. 04:45 10:30 5.75 350 11,315 PROD2 DRILL TRIP P TIH on elevators, Fill pipe every 25 stands. Record PU & SO every 10 stands. Monitor displacement via trip tank. Installed CCV Valve below top sin le on stand 85. 10:30 10:45 0.25 11,315 11,315 PROD2 DRILL CIRC P Record slow pump rates. Blow down to drive. 10:45 11:00 0.25 11,315 11,315 PROD2 DRILL SFTY P PJSM -Slip and Cut drilling line. 11:00 13:00 2.00 11,315 11,315 PROD2 DRILL OTHR P Slip an cut drilling line, service crown, to drive and blocks. Page 2~ off 37 r ~~ ~~~ ~R~ i .~ r1 l i Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM I 12/19!2007 13:00 18:00 5.00 11,315 12,050 PROD2 DRILL DDRL P Drilling D-Lateral. Crossed fault @ 11774' MD with 5' throw to the south. Total 70' out of pay while building ah le from window to D sands. 18:00 00:00 6.00 12,050 12,422 PROD2 DRILL DDRL P Drilling D-Lateral. Experienced trouble steering. Adjust flow rate, rpms and WOB. Geo-pilot reporting housing roll via Insite. 12/20/2007 00:00 06:00 6.00 12,422 12,740 PROD2 DRILL DDRL P Drilling D-Lateral. 06:00 12:00 6.00 12,740 13,978 PROD2 DRILL DDRL P Drilling D-Lateral. 12:00 12:45 0.75 13,978 13,978 PROD2 DRILL SFTY P Safety awareness meeting on the rig. Attended by CPAI Drilling Supervisor, CPAI Drilling Field Supervisor, CPAI Safety Rep, DDI Toolpusher, DDI Safety Rep, RLG, Sperry Sun, Little Red, MI, DDI Rig manager and all non-essential rig crew. Discussed recent COP incidients and discussed preventative measures taken in our o eration to achieve Tar et Zero oats. 12:45 18:00 5.25 13,978 14,929 PROD2 DRILL DDRL P Drilling D-Lateral. 18:00 00:00 6.00 14,929 15,786 PROD2 DRILL DDRL P Drilling D-Lateral. Safety awareness meeting in camp with night crew. Attended by CPAI Drilling Supervisor, CPAI Safety Rep, DDI Toolpusher, DDI Tourpusher, night rig crew and members of day crew that could not attend day meeting. Discussed recent COP incidients and discussed preventative measures taken in our o eration to achieve Tar et Zero oats. 12/21/2007 00:00 06:00 6.00 15,786 16,489 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 621 gpm, SPP 4020 si, ECDs 11.82 06:00 12:00 6.00 16,489 17,309 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 610 gpm, SPP 4000 si, ECDs 11.85 12:00 18:00 6.00 17,309 18,166 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 600 gpm, SPP 4050 si, ECDs 11.90 18:00 00:00 6.00 18,166 18,832 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 600 gpm, SPP 4070 si, ECDs 11.95 12/22/2007 00:00 06:00 6.00 18,832 19,403 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 580 gpm., SPP 3980 si, ECDs 11.99 06:00 09:30 3.50 19,403 19,750 PROD2 DRILL DDRL P Drilling D-Lateral to TD. Flow rate 570 m, SPP 4000 si, ECDs 12.16 09:30 11:15 1.75 19,750 19,750 PROD2 DRILL CIRC P Circulate 1.5 bottoms up @ 570 gpm, 3950 psi, 140 rpm, torque 22k, ECDs 12.15 ppge before beginning to circulate. 11:15 12:00 0.75 19,750 19,310 PROD2 DRILL REAM P Backream, pumping 570 gpm, 4030 si, 140 r m, for ue 20k. 12:00 18:00 6.00 19,310 15,884 PROD2 DRILL REAM P Backream, pulling 40-45 fpm, pumping 630 gpm, 3950 psi, 140 rpm, torque 18k. la~g~ 2~ t~f 37 ~~ Time Logs Date From To Dur 5 D th E. De th Phase Code Subcode T COM 12/24/2007 00:30 01:15 0.75 19,748 19,748 PROD2 DRILL CIRC P Drop ball to close circulation sub. Pump ball down at 3 bpm, 330 psi, rotating 50 rpm. Ball landed early. Pressure up to 1500 psi hold for 1 minute, pressure up to 2000 psi hold for 30 seconds, pressure up to 2500, sub closed at about 2300 psi. Established circulation thru bit. 01:15 04:00 2.75 19,748 19,748 PROD2 DRILL CIRC P Displace well over to 8.8 ppg, 79 vis SFOBM. Displaced at 500 gpm, 3210 psi, rotating 100 rpm (-14100 strokes). Before displacement ECDs 11.78 ppge after 11.43 ppge. Pumps off rotating 40 rpm, PU 245k, rotating wt 140k. 04:00 04:15 0.25 19,748 19,748 PROD2 DRILL OWFF P Monitor well -static 04:15 10:30 6.25 19,748 11,312 PROD2 DRILL TRIP P Pull out of hole on elevators to window. Monitoring well via trip tank. Recording PU & SO every 10 stands. Lost 17 bbls more than calculated for tri . 10:30 12:30 2.00 11,312 11,312 PROD2 DRILL CIRC P Add tubes to system. Increase tubes in cased hole from 1 % to 3%. Pumped at 400 gpm, 1700 psi, rotating 120 rpm and reciprcating pipe 90'. Before tube: torque 17k, PU 228k, SO 90k, rotating wt 145k After tube: torque 10k, PU 180k, SO 115k, rotatin wt 140k 12:30 13:00 0.50 11,312 11,312 PROD2 DRILL OWFF P Monitor well -static. Blow down top drive. 13:00 14:30 1.50 11,312 8,421 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Recording PU & SO eve 10 stands. 14:30 15:00 0.50 8,421 8,421 PROD2 DRILL PULD P Breakout and lay down circ sub. Retrieved 2 balls. 15:00 18:00 3.00 8,421 2,353 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Recording PU & SO eve 10 stands. 18:00 20:15 2.25 2,353 355 PROD2 DRILL TRIP P Drop mud dawg (drillpipe wiper), pull out of hole and lay down 21 stands of 'old' drillpipe. Monitoring well via trip tank. Lost total of 26 bbls on trip from td. 20:15 21:45 1.50 355 76 PROD2 DRILL PULD P Rack back 1 stand of HWDP and lay down 2 singles. Lay down jars, bumper sub, flex collars and float sub. Break off bit. 21:45 00:00 2.25 76 0 PROD2 DRILL PULD P Download MWD. Lay down MWD and eo- ilot. Clear and clean ri floor. 12/25/2007 00:00 00:30 0.50 0 0 COMPZ RIGMN SVRG P Service top drive, drawworks and iron rou hneck. 00:30 01:00 0.50 0 0 COMPZ DRILL SFTY P PJSM -Picking up BHA to rig floor. Page 31 of 37 r~ Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T COM 12/25/2007 01:00 02:15 1.25 0 180 COMPZ DRILL PULD P Pick up and make up hook, 1 joint HWDP, string magnet, bumbper sub, jars, float sub, MWD and 2 joints of HWDP. 02:15 03:00 0.75 180 180 COMPZ DRILL PULD P Download MWD. Monitoring well via tri tank -static 03:00 03:45 0.75 180 1,133 COMPZ DRILL TRIP P Run in hole on elevators and shallow test MWD. Seeing high standpipe ressure 03:45 04:30 0.75 1,133 1,133 COMPZ DRILL OTHR T Trouble shoot high standpipe pressure. Tested surface equipment. Rotated BHA and pressure dropped to normal 04:30 11:30 7.00 1,133 11,297 COMPZ DRILL TRIP P Continue RIH on elevators to 11,297', Fill pipe every 25 stands, Lost 6 bbls mud while RIH. 11:30 13:00 1.50 11,297 11,294 COMPZ DRILL CIRC P Break circ w/ 427 gpm @ 2430 psi Up 210K, Dn 130K, Orient Whipstock retrieving hook & hook @ 11,372" (On depth), Pull whipstock loose w/ 90K over ull, Pull u to 11,294'. 13:00 13:15 0.25 11,372 11,294 COMPZ DRILL CIRC P Attempt to circ btm's up- No good - loosin mud. Lost 7 bbls 13:15 13:30 0.25 11,294 11,294 COMPZ WELC OWFF P Monitorwell-Static 13:30 20:00 6.50 11,294 119 COMPZ DRILL TRIP P POOH on elevators w/whipstock f/ 11,294' to 119', Lost 23 bbls over calculated f/displacement for entire trip out, Monitor well @ 6,588', 2,880, & 532' on wat out of hole. 20:00 20:30 0.50 119 119 COMPZ DRILL OTHR P Down load MWD. 20:30 21:45 1.25 119 61 COMPZ DRILL PULD P Lay down MWD, Float sub, Jars & .Bumper sub, String magnet, 1 jt HWDP & Retrievin tool. 21:45 22:00 0.25 61 61 COMPZ DRILL OTHR P Pick up and check orientation of whi stock and Anchor- OK, 22:00 23:00 1.00 61 0 COMPZ DRILL PULD P Lay down Whipstock, Debris sub, Magnet, Blank sub, Unloader, Shear disconnect, Pu & Anchor. 23:00 00:00 1.00 0 COMPZ DRILL OTHR P Clean & Clear rig floor. Note; Lost 88 bbls mud for the da . 12/26/2007 00:00 00:45 0.75 COMPZ DRILL PULD P Pick up Boot baskets and Crossovers to rig floor, Rig GBR Casing tong E ui ment. 00:45 01:15 0.50 COMPZ CASIN SFTY P PJSM w/All Baker oil tools, GBR, ConocoPhillips, Doyon on picking up Diverter s tem. 01:15 02:30 1.25 104 COMPZ CASINC PUTS P Pick up & Make up Diverter as per detail, Orient Diverter to Anchor for 11 de . Ri ht of Hi hside. 02:30 03:45 1.25 104 155 COMPZ CASINC PUTS P Pick up & Make up MWD & Upload same. F'~e 32 cif 3~ l d Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/26/2007 03:45 04:15 0.50 155 155 COMPZ CASIN DHEQ P Surface test MWD & FJD Tool on Diverter to release, Had good detection on MWD at 265 gpm @ 580 psi, FJD Tool relesed at 410 gpm @ 1350 si. 04:15 04:30 0.25 155 220 COMPZ CASIN PUTB P Make up Float sub, 2 Boot baskets, Crossovers & 2 Strin Ma nets. 04:30 13:30 9.00 220 11,454 COMPZ CASIN RUNL P RIH w/ RAM Seal Bore Diverter at 90 fUmin to 11,398', Record Up & Dn wt's every 10 stands, Fill pipe every 25 stands, Lost 6 bbls while RIH. 13:30 14:00 0.50 11,454 11,454 COMPZ CASIN RUNL P Break circ, Circ at rate of 265 gpm @ 1140 psi, Tool face of 1 deg Left, Obtain wt's of Up 215K & Dn 110K, Set down w/ 20K & Latch Anchor w/ 11 deg Right of Highside toolface on depth w/ Mule shoe @ 11,454', Top of Seal Bore Diverter @ 11,360' w/ Seal Assembly spaced out 10.25' inside Seal Bore Extention, Pull test Anchor w/ 70K over, Release from Diverter by staging rate at 25 gpm increments up to 475 m 3450 to release. 14:00 14:15 0.25 11,454 11,454 COMPZ WELC OWFF P Monitor well -Static. 14:15 15:15 1.00 11,454 11,019 COMPZ DRILL TRIP P POOH to 11,019', Blow down top drive, Line u hole fill um . 15:15 17:45 2.50 11,019 11,019 COMPZ RIGMN SVRG P PJSM, Cut & Slip Drilling line, Adjust Brakes, Serive ri Lost 2 bbls mud 17:45 00:00 6.25 11,019 2,858 COMPZ DRILL TRIP P POOH w/ Diverter running tool f/ 11,019' to 2,858'. 12/27/2007 00:00 01:15 1.25 2,858 114 COMPZ DRILL TRIP P POOH w/ Diverter running tool f/ 2,858' to 114'. 01:15 02:15 1.00 114 57 COMPZ DRILL PULD P Clean & Lay down String Magnets, Boot baskets and Crossovers (Good amount of metal shavin son ma nets 02:15 02:45 0.50 57 57 COMPZ DRILL PULD P Down load MWD. 02:45 03:45 1.00 57 COMPZ DRILL PULD P Lay down MWD, Seal Bore Diverter runni tools. 03:45 04:30 0.75 COMPZ CASIN RURD P Rig to run 4-1/2" D-Lateral liner, PJSM with all involved personal for running liner. 04:30 12:00 7.50 8,291 COMPZ CASIN PUTB P Pick up & Run 4-1/2", 11.6#, L-80, Slot t Blank as per detail, Up 112K, Dn 90K, Lost 5.1 bbls over calculated. 12:00 13:30 1.50 8,291 8,343 COMPZ CASIN( PUTS P Pick up RAM Hanger and Inner string as er Baker oil tools. 13:30 14:00 0.50 8;343 8,343 COMPZ CASIN RURD P Rig down GBR casing equipment, Clean & Clear ri floor. 14:00 14:45 0.75 8,343 8,441 COMPZ CASIN( PUTB P Pick up Bumper sub, RIH to 8,441', Record Up 115K, Dn 95K, Rot 100K, Tq 3/4K, Break circ thru Hanger e ui ment. ~~ ~ ~ Page 33 of 3T ~' Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 12/27/2007 14:45 22:00 7.25 8,441 19,531 COMPZ CASINC RUNL P RIH w/ 4-1/2", 11.6#, L-80 liner & RAM Hanger on 5" drill pipe & HWDP f/ 8,441' to 19,531', Record T & D every 10 stands, Fill pipe every 25 stands, Did not have to rotate pipe -Ran pipe on elevators the entire wa . 22:00 22:45 0.75 19,531 19,689 COMPZ CASIN OTHR P PU stand 119. 240k up, 90k down with no pumps. Rotating torque last movement up: 12k ft-Ibs @ 30rpm. Rotating torque last movement down: 13.5k ft-Ibs @ 30 rpm, 150k rotating weight down. PU stand 120. Set top drive top drive torque limit to 15.5k ft-Ibs. Pump 214 gpm @ 850 psi and RIH with stand 120 rotating 30 rpm. Turn pumps off 35' in on stand 120 (ported X-O at 11,366'). Land RAM hanger at 69' in (top of RAM hanger at 11,355', liner shoe at 19,689' rotating entire way. Set down 20k, turn top drive off. PU, see bumper sub open at 220k, snap RAM hanger out at 270k (50k overpull). Pull entire stand 120 out. Pump 209 gpm, rotate 30 rpm, RIH, turn pumps off 35' in, land RAM hanger 69' in on stand 120 (same depth as previous land point). turn top drive off, set down to block weight. PU, see bumper sub open at 220k, pull to 245k (25k overpull to confirm RAM han er is latched . 22:45 23:45 1.00 19,689 19,689 COMPZ CASIN CIRC P Drop Ball &Circ at rate of 5.0 bpm @ 840 psi f 1500 stks, Then slowed to 2.0 bpm @ 310 psi, Ball on seat w/ 1950 stks. 23:45 00:00 0.25 19,689 19,689 COMPZ CASINC OTHR P Pressure up to 3000 psi to release running tool, Pick up to 235K twice in attem t to release liner- No ood. 12/28/2007 00:00 00:15 0.25 19,689 11,355 COMPZ CASINC OTHR P Attempt to release from liner by appling 3000 psi on drill pipe and checking to see if running tool was free- No Good, Applied 3300 psi to release running tool and that finally released the runnin tool. 00:15 00:30 0.25 11,355 11,196 COMPZ DRILL TRIP P POOH f/ 11,355' to 11,196'. 00:30 02:00 1.50 11,196 11,196 COMPZ DRILL CIRC P Circ Btm's up at rate of 380 gpm @ 1400 si. 02:00 02:15 0.25 11,196 11,196 COMPZ WELCT OWFF P Monitor well-OK. 02:15 12:00 9.75 11,196 720 COMPZ DRILL PULD P Pump dry job, Drop Mud Dog I.D. wiper, POOH & Lay down 5" Drill pipe f/ 11,196' to 720' 12:00 12:30 0.50 720 720 COMPZ WELC OWFF P Monitor well- Static. ~'~g~ 34 of 37 ' Time Logs _ D to From To Dur 5 De th E. th Ph ~e Code Subco e T COM 12/28/2007 12:30 13:15 0.75 720 101 COMPZ DRILL PULD P Finish laying down 5" Drill pipe, Hole took 28 bbls over calculate dis lacement for entire tri out. 13:15 15:00 .1.75 101 COMPZ DRILL PULD P Lay down Bumper sub & Baker running tools, Clear tools from rig floor, Clean ri floor. 15;00 17:15 2.25 COMPZ RPCO RURD P Rig GBR Tong service, Bring Centrilift tools to rig floor & rig up same for runnin 4-1/2" ESP Com letion. 17:15 18:45 1.50 COMPZ RPCOh RURD P PJSM, Hang ESP Cable sheave in derrick and secure. 18:45 19:15 0.50 COMPZ RPCO PULD P Pull wear bushing. 19:15 19:30 0.25 COMPZ RPCO SFTY P PJSM with Doyon, ConocPhillips, Centrifilt, Howco wireline on picking up ESP Com letion. 19:30 20:15 0.75 97 COMPZ RPCO PULD P Pick up & Make up TCC Crossover, 2 jts $-1/2" Tbg, Pressure Discharge sub. 20:15 20:45 0.50 97 97 COMPZ RPCO RURD P Rig Halliburton wire line. 20:45 23:00 2.25 97 97 COMPZ RPCOh PULD P Install Pump Assembly & Pack off. 23:00 23:30 0.50 97 97 COMPZ RPCOti DHEQ P Rig & Test pack off to 1000 psi f! 15 min.-OK, Ri down test a ui ment. 23:30 00:00 0.50 97 97 COMPZ RPCO PULD P Install Tubing stop w/ Slick line. 12/29/2007 00:00 00:30 0.50 97 0 COMPZ RPCO PULD P Rack back TCC Crossover, 2 jts 4-1/2" Tbg, Pressure Discharge sub in derrick, Ri down Halliburton wire line 00:30 01:30 1.00 0 51 COMPZ RPCOb PULD P Pick up & make up Motor centralizer, Pump gauge, Motor, Upper & lower Tandem seal sections, Fill w/oil & service. 01:30 02:30 1.00 51 51 COMPZ RPCOh PULD P Make up ESP Cable & Perform olarit test. 02:30 04:00 1.50 51 152 COMPZ RPCOb PULD P Pick up TCC Crossover, 2 jts 4-1/2" Tbg, Pressure Discharge sub f/ derrick, RIH to/ 152'. 04:00 17:45 13.75 152 6,101 COMPZ RPCO PULD P RIH f/ 152' to 6,101' w/ 4-1/2", 12.6#, L-80, IBT completion string w/ ESP, Installing Cannon clamps on every collar, Test cable @ 2145', 3174', 4400', 5636'. 17:45 18:15 0.50 6,101 6,101 COMPZ RPCOh RURD T Change out GBR Tongs. 18:15 23:30 5.25 6,101 9,551 COMPZ RPCO PULD P RIH f/ 6,101' to 9,551' w/ 4-1/2", 12.6#, L-80, IBT completion string w/ ESP, Installing Cannon clamps on every collar, Test cable eve 40 'ts. 23:30 23:45 0.25 9,551 9,583 COMPZ RPCOb PULD P Make up Vetco Gray Hanger & Landin ~oint 23:45 00:00 0.25 9,583 9,583 COMPZ RPCOh PULD P Install Penetrator & Begin Cable Splice, Total Hard wear used = 272 Cannon clamps, 3 Protectolizer uards, 2 Flat uards, 17 Flat bands. j Page ~~ of 37 a_._ ___. Time Logs _ _ Date From To D r S De th E. De th Ph se Code Subcode T COM 12/30/2007 00:00 02:45 2.75 9,583 9,583 COMPZ RPCO RURD P Splice ESP Cable to Penetrator, Rig down ESP Cable sheaves, Clean rig floor, Ri down GBR ton a ui ment. 02:45 03:00 0.25 9,583 9,583 COMPZ RPCOh OTHR P Check continuity on cable, Blow down choke & KiA lines to stack. 03:00 03:15 0.25 9,583 9,619 COMPZ RPCOti PULD P RIH & Land Hanger w/ Tail @ 9,619', RILDS. 03:15 04:00 0.75 9,619 COMPZ RPCO SFEQ P Test Upper & Lower seals to 250 psi Low & 5000 si Hi h for 10 min- OK. 04:00 04:45 0.75 COMPZ RPCOh NUND P Lay down Landing jt., Rig down Flow line, Hole fill line, Clear rig floor of Centrilift tools & Equipment, Pull mouse hole, Clean dri an. 04:45 06:00 1.25 COMPZ RPCOR NUND P Nipple down BOP & Riser, Continue laying down Centilift tools & Cleaning dri an. 06:00 07:00 1.00 COMPZ RPCO NUND P Set back BOP & Riser. 07:00 10:00 3.00 COMPZ RPCOh NUND P Install & Nipple up Tree, Test adapter to 250 psi low & 5000 psi high f/ 10 min. 10:00 10:30 0.50 COMPZ RPCO OTHR P Check electrical integrity of ESP cable thru Tree- OK. 10:30 11:30 1.00 COMPZ RPCO OTHR P Test Tree to 250 psi low & 5000 psi hi h. 11:30 12:00 0.50 COMPZ RPCO NUND P Pull two-way check. 12:00 12:45 0.75 COMPZ RPCO RURD P Install mouse hole and secure. 12:45 13:15 0.50 COMPZ RPCO RURD P Rig to freeze protect well. 13:15 16:45 3.50 COMPZ RPCOh FRZP P Freeze protect well by pumping 193 bbls diesel down 10-3/4" x 4-1/2" annulus at rate of 1 bpm @ 675 psi, Shut down and pump down tubing and shear valve in GLM w/ 2320 psi, Put tbg and annulus in communication and let U-tube, Lay down 5"drill pipe out of derrick in mouse hole while freeze protecting well, Lost total of 15 bbls to well while freeze rotectin . 16:45 18:45 2.00 COMPZ DRILL PULD P Continue to lay down 5" drill pipe out of derrick. 18:45 19:30 0.75 COMPZ DRILL RURD P Pull mouse hole & reposition in rotarty table, Pick up more thread protectors to ri floor. 19:30 22:30 3.00 COMPZ DRILL PULD P Continue to lay down 5"drill pipe out of derrick. 22:30 23:00 0.50 COMPZ RPCOti NUND P Blow down & rig down freeze protect hoses, (Note; Let freeze protect U-tube 5:45 min's), Continue to remove 5" i e from i e shed. 23:00 23:45 0.75 COMPZ RPCOh OTHR P Pick up lubricator & Install BPV, Clean pollution pan under floor, Finish removing 5"drill pipe f/ pipe shed, Rig down lubricator. Page 36 caf 37 Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T COM 12/30/2007 23:45 00:00 0.25 COMPZ RPCO OTHR P Secure well, Release rig at 24:00 hours 12/30/07 €~ac~e ~~' of 37 Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Bate: 1!7/2008 Time: 14:53:26 Page: Field: Kuparuk River Unit Co-ordiuate(NE)Refercnce: Wefl: 1J-174, Tr ue North - tiite: Kuparuk 1J Pad ~c,-tical(I'1~D)Re ferencc 1J-174 Doyon 1 5 (81+40.5 121.5 ~1ell: 1J-174 Section(VS)Refer encr. Wetl(O.OON,0.00E,180.OOAzi1 Wellpath: 1J-174 Surce} Cakalatian Method: Minimum Curva ture nn: Oracle Field: Kuparuk River Unit __ _ _ _ ! North Slope Alaska I United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre ~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-174 Slot Name: 50-029-23374-00 Well Position: +N/-S -382.67 ft North ing: 5945536.61 ft Latitude: 70 15 42.494 N +E/-W -52.13 ft Easting : 558740.81 ft Longitude: 149 31 30.524 W ' Position Uncertainty: 0.00 ft ~ Wellpath: 1J-174 Drilled From: 1J-174P62 50-029-23374-00 Tie-on Depth: 17660.08 ft Current Datum: 1J-174 Doyon 15 (81+40.5 Height 121 .53 ft 'Above System Datum: Mean Sea Level Magnetic Data: 11/10/2007 Declination: 23.09 deg i Field Strength: 57623 nT Mag Dip Angle: 80.80 deg ' Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.53 0.00 0.00 180.00 '. Survey Program for Definitive Wellpath Date: 12/11/2007 Validated: No Version: 4 i Actual From To Survey Toolcode Tool Name ft ft 50.00 461.00 1J-174PB1 Gyro (50. 00-461.00) CB-MAG-SS Camera based mag single shot 508.50 15090.45 1J-174P81 IIFR+MS+SAG (508.50- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15140.00 17660.08 1J-174P6211FR+MS+SAG (15140.0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 17700.00 19679.15 1J-174 IIFR+MS+SAG (17700.00-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey SID Intl Azim I'VR Sys TVD A?ti PaV1' MapV' MapE -1'001 ft deg deg ft ft ft ft ft ft 40.53 0.00 0.00 40.53 -81.00 0.00 0.00 5945536.61 ~ 558740.81 ~ TIE LINE 50.00 0.35 249.08 50.00 -71.53 -0.01 -0.03 5945536.60 558740.78 CB-MAG-SS 120.00 0.16 226.19 120.00 -1.53 -0.15 -0.30 5945536.45 558740.51 CB-MAG-SS 151.00 0.36 237.75 151.00 29.47 -0.24 -0.41 5945536.37 558740.40 CB-MAG-SS 200.00 0.54 232.25 200.00 78.47 -0.46 -0.72 5945536.14 558740.09 CB-MAG-SS 267.00 2.49 233.60 266.97 145.44 -1.52 -2.14 5945535.08 558738.68 CB-MAG-SS i 363.00 5.64 238.24 362.72 241.19 -5.24 -7.84 5945531.31 558733.02 CB-MAG-SS ~~ 461.00 8.86 241.39 459.92 338.39 -11.39 -18.56 5945525.08 558722.34 CB-MAG-SS 508.50 9.91 236.81 506.79 385.26 -15.38 -25.19 5945521.04 558715.74 MWD+IFR-AK-CAZ-SC 603.64 12.54 237.41 600.10 478.57 -25.42 -40.75 5945510.87 558700.27 MWD+IFR-AK-CAZ-SC 698.58 15.45 240.50 692.21 570.68 -37.21 -60.44 5945498.94 558680.67 MWD+IFR-AK-CAZ-SC 793.54 20.77 241.94 782.43 660.90 -51.36 -86.33 5945484.58 558654.89 MWD+IFR-AK-CAZ-SC 888.73 23.82 244.33 870.50 748.97 -67.63 -118.55 5945468.06 558622.80 MWD+IFR-AK-CAZ-SC 984.34 25.36 248.14 957.44 835.91 -83.62 -154.96 5945451.79 558586.52 MWD+IFR-AK-CAZ-SC 1079.17 29.35 249.39 1041.65 920.12 -99.37 -195.58 5945435.72 558546.03 MWD+IFR-AK-CAZ-SC 1173.46 33.55 247.63 1122.07 1000.54 -117.43 -241.33 5945417.31 558500.43 MWD+IFR-AK-CAZ-SC 1269.34 37.55 246.00 1200.07 1078.54 -139.41 -292.54 5945394.94 558449.39 MWD+IFR-AK-CAZ-SC 1365.12 40.79 245.38 1274.31 1152.78 -164.32 -347.66 5945369.60 558394.48 MWD+IFR-AK-CAZ-SC 1460.41 44.98 245.72 1344.12 1222.59 -191.15 -406.68 5945342.31 558335.67 MWD+IFR-AK-CAZ-SC ~ 1554.68 46.42 246.05 1409.96 1288.43 -218.71 -468.26 5945314.28 558274.31 MWD+IFR-AK-CAZ-SC , 1650.38 49.77 248.34 1473.87 1352.34 -246.27 -533.92 5945286.20 558208.88 MWD+IFR-AK-CAZ-SC 1745.78 50.88 252.31 1534.79 1413.26 -270.97 -603.04 5945260.97 558139.96 MWD+IFR-AK-CAZ-SC ' . 1840.83 53.83 249.73 1592.84 1471.31 -295.47 -674.18 5945235.92 558069.02 MWD+IFR-AK-CAZ-SC 1935.78 57.54 247.52 1646.37 1524.84 -324.08 -747.17 5945206.75 557996.26 MWD+IFR-AK-CAZ-SC i 2030.49 61.49 246.70 1694.41 1572.88 -355.83 -822.34 5945174.41 557921.35 MWD+IFR-AK-CAZ-SC ~ 2126.64 63.76 245.73 1738.61 1617.08 -390.27 -900.47 5945139.37 557843.50 MWD+IFR-AK-CAZ-SC 2221.15 67.60 243.97 1777.53 1656.00 -426.88 -978.40 5945102.15 557765.87 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report --- - _-~ (_~umhany: Cr~nocoPhi3fips Alaska Inc- [>•.~tc 1/7/2003 Time: 14:5326 Page 2 Field: Kuparuk River Unit ('u-ordinate(~~I:l Reference: Well: 1J-174, True NoRh Site: Kuparuk 1J Pad ~"crtical (Tt'D) Reference: 1J-'174 Doyon 15 (81+40.5 121.5 Well: 1J-174 tiectiun~~~S)KeCerence: Well (QOON.D.ODE,18~J.OOAzi) tiVellpath: 1J-174 tiun~e~ (,alculatiun Slethod: Minimum Cwvature 1)h: Oracle C~~n c~ SID lncl Azim Till ,tirsl'~D ~'/S F.%1~~ ~tap~i StapF. Tnul ft deg deg ft ft ft ft ft ft _.__ 2315.63 68.70 240.48 1812.70 1691.17 -467.74 -1055.96 5945060.69 557688.63 MWD+IFR-AK-CAZ-SC 2411.62 72.28 236.38 1844.77 1723.24 -515.12 -1133.00 5945012.71 557611.97 MWD+IFR-AK-CAZ-SC 2506.31 73.30 235.14 1872.79 1751.26 -566.02 -1207.77 5944961.24 557537.61 MWD+IFR-AK-CAZ-SC 2601.59 76.59 235.97 1897.53 1776.00 -618.05 -1283.64 5944908.63 557462.15 MWD+IFR-AK-CAZ-SC 2697.20 73.97 237.05 1921.82 1800.29 -669.07 -1360.75 5944857.01 557385.45 MWD+IFR-AK-CAZ-SC 2790.67 74.01 237.45 1947.60 1826.07 -717.67 -1436.31 5944807.82 557310.28 MWD+IFR-AK-CAZ-SC 2887.71 75.26 235.59 1973.32 1851.79 -769.29 -1514.35 5944755.60 557232.65 MWD+IFR-AK-CAZ-SC 2982.52 74.41 236.37 1998.12 1876.59 -820.49 -1590.19 5944703.82 557157.22 MWD+IFR-AK-CAZ-SC 3078.08 73.83 236.55 2024.27 1902.74 -871.27 -1666.80 5944652.45 557081.01 MWD+IFR-AK-CAZ-SC 3173.10 73.38 238.09 2051.09 1929.56 -920.49 -1743.53 5944602.63 557004.68 MWD+IFR-AK-CAZ-SC 3268.00 75.00 238.53 2076.94 1955.41 -968.46 -1821.22 5944554.07 556927.37 MWD+IFR-AK-CAZ-SC 3363.34 75.13 238.67 2101.52 1979.99 -1016.45 -1899.85 5944505.47 556849.13 MWD+IFR-AK-CAZ-SC 3457.80 75.82 237.20 2125.21 2003.68 -1065.00 -1977.34 5944456.33 556772.03 MWD+IFR-AK-CAZ-SC 3552.72 74.53 235.85 2149.49 2027.96 -1115.60 -2053.87 5944405.13 556695.90 MWD+IFR-AK-CAZ-SC 3647.22 74.65 234.87 2174.61 2053.08 -1167.39 -2128.83 5944352.77 556621.36 MWD+IFR-AK-CAZ-SC 3742.44 74.65 235.21 2199.81 2078.28 -1220.00 -2204.08 5944299.57 556546.53 MWD+IFR-AK-CAZ-SC ! 3838.09 73.86 236.32 2225.77 2104.24 -1271.79 -2280.19 5944247.19 556470.83 MWD+IFR-AK-CAZ-SC ~ 3933.06 75.08 236.20 2251.20 2129.67 -1322.62 -2356.28 5944195.78 556395.15 MWD+IFR-AK-CAZ-SC 3991.88 76.27 235.69 2265.75 2144.22 -1354.53 -2403.49 5944163.50 556348.19 MWD+IFR-AK-CAZ-SC ~ 4045.36 76.31 238.36 2278.43 2156.90 -1382.81 -2447.07 5944134.89 556304.83 MWD+IFR-AK-CAZ-SC 4139.95 77.68 236.46 2299.71 2178.18 -1432.45 -2524.72 5944084.65 556227.58 MWD+IFR-AK-CAZ-SC 4235.18 79.51 235.62 2318.54 2197.01 -1484.59 -2602.14 5944031.91 556150.58 MWD+IFR-AK-CAZ-SC 4330.39 82.14 236.29 2333.72 2212.19 -1537.21 -2680.02 5943978.69 556073.12 MWD+IFR-AK-CAZ-SC 4426.17 83.39 236.19 2345.79 2224.26 -1590.01 -2759.01 5943925.28 555994.55 MWD+IFR-AK-CAZ-SC 4521.76 83.60 237.36 2356.62 2235.09 -1642.05 -2838.46 5943872.63 555915.52 MWD+IFR-AK-CAZ-SC 4617.38 83.41 235.87 2367.43 2245.90 -1694.32 -2917.78 5943819.74 555836.61 MWD+IFR-AK-CAZ-SC 4713.17 84.16 234.27 2377.80 2256.27 -1748.85 -2995.85 5943764.62 555758.98 MWD+IFR-AK-CAZ-SC 4807.51 83.46 234.53 2387.98 2266.45 -1803.44 -3072.11 5943709.43 555683.15 MWD+IFR-AK-CAZ-SC 4900.98 83.66 234.56 2398.46 2276.93 -1857.32 -3147.77 5943654.97 555607.93 MWD+IFR-AK-CAZ-SC 4997.48 82.79 231.60 2409.85 2288.32 -1914.87 -3224.37 5943596.83 555531.78 MWD+IFR-AK-CAZ-SC 5093.72 83.96 231.68 2420.95 2299.42 -1974.20 -3299.33 5943536.92 555457.30 MWD+IFR-AK-CAZ-SC 5188.36 84.02 232.50 2430.86 2309.33 -2032.03 -3373.59 5943478.52 555383.50 MWD+IFR-AK-CAZ-SC 5283.81 83.60 234.19 2441.15 2319.62 -2088.68 -3449.71 5943421.29 555307.83 MWD+IFR-AK-CAZ-SC 5378.85 83.15 235.17 2452.12 2330.59 -2143.26 -3526.74 5943366.11 555231.23 MWD+IFR-AK-CAZ-SC 5474.38 82.47 235.14 2464.07 2342.54 -2197.41 -3604.52 5943311.36 555153.88 MWD+IFR-AK-CAZ-SC 5569.19 83.94 237.22 2475.29 2353.76 -2249.80 -3682.73 5943258.36 555076.09 MWD+IFR-AK-CAZ-SC 5664.47 83.41 237.61 2485.79 2364.26 -2300.80 -3762.53 5943206.75 554996.71 MWD+IFR-AK-CA2-SC 5759.50 84.28 236.28 2495.98 2374.45 -2352.34 -3841.71 5943154.60 554917.93 MWD+IFR-AK-CAZ-SC 5854.45 83.85 235.00 2505.80 2384.27 -2405.64 -3919.67 5943100.70 554840.40 MWD+IFR-AK-CAZ-SC 5949.64 84.09 234.00 2515.80 2394.27 -2460.61 -3996.74 5943045.14 554763.77 MWD+IFR-AK-CAZ-SC 6045.24 83.97 234.05 2525.74 2404.21 -2516.46 -4073.69 5942988.69 554687.27 MWD+IFR-AK-CAZ-SC 6139.32 83.60 234.59 2535.92 2414.39 -2571.01 -4149.66 5942933.55 554611.73 MWD+IFR-AK-CAZ-SC 6235.65 84.21 235.57 2546.15 2424.62 -2625.84 -4228.20 5942878.12 554533.63 MWD+IFR-AK-CAZ-SC 6330.79 82.23 235.57 2557.38 2435.85 -2679.26 -4306.12 5942824.10 554456.14 MWD+IFR-AK-CAZ-SC 6425.78 83.10 236.55 2569.51 2447.98 -2731.86 -4384.28 5942770.90 554378.40 MWD+IFR-AK-CAZ-SC 6521.76 83.65 236.71 2580.58 2459.05 -2784.30 -4463.90 5942717.85 554299.20 MWD+IFR-AK-CAZ-SC 6616.55 83.48 234.74 2591.21 2469.68 -2837.34 -4541.73 5942664.20 554221.79 MWD+IFR-AK-CAZ-SC 6713.09 83.65 233.79 2602.03 2480.50 -2893.37 -4619.60 5942607.58 554144.37 MWD+IFR-AK-CAZ-SC 6807.21 83.72 233.77 2612.38 2490.85 -2948.64 -4695.07 5942551.72 554069.34 MWD+IFR-AK-CAZ-SC 6902.46 82.53 234.04 2623.78 2502.25 -3004.35 -4771.48 5942495.42 553993.37 MWD+IFR-AK-CAZ-SC 6995.90 84.19 235.29 2634.59 2513.06 -3058.03 -4847.19 5942441.16 553918.08 MWD+IFR-AK-CAZ-SC 7091.95 84.72 235.41 2643.87 2522.34 -3112.38 -4925.84 5942386.20 553839.87 MWD+IFR-AK-CAZ-SC 7188.14 84.16 235.62 2653.19 2531.66 -3166.59 -5004.75 5942331.39 553761.39 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 1/7/2008 Timc: 14:53:26 Pa~c: 3 ' Eield: Kuparuk River Unit Co-ordinatclNE)Reference: Well: 1J-174, True Narth Site: Kuparuk 1 J Pad Vertical (~I1~D) Reference: 1 J-174 Doyon 15 (81+40.5 121.5 ~1cllt 1J-174 Section (~~S) Relrreucc: Well (O.OON,O.OOE,180.OOAzij ~ycllpath: 1J-174 Surce~~ Calculation A1Mhod: Minimum Curvature Db: Oracle Suncr ~1D Incl ~zim f~D Sys T1~D V/S E/~F ~tap~~ S1apE Tool ft deg deg ft ft ft ft ft ft 7282.65 84.03 234.69 2662.91 2541.38 -3220.30 -5081.90 5942277.08 553684.67 MWD+IFR-AK-CAZ-SC 7377.38 83.72 235.11 2673.02 2551.49 -3274.46 -5158.96 5942222.33 553608.04 MWD+IFR-AK-CAZ-SC 7474.22 83.29 234.91 2683.97 2562.44 -3329.63 -5237.79 5942166.54 553529.66 MWD+IFR-AK-CAZ-SC 7568.31 83.66 235.30 2694.67 2573.14 -3383.11 -5314.46 5942112.47 553453.41 MWD+IFR-AK-CAZ-SC 7663.31 83.03 235.59 2705.68 2584.15 -3436.63 -5392.17 5942058.35 553376.12 MWD+IFR-AK-CAZ-SC 7758.72 82.98 235.02 2717.29 2595.76 -3490.53 -5470.04 5942003.85 553298.69 MWD+IFR-AK-CAZ-SC 7853.64 84.08 235.04 2727.99 2606.46 -3544.59 -5547.32 5941949.20 553221.84 MWD+IFR-AK-CAZ-SC 7949.85 82.91 236.40 2738.89 2617.36 -3598.43 -5626.30 5941894.75 553143.29 MWD+IFR-AK-CAZ-SC 8044.56 84.31 236.98 2749.43 2627.90 -3650.12 -5704.96 5941842.46 553065.04 MWD+IFR-AK-CAZ-SC 8138.61 83.72 236.02 2759.24 2637.71 -3701.74 -5782.96 5941790.23 552987.46 MWD+IFR-AK-CAZ-SC 8233.85 83.29 235.06 2770.01 2648.48 -3755.28 -5860.98 5941736.08 552909.86 MWD+IFR-AK-CAZ-SC 8329.71 83.16 235.44 2781.32 2659.79 -3809.54 -5939.19 5941681.22 552832.08 MWD+IFR-AK-CAZ-SC 8424.82 83.78 235.85 2792.14 2670.61 -3862.87 -6017.20 5941627.30 552754.50 MWD+IFR-AK-CAZ-SC j 8520.36 83.71 237.93 2802.55 2681.02 -3914.74 -6096.75 5941574.81 552675.37 MWD+IFR-AK-CAZ-SC 8614.62 83.72 234.38 2812.87 2691.34 -3966.92 -6174.55 5941522.03 552597.98 MWD+IFR-AK-CAZ-SC I 8710.45 83.35 233.25 2823.66 2702.13 -4023.13 -6251.41 5941465.23 552521.58 MWD+IFR-AK-CAZ-SC 8805.50 84.03 234.27 2834.11 2712.58 -4078.98 -6327.60 5941408.79 552445.83 MWD+IFR-AK-CAZ-SC i 8900.16 83.84 236.35 2844.11 2722.58 -4132.55 -6405.00 5941354.62 552368.86 MWD+IFR-AK-CAZ-SC 8995.82 83.91 235.16 2854.32 2732.79 -4186.07 -6483.62 5941300.49 552290.66 MWD+IFR-AK-CAZ-SC 9091.24 83.78 235.28 2864.55 2743.02 -4240.19 -6561.54 5941245.78 552213.17 MWD+IFR-AK-CAZ-SC 9186.63 83.90 235.24 2874.78 2753.25 -4294.23 -6639.47 5941191.13 552135.67 MWD+IFR-AK-CAZ-SC 9282.10 83.71 235.75 2885.08 2763.55 -4348.00 -6717.69 5941136.76 552057.89 MWD+IFR-AK-CAZ-SC ~ 9378.39 83.47 235.74 2895.83 2774.30 -4401.86 -6796.78 5941082.29 551979.23 MWD+IFR-AK-CAZ-SC 9472.74 84.03 236.79 2906.11 2784.58 -4453.95 -6874.77 5941029.60 551901.65 MWD+IFR-AK-CAZ-SC ~' 9567.86 84.34 236.76 2915.74 2794.21 -4505.80 -6953.93 5940977.14 551822.90 MWD+IFR-AK-CAZ-SC 9662.57 83.90 235.98 2925.45 2803.92 -4557.97 -7032.38 5940924.36 551744.87 MWD+IFR-AK-CAZ-SC 9757.75 84.03 235.58 2935.45 2813.92 -4611.20 -7110.64 5940870.53 551667.03 MWD+IFR-AK-CAZ-SC 9853.10 84.22 235.58 2945.21 2823.68 -4664.82 -7188.89 5940816.31 551589.22 MWD+IFR-AK-CAZ-SC 9947.66 83.53 233.61 2955.30 2833.77 -4719.28 -7265.52 5940761.25 551513.02 MWD+IFR-AK-CAZ-SC 10042.24 84.09 230.48 2965.50 2843.97 -4777.11 -7339.65 5940702.86 551439.35 MWD+IFR-AK-CAZ-SC j 10137.74 83.10 227.40 2976.16 2854.63 -4839.43 -7411.20 5940639.98 551368.30 MWD+IFR-AK-CAZ-SC 10233.35 83.84 225.88 2987.03 2865.50 -4904.65 -7480.26 5940574.23 551299.76 MWD+IFR-AK-CAZ-SC 10328.54 82.41 221.91 2998.43 2876.90 -4972.73 -7545.77 5940505.65 551234.78 MWD+IFR-AK-CAZ-SC 10423.29 82.98 219.48 3010.48 2888.95 -5043.98 -7607.04 5940433.93 551174.07 MWD+IFR-AK-CAZ-SC i j 10519.50 83.65 216.63 3021.68 2900.15 -5119.22 -7665.94 5940358.24 551115.77 MWD+IFR-AK-CAZ-SC I 10614.03 83.10 212.55 3032.59 2911.06 -5196.50 -7719.23 5940280.55 551063.09 MWD+IFR-AK-CAZ-SC 10709.41 82.91 211.17 3044.21 2922.68 -5276.91 -7769.20 5940199.77 551013.75 MWD+IFR-AK-CAZ-SC 10804.51 82.73 211.25 3056.10 2934.57 -5357.61 -7818.10 5940118.70 550965.49 MWD+IFR-AK-CAZ-SC 10899.91 82.48 207.80 3068.38 2946.85 -5439.91 -7864.71 5940036.04 550919.53 MWD+IFR-AK-CAZ-SC 10994.66 82.41 205.41 3080.84 2959.31 -5523.89 -7906.77 5939951.75 550878.12 MWD+IFR-AK-CAZ-SC 11090.17 82.17 201.86 3093.66 2972.13 -5610.58 -7944.71 5939864.77 550840.87 MWD+IFR-AK-CAZ-SC 11185.27 82.66 198.79 3106.21 2984.68 -5698.97 -7977.45 5939776.14 550808.82 MWD+IFR-AK-CAZ-SC 11280.36 82.92 194.65 3118.15 2996.62 -5789.30 -8004.58 5939685.61 550782.40 MWD+IFR-AK-CAZ-SC 11375.17 83.17 191.46 3129.64 3008.11 -5880.97 -8025.84 5939593.78 550761.86 MWD+IFR-AK-CAZ-SC 11469.79 82.90 188.64 3141.11 3019.58 -5973.44 -8042.23 5939501.20 550746.19 MWD+IFR-AK-CAZ-SC 11565.15 82.97 183.76 3152.85 3031.32 -6067.49 -8052.45 5939407.08 550736.71 MWD+IFR-AK-CAZ-SC 11660.41 83.10 179.83 3164.40 3042.87 -6161.98 -8055.41 5939312.57 550734.49 MWD+IFR-AK-CAZ-SC 11755.39 82.53 178.20 3176.28 3054.75 -6256.20 -8053.79 5939218.38 550736.84 MWD+IFR-AK-CAZ-SC 11850.25 83.95 175.56 3187.45 3065.92 -6350.25 -8048.66 5939124.38 550742.70 MWD+IFR-AK-CAZ-SC 11945.32 85.98 173.18 3195.80 3074.27 -6444.48 -8039.36 5939030.23 550752.73 MWD+IFR-AK-CAZ-SC i 12040.75 85.52 173.56 3202.87 3081.34 -6539.01 -8028.38 5938935.80 550764.45 MWD+IFR-AK-CAZ-SC 12060.68 85.64 173.39 3204.40 3082.87 -6558.76 -8026.12 5938916.08 550766.87 MWD+IFR-AK-CAZ-SC i ! +~ Halliburton Company Survey Report ( ompany: ConoCOPhillips Alaska Inc. Irutr. 1/7/2008 1'imc: 14:5326 I'a~~c: a Field: Kuparuk River Unit Co-ordiuate(NE)Reference: Well: 1J-174,True North Site: Kuparuk 1J Pad 1'erticnl (f~`D)Reference: 1J-174 Doyon 15 (81+40.5121.5 WeIE: 1J-174 Section Ids) Reference: Well (O.OON.O.OOE,130.OOr1~i) Vb'ellp»th: 1J-174 Sun~eg Calcutation!~lctfiod: Minimum Curvature Oh- Oracle Sand ~~1D Incl Azim I'C'I) Sys T~'D ~YIS H:/N' ~lapA" ti1upE Tool ft deg deg ft ft ft ft ft ft 12137.87 86.07 174.14 3209.98 3088.45 -6635.29 -8017.76 5938839.62 550775.82 MWD+IFR-AK-CAZ-SC 12232.47 87.29 174.96 3215.46 3093.93 -6729.30 -8008.79 5938745.69 550785.52 MWD+IFR-AK-CAZ-SC 12328.43 89.78 174.34 3217.91 3096.38 -6824.80 -7999.84 5938650.27 550795.21 MWD+IFR-AK-CAZ-SC i ~ 12423.48 89.18 171.34 3218.78 3097.25 -6919.10 -7988.00 5938556.08 550807.79 MWD+IFR-AK-CAZ-SC I 12518.35 91.03 172.88 3218.60 3097.07 -7013.06 -7974.98 5938462.23 550821.54 MWD+IFR-AK-CAZ-SC I 12614.04 90.35 172.03 3217.45 3095.92 -7107.91 -7962.41 5938367.49 550834.85 MWD+IFR-AK-CAZ-SC ~ 12707.47 89.55 171.74 3217.53 3096.00 -7200.41 -7949.23 5938275.11 550848.75 MWD+IFR-AK-CAZ-SC 12803.72 90.75 173.92 3217.28 3095.75 -7295.90 -7937.21 5938179.72 550861.51 MWD+IFR-AK-CAZ-SC 12898.63 90.23 177.14 3216.47 3094.94 -7390.50 -7929.82 5938085.19 550869.64 MWD+IFR-AK-CAZ-SC 12994.21 89.98 176.80 3216.29 3094.76 -7485.95 -7924.77 5937989.79 550875.44 MWD+IFR-AK-CAZ-SC 13090.05 89.86 177.11 3216.43 3094.90 -7581.65 -7919.67 5937894.14 550881.28 MWD+IFR-AK-CAZ-SC 13184.33 92.43 180.90 3214.54 3093.01 -7675.87 -7918.04 5937799.94 550883.65 MWD+IFR-AK-CAZ-SC 13279.81 91.59 180.88 3211.19 3089.66 -7771.28 -7919.52 5937704.54 550882.91 MWD+IFR-AK-CAZ-SC 13375.36 90.66 180.43 3209.32 3087.79 -7866.81 -7920.61 5937609.02 550882.56 MWD+IFR-AK-CAZ-SC 13471.57 89.86 180.54 3208.88 3087.35 -7963.01 -7921.42 5937512.82 550882.50 MWD+IFR-AK-CAZ-SC 13566.52 90.40 180.75 3208.67 3087.14 -8057.96 -7922.49 5937417.88 550882.17 MWD+IFR-AK-CAZ-SC 13661.43 89.98 180.92 3208.35 3086.82 -8152.85 -7923.88 5937322.98 550881.53 MWD+IFR-AK-CAZ-SC 13756.87 90.70 180.19 3207.79 3086.26 -8248.29 -7924.80 5937227.55 550881.35 MWD+IFR-AK-CAZ-SC 13851.59 91.08 178.87 3206.31 3084.78 -8342.99 -7924.02 5937132.87 550882.86 MWD+IFR-AK-CAZ-SC 13946.88 91.09 178.53 3204.51 3082.98 -8438.24 -7921.86 5937037.65 550885.77 MWD+IFR-AK-CAZ-SC 14043.25 90.54 180.51 3203.14 3081.61 -8534.59 -7921.06 5936941.31 550887.33 MWD+IFR-AK-CAZ-SC 14137.27 90.23 179.75 3202.51 3080.98 -8628.61 -7921.27 5936847.31 550887.85 MWD+IFR-AK-CAZ-SC 14232.69 89.92 179.56 3202.38 3080.85 -8724.03 -7920.69 5936751.91 550889.17 MWD+IFR-AK-CAZ-SC 14327.73 90.58 179.65 3201.97 3080.44 -8819.06 -7920.04 5936656.89 550890.56 MWD+IFR-AK-CAZ-SC 14423.14 91.08 180.61 3200.59 3079.06 -8914.46 -7920.26 5936561.50 550891.09 MWD+IFR-AK-CAZ-SC 14519.76 90.97 180.11 3198.86 3077.33 -9011.06 -7920.86 5936464.90 550891.24 MWD+IFR-AK-CAZ-SC 14614.04 90.10 179.00 3197.98 3076.45 -9105.33 -7920.13 5936370.65 550892.70 MWD+IFR-AK-CAZ-SC ~ 14708.07 90.11 178.74 3197.80 3076.27 -9199.34 -7918.28 5936276.67 550895.29 MWD+IFR-AK-CAZ-SC I j 14804.49 90.17 180.46 3197.57 3076.04 -9295.76 -7917.60 5936180.27 550896.72 MWD+IFR-AK-CAZ-SC I 14899.49 90.77 180.32 3196.79 3075.26 -9390.75 -7918.25 5936085.28 550896.81 MWD+IFR-AK-CAZ-SC 14996.23 90.60 178.42 3195.63 3074.10 -9487.47 -7917.19 5935988.58 550898.63 MWD+IFR-AK-CAZ-SC 15090.45 90.54 176.58 3194.70 3073.17 -9581.60 -7913.08 5935894.50 550903.47 MWD+IFR-AK-CAZ-SC I 15140.00 91.51 176.70 3193.81 3072.28 -9631.05 -7910.17 5935845.07 550906.76 MWD+IFR-AK-CAZ-SC I 15183.65 91.67 175.98 3192.60 3071.07 -9674.60 -7907.39 5935801.56 550909.89 MWD+IFR-AK-CAZ-SC I 15279.93 92.19 174.36 3189.35 3067.82 -9770.48 -7899.29 5935705.75 550918.73 MWD+IFR-AK-CAZ-SC 15375.38 92.20 176.13 3185.70 3064.17 -9865.52 -7891.38 5935610.78 550927.38 MWD+IFR-AK-CAZ-SC 15470.06 90.66 178.63 3183.34 3061.81 -9960.07 -7887.05 5935516.28 550932.44 MWD+IFR-AK-CAZ-SC 15565.22 90.54 180.08 3182.34 3060.81 -10055.21 -7885.98 5935421.16 550934.26 MWD+IFR-AK-CAZ-SC 15660.62 91.08 180.83 3180.99 3059.46 -10150.60 -7886.74 5935325.78 550934.24 MWD+IFR-AK-CAZ-SC 15757.03 91.09 182.37 3179.16 3057.63 -10246.95 -7889.43 5935229.42 550932.30 MWD+IFR-AK-CAZ-SC 15850.47 90.10 180.30 3178.19 3056.66 -10340.35 -7891.61 5935136.01 550930.86 MWD+IFR-AK-CAZ-SC 15946.34 91.18 180.97 3177.12 3055.59 -10436.21 -7892.67 5935040.16 550930.54 MWD+IFR-AK-CAZ-SC 16041.48 90.54 180.71 3175.70 3054.17 -10531.33 -7894.07 5934945.04 550929.89 MWD+IFR-AK-CAZ-SC 16135.67 90.54 180.49 3174.81 3053.28 -10625.51 -7895.05 5934850.86 550929.64 MWD+IFR-AK-CAZ-SC 16231.73 90.90 179.61 3173.60 3052.07 -10721.56 -7895.14 5934754.82 550930.30 MWD+IFR-AK-CAZ-SC 16326.87 90.41 180.05 3172.51 3050.98 -10816.69 -7894.85 5934659.70 550931.33 MWD+IFR-AK-CAZ-SC 16422.06 90.71 180.31 3171.58 3050.05 -10911.88 -7895.15 5934564.53 550931.77 MWD+IFR-AK-CAZ-SC 16517.14 90.17 180.34 3170.85 3049.32 -11006.95 -7895.69 5934469.46 550931.97 MWD+IFR-AK-CAZ-SC 16612.35 90.59 181.31 3170.22 3048.69 -11102.15 -7897.06 5934374.27 550931.35 MWD+IFR-AK-CAZ-SC 16707.93 90.96 180.83 3168.93 3047.40 -11197.70 -7898.85 5934278.71 550930.31 MWD+IFR-AK-CAZ-SC 16802.19 90.10 180.44 3168.06 3046.53 -11291.95 -7899.89 5934184.46 550930.00 MWD+IFR-AK-CAZ-SC i 16897.95 90.41 180.51 3167.63 3046.10 -11387.71 -7900.69 5934088.71 550929.95 MWD+IFR-AK-CAZ-SC 16993.04 90.60 181.28 3166.79 3045.26 -11482.78 -7902.17 5933993.64 550929.21 MWD+IFR-AK-CAZ-SC s Halliburton Company Survey Report Cumpam: ConuCOFhillips Alaska Inc. icld: Kuparuk River Unit silt Kuparuk 1J Pad ~~ ell: 1 J-174 ~~ el rpath: 1 J-174 tiu rz c~ - __ ~lll lncl Azim Tel) Sys TVD '~'s ft deg deg ft ft ft Date: 1/7/2008 Time: 14.53:26 I'a~c: ('u-ordinate(~EJ Kclcrence: Well: 1J-174, True North ~~crtical ("f~"D) Reference: 1J-174 Doyon 15 (81+40.5 121.5 ticction (~'S) Rcfcrcuce: Well (O.OON.O.OOE,180.OOAzi) Sun~e~~ ('akulation Method: Minimum Curvature Db: Oracle FJW' ~fapN ~~ _ ~ ~~1apIC Tool ft ft ft 17088.83 89 .24 179.17 3166. 93 3045. 40 -11578. 56 -7902. 55 5933897.87 550929 .58 MWD+IFR-AK-CAZ-SC 17183.91 90 .02 180. 54 3167. 54 3046. 01 -11673. 64 -7902. 31 5933802.81 550930 .56 MWD+IFR-AK-CAZ-SC 17279.11 91 .00 180. 15 3166. 69 3045. 16 -11768. 83 -7902. 88 5933707.62 550930 .73 MWD+IFR-AK-CAZ-SC 17374.42 89 .79 178. 98 3166. 04 3044. 51 -11864. 13 -7902. 16 5933612.34 550932 .20 MWD+IFR-AK-CAZ-SC 17469.58 88 .93 177. 94 3167. 10 3045. 57 -11959. 25 -7899. 60 5933517.25 550935 .49 MWD+IFR-AK-CAZ-SC 17564.93 89 .17 176. 75 3168. 68 3047. 15 -12054. 48 -7895. 18 5933422.07 550940 .65 MWD+IFR-AK-CAZ-SC 17660.08 89 .24 178. 01 3170. 00 3048. 47 -12149 .52 -7890. 83 5933327.07 550945 .74 MWD+IFR-AK-CAZ-SC 17700.00 89 .11 178. 38 3170. 57 3049. 04 -12189. 42 -7889. 58 5933287.19 550947 .31 MWD+IFR-AK-CAZ-SC 17754.07 90 .53 178. 17 3170. 74 3049. 21 -12243 .46 -7887. 95 5933233.17 550949 .36 MWD+IFR-AK-CAZ-SC 17849.55 91 .08 178. 28 3169. 40 3047. 87 -12338. 89 -7884. 99 5933137.78 550953 .06 MWD+IFR-AK-CAZ-SC 17944.94 90 .52 178. 25 3168. 07 3046. 54 -12434 .22 -7882. 10 5933042.48 550956 .69 MWD+IFR-AK-CAZ-SC 18040.97 89 .10 179. 45 3168. 39 3046. 86 -12530 .23 -7880. 18 5932946.50 550959 .37 MWD+IFR-AK-CAZ-SC 18136.19 89 .78 178. 58 3169. 32 3047. 79 -12625 .43 -7878. 54 5932851.32 550961 .75 MWD+IFR-AK-CAZ-SC 18231.20 90 .22 179. 83 3169. 32 3047. 79 -12720. 43 -7877. 22 5932756.35 550963 .81 MWD+IFR-AK-CAZ-SC 18324.74 89 .72 179. 43 3169. 37 3047. 84 -12813. 97 -7876. 62 5932662.83 550965 .14 MWD+IFR-AK-CAZ-SC 18421.67 89 .17 179. 77 3170. 31 3048. 78 -12910 .89 -7875. 94 5932565.92 550966 .57 MWD+IFR-AK-CAZ-SC 18517.54 88 .86 179. 81 3171 .96 3050. 43 -13006 .74 -7875. 59 5932470.08 550967 .67 MWD+IFR-AK-CAZ-SC 18612.07 90 .46 180. 07 3172 .52 3050. 99 -13101 .27 -7875. 49 5932375.57 550968 .51 MWD+IFR-AK-CAZ-SC 18706.32 92 .13 180. 69 3170. 39 3048. 86 -13195 .49 -7876. 12 5932281.35 550968 .62 MWD+IFR-AK-CAZ-SC 18802.16 92 .31 180. 84 3166. 67 3045. 14 -13291 .25 -7877. 39 5932185.60 550968 .09 MWD+IFR-AK-CAZ-SC 18897.59 90 .21 179. 27 3164 .58 3043. 05 -13386 .65 -7877. 49 5932090.21 550968 .74 MWD+IFR-AK-CAZ-SC 18992.03 90 .59 178. 62 3163 .92 3042. 39 -13481 .07 -7875. 75 5931995.81 550971 .21 MWD+IFR-AK-CAZ-SC 19088.27 91 .14 179. 64 3162 .46 3040. 93 -13577 .29 -7874. 29 5931899.62 550973 .43 MWD+IFR-AK-CAZ-SC 19183.65 91 .27 181. 77 3160 .46 3038. 93 -13672 .63 -7875. 46 5931804.28 550973 .00 MWD+IFR-AK-CAZ-SC 19278.19 92 .99 183. 96 3156 .94 3035. 41 -13766 .98 -7880. 18 5931709.91 550969 .01 MWD+IFR-AK-CAZ-SC 19372.81 90 .46 182. 51 3154. .10 3032. 57 -13861 .39 -7885. 51 5931615.46 550964 .41 MWD+IFR-AK-CAZ-SC 19466.46 89 .97 180. 27 3153 .74 3032. 21 -13955 .01 -7887. 79 5931521.84 550962 .87 MWD+IFR-AK-CAZ-SC 19563.46 89 .04 179. 67 3154 .58 3033. 05 -14052 .01 -7887. 74 5931424.86 550963 .68 MWD+IFR-AK-CAZ-SC 19658.33 88 .86 179. 34 3156 .32 3034. 79 -14146 .86 -7886. 92 5931330.02 550965 .24 MWD+IFR-AK-CAZ-SC 19679.15 89 .59 179. 37 3156 .60 3035. 07 -14167 .67 -7886. 68 5931309.21 550965 .64 MWD+IFR-AK-CAZ-SC 19708.00 89 .59 179. 37 3156 .81. 3035. 28 -14196 .52 -7886. 36 5931280.37. 550966 .18 ~ PROJECTED to TD • Halliburton Company Survey Report Cumpam~: GonocoPhillips Alaska Inc. Uatc 1/7;2008 Timr. 13:13:22 Pair. I Field: Kuparuk River Unit C~u -o rdiuate(NE)Refcrcncc Well. 1J-174, T nie North Site Kuparuk 1J Pad ~c rtical(TVD)Rc lcrencc: 1J-174 Doyon 1 5 (81+40.5121.5 ~~ell: 1J-174 Sec tion(VS)Refer rnce: Well (0-OON.O-O OE.IEO.OO,Azi) ~~~cllpalh: 1,1-1741'l31 Su rvey CalculationMerhod: Minimum Curva ture Db: Uncle ' Field: Kuparuk River Unit j North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ' Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-174 Slot Name: 50-029-23374-00 Well Position: +N/-S -382.67 ft Northing: 5945536.61 ft Latitude: 70 15 42.494 N +E/-W -52.13 ft Easting : 558740.81 ft Longitude: 149 31 30.524 W Position Uncertainty: 0.00 ft _ J _ Wellpath: 1J-174P61 Drilled From: Well Ref. Point 50-029-23374-70 Tie-on Depth: 40.00 ft Current Datum: 1 J-174 Doyon 15 (81+40.5 Height 121.53 ft Above System Datum: Mean Sea Level Magnetic Data: 11/10/2007 Declination: 23.09 deg I Field Strength: 57623 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 12/4/2007 Validated: Yes V ersion: 4 Actual From To Survey ft ft Toolcode Tool Name 50.00 461.00 1J-174P61 Gyro (50. 00-461.00) C B-MAG-SS Camera based mag single shot 508.50 15276.48 1J-174P61 /IFR+MS+SAG (508.50- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC j Survey MD Ind lzim TVI) S~~ l~~'D [V/S E/W ~fapN ~lapF. Tool ft deg deg ft ft ft ft ft ft 40.53 0.00 0.00 40.53 -81.00 0.00 0.00 5945536.61 558740.81 TIE LINE 50.00 0.35 249.08 50.00 -71.53 -0.01 -0.03 5945536.60 558740.78 CB-MAG-SS 120.00 0.16 226.19 120.00 -1.53 -0.15 -0.30 5945536.45 558740.51 CB-MAG-SS 151.00 0.36 237.75 151.00 29.47 -0.24 -0.41 5945536.37 558740.40 CB-MAG-SS 200.00 0.54 232.25 200.00 78.47 -0.46 -0.72 5945536.14 558740.09 CB-MAG-SS I 267.00 2.49 233.60 266.97 145.44 -1.52 -2.14 5945535.08 558738.68 CB-MAG-SS 363.00 5.64 238.24 362.72 241.19 -5.24 -7.84 5945531.31 558733.02 CB-MAG-SS 461.00 8.86 241.39 459.92 338.39 -11.39 -18.56 5945525.08 558722.34 CB-MAG-SS 508.50 9.91 236.81 506.79 385.26 -15.38 -25.19 5945521.04 558715.74 MWD+IFR-AK-CAZ-SC 603.64 12.54 237.41 600.10 478.57 -25.42 -40.75 5945510.87 558700.27 MWD+IFR-AK-CAZ-SC 698.58 15.45 240.50 692.21 570.68 -37.21 -60.44 5945498.94 558680.67 MWD+IFR-AK-CAZ-SC ~ 793.54 20.77 241.94 782.43 660.90 -51.36 -86.33 5945484.58 558654.89 MWD+IFR-AK-CAZ-SC 888.73 23.82 244.33 870.50 748.97 -67.63 -118.55 5945468.06 558622.80 MWD+IFR-AK-CAZ-SC ~ 984.34 25.36 248.14 957.44 835.91 -83.62 -154.96 5945451.79 558586.52 MWD+IFR-AK-CAZ-SC 1079.17 29.35 249.39 1041.65 920.12 -99.37 -195.58 5945435.72 558546.03 MWD+IFR-AK-CAZ-SC 1173.46 33.55 247.63 1122.07 1000.54 -117.43 -241.33 5945417.31 558500.43 MWD+IFR-AK-CAZ-SC 1269.34 37.55 246.00 1200.07 1078.54 -139.41 -292.54 5945394.94 558449.39 MWD+IFR-AK-CAZ-SC 1365.12 40.79 245.38 1274.31 1152.78 -164.32 -347.66 5945369.60 558394.48 MWD+IFR-AK-CAZ-SC 1460.41 44.98 245.72 1344.12 1222.59 -191.15 -406.68 5945342.31 558335.67 MWD+IFR-AK-CAZ-SC 1554.68 46.42 246.05 1409.96 1288.43 -218.71 -468.26 5945314.28 558274.31 MWD+IFR-AK-CAZ-SC i 1650.38 49.77 248.34 1473.87 1352.34 -246.27 -533.92 5945286.20 558208.88 MWD+IFR-AK-CAZ-SC ~ 1745.78 50.88 252.31 1534.79 1413.26 -270.97 -603.04 5945260.97 558139.96 MWD+IFR-AK-CAZ-SC 1840.83 53.83 249.73 1592.84 1471.31 -295.47 -674.18 5945235.92 558069.02 MWD+IFR-AK-CAZ-SC 1935.78 57.54 247.52 1646.37 1524.84 -324.08 -747.17 5945206.75 557996.26 MWD+IFR-AK-CAZ-SC 2030.49 61.49 246.70 1694.41 1572.88 -355.83 -822.34 5945174.41 557921.35 MWD+IFR-AK-CAZ-SC 2126.64 63.76 245.73 1738.61 1617.08 -390.27 -900.47 5945139.37 557843.50 MWD+IFR-AK-CAZ-SC 2221.15 67.60 243.97 1777.53 1656.00 -426.88 -978.40 5945102.15 557765.87 MWD+IFR-AK-CAZ-SC 2315.63 68.70 240.48 1812.70 1691.17 -467.74 -1055.96 5945060.69 557688.63 MWD+IFR-AK-CAZ-SC i 2411.62 72.28 236.38 1844.77 1723.24 -515.12 -1133.00 5945012.71 557611.97 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Bate: 1/7!2003 1'imc: 13:1322 Pa~c: 2 Field: Kuparuk River Unit Co-ordinate(.~h'i Kefcrencc: Well: 1J-174, TRie North Site: Kuparuk 1J Pad Vertical("I'VI))Referencc 1J-174 Doyon 15 (81+40.5 121.5 Well: 1J-174 Section(VS)Refereucc: Well (O.OON.O.OOE,180.OOAzi) WellpA[h: 1J-174PB1 Surrey Caknlation Method: Miriimurn Curvature Dh: Oracle Survev MD Intl Azim ~I'~D Scs"I'U'D V/S Ei~1' ~lap1 ~IapF. I'onl ft deg deg ft ft ft ft ft ft _ _ __ ---- 2506.31 73.30 235.14 1872.79 1751.26 -566.02 -1207.77 5944961.24 557537.61 MWD+IFR-AK-CAZ-SC I 2601.59 76.59 235.97 1897.53 1776.00 -618.05 -1283.64 5944908.63 557462.15 MWD+IFR-AK-CAZ-SC 2697.20 73.97 237.05 1921.82 1800.29 -669.07 -1360.75 5944857.01 557385.45 MWD+iFR-AK-CAZ-SC 2790.67 74.01 237.45 1947.60 1826.07 -717.67 -1436.31 5944807.82 557310.28 MWD+iFR-AK-CAZ-SC I 2887.71 75.26 235.59 1973.32 1851.79 -769.29 -1514.35 5944755.60 557232.65 MWD+IFR-AK-CAZ-SC 2982.52 74.41 236.37 1998.12 1876.59 -820.49 -1590.19 5944703.82 557157.22 MWD+IFR-AK-CAZ-SC ~ i 3078.08 73.83 236.55 2024.27 1902.74 -871.27 -1666.80 5944652.45 557081.01 MWD+IFR-AK-CAZ-SC 3173.10 73.38 238.09 2051.09 1929.56 -920.49 -1743.53 5944602.63 557004.68 MWD+IFR-AK-CAZ-SC !, 3268.00 75.00 238.53 2076.94 1955.41 -968.46 -1821.22 5944554.07 556927.37 MWD+IFR-AK-CAZ-SC 3363.34 75.13 238.67 2101.52 1979.99 -1016.45 -1899.85 5944505.47 556849.13 MWD+IFR-AK-CAZ-SC 3457.80 75.82 237.20 2125.21 2003.68 -1065.00 -1977.34 5944456.33 556772.03 MWD+IFR-AK-CAZ-SC 3552.72 74.53 235.85 2149.49 2027.96 -1115.60 -2053.87 5944405.13 556695.90 MWD+IFR-AK-CAZ-SC 3647.22 74.65 234.87 2174.61 2053.08 -1167.39 -2128.83 5944352.77 556621.36 MWD+IFR-AK-CAZ-SC 3742.44 74.65 235.21 2199.81 2078.28 -1220.00 -2204.08 5944299.57 556546.53 MWD+IFR-AK-CAZ-SC 3838.09 73.86 236.32 2225.77 2104.24 -1271.79 -2280.19 5944247.19 556470.83 MWD+IFR-AK-CAZ-SC 3933.06 75.08 236.20 2251.20 2129.67 -1322.62 -2356.28 5944195.78 556395.15 MWD+IFR-AK-CAZ-SC 3991.88 76.27 235.69 2265.75 2144.22 -1354.53 -2403.49 5944163.50 556348.19 MWD+IFR-AK-CAZ-SC 4045.36 76.31 238.36 2278.43 2156.90 -1382.81 -2447.07 5944134.89 556304.83 MWD+IFR-AK-CAZ-SC 4139.95 77.68 236.46 2299.71 2178.18 -1432.45 -2524.72 5944084.65 556227.58 MWD+IFR-AK-CAZ-SC j 4235.18 79.51 235.62 2318.54 2197.01 -1484.59 -2602.14 5944031.91 556150.58 MWD+IFR-AK-CAZ-SC ~ 4330.39 82.14 236.29 2333.72 2212.19 -1537.21 -2680.02 5943978.69 556073.12 MWD+iFR-AK-CAZ-SC 4426.17 83.39 236.19 2345.79 2224.26 -1590.01 -2759.01 5943925.28 555994.55 MWD+IFR-AK-CAZ-SC 4521.76 83.60 237.36 2356.62 2235.09 -1642.05 -2838.46 5943872.63 555915.52 MWD+IFR-AK-CAZ-SC 4617.38 83.41 235.87 2367.43 2245.90 -1694.32 -2917.78 5943819.74 555836.61 MWD+IFR-AK-CAZ-SC 4713.17 84.16 234.27 2377.80 2256.27 -1748.85 -2995.85 5943764.62 555758.98 MWD+IFR-AK-CAZ-SC ~ 4807.51 83.46 234.53 2387.98 2266.45 -1803.44 -3072.11 5943709.43 555683.15 MWD+IFR-AK-CAZ-SC 4900.98 83.66 234.56 2398.46 2276.93 -1857.32 -3147.77 5943654.97 555607.93 MWD+IFR-AK-CAZ-SC 4997.48 82.79 231.60 2409.85 2288.32 -1914.87 -3224.37 5943596.83 555531.78 MWD+IFR-AK-CAZ-SC I 5093.72 83.96 231.68 2420.95 2299.42 -1974.20 -3299.33 5943536.92 555457.30 MWD+IFR-AK-CAZ-SC 5188.36 84.02 232.50 2430.86 2309.33 -2032.03 -3373.59 5943478.52 555383.50 MWD+IFR-AK-CAZ-SC 5283.81 83.60 234.19 2441.15 2319.62 -2088.68 -3449.71 5943421.29 555307.83 MWD+IFR-AK-CAZ-SC 5378.85 83.15 235.17 2452.12 2330.59 -2143.26 -3526.74 5943366.11 555231.23 MWD+IFR-AK-CAZ-SC 5474.38 82.47 235.14 2464.07 2342.54 -2197.41 -3604.52 5943311.36 555153.88 MWD+IFR-AK-CAZ-SC 5569.19 83.94 237.22 2475.29 2353.76 -2249.80 -3682.73 5943258.36 555076.09 MWD+IFR-AK-CAZ-SC 5664.47 83.41 237.61 2485.79 2364.26 -2300.80 -3762.53 5943206.75 554996.71 MWD+IFR-AK-CAZ-SC 5759.50 84.28 236.28 2495.98 2374.45 -2352.34 -3841.71 5943154.60 554917.93 MWD+IFR-AK-CAZ-SC 5854.45 83.85 235.00 2505.80 2384.27 -2405.64 -3919.67 5943100.70 554840.40 MWD+IFR-AK-CAZ-SC I 5949.64 84.09 234.00 2515.80 2394.27 -2460.61 -3996.74 5943045.14 554763.77 MWD+IFR-AK-CAZ-SC ~ 6045.24 83.97 234.05 2525.74 2404.21 -2516.46 -4073.69 5942988.69 554687.27 MWD+IFR-AK-CAZ-SC i 6139.32 83.60 234.59 2535.92 2414.39 -2571.01 -4149.66 5942933.55 554611.73 MWD+IFR-AK-CAZ-SC 6235.65 84.21 235.57 2546.15 2424.62 -2625.84 -4228.20 5942878.12 554533.63 MWD+IFR-AK-CAZ-SC I 6330.79 82.23 235.57 2557.38 2435.85 -2679.26 -4306.12 5942824.10 554456.14 MWD+IFR-AK-CAZ-SC 6425.78 83.10 236.55 2569.51 2447.98 -2731.86 -4384.28 5942770.90 554378.40 MWD+IFR-AK-CAZ-SC 6521.76 83.65 236.71 2580.58 2459.05 -2784.30 -4463.90 5942717.85 554299.20 MWD+IFR-AK-CAZ-SC 6616.55 83.48 234.74 2591.21 2469.68 -2837.34 -4541.73 5942664.20 554221.79 MWD+IFR-AK-CAZ-SC 6713.09 83.65 233.79 2602.03 2480.50 -2893.37 -4619.60 5942607.58 554144.37 MWD+IFR-AK-CAZ-SC 6807.21 83.72 233.77 2612.38 2490.85 -2948.64 -4695.07 5942551.72 554069.34 MWD+IFR-AK-CAZ-SC 6902.46 82.53 234.04 2623.78 2502.25 -3004.35 -4771.48 5942495.42 553993.37 MWD+IFR-AK-CAZ-SC 6995.90 84.19 235.29 2634.59 2513.06 -3058.03 -4847.19 5942441.16 553918.08 MWD+IFR-AK-CAZ-SC 7091.95 84.72 235.41 2643.87 2522.34 -3112.38 -4925.84 5942386.20 553839.87 MWD+IFR-AK-CAZ-SC 7188.14 84.16 235.62 2653.19 2531.66 -3166.59 -5004.75 5942331.39 553761.39 MWD+IFR-AK-CAZ-SC 7282.65 84.03 234.69 2662.91 2541.38 -3220.30 -5081.90 5942277.08 553684.67 MWD+IFR-AK-CAZ-SC ~ • Halliburton Company Survey Report Comps~m~: ConocoPhlliips Alaska Inc. Ikatc 1/7/2L1Q8 ~'ime: 13:1322 Pa~~c 3 Field: Kuparuk River Unit ('u-ordinate(i`TE) Reference: WeEI: 1J-174, True North -- site Kuparuk 1J Pad ~crtical (TVD) Reference: 1J-174 Coyon 15 ($1+40.5 121.5 ~~cll: 1J-174 Sectiun (VS)Reference_ Well (O.OON,O.OOE,180.OOAzi) ~~'cllp~~lh: 1J-174PB1 tiuncy~ Cakularion117elhod: Minimum CUrvatUfe llb: Oracle __ __ tiui~ c~ ~1I) Licl ~zim ~f~'D SvgT~ \.S EIW k11apN MapE Ilrol ft deg deg ft ft ft ft ft ft 7377.38 83.72 235.11 2673.02 2551.49 -3274.46 -5158.96 5942222.33 553608.04 MWD+IFR-AK-CAZ-SC 7474.22 83.29 234.91 2683.97 2562.44 -3329.63 -5237.79 5942166.54 553529.66 MWD+IFR-AK-CAZ-SC 7568.31 83.66 235.30 2694.67 2573.14 -3383.11 -5314.46 5942112.47 553453.41 MWD+IFR-AK-CAZ-SC 7663.31 83.03 235.59 2705.68 2584.15 -3436.63 -5392.17 5942058.35 553376.12 MWD+IFR-AK-CAZ-SC i 7758.72 82.98 235.02 2717.29 2595.76 -3490.53 -5470.04 5942003.85 553298.69 MWD+IFR-AK-CAZ-SC 7853.64 84.08 235.04 2727.99 2606.46 -3544.59 -5547.32 5941949.20 553221.84 MWD+IFR-AK-CAZ-SC ~ 7949.85 82.91 236.40 2738.89 2617.36 -3598.43 -5626.30 5941894.75 553143.29 MWD+IFR-AK-CAZ-SC 8044.56 84.31 236.98 2749.43 2627.90 -3650.12 -5704.96 5941842.46 553065.04 MWD+IFR-AK-CAZ-SC 8138.61 83.72 236.02 2759.24 2637.71 -3701.74 -5782.96 5941790.23 552987.46 MWD+IFR-AK-CAZ-SC 8233.85 83.29 235.06 2770.01 2648.48 -3755.28 -5860.98 5941736.08 552909.86 MWD+IFR-AK-CAZ-SC 8329.71 83.16 235.44 2781.32 2659.79 -3809.54 -5939.19 5941681.22 552832.08 MWD+IFR-AK-CAZ-SC 8424.82 83.78 235.85 2792.14 2670.61 -3862.87 -6017.20 5941627.30 552754.50 MWD+IFR-AK-CAZ-SC 8520.36 83.71 237.93 2802.55 2681.02 -3914.74 -6096.75 5941574.81 552675.37 MWD+IFR-AK-CAZ-SC 8614.62 83.72 234.38 2812.87 2691.34 -3966.92 -6174.55 5941522.03 552597.98 MWD+IFR-AK-CAZ-SC 8710.45 83.35 233.25 2823.66 2702.13 -4023.13 -6251.41 5941465.23 552521.58 MWD+IFR-AK-CAZ-SC 8805.50 84.03 234.27 2834.11 2712.58 -4078.98 -6327.60 5941408.79 552445.83 MWD+IFR-AK-CAZ-SC 8900.16 83.84 236.35 2844.11 2722.58 -4132.55 -6405.00 5941354.62 552368.86 MWD+IFR-AK-CAZ-SC 8995.82 83.91 235.16 2854.32 2732.79 -4186.07 -6483.62 5941300.49 552290.66 MWD+IFR-AK-CAZ-SC 9091.24 83.78 235.28 2864.55 2743.02 -4240.19 -6561.54 5941245.78 552213.17 MWD+IFR-AK-CAZ-SC 9186.63 83.90 235.24 2874.78 2753.25 -4294.23 -6639.47 5941191.13 552135.67 MWD+IFR-AK-CAZ-SC 9282.10 83.71 235.75 2885.08 2763.55 -4348.00 -6717.69 5941136.76 552057.89 MWD+IFR-AK-CAZ-SC 9378.39 83.47 235.74 2895.83 2774.30 -4401.86 -6796.78 5941082.29 551979.23 MWD+IFR-AK-CAZ-SC I ~ 9472.74 84.03 236.79 2906.11 2784.58 -4453.95 -6874.77 5941029.60 551901.65 MWD+IFR-AK-CAZ-SC 9567.86 84.34 236.76 2915.74 2794.21 -4505.80 -6953.93 5940977.14 551822.90 MWD+IFR-AK-CAZ-SC 9662.57 83.90 235.98 2925.45 2803.92 -4557.97 -7032.38 5940924.36 551744.87 MWD+IFR-AK-CAZ-SC 9757.75 84.03 235.58 2935.45 2813.92 -4611.20 -7110.64 5940870.53 551667.03 MWD+IFR-AK-CAZ-SC 9853.10 84.22 235.58 2945.21 2823.68 -4664.82 -7188.89 5940816.31 551589.22 MWD+IFR-AK-CAZ-SC 9947.66 83.53 233.61 2955.30 2833.77 -4719.28 -7265.52 5940761.25 551513.02 MWD+IFR-AK-CAZ-SC 10042.24 84.09 230.48 2965.50 2843.97 -4777.11 -7339.65 5940702.86 551439.35 MWD+IFR-AK-CAZ-SC 10137.74 83.10 227.40 2976.16 2854.63 -4839.43 -7411.20 5940639.98 551368.30 MWD+IFR-AK-CAZ-SC 10233.35 83.84 225.88 2987.03 2865.50 -4904.65 -7480.26 5940574.23 551299.76 MWD+IFR-AK-CAZ-SC 10328.54 82.41 221.91 2998.43 2876.90 -4972.73 -7545.77 5940505.65 551234.78 MWD+IFR-AK-CAZ-SC 10423.29 82.98 219.48 3010.48 2888.95 -5043.98 -7607.04 5940433.93 551174.07 MWD+IFR-AK-CAZ-SC 10519.50 83.65 216.63 3021.68 2900.15 -5119.22 -7665.94 5940358.24 551115.77 MWD+IFR-AK-CAZ-SC ~~ 10614.03 83.10 212.55 3032.59 2911.06 -5196.50 -7719.23 5940280.55 551063.09 MWD+IFR-AK-CAZ-SC 10709.41 82.91 211.17 3044.21 2922.68 -5276.91 -7769.20 5940199.77 551013.75 MWD+IFR-AK-CAZ-SC i 10804.51 82.73 211.25 3056.10 2934.57 -5357.61 -7818.10 5940118.70 550965.49 MWD+IFR-AK-CAZ-SC 10899.91 82.48 207.80 3068.38 2946.85 -5439.91 -7864.71 5940036.04 550919.53 MWD+IFR-AK-CAZ-SC i 10994.66 82.41 205.41 3080.84 2959.31 -5523.89 -7906.77 5939951.75 550878.12 MWD+IFR-AK-CAZ-SC i 11090.17 82.17 201.86 3093.66 2972.13 -5610.58 -7944.71 5939864.77 550840.87 MWD+IFR-AK-CAZ-SC 11185.27 82.66 198.79 3106.21 2984.68 -5698.97 -7977.45 5939776.14 550808.82 MWD+IFR-AK-CAZ-SC 11280.36 82.92 194.65 3118.15 2996.62 -5789.30 -8004.58 5939685.61 550782.40 MWD+IFR-AK-CAZ-SC 11375.17 83.17 191.46 3129.64 3008.11 -5880.97 -8025.84 5939593.78 550761.86 MWD+IFR-AK-CAZ-SC 11469.79 82.90 188.64 3141.11 3019.58 -5973.44 -8042.23 5939501.20 550746.19 MWD+IFR-AK-CAZ-SC 11565.15 82.97 183.76 3152.85 3031.32 -6067.49 -8052.45 5939407.08 550736.71 MWD+IFR-AK-CAZ-SC 11660.41 83.10 179.83 3164.40 3042.87 -6161.98 -8055.41 5939312.57 550734.49 MWD+IFR-AK-CAZ-SC 11755.39 82.53 178.20 3176.28 3054.75 -6256.20 -8053.79 5939218.38 550736.84 MWD+IFR-AK-CAZ-SC 11850.25 83.95 175.56 3187.45 3065.92 -6350.25 -8048.66 5939124.38 550742.70 MWD+IFR-AK-CAZ-SC 11945.32 85.98 173.18 3195.80 3074.27 -6444.48 -8039.36 5939030.23 550752.73 MWD+IFR-AK-CAZ-SC i 12040.75 85.52 173.56 3202.87 3081.34 -6539.01 -8028.38 5938935.80 550764.45 MWD+IFR-AK-CAZ-SC i j 12060.68 85.64 173.39 3204.40 3082.87 -6558.76 -8026.12 5938916.08 550766.87 MWD+IFR-AK-CAZ-SC 12137.87 86.07 174.14 3209.98 3088.45 -6635.29 -8017.76 5938839.62 550775.82 MWD+IFR-AK-CAZ-SC ~ 12232.47 87.29 174.96 3215.46 3093.93 -6729.30 -8008.79 5938745.69 550785.52 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Cumpanti: ConocoPhillipsAlaskalnC. Date_ 1/?!2008 Time 13:1322 Pair. -t ricld: Kuparuk River Unit ('u-ordinate(~EI Reference: Well- 1J-174, True North Site: Kuparuk 1J Pad Y'ei~Yieal(r['Vt)) Reference 1J-174 f3oyon 15 (81+40.5 121.5 ~~ell: 1 J-174 Section (VS) 12eCerence Well (O.RON,O.OOE,180 OOAzIj Weflpalh: 1J-174PB1 Survey Calculation .~]cthod: Minimum CuNature llh: Oracle Snn c~ ~iD Inc! dim T~~D Svs'fVD V/S E/W ~fap~ ~TapF lLol ft deg deg ft ft ft ft ft ft 12328.43 89.78 174.34 3217,91 3096.38 -6824.80 -7999.84 5938650.27 550795.21 MWD+IFR-AK-CAZ-SC 12423.48 89.18 171.34 3218.78 3097.25 -6919.10 -7988.00 5938556.08 550807.79 MWD+IFR-AK-CAZ-SC ~ 12518.35 91.03 172.88 3218.60 3097.07 -7013.06 -7974.98 5938462.23 550821.54 MWD+IFR-AK-CAZ-SC 12614.04 90.35 172.03 3217.45 3095.92 -7107.91 -7962.41 5938367.49 550834.85 MWD+IFR-AK-CAZ-SC 12707.47 89.55 171.74 3217.53 3096.00 -7200.41 -7949.23 5938275.11 550848.75 MWD+IFR-AK-CAZ-SC 12803.72 90.75 173.92 3217.28 3095.75 -7295.90 -7937.21 5938179.72 550861.51 MWD+IFR-AK-CAZ-SC 12898.63 90.23 177.14 3216.47 3094.94 -7390.50 -7929.82 5938085.19 550869.64 MWD+IFR-AK-CAZ-SC 12994.21 89.98 176.80 3216.29 3094.76 -7485.95 -7924.77 5937989.79 550875.44 MWD+IFR-AK-CAZ-SC 13090.05 89.86 177.11 3216.43 3094.90 -7581.65 -7919.67 5937894.14 550881.28 MWD+IFR-AK-CAZ-SC 13184.33 92.43 180.90 3214.54 3093.01 -7675.87 -7918.04 5937799.94 550883.65 MWD+IFR-AK-CAZ-SC 13279.81 91.59 180.88 3211.19 3089.66 -7771.28 -7919.52 5937704.54 550882.91 MWD+IFR-AK-CAZ-SC 13375.36 90.66 180.43 3209.32 3087.79 -7866.81 -7920.61 5937609.02 550882:56 MWD+IFR-AK-CAZ-SC 13471.57 89.86 180.54 3208.88 3087.35 -7963.01 -7921.42 5937512.82 550882.50 MWD+IFR-AK-CAZ-SC 13566.52 90.40 180.75 3208.67 3087.14 -8057.96 -7922.49 5937417.88 550882.17 MWD+IFR-AK-CAZ-SC 13661.43 89.98 180.92 3208.35 3086.82 -8152.85 -7923.88 5937322.98 550881.53 MWD+IFR-AK-CAZ-SC 13756.87 90.70 180.19 3207.79 3086.26 -8248.29 -7924.80 5937227.55 550881.35 MWD+IFR-AK-CAZ-SC 13851.59 91.08 178.87 3206.31 3084.78 -8342.99 -7924.02 5937132.87 550882.86 MWD+IFR-AK-CAZ-SC 13946.88 91.09 178.53 3204.51 3082.98 -8438.24 -7921.86 5937037.65 550885.77 MWD+IFR-AK-CAZ-SC 14043.25 90.54 180.51 3203.14 3081.61 -8534.59 -7921.06 5936941.31 550887.33 MWD+IFR-AK-CAZ-SC 14137.27 90.23 179.75 3202.51 3080.98 -8628.61 -7921.27 5936847.31 550887.85 MWD+IFR-AK-CAZ-SC 14232.69 89.92 179.56 3202.38 3080.85 -8724.03 -7920.69 5936751.91 550889.17 MWD+IFR-AK-CAZ-SC 14327.73 90.58 179.65 3201.97 3080.44 -8819.06 -7920.04 5936656.89 550890.56 MWD+IFR-AK-CAZ-SC 14423.14 91.08 180.61 3200.59 3079.06 -8914.46 -7920.26 5936561.50 550891.09 MWD+IFR-AK-CAZ-SC 14519.76 90.97 180.11 3198.86 3077.33 -9011.06 -7920.86 5936464.90 550891.24 MWD+IFR-AK-CAZ-SC ~ 14614.04 90.10 179.00 3197.98 3076.45 -9105.33 -7920.13 5936370.65 550892.70 MWD+IFR-AK-CAZ-SC ~ 14708.07 90.11 178.74 3197.80 3076.27 -9199.34 -7918.28 5936276.67 550895.29 MWD+IFR-AK-CAZ-SC 14804.49 90.17 180.46 3197.57 3076.04 -9295.76 -7917.60 5936180.27 550896.72 MWD+iFR-AK-CAZ-SC 14899.49 90.77 180.32 3196.79 3075.26 -9390.75 -7918.25 5936085.28 550896.81 MWD+iFR-AK-CAZ-SC 14996.23 90.60 178.42 3195.63 3074.10 -9487.47 -7917.19 5935988.58 550898.63 MWD+IFR-AK-CAZ-SC 15090.45 90.54 176.58 3194.70 3073.17 -9581.60 -7913.08 5935894.50 550903.47 MWD+IFR-AK-CAZ-SC 15185.13 92.39 176.81 3192.27 3070.74 -9676.08 -7907.62 5935800.07 550909.67 MWD+IFR-AK-CAZ-SC 15276.48 91.71 178.13 3189.01 3067.48 -9767.28 -7903.59 5935708.91 550914.41 MWD+IFR-AK-CAZ-SC 15308.00 91.71 178.13 3188.07 3066.54 -9798.77 -7902.56 5935677.44 550915.68 PROJECTED to TD Halliburton Company Survey Report • Company: ConocoPhiUips Alaska lnc. Daft 1/712003 Fimc 14:00:16 Nngc I Field: KupaNk River Unit Co -ordinnte(,AE1 Reference: Welly 1J-174, Tr ue North Site Kuparuk 1J'Pad ~~ertical (T~~i))Re feren~e: 1J-174 ~oyon 1 5 (81+40-5 121.5 Nell: 1J-174 Se ction (~~S) Rrfer eucc Well (O OON.O.OOE130.OOAzi) 1~c1 lpath: 1 J-174PB2 Su rvey Calculation Method: Minimum Curva _-' _ _- - ture Ub: Oracle I - Field: Kuparuk River Unit North Slope Alaska ~ United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-174 Slot Name: 50-029-23374-00 Well Position: +N/-S -382.67 ft Northing: 5945536.61 ft Latitude: 70 15 42.494 N +E/-W -52.13 ft Eastin g : 558740 .81 ft Longitude: 149 31 30.524 W Position Uncertainty: 0.00 ft i Wellpath: 1 J-174P62 50-029-23374-71 Drilled From: Tie-on Depth: 1 J-174P61 15090.45 ft Current Datum: 1J-174 Doyon 15 (81+40.5 Height 121 .53 ft Above System Datum: Mean Sea Level Magnetic Data: 11/10/2007 Declination: 23.09 deg Field Strength: 57623 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.53 0.00 0.00 180.00 Survey Program for Definitive Wellpath ~ i Date: 12/6/2007 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 50.00 461.00 1J-174P61 Gyro (50. 00-461.00) CB-MAG-SS Camera based mag single shot 508.50 15090.45 1J-174P61 IIFR+MS+SAG (508.50- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15140.00 18114.14 1J-174P62 IIFR+MS+SAG (15140.0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey _-_ - - ~ID Intl Azim TV11 Spsl'~~D Y/S E,tiy' StapA IVIapF: 7'001 ft deg deg ft ft ft ft ft ft 40.53 0.00 0.00 40.53 -81.00 0.00 0.00 5945536.61 558740.81 TIE LINE 50.00 0.35 249.08 50.00 -71.53 -0.01 -0.03 5945536.60 558740.78 CB-MAG-SS 120.00 0.16 226.19 120.00 -1.53 -0.15 -0.30 5945536.45 558740.51 CB-MAG-SS i 151.00 0.36 237.75 151.00 29.47 -0.24 -0.41 5945536.37 558740.40 CB-MAG-SS 200.00 0.54 232.25 200.00 78.47 -0.46 -0.72 5945536.14 558740.09 CB-MAG-SS i 267.00 2.49 233.60 266.97 145.44 -1.52 -2.14 5945535.08 558738.68 CB-MAG-SS 363.00 5.64 238.24 362.72 241.19 -5.24 -7.84 5945531.31 558733.02 CB-MAG-SS 461.00 8.86 241.39 459.92 338.39 -11.39 -18.56 5945525.08 558722.34 CB-MAG-SS 508.50 9.91 236.81 506.79 385.26 -15.38 -25.19 5945521.04 558715.74 MWD+IFR-AK-CAZ-SC 603.64 12.54 237.41 600.10 478.57 -25.42 -40.75 5945510.87 558700.27 MWD+IFR-AK-CAZ-SC 698.58 15.45 240.50 692.21 570.68 -37.21 -60.44 5945498.94 558680.67 MWD+IFR-AK-CAZ-SC i 793.54 20.77 241.94 782.43 660.90 -51.36 -86.33 5945484.58 558654.89 MWD+IFR-AK-CAZ-SC 888.73 23.82 244.33 870.50 748.97 -67.63 -118.55 5945468.06 558622.80 MWD+IFR-AK-CAZ-SC j 984.34 25.36 248.14 957.44 835.91 -83.62 -154.96 5945451.79 558586.52 MWD+IFR-AK-CAZ-SC 1079.17 29.35 249.39 1041.65 920.12 -99.37 -195.58 5945435.72 558546.03 MWD+IFR-AK-CAZ-SC 1173.46 33.55 247.63 1122.07 1000.54 -117.43 -241.33 5945417.31 558500.43 MWD+IFR-AK-CAZ-SC 1269.34 37.55 246.00 1200.07 1078.54 -139.41 -292.54 5945394.94 558449.39 MWD+IFR-AK-CAZ-SC 1365.12 40.79 245.38 1274.31 1152.78 -164.32 -347.66 5945369.60 558394.48 MWD+IFR-AK-CAZ-SC 1460.41 44.98 245.72 1344.12 1222.59 -191.15 -406.68 5945342.31 558335.67 MWD+IFR-AK-CAZ-SC 1554.68 46.42 246.05 1409.96 1288.43 -218.71 -468.26 5945314.28 558274.31 MWD+IFR-AK-CAZ-SC ~ I 1650.38 49.77 248.34 1473.87 1352.34 -246.27 -533.92 5945286.20 558208.88 MWD+IFR-AK-CAZ-SC 1745.78 50.88 252.31 1534.79 1413.26 -270.97 -603.04 5945260.97 558139.96 MWD+IFR-AK-CAZ-SC 1840.83 53.83 249.73 1592.84 1471.31 -295.47 -674.18 5945235.92 558069.02 MWD+IFR-AK-CAZ-SC 1935.78 57.54 247.52 1646.37 1524.84 -324.08 -747.17 5945206.75 557996.26 MWD+IFR-AK-CAZ-SC 2030.49 61.49 246.70 1694.41 1572.88 -355.83 -822.34 5945174.41 557921.35 MWD+IFR-AK-CAZ-SC 2126.64 63.76 245.73 1738.61 1617.08 -390.27 -900.47 5945139.37 557843.50 MWD+IFR-AK-CAZ-SC 2221.15 67.60 243.97 1777.53 1656.00 -426.88 -978.40 5945102.15 557765.87 MWD+IFR-AK-CAZ-SC 2315.63 68.70 240.48 1812.70 1691.17 -467.74 -1055.96 594560.69 557688.63 MWD+IFR-AK-CAZ-SC i • • Halliburton Company Survey Report ~~'~ Cornpan~~: ConocoRhillipsAlaskalnc- !tart: 1/7/2008 Time 14.00:16 Pa~c 2 Field: Kuparuk Rlver Unit Co-ordinate(~Ei F2cfcrence: Well: 1J-174, True North Siter Kuparuk 1J Pad Vertical (I'~i)) ficfereuce: 1J-174 poyon 15 (8 ~ *40.5 121.5 ~~~cll: 1J-174 5ecrion(VS)Reference: Well (QIgON,0.00E,180.00Azi) ~~ cllpati~: 1 J-174PB2 Surrey Calculation Method: Minimum Cctrvature llh: Oracle tiui~cc }ID Intl ~iim Z'~~D Sps "h~ D S/S E;1V 11np`~~ MapE fuul ft deg deg ft ft ft ft ft ft _ _._ --- 2411.62 72.28 236.38 1844.77 1723.24 -515.12 -1133.00 5945012.71 557611.97 MWD+IFR-AK-CAZ-SC 2506.31 73.30 235.14 1872.79 1751.26 -566.02 -1207.77 5944961.24 557537.61 MWD+IFR-AK-CAZ-SC 2601.59 76.59 235.97 1897.53 1776.00 -618.05 -1283.64 5944908.63 557462.15 MWD+IFR-AK-CAZ-SC 2697.20 73.97 237.05 1921.82 1800.29 -669.07 -1360.75 5944857.01 557385.45 MWD+IFR-AK-CAZ-SC ~ 2790.67 74.01 237.45 1947.60 1826.07 -717.67 -1436.31 5944807.82 557310.28 MWD+IFR-AK-CAZ-SC 2887.71 75.26 235.59 1973.32 1851.79 -769.29 -1514.35 5944755.60 557232.65 MWD+IFR-AK-CAZ-SC ' 2982.52 74.41 236.37 1998.12 1876.59 -820.49 -1590.19 5944703.82 557157.22 MWD+IFR-AK-CAZ-SC 3078.08 73.83 236.55 2024.27 1902.74 -871.27 -1666.80 5944652.45 557081.01 MWD+IFR-AK-CAZ-SC 3173.10 73.38 238.09 2051.09 1929.56 -920.49 -1743.53 5944602.63 557004.68 MWD+IFR-AK-CAZ-SC 3268.00 75.00 238.53 2076.94 1955.41 -968.46 -1821.22 5944554.07 556927.37 MWD+IFR-AK-CAZ-SC 3363.34 75.13 238.67 2101.52 1979.99 -1016.45 -1899.85 5944505.47 556849.13 MWD+IFR-AK-CAZ-SC 3457.80 75.82 237.20 2125.21 2003.68 -1065.00 -1977.34 5944456.33 556772.03 MWD+IFR-AK-CAZ-SC I 3552.72 74.53 235.85 2149.49 2027.96 -1115.60 -2053.87 5944405.13 556695.90 MWD+IFR-AK-CAZ-SC 3647.22 74.65 234.87 2174.61 2053.08 -1167.39 -2128.83 5944352.77 556621.36 MWD+IFR-AK-CAZ-SC 3742.44 74.65 235.21 2199.81 2078.28 -1220.00 -2204.08 5944299.57 556546.53 MWD+IFR-AK-CAZ-SC 3838.09 73.86 236.32 2225.77 2104.24 -1271.79 -2280.19 5944247.19 556470.83 MWD+IFR-AK-CAZ-SC 3933.06 75.08 236.20 2251.20 2129.67 -1322.62 -2356.28 5944195.78 556395.15 MWD+IFR-AK-CAZ-SC ~ i 3991.88 76.27 235.69 2265.75 2144.22 -1354.53 -2403.49 5944163.50 556348.19 MWD+IFR-AK-CAZ-SC 4045.36 76.31 238.36 2278.43 2156.90 -1382.81 -2447.07 5944134.89 556304.83 MWD+IFR-AK-CAZ-SC j 4139.95 77.68 236.46 2299.71 2178.18 -1432.45 -2524.72 5944084.65 556227.58 MWD+IFR-AK-CAZ-SC 4235.18 79.51 235.62 2318.54 2197.01 -1484.59 -2602.14 5944031.91 556150.58 MWD+IFR-AK-CAZ-SC 4330.39 82.14 236.29 2333.72 2212.19 -1537.21 -2680.02 5943978.69 556073.12 MWD+IFR-AK-CAZ-SC 4426.17 83.39 236.19 2345.79 2224.26 -1590.01 -2759.01 5943925.28 555994.55 MWD+IFR-AK-CAZ-SC 4521.76 83.60 237.36 2356.62 2235.09 -1642.05 -2838.46 5943872.63 555915.52 MWD+IFR-AK-CAZ-SC 4617.38 83.41 235.87 2367.43 2245.90 -1694.32 -2917.78 5943819.74 555836.61 MWD+IFR-AK-CAZ-SC 4713.17 84.16 234.27 2377.80 2256.27 -1748.85 -2995.85 5943764.62 555758.98 MWD+IFR-AK-CAZ-SC 4807.51 83.46 234.53 2387.98 2266.45 -1803.44 -3072.11 5943709.43 555683.15 MWD+IFR-AK-CAZ-SC 4900.98 83.66 234.56 2398.46 2276.93 -1857.32 -3147.77 5943654.97 555607.93 MWD+IFR-AK-CAZ-SC ~ 4997.48 82.79 231.60 2409.85 2288.32 -1914.87 -3224.37 5943596.83 555531.78 MWD+IFR-AK-CAZ-SC ~ 5093.72 83.96 231.68 2420.95 2299.42 -1974.20 -3299.33 5943536.92 555457.30 MWD+IFR-AK-CAZ-SC j 5188.36 84.02 232.50 2430.86- 2309.33 -2032.03 -3373.59 5943478.52 555383.50 MWD+IFR-AK-CAZ-SC i 5283.81 83.60 234.19 2441.15 2319.62 -2088.68 -3449.71 5943421.29 555307.83 MWD+IFR-AK-CAZ-SC 5378.85 83.15 235.17 2452.12 2330.59 -2143.26 -3526.74 5943366.11 555231.23 MWD+IFR-AK-CAZ-SC 5474.38 82.47 235.14 2464.07 2342.54 -2197.41 -3604.52 5943311.36 555153.88 MWD+IFR-AK-CAZ-SC 5569.19 83.94 237.22 2475.29 2353.76 -2249.80 -3682.73 5943258.36 555076.09 MWD+IFR-AK-CAZ-SC 5664.47 83.41 237.61 2485.79 2364.26 -2300.80 -3762.53 5943206.75 554996.71 MWD+IFR-AK-CAZ-SC 5759.50 84.28 236.28 2495.98 2374.45 -2352.34 -3841.71 5943154.60 554917.93 MWD+IFR-AK-CAZ-SC 5854.45 83.85 235.00 2505.80 2384.27 -2405.64 -3919.67 5943100.70 554840.40 MWD+IFR-AK-CAZ-SC 5949.64 84.09 234.00 2515.80 2394.27 -2460.61 -3996.74 5943045.14 554763.77 MWD+IFR-AK-CAZ-SC 6045.24 83.97 234.05 2525.74 2404.21 -2516.46 -4073.69 5942988.69 554687.27 MWD+IFR-AK-CAZ-SC 6139.32 83.60 234.59 2535.92 2414.39 -2571.01 -4149.66 5942933.55 554611.73 MWD+IFR-AK-CAZ-SC 6235.65 84.21 235.57 2546.15 2424.62 -2625.84 -4228.20 5942878.12 554533.63 MWD+IFR-AK-CAZ-SC 6330.79 82.23 235.57 2557.38 2435.85 -2679.26 -4306.12 5942824.10 554456.14 MWD+IFR-AK-CAZ-SC 6425.78 83.10 236.55 2569.51 2447.98 -2731.86 -4384.28 5942770.90 554378.40 MWD+IFR-AK-CAZ-SC I 6521.76 83.65 236.71 2580.58 2459.05 -2784.30 -4463.90 5942717.85 554299.20 MWD+IFR-AK-CAZ-SC 6616.55 83.48 234.74 2591.21 2469.68 -2837.34 -4541.73 5942664.20 554221.79 MWD+IFR-AK-CAZ-SC I 6713.09 83.65 233.79 2602.03 2480.50 -2893.37 -4619.60 5942607.58 554144.37 MWD+IFR-AK-CAZ-SC 6807.21 83.72 233.77 2612.38 2490.85 -2948.64 -4695.07 5942551.72 554069.34 MWD+IFR-AK-CAZ-SC 6902.46 82.53 234.04 2623.78 2502.25 -3004.35 -4771.48 5942495.42 553993.37 MWD+IFR-AK-CAZ-SC 6995.90 84.19 235.29 2634.59 2513.06 -3058.03 -4847.19 5942441.16 553918.08 MWD+IFR-AK-CAZ-SC ~ 7091.95 84.72 235.41 2643.87 2522.34 -3112.38 -4925.84 5942386.20 553839.87 MWD+IFR-AK-CAZ-SC 7188.14 84.16 235.62 2653.19 2531.66 -3166.59 -5004.75 5942331.39 553761.39 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report ompan~: ConocoPhillips Alaska Inc. Datr. 1/7/2008 'time: 14:00:16. Page: 3 Field: Kuparuk River Unit Co-ordinate(NE)Refcrence: WeII: 1J-174. True North Site KUpafuk 1J Pad Pertical(TVD) Reference: 1J-174 Doyon 15 (21+40.5 121.5 \lcfl: 1J-174 Section(VS)Reference: Well (O.OON,O OOE,180.OOAzi) ~1~clfpath: 1J-~74PB2' SurveyCalcalatiun J]ctlwd: Minimum Curvature llb: C~~racle Survey ilik Licl _lzim TVll Cc, l'~'D _AiS F./1F ~1apN ~tapl? foul ft deg deg ft ft ft ft ft ft 7282.65 84.03 234.69 2662.91 2541.38 -3220.30 -5081.90 5942277.08 553684.67 MWD+IFR-AK-CAZ-SC 7377.38 83.72 235.11 2673.02 2551.49 -3274.46 -5158.96 5942222.33 553608.04 MWD+IFR-AK-CAZ-SC 7474.22 83.29 234.91 2683.97 2562.44 -3329.63 -5237.79 5942166.54 553529.66 MWD+IFR-AK-CAZ-SC 7568.31 83.66 235.30 2694.67 2573.14 -3383.11 -5314.46 5942112.47 553453.41 MWD+IFR-AK-CAZ-SC 7663.31 83.03 235.59 2705.68 2584.15 -3436.63 -5392.17 5942058.35 553376.12 MWD+IFR-AK-CAZ-SC 7758.72 82.98 235.02 2717.29 2595.76 -3490.53 -5470.04 5942003.85 553298.69 MWD+IFR-AK-CAZ-SC 7853.64 84.08 235.04 2727.99 2606.46 -3544.59 -5547.32 5941949.20 553221.84 MWD+IFR-AK-CAZ-SC ~ 7949.85 82.91 236.40 2738.89 2617.36 -3598.43 -5626.30 5941894.75 553143.29 MWD+IFR-AK-CAZ-SC j 8044.56 84.31 236.98 2749.43 2627.90 -3650.12 -5704.96 5941842.46 553065.04 MWD+IFR-AK-CAZ-SC 8138.61 83.72 236.02 2759.24 2637.71 -3701.74 -5782.96 5941790.23 552987.46 MWD+IFR-AK-CAZ-SC 8233.85 83.29 235.06 2770.01 2648..48 -3755.28 -5860.98 5941736.08 552909.86 MWD+IFR-AK-CAZ-SC ~I 8329.71 83.16 235.44 2781.32 2659.79 -3809.54 -5939.19 5941681.22 552832.08 MWD+IFR-AK-CAZ-SC 8424.82 83.78 235.85 2792.14 2670.61 -3862.87 -6017.20 5941627.30 552754.50 MWD+IFR-AK-CAZ-SC 8520.36 83.71 237.93 2802.55 2681.02 -3914.74 -6096.75 5941574.81 552675.37 MWD+IFR-AK-CAZ-SC 8614.62 83.72 234.38 2812.87 2691.34 -3966.92 -6174.55 5941522.03 552597.98 MWD+IFR-AK-CAZ-SC 8710.45 83.35 233.25 2823.66 2702.13 -4023.13 -6251.41 5941465.23 552521.58 MWD+IFR-AK-CAZ-SC 8805.50 84.03 234.27 2834.11 2712.58 -4078.98 -6327.60 5941408.79 552445.83 MWD+IFR-AK-CAZ-SC 8900.16 83.84 236.35 2844.11 2722.58 -4132.55 -6405.00 5941354.62 552368.86 MWD+IFR-AK-CAZ-SC 8995.82 83.91 235.16 2854.32 2732.79 -4186.07 -6483.62 5941300.49 552290.66 MWD+IFR-AK-CAZ-SC 9091.24 83.78 235.28 2864.55 2743.02 -4240.19 -6561.54 5941245.78 552213.17 MWD+IFR-AK-CAZ-SC 9186.63 83.90 235.24 2874.78 2753.25 -4294.23 -6639.47 5941191.13 552135.67 MWD+IFR-AK-CAZ-SC ~ 9282.10 83.71 235.75 2885.08 2763.55 -4348.00 -6717.69 5941136.76 552057.89 MWD+IFR-AK-CAZ-SC 9378.39 83.47 235.74 2895.83 2774.30 -4401.86 -6796.78 5941082.29 551979.23 MWD+IFR-AK-CAZ-SC 9472.74 84.03 236.79 2906.11 2784.58 -4453.95 -6874.77 5941029.60 551901.65 MWD+IFR-AK-CAZ-SC 9567.86 84.34 236.76 2915.74 2794.21 -4505.80 -6953.93 5940977.14 551822.90 MWD+IFR-AK-CAZ-SC 9662.57 83.90 235.98 2925.45 2803.92 -4557.97 -7032.38 5940924.36 551744.87 MWD+IFR-AK-CAZ-SC ': 9757.75 84.03 235.58 2935.45 2813.92 -4611.20 -7110.64 5940870.53 551667.03 MWD+IFR-AK-CAZ-SC I 9853.10 84.22 235.58 2945.21 2823.68 -4664.82 -7188.89 5940816.31 551589.22 MWD+IFR-AK-CAZ-SC 9947.66 83.53 233.61 2955.30 2833.77 -4719.28 -7265.52 5940761.25 551513.02 MWD+IFR-AK-CAZ-SC 10042.24 84.09 230.48 2965.50 2843.97 -4777.11 -7339.65 5940702.86 551439.35 MWD+IFR-AK-CAZ-SC 10137.74 83.10 227.40 2976.16 2854.63 ~t839.43 -7411.20 5940639.98 551368.30 MWD+IFR-AK-CAZ-SC 10233.35 83.84 225.88 2987.03 2865.50 -4904.65 -7480.26 5940574.23 551299.76 MWD+IFR-AK-CAZ-SC 10328.54 82.41 221.91 2998.43 2876.90 -4972.73 -7545.77 5940505.65 551234.78 MWD+IFR-AK-CAZ-SC 10423.29 82.98 219.48 3010.48 2888.95 -5043.98 -7607.04 5940433.93 551174.07 MWD+IFR-AK-CAZ-SC 10519.50 83.65 216.63 3021.68 2900.15 -5119.22 -7665.94 5940358.24 551115.77 MWD+IFR-AK-CAZ-SC i 10614.03 83.10 212.55 3032.59 2911.06 -5196.50 -7719.23 5940280.55 551063.09 MWD+IFR-AK-CAZ-SC I 10709.41 82.91 211.17 3044.21 2922.68 -5276.91 -7769.20 5940199.77 551013.75 MWD+IFR-AK-CAZ-SC ~ 10804.51 82.73 211.25 3056.10 2934.57 -5357.61 -7818.10 5940118.70 550965.49 MWD+IFR-AK-CAZ-SC 10899.91 82.48 207.80 3068.38 2946.85 -5439.91 -7864.71 5940036.04 550919.53 MWD+IFR-AK-CAZ-SC 10994.66 82.41 205.41 3080.84 2959.31 -5523.89 -7906.77 5939951.75 550878.12 MWD+IFR-AK-CAZ-SC 11090.17 82.17 201.86 3093.66 2972.13 -5610.58 -7944.71 5939864.77 550840.87 MWD+IFR-AK-CAZ-SC 11185.27 82.66 198.79 3106.21 2984.68 -5698.97 -7977.45 5939776.14 550808.82 MWD+IFR-AK-CAZ-SC 11280.36 82.92 194.65 3118.15 2996.62 -5789.30 -8004.58 5939685.61 550782.40 MWD+IFR-AK-CAZ-SC 11375.17 83.17 191.46 3129.64 3008.11 -5880.97 -8025.84 5939593.78 550761.86 MWD+IFR-AK-CAZ-SC 11469.79 82.90 188.64 3141.11 3019.58 -5973.44 -8042.23 5939501.20 550746.19 MWD+IFR-AK-CAZ-SC 11565.15 82.97 183.76 3152.85 3031.32 -6067.49 -8052.45 5939407.08 550736.71 MWD+IFR-AK-CAZ-SC 11660.41 83.10 179.83 3164.40 3042.87 -6161.98 -8055.41 5939312.57 550734.49 MWD+IFR-AK-CAZ-SC 11755.39 82.53 178.20 3176.28 3054.75 -6256.20 -8053.79 5939218.38 550736.84 MWD+IFR-AK-CAZ-SC 11850.25 83.95 175.56 3187.45 3065.92 -6350.25 -8048.66 5939124.38 550742.70 MWD+IFR-AK-CAZ-SC 11945.32 85.98 173.18 3195.80 3074.27 -6444.48 -8039.36 5939030.23 550752.73 MWD+IFR-AK-CAZ-SC 12040.75 85.52 173.56 3202.87 3081.34 -6539.01 -8028.38 5938935.80 550764.45 MWD+IFR-AK-CAZ-SC I 12060.68 85.64 173.39 3204.40 3082.87 -6558.76 -8026.12 5938916.08 550766.87 MWD+IFR-AK-CAZ-SC i 12137.87 86.07 174.14 3209.98 3088.45 -6635.29 -8017.76 5938839.62 550775.82 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Companc: ConocoPhiliips Alaska Inc. Dsrtc: 1l7/'ZOOS Firoc 14:40:16 Nair. -t Field: Kuparuk River Unit Co-o rdiuatc(NE)Referencc UJetl:`1J-174, True North Sift Kuparuk 1J Pad ~'crtical fl'~'D)Referencc 1J-174 Doyen 15 (81+40.5 ~<<^1.5 Nell: 1J-174 Section I~S)Referencc Well (O.OON,O.OOE,180.OO,Azi) ~1eIIpa1L: 1J-174PB2 Sun~e~~ i.'aleulation Method: Mlfllnlulll CUivature Db: OraCle Sung )ID Inc1 ~zim TVD Scti'f~ D N/S E/N' >tapA MapE Tool ft deg deg ft ft ft ft ft ft 12232.47 87.29 174.96 3215.46 3093.93 -6729.30 -8008.79 5938745.69 550785.52 MWD+IFR-AK-CAZ-SC 12328.43 89.78 174.34 3217.91 3096.38 -6824.80 -7999.84 5938650.27 550795.21 MWD+IFR-AK-CAZ-SC 12423.48 89.18 171.34 3218.78 3097.25 -6919.10 -7988.00 5938556.08 550807.79 MWD+IFR-AK-CAZ-SC 12518.35 91.03 172.88 3218.60 3097.07 -7013.06 -7974.98 5938462.23 550821.54 MWD+IFR-AK-CAZ-SC 12614.04 90.35 172.03 3217.45 3095.92 -7107.91 -7962.41 5938367.49 550834.85 MWD+IFR-AK-CAZ-SC 12707.47 89.55 171.74 3217.53 3096.00 -7200.41 -7949.23 5938275.11 550848.75 MWD+IFR-AK-CAZ-SC 12803.72 90.75 173.92 3217.28 3095.75 -7295.90 -7937.21 5938179.72 550861.51 MWD+IFR-AK-CAZ-SC 12898.63 90.23 177.14 3216.47 3094.94 -7390.50 -7929.82 5938085.19 550869.64 MWD+IFR-AK-CAZ-SC 12994.21 89.98 176.80 3216.29 3094.76 -7485.95 -7924.77 5937989.79 550875.44 MWD+IFR-AK-CAZ-SC 13090.05 89.86 177.11 3216.43 3094.90 -7581.65 -7919.67 5937894.14 550881.28 MWD+IFR-AK-CAZ-SC 13184.33 92.43 180.90 3214.54 3093.01 -7675.87 -7918.04 5937799.94 550883.65 MWD+IFR-AK-CAZ-SC 13279.81 91.59 180.88 3211.19 3089.66 -7771.28 -7919.52 5937704.54 550882.91 MWD+IFR-AK-CAZ-SC ~ 13375.36 90.66 180.43 3209.32 3087.79 -7866.81 -7920.61 5937609.02 550882.56 MWD+IFR-AK-CAZ-SC 13471.57 89.86 180.54 3208.88 3087.35 -7963.01 -7921.42 5937512.82 550882.50 MWD+IFR-AK-CAZ-SC 13566.52 90.40 180.75 3208.67 3087.14 -8057.96 -7922.49 5937417.88 550882.17 MWD+IFR-AK-CAZ-SC 13661.43 89.98 180.92 3208.35 3086.82 -8152.85 -7923.88 5937322.98 550881.53 MWD+IFR-AK-CAZ-SC i 13756.87 90.70 180.19 3207.79 3086.26 -8248.29 -7924.80 5937227.55 550881.35 MWD+IFR-AK-CAZ-SC i 13851.59 91.08 178.87 3206.31 3084.78 -8342.99 -7924.02 5937132.87 550882.86 MWD+IFR-AK-CAZ-SC 13946.88 91.09 178.53 3204.51 3082.98 -8438.24 -7921.86 5937037.65 550885.77 MWD+IFR-AK-CAZ-SC 14043.25 90.54 180.51 3203.14 3081.61 -8534.59 -7921.06 5936941.31 550887.33 MWD+IFR-AK-CAZ-SC 14137.27 90.23 179.75 3202.51 3080.98 -8628.61 -7921.27 5936847.31 550887.85 MWD+IFR-AK-CAZ-SC 14232.69 89.92 179.56 3202.38 3080.85 -8724.03 -7920.69 5936751.91 550889.17 MWD+IFR-AK-CAZ-SC 14327.73 90.58 179.65 3201.97 3080.44 -8819.06 -7920.04 5936656.89 550890.56 MWD+IFR-AK-CAZ-SC 14423.14 91.08 180.61 3200.59 3079.06 -8914.46 -7920.26 5936561.50 550891.09 MWD+IFR-AK-CAZ-SC 14519.76 90.97 180.11 3198.86 3077.33 -9011.06 -7920.86 5936464.90 550891.24 MWD+IFR-AK-CAZ-SC 14614.04 90.10 179.00 3197.98 3076.45 -9105.33 -7920.13 5936370.65 550892.70 MWD+IFR-AK-CAZ-SC 14708.07 90.11 178.74 3197.80 3076.27 -9199.34 -7918.28 5936276.67 550895.29 MWD+IFR-AK-CAZ-SC 14804.49 90.17 180.46 3197.57 3076.04 -9295.76 -7917.60 5936180.27 550896.72 MWD+IFR-AK-CAZ-SC 14899.49 90.77 180.32 3196.79 3075.26 -9390.75 -7918.25 5936085.28 550886.81 MWD+IFR-AK-CAZ-SC 14996.23 90.60 178.42 3195.63 3074.10 -9487.47 -7917.19 5935988.58 550898.63 MWD+IFR-AK-CAZ-SC 15090.45 90.54 176.58 3194.70 3073,17 -9581.60 -7913.08 5935894.50 550903.47 MWD+IFR-AK-CAZ-SC 15140.00 91.51 176.70 3193.81 3072.28 -9631.05 -7910.17 5935845.07 550906.76 MWD+IFR-AK-CAZ-SC 15183.65 91.67 175.98 3192.60 3071.07 -9674.60 -7907.39 5935801.56 550909.89 MWD+IFR-AK-CAZ-SC 15279.93 92.19 174.36 3189.35 3067.82 -9770.48 -7899.29 5935705.75 550918.73 MWD+IFR-AK-CAZ-SC 15375.38 92.20 176.13 3185.70 3064.17 -9865.52 -7891.38 5935610.78 550927.38 MWD+IFR-AK-CAZ-SC 15470.06 90.66 178.63 3183.34 3061.81 -9960.07 -7887.05 5935516.28 550932.44 MWD+IFR-AK-CAZ-SC 15565.22 90.54 180.08 3182.34 3060.81 -10055.21 -7885.98 5935421.16 550934.26 MWD+IFR-AK-CAZ-SC 15660.62 91.08 180.83 3180.99 3059.46 -10150.60 -7886.74 5935325.78 550934.24 MWD+IFR-AK-CAZ-SC 15757.03 91.09 182.37 3179.16 3057.63 -10246.95 -7889.43 5935229.42 550932.30 MWD+IFR-AK-CAZ-SC 15850.47 90.10 180.30 3178.19 3056.66 -10340.35 -7891.61 5935136.01 550930.86 MWD+IFR-AK-CAZ-SC 15946.34 91.18 180.97 3177.12 3055.59 -10436.21 -7892.67 5935040.16 550930.54 MWD+IFR-AK-CAZ-SC ~ 16041.48 90.54 180.71 3175.70 3054.17 -10531.33 -7894.07 5934945.04 550929.89 MWD+IFR-AK-CAZ-SC 16135.67 90.54 180.49 3174.81 3053.28 -10625.51 -7895.05 5934850.86 550929.64 MWD+IFR-AK-CAZ-SC 16231.73 90.90 179.61 3173.60 3052.07 -10721.56 -7895.14 5934754.82 550930.30 MWD+IFR-AK-CAZ-SC 16326.87 90.41 180.05 3172.51 3050.98 -10816.69 -7894.85 5934659.70 .550931.33 MWD+IFR-AK-CAZ-SC 16422.06 90.71 180.31 3171.58 3050.05 -10911.88 -7895.15 5934564.53 550931.77 MWD+IFR-AK-CAZ-SC 16517.14 90.17 180.34 3170.85 3049.32 -11006.95 -7895.69 5934469.46 550931.97 MWD+IFR-AK-CAZ-SC 16612.35 90.59 181.31 3170.22 3048.69 -11102.15 -7897.06 5934374.27 550931.35 MWD+IFR-AK-CAZ-SC 16707.93 90.96 180.83 3168.93 3047.40 -11197.70 -7898.85 5934278.71 550930.31 MWD+IFR-AK-CAZ-SC 16802.19 90.10 180.44 3168.06 3046.53 -11291.95 -7899.89 5934184.46 550930.00 MWD+IFR-AK-CAZ-SC 16897.95 90.41 180.51 3167.63 3046.10 -11387.71 -7900.69 5934088.71 550929.95 MWD+IFR-AK-CAZ-SC 16993.04 90.60 181,28 3166.79 3045.26 -11482.78 -7902.17 5933993.64 550929.21 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Companc: GonocoPhillips Alaska Inc . Dutc: 1!712003 Time: 140016 Pa~c Field: Ku parukRiverUnit Co-ordinaCe(NE)ReBerence: Weli~ 1J-174, Tr ue North Sitr. Ku paruk 1J Pad Vertical(TVD)Reference: 1J-174 Doyon 1 5 (31+40.5 121.5 ~~'cll: 1J -174 Section (VS)Reference: Well {O.OON.0-O OE,130.OOAzi) ~~ellpath: 1~ -174PB2 SurveyCakulationlllethud: Minimum Curva ture Uh: Orade tiin,c~ SID Incl ~ Azim I'~~D tivs'I'~'D V/ti ~:%11' ~t~pA S1upE Tunl ft deg deg ft ft ft ft ft ft 17088.83 89.24 179.17 3166.93 3045.40 -11578.56 -7902.55 5933897.87 550929.58 MWD+IFR-AK-CAZ-SC ~ 17183.91 90.02 180.54 3167.54 3046.01 -11673.64 -7902.31 5933802.81 550930.56 MWD+IFR-AK-CAZ-SC +~ 17279.11 91.00 180.15 3166.69 3045.16 -11768.83 -7902.88 5933707.62 550930.73 MWD+IFR-AK-CAZ-SC I 17374.42 89.79 178.98 3166.04 3044.51 -11864.13 -7902.16 5933612.34 550932.20 MWD+IFR-AK-CAZ-SC 17469.58 88.93 177.94 3167.10 3045.57 -11959.25 -7899.60 5933517.25 550935.49 MWD+IFR-AK-CAZ-SC ~ 17564.93 89.17 176.75 3168.68 3047.15 -12054.48 -7895.18 5933422.07 550940.65 MWD+IFR-AK-CAZ-SC 17660.08 89.24 178.01 3170.00 3048.47 -12149.52 -7890.83 5933327.07 550945.74 MWD+IFR-AK-CAZ-SC 17753.79 88.93 178.88 3171.50 3049.97 -12243.19 -7888.29 5933233.44 550949.02 MWD+IFR-AK-CAZ-SC 17849.92 88.62 179.85 3173.55 3052.02 -12339.29 -7887.23 5933137.36 550950.83 MWD+IFR-AK-CAZ-SC 17945.06 88.86 180.04 3175.64 3054.11 -12434.40 -7887.13 5933042.26 550951.66 MWD+IFR-AK-CAZ-SC 18039.80 87.51 180.03 3178.64 3057.11 -12529.09 -7887.19 5932947.58 550952.34 MWD+IFR-AK-CAZ-SC 18114.14 88.99 179.67 3180.91 3059.38 -12603.40 -7887.00 5932873.29 550953.12 MWD+IFR-AK-CAZ-SC 18141.39 88.99 179.67 3181.39 3059.86 -12630.64 -7886.84 5932846.05 550953.49 PROJECTED to TD ~ ~~ 7J-174 "B"lateral liner Well: 1J-174 C~n~C~~ ~l l~ $ p 5-112" BTC and Hydril 521 slot and blank liner Date: 12/15/2007 Alaska, Inc. Rig: Doyon 15 Supervisors: Mike Thornton/ Granville Rizek Deptn Jt Number N j~of Well Equipment Description and Comments Page 1 Length Tops 5" DP to Surface =_> Baker Liner settin tool Does not sta in hole 10.67 11405.87 Baker 7" X 9-5/8" MLZXP Liner Hn r Pkr-Len th above collet rofile 1z.s3 11416.54 Baker 7" X 9-518" MLZXP Liner Han er Packer O.D. 8:44"/ LD 7_.00" ` 8.42 11429.37 Baker "Flex-Lock" Han er Section O.D. 8.31" / I.D. 7.00" 5.26 11437.79 Crossover Bushin 7" H d 563 X 5-1/2" H d 563 O.D. 7.65" / I.D. 4.92 1.41 11443.05 Baker "Seal Bore Extension" O.D. 6.25" / LD. 4.75" 19.22 11444.46 Crossover Pu 5-112" H d 563 X 5-1/2" H d 521 O.D. 6.08" / I. D. 4.90' 3.86 11463.68 Jts 177 to 195 19 Jts :5-1/2" 15.5 f,_L-80, H dril 521 Blan,k,Casin 777.56 11467.54 Jts 120 to 176 57 Jts 5-1/2'' 15.5. f L-80 :H drif 521- Slotted Casin` 2337.29 12245.10 XO Sub 5-1/2" H d 521 X 5-1/2" BTCM 1.64 14582.39 Jts 45 to 119 75 Jts 5-1/2'' 15.5' f L-80 -BTCM '.Slotted cs with for ue rin s 3145.90 14584.03 Jts 1 to 44 44 Jts 5-1/2"; :15.5 f L-80 :-BTCM Slotted Casin 1838.48 17729.93 XO Sub 5-1/2" BTCM X 4-1/2" BTC 1.41 19568.41 4-1/2''x, 11.6' ' f;'L-80 BTCM'Blank Casin' with for ue rin 43.12 19569.82 4-1/2", 11'.6 f, L-80BTCM' Blank'Casin gran a eeled w/-tor iri 43.54 19612.94 Btfm of Shoe =__> 19656.48 19656.48 19656.48 B Lat TD 19 708' MD/ 3 156' TVD 19656.48 5-1/2" Shoe 19 656.48' MD / 3156.3' TVD Rat Hole 51.52' 19656.48 19656.48 MLZXP Oriented to 26 de .Left of hi h side. 19656.48 19656.48 To of ZXP to to of Helix inside to of liner = 10.73' 19656.48 To of ZXP to HR collet Profile inside to of liner = 12.52' 19656.48 To of ZXP to ML Anchor collet Profile = 12.83' 19656.48 19656.48 19656.48 Ran out of do wt 10915' MD. Rotated to bttm. 19656.48 Hole Fluid: 50/50 SFOBM 8.8 w/ 1% - 776 from TD to Window 8< 19656.48 -- 50/50 SFOBM 8.8 w/ 1% - 776 tube from window to surface. 19656.48 19656.48 S iral lider Centralizers f/ 19,564' to 11 996' 182 Floatin 19656.48 19656.48 19656.48 Remarks: Tor ue Instructiol Tor ue H d 521= 6000 ft-Ibs BTCM w/ for rin s= 5900 ft-Ibs , up wt 240K BTCM ~ 4500 ft-Ibs Av 10 'ts to diamonds, 4-1/2 BTC w/tor ue rin s 4500 ft-Ibs. Dn Wt oK Total Foota a of each = 3114.85' H d 521, 3145.90' BTCM w/ Tor Rin s, 1838.48' BTCM Block Wt 7oK Centrilizers :Run=5.5" X 8-1/4" S iral lider er'oint floatin on Joints #1 thru # 182 =Total ran 182 Tor ue Rin s In : 45 thru 119 =Total used 75 Rot Tor ue TD 21 k ft Ibs Rot wt 142K 1 J-174 B Lateral Geological Sidetrack PB2 Page 1 of 2 Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Tuesday, December 11, 2007 12:17 PM To: Maunder, Thomas E (DOA) Cc: Hartwig, Dennis D Subject: RE: 1J-174 B Lateral Geological Sidetrack PB2 - (PB1 DETAILS) Attachments: Patrick.J.Reilly@conocophillips.com.vcf Tom, c7 t3 `~ - ~y~ The ;:~ ~ ~ k (f J=1 T4' B: t•:: ~ P~'t~t~' , . • Well: 1 J-174 • Rig: Doyon 15 • Date: 12/4107 Time: 2200 hrs • Last Casing: Intermediate (12,080') • AAD of abandoned section: 15,100' -15,308' After reaching 15,308' we started experiencing tool communication problems. An analysis of the survey data indicated that we had a 17.75 degree dogleg over a short distance. We had several concretions in the 200' section before the communication problems started. We believe the dogleg was causing the communication problems. After we pulled a couple of stands above the dogleg, we had no communication problems. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to co{lapse. {f you need any add~ional information please contact rrre. Thanks. Pat Reilly ConocoPhi(lips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J. Reilly@conocophillips.com From: Maunder, Thomas E (DOA) [mailtoaom.maunder@a}aska.gov] Sent: Monday, December 10, 2007 3:26 PM To: Reilly, Patrick J Subject: RE: 17-i74 B Lateral Geological Sidetrack PB2 Pat, On closer read, you message would indicate that this is the 2"d geological sidetrack. I don't find any message regarding PB1. Could you elaborate? Thanks, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) 1/23/2008 1 J-174 B Lateral Geological Sid, etrack PB2 Page 2 of 2 Sent: Monday, December 10, 2007 3:19 PM To: 'Reilly, Patrick J' Subject: RE: 1J-174 B Lateral Geological Sidetrack PB2 Thanks Pat. I will place a copy of this message in the file. Tom Maunder, PE AOGCC Prom: Reilly, Patrick ] [mailto:Patrick.].Reilly@conocophiltips.com] Sent: Monday, December 10, 2007 9:42 AM To: Maunder, Thomas E (DOA) Cc: Narhn-ig, Dennis D Subject: 1J-174 B Lateral Geological Sidetrack P62 Tom, The details of the sidetrack are as follows: • Well: 1 J-174 • Rig: Doyon 15 • Date: 12/8/07 • Time: 1745 hrs • Last Casing: Intermediate (12,080'} • MD of abandoned section: 17,660' -18,141' We exited the bottom of the formation due to geologic uncertainty. We have started to make a low side sidetrack to the Left. We are planning to isolate the sidetrack by allowing it to collapse. if you need any additional information please contact me. Thanks. Pat Reilly ConocoPhiltips Alaska DriNing & Wells (907) 265-604$ WORK (907) 244-555$ CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J. Reilly@conocophil[ips.com «Patrick.J.Reilly@conocophitlips.com.vch> 1/23/2008 1J-174 B Lateral Geological Sidetrack PB2 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Monday, December 10, 2007 3:26 PM To: Reilly, Patrick J Subject: RE: 1J-174 B Lateral Geological Sidetrack PB2 Pat, On closer read, you message would indicate that this is the 2"d geological sidetrack. I don't find any message regarding P61. Could you elaborate? Thanks, Tom Maunder, PE ~v~ - ~~~ AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, December 10, 2007 3:19 PM To: 'Reilly, Patrick 3' Subject: RE: iJ-174 B Lateral Geological Sidetrack PB2 Thanks Pat. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Reilly, Patrick) [mailto:Patrick.}.Reify@conocophillips.com] Sent: Monday, Deceml~r 10, 2007 9:42 AM To: Maunder, Thomas E (DOA} Cc: Hartwig, Dennis D Subject:. i.~-174 B iral GeolCai Siti~adc~ P~ Tam, The details of the sidetrack are as follows: • Wetl: 1J-174 • Rig: Doyon 15 • Date: 12/8/07 • Time: 1745 hrs • Last Casing: Intermediate (12,080'} • IUID of abandoned section: 17,t31~' -18,141' We exited the bottom of the formation due to geologic uncertainty. We have started to make a low side sidetrack to the left. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhiltips Alaska Drilling & Wells 1/23/2008 1J-174 B Lateral Geological Si~ ack PB2 Page 2 of 2 (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J. Reilly@conocophillips.com «Patrick.J.Reilly@conocophi{lips.com.vcf» 1/23/2008 I J-174 Intermediate Cement J~ S Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Friday, November 30, 2007 10:23 AM To: Maunder, Thomas E (DOA) Subject: 1J-174 Intermediate Cement Job Page 1 of 2 Attachments: 1J-174 10 75 x 9 625 Csg.pdf; 1J-174 log.pdf; 1J-174_112907.pdf; 1J-174_112807.pdf Tom, I thought I would keep you in the loop on our Big West Sak 1J-174 intermediate job. Intermediate hole was drilled to 12,089'MD / 3206'TVD with rotary steerable system. After changing and testing top upper RAMS to 10-3/4" the tapered intermediate casing (73.2# 10-3/4 x 40# 9-5/8") was successfully run with shoe at ~ 12,079'MD (see attached Drag Plot). «1J-17410 75 x 9 625 Csg.pdh> The planned 2 stage cement job began on 11/28/07. The first stage cement job went very well with approximately 172.5 bbls (12.Sppg) pumped and planned TOC at ~ 10,000'MD (Top of West Sak 11,270'MD, Stage collar ~ ~ 8,990'MD). Full returns were observed as well as full reciprocation throughout the entire lst stage job. Plug bumped at calculated strokes and floats held. We are very confident that the first stage was very successful and that the West Sak is successfully isolated. The 2"d stage did not proceed as well as the 1St stage. The stage tool was opened successfully following the 1St stage. Circulation continued as clabbered up mud and lst stage mudpush was observed at surface. (Observing Mud push at surface was expected). No lst stage cement was observed at surface during circulation. Circulation continued for approximately 3 bttms up until good mud was all the way around the system. Displacement of the 2"d stage cement (166 bbs ,12.Sppg cement) appeared normal with steady returns and lift pressure throughout the job. Planned TOC was ~ 6,750' MD (500' above Ugnu C). Approximately 4750 strokes into the planned 5990 stroke displacement, CW100 and MudPush were observed at surface, possibly indicating that we may have cement in the IM x Surface annulus. Continued displacement and bumped plug at planned 5990 stroke displacement then pressured up to 2780psi to close stage collar -held pressure far 10 minutes then bleed off with no flow back confirming stage collar closed. While no cement was observed at surface during displacement of 2"d stage, it is highly likely that the 2"d stage job experienced significant channeling. The Ugnu portion of the well (Top Ugnu 7,250'MD, Base Ugnu 10,611'MD) which we would like to have covered with the 2°d stage has no significant hydrocarbon bearing zones as described by our West Sak operations Geologist Jeff Harrison. (see attached MD log) «1J-174 log.pdh> Considering that cement may be inside the surface annulus, we proceeded ASAP to flush annulus 1 /23/2008 IJ-174 Intermediate Cement J~ Page 2 of 2 with water then diesel and then finally kill weight mud. The annulus was successfully flushed and we are proceeding ahead as planned, pending any required cement remediation to ensure coverage of the Ugnu. I am not confident that remedial cement work will garner any better results than our initial 2°d stage attempt and may end up creating additional problematic wellbore issues. In addition I have attached the daily reports for your review and would appreciate any suggestions or comments. «1J-174_112907.pdf» «1J-174_112807.pdf>> Thanks & Regards Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 1/23/2008 1J-174 -- 10-3/4" x 9-5/8" Intermediate Casing Drag 390 370 350 330 310 290 270 ~, 250 .c Y -d 230 ~o 0 Y $ 210 x 190 170 150 130 110 90 70 50 -- ----~ - Csg Strinsr Heel ' 4,000' - 10 3/4" 73.2 Ib/ft, L-80, BTC-M LSND , _ _ _ 8,000' - 9-5/8", 40.0 Ib/ft, L-80, BTC-M ~ Mud Wt = 9.2 ppg • PU Actual 3,500' of Lo-drags in Surface Interval PV/YP = 11114 5256' of Hydroforms in Openhole Interval _ __ ~ - -Pre-Well Model PU 0.26/0.32 Actual PU 0.24/0.27 ~' / • • SO Actual o o r Actual SO 0.25/0.30 '~ ~ / Pre-Well Model SO 0.35/0.35 '~ V ~ • ---- - I ~ ~ / ~ , M ~ ` ~ / ~ • ~ • • i i i ... _ ~ _ csu ''' cB u ~ ~ i -- --- --- --- --- •BlockWt 75kips- --- --- -- -- --- 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 Measured Depth, ft ROP Deep Phase Res. fph ohmm 500.00 0.00 0.20 200.00 Gamma Ray Depth S hallow Phase Res. Bit Depth TVD api ft ohmm ft 0.00 150.00 ~ ~ 20 0.20 20 0.00 3400.00 3200.0! - - ~_ ,~ ~ . r ' - 6100 ---- ---- --- --- ---- ~: ~....... ~~ . ' :: 6200 -----• ------ -- --- ---- - - - _ ... ~... ..... `~: ~~ ..: J..... c --~ " " ' - - 300 :::: ....... ~..... ~:::: ~..... ~ ' 400 -- --- ~ ::: - --- ---- ~... y ~ 6500 - -- ----- ------- --- ---- - - -~-: ' - 6600 --- ---- ~: ---- ---- ----- ~.~ r. t { ~ t -s' 6700 . - ~_ _ _ _. . _ _- 6800 --- ---- --- -- -- ----- ~Y ~ ~ ..:::: 6900 --- ---- - -- ------ ------- --- `~':::: ~-- --~ • --- 7000 .~ __ _ -.. __ -- ~„~: --- 7100 i ---- ~- 7200 ~ .. - ~"~ ..::: --~- ~ ~ ~- - - 300 ::: - --- ..... ~" " " 7400 I :~,..... .... .~ .... i ~~; ~ --- ~ - 500 ~ - ~~ r----~- ~` ~~ ~~- -- ~ : r'te` r - 7600 I ~- `~ 7700 -- :: ~- -- : - - 7800 y _~_ --- - z -- 7900 - ::: - -- 8000 .. ~ .-.: : ~..:::: 8100 8?00 8300 8400 8600 8600 8700 8800 8900 9000 9100 __ ~ _ _ _ __ 9200 ------ ------- ------- --- --- _....._-. --___. 9300 -----. ------- -._____. --- --- 9400 ------ ------- ------- --- --- 9500 ------ ------• ------- --- ----- 9600 ------ ------- ------- _._. 9700 ------ ------- ------- --- ---- --- ---- 9800 ------ ------• ------- _ ; _ __t. . 9900 ------ ---- - ------- -- ---- --- --- 10000 ------ ------- ------- --- ---- 10100 -----• ------- ------- --- ---- 10200 ------ ------- ------- ~~- - __ _ • _ - _ __ --- -- L 10300 - ----- ~' T~ ~~ ~ --- -- - c. 10400 -- ----- -- -- --- 10500 --- ----- _ r r~ ~_ ~-= - - ~ . t-- 10600 ------ i - -° 10700 ---- ----- ?_ y __.._____ _ __.___._._.__. __~-. --- --- 10800 ----- ----- 3 -__ __ . _~_ _ .~---. _. _ _ ___. -- - ~_ 10900 ---- ---- ~ ~ - --- ----t- 11000 ----- ------ t - r r -- _~ 11100 --- ------ - -.'- - 11200 ----- ---- s -- ~~ 11300 ---- ----- --- --- ~ t • • lr'' Page 1 of 2 ConocoPl~llips Daily Drilling Report Printed: 11/30/2007 Wetlview Web Reporti~+g Re ort Header Well: Report Date: Job Type: Network: Report # Daily Cost: Cum Cost: 1J-174 11/29/2007 DRILLING 15 $592,740 $4,138,366 ORIGINAL Field: Rig Name: Rig Supervisor: Rig Accept: Rig Release: WEST SAK DOYON 15 Dan Lowe/Scott 11/15/2007 2:30:00 Lapiene/Fred PM 24 hr Summary: Displace 1st stage cement. Bumped plug at 7830 stks (922.2 bbls). Bumped and pressured to 920 psi, 500 psi over final pumping pressure. Pressured up to 2470 psi to open stage collar. Collar opened and established circulation. Loaded cement head with second plug and pumped 2nd stage cement job, 166 bbls. Displaced cement at 5 bpm. Slowed pumps to 3 bpm, 1050 psi and bumped plug at 5990 stks (705.5 bbls). Saw contaminated mud and spacers at surface 560.5 bbls into displacement. Staged pressured up 1750 psi, then 2780 psi to close stage collar. Close hydrill and flushed 13-38" x 10-3/4" annulus with 177 bbls water at 1.5 bpm 990 psi , 175 bbls diesel at 1.5 bpm, 1050 psi. Bull head 165 bbls 9.2 ppg mud into 13-38" x 10-3/4" annulus at 1 bpm, 1020 psi. Summary CrD_ Rpt Time: Bleeding off 13-3/8" x 10-3/4" annulus. 24 hr Forecast: Break stack and set emergency slips. Rig down cementing equipment & 10-3/4" pipe handling equipment. Time I_o From To Duration Phase O Gode Subcode Time Activi 00:00 03:30 3.50 INTRM1 CEMENT DISP P Displace cement using rig pumps at 5 bpm, 250 psi. Reduce rate to 3 bpm while passing the stage collar. Return to 5 bpm. At 100 bbls from bumping plug slowed to 3 bpm until bumping. Bumped plug at 7830 stks. Pressure up to 920 psi, 500 psi over final pump pressure. Held for 2 min. Bleed off pressure and checks floats, floats held. 03:30 06:00 2.50 INTRMI CEMENT CIRC P Pressure up to 2470 psi to open hydraulic stage collar. Collar opened and pressure dropped to 475 psi. Begin circulating at 5 bpm. Appeared to be seeing losses and slowed rate to 3 bpm, 410 psi. Returns stabilized. Saw Mud Push followed by clabbered up mud returns to surface. 06:00 08:00 2.00 INTRMI CEMENT CIRC P Increase rate to 5 bpm 360 psi for second bottoms up. Saw more clabbered up mud at surface. Circulated until ood mud was all the wa around.. 08:00 08:30 0.50 INTRM1 CEMENT SFTY P PJSM - 2nd stage cement job. 08:30 09:00 0.50 INTRM1 CEMENT PULD P Stopped circulation, bleed off pressure. Break open cement head and load second plu . 09:00 10:45 1.75 INTRM1 CEMENT OTHR P Pump 10 bbls CW100, shut down and pressure test lines to 3000 psi. Pump remaining 90 bbls CW100. Pump 100 bbl Mud Push. Mix and pump 166 bbls (12.5 ppg) cement @ 5 BPM. Drop Plug and kickout with 10 bbls of water. Page 1 of 2 • C~ 10:45 13:45 3.00 lNTRM1 CEMENT DISP P Displace cement using rig pumps at 5 bpm, 250 psi. Saw CW100 and mud push at surface 4750 - 5990 stks into displacement. At 100 bbls from bumping plug slowed to 3 bpm, 1050 psi until bumping. Bumped plug at 5990 stks. Pressure up to 1750, then 2780 psi to close stage collar. Held pressure for 10 min. Bleed off pressure and check for flow back - no flow. 13:45 14:00 0.25 INTRMI CEMENT RURD P Flush stack and rig up to flush annulus. 14:00 20:45 6.75 INTRM1 CEMENT CIRC P Flush 13-318" x 10-3/4 annulus with 177 bbls of water at 1.5 bpm, 990 psi and 175 bbls of diesel at 1.5 bpm, 1050 psi. Monitor annulus pressure. Sim ops -load pipe shed with new 5" drill pipe, clean pits, change out expansion boot at suction boot on mud pump #1, check rechar eon ulsation dam eners. 20:45 22:00 1.25 INTRM1 DRILL OTHR P Continue loading pipe shed with new 5"drill pipe and cleanin pits. 22:00 22:15 0.25 INTRM1 DRILL SFTY P PJSM - bullheading into 13-3/8" x 10-3/4 annulus using ri umps. 22:15 00:00 1.75 lNTRM1 CEMENT Load LSND mud into pits and bullhead into 13-3/8" x 10-3/4 annulus using rig pumps. Pumping 1.5 bpm. Shut in and monitor pressure. Bleed back, open annular reventer and observe well. Mud Checks :Time Type Source Depth Densi ~ F Vis. PV YP Gels HTHP MBT FL Temp 11:00 Water Based Mud Out 12,089 9.1 7.7 40.7 7 11.00 3.00 6.00 7.00 2.10 22:00 Water Based Mud Out 12,089 9.1 7.5 36.0 7 11.00 3.00 6.00 7.00 2.10 Page 2 of 2 • Page 1 of 2 ~or~o~~ Pl~ill~p~ Daily Drilling Report Printed: 11/30/2007 Re rt Header . Well: Report Date: Job Type: Network: Report # Daily Cost: Cum Cost: 1J-174 11/28/2007 DRILLING 14 $253,582 $3,545,627 ORIGINAL Field: Ria Name: Ria Supervisor: Ria Accept: Ria Release: WEST SAK DOYON 15 Dan Lowe/Scott 11/15/2007 2:30:00 Lapiene/Fred PM 24 hr Summary: Finish running 10-3/4" x 9-5/8" casing. Circulate and condistion mud for cement job. Rig up cementing equipment. Pump CW100, Mud Push, cement and begin displacement. Summary CcD_ Rpt Time: Circulating and conditioning mud for 2nd stage cej 24 hr Forecast: Pump 2nd stage cement job. rig down cementing equipment & 10-3/4" pipe handling equipment. Break stack and set emergency slips. 'f ime L From To Duration Phase O Code Subcade Time Activit 00:00 02:00 2.00 INTRM1 CASING RNCS P Run 48 joints 9-5/8" casing. 02:00 04:00 2.00 INTRM1 CASING CIRC P Circulate bottoms staging up to 5 bpm, 310 psi 04:00 05:00 1.00 INTRM1 CASING RNCS P Run 29 joints 9-5/8" casing. 05:00 05:45 0.75 INTRM1 CASING RURD P Rig down 9-5/8" handling equipment. Make up 10-3/4" cross over. 05:45 06:30 0.75 INTRM1 CASING CIRC P Circulate while removing 9-5/8" handling equipment from ri floor. 06:30 08:15 1.75 INTRM1 CASING RNCS P Run 25 joints 10-3/4" casing. 08:15 10:00 1.75 INTRM1 CASING CIRC P Circulate bottoms staging up to 5 bpm, 370 psi 10:00 12:00 2.00 INTRM1 CASING RNCS P Run 36 joints 10-3/4" casing. 12:00 13:45 1.75 INTRM1 CASING CIRC P Circulate bottoms staging up to 5 bpm, 500 psi. After circulations PU=300k, S0=150k 13:45 16:15 2.50 INTRM1 CASING RNCS P Run 36 joints 10-3/4" casing to TD. Calculated displacement=222.5 bbls, actual dis198 bbls, lost 24.5 bbls. At TD PU=360k, S0=140k. 16:15 20:00 3.75 INTRMI CASING CIRC P Circluate and condition mud for cement job. Circulate at 5 bpm, 500 psi, reciprocate pipe 20'. PU=360k, S0=145k 20:00 20:30 0.50 INTRM1 CEMENT PULD P Pick up and make up cement head. 20:30 21:30 1.00 INTRM1 CEMENT CIRC P Circluate and condition mud for cement job. Circulate at 5 bpm, 500 psi. reciprocate pipe 20'. PU=360k, S0=145k 21:30 21:45 0.25 INTRM1 CEMENT SFTY P PJSM -cementing intermediate 1st stage 21:45 23:15 1.50 INTRM1 CEMENT OTHR P Pump 10 bbls CW100, shut down and test lines to 3000 psi. Pump remaining 90 bbls CW100. Pump 100 bbl Mud Push. Stop and break cement head, load 10'-3/4" x 9-5/8" Davis-L nch Plu . 23:15 00:00 0.75 INTRM1 CEMENT PULD P Mix and pump 172.5 bbls (12.5 ppg) cement @ 5 BPM.w/ Dowell. Dro Plu and kickout w/ 10 bbls H2O Page 1 of 2 • • AAud Checks Time Tvpe Source Death Densi ~H E Wis. PV YP Gels HTHP MBT FL Temp 10:00 Water Based Mud In 12,089 9.2 8.6 45.4 11 14.00 7.00 13.0014.0 4.20 20:00 Water Based Mud In 12,089 9.2 7.4 36.9 7 10.00 3.00 7.00 11.0 3.20 Rage 2 of 2 1J-174 Surface Cement Job s Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 20, 2007 3:58 PM To: Hartwig, Dennis D Subject: RE: 1 J-174 (207-143) Surface Cement Job Thanks Dennis_ Not a problem. From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, November 20, 2007 3:35 PM To: Maunder, Thomas E (DOA) Subject: RE: 1]-174 (207-143) Surface Cement Job Report. for yesterday attached - I will copy you on today's report ASAP Dennis From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 20, 2007 3:29 PM To: Hartwig, Dennis D Subject: RE: 1J-174 (207-143) Surface Cement Job Thanks Dennis. Could you also send the CPAI report or the daily summary? Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, November 20, 2007 3:07 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-174 (207-143) Surface Cement Job Page 1 of 4 Tom, Initially tubing stopped at 160'md and was worked another 10'. When pumping was initiated in tubing (at I70Tmd} it took approximately 480psi to blow plug from end. bead Cement (~10.79ppg} was circulated during. top job. During the initial jab red dye was pumped but was not observed at surface. Contaminated mud was obser~Fed at surface. Attached aze the cementing operations reports...Dennis From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 20, 2007 2:38 PM To: Hartwig, Dennis D Subject: RE: iJ-174 (207-143) Surface Cement Job Dennis, What was encountered at 170'? Was it not possible to go deeper? Was lead cement circulated from there? During the initial job, was any of the mud wash seen? Was any red dye used as a "flag? I request that you send the cementing operations report. 1/23/2008 1 J-174 Surface Cement Job Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, November 20, 2007 2:29 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-174 (207-143) Surface Cement Job Tom, 1 J-174 top job went well. - Cement in place at l 1:24am . - One inch tubing ran to 170'md in annulus. - After flushing annulus pumped a total of 45.7 bbls cr 1.7 bpm. - Good returns throughout. Regards Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 From: Hartwig, Dennis D Sent: Tuesday, November 20, 2007 1:32 PM To: 'Maunder, Thomas E (DOA)' Subject: RE: 1J-174 (207-143) Surface Cement Job Tom, • Page 2 of 4 Lift pressure increased by approximately 425psi during full return displacement (1St 1500 strokes pumping ~ 7 bpm~177bb1s). After loss of returns were observed, lift pressure continued to increase by approximately 250 psi (2nd 2540 strokes pumping ~ Sbpm~300bb1s). The last 90 bbls or 760 strokes the lift pressure did not change. We will continue to keep you apprised of the situation...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 1/23/2008 1 J-174 Surface Cement Job From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 20, 2007 9:58 AM To: Hartwig, Dennis D Cc: Thomas, Randy L; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: iJ-174 (207-143) Surface Cement Job Page 3 of 4 Dennis, When difficulties are encountered with cementing surface casing, contacting the NS Inspector is proper. Contacting either myself or the Inspector's supervisor is equally important In this case, it would appear that proceeding to do a 1 ~ job is likely the only possible action since as I understand no port collar was included. I presume that the lift pressure increased as the job proceeded. Did the lift pressure continue to increase after retums were lost? Please keep myself and the Inspectors informed as to the progress of the operations. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, November 20, 2007 9:47 AM To: Maunder, Thomas E (DOA) Subject: 1J-174 Surface Cement Job Tom, The 1J-174 surface cement job did not go as planned last night. VVe notified your man on the slope last night, but I thought I would fill you in on the specifics. After drilling the 16" hole to ~ 4,030'MD and landing 13-318" on hanger at ~ 4,020'MD, we commenced pumping the cement job as follows; • 75 bbl Pre-flush • ?5 bbl MudWash • Drop Bttm Cmt Plug • 602 bbl(740 sx) of 10.7ppg AS Lead • 106 bbl (245sx) Of 12.Oppg LiteCrete Tail • Drop top plug and displace 1500 strokes into the 4800 stroke displacement started losing returns. Picked up off casing hanger and regained full returns, however was not able to land casing back on hanger. Increased quantity of ~=ood noticed coming over shakers during displacement_ 1/23/2008 1J-174 Surface Cement Job • Page 4 of 4 Lost full returns at 2,000 strokes -continued pumping until plug bumped. Calculated theoretical TOC was 16 bbl from surface ~ 213' Contaminated mud samples at surface but no cement. Currently -Rigging up for top job -running 1" Hydril pipe down annulus to pump cement. If questions or concerns arise please contact me. Regards...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fa.Y :907-265-1535 1 /23/2008 ~onotoPl~illips Page 1 of 2 Daily Drilling Report Printed: 11/21/2007 ti+Eit,•±twr YVfb ReDnrtifrg Re ort Header. Well: Report Date: Job Tvpe: Network: Report # Daily Cost: Cum Cost: 1J-174 11/20/2007 DRILLING 6 $185,401 $1,827,125 ORIGINAL Field: Rig Name: Rig Supervisor: Rig Accept: Riq Release: WEST SAK DOYON 15 Mike 11/15/2007 2:30:00 Thornton/Dan PM 24 hr Summary: Finsh displacing surface cement job. Nipple down diverter. Set emergency slips. Mix and pump 47.5 bbls of cement for top job. Weld on landing rig, nipple up and test well head adapter to 1800 for 10 min and wellhead to 5000 for 10 min. Summary CcD Rpt Time: 1 Nipple up and test BOPE 24 hr Forecast: Nipple up and test BOP. Pick up BHA #2, 9600 geopilot and 12.25" bit. RIH, tag cement, perform casing test and LOT. Time Lo From To Duration. Phase O Code Subcode Time Activit 00:00 00:45 0.75 SURFAC CEMENT DISP P Continue displacing cement at 5 bbls/min, 1090 psi & no returns. Slow to 3 bbls/min at 4740 strokes, 990 psi. Bumped plug at 4794 strokes. Pressure up to 1500 psi for 15 minutes. Bleed off and checked floats -Floats holdin .417 bbls total losses durin cement 'ob. 00:45 03:15 2.50 SURFAC CEMENT RURD P Nipple down and prepare to set emergency slips. Blow down lines, rig down cement head, clear rig floor and drain stack. 03:15 05:45 2.50 SURFAC CEMENT OTHR P PU stack, install slips, cut casing and lay down excess. Sli s set with 82k over up wei ht of 290k. 05:45 07:30 1.75 SURFAC CEMENT OTHR P Finish nipple down of surface equipment. Sim ops - load and strap 126 ~oints of 5" drillpi a in pi a shed. 07:30 08:15 0.75 SURFAC CEMENT OTHR T Cut 3" x 14" hole 5" from top of conductor per Vetco rep for to 'ob. 08:15 10:00 1.75 SURFAC CEMENT TRIP T PU &RIH with 1" hydrill. Tagged at 170'. Pressure up to 480 psi to clear pi e. 10:00 10:45 0.75 SURFAC CEMENT CIRC T Circulate 35 bbls of water, 2 annular volumes, at 2 bbl/min. 10:45 11:15 0.50 SURFAC CEMENT OTHR T Pump 2 bbls of lead water followed by 47.5 bbls of 10.7 ppb cement at 1.7 bbls/min 300 psi. 11:15 12:00 0.75 SURFAC CEMENT RURD T RD cement equipment, blow down lines, flush & LD hydrill. Marked all hydrill used, sending out for cleanin . 12:00 14:30 2.50 SURFAC CASING NUND T Prepare conductor for wellhead adapter. Weld adapter in place. Vetco rep present. Sim ops- clean & clear rig floor, RD casing elevators and long bails. Install link tilt yoke w/new bushings, install short bails and 5" drill pi a elevators. 14:30 15:45 1.25 SURFAC CASING RPTH T Weld patch in conductor. PJSM on moving drill pipe. Move 22 stands of 5"drill pipe from drillers side to off dirllers side old drill pipe). 15:45 21:45 6.00 SURFAC DRILL PULD P Install mouse hole in rotary table and PU 126 joints fo drill pipe from pipe shed. Drift to 2.88". PU 1 joint HWDP for cut & slip drillin line. Pull mouse hole. Page 1 of 2 21:45 23:30 1.75 SURFAC RIGMNT SVRG P PJSM -cut & slip drilling line. Hang blocks, cut & slip 130' of drilling line. Inspect brakes and deadman. Greased drawworks. Sim ops -test well head adapter, 5000 si for 10 min. 23:30 00:00 0.50 SURFAC CASING NUND P Nipple up well head Mud Checks Time Type Source Depth Qensity ~H F Vas. PV YP Gels HTHP MBT FL Tem 12:00 Water Based Mud In 4,030 9.3 8.9 46.4 21 10.00 4.00 5.00 20.0 12.3 21:00 Water Based Mud In 4,030 8.8 9.2 66.2 16 18.00 3.00 5.00 8.00 10.5 Page 2 of 2 s ~ Page 1 of 2 ConoeoPhillips Daily Drilling Report Printed: 11/20/2007 WEdIv/eW Web Reporting. Re ort Header Well: Report Date: Job Type: Network: Report # Daily Cost: Cum Cost: 1J-174 11!19!2007 DRILLING 5 $889,700 $1,637,223 ORIGINAL Field: Rig Name: Rig Supervisor: Rig Accept: Rig Release: WEST SAK DOYON 15 Mike 11/15/2007 2:30:00 Thornton/Dan PM 24 hr Summary: Finish BROOH, download MWD, LD BHA, clear rig floor, RU casing equipment, PJSM, Run 95 Joints of 13-318", 68 IbJft Csg to 4,020' TMD, circ and cond. mud, pump and displace 602 bbl of Lead Cmt followed by 106 bbl of Tail cement, drop plug and displace with rig pumps, lost returns, slow pumps, displace cement until a calculated estimate of cement 16 bbl from surface. Contaminated mud samples were collected at surface, but no cement samples. Prep for top job. Summary ~ Rat Time: RU to pump Top Job 24 hr Forecast: Gut csg and remove excess cut joint, set sNps, cut slots in 13-3l8" casing, RU and run 1" Hydril pipe down annulus, arculate hole clean, pu T+me L Fram To Duration Phase Op Code Subcode :Time `Activity 00:00 02:00 2.00 SURFAC DRILL REAM P Continue BROOH from 1,407' to 600' TMD. No overpull or tight spots while BROOH. BROOH at 600 gpm and 5' per min from 900' to 600'. Estimated 100°lo increase in clay cuttings initially and decreasing to normal cutting returns by 600' tmd (3x bottoms up over that de th interval). 02:00 02:15 0.25 SURFAC DRILL TRIP P POOH on elevators from 600' to 360' tmd with hole takin pro er fill. 02:15 04:30 2.25 SURFAC DRILL PULD P Download EM MWD tool. Stand back one stand, LD 2 jts of HWDP + Jars of HWDP. Stand back Flex DC, break out bit, LD MWD and motor assembl . 04:30 05:00 0.50 SURFAC DRILL PULD P Finish LD MWD and motor, clear and clean rig floor. 05:00 08:00 3.00 SURFAC CASING KURD P RU casing equipment 08:00 08:15 0.25 SURFAC CASING SFTY P PJSM for running 13-318" casing. 08:15 12:00 3.75 SURFAC CASING RNCS P PU/MU float joints and threadlock same. Check floats. Run 43 joints of 13-3/8", 68 Iblft, L-80, BTC R2 casing, using the Fill-up tool on every joint and "topping off' every 5 joint. Record up and down weights every 10 ~oints. 12:00 13:00 1.00 SURFAC CASING RNCS P Continue running csg to joint 63 at 2,625' tmd with proper displacement. CBU staging flowrate up to 7 BPM, 410 psi with no mud losses. SO weight before = 128K, SO wei ht after = 140K. 13:00 16:00 3.00 SURFAC CASING RNCS P Continue running casing to 4,020' (2,272') without problems while takin pro er dis lacement. 16:00 20:30 4.50 SURFAC CASING CIRC P Circulate and condition mud, staging pumps up to 7 BPM without fluid losses and reciprocating pipe with 10' strokes. Initia{ PU Wt = 285K, Final PU Wt = 260K, Initial SO Wt =Final SO Wt = 155K. Page 1 of 2 20:30 23:00 2.50 SURFAC CEMENT CIRC P Finish conditioning mud. Pump 10 bbl of Pre-Wash, test cement lines to the cement head to 3,000 psi. Continue pumping 65 more bbl of Pre-Flush followed by 76 bbl of Mud Wash. Drop bottom cmt plug and follow with 602 bbl (740 sx) of 10.7 ppg ARCTICSET Lead cement followed by 106 bbl (245 sxj of 12.0 ppg LiteCrete Tail cement pumped at 7.5 bpm. Drop top plug and clear lines with 21 bbl of water. Displace cement with rig pumps at 5-7 bpm while continuing reciprocating with 10' strokes. PU weight while stroking increased from 285K to 290K while reciprocating while SO wt decreased from 135K to 90K. Landed casin in han eras mud ush was at the shoe. 23:00 00:15 1.25 SURFAC CEMENT CIRC P Continue displacing cement at 6 BPM and began losing returns at 1,500 strokes into 4,800 stroke displacement. PU casing off of hanger and regained full returns. Could not get casing back down on hanger. PU casing to 4,012' for emergency slip placement. Continue pumping at 6 bpm and lost full returns at 2,000 strokes. Calculated theoretical TOC was 16 bbl from surface. Reduced pump rate to 4 bpm with no increase in flowback. Increased pump rate to 5 bpm and continued displacement to clear cement from pipe. At report time 4,000 strokes pumped. (Total mud losses Burin displacement = 388.6 bbl). Mud Checks Time Type Source.. Depth De, nsity ~H F us. PV YP its HTHP MBT FL Temq 14:00 Water Based Mud In 4,030 9.3 8.9 57.7 31 18.00 3.00 5.00 20.0 12.3 19:00 Water Based Mud In 4,030 9.3 8.9 46.4 21 10.00 4.00 5.00 20.0 12.3 Page 2 of 2 ~v 20 07 03:47p Doyon-15 907-659- Re art Cementrn fob p hiumher er ~ g Well i]-174 I Client CPAl Field west Sak SIR Plo. 2201063497 Engineer Gary Giersdort i ]ob Type Top Ot,t Country Unlt¢d States Job Date 11-20-2007 ~ 'Time . _ ._. Pressure J Rate - Density 10:45:12 ( ' 10:50:00 ~ -. ( ~ 1 ~ L 10:55:00 I •: 11:00:00 11:05:00 11:10:00 f 11:1s:oo f ~ ~ r~ 11:20:51 hh:mfn:95 ' O.M 1000 Flpm ]008 X000 •.00n 0.00 2.0 +.u G.0 N.n ia0 5.0 10.0 15.0 20.0 M.0 ~um.1oe- ir.M•xi PSI B/M LB/G p.l CemCAT v1.0 .. ~ Messages tic~rt Dumping water FnA WarFr (iasr•t Tnral. Vnl = 1.82 bbl Start Cement slurry R~•c~,r Tnf~l. Vol- F,.2.04 bbl StnnnM M.rndakion End GCment Slurry 11/70/?U07 11:29:51 Nov ZO 07 03:47p ~chh~l~rger well 1J 174 Do~on-15 907-659- p. Z Cementing Service Report Cu~lomer .. ._ ...._.. . I Jab Number .. ..__. . CONOCO PHILLIPS ALASKA, INC 2201083497 scldu,ODefpNt' Locetbn JoD Start Locetlar (leyaf 1 I . Prudhoe Bay, AK 2007-Nov-20 Rtvld j Formellnn N.maType ... ... _ . . WQST SAK 1 r:ounty StxtarProvlnce Beechey Point AK wml Nagler. 0690907028 -- ... .. API / tplw: • ~Nlg Nerrm DrrlkA For Sautes Vle Doyonl5 Oif Lana - Ol/xlgre 7!ona Well Claea tvloll 7ypa pmrlotlon ~t alts Wen MD watt riD in 4,020 ft i 2.6&5 ft BNP~_-.. ~ BNST I OMCT I POnrpxl•.Oraaant pal 46 "F 69 °F ~ psi/ft Casing/Liner pepln,te Slzo,ln ~ 4vaIW11,IWrt I Graoe rnroad 4020 13,08 68 New Exploration TtJbinglOnll Pipe ~ ~~_ ... DAfllnp Fluid TVPe Nmx. Denslly Plaetk Vu Cp Depth, - Slie,•~ ho i Welgnt, flHlt Grade Throrl I Ib/gal ~ 170 1.015 ( 1.2 &arvlcs Line JoD Type Cementirtg Com Top Outside Case _ - Perforations/Open Hole Max, Atwwaa 7uDing Proseurc Mex. AfloweO Ann. Prp•suro ~ wollNOad Cannocdan K 6olewn, To0. n epr Tetd IMenel No. d Shot psi 3 psi 2' Weco -.-. • • I (t Smvhro Me1ruONune . .... .... .. i .. - Otm„•mr .. .. .. .. ... l....... Treatment No_ 52607 Equipment. Materials for Surfaco ~ ~ ~ '^ ~ Cement Pump J-200 Add Hrs $ ; TietN Down Dieptecemefll Yseka Dspen PaEhel type j Materials-3-J100 Tubing 1 bbl I ft Total Cost. $ Approver Code:jabrink _ Tubing Vd. Gaellq Vd, Annatar Vd. OpenMde VOI bbl bbl bbl I bbl CadlyllTuOln9 Seourod.~I •~ ~~ ~ _ 1 Nato volume Cilculetsd prior to CwttsnlMa~l Gasing T00f9 SQY962A JOb un Pnl.sure; psi snore TyPe~ Float saeeere TVpe Pipe Rotated .. Pipe Reciprocatedit/I store Depth: 4020 H root Typs: N0. C•noaltaon: Top P/ua: 1 Itrottan Wuge: t _ - -_._ steps Tool TYPe .._.. Taal Oepm: ft Ceetent Nord Type; Stego Tad Depth: ft TWI Plpa $lye: .... in Job $cheddad r-or: Arrhrad on 4ooatlon: Leave Location: Co1Mr Type: FIDat Tall Pflfe Daplh: ft ~ 11/2012007 7:00 I 2007-Nov20 7:00 2007-NOV-20 13:00 Gtr p°Ptn= 3838 ft s4: Teta1 volt hbl Date Time TreMlno Oaneny MM IW7E MM STG MM TOTAt o o JI/eggay@ Prsswro za Ix cock i I P~ I ItUpal DDVmIn nnl bbl 0 , o . ~._.....---..._ _.... 2007-Nov-20 _....... . ~ 10:45 -179 8,39 I 0.0 0.0 0.0 ~ 0 ~ 0 2007-Nov-20 10:45 -179 8.40 0.0 0.0 0.0 0 - 0 _ ~- 2007-NOv-2Q 10:45 Start Pumping Water 2007-Nov20 10:47 -179 8.40 0.0 0,0 0-0 0 0 . _ .._ , 2007•Nov-20 10:48 -179 8.40 0.0 0.0 0.0 0 - ~ 0 2007-Nov-20 10:51 ' 191 8,a0 1.7 0.9 0,9 0 0 2007-Nov-20 10:52 ~ i End Water 2007-Nov-20 10:52 166 8.32 ~ 0.0 t .7 1.7 0 0 2007-Now-20 10:52 ... .._, _ Reset Total, Vol = 1.82 bbl 2007-Nov 20 70:52 -161 8.28 0.0 1.7 1.7 0 0 2007•Nov-20 10:52 ~ Start Cemenf•S1urry I 2007-Nov-20 10:52 -166 8.26 0.0 . •..._• .. 0.0 1.7 0 0 2~7-Nov-20 10:53' -166 8,66 0.0 0.0 7.7 0 0 2007-Nov-2D 10:55 , 109 11.16 7.9 1.3 3.0 0 0 2007-Nov-20 10:571 352 i 10.76 2.0 5,1 6.8 j 0 _ 0 2007•Nov20 70:59' 205 10.74 2.0 9.0 10.7 0 0 2007-Nov-20 11:01 228 t 0.77 1.9 12.8 , 1 a, 5 0 0 f 2007-NOv-20 11:03 168 10.74 1.9 18.7 _ 16.4 _ _ 0 0 2007-NOv-20 1 t:Ob 210 10.75• • •- 1,$J 20.5 22.2 0 0 ....._........ . ....... 2007-Nov-20 _.. 11:07 ._ __ . 233 1 D.79 1.9 24.3 26,1 0 I O , 2007-NOV-20 ; t t :09 I 201 10, 79 1,9 28.2 29.9 0 0 2007-NOv-20 ~ 11:11' 242 10.79 1,9 32.0 33,7 _. 0 0 No~xn,xrnivvRra va.ata.sR •• _ ~~ Pogo 1 oft Nov 20 07 03:47p Doyon-15 907-659- p.3 .. . weu Free ... 9xvfce Date CuetaTler Jee Number t J s17A I Wf $T SAK ~ p~:I74 Nw-ZO I CONOCO PMKLIP^u ALAuKA, fNC .- I 22010Ha447 1IM RATE .-~ Oeneey ~.~ DatO I Tlrtle 1teM1^9 . NIM STG eax TOTAL ._.. - C 0 1 Message i preb+fure I i 24 M Clad ( pal ~ ImaM ~ hWmin Ohl DW ~ D 0 2007-Nov-20 11:13 155 ~ 10.75 i L9 35.9 I . 37.6 0 0 _..._I -_ - ~ --... , 2007-Nov-20 .. 11:15 z97 10,77 1.9 . 39-7 ~ 41.4 0 0 2007•Nov-?.0 11:17' 17$ __ 10.79 ~ 2.0 43.E 45.3 0 0 ,_,- 2007-Nov-20 11;19 187 11.32 1.9 47,4 49.2 0 0 2007-Nov-20 11:19 228 11.36 2.0 48.1 49.8 0 0 -_.. - 2007-Nov20 ~ _. 11:19 .--- .... .. , . ,. ..r... ResetTOtal, Vol ^ 62.Oa bbl Rost JoD Summary Average Pump Rates, bpm ~ Volume of Fluid Injected, bbl = Slurry N2 mud BAe^ImumRete YoielSlurry Mud Spacor N2 I ~ I ~ 1 I I I _... . Treating Pressure Summery, psi Breakdown Fluid Maa4twnl Clnd Ayo-t•9e Bugg Ph~p to &eekAown volume Density 1300 I 500 I 1 . ~ I .._ bbl I Ib/gal -... .._ _.-.. ......---~ ~ AYq. N2 PoreaM I Oosiensd 91uny Volume oleplecnme,n I MR>• werer ramp ~ ( Cement CIrCIlletwd to Surface? VOIYmo 150 bbl ~ bbl ~ bbl 65 °F ~ ~ I weeMd Tnru Parrs 'ra ft Cus(erry,r or Autborlsed Reprosa,wd„e 1 ScelurW~erper 5upwviwr .,, -Mike, Thornton. ,) ._..-_. ..--- Giersdo~f, Gary I I.. cuculatlonLO.e (t/I JoDComplsted Nov zo,zoui wRSS v3.411-$N Page 2 of 2 ~v ZO 07 O3:48p chiurnhergcr Doyon-15 907-659- p.i Cementing fob Report C2mCATv1.0 ~ Well 1J-17a Client CPAI II Field Wes[ Sak I 5IR No. 2201083435a Engineer Gary Giersdorf ! fob Type Surface Country United States I lob Date 11-19-2007 „Time y pressure Rate I Density Wellhead Pr ~ Messages ! z0:07;sG . ~ stare ]ob r 20:28:OOI . .. ' '- zo:as:oo I ~ ~ i l 21:06:00 7.1:28:00 2.l ;x8:00 ' zz:os:oo 22=28:00 z?:8:00 ' 23:OR:00 /' I "' 23:2A:00 2a:4N;OOi ~ , ,~ I Pre~urt Test Lines ,w ~ ~ ~ r _~ ~- L`L _ I~ Vnyy ha.04 S rp , ..-..- t rt um A 9 dS Fnrl W~h ' rrr------~" ~ ~ ~ ! Start Pumping Spacer I "' ~~~ i R 1 I E . _`. t f. I _.' i RrCr~ Tntal, Vol - 75.3G Fnrt Snafwr Dr~~ Rnrmm Pluo Start Mlxing Lead Slung Rrsvr 7nra1. Vnl = 602.tiq~ Fnn I curl Slurry ~ Start Mixing Tall Slurry Fnd Trll Sli~rrv tH An TAn Ph ~~, Rrc.•r Tn-~.I. Vnl r 105.8 Start Displa~emone I~ I f ~ I OO:OR:00~ ~ f, 00:25;14 ~ ' ~ I F~~mplsnl~PmPnr I l _ .___ ~ Stopped Acqul5l[lon ._. _ .. ., u.uo m~u mnn :~aai +uoo soon o.oo a.o o.0 6.o s.o ~n.m :. n ~n.a u.o zo.o ~..o n.im ,nn •roo sno .cool .. ... . hh:mm•s.. ! 11 InierN,eour on•n:wl PSI N/M ~. LB/G ... ... PSS __._._.__._. ~ •~~•~_.~.~11/20/1007 01:03:47 Nov 20 07 03:49p Doyon-15 907-659- p.2 S~~IeI~PP Cementing Service Report Cuetonrer Job Nurrlber CONOCO PHILLIPS ALASKA, INC 2201083435 Wd! Lo~allal (bgai) Sclrlunmsr9sr Leoatlon Job Seers t J 1 74 I Prudhoe I~ay, AK 2007-NOv-19 Flod Fomreden NerrrefTypa Devledon DIt Slzs well un Wall 1V0 WCST SAK - ! in 4,020 ft 2.665 ft CoumY ~ Slete/ProvNloe ~ BNP • • I BHST i BHCT Pore bless. GreMSnl [~echoy Point AK psi ~ 46 °F i 69 °F psi/ft W0^ A1°B1Or 06309070 28 Aot~ VuN: CasinglLincr • I'tlD Nemo DnNad i'cr Sorvlu Vle I Oeplh, h Slzs,, In Wsi~x, ItrNi ~ Grads lteeed Doyonf5 Oil ~ Land i 4020 I 13.38 68 I i Olrghuni TAMP WAIT CIeAS WW1 Type ~ { ~ I New Exploration .. .._......_. .. •. ...__... _ _.._.__.. __... _._., ... .... _.. ... ... .... TubingrOril) Pipe [Mllbp Fluid Typo ~ klea. Deneky l Plmtic Vb cp Depth, Sloe, U Weight, IbHt Grads Thread tb/gal . . ~ Service Lino i i .. .. Jrrp Yypw . ... . .......... ............ Cementing Cem Surtace Casing PortoratJonslOperl Hole plea. AlMrwwe 7yWInfJ Proneuro Ya W Aeovron Ann. Pfoaeun We11Nos0 Gu~norxllon Top, h Flottorr4 A epr No, rd $eAre I TOlat InlervM psi psi 2° worn I n Servlea kreeucdorts Olemder Trr~atmont No. 52575 Equipment, Materials for in , Cement Pump 1st 5Hours-$30358.00 J-200 Add Hts $7893.00 ~ rn,t Down Dleplecomonl Pe ckor Type Peckor Dopnl j Materials-5207583.88-J1 pp Tote! Cost. S 245634.68 Approver Cotie:jabrink ~ Casing 589.5 bbl ft TuDIRII Vd. I CeNnO Vo6 Anrwlar Vol. OparMole Val bbl f 602 bbl 297 bbl 994 bbl Ceelnarrublrrp Secured !~~ ~ 1 Nola Volume Cllcvlalod prier to comendeg ~; Casing Too1S I SQuee~ Job ue Prnseure: Psi .. shoe ryp•: Float . sQurtaae t~rpo PIPe RWMed I .. ... Pipe RACIWACe1etl~.. .. .9tlos Deppll 4020ft Tod Typal Ne. CanrnllZe-e7 Top WtiA: 1 ~9o1[em PIOOAt 1 Stye Tool Type Tod Dsp1h: ft ICSmenl Need Typst Slrrgs Tael DgNH: ft TaY Pipe Sias: • ~ ~ • ~ jn I Job Scheduiod For: Ardvad on LoeaMan: i Lmve LoosMOn; I tabu type: F108t Tell Plpo enplhl fl , 11!1912007 14:00 200'7-NOV-19 14:00 ~ 2007-Nov-7.0 2:00 CoWrDepeh: 3938 R 7otelVal: •~~ -~~ Sw bbl I Date Time Pr er d~ Densiey ' teM RAPE Mle STG MM TOTAL WHP 0 I MCSSagC n m i 24 M dusk Pei ItV0A1 bbllmin DDI Dbl psi 0 j 2007-Nov-1 rJ 20:07 0 8.46 0.0 0.0 0.0 91 0 2007-NOv-19 . 2D:07 -5 B.d7 0.0 0.0 j 0.0 8e 0 2007-NOV-19 20:07 I ..., .. Slag Job 2007-Nov-19 20:09 23 8.46 0.0 0,0 I 0,0 136 0 2007-Nav-19 . 20:11 ~ B.d6 1.2 j 0.1 .. •0.1 ... -65 . 0 .. .. ". ... -__.....•........... 1 _. _.. . 2007-Nov-19 ~ .. •.... 20:13 ... 169 ... .. 8.41 4.1 5.3 5.3 -1 ......... .. 0 20o7-NOV-19 20'15 ~ 18 i 8.41 0.0 10.6 10.8 ~ -56 0 ~ 2007-NOv-19 20:17 Pressure Test lines 2007-NOwt9 20:x7 3026 8.a2 0.0 •10.7 10.7 ~ • • •29513 0 ?.007-Nov-19 7.0:17 3003 8.d1 0,0 10,7 10.7 2933 0 ~ ~ ~ - ~-• 2007-Nov-19 20:19 247 8,41 5.9 13:1 I 13.1 8 D 2007-Nov-19 20:21 298 8.41 5.9 24.8 24.8 63 0 • 2007-Ntty-19 20:23 iS6 8.40 S.9 3G.G 3G6 22 0 2007-Nov-19 20:25 275 8.39 5.9 48.4 48.4 17 0 2007-NDV-19 20:27 , 343 8,39 5.9 60.2 60.2 86 0 2007-Npv-19 20:29 ; 28$ 8,41 5,9 72,0 ~ 72.0 ~ 40 ~ 0 • • 2007-NOv-19 20:31 ; 41 ~ 8.40 I 0,0 76,9 76,9 -33 ~ 0 2007-Nov-19 20:31 ~ ~ ~ Reset Total, Vol = 75.04 bbl . 2007-Nov-19 ........__..._ .... 20:31 ......... .__......_ _.... ........ ~ - ~• ~ ~ .. .. .... ... ~ - ~~ - ~ I Start Pum In Wash ......._-......p._.9.......~_._ _........... . 2007-Nov-19 20:31 41 ' 8.41 0,0 0,0 76.9 -38 0 2007-Nov-19 20:31 41 8.40 0.0 0.0 76.9 -38 0 2007-Nov-19 20:31 I ~ End Wash iuov ~o,roor way v9.a »-sn Pago .1 of 4 i ~ Nov 20 07 03 :490 Doyon-15 907-65 9- p.3 YVell i Field IServ~ca Oats ~ Caaromar jJoe Number 7J 0774 i VtlF ;T SAK I 07991Nnv-ti9 j CONOCO VHILUpS /LLhSKA, INC :Z01D80a35 Dato Tlmo Treautq ! oenetty RIM BATE MM 9TG MM TOTAL ~ WNP i 0 I Mossaga Pfssawa ~ z~ nr dorm psi lbrgd eeumin eel ebl psI O i, 2007-NOw19 z0a1 a1 8.a1 0.0 0.0 76.9 ~a o 2007-Nov-t9 20:31 ~ Start Pumping Spatar 2007-Nov-19 20:31 ~ 9 8.33 0.0 0.0 76.9 -60 0 2007-Nov-19 20:33 14 10.54 0.0 0.0 78.9 -60 0 2007-Now19 20:35 243 10.69 4.6 6.2 63.1 54 0 2007-Nov-19 20:37 188 10.53 5.0 t5.® 92.5 36 0 2007-Nov-19 20:39 165 10.53 4.9 Z5.5 102.4 -1 I 0 2007-Nov19 20:41 192 10.33 5,0 35.4 112.3 _ 8 ~ 0 2007-Nov-19 20:43 201 10.31 5.0 45.3 122.3 22 0 2007-Now19 20:45 96 10.79 3.2 52.9 129.8 4 0 2007-NOv-~ 9 20:47 174 7 0.63 5.0 624. 139.3 31 0 -~---••---._.__.- 2007-Nov-19 ..._.. 20;49 .. _ ._ ......_ _., 150 ...... 10.40 4.7 72.3 1x9.2 -19 0 .. 2007-Now19 20:50 18 ~ 10,52 0_.0 ___76.5____ _153-a -60 ~ 0 2007-Nowt 9 20:50 I Resot Total, Vol = 75.36 bbl 2007-NOv-19 20:51 18 10.52 0.0 i 0.0 153.4 -60 0 2007-Nov-19. 20:51 ~~~~ ~ ~ ~ ~ ~ ~ End Spacer 2007-Now19 20:51 rop Bottom Plug 2007-Nov19 20:51 18 10.52 0.0 0,0 15x.4 -60 0 2007-Nov-19 20:51 18 ~ ~~ ~ ~~ 8.59 ~ _ •_ ~~ 0.0 1.6 155.0 -65 0 2007-NOv-19 20:52 Slant Mixing Lead Slurry 2007-Nov-19 20: 52 18 10.73 0.0 Ii 1.6 155.0 -60 0 2007-NOw19 _ 20:53 _ 224 -~ ~ 10.89 4.9 ! 1,4 156.4 -1 0 . _ --- - _ . . 2007-NOw19 20:55 _ 545 1 0.76 7.5 15.4 170.a I 95 0 . -------_... 2007-NOw19 20:57 407 . -_ _. 10.77 7.5 30.4 185.4 123 0 2007-Nov-19 20:59 398 ~ 10.79 7.5 45.4 200.4 '. 72 0 2007-NOV-19 21:01 ~ 449 ~ 10.%7 7.5 60.4 215.4 ~ 61 j 0 2007-Nov19 21:03 508 10.79 7.5 75.5 230.5 118 0 .. .. .--- 2007-NOw19 21:05 389 10.77 7.6 90.5 245.5 68 0 2007-Now19 21:07 325 10.76 7.6 105.6 260.6 i 77 0 2007-Now19 21:09 389 10.76 7.6 120.7 275.7 68 0 2007-Nov-19 21:11 352 10,78 7.G _ 135.8 290.8 68 0 .. _ ............... 2007-Nov-19 21:13 ._....... 394 10,79 7.5 150.9 ` 305.9 .. 68 0 .. ......-I 2007-Nov-19 21:15 481 ~ 10.77 ~ 7.4 ~ 165.9 - I 320.9 _ 54 0 I 2007-NOw19 21:17 444 10.75 7.5 _ 181.0 33G.0 54 0 2007-Nov-19 21:19 380 10.76 ~ ~~~ --~7.6~~ -~ 196.1 ~ ~ 351.1 ~ ~ ~ _ S4 0 i. ,... . 2007-NOV-19 21:21 357 10.77 .. .._.._. 7.6 ...........,.. 211.1 366.1 63 0 2007-NOV-19 21:23. 385 10.77 i 7,5 226.2 381.2 ~ 59 0 2007-NotF19 21:25 320 10.78 7.5 241,2 396.2 ~ 77 0 2007-Now19 21;27 417 10.76 7.5 256.3 , 411.3 63 0 . 2007-Now19 21:29 439 10.76 7.5 271.3 426.3 54 ~ ~ . 0 2007-NOw19 ; 21:31 ; 389 10.77 7.5 . , . , . 286.4 , 441.4 59 0 2007-Nov-1fl 121:33 471 10.79 i 7.6 301.5 456.5 ~ ~ 59 I 0 . 2007-NOw19 ~ 21:35 417 10.78 7.6 316.5 471.5 ~ 59 0 2007~1ow19 ~ 21:37 339 10.78 `. 7.5 331.5 486.5 I 6B 0 i .......~.. 2007-Nov-19 , 21:39 , __......._. 357 10.87 7.4 346.6 ..... .__:. 501.0 ;' .__ S4 I ~~-_ _ 0 ___....... 200?-Now19 21:41 j 385 10-76 7.6 361.6 516.6 72 ~ 0 _ 2007-NOw19 21:a31 394 ~~ ~ 10.77 7.7 376.8 531.8 63 0 _ ...._... I 12007-NOw19 .21:43 , 38S , 10.75 ; . 7.5 _ 391.9 _ 547.0 77 0 I 2007-Nowt 9 21:47 ; 508 10.76 7.5 407.0 562.0 36 0 2007-Nov19 21:49 371 10.77 7,3 ~ ~ ~ 422.0 577.0 54 0 I 2007•Nov-19 21:51 476 10.75 7.5 436.9 591.9 63 0 2007-Nov-19 21:53 ~ 499 10.79 7.5 ~ ~ ~ ~ 451.9 606.9 49 0 2007•Nov-19 21;55' 403 10.75 ~ T.5 466.9 621.9 77 0 2007-Nov-79 2L-57j 357 ! 10.76 ~ 7.6 481.8 636.9 I 72 0 Nov rofoo'I YYk53 v3,4, a-sH ..... - ..... .... Page 2Ofa fYov 20 07 03:490 Doyon-15 907-659- p.4 Wall Gkld ~ Servlte Date Customer ;JOD Number ~ ~~ ~ Y -'- . ~..•-- -~•-•.M.~.-. 1.1 N17d WE°T SAK ~ 073 e3-NOV-10 I CUNOCU C Y:U1UIf:l4:T~ YHIlL1Yb ALASKA, IN Date Timo ' TMa"a9 I oemuy lalA RATE MM STG AIM TOTAL WMP 0 M9g59g@ Prseaure ' 2< hr elOd~ pet IDlpal DDUmIn DDI bDl pal O 2007-Nov-19 21:59 380 10.78 7.5 497.0 652.0 49 0 ! 2007-Nov-19 22:01 430 10.76 7.4 512.0 667.0 fi3 0 2007-Now19 22;03 398 10.77 7,5 526.9 682.0 54 0 2007-Nov-19 22:05 348 10.76 7.6 541.9 696.9 40 0 ~ 2007-Nov-19 22;07 385 10.76 7.5 ~ 5ti,9 5 711.9 G8 0 2007-Nov-10 22:00 • ~ 320 - ~~ 10.74 -- -~-7.5 -~--' _ -571.9 •~- -~~-726.9 77 0 I 2007-Nov-19 22:11 348 10.77 7.5 58 6.9 747.9 i ~9 0 2007-Nov-19 22:13 27 ~ ~ 10.61 ~ •~ ~ ~- 0.0 --- _ - 600.7- _ I -755.7 ~ ~ • ~ ~ ~ -60 ~ 2007-NOw19 22;14 . .Rosot Total, Vol = 602.64 bbl . soo7-Nov-19 z2;1• 27 10.37 0.0 ~ 600.7 ~ 755.7 -ss . D .. 2007-Nov-19 22:14 23 10.37 0.0 0.0 ~ 755.7 -60 0 2007-Nov-19 22:14 End Lead Slurry 2007-Nov-19 2007-Nov-19 22:1a 22:14 23 10.37 0.0 0.0 755,7 -60 0 Start Mixing Tail Slurry 2007-Nov-19 22:15 27 9,34 0,0 0,0 755,7 -56 0 2007-Nov-19 22:17 ~ 60 11,97 0.9 0.0 755.7 -51 0 2007-Nov-19 22:19; 490 I 12.15 6.7 8.0 763.7 104 0 2007-Nov-19 22:21 ; 632 i 11.94 i 6.6 21.5 777.2 338 0 2007-Nov-19 22:23; 655 ~ 11.98 ~ 6.5 34.8 79D.5 I 132 0 2007-Nov-19 22:25 ! 540 12.11 ~ 6.6 48.0 803.7 ~ 159 ~ 0 2007-Nov-19 22;27' G30 I 12.03 6.6 61.3 817.0 168 ~ 0 2007-Nov-19 t 22:29 ( 650 -` - 12.06 6.5 74.6 830.2 159 0 2007-NOv-19 22:31 549 12.14 6.5 87.8 843.5 191 i 0 2007-Nov-19 22:33 732 12.17 6.7 101.0 856.7 167 ; 0 2007-Nov-19 22:35 37 12.01 0.0 106.5 862.2 -51 ! 0 2007-NOu-1g 22;35 End 2007-Nov-19 22:35 OrOt 2007-Nov-19 22:35 37 12.01 0.0 106.5 862.2 -56 0 2007-NOV-19 22:35 32 12.01 0.0 106.5 862.2 -56 0 2007-Nov-19 22:35 Res 2007•Nov-19 22:35 tar 2007-Now19 22:35 32 12.01 0.0 0.0 862.2 -51 0 2007-Nov-19 22:35 27 9.25 0.0 0.0 862.2 -56 0 2007-NOw19 22:37 417 8.81 72 4.6 866.8 127 0 Tail $lufry ~ 700 Plug . . t Tote{, Vo1=105.84 bbl pi4p10rement 2007-NOw19 22:39 4i2~ ~ 8.40 7.2 ~ 11.9 ~ 881.1 164 0 2007-NOw19 22;41 5 ! S.a1 I 0-0 22,0 88x.2 ! 173 0 2007-Nov-19 ............. 22:43 ...., ....., 0 8.59 _ ..-- - --~ -~ -~--__J 0.0 .~---_ 22.0 884.2 ' 260 0 ____....__..-~-----.__......._ ...... ..._ . ....._ ........ . . 2007-NOV-19 22:45 5 9.26 0.0 251 0 22.0 884.2 . 2007-Nov-19 22:47 5 11.03 0.0 _ _ 22.0 884.2 255 0 2007-NOw19 22;49 5 10.77 0.0 22.0 884.2 310 0 2007-Nov19 22:51 27 0.22 0.0 22.0 884.2 ~ 352 0 2007-Nov-19 22:53 0 0.23 0.0 22.0 884.2 342 0 2007-Nov-19 2255 _ 5 8.45 _ 0.0 I 884.2 347 0 22.0 2007-Nov-19 22:57 165 8.61 0.0 22.0 ~ 884_z 393 0 _ -Y-,-~-- -.,_ 2007-Now 19 22:59 192 8.60 0.0 ~ 22. D 884.2 457 0 2007-NOw19 23:01 298 8.65 0.0 ~ 22.0 884.2 475 0 2007-Nov19 23;03 14 8.54 0,0 22.0 ; 88x,2 475 0 2007-Nov-19 23:OS 23 8.41 0.0 . . Z2.0 884.2 645 0 I . .... . I.... ..... ._...-._ ............ ..._... -.-........._.__ ....._._....~_-_..___......_._._»_-.._____...... 2007-Nov-19 .`• 23:07 23 ! 8.40 0.0 22.0 884.2 I --580 - -~ 0 2007-Now 19 ? 23:09 ~ -14 ~ 8.40 I D.0 22.0 884.2 I 622 0 2007-Now19 ; 23:11 i -14 ; 8.28 0.0 22.0 884.2 ~ 745 0 2007-Nov-19 i 23:13 I 23 0.0 22.0 884.2 704 0 ~ 2007-Nov-19 i 23:15 ~ 27 , B.d1 0.0 22.0 884.2 695 0 2007-Nov-19 i 23:17 ~ 37 _ 0,28 0.0 a2.0 88x.2 ? 754 , 0 , nmv Yo,2uUY wkS3 uM a+n-$Ft Page 3 Of 4 ~J Nov ZO 07 03:49p Doyen-15 Wall Gish 1J #t 74 wCST SAIL Date Time r,aeilne I DaMl1y MN HATE Praasure 241v I clua^k ~ pet i Ibl~al bbUmia bbl 2007-Nov-19 23:19 ~ 0 1 0.1 n 0.0 22.0 200%-Nov-1D 23:21 ~ 0 If 0.12 0.0 22.0 2007-N0~-19 23:23 ~ 0 0,11 0-0 22.0 2007-Nov-19 23:25 5 0.13 0.0 22.0 2007-Nov-19 23:27 0 0.11 0,0 22.0 2007-Nov-19 23:29 0 0-07 0.0 22.0 2007-Nov-19 23:31 5 0.11 0.0 22.0 2007-Nov-19 23:33 5 0-12 0.0 ~ 22.0 2007-Nov-19 23:35 0 0.07 0.0 22.0 2oo7-Now, ~ 23:37 0 0., o _ o,0 2z,o 2007-Nov-19 23:39 0 0.11 0.0 22.0 .200%-Nov-19 23:41 0 0.09 0.0 22.0 2007-Nov-19 23:43 0 0.10 0.0 _ 220 ... .. ~I 2007-Nov-t9 23:a5 5 O.OJ ~ i~ ~ 0.0 22.0- 2007•Nov-19 23;x7 0 0.08 0.0 220 .. . . 2007•Nov-19 23:49 ~ ~ ~ •0 0.12 ~ 0.0 22.0 2007-Nov-10 23:51 0 j 0.09 0-0 22.0 2007-Plov19 23:53 -5 ~ 0.11 0.0 22-0 2007-Nov-19 23:55 0 ; 0. t i 0.0 22-0 2007-NOv-19 23:57 0 0.09 0.0 22.0 2007-Nov-1~J 23:581 0 ~ 0-09 0.0 22.0 2007-Nov20 0:01 0 0-11 0.0 22.0 2007-Nov-20 ; 0:03 0 0.11 0.0 22.0 2007-Nov 20 ! 0:05 9 0.08 0-0 ~ 220 2007-NOv-20 ~ 0:07 0 0.11 0.0 22.0 2007-Nov-20 0:09 -5 0.07 0.0 22.0 2007-Nov-20 0:11 0 0.12 0.0 22.0 2007-Nov-20 0:13 0 0.12 0.0 22-0 2007-NOV•20 0:15 0 0.10 0.0 ~ 22.0 . .. 2oo7-Nov-2o 0:17 o D.11 0.0 ~ ~ as:o 2007-Nov-20 _0:19 0 0,11 0,0 ZZ.O 2007-Nov-20 0:21 ~... ~ .. O.M 7. .. . 0-0 22 0 2_007-Nov-20 _D:23 0 0.11 OA 22.0 2007-Nov-20 0:23 ~ ~ 2007-Nov-20 0:23_ 0 _ O.D%_ r 0.0 22.0 2007-Nov-20- ~0~24 r 2007-NOV-20 0:24 I ..-Q - ~ 0.07 - ---0 0 ---'-22 0 - - 907-659- i Customer CONOCO PHILLIPS ALASKA, iNC YYNP ~ 0 i p.5 IJOb Number I ^.:013435 Message um eel o ~ , BB4.2 745 ~ ~ 8842 _..- 759 .._...... --.-.. 0 . 884.2 777 ~ 0 j 884,2 782 ~ 0 88d,2 786 ~ 0 884.2 736 ~ ~ 0 -_._....._._..... __..__..._......_...._. 884.2 .. ~ ... 7~---- --..-.. O_.._ i .._ 8842 ~ 759 0 884,2 i 708 0 5a4.z 777 0 884.2 796 0 884.2 _ 828 0 884.2 832 0 8842 BOS 0 884.2 014 0 884,2 ~ 832 0 8842 841 0 884:2 851 0 ------_.__..._._...._.---"--• ....^ 884.2 _ .- 884 -•-~-p--- i •- ~ 884.2 8S4 D 884.2 873 i 0 884.2 ~5 ' 0 1 884.2 i 979 _ 0 884.2 965 0 884.2 I 970 0 884.2 i 896 0 88a,2 979 0 884.2 970 0 _ ~88a.2 -• ~_•-965 0 es4.z 95s ~~ " o 884,2 951 0 88a-2 88a 0 88x.2 1400 0 . .. .. Btunp Top Plug 884.2 1395 0 Cnd Displaooment 884.2 ~ 1395 ~ 0 Average Pump Rates, bpm Slurry N2 Mw1 NYaImwM rule Taal Slurry .. 7 . I I . I . 7s 7oB Treating Prosstyo Summary, psi NWaiinum Final Awrrga B~er4r Plup to DroaMdown X000 450 I 1300 Avg, Nj Parcem OealpNw 51a!!Y vollane outplacement Mh! Mater Tamp % 580 bbl ; 587.5 bbl I 65 °F Castanet or AufhMtsd RepiasemaWs I Schlumbsrpsr Supavlaor Volume of Fluid injected, bbl Nu0 Speoer N2 I. .. I 75 . Breakdown fluid velum. D^aally bbl ib/gal ~ ~ Can+entgaWStaoto5la1ace7 volume 150 bbl ~ ~~ wasnea mra Pate re ft Mike, Thomton,l GiersdoA, Gary I ~ ~ C'mnAaaonLaae Nov?t1,9007 WKt$: ~f1A1a-yN ~3snecu Drt^ 07929-NOV-19 MN $'fO MN 70YAL j~ Jab camPl^ad Page 4 014 Nov 20 07 03:49p • Doyon-15 90?-659- p.6 Schlumberger laboratory Cement lest Report Doyon 15 1J-174 Surface Tail Field Blend ~.~ r ~- uid No : PAK surt0T094 talent : ConoeoPbiBip9 Location /Rig : Ooyon 1b tte :Nov-172007 WeY Name : 1JA74 Field :West Sak MonamQd Bashed Job Type 1 318" Surface Oop[h 4000.0 ft TVD 2265.0 R DHST 40 degF eHCT s9 degF BHP 13e6 psi St:~lling Temp. 80 degF Time ro Temp. 00:18 hrmn Hosting Ram -0.95 degF/mM Sta Pressure 307 i T'irce tv PresSUre 00:18 hymn Sehotlule 9.3-1 Coln sition Slurry Density 12.00 Ib/gal Yielq 2.46 A3laK Mitt Fluid 8.225 gaVak 5o1i0 Vol. Frattipn 55.4 Ye PwoslN 44.6 % Slurrv tvce l:~EsCRE~E Do4s o.40o xt3woc ~1a5A o.oTO gausk D110 OA7t1 gaVsk Rbcol Avers a readin ) base Fluid I nrni~oam Tu7E000Sno Diapers. LT 3519 ReWnder TU7E0163A0 300 200 100 fi0 30 6 3 75.0 57.5 47A 35,5 30.5 z0A 15.0 83.0 63.0 383 Z8.5 21.5 1a.0 71,5 7em /dtYR 80 d F 69 F P• : 110.138 oD T~; ~1;,011bf1100tGt P• : 1,5,313 r.P 7x:'15-31 rbUl0ptt2 Thickenin Ti me 30 Bc 02:44 hrann 70 Bc 04:17 hymn 100 Be 05:18 Itrme Pogc t • Nov 20 07 03:49p Doyon-15 • 907-659- p.7 Schlumberger Laboratory Cement Test Report Doyon 151J-174 Surface Lead Field Blend w. Fluid No : PAK auN07079 Client : ConocoPhillips location /Rig :Doyon 75 Date : No+F17-2007 WoU Name : 1J-174 Field :West Sak Oianiel Hanel ,Jpp Type Surfaco Depth ~OOOA R TW 2265_o R BHST Gti daglF BHCT 65 deg>= 8MP 2000 psi Staring Temp_ t10 degF Tone to Temp. 00:30 hrmn 4ioating Race (degFhniny Startin Pn~stae 300 ~ Tuna to PRxstue 00:30 hymn Schedule 9.31 Composition - T Slum Density 10.70 Ib1ea1 Yiold 4.St 1T3/sk Mix Fluid ~ 21.2136 gabsk Solid Vol. Frarsion 36.9 % Porosity 63.1 % Slurry typo t~montional ~ ° - ° '799.771Wh3 ArticSetl.ITE 94 Ib of BLEND t3lend Frosh water 20.702 Ysk Base Fluid Rheo Av etra ®readin 300 .- 16.0 47.0 2lM 12.0 40.0 100 8.0 31.6 60 6.5 29.0 30 4.5 23.5 6 3.0 14.6 3 3.0 11 A Tam hire eo F 65 d w:12,a96 oP Pv: 25.442 cP Ty : 3.67 IDf/10082 Tv ; 22,301bfH OOtt2 Thickeniee Ti me P.O.D. .09.00 hymn 30 8c hrmn 70 BC hrmn 100 ec rmn r~ ~ 1 J-174 Surface Cement Job Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Tuesday, November 20, 2007 10:08 AM To: 'Chip Alvard' Subject: FW: 1J-174 (207-143} Surface Cement Job Page 1 of 2 Hi Chip, Got a bounce back that Randy is not in the office. While I don't really want to get late night or early morning calls, contact me or Jim Regg should be one of the first orders of business when the business day starts. Call and we can discuss. Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, November 20, 2007 9:58 AM To: 'Hartwig, Dennis D` Cc: Randy Thomas (CPAI); 'aogcc Prudhoe bay@admin.state.ak.us' Subject: RE: iJ-174 (207-143) Surface Cement lob Dennis, When difficulties are encountered with cementing surface casing, contacting the NS Inspector is proper. Contacting either myself or the Inspector's supervisor is equally important. In this case, it would appear that proceeding to do a 1"job is likely the only possible action since as I understand no port collar was included. I presume that the lift pressure increased as the job proceeded. Did the lift pressure continue to increase after returns were lost? Please keep myself and the Inspectors informed as to the progress of the operations. Call or message with any questions. Tom Maunder, PE AOGCC Fro • Hartwig, Dennis D [maiito:Dennis.D.Hartwig@conocophillips.com] Sent: Tu ay, November 20, 2007 9:47 AM To: Maunder, as E (DOA) Subject: iJ-174 S Cement Job Tom, The 1J-174 surface cement job did not go as night, but I thought I would fill you in on the night. We notified your man on the slope last After drilling the 16" hole to ~ 4,030' and landing commenced pumping the cement ' as follows; 75 bbl Pre- • 75561 MudWash Drop Bttm Cmt Plug hanger at ~ 4,020'MD, we 1/23/2008 • Maunder, Thomas E (DOA) From: Crisp, John H (DOA) Sent: Tuesday, November 20, 2007 1:46 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) ~ ~~3~1 - ~ ~^\~ Subject: No cement to surface KRU 1J-174 Page 1 of 1 0 hrs. from Nabors 3S on KRU 2G-06 that the well was shut in with Annula psi surface pressure. The we er was pulled loo ng 4.5 kill weigh# fluid made & trucked to the Rig. My understandin rotor Rep. stated the circulation would r nmg 11/20/07. They also stated that lower pipe rams w a empted tubing POOH. Call came in @ 0110 hrs. 11/20/07 from Doyon 15 on KRU 1 J-174 that total circulation was lost while attempting to cement their surface casing. The Drilling Foreman stated that calculated,. the cement was very close to surface. f told the Foreman that there was nothing 1 could do from the field to help him, that it was my understanding cement to surface had been a problem in Kuparuk for the life of the field. The Foreman stated that they had 1" pipe headed out to 1 J-174 for top jab. 1 told the Foreman that cement to surface was State Regulation & I could not help him from the field. The Foreman stated that they had to do this several times on 1J Pad & they needed no help. The call was just notification to give me a chance to witness their top job. 1 told the Foreman that cement to surface was State regulation i~ that it had been a problem for the life of the Kuparuk field. I declined to witness. I told him I could not help from the Field. 1 don't know if permission had been granted from AOGCC Anchorage for C/P to top off this well, they just stated they needed no help from me. Is top job common on KRU 1J Pad? 1 know of nothing else thay could do @ this point without Tam collar or 2 stage cement job, it just seemed like they considered the top job SOP. 11 /20/2007 1J-174 Intermediate Cement Joeb ~ Page 1 of 2 Maunder, Thomas E (DOA} From: Maunder, Thomas E (DOA) Sent: Friday, October 26, 2007 2:04 PM To: 'HarNvig, Dennis D' '10`x_ `y~ Subject: RE: 1J-174 Intermediate Cement Job c/ Dennis, We spoke about the plans you outlined in this message. Haven't seen that heavy 10-3/4" run on the slope before, but you do need the weight. Quick comment on the cementing design sheets provided by SOS. Have a look when the permit comes back. Some minor editing did not get done. It does not appear to affect the calculations, but edits likely should have been made. On the 1St stage of the 9-5/8, is the TOC 9850 or 10000? Not much difference with the volumes needed, but both numbers are listed on the sheet. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Friday, October 19, 2007 3:20 PM To: Maunder, Thomas E (DOA) Subject: 1J-174 Intermediate Cement Job Tom, I just submitted the 1J-174 permit for your review but thought some extra explanation of the intermediate casing and cement job might be in order. This will be our most challenging well to date for the West Sak project. The Intermediate is planned at 12,040'MD and requires that we place 4,000' of heavy 73# 10-3/4" casing on top of 40# 9-5/8 just to get the casing to bottom. Analysis of the cement job indicated that pumping as a single stage was restrictive due to ECD limitations. The current plan is a 2-stage job utilizing a hydraulic stage tool. One of the risks is that we get too much cement from the 1St-stage above the tool and are unable to open/activate for the 2nd stage. Another associated risk may occur after the stage tool opens and as we circulate the hole clean, contaminated cement from the 1St stage plugs or packs off in the tight clearance around the upper 10- 3/4" pipe. I have attached a simple diagram which indicates my proposed plan. The intent is to ensure good primary coverage of the West SAK sands with the 1St stage. Place the stage collar high enough above the 1st stage TOC to ensure little or minimal impact when the stage tool is opened. Cover and isolate the remaining UGNU with the 2nd stage. «1J-174 tntermediate.PDF» The downside of this plan is that a portion of the UGNU (9,000 to 10,000) will not be covered. We anticipate the UGNU to be wet as evidenced from the 1J-176 to the EAST. 10/26/2007 1 J-174 Intermediate Cement J: • Page 2 of 2 I appreciate any concerns or opinions -I'll try to ring you up on Monday...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 10/26/2007 ConocoPhillips tilaska ~i 73.2 /o~ -~ 9~f06" 7"A C ~ aoo' yon _ q~ ., ~. d ~ TD' C$, oo~a~ Calculations Chart of ..~~jj// ~.3 /,~ ~J(7!' fir''- _'' ~CL'L~Y~.e -Z'~c- ;lug Sr~~- x,750 ;v - TG`s C ~~T,v~c - 7,.z5vf ~t v ~~ Wt~~. .ter'-~ //: AI.A-SSiA OIL L~11TD f7[~-S C01QSF.R~A'1`I011T CO1rII~II5SIOr1T Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH rALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-174 ConocoPhillips Alaska, Inc. Permit No: 207-143 Surface Location: 1724' FSL, 2471' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1916' FNL, 198' FWL, SEC. 15, T10N, R10E, 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 an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9659-3607 (pager). K. N DATED this .day of October, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Conoco~hilli s ~ p Alaska Post Office.Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com October 16, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-174 and iJ-174 L1 Dear Commissioners: ~cr~~2f107 Alaska Ql ~ Gas Cons. ~ammission Anchorage ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated iJ-174, and the lateral bore of the well will be de§ignated iJ-174L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-174 is November 7, 2007. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA l V ALASKA OIL AND GAS CONSERVATION COMMISSION f~ ~o PERMIT TO DRILL 20 AAC 25.005 41 ~.: ~ ~ 2407 .., :; ..~ii ._ .. ;~ :011S. L`Qfl'Ytiissi. 1a. Type of Work: Drill Q jRe-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Q °` Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 a Specify if well is propos~l~Or~ Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-174 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 19696' ' D: 31 ' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1724' FSL, 2471' FEL, Sec. 35, T11 N, R10E, UM ' 7. Property Desig ZSG ~~' ~i ~ ADL 25661 25663, 2~~ ~bZo-23 •~'~ West Sak Oil Pool Top of Productive Horizon: 495' FSL, 62' FWL, Sec. 3, T10N, R10E, UM 8. Land Use Permit: ALK 471, 2177, 472, 2181 13. Approximate Spud Date: 11!7/2007 Total Depth: 1916' FNL, 198' FWL, Sec. 15, T10N, R10E, UM ' 9. Acres in Properly: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558741 - y- 5945537 ~ Zone- 4 10. KB Elevation (Height above GL): 121' AMSL' feet 15. Distance to Nearest 1 J-162L2, Well within Pool: , 268' @ 11339' MD 16. Deviated wells: Kickoff depth: ~ ~ ft. 33QD /o-4q?.o Maximum Hole Angfe: 91.5° deg 7. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1408 psig ' Surface: 1056 psig ~ 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" x 34" 94# K-55 Welded 80' 40' 40' 121' 121' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 4000' 40' 40' 4000' ~ 2265' 740 sx AS Lite, 230 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 4000' 40' 40' 4000' - 2265' 410 sx DeepCRETE, 430 sx DeepC. 12.25" 9-5/8" 40# L-80 BTCM 8000' 4000' 2265' 12000' ' 3192' ~ see above 8.5" 5.5" 15.5# L-80 Hydril 521 8257' 11439' 3131' 19696'- 3156' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature ~'•""~ ~~' ~'' ~ Phone ° _ ~. ; Date t G f (6l ~ ?~ `r..c:~s' ~ ~p"~ --~ ~ S (,s G ~C? h n All D k Commission Use Only Permit to Drill Number: ~~ ~~~ API Number: /~~~^ 50-QZ..g~~~?~(.~CJ Permit Approval Date: ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gash rate , or gas contained in shales: t Samples req'd: Yes ^ No u log req'd: Yes ^ No [~ Other: 'L~"~~g~ ~Q ~g+t- H2S measures: Yes ^ N ecti I svy req'd: Yes [[~ No ^ g APPROVED BY THE COMMISSION DATE: / ~ { r4 ,COMMISSIONER Form 10-401 Revised 12/2005 ~"'~ `~ ~ Submit in Duplicate ~fL~ /o • 2 3 • o •~ ration for Permit to Drill, Well 1 J-174 Revision No.O Saved: 16-Oct-07 Permit It -West Sak Well #1 J-174 Application for Permit to Drill Document Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information .........................................~:........................................ 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 4 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................:.. 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ......................................................................................:........... 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ........................:....................................................................... 5 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25:005 (c)(11) ............................................................:..........:........................ 6 1J-174 PERMIT /T Page 1 of 8 Printed: 16-Oct-07 ~~~~~ Ap~ion for Permit to Drill, Well 1J-174 Revision No.O Saved: 16-Oct-07 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 _ _. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25. D05 (c) (14) ................................................................................................ 7 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1!4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (fl Each we(I must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-174. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) ` An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates ~~f the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1 724' FSL 2,471' FEL, Section 35, T11N R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121.0' AMSL ~ Northings: 5,945,537 Eastings: 558,741 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 495' FSL, 62' FWL, Section 03, T10N, R10E West Sak ~~B" Sand ASP Zone 4 NAD 27 Coordinates MeaSUred De th RKB: 12,000' Northings: 5,938,970 Eastings: 550,772 Total Vertical De th, RKB: 3 192' Total Vertical De th SS: 3,071' Location at Total De th 1916' FNL, 198' FWL Section 15, T10N, R10E ' ASP Zone 4 NAD 27 Coordinates MeaSUred De th RKB: 19,696' Northings: 5,931,280 .Eastings: 550,977 Total Vertical De th, RKB: 3,156' Total Vertical De th SS: 3 035' ~. ~ ~„ q ~ 1J-174 PERMIT IT ~4.-.J~ jd Page 2 of 8 `ws Printed: 16-Oct-07 ~ation for Permit to Drill, Well 1J-174 Revision No.O Saved: 16-Oct-07 and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-40i) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1J-174 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be_accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J- 174. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. Both 10 3/4" and 9 5/8" Rams will be installed while running the tapered intermediate string. 4. Drilling Hazards Information , Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the rommission and identified in the application: ~ , (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient• The expected reservoir pressures in the West Sak sands in the 1J area are 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak °B" sand formation is x;,056 psi, calculated thusly: ~~ MPSP = (3,189 ft TVD)(0.44 - 0.11 psi/ft) = 1,056 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and ~ ~. ~. . (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-174 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be .accompanied by each of the following items, except for an item already on file -with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1]; 1J-174 PERMIT IT Page 3 of 8 Printed: 16-Oct-07 JR161NAL Ap~ion for Permit to Drill, Well 1J-174 Revision No.0 Saved: 16-Oct-07 1J-174 will be completed with a 10 3/a" x 9-5/8" tapered intermediate casing landed at the top of the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program ~Pa alsn Attachment 3' Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MDlTVD MD/TVD OD in in t (Ib/ft Grade Connection ft ft (ft) Cement Program 2fl x 34 40 94 K55 Welded 80 40 / 40 121 / 121 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 4,000 40 / 40 4,000 /2,265 740 sx ASLite Lead, 230 sx DeepCRETE Tail Top of tapered 10 3/a" x 9 5/8" 10 3/a 12-1/4 73.2 L-80 BTCM 4,000 40 / 40 4,000 / 2,265 See 9 5/8" Program in next row .~ ~ 0 1~` stage Cement,top planned ' ' 9-5%$ J [-' 12-1/4 40 L-80 BTCM 8,000 4,000 / 2,265 12,000 / 3,192 MD / 2,965 TVD. @ 10,000 cemented w/ 41o sx --- DeepCRETE. ~ I ~ ~ o Hydraulic Stage tool located at 9,000'MD / 2,854'll/D --~ 0 2`~ stage Cement top planned @ 6,744'MD / 2,604TVD. Cemented with 430 sx Dee CRETE 5-1/2 81/2" B Sand 15.5 L-80 Hydril 521 8,257 11,439 / 3,131 19,696 / 3,156 Slotted- no cement slotted Lateral (1J-174) x BTC 4-1/2 81/2" D Sand 11.6 L-80 Hydril 521 8,353 11,339/ 3,120 19,692 / 3,079 Slotted- no cement Slotted Lateral (1]-174 Li) x BTC 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: ' (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter System used in the drilling of 1J-174. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (S) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-174 PERMIT IT Page 4 of 8 ~ ~ ~~ ~ f~ ~ ~ ~ Printed: 16-Oct-07 t:~. -~.. ~ation for Permit to Drill, Well 1 J-174 Revision No.O Saved: 16-Oct-07 Surface Hole Mud Program (extended bentonite) S ud to Base of Permafrost Base of Permafrost to 13-3/8" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 ~ 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 (cP) Plastic Viscostiy 20 45 15 20 Ib/100 s pH, 8.5 9.0 8.5 9.0 APB Filtrate cc / 30 min NC 8.0 5.0 7.0 Intermediate Hole Mud Program (LSND) 13-3/8" Cs Shoe to 9-5/8" Cs Point Value Density (p ) 9.0 - 9.2 Funnel Viscosity 45 - 60 (seconds) Plastic Viscostiy 12 - 18 Ib/100 s Yield Point 15-~19 cP API Filtrate _ 4 6 cc / 30 min) ~ Chlorides (mg/1) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud. Program (MI VersaPro Mineral Oil Base) B & D sand laterals Value Densit ( ) 8.4 - 8.5 Plastic Viscostiy 15 - 25 (Ib/100 st) Yield Point 18 - 28 cP) HTHP Fluid loss . (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio '~ 70 / 30 Electrical 650 - 900 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the , t • ~ commission and identified in the application: %- ,': .y ~ (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as ~, ~ ~ t , ~ , required by 20 AAC 25.033(f); Not applicable:, Application is not for an exploratory or stratigraphic test well .,,~~l.~ h. ~, q ~ L''),1 ~. , iy f. ~ 10. Seismic ,~4nalYsis ,,, , ~,,, ~,~,,~ . Re.giri~m~w~s~fi~0 AAC X5.005 (c)(10) ; ~~''~`~ Afi application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the .~~; commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well 1J-174 PERMIT IT Q ~ ~ ~ ~ ~ ~ ~ Page. 5 of 8 Printed: 16-Oct-07 Ap~tion for Permit to Drill, Well 1 J-174 Revision No.O Saved: 16-Oct-07 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (il) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 121' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 4,000' MD / 2,265' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test 4 casing to 2500 psi for 30 minutes and .record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 8"drilling assembly, with MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 12,000' MD / 3,192' TVD, the prognosis top of the B sand. jt~S~~« 9. Run 10 3/a" 73.2# L80 BTC Mod x 9-5/8", 40# L80, BTC Mod casing to surface. Due to ECD concerns the ~ c.S wMS cement will be pumped in 2 stages. Pump 1St stage cement and displace with mud (top of cement to be S 10,000' MD / 2,965' TVD or approximately 1,339' above the West Sak Sands.) The 2"d stage cement will aSh~ctY~y be pumped to a height of approximately 6,744'MD, which corrrepsonds to 500' above the Ugnu C ~~~ ~ formation. ~~ `~ 10. Install wellhead x 10 3/a" packoff and test to 5000 psi. CyW,rSQ t-+U,MS, ) (~~ ~~ 11. Flush 13-3/8" x 10-3/4"/9-5/8"annulus with water, followed by diesel. /~'y ~~' 12. PU 8-1/2" PDC Bit and 6-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. 1J-174 PERMIT /T Page 6 of 8 ,. ~ ~ ~ ~ f Printed: 16-Oct-07 ..,~ ' ~~ i ~ ration for Permit to Drill, Well 1 J-174 Revision No.O Saved: 16-Oct-07 14. Directionally drill 8-1/2" hole to TD at +/- 19,696' MD / 3,156' TVD as per directional plan. 15. POOH, back reaming out of lateral to 9-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. Pump out of Hole. 16. PU and run 5-1/2" slotted liner. ~~~14 ~~ ~~~Cx, 17. Land liner, set liner hanger @ +/- 11,439' MD / 3,126'ND. POOH. Note: Remaining operations are covered under the iJ-176L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 11,339' MD / 3,120' TVD, the top of the. D sand. 19. Mill 8-1/2" window. POOH. 20. Pick up 8-1/2"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 21. Drill to TD of B sand lateral at +/- 19,692' MD / 3,079' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. RIH and set. Baker Seal Bore diverter 25. PU and run 4-1/2" slotted liner with Baker Oil Tools RAM Hangar system. 26. RIH and land RAM hanger in Baker seal bore diverter. 27. Release hanger running tool. Pull out of hole laying down drillpipe as required. 28. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 29. Nipple down BOPE, nipple up tree and test. Pull BPV. ' 30. Freeze protect well with diesel by pumping into 4-1/2" x 10-3/4" / 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). ' 31. Set BPV and move rig off. 32. Rig up wire line unit. Pull BPV. 33. Set gas lift valves in mandrels. Use ESP to clean up well. 34. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the~fiollowing items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25:080-for an annular disposal operation in the well.; Waste fluids generated during the drilling, process willbe disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and-eventual. processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 1J-174 PERMIT IT Page 7 of 8 Printed: 16-Oct-07 ~"~o ~ p `~'~L A~tion for Permit to Drill, Well 1 J-174 Revision No.0 Saved: 16-Oct-07 ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 4 1J-174 PERMIT IT Page 8 of 8 Printed: 16-Oct-07 ~, ;,.~ onC?~oP~'11 ~ ~ 1 S Alaska Plan: 1 J-174 (wp11) Sperry Drilling Services Proposal Report -Geographic 22 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit ' Kuparuk 1J Pad Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 1 J-174 Local Coordinate Origin: entered on Well Plan 1J-174 (01 Phase 2) -Slot 1J Viewing Datum: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet. _ _ ,,__ ~., ,=~~`i"'" - _, -, s~_ ._ Wiz. .~" ORIGINAL 2 ~ ; ,:. , ,. Spesrry Drilling 8.rvices HALLI~IL~ TON -3000 -2500 -2000 -1500 -1000 Drilling Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-174 (Q1 Phase Wel Ibore: 1 J-174 Plan: 1J-174 (wp11) WELL DETAILS: Plan IJ-174 (QI Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level. g1.00 +N/-S +El-W Northing Fasting [atittude Longitude Slot 0.00 0.00 594553G.G1 558740.81 70°15'42494N 149°31'30.524W IJ-174 ANNOTATIONS ND MD Annotation 40.00 40.00 SHL @ 40' MD, 40' TVD: 1724' FSL, 2471' FEL-Sec 35-T11N-R10E 2909.25 9500.00 Begin Pump Tangent @ 9500' MD, 2909' ND 2931.37 9700.00 End Pump Tangent @ 9700' MD, 2931' TVD 3192.30 11999.08 9 5/8" Casing @ 11999' MD, 3192' ND: 495' FSL, 62' FWL Sec 3-T10N-R10E 3192.87 15053.70 PA Boundary @ 15054' MD, 3193' ND: 2555' FNL, 191' FWL - Sec10-T10N-R10E 3155.70 19695.98 BHL @ 19696' MD, 3156' ND: 1916' FNL, 198' FWL- Sec 15 -T10N-R10E FORMATION TOP DETAILS No. NDPath NDSS MDPath Formation 1 1530.10 1409.1 1743.56 Pfrost 2 1637.5[ 1516.51 1932.33 t3 3 1923.69 1802.69 2682.65 k15 4 2126.61 2005.61 3466.67 csgpt 5 2659.75 2538.75 7244.20 Ugnu C 6 2847.29 2726.29 8939.83 Ugnu B 7 2917.86 2796.86 9577.89 Ugnu A 8 3035.35 2914.35 10610.77 K13 9 3119.60 2998.6 11339.05 Wsak D 10 3169.4G 3048.46 11791.69 Wsak C 11 3192.66 3071.66 12002.33 Wsak B -500 -0 p°- - - - - - - - - - - - - - - -, -Np 1724 FSL 2471' FEL-$ec 35-T11N-R10E \~, I ~ No MD C NDG DNDssS Name Size 1 4000.00 2264.65 2143.65 13 3/8" 13-3/8 40' MD' 40 2 11999.08 3192.30 3071.3 9 5/8" 9-5/8 ~_ 500 SHL @ 3 19695.98 3155.70 3034.7 5 1/2" 5-1/2 ~ 15° 0 2909' TVD t~ 1000 ~gp0 9500' MD, 2931' TVD = A5 gegln Pump Tangent @ End Pump Tangent @ 9700' MD • FWL Sec 3-T10N-R10E _ Sect 10N-R10E a 1500 Pfrost _ ~p 0 T p~ - - - ~~ ^h oo° ° ~ 11999' MD, 3192' TVD' 495' FSL, 62 D, 3193' TvD'~ 2555' FNL, 191 FWL ~ FNL, 198' FWL- Sec 15 T10N-R10E ~ 2000 ~ -t3 -- -~h`"--og--o---------\`~ -------, 8518"Casin9°C -------'~ darY@15054'M ----~------ 3156'ND:1916 ---------------- U .-`-k15 ---- -~---to---o---o-- ~----- ~- ------------PAgoon - HL@19696'MD• ~ -------- ` ~ ~ o° o` / ---------g --------- ----- ~ v o .3 2500 csgpt i `n cu° o ~ o° _ o ~ ____ _____ ~ _ _ ____ _ __~ _~ _ -=-='UgnuC 133/8"- ------_-_-____-__--__~_~-'-g----o_95/8,, = o <-=--o------------r------------------ o -----_---- -_--_- --______-_-_-_-_-_- --- - _~___~i -or°--_~-t°v------------+-------------------~------- -51/2"_ ~ 3000 ~ - -Ugnu6----------------------------- - ---~~~-~-- °1-~------------r---------------------------- --- 3500 t~ `~ ~ K13 7103107'.. - ,.. °o °o '~ °o ~ °o f °o :'rn p He ~~ ~. Wsak D 1 J-174 wP06 ToP e10 4000 ~ ~ Gp107103107 ~- tt Wsak C 1J-174 MB B- J _ -'~~ ~ 3107: A 1 - ,; J 07103107 g Cp8 0710 ~ 4500 Wsak C g Cp6 1 J_174 Mg_ ~ g CP2 07103107 g Opq 07103107 1 J-174 Mg_ 1 J-174 Mg- - 1J-174 Mg_ - 5000 ' g Cp307103107 ;~, ,~~ 1J-174 Mg' 1J-174 Mg B Gp5 07103107 B Cpl 07103107 5500 1J-174 MB_ - 1J-174wPp6 B Toe 07103107 6000 6500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 Vertical Section at 180.00° (1500 ft/in) ConocoPhillips Alaska Sperry ~rilliing Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-174 (Q1 Phase Wellbore: 1 J-174 Plan: 1J-174 (wp11) WELL DETAILS: Plan 1~T4 (01 Phase 2JAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945536.61 558740.81 70°15'42.494N 149°31'30.524W 1J-174 REFERENCE INFORMATION )fdlnate (N/E) Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot iJ-174, True North Vertical (TVD) Reference: ooyon is (a tzLOOn (Doyon is (ao . at)) lasured Depth Reference: ooyon is (~ tzt.ooa (ooyonts (ao . et» Calculation Method: Minimum Curvature 0 o~ ooi i -800 13 3/8" I ~ i ~ i -1600 i i I i -2400 ~ SHL @ 40' MD, 40' TVD: 1724' FS4 2471' FELSec 35-T11N-RlOE _;200 -4000 - - - - - - - - - - - - - - - -Begin Pump Tangent @ 9500' MD, 2909' TVD -4800 - - - _ _ _ '70~ End Pump Tangent @ 9700' MD, 2931' TVD -5600 11-174 wp06 Top D Heel 07/03/0 i C ~ -' p o -6400 9 5/8" 9 5/8" Casing @ 11999' MD, 3192' TVD: 495' FSL, 62' FWL Sec 3-TION-Rl OE CASING DETAILS ~ '~ ------------'---- , ~ No MD TVD TVDss Name Size 1 4000.00 2264.65 2143.65 13 318" 13-318 + - 2 11999.08 3192.30 3071.3 9 5/8" 9-518 S: -7200 1J-174 MB B CPI 07/03/07 -- 3 19695.98 3155.70 3034.7 5 112" 5-1/2 o r -8000 I1-174 MB B CP2 07/03/0 ANNOTATIONS ~ TVD MD Annotation v°) 40.00 40.00 SHL @ 40' MD, 40' TVD: 1724' FSL, 2471' FEL-Sec 35-T11N-R10E -----~-~- IJ-174 MB B CP3 07/03/07 2909.25 9500.00 Begin Pump Tangent @ 9500' MD, 2909' TVD -8800 - - 2931.37 9700.00 End Pump Tangent @ 9700' MD, 2931' TVD 3192.30 11999.08 9 5/8" Casing @ 11999' MD, 3192' TVD: 495' FSL, 62' FWL Sec 3-T10N-R10E I1-174 MB B CP407/03/07 3192.87 15053.70 PA Boundary (d 15054' MD, 3193' TVD: 2555' FNL, 191' FWL - Sec10-T10N-F ' _ .-- - - - 3155.70 19695.98 FWL- Sec 15 -T10N-R10E BHL ~ 19696' MD, 3156' TVD: 1916' FNL, 198 -9600 - - -10400 - - - - _ 1J-174 MB B CPS 07/03/07 PA Boundary @ 15054' MD, 3193' TVD: 255 5' FN1, 191' FWL - Sec10-TION-RIOE -I 1200 12000 12800 13600 14400 15200 I J-174 MB B CP6 07/03/0 IJ-174 MB B CP7 07/03/0 ~~ 1J-174 MB B CP8 07/03/0 5 1 /2" 1J-174wp06 B Tce 07/03/0 .. ~ - - - - - - - - - - -BHL @ 19696' MD, 3156' TVD: 1916' FNL, 198' FWL. Sec I S -TI ON-R10E i I J-174 (wp I I) -9600 -8800 -8000 -7200 -6400 -5600 -4800 -0000 -3200 -2400 -1600 -800 0 800 West(-)/East(+) (2000 ft/in) T M Azimuths to True North Magnetic North: 23.51 ° Magnetic Field Strength: 57621.4nT Dip Angle: 80.82° Date: 5/22/2007 Model: BGGM2006 1600 2400 3200 4000 4800 ConocoPhillips Alaska • `/ Halliburton Company ~OI'lOGO~'ll~a~ Compass Proposal Report -Geographic ~.,~ 8p~ry Orilliing 8®rvtaes• Database: Sperry EDM .11 Local Co-ordittate Reference: Well Plan 1J-174 (Q1 Phase 2) - Scot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) Project Kuparuk River Unit, North Slope Alaska. United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Wcll Plan 1 J-174 (Gi1 Ptiase 2) - Siot 1J-174 Well Position +N/S 0.00 ft Northing: 5,945,536.61 ft Latitude: 70° 15' 42.494" N +E/-W 0.00 ft Easting: 558,740.81 ft Longitude: 149° 31' 30.524" W Position Uncerta inty O.OOft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-174 Magnetics Model Narne Sample Date Declination Dip Angle Field Strength (~~) (~) (nT) BGGM2006 5/22/2007 23.51 80.82 57,621 Design 1J-174 (wp11) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +N/-S +E/-W lft) (ft) (n) 40.00 0.00 0.00 Direction (") 180.00 8/22/2007 3:26:25PM (`''~ ~ 2~1 COMPASS 2003.11 Build 48 • ~tN1QC0~'1[~~t~3S Halliburton Company `. °_w "~"`~ :'~ ~ Compass Proposal Report -Geographic gperry Drilling Sarvic®a Database: '.Sperry EDM .11 Local Go-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: I<uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) i Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth ND TVDSS +N/-S +E!-W Rate Rate Rate TFO (ft) (~) (~) (ft) (ft) lft) lft) ('/100ft) (°I100ft) (°I100ft) (°) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 129.00 0.00 0.00 0.00 0.00 0.00 0.00 550.00 9.00 227.00 548.77 427.77 -16.04 -17.20 3.00 3.00 0.00 227.00 1,692.41 53.96 248.97 1,500.00 1,379.00 -255.59 -541.73_ 4.00 3.94 1.92 25.00 1,792.41 53.96 248.97 1,558.84 1,437.84 -284.61 -617.20 0.00 0.00 0.00 0.00 2,579.13 75.00 237.00 1,896.90 1,775.90 -610.30 -1,241.60 3.00 2.67 -1.52 -30.00 4,100.00 75.00 237.00 2,290.53 2,169.53 -1,410.31 -2,473.71 0.00 0.00 0.00 0.00 4,388.33 83.65 237.00 2,343.89 2,222.89 -1,564.46 -2,711.12 3.00 3.00 0.00 0.00 4,461.22 83.65 235.00 2,351.95 2,230.95 -1,604.97 -2,771.18 2.73 0.00 -2.75 -90.00 9,961.22 83.65 235.00 2,960.26 2,839.26 -4,740.28 -7,248.87 0.00 0.00 0.00 0.00 11,339.05 83.68 192.56 3,119.60 2,998.60 -5,852.01 -7,992.47 3.06 0.00 -3.08 -92.42 11,755.88 83.68 177.80 3,165.52 3,044.52 -6,263.47 -8,029.75 3.52 0.00 -3.54 -90.00 11,969.08 83.68 177.80 3,189.00 3,068.00 -6,475.21'. -8,021.62 0.00 '. 0.00 0.00 ~, 0.00 11,999.08 83.68 177.80 3,192.30 3,071.30 -6,505.01 -8,020.47 0.00 0.00 0.00 0.00 12,250.26 91.45 171.42 3,202.99 3,081.99 -6,754.53, -7,996.90 4.00 ,, 3.09 -2.54 -39.52 12,345.47 91.45 171.42 3,200.58 3,079.58 -6,848.64 -7,982.71 0.00 0.00. 0.00 0.00 12,495.98 89.93 177.25 3,198.77 3,077.77 -6,998.34 -7,967.86 4.00 -1.01 3.87 104.57 13,095.98 89.93 177.25 3,199.50 3,078.50 -7,597.64 -7,939.08 0.00 0.00 0.00 0.00 13,286.35 90.01 179.15 3,199.61 3,078.61 -7,787.91 -7,933.10 1.00 0.04 1.00 87.69 14,195.47 90.01 179.15 3,199.50 3,078.50 -8,696.94 -7,919.65 0.00 0.00 0.00 0.00 14,264.98 90.46 179.68 3,199.22 3,078.22 -8,766.44 -7,918.94 1.00 , 0.65 0.76 49.69 14,995.65 90.46 179.68 3,193.40 3,072.40 -9,497.07 -7,914.89 0.00 0.00 0.00 0.00 15,010.65 90.54 179.55 3,193.27 3,072.27 -9,512.07 -7,914.79 1.00 0.53 -0.85 -58.23 15,895.88 90.54 179.55 3,185.00 3,064.00 -10,397.24 -7,907.91 0.00 0.00 0.00 0.00 15,940.09 90.10 179.51 3,184.76 3,063.76 -10,441.45 -7,907.55 1.00 -1.00 -0.10 -174.44 16,816.10 90.10 179.51 3,183.30 3,062.30 -11,317.42 -7,900.09 0.00 0.00 0.00 0.00 16,868.42 90.62 179.52 3,182.97 3,061.97 -11,369.75 -7,899.64 1.00 1.00 0.01 0.47 17,616.32 90.62 179.52 3,174.90 3,053.90 -12,117.57 -7,893.33 0.00 0.00 0.00 0.00 17,707.99 89.70 179.52 3,174.64 3,053.64 -12,209.23 -7,892.56 1.00 -1.00 0.00 179.82 18,295.49 89.70 179.52 3,177.70 3,056.70 -12,796.70 -7,887.62 0.00 0.00 0.00 0.00 18,420.93 90.96 179.51 3,176.98 3,055.98 -12,922.13 -7,886.56 1.00 1.00 -0.01 -0.63 19,695.99 90.96 179.51 3,155.70 3,034.70 -14,196.98 -7,875.54 0.00 0.00 0.00 0.00 8/22/2007 3:26:25PM Page. 3 of 11 COMPASS 2003.11 Build 48 ~~ ~~~,~L ~'" Halliburton Company ConocoPhill~p~5 Compass Proposal Report -Geographic ®'~` "~ ~ Sperry Drilling Servioas Database: .Sperry EDM .11 Local Co-ard'+nate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOf1 (Doyon 15 (40 + 81)) Site: I~:uparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method:" PAinimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) Planned Survey 1J-174 (wp11) MD Incl Azimuth TVD (ft) TVDSS +N/-S ift) (°) (°) (ftl (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 SHL @ 40' MD, 40' TVD: 1724' FSL, 2471' FEL-Sec 35-T11N-R10E 100.00 0.00 0.00 100.00 -21.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 250.00 0.00 0.00 250.00 129.00 0.00 ..- 300.00 1.50 i 227.00 299.99 178.99 -0.45 400.00 4.50 227.00 399.85 278.85 -4.02 500.00 7.50 227.00 499.29 378.29 -11.14 550.00 9.00 227.00 548.77 427.77 -16.04 600.00 10.85 231.50 598.02 477.02 -21.63 700.00 14.66 237.05 695.54 574.54 -34.38 800.00 18.55 240.34 791.35 670.35 -49.13 900.00 22.47 242.51 885.00 764.00 -65.83 1,000.00 26.42 244.07 976.01 855.01 -84.39 1,100.00 30.38 245.24 1,063.96 942.96 -104:72 1,200.00 34.35 246.17 1,148.40 1027.40 -126.72 1,300.00 38.33 246.92 1,228.94 1107.94 -150.29 1,400.00 '- 42.31 247.55 1,305.17 1184.17 -175:30 1,500.00 46.29 248.10 1,376.73 1255.73 -201.64 1,600.00 50.27 248.57 1,443.26 1322.26 -229.19 1,692.41 53.96 248.97 1,500.00 1379.00 -255.59 1,700.00 53.96 248.97 .1,504.47 1383.47 -257.79 1,743.56 53.96 248.97 1,530.10 1409.10 -270.43 Pfrost 1, 792.41 53.96 248.97 1, 558.84 1437.84 -284.61 1, 800.00 54.15 248.83 1, 563.30 1442.30 -286.82 1,900.00 56.77 247.04 1,619.99 1498.99 -317.78 1,932.33 57.62 246.48 1,637.51 1516.51 -328.51 t3 2,000.00 59.40 245.35 1,672.85 1551.85 -352.06 2,100.00 62.06 243.76 1,721.74 1600.74 -389.55 2,200.00 64.74 242.24 1,766.51 1645.51 -430.15 2,300.00 67.43 240.79 1,807.05 1686.05 -473.75 2,400.00 70.13 239.39 1,843.24 1722.24 -520.24 2,500.00 72.85 238.04 1,874.98 1753.98 -569.48,: 2,579.13 75.00 237.00 1,896.90 1775.90 -610.30 2,600.00 75.00 237.00 1,902.30 1781.30 -621.28 2,682.65 75.00 237.00 1,923.69 1802.69 -664.76 k15 2,700.00 75.00 237.00 1,928.18 1807.18 -673.88 2,800.00 75.00 237.00 1,954.06 1833.06 -726.48 2,900.00 75.00 237.00 1,979.94 1858.94 -779.09 3,000.00 75.00 237.00 2,005.83 1884.83 -831.69 3,100.00 75.00 237.00 2,031.71 1910.71 -884.29 3,200.00 75.00 237.00 2,057.59 1936.59 -936.89 3,300.00 75.00 237.00 2,083.47 1962.47 -989.49 Map Map +E/_W Northing Easting DLSEV V ert Section ~~~ (ft) (ft) (°I100ft) (ft1 0.00 5,945,536.61 558,740.81 0.00 0.00 0.00 5,945,536.61 558,740.81 0.00 0.00 0.00 5,945,536.61 558,740.81 0.00 0.00 0.00 5,945,536.61 558,740.81 0.00 0.00 -0.48 5,945,536.16 558,740.33 3.00 0.45 -4.31 5,945,532.56 558,736.54 3.00 4.02 -11.95 5,945,525.37 558,728.95 3.00 11.14 -17.20 5,945,520.44 558,723.74 3.00 16.04 -23.74 5,945,514.80 558,717.24 4.00 21.63 -41.73 5,945,501.91 558,699.36 4.00 34.38 -66.17 5,945,486.97 558,675.03 4.00 49.13 -96.96 5,945,470.03 558,644.37 4.00 65.83 -133.94 5,945,451.19 558,607.54 4.00 84.39 -176.93 5,945,430.52 558,564.72 '.4.00 104.72 -225.73 5,945,408.14 558,516.10 4.00 126.72 -280.08 5,945,384.16 558,461.94 4.00 150.29 -339.74 5,945,358.68 558,402.48 i 4.00 175.30 -404.40 5,945,331.84 558,338.03 4.00 201.64 -473.76 5,945,303.76 558,268.90 4.00 229.19 -541.73 5,945,276.83 558,201.14 4.00 255.59 -547.46 5,945,274.58 558,195.43 0.00 257.79 -580.34 5,945,261.69 558,162.65 0.00 270.43 -617.20 5,945,247.22 558,125.91 0.00 284.61 -622.94 5,945,244.97 558,120.19 3.00 286.82 -699.26 5,945,213.41 558,044.12 3.00 317.78 -724.23 5,945,202.49 558,019.24 ..3.00 328.51 -776.90 5,945,178.54 557,966.75 3.00 352.06 -855.66 5,945,140.44 557,888.30 3.00 389.55 -935.31 5,945,099.22 557,808.97 3.00 430.15 -1,015.64 5,945,055.00 557,728.99 3.00 473.75 -1,096.43 5,945,007.89 557,648.57 3.00 520.24 -1,177.46 5,944,958.02 557,567.94 3.00 569.48 -1,241.60 5,944,916.70 557,504.13 3.00 610.30 -1,258.51 5,944,905.59 557,487.31 0.00 621.28 -1,325.46 5,944,861.60 557,420.70 .0.00 664.76 -1,339.52 5,944,852.36 557,406.72 0.00 673.88 -1,420.53 5,944,799.14 557,326.12 0.00 726.48 -1,501.55 5,944,745.91 557,245.53 0.00 779.09 -1,582.56 5,944,692.68 557,164.94 0.00 831.69 -1,663.57 5,944,639.46 557,084.35 0.00 884.29 -1,744.59 5,944,586.23 557,003.75 0.00 936.89 -1,825.60 5,944,533.00 556,923.16 0.00 989.49 8/22/2007 3:26:25PM Page 4 of 11 COMPASS 2003.11 Build 48 ~~~ .~ • • ' Halliburton Company ~OCt©COPhtl~tp5 Compass Proposal Report -Geographic Afasfca Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: WeR Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True - Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature - Wellbore: IJ-174 Design: iJ-174 (wp11) Planned Survey 1J-174 (wp11> Map Map MD Incl Azimuth ND (ft) NDSS +NI-S +E/_yy Northing Easting DLSEV Vert Section (ft) l°) (') (ftl Iftl lft) (ftl (ft) (°I100fi) (ft) 3,400.00 75.00 237.00 2,109.35 1988.35 -1,042.10 -1,906.61 5,944,479.77 556,842.57 0.00. 1,042.10 3,466.67 75.00 237.00 2,126.61 2005.61 -1,077.17 -1,960.63 5,944,444.29 556,788.83 0.00 1,077.17 csgpt 3,500.00 75.00 237.00 2,135.24 2014.24 -1,094.70 -1,987.63 5,944,426.55 556,761.97 0.00 1,094.70 3,600.00 75.00 237.00 2,161.12 2040.12 -1,147.30 -2,068.64 5,944,373.32 556,681.38 0.00 1,147.30 3,700.00 75.00 237.00 2,187.00 2066.00 -1,199.90 -2,149.65 5,944,320.09 556,600.79 0.00 1,199.90 3,800.00 75.00 237.00 2,212.88 2091.88 -1,252.50 -2,230.67 5,944,266.87 556,520.20 0.00 1,252.50 3,900.00 75.00 237.00 2,238.76 2117.76 -1,305.11 -2,311.68 5,944,213.64 556,439.60 0.00 1,305.11 4,000.00 75.00 237.00 2,264.65 2143.65 -1,357.71 -2,392.69 5,944,160.41 556,359.01 0.00 1,357.71 . 13 318" 4,100.00 75.00 237.00 2,290.53 2169.53 -1,410.31 -2,473.71 5,944,107.18 556,278.42 0.00 1,410.31 4,200.00 78.00 237.00 2,313.87 2192.87 -1,463.26 -2,555.25 5,944,053.61 556,197.30 3.00 1,463.26 4,300.00 81.00 237.00 2,332.09 2211.09 -1,516.80 -2,637.71 5,943,999.43 556,115.27 3.00 1,516.80 4,388.33 83.65 237.00 2,343.89 2222.89 -1,564.46 -2,711.12 .5,943,951.20 556,042.23 3.00 1,564.46 , 4,400.00 83.65 236.68 2,345.18 2224.18 X1,570.81 -2,720.83 5,943,944.78 556,032.58 2.73 1,570.81 4,461.22 83.65 235.00 2,351.95 2230.95 -1,604.97 -2,771.18 5,943,910.23 555,982.50 2.73 1,604.97 4,500.00 83.65 235.00 2,356.24 2235.24 -1,627.07 -2,802.75 5,943,887.88 555,951.11. 0.00 1,627.07 4,600.00 83.65 235.00 ` 2,367.30 2246.30 `-1,684.08 -2,884.16 5,943,830.25 555,870.15' 0.00 1,684.08 ' 4,700.00 83.65 235.00 2,378.36 2257.36 -1,741.09 -2,965.57 5,943,772.61 555,789.19 0.00 1,741.09 4,800.00 83.65 235.00 2,389.42 2268.42 -1,798.09 -3,046.99 5,943,714.98 555,708.23 0.00 1,798.09 4,900.00 83.65 235.00 2,400.48 2279.48 -1,855.10 -3,128.40 5,943,657.34 555,627.28 0.00 1,855.10 5,000.00 83.65 235.00 2,411.54 2290.54 -1,912.10 -3,209.81 5,943,599.71 555,546.32 0.00 1,912.10 5,100.00 83.65 235.00 2,422.60 2301.60 -1,969.11 -3,291.23 5,943,542.08 555,465.36 0.00 1,969.11 5,200.00 83.65 235.00 2,433.66 2312.66 -2,026.12 -3,372.64 5,943,484.44 555,384.40 0.00 2,026.12 5,300.00 83.65 235.00 2,444.72 2323.72 -2,083.12 -3,454.05 5,943,426.81 555,303.45 0.00 2,083.12 5,400.00 83.65 235.00 2,455.78 2334.78 -2,140.13 -3,535.46 5,943,369.18 555,222.49 0.00 2,140.13 5,500.00 83.65 235.00 2,466.84 2345.84 -2,197.13 -3,616.88 5,943,311.54 555,141.53 0.00 2,197.13 5,600.00 83.65 235.00 2,477.90 2356.90 -2,254.14 -3,698.29 5,943,253.91 555,060.57 .0.00 2,254.14 5,700.00 83.65 235.00 2,488.96 2367.96 -2,311.14 -3,779.70 5,943,196.28 554,979.61 0.00 2,311.14 5,800.00 83.65 235.00 2,500.02 2379.02 -2,368.15. -3,861.11 5,943,138.64 554,898.66 0.00 2,368.15 5,900.00 83.65 235.00 2,511.08 2390.08 -2,425.16 -3,942.53 5,943,081.01 554,817.70 0.00 2,425.16 6,000.00 83.65 235.00 2,522.14 2401.14 -2,482.16 -4,023.94 5,943,023.38 554,736.74 0.00 2,482.16 6,100.00 83.65 235.00 2,533.20 2412.20 -2,539.17 -4,105.35 5,942,965.74 554,655.78 0.00 2,539.17 6,200.00 83.65 235.00 2,544.26 2423.26 -2,596.17 -4,186.76 5,942,908.11 554,574.83 0.00 2,596.17 6,300.00 83.65 235.00 2,555.32 2434.32 -2,653.18 -4,268.18 5,942,850.47 554,493.87 0.00 2,653.18 6,400.00" 83.65 235.00 2,566.38 2445.38 -2,710.18 -4,349.59 5,942;792.84 554,412.91 0.00 2,710.18 6,500.00 83.65 235.00 2,577.44 2456.44 -2,767.19 -4,431.00 5,942,735.21 554,331.95 0.00 2,767.19 6,600.00 83.65 235.00 2,588.50 2467.50 -2,824.20 -4,512.41 5,942,677.57 554,251.00 0.00 2,824.20 6,700.00 83.65 235.00 2,599.56 2478.56 -2,881.20 -4,593.83 5,942,619.94 554,170.04 0.00 2,881.20 6,800.00 83.65 235.00 2,610.62 2489.62 -2,938.21 -4,675.24 5,942,562.31 554,089.08 0.00 2,938.21 6,900.00 83.65 235.00 2,621.68 2500.68. -2,995.21 -4,756.65 5,942,504.67 554,008.12 0.00 2,995.21 7,000.00 83.65 235.00 2,632.74 2511.74 -3,052.22 -4,838.07 5,942,447.04 553,927.16 0.00 3,052.22 7,100.00 .83.65 235.00 2,643.80 2522.80 -3,109.22 -4,919.48.. 5,942,389.41 ..553,846.21 0.00. .3,109.22 7,200.00 83.65 235.00 2,654.86 2533.86 -3,166.23 -5,000.89 5,942,331.77 553,765.25 0.00 3,166.23 7,244.20 83.65 235.00 2,659.75 2538:75 -3,191.42 -5,036.87 5,942,306.30 553,729.47 0.00 3,191.42 Ugnu G 7,300.00 83.65 235.00 2,665.92 2544.92 -3,223.24 -5,082.30 5,942,274.14 553,684.29 0.00 3,223.24 8/22/2007 3:26:25PN1 Page 5 of 11- COMPASS 2003.11 Build 48 Q~~E~~L • Halliburton Company U~"~".~® COtlocoPhillips Compass Proposal Report -Geographic qla~ !Sperry Drilling Servloes Database: ~~ _ Sperry EDM .11 --- Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: I<uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: 1~linimum Curvature Wellbore: 1 J-174 Design: 1J-174 (wp11) - ~ Planned Surv ey 1J-174 (wp 111 Map Map MD Inc! Pzimuth ND (ft) TVDSS +N1S` +El-W Northing Easting DLSEV Vert Section (ft) (°) (') (ftI Ift1 (ft) lft) Iftl (°/100ft1 (ftl 7,400.00 83.65 235.00 2,676.98 2555.98 -3,280.24 -5,163.72 5,942,216.51 553,603.33 0.00 3,280.24 7,500.00 83.65 235.00 2,688.04 2567.04 -3,337.25 -5,245.13 5,942,158.87 553,522.38 0.00 3,337.25 7,600.00 83.65 235.00 2,699.10 2578.10 -3,394.25 -5,326.54 5,942,101.24 553,441.42 0.00 3,394.25 7,700.00 83.65 235.00 2,710.16 2589.16 -3,451.26 -5,407.95 5,942,043.60 553,360.46 0.00 3,451.26 7,800.00 83.65 235.00 2,721.22 2600.22 -3,508.26 -5,489.37 5,941,985.97 553,279.50 0.00 3,508.26 7,900.00 83.65 235.00 2,732.28 2611.28 -3,565.27 -5,570.78 5,941,928.34 553,198.55 0.00 3,565.27 8,000.00 83.65 235.00 2,743.34 2622.34 -3,622.28 -5,652.19 5,941,870.70 553,117.59 0.00 3,622.28 8,100.00 83.65 235.00 2,754.40 2633.40 -3,679.28 -5,733.60 5,941,813.07 553,036.63 0.00 3,679.28 8,200.00 83.65 235.00 2,765.46 2644.46 -3,736.29 -5,815.02 5,941,755.44 552,955.67 0.00 3,736.29 8,300.00 83.65 235.00 2,776.52 2655.52 -3,793.29 -5,896.43 5,941,697.80 552,874.71 0.00 3,793.29 8,400.00 83.65 235.00 2,787.58 2666.58 -3,850.30 -5,977.84 5,941,640.17 552,793.76 0.00 3,850.30. 8,500.00 83.65 235.00 2,798.64 2677.64 -3,907.30 -6,059.25 5,941,582.54 552,712.80 0.00 3,907.30 8,600.00 83.65 235.00 2,809.70 2688.70 -3,964.31 -6,140.67 5,941,524.90 552,631.84 0.00 3,964.31 8,700.00 83.65 235.00 2,820.76 2699.76 -4,021.32 -6,222.08 5,941,467.27 552,550.88 0.00 4,021.32 8,800.00. 83.65 235.00 2,831.82 2710.82 ,-4,078.32 -6,303.49 5,941,409.64 552,469.93, 0.00 4,078.32 , 8,900.00 83.65 235.00 2,842.88 2721.88 -4,135.33 -6,384.91 5,941,352.00 552,388.97 0.00 4,135.33 8,939.83 83.65 235.00 2,847.29 2726.29 -4,158.03 -6,417.33 5,941,329.05 552,356.72 0.00 4,158.03 Ugnu B ~ ~ 9,000.00 83.65 235.00 2,853.94 2732.94 -4,192.33 -6,466.32 5,941,294.37 552,308.01 0.00 4,192.33 9,100.00 83.65 235.00 2,865.00 2744.00 -4,249.34 -6,547.73 5,941,236.73 552,227.05 0.00 4,249.34 9,200.00 83.65 235.00 2,876.07 2755.07 -4,306.34 -6,629.14 5,941,179.10 552,146.10 0.00 4,306.34 9,300.00 83.65 235.00 2,887.13 2766.13 -4,363.35 -6,710.56. 5,941,121.47 552,065.14 0.00 4,363.35 9,400.00 83.65 235.00 2,898.19 2777.19 -4,420.36 -6,791.97 5,941,063.83 551,984.18 0.00 4,420.36 9,500.00 83.65 235.00 2,909.25 2788.25 -4,477.36 -6,873.38 5,941,006.20 551,903.22 0.00 4,477.36 Begin Pump Tangent @ 9500' MD , 2909' TVD 9,577.89 83.65 235.00 2,917.86 2796.86 -4,521:76 -6,936.79 5,940,961.31 551,840.17 0.00 4,521.76 Ugnu A 9,600.00 83.65 235.00 2,920.31 2799.31 -4,534.37 -6,954.79 5,940,948.57 551,822.26 0.00 4,534.37 9,700.00 83.65 235.00 2,931.37 2810.37 -4,591.37 -7,036.21 5,940,890.93 551,741.31 0.00 4,591.37 End Pump Tangent @ 9700' MD, 2931' TVD 9,800.00 83.65 235.00 2,942.43 2821.43 -4,648.38 -7,117.62 5,940,833.30 551,660.35 0.00 4,648.38 9,900.00 83.65 235.00 2,953.49 2832.49 -4,705.39 -7,199.03 5,940,775.67 551,579.39 0.00 .4,705.39 9,961.22 83.65 235.00 2,960.26 2839.26 -4,740.28 -7,248.87 5,940,740.38 551,529.83 0.00 4,740.28 10,000.00 83.60 233.81 2,964.56 2843.56 -4,762.72 -7,280.21 5,940,717.71 551,498.67 3.06 4,762.72 10,100.00 83.49 230.73 2,975.81 2854.81 -4,823.52 -7,358.79 5,940,656.30 551,420.58 ~ 3.06 4,823.52 10,200.00 83.39 227.65 2,987.23 2866.23 -4,888.44 -7,433.97 5,940,590.80 551,345.91 3.06 4,888.44 10,300.00 83.32 224.57 2,998.81 2877.81 -4,957.30 -7,505.54 5,940,521.40 551,274.88 3.06 4,957.30 10,400.00 83.26 221.49 3,010.49 2889.49 -5,029.89 -7,573.30 5,940,448.29 551,207.70 3.06 .5,029.89 10,500.00 83.23 218.41 3,022.26 2901.26 -5,106.01 -7,637.05 5,940,371.67 551,144.55 3.06 5,106.01 10,600.00 83.21 215.32 3,034.08 2913.08 -5,185.45 -7,696.62 5,940,291.78 551,085.61 3.06 5,185.45 10,610.77 83.21 214.99 3,035.35 .2914.35 -5,194.19 -7,702.78 5,940,282.99 551,079.52 3.07 5,194.19 K13 10,700.00 83.21 212.24 3,045.90 2924.90 -5,267.97 -7,751.82 5,940,208.84 551,031.06 3.06 5,267.97 10,800.00 83.23 209.16 3,057.71 2936.71 -5,353.34 -7,802.51 5,940,123.08 550,981.04 3.06 5,353.34 10,900.00 83.27 206.08 3,069.47 2948.47 -5,441.33 -7,848.54 5,940,034.75 550,935.70 3.06 5,441.33 11,000.00 83.33 203.00 3,081.13 2960.13 -5,531.66 -7,889.78 5,939,944.10 550,895.18 3.06 5,531.66 8/22/2007 3:28:25PM Page 6 of 11 COMPASS 2003.11 Build 48 ' ~~~~~~ Conocof~hiffips Alaska Halliburton Company Compass Proposal Report -Geographic r s ~~ Q ®~,n Sp®rry Drilling Service Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: ~,linimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) - ..._ i Planned Survey 1J-174 (w p11) Map Map MD Inc! Azimuth TVD (ft) TVDSS +N!-S +E/-W Northing Easting DLSEV Vert Section (fti (°) (°) (ft) (ft) (ft) (ft) (ft) (°l100ft) (ft) 11,100.00 83.41 199.92 3,092.68 2971.68 -5,624.10 -7,926.11 5,939,851.40 550,859.57 3.06 5,624.10 11,200.00 83.51 196.84 3,104.07 2983.07 -5,718.37 -7,957.42 5,939,756.89 550,829.00 3.06 5,718.37 11,300.00 83.63 193.76 3,115.28 2994.28 -5,814.21 -7,983.63 5,939,660.86 550,803.54 3.06 5,814.21 11,339.05 83.68 192.56 3,119.60 2998.60 -5,852.01 -7,992.47 5,939,623.00 550,795.00 3.06 5,852.01 1Nsak D - 7J-174 wp06 Tap D Hee107/03107 11,400.00 83.68 190.40 3,126.31 3005.31 -5,911.37 -8,004.52 5,939,563.55 550,783.41 3.52 5,911.37 11,500.00 83.68 186.86 3,137.33 3016.33 -6,009.62 -8,019.43 5,939,465.20 550,769.27 3.52 6,009.62 11,600.00 83.68 183.32 3,148.34 3027.34 -6,108.60 -8,028.24 5,939,366.16 550,761.23 3.52 6,108.60 11,700.00 83.68 179.78 3,159.36 3038.36 -6,207.94 -8,030.93 5,939,266.81 550,759.32 3.52 6,207.94 11,755.88 83.68 177.80 3,165.52 3044.52 -6,263.47 -8,029.75 5,939,211.30 550,760.93 3.52 6,263.47 11,791.69 83.68 177.80 3,169.46 3048.46 -6,299.03 -8,028.39 5,939,175.75 550,762.57 0.00 6,299.03 Wsak C 11,800.00 83.68 177.80 3,170.38 3049.38 -6,307.29 -8,028.07 5,939,167.50 550,762.95 0.00 6,307.29 11,900.00 83.68 177.80 3,181.39 3060.39 -6,406.60 ~ -8,024.25 5,939,068.23 550,767.54 0.00 6,406.60 11,969.08 83.68 177.80 3,189.00 3068.00 -6,475.21 -8,021.62 5,938,999.65 550,770.71 0.00 6,475.21 11,999.08 83.68 177.80 3,192.30 3071.30 -6,505.01 -8,020.47 5,938,969.87 550,772.09 0.00 6,505.01 9 518" Casing ~ 11999' MD, 3192' TVD: 495' FSL, 62' FWL Sec 3-T10N-R10E - 9 5/8" 12,000.00 83.70 177.78 3,192.41 3071.41 -6,505.92 -8,020.44 5,938,968.95 550,772.13 4.00 6,505.92 12,002.33 83.78 177.72 3,192.66 3071.66 -6,508.24 -8,020.35 5,938,966.64 550,772.24 4.00 6,508.24 Wsak B 12,069.06 85.84 176:01 3,198.70 3077.70 -6,574.59 -8,016.71 5,938,900.32 550,776.39 4.00 6,574.59 1J-174 MB B CP1 07!03107 12,100.00 86.79 175.23 3,200.69 3079.69 -6,605.37 -8,014.35 5,938,869.56 550,778.99 3.99 6,605.37 12,200.00 89.89 172.70 3,203.58 3082.58 -6,704.76 -8,003.84 5,938,770.27 550,790.28 4.00 6,704.76 12,250.26 91.45 171.42 3,202.99. 3081.99 -6,754.53 -7,996.90 5,938,720.56 550,797.61 4.00 6,754.53 12,300.00 91.45 171.42 3,201.73 3080.73 -6,803.70 -7,989.48 5,938,671.46 550,805.41 0.00 6,803.70 12,345.47 91.45 171.42 3,200.58 3079.58 -6,848.64 -7,982.71 5,938,626.57 550,812.53 0.00 6,848.64 12,400.00 90.90 173.53 3,199.46 3078.46 -6,902.69 -7,975.57 5,938,572.58 550,820.09 4.00 6,902.69 12,495.98 89.93 177.25 3,198.77 3077.77 -6,998.34 -7,967.86 5,938,477.01 550,828.54 4.00 6,998.34 12,500.00 89.93 177.25 3,198.77 3077.77 -7,002.35 -7,967.67 5,938,472.99 550,828.77 0.00 7,002.35 12,600.00 89.93 177.25 3,198.89 3077.89 -7,102.24 -7,962.87 5,938,373.16 550,834.34 0.00 7,102.24 12,700.00 89.93 177.25 3,199.02 3078.02 -7,202.12 -7,958.08 5,938,273.32 550,839.92 .0.00 7,202.12 12,800.00 89.93 177.25 3,199.14 3078.14 -7,302.01 -7,953.28 5,938,173.49 550,845.50 0.00 7,302.01 12,900.00 89.93 177.25 3,199.26 3078.26 -7,401.89 -7,948.48 5,938,073.65 550,851.07 0.00 7,401.89 13,000.00 89.93 177.25 3,199.38 3078.38 -7,501.78 -7,943.68 5,937,973.82 550,856.65 0.00 7,501.78 13,095.98 89.93 177.25 3,199.50 3078.50 -7,597.64 -7,939.08 5,937,878.00 550,862.00 0.00 7,597.64 1J-174 MB B CP2 07103107 13,100:00 89.93 177.29 3,199.50 3078.50 -7,601.66 -7,938.89 5,937,873.98 550,862.22 0.99 7,601.66 13,200.00 89.97 178.29 3,199.59 3078.59 -7,701.59 -7,935.03 5,937,774.10 550,866.86 1.00 7,701.59 13,286.35 90.01 179.15 3,199.61 3078.61 -7,787.91 -7,933.10 5,937,687.80 550,869.46 1.00 7,787.91 13,300.00 90.01 179.15 3,199.60 3078.60 -7,801.56 -7,932.90. 5,937,674.16 550,869.77 0.00 7,801.56 13,400.00 90.01 179.15 3,199.59 3078.59 -7,901.55 -7,931.42 5,937,574.19 550,872.03 0.00 7,901.55 13,500.00 90.01 179.15 3,199.58 3078.58 -8,001.54 -7,929.94 5,937,474.23 550,874.29 0.00 8,001.54 13,600.00 90.01 179.15 3,199.57 3078.57 -8,101.53 -7,928.46 5,937,374.26 550,876.55 0.00 8,101.53 13,700.00 90.01 179.15 3,199.56 3078.56 -8,201.52 -7,926.98 5,937,274.30 550,878.81 0.00 8,201.52 8/22/2007 3:26:25PM Page 7 of 11 COMPASS 2003.11 Build 48 ORIGINAL • • ConocaPhillips Alaska Halliburton Company Compass Proposal Report -Geographic ^ , I ~...: _ Bpsrry Orillirtig gervicsms Database: Sperry EDM .11 Local Co-ordinate Reference: WeII Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) Planned Survey 1J-174 (wp11) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/_S +E/_yy Northing Fasting DLSEV Vert Section lft? (°) (°) Ift) (ft) lft) Ift1 (ft) (°I100ft1 (ft1 13,800.00 90.01 179.15 3,199.55 3078.55 -8,301.51 -7,925.50 5,937,174.33 550,881.06 0.00 8,301.51 13,900.00 90.01 179.15 3,199.53 3078.53 -8,401.50 -7,924.02 5,937,074.37 550,883.32 0.00 8,401.50 14,000.00 90.01 179.15 3,199.52 3078.52 -8,501.49 -7,922.54 5,936,974.40 550,885.58 0.00 8,501.49 14,100.00 90.01 179.15 3,199.51 3078.51 -8,601.48 -7,921.06 5,936,874.44 550,887.84 0.00 8,601.48 14,195.47 90.01 179.15 3,199.50 3078.50 -8,696.94 -7,919.65 5,936,779.00 550,890.00 0.00 8,696.94 1J-174 MB B CP3 07/03/07 14,200.00 90.04 179.19 3,199.50 3078.50 -8,701.46 -7,919.58 5,936,774.47 550,890.10 0.99 8,701.46 14,264.98 90.46 179.68 3,199.22 3078.22 -8,766.44 -7,918.94 5,936,709.51 550,891.25 1.00 8,766.44 14,300.00 90.46 179.68 3,198.94 3077.94 -8,801.46 -7,918.75 5,936,674.50 550,891.72 0.00 8,801.46 14,400.00 90.46 179.68 3,198.14 3077.14 -8,901.45 -7,918.19 5,936,574.52 550,893.05 0.00 8,901.45 14,500.00 90.46 179.68 3,197.35 3076.35 -9,001.45 -7,917.64 5,936,474.54 550,894.39 0.00 9,001.45 .14,600.00 90.46 179.68 3,196.55 3075.55 -9,101.44 -7,917.08 5,936,374.56 550,895.72 0.00 9,101.44 14,700.00 90.46 179.68 3,195.75 3074.75 -9,201.44 -7,916.53 5,936,274.58 550,897.05 0.00 9,201.44 14,800.00 90.46 179.68 3,194.96 3073.96 -9,301.44 -7,915.97 5,936,174.61 550,898.39 0.00 9,301.44 14,900.00 90.46 179.68 3,194.16 3073.16 '-9,401.43 -7,915.42 5,936,074.63 550,899.72 0.00 9,401.43 ' 14,995.65 90.46 179.68 3,193.40 3072.40 -9,497.07 -7,914.89 5,935,979.00 550,901.00 0.00 9,497.07 1 J-174 M B B CP4 07/03/07 - - 15,000.00 90.48 179.65 3,193.36 3072.36 -9,501.43 -7,914.86 5,935,974.65 ~ 550,901.06 0.99 ~ 9,501.43 15,010.65 90.54 179.55 3,193.27 3072.27 -9,512.07 -7,914.79 5,935,964.01 550,901.22 1.01 9,512.07 15,053.70 90.54 179.55 3,192.87 3071.87 -9,555.12 -7,914.46 5,935,920.96 550,901.89 0.00 9,555.12 PA Boundary ~ 15054' MD, 3193' TVD: 2555' FNL, 191' FWL - Sec10-T10N-R10E 15,100.00 90.54 179.55 3,192.44 3071.44 -9,601.42. -7,914.10 5,935,874.67 550,902.61 0.00 9,601.42 15,200.00 90.54 179.55 3,191.50 3070.50 -9,701.41 -7,913.32 5,935,774.70 550,904.17 0.00 9,701.41 15,300.00 90.54 179.55 3,190.57 3069.57 -9,801.40 -7,912.54 5,935,674.73 550,905.72 0.00 9,801.40 15,400.00 90.54 179.55 3,189.63 3068.63 -9,901.40 -7,911.76 5,935,574.75 550,907.28 0.00 9,901.40 15,500.00 90.54 179.55 3,188.70 3067.70 -10,001.39 -7,910.99 5,935,474.78 550,908.84 0.00 10,001.39 15,600.00 90.54 179.55 3,187.76 3066.76 -10,101.38 -7,910.21 5,935,374.81 550,910.39 0.00 10,101.38 15,700.00 90.54 179.55 3,186.83 3065.83 -10,201.37 -7,909.43 5,935,274.83 550,911.95 0.00 10,201.37 15,800.00 90.54 179.55 3,185.90 3064.90 -10,301.37 -7,908.66 5,935,174.86 550,913.51 0.00 10,301.37 15,895.88 90.54 179.55 3,185.00 3064.00 -10,397.24 -7,907.91 5,935,079.00 550,915.00 0.00 10,397.24 1J-174 MB B CP5 07/03/07 15,900.00 90.49 179.55 3,184.96 3063.96 -10,401.36 -7,907.88 5,935,074.88 550,915.06 0.98 10,401.36 15,940.09 90.10 179.51 3,184.76 3063.76 -10,441.45 -7,907.55 5,935,034.80 550,915.70 1.00 10,441.45 16,000.00 90.10 179.51 3,184.66 3063.66 -10,501.36 -7,907.04 5,934,974.91 550,916.68 0.00 10,501.36 16,100.00 90.10 179.51 3,184.49 3063.49 -10,601.35 -7,906.19 5,934,874.93 550,918.31 ~ 0.00 10,601.35 16,200.00 90.10 179.51 3,184.32 3063.32 -10,701.35 -7,905.34 5,934,774.95 550,919.95 0.00 10,701.35 16,300.00 90.10 179.51 3,184.16 3063.16 -10,801.34 -7,904.48 5,934,674.98 550,921.58 0.00 10,801.34 16,400.00 90.10 179.51 3,183.99 3062.99 -10,901.34 -7,903.63 5,934,575.00 550,923.21 0.00 10,901.34 16,500.00 90.10 179.51 3,183.83 3062.83 -11,001.34 -7,902.78 5,934,475.02 550,924.84 0.00 11,001.34 16,600.00 90.10 179.51 3,183.66 3062.66 -11,101.33 -7,901.93 5,934,375.05 550,926.47 0.00 11,101.33 16,700.00 90.10 179.51 3,183.49 3062.49 -11,201.33 -7,901.08 5,934,275.07 550,928.11 0.00 11,201.33 16,800.00 90.10 179.51 3,183.33 3062.33 -11,301.33 -7,900.22 5,934,175.09 550,929.74 0.00 11,301.33 16,816.10 90.10 179.51 3,183.30 3062.30 -11,317.42 -7,900.09 5,934,159.00 550,930.00 0.00 11,317.42 1J-174 MB B CP6 07/03/07 16,868.42 90.62 179.52 3,182.97 3061.97 -11,369.75 -7,899.64 5,934,106.68 550,930.85 1.00 11,369.75 16,900.00 90.62 179.52 3,182.63 3061.63 -11,401.32 -7,899.38 5,934,075.12 550,931.36 0.00 11,401.32 8/22/2007 3:26:25PM Page 8 of 11 COMPASS 2003.11 Build 48 nR!ciNAL • COCIUCO~'tl~~t~5 Alaska Halliburton Company Compass Proposal Report -Geographic { ,, , _- _~ ,- Sp®rry Drilling S®rvices Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-974 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: flan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) Planned Survey 1J-174 i~a~p11) Map Map MD Inc! Azimuth TVD (ft) TVDSS +N/.$ +E/-W Northing Fasting (ft) (°) (°) (ftl (ftl (ft) lft) (ft) 17,000.00 90.62 179.52 3,181.55 3060.55 -11,501.31 -7,898.53 5,933,975.15 550,932.99 17,100.00 90.62 179.52 3,180.47 3059.47 -11,601.30 -7,897.69 5,933,875.17 550,934.61 17,200.00 90.62 179.52 3,179.39 3058.39 -11,701.29 -7,896.84 5,933,775.20 550,936.24 17,300.00 90.62 179.52 3,178.31 3057.31 -11,801.28 -7,896.00 5,933,675.23 550,937.86 17,400.00 90.62 179.52 3,177.24 3056.24 -11,901.27 -7,895.15 5,933,575.26 550,939.49 17,500.00 90.62 179.52 3,176.16 3055.16 -12,001.26 -7,894.31 5,933,475.29 550,941.11 17,600.00 90.62 179.52 3,175.08 3054.08 -12,101.25 -7,893.47 5,933,375.32 550,942.73 17,616.32 90.62 179.52 3,174.90 3053.90 -12,117.57 -7,893.33 5,933,359.00 550,943.00 1J-174 MB B CP7 07/03/07 17,700.00 89.78 179.52 3,174.61 3053.61 -12,201.25 -7,892.62 5,933,275.34 550,944.36 17,707.99 89.70 179.52 3,174.64 3053.64 -12,209.23 -7,892.56 5,933,267.36 550,944.49 17,800.00 89.70 179.52 3,175.12 3054.12 -12,301.24 -7,891.78 5,933,175.37 550,945.98 17,900.00 89.70 179.52 3,175.64 3054.64 -12,401.24 -7,890.94 5,933,075.39 550,947.60 18,000.00 89.70 179.52 3,176.16 3055.16 -12,501.23 -7,890.10 5,932,975.41 550,949.22 18,100.00 89.70 179.52 ~ 3,176.68 3055.68 -12,601.23 -7,889.26 5;932,875.44 550,950.83 18,200.00 89.70 179.52 3,177.20 3056.20 =12,701.22 -7,888.43 5,932,775.46 550,952.45 18,295.49 89.70 179.52 3,177.70 3056.70 -12,796.70 -7,887.62 5,932,680.00 550,954.00 1J-174 MB B_CP8 07/03!07 , 18,300.00 89.75 179.52 3,177.72 3056.72 -12,801.22 -7,887.59 5,932,675.49 550,954.07 18,400.00 90.75 179.51 3,177.29 3056.29 -12,901.21 -7,886.74 5,932,575.51 550,955.70 18,420.93 90.96 179.51 3,176.98 3055.98 -12,922.13 -7,886.56. 5,932,554.59 550,956.05 18,500.00 90.96 179.51 3,175.66 3054.66 -13,001.20 -7,885.87 5,932,475.55 550,957.35 18,600.00 90.96 179.51 3,173.99 3052.99 -13,101.18 -7,885.01 5,932,375.59 550,958.99 18,700.00 90.96 179.51 3,172.32 3051.32 -13,201.16 -7,884.15 5,932,275.62 550,960.63 18,800.00 90.96 179.51 3,170.65 3049.65 -13,301.14 -7,883.28 5,932,175.66 550,962.28 18,900.00 90.96 179.51 3,168.98 3047.98 -13,401.12 -7,882.42 5,932,075.70 550,963.92 19,000.00 90.96 179.51 3,167.32 3046.32 -13,501.11 -7,881.56 5,931,975.73. 550,965.56 19,100.00 90.96 179.51 3,165.65 3044.65 -13,601.09 -7,880.69 5,931,875.77 550,967.21 19,200.00 90.96 179.51 3,163.98 3042.98 -13,701.07 -7,879.83 5,931,775.81 550,968:85 19,300.00 .90.96 179.51 3,162.31 3041.31 -13,801.05 -7,878:96 5,931,675.84 550,970.49 19,400.00 90.96 179.51 3,160.64 3039.64 -13,901.04 -7,878.10 5,931,575.88 550,972.14 19,500.00 90.96 179.51 3,158.97 3037.97 -14,001.02 -7,877.24 5,931,475.92 550,973.78 19,600.00 90.96 179.51 3,157.30 3036.30 -14,101.00 -7,876.37 5,931,375.96 550,975.42 19,695.99 90.96 179.51 3,155.70. 3034.70 -14,196.98 -7,875.54 5,931,280:00 550,977.00 BFtL ~ 19696' MD, 31 56' TVD: 1916' FNL, 198' FWL- Sec 1 5 -T10N-R10E - 5 1/Z" -1J-174wp06 B Toe 07/03/07 DLSEV Vert Section (°/100ft) (ft) 0.00 11,501.31 0.00 11,601.30 0.00 11,701.29 0.00 11,801.28 0.00 11,901.27 0.00 12,001.26 0.00 12,101.25 0.00 12,117.57 1.00 12,201.25 1.00 12,209.23 0.00 12,301.24 0.00 12,401.24 0.00 12,501.23 0.00 12,601.23 0.00 12,701.22 0.00 12,796.70 0.98 12,801.22 1.00 12,901.21 1.00 12,922.13 0.00 13,001.20 0.00 13,101.18 0.00 13,201.16 0.00 13,301.14 0.00 13,401.12 0.00 13,501.11 0.00 13,601.09 0.00 13,701.07 0.00 13,801.05 0.00 13,901.04 0.00 14,001.02 0.00 14,101.00 0.00 14,196.98 8/22rZ007 3:26:25PM Page 9 of 11 COMPASS 2003.11 Build 48 R t ~ ~~ ~~ ConocoPhillips AJaska Halliburton Company Compass Proposal Report -Geographic \J ~i::~~`~ Sperry Drilii~g Services Database: .Sperry EDM .11 ,~ Local Co-0rdinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: 'True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: J Minimum Curvature Wellbore: 1J-174 Design: 1J-174 (wp11) i Geologic Targets 1 J 1 4 TVD TVDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) -Shape ft ft (ft) (ft) 3,185.00 1J-174 MB_B_CP5 07/03/07 -10,397.24 -7,907.91 5,935,079.00 550,915.00 - Polygon Point 1 0.00 0.00 5,935,079.00 550,915.00 Point 2 -920.18 7.82 5,934,159.00 550,930.00 3,174.90 1J-174 MB_B_CP7 07/03/07 -12,117.57 -7,893.33 5,933,359.00 550,943.00 - Polygon Point 1 0.00 0.00 5,933,359.00 550,943.00 Point 2 -679.21 5.70 5,932,680.00 550,954.00 3,207.00 1J-174 MB_B_Heel 07/03/07 -5,852.01 -7,992.47 5,939,623.00 550,795.00 - Polygon Point 1 0.00 0.00 5,939,623.00 550,795.00 Point2 -1,046.30 19.84 5,938,577.00 550,823.00 3,183.30 1J-174 MB_B_CP6 07/03/07 -11,317.42 -7,900.09 5,934,159.00 550,930.00 - Polygon Point 1 ~ ~ 0.00 0.00 ~ 5,934,159.00 550,930.00 Point 2 -800.29 6.76 5,933,359.00 550,943.00 3,155.70 1J-174wp06 B Toe 07/03/07 -14,196.98 -7,875.54 5,931,280.00 550,977.00 - Point " 3,1.98.70 1J-174 MB_B_CP1 07/03/07 -6,898.29 -7,972.63 5,938,577.00 550,823.00 - Polygon Point 1 0.00 0.00 5,938,577.00 550,823.00 Point 2 -699.36 33:55 5,937,878.00 550,862.00 .3,193.40 1J-174 MB_B_CP4 07103/07 -9,497.07 -7,914.89 5,935,979.00 550,901.00 -.Polygon Point 1 0.00 0.00 5,935,979.00 550,901.00 Point 2 -900.24 6.98 5,935,079.00 550,915.00 3,119.60 1J-174 wp06 Top D Heel 07/03/07 -5,852.01 -7,992.47 5,939,623.00 550,795.00 - Point 3,199.50 1J-174 MB_B_CP3 07/03/07 -8,696.94 -7,919.65 5,936,779.00 550,890.00 - Polygon Point 1 0.00 0.00 5,936,779.00 550,890.00 Point 2 -800.14 4.76 5,935,979.00 550,901.00 3,177.70 1J-174 MB_B_CP8 07/03/07 -12,796.70 -7,887.62 5,932,680.00. 550,954.00 - Polygon ' ,. Point 1 0.00 0.00 5,932,680.00 550,954.00 Point 2 -1,400.28 12.08 5,931,280.00 550,977.00 3,199.50 1J-174 MB_B_CP2 07/03/07 -7,597.64 -7;939.08 5,937,878.00 550,862.00 - Polygon Point 1 0.00 0.00 5,937,878.00 550,862.00 Point 2 -1,099.37 19.43 5,936,779.00 550,890.00 --. _.. _.__ _. .__._ -m~, _... _.. ~ 8/22/2007 3:26:25PM Page 10 of 19 f COMPASS 2003.11 Build 48 s . ~ _., ,, COC10C0~'t1~~Ip5 Alaska Halliburton Company Compass Proposal Report -Geographic Sperry Drilling Services I Database: Sperry EDM .11 Local Co-ordinate Reference: Welf Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: I(uparuk 1J Pad North Reference: True Well: flan 1J-174 (Q1 Phase 2 ) Survey Calculation Method: Minimum Curvature Wellbore: IJ-174 Design: 1J-174 (wp11) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter diameter (ft) (ft) („) (,.) 4,000.00 2,264.65 13-318 16 11,999.08 3,192.30 9-518 12-1/4 19,695.98 3,155.70 5-1/2 8-1/2 Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD TVDSS +N/-E (ft} +Fr-W (ft) (ft) 1''1 (°} (ftl (ftl Naitte 1,743.56 53.96 248.97 1,530.10 -270.43 -580.34 Pfrost 1,932.33 57.62 246.48 1,637.51 -328.51 -724.23 t3 2,682.65 75.00 237.00 1,923.69 -664.76 -1,325.46 k15 3,466.67 75.00 237.00 2,126.61 -1,077.17 -1,960.63 csgpt 7;244.20 83.65 235.00 2,659.75 ~ -3,191.42 ~ -5,036.87 ~ Ugnu C 8,939.83 83.65 235.00 2,847.29 -4,158.03 -6,417.33 Ugnu B 9,577.89 83.65 235.00 2,917.86 -4,521.76 -6,936.79 Ugnu A 10,610.77 83.21 ` 214.99 3,035.35 -5,194.19 -7,702.78 K73 11,339.05 83.68 192.56 3,119.60 -5,852.01 -7,992.47 Wsak D 11,791.69 83.68 177.80 3,169.46 -6,299.03 -8,028.39 Wsak C 12,002.33 83.78 177.72 3,192.66 . -6,508.24 -8,020.35 Wsak B Plan Annotati ons Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) (ft) (ft) (ft) 40.00 40.00 0.00 0:00 SHL @ 40' MD, 40' TVD: 1724' FSL, 2471' FEL-Sec 35-T11 N-R10E 9,500.00 2,909.25 -4,477.36 -6,873.38 Begin Pump Tangent @ 9500' MD, 2909' TVD 9,700.00 2,931.37 -4,591.37 -7,036.21 End Pump Tangent @ 9700' MD, 2931' TVD 11,999.08 3,192.30 -6,505.01 -8,020.47 9 5/8" Casing @ 11999' MD, 3192' TVD: 495' FSL, 62' FWL Sec 3-T10N-R10E 15,053.70 3,192.87 -9,555.12 -7,914.46 PA Boundary @ 15054' MD, 3193' TVD: 2555' FNL, 191' FWL - Sec10-T10N-I 19,695.98 3,155.70 -14,196.96 -7,875.54 BHL @ 19696' MD, 3156' TVD: 1916' FNL, 198' FWL- Sec 15 -T10N-R10E 8/22x1007 3:26:25PM Page 11 of 11 COMPASS 2003.11 Build 48 ConocoPhillips Alaska Plan: 1 J-174 L1 (wp11) Sperry Drilling Services Anticollision Summary 21 August, 2007 ConocoPhillips Alaska, Inc. ' Kuparuk' River Unit ' Kuparuk 1J Pad Plan 1J-174 (Q1 Phase 2) ' 1J-174 L1 Local Coordinate Origin: Centered on Well Plan 1J-174 (01 Phase 2) -Slot 1J Viewing Datum: Doyon 15 Q 121.OOft (Doyon 15 (40 + 81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~,. Sperry Grilling ~srviGew i Halli r n m bu to Co pany Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/21/2007 Time: 14:06:46 Pa~c: 1 Field: Kuparuk River Un it Reference Site: Kuparuk 1 J Pad Co-ordinate( NE) Refer ence: Well: Pla n 1 J-174, Tr ue North Reference 'f'ell: Plan 1J-174 Vertical (TVD) Reference: Doyon 15 (40+81) 121.0 Referencew'ellpath: PIan:1J-174 Db: Oracle GLOBAL SCAN APPLIED: All wellpa ths within 200'+ 100/1000 of reference Reference: Plan: 1J-174 (wp 11) & NOT PLANNED PR GRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 19696.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2165.60 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Holc Size Name ft ft in in 3700.00 2187.00 13.375 16.000 13 3/8" 11888.38 3180.11 9.625 12.250 9 5/8" 19665.86 3156.20 4.500 8.500 4 1 /2" Plan: 1J-174 (wp11) Date Composed: 5/22/2007 Version: 12 Principal: Yes Tied-to: From Well Ref. Point Summary <---- --- -- ------ Offset ~'1'ellpath --- ---------------> Reference Offset Ctr-Ctr No-Go ~Ilowable Site Well ~Vellpath y1D yiD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-118 1J-118 V9 283.41 275.00 215.37 5.79 209.58 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L1 V5 283.41 275.00 215.37 5.66 209.71 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L2 V4 283.41 275.00 215.37 5.66 209.71 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118P61 V4 283.41 275.00 215.37 5.90 209.47 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118P62 V5 283.41 275.00 215.37 5.90 209.47 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120 V5 283.71 275.00 189.29 4.97 184.32 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1 V3 .283.71 275.00 189.29 4.84 184.45 Pass: Major Risk Kuparuk 1J Pad 1J-120. 1J-120L1PB1 ~V4 283.71 275:00 189.29 5.08 184.21 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1PB2 V6 283.71 275.00 189.29 5.08 184.21 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1P63 V6 283.71 275.00 189.29 5.08 184.21 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L1P64:V4 283.71 275.00 189.29 5.08 184.21 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2 V3 283.71. 275.00 189.29 4.84 184.45 Pass: Major Risk Kuparuk 1J Pad 1J-120 1J-120L2P61 V3 283.71 275.00 189.29 5.08 184.21 Pass: Major Risk Kuparuk 1J Pad 1J-122 1J-122 V6 261.04 250.00 166.58 4.97 161.62 Pass: Major Risk Kuparuk 1J Pad 1J-122 1J-122L1 V7 261.04 250.00 166.58 4.97 161.62 Pass: Major Risk Kuparuk 1J Pad 1J-122 1J-122L2.V6 261.04 - 250.00 166.58 4.97 .161.62 Pass: Major Risk. Kuparuk 1J Pad 1J-122 1J-122PB1 V7 261.04 250.00 166.58 4.97 161.62 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127 V7 272.32 275.00 148.37 5.06 143.30 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1 V3 272.32 275.00 148.37 4.93 143.43 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1PB1 V3 272.32 275.00 148.37 5.17 143.19 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V2 272.32 275.00 148.37 4.93 143.43 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V2 272.32 275.00 148.37 5.17 143.19 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P62 V2 272.32 275.00 148.37 5.17 143.19 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V3 261.63 250.00 202.32 5.21 197.10 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 L1 V4 40.00 40.00 202.79 No Offset Stations Kuparuk 1J Pad 1J-133 Plan 1J-133 V1 40.00 40.00 202.79 No Offset Stations Kuparuk 1J Pad 1J-135 1J-135 V2 370.76 375.00 231.54 6.46 225.08 Pass: Major Risk Kuparuk 1J Pad 1J-135 1J-135L1 V3 370.76 375.00 231.54 6.09 225.45 Pass: Major Risk Kuparuk 1J Pad 1J-135 1J-135L1P61 V4 370.76 375.00 231.54 6.09 225.45 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136 V2 293.74 300.00 248.27 5.12 243.15 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1 V3 293.74 300.00 248.27 4.97 243.31 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1P61 V3 ,. 293.74 300.00,; 248.27 5.12 243.15,. Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1P82 V4 293J4 300.00 248.27 5.12 243.15 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136PB1 V5 293.74 300.00 248.27. 5.12 243.15 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V13 647.59 625.00 270.46 9.59 260.87 Pass: Major Risk Kuparuk 1J Pad 1J-158 1J-158 V6 295.49 300.00 339.93 5.05 334.88 Pass: Major Risk Kuparuk 1J Pad 1J-158 1J-158L1 V3 295.49 300.00 339.93 4.92 335.01 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L1 V6 272.00 275.00 300.36 5.51 294.85 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L2 V2 8979.41 11750.00 391.88 138.58 253.30 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164 V4 308.94 300.00 200.05 5.69 194.36 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V2 308.94 300.00 200.05 5.56 194.49 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2 V3 308.94 300.00 200.05 5.80 194.25 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2P61 V2 308.94 300.00 200.05 5.69 194.36 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V6 285.52 275.00 159.41 5.13 154.28 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V4 285.52 275.00 159.41 5.00 154.41 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1PB1 V4 285.52 275.00 159.41 5.00 154.41 Pass: Major Risk OR!GI~IAL '~ Halhburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/21/2007 1"ime: 14:06:46 Pagc: 2 Field: Kuparuk River Unit Reference Site: Kuparuk 1 J Pad Co-ordinate(NE) Reference: Well: Pla n 1 J-174, Tr ue North Reference'tl`eIL• Plan 1J-174 Vertical (TVD)Reference: Doyon 15 (40+81) 121.0 Reference VI'ellpath: Plan: 1J-174 Db: Oracle Summary -- <-- ------------------- Offset'ti'ellpath -------- - ----------> Reference Offset Ctr-Ctr No-Go :Ulowahle Site Well Wellpath MD MD Distance Area Deviation Warning ff ft ft ft ft Kuparuk 1 J Pad 1 J-166 1 J-166L2 V2 285.52 275.00 159.41 5.00 154.41 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2PB1 V2 285.52 275.00 159.41 5.00 154.41 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168 V6 358.69 350.00 120.59 6.37 114.22 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V4 358.69 350.00 120.59 6.24 114.35 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V3 358.69 350.00 120.59 6.24 114.35 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2PB1 V2 358.69 350.00 120.59 6.24 114.35 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V3 1446.78 1475.00 79.19 22.30 56.89 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V2 1446.78 1475.00 79.19 22.17 57.02 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V2 1446.78 1475.00 79.19 22.17 57.02 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P61 V2 1446.78 1475.00 79.19 22.30 56.89 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P62 V2 1446.78 1475.00 79.19 22.30 56.89 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180 V4 249.59 250.00 120.70 4.66 116.03 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1 V3 249.59 250.00 120.70 4.51 116.19 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1PB1 V1 249.59 250.00 120.70 4.66 116.03 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180PB1 V1 249.59 250.00 120.70 No Offset Errors Kuparuk 1J Pad 1J-182 1J-182 V3 199.69 200.00 161.29 4.18 157.11 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1 V8 199.69 200.00 161.29 4.02 157.26 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1PB1 V5 199.69 200.00 161.29 4.02 157.26 Pass: Major Risk Kuparuk 1J Pad 1J-184. 1J-184 V6 600.62 575.00 196.44 9.19 187.25 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V6 600.62 575.00 196.44 9.03 187.41 Pass: Major Risk Kuparuk 1J Pad Plan 1J-119 (M15 P helan 1J-119 VO 40.00 99.00 202.40 No Offset Stations Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 40.00 40.00 157.91 No Offset Stations Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 L1 V1 Plan 273.21 275.00 151.63 5.66 145.97 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V3 Plan: 1 273.21 275.00 151.63 5.82 145.82 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V3 40.00 40.00 158.10 No Offset Stations Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V3 40.00 40.00 166.72 No Offset Stations Kuparuk 1J Pad Plan 1J-132 1J-132 V3 40.00 40.00 189.27 No Offset Stations Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 40.00 40.00 20.12 '~ No Offset Stations Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 V1 Plan 4375.00 4375.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 L1 V1 Plan 627.05 625.00 37.97 10.43 27.54 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 V1 Plan: 1 627.05 625.00 37.97 10.43 27.54 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V3 Pla 580.46 575.00 78.18 9.42 68.76 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V3 Plan: 580.46 575.00 78.18 9.42 68.76 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 L1 V4 Plan 11100.35. 14418.17 109.37 235.69 -126.32 FAIL: Major Risk Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 V8 Plarr.,1 11108.18 14421.07 155.13 196.37 -41.24 FAIL: Major Risk Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162 V1 11110.16 14490.00 161.83 34.42 127.41 Pass: Minor 1/200 Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162L1 VO 11099.25 14489.00 107.67 45.02 62.65 Pass: Minor 1/200 Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162L1PB1 VO 297.11 300.00 239.96 5.32 .234.64 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162PB1 V8 297.11 300.00 239.96 5.32 234.64 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162P62 V1 297.11 300.00 239.96 5.32 234.64 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V2 293.83 300.00 227.76 6.77 220.99 Pass: Major Risk Kuparuk 1J Pad WSP-06 WSP-06 V3 294.43 300.00 197.53 6.76 190.77 Pass: Major Risk, Kuparuk 1J Pad WSP-07 WSP-07 V2 295.07 300.00 181.53 7.51 174.02 Pass: Major Risk Kuparuk 1J Pad WSP-08 WSP-08 V3 332.99 325.00 185.91 10.29 175.62 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V2 320.01 325.00 207.10 7.11 199.99 Pass: Major. Risk Kuparuk 1J Pad WSP-10 WSP-10 V2 337.28 325.00 241.13 7.08 234.05 Pass: Major Risk Kuparuk 1J Pad WSP-20 WSP-20 V2 313.88 300.00 203.16 6.25 196.90 Pass: Major Risk Non-Pad KRUST-02 KRUST-02 VO 17550.68 3675.00 967.50 189.54 777.96 Pass: Major Risk ~~~~,~~~ SURVEY PROGRAM Date: 2007-OS-2ITOU:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 40.00 1000.00 1J-174 (wpll) C&GYRO-SS 1000.00 4000.00 1J-174 (wpll) ~1WD+IFR-AK CA~SC 4000.00 19695.99 1J-174 (wpll) O1~VD+IFR-AK CA~SC 300 1J-182PB2 ..1.-- WSP-10 - - '~ t,' ~ t,~/J/)~ ''~~~ , ^„~\ 1J-135 - `f2 % ~~ a ~ 3 ^ ~ >+' `~\ 1J-136 /y(y 210 ~ i~1.(x 150 \\\ \ J ~ ~~ / 1 ~ ~ \ 180 ~ 1 1J-178(wp03) ~ ~ 1J-176(wp05) 18-2 '=`7u2 Travelling Cylinder Azimuth (TFO+AZI) [°~ vs Centre to Centre Separation [200 it/inJ ~ REFERENCEINFORMATION I Co-ordinate (NIE) Reference: Well Plan 1J-174 (01 Phase 2) -Slot 1J-174, True Vertical (TVD) Reference: Doyon 15 ~ 121.OOft (Doyon 15 (40+ 81)) Section (VS) Reference: Slot - 1J-174(O.OON, O.OOE) Measured Depth Reference: Doyon 15 ~ 121.OOft (Doyon 15 (40 + 81)) Calculation Method: Minimum Curvature COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based WSP-20 1J-170 1J-166 `~ WSP-05 1 WSP-O6 ~ ~ ~ I I ~ l0 ` ` 1 I I~ 1 J {43 ` ` I I I ~."< , ` ` I I 1 1J-127 ~30 1 1 I I I 1 I 1 I / ] ~oly~~. .I; I ~ ~ I ] 30• _ -, d {-''_ ~~~'~ , ' ~ i WSP-08 From Colour To MD 40 250 250 500 500 750 750 1000 1000 1250 1250 1500 lsoa nso nso -- zooo 2000 _......_...-___.. 2250 2250 2500 2500 2750 2750 3000 3000 - 3250 3250 3500 3500 3750 3750 4000 4000 4250 4250 4500 4500 4750 also - - - -sooo sooo szso s25o ssoo 5500 ................__.,... 5750 5750 6000 6000 6250 6250 6500 6500 6750 6750 7000 7000 7250 7250 7500 7500 7750 7750 8000 8000 8250 8250 --------""` 8500 8500 ...."..... 20000 NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-174 (01 Phase 2) ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 40.00 To 19695.99 Maximum Range:2165.59915758557 Reference: Plan: 1J-174 (wp11) 330 ,r-,; ''~ 30 _ `. 300 / % / ~_ \ \~l1h~. 60 90 ~~ I 50 , y\l E ~ ~ ~ II 210 ~ '' 150 60 ---'' 180 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation 135 ftiinl Ground Level: 81.00 +N/-5 +EI-W Northing Easting Latittude Longitude Slot 0.00 O.OD 5945536.61 558740.81 70°15'42.494N 149°31'30.524W 1J-174 s6cnoM D6Tn1~s Sec MD Irrc An ND ~WS ~E1-W DLeg TFace V6ec Target 4o ao aoa °60 4ow BO° 0.09 0.09 oao °ao z zw.9o Ooa oa9 zw.oo ow 9.oB 3 550.00 9.00 22]00 548.]] 1604 .1].20 o.9B J.00 909 o.a0 22100 16.04 1 1692.41 53.% 248.9] 1500.00 -255.59 -541.]3 4.00 2500 255.59 5 1]92.41 53.% 248.9] 1558.81 -284.61 bt].20 0.00 000 281.61 6 25]9.13 ]500 23100 18%.% .610.30 -124160 ] 4100.00 ]500 23]00 3290.53 1110.31 -24]3.]1 300 0.00 -3000 61030 000 1410.31 8 4]88.33 6]65 23]00 2313.89 -1%d46 -2711.12 300 000 1564.46 9 4481.22 8365 235.00 2351% -160d97 -2]]1.18 2.15 .90.00 1604.97 10 8%1.23 83.65 235.00 2860.26 _d]4038 -]248.8] 1339.05 0358 9?56 -]99]41 000 306 0.00 4]4038 '<42 J1i "7 i°e I~II~~i40~~0;4U] I 12 11]5560 8368 1]].BO 3165.52 -62634] -0028.]5 362 9000 6263.d7 1J 11969.08 83.68 1]1.80 3189.00 b4]521 -002162 000 0.00 6415.31 14 1199908 BJ.BB 1]].80 J192.J0 650501 -00209] t5 12250.26 81.45 171 d2 3202.98 675153 -]988.90 000 4.00 000 8505.01 -38.52 6]54.53 18 12345/] 91.45 1T1A2 JZ00.% b84861 .]982.]1 0.00 000 6848.64 17 124%.% 89.% 1]].25 3188.]) 398831 .]86).86 4.00 101.5] 6990.31 10 13095.% 6993 ]]25 3199.A -7591 64 -]93908 0.00 000 ]59)64 tJ ti4 rA06~-P_rli of Oi 19 1]286.35 %.01 1]8.15 Jf89.61 -7]8].91 -]933.10 20 14195 d] 9001 915 3199.50 -66%94 191965 1.00 000 8].fi9 7/8].91 000 e6%94 1J-1 ]0 M8 B GP)0]/0107 _ _ 21 14284.% ~~ 1]8.88 3199.22 -0]Be.M -7918.94 23 14995 Cv 1]960 1489 1.00 0.00 49.69 e]98.M 0.00 949]07 1J~1]4 MB BGP40]N10] 2J 15010.65 %.54 179.55 1193.zT 351201 .191x.19 1.00 5823 %12.0] _ _ 4 1589588 9p 54 17955 JI8500 -10]9724 -]%]91 O.DO 000 1039]24 111]4 M8 B CP50]/010] _ _ 25 15810.09 %.10 1]8.51 ]181. ]fi -10141.45 -7%7.55 26 16816.10 90.10 1]951 JIB].30 -I ]1142 -7500.09 1.00 000 -174.44 10441.45 000 1131]42 111]4 M8 B CPBO]N10] 27 16%8.42 90.82 1]8.52 ]182.8] -11368.15 -]888.&1 28 1]618.32 9062 1]952 3174.% -131115] -IB9].3J 1.00 000 0.4] 11389.15 - - 000 1211]57 1J-1 ]4 M8 B CP10]NYOT 29 1])01% 89.]0 179.sz 3174.64.1230933 .]992.58 1.00 _ _ 179.82 12209.23 ]0 1829549 8970 179.52 317] ]0 ~12i9610 ]88162 31 18920.93 %.% 1]8.51 ]1]6.% -12922.13 -]899.% 000 1.00 000 12]%.70 1J~1 ]4 MB B CP80]/OJNI -083 12822.13 J2 1%9599 9096 1]951 31,5.0 -1413b 96 -]6]554 0.00 000 141%.98 111]4wpOGBTae 071010] SURVEY PROGRAM Date: 2007-08-21700:00:00 Validated: Yes Version: Depth From Depth To Survey/121an Tool 40.00 1000.00 IJ-174(wpll) C~GYRO-SS 1000.00 4000.00 1J-174 (wpll) MWD+IFR-AK-CA~SC 4000.00 19695.99 1J-174 (wpll) MWD+IFR-AK-C.42rSC COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based 0 270 180 90 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X200 ft/ink REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 7J-174 (01 Phase 2) - Slot 1J-174, True Vertical (TVD) Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Section (VS) Reference: Slot - 1J-174(O.OON, O.OOE) Measured Depth Reference: Doyon 15 @ 121.OOtt (Doyon 15 (40 + 81)) Calculation Method: Minimum Curvature From Colour To MD a0 - - 8500 8500 --"-~" 8750 8750 9000 9000 9250 9250 9500 ssao s7so 9750 10000 10000 10250 10250 10500 10500 10750 10750 11000 11000 11250 11250 `-"-~- ---- 11500 11500 11750 11750 12000 12000 12250 12250 --- 12500 12500 12750 12750 13000 13000 13250 13250 13500 13500 13750 13750 14000 14000 14250 14250 14500 14500 14750 14750 ~~_-~- ~~~~ ~ ~ 15000 15000 15250 lszsa lssoo 15500 15750 15750 16000 i6o00 16250 16250 18500 16500 16750 16750 17000 17000 -- 17250 17250 17500 17500 17750 17750 -- 18000 18000 18250 18250 18500 18500 ~-'-_ - 18750 18750 -_' 19000 19000 19250 19250 19500 19500 19750 19750 20000 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 8500 To 19695.99 Maximum Range: 2165.59 Reference: Plan: 1J-174 (wp11) 330 I 30 -__. 50_, --,,. 40 300 60 3 2 90 240 120 40 50 210 150 60 180 Travelling Cylinder Azimuth (TFO+A"LI) ~°J vs Centre t° Centre Separafion (35 ft/in( SECTION DETAILS 5« MD IM Aal ND ~WS AEI-W OLeg TFeu VS« Tary41 1 4D.W °W o.W 4o.W °W D.oo aW BDO 9W z zsoao o.W 9W 250.W o.W 9W o.W 9W 9W J SSO.W 9.W 12).W 54e.]I -1601 -1].20 1692 41 53.% 248.9] 1500.W -255.59 541.13 3.W 4W Z21.W 18.01 ZS.W 2%.% 5 1]9291 53.% 248.9) 15%.61 -28481 EI].20 O.W OW 261.61 6 2s]9.13 ]s.W 23].W leesSO -61a.3a -1241.% 3.% aD.W 61a.3o ] 41WW ]500 23).W 22%53 -141031 -2473.)1 e 4388.3) 83.% 23iW 2343.89 -156446 -2]11.12 0.00 J.W OW 1410 J1 OW 1561.48 9 M8122 8365 235.00 2351% -ifi01.9] -27]1.18 10 8961.22 93.% 235.W 2860.% )]40.28 -]248 8] 2.]3 O.W 90.W 1801 H] o.W 4140.28 11 JJ905 BJ 68 19256 311950 -585201 -799:47 ]O6 242 585201 }I: rvy p H°e10110301 12 11)%.88 8]68 177.% 3165.52 -62634) -0OR.]5 352 -9000 636).47 13 119fi9.W w.m lneo 31e9.W 647s.r 43on.62 o.W BW w]s.z1 t4 1f9%.% 83.68 1]7.60 319130 .6505.01 -0020.41 15 1225026 9145 1]1.92 3202.98 6]5453 -]g86.% OW 4.W 8W 8505.01 -)8.52 6]54.53 18 123454) 91.45 17142 320058 -684864 -1982.]1 O.W O.W 881884 17 12485.% 89.93 171.25 31%.P -6998.34 -]86188 4.W 101.51 BBBB.N 1B iJ095% 17).25 3199:4 - -793909 18 13288.35 %.Ot 1]8.15 31%81 -]]6]91 -)933.10 OOD 1.W 000 ]59i 64 IJ-1 ]4 MbB R20]/010i 8].69 )]81.81 41954] 9001 1)915 ]19950 86%9A -]919.65 1 000 000 Bb%.94 1J-I ]4 M8 B CP]0)1010] 3 14281.80 %.48 1)9.88 ]1W.22 -0]66.M -)918.94 22 14995.65 90.46 11968 31%40 945]0] .)91489 1.W 000 49.W eIW.44 000 949)0] iJ-i ]d MB B_CP401I010] 23 15010.% 80.51 179.% ]183.27 -%12.07 -791/.79 1.W 5823 %12.0] 15895.88 %54 17055 JI8500 -10]9]24 ~T%]91 000 000 1039724 1}1)4 M8_B CP50]g10I 25 15B40.W %.10 1]9.51 3181.]6 -1004145 -780].55 610 %1D 17951 JI e]JO -1131142 -19W 09 l.W OW -1]944 10M1.45 000 1131]43 1}174 MB BCP80)8110] NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-174 (01 Phase 2) n i88Bdu %:6z 1]8.52 3182.9] -T13W.]5 -0898.W iW as n3W.]s - - 28 176 I6.3I 9062 1)951 )114%-121115] .IB9]JJ 000 000 12i1]Sl 1J-I )1 MB_B CPI OIr060] 28 1T)D7.98 B9.1D 1)852 3111.64 -12208.23 -)892.% 1 OD 1]982 122082] GfOUnd Level: 81.00 B Js4 -9s D .1n 6 ; sz o.DD ow m%.]o ua]4 MB_e cPe o7ro3ro1 J1 84308) %% 1]9.51 31]6%-1292213 ]8%.56 00 -Ofi3 13822.13 +N/-S +E/-W Northing Easting Latittude Longitude Slot .. _ 9 .. .. -D .... ,.~ 0 0011 i41%% ,J-n4wWBJ°°o]~9Jlm 0.00 0.00 5945536.61 558740.81 70°15'42.494N 149°31'30.524W 1J-174 Cant~coP'hillips ~~~~ ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1 J Pad ~' Plan: 1J-174 L1 (wpll) 1/4 Mile Pool Scan Sperry Drilling Services August 27, 2007 ~ 1 /_ R t_w. -...,, .s~t?~?:kn^^~ c ~.__.~~: ~_ ~:~:;... ,°c:;:a~.,'3: ~,....,~..~;sl~liFe"~~.Fsti::~L'+.i~1"; .':'sue ,., ;'~'//.-^'`~., ..,., , , . . ,.. _,_ ~`'yT'`ui4$~C~~ "fe.._: ~.,~".-^.uF.~4SL3.. .-'sT"'r:3.14iJ::.b3';..A., .,.., ,.:':~4'4„i;'.,`X7~"~S: ~i~:l: -'::ow:#Y :: ate'.`...... --_ ,.. .,:lV<, ..~ Lam' ~ _^ ,:.,r .. Y.~~..~ ,.-. a ,,..... :aw... ': :. i, LL.IBIJ T Drilling and Formation Evaluation • Closest in POOL Closest A roach: Reference Well: 1J-174 L1 w 11 Plan Offset Well: 1J-162 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W _) 180° Comments De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments P L Min Distance (268.02 ft) in POOL POOL Min Distance (268.02 ft) in (11339 - 19691.64 POOL (11339 - 19691.64 MD) to 1 J MD) to 1 J-162 L1 174 L1 (wp11) Plan (9953 -14489 268.02 +'' ~ j 11339.05 83.68 192.56 2998.679 5939621.9 550794.6 5852.134 (9953 - 14489 MD) 14489 89.05 180.77 3019.832 5939888.1 0772.1 5585.726 MD) Closest A roach: Reference Well: 1J-174 L1 w 11 Plan Offset Weii: KRU STA TE 02 ~o-L3- Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 180°) Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments P OL Min Distance (1038 ft) in POOL (11339 - 19691.64 POOL Min Distance (1038 ft) in MD) to KRU STATE POOL (11339 - 19691.64 MD) to 1J 02 (2970.8 - 3070.3 174 L1 (wp11) Plan (2970.8 - 1038 17425 90.63 179.52 2979.314 5933544.2 550940.1 11930.76 NDss) 3225 19.92 229.84 3076.57 5933557.4 551973.4 101.77 3070.3 TVDss) POOL Summary.xls 8/27/2007 10:20 AM 1J-174 drilling Hazards S~r-mary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced ~ drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12-1/4" Open Hole / 10 3/4" x 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low ~ Stripping drills, shut-in drills, increased mud Pressure wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced ump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pum ing out, backreaming ,~ 1J-174 Drilling Hazards Summary E a ~ !~ ~ ~ prepared by Dennis Hartwig ~:.,.,+' q ~ 10/11/2007 3:23 PM Schlumberger Rig: Doyon 15 Location: Alpine Client: ConocoPhillips Alaska, Inc. Revision Date: 10/10/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface .~ Previous Csg. < 16", 62.6# casing at 114' MD < Base of Permafrost at 1,744' MD (1,530' TVD) < Top of Tail at 3,200' MD i i ~~ ~ 4 i fa~~ < 13 3/8", .0# casing in 16" OH TD at 4,000' MD (2,265' TVD) * Mark of Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,200' MD. Lead Slurry (minimum pump time 310 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.2927 ft3/ft x (114') x 1.00 (no excess) _ 0.4206 ft3/ft x 1630' x 3.50 (250% excess; 0.4206 ft3/ft x 1456' x 1.35 (35% excess) 33.4 ft3 + 2399.5 ft3+ 826.7 ft3 = 3259.6ft3 / 4.45 ft3/sk = Round up to 740 sks 33.4 ft3 2399.5 ft3 826.7 ft3 3259.6 ft3 732.5 sks Have 300 sks of additional Lead on location for Top Out stage, if necessary, Tail Slurrv (minimum pump time 230 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 0.4206 ft3/ft x 800x 1.35 (35% excess) = 454.2 ft3 0.8315ft3/ft x 80' Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft = 520.7 ft3 520.7 ft3/ 2.28 ft3/sk = 228.4 sks Round up to 230 sks BHST = 46~, Estimated BHCT = 66~'. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Comments Rate Volume Time Time Stage (bpm) (bbl) (min) (min) CW100 5 20 4.0 4.0 Start Pumping Wash Drop Btm Plug 10.0 14.0 MudPUSH II 6 50 8.3 22.3 Start Pumping Spacer Lead Slurry 7 587 83.9 106.2 Mix and Pump Lead Slurry Tail Slurry 6 93 15.5 121.7 Mix and Pump Tail Slurry Drop Top Plug 8.0 129.7 Displacement 7 571 81.6 211.3 Start Displacement Slow Rate 3 10 3.3 214.6 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ~ 17-20, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest-and 2 per joint across shoe track for proper cement placement. ORIGINAL Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 10/16/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. {p~~ < 13 3/8", / casing at 4,000' MD < Stage collar at 9,000' MD < Top of Tail at -,~ 10,000' MD ,~ ~~ ~, < 9 5/8", # casing -~ in 12 1/4" OH I ~ TD at 12,000' MD (3,231' ND) ' Schlumberger CemCADE Preliminary Job Design it v Intermediate 1St Sta e 'Rr i ary Job Design based on limited input data. For estimate purposes only. ~~ 1~,~6 TWO STAGE -Stage 1 Volume Calculations and Cement Systems Volumes are based on 35% excess. Slurry is designed for TOC of the cement at 9850' MD. Tail Slurry Minimum thickening time: 320 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.3132ft3/ft x 2000' x 1.35 (35% excess) = 845.6ft3 0.4341ft3/ft x 150' (Shoe Joint) = 65.2ft3 65.2ft3 + 845.6ft3 = 910.8 ft3 910.8 ft3/ 2.26 ft3/sk = 403.0 sks Round up to 410.0 sks BHST = 67~, Estimated BHCT = 68~. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Vol Stage Cumulative Comments Rate Time Time Stage (bpm) (bbl) {min) (min) CW 100 5 100. 20.0 20.0 Start Pumping Wash 10.0 30.0 Pressure Test Lines MudPUSH II 6 100 16.7 46.7 Start Pumping Spacer Tail Slurry 6 165 27.5 76.2. Mix and Pump Tail Slurry Drop Top Plug 10.0 86.2 Drop Top Plug Water 5 20 4.0 90.2 Start Pumping Water Switch to Rig 5.0 95.2 Switch to Rig pump to Pump Displace Displacement 6 882 147.0 242.2 Start Displacement Slow Rate 3 20 6.7 248.9 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible. to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: As per CPAi program. Highly recommend also centralizing above and below the stage collar ORIGINAL • Schlumberger CemCADE Preliminary Job Design ~k~ " ntermediate 2nd Stage Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 10/16/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Mobile: (907) 952-0445 email:. mtorrie@slb.com Previous Csg. CpD < 13 3/8", casing at 4,000' MD < Top of cement at 6,744' MD ~y < 9 5/8", 36.0# casing in 12 1/4" OH Stage collar < at 9,000' MD, 2,905' TVD Felimina_ ry Job Design based on limited input data. For estimate purposes only. ~~ ~ ~-CO O STAGE - Staae 2 Volume Calculations and Cement Systems Volumes are based on 35% excess. Slurry is designed for 2256' MD annular length. Stage collar set at 9000' MD. Tail Slurry Minimum thickening time: 270 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.4341 ft3/ft x 2256' x 1.35 (35%excess) = 953.9ft3 953.9 ft3/ 2.26 ft3/sk = 422.1 sks Round up to 430.0 sks BHST = 60~, Estimated BHCT = 73~. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Comments Rate Volume Time Time'. ~~ Stage (bpm) (bbl) (min) (min) CW100 5 100. 20.0 20.0 Start Pumping Wash 10.0 30.0 Pressure Test Lines MudPUSH II 6 100 16.7 46.7 Start Pumping Spacer Tail Slurry 6 173 28.8 75.5 Mix and Pump Tail Slurry Drop Top Plug 10.0 85.5 Drop Top Plug Water 5 20 4.0 89.5 Start Pumping Water Switch to Rig 5.0 94.5 Switch to Rig pump to Pump Displace Displacement 7 666 95.1 189.6 Start Displacement Slow Rate 3 10 3.3 192.9 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.2 ppg; Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: As per CPAi program. Highly recommend also centralizing above and below the stage collar a~~a~~ 0 ^~ V .~~~ Wellhead / Tubing I Tree: 133/8" x 4112", 5,000 psi ~~ Insulated Conductor: 20" 94# K-55x34" 0.312 WT +l- 80' ConOCOPhi I li pS 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMT^") System --- 10.314' ,L-80,BTC Casing Dual lateral Completion ~3800'M° 1J-174 HB DLP WP 11 GLM, Camc 41/2" x 1" KBMG, 13318" Casin hoe, set @ <67 de +/- 2200' MD 68#, L-80, BTC 4000' MD, 2265' D, 75 deg inc / +l- 748 D -Bottom of Motor Centralizer Centrali 418 HP KMHFER with FC6000 Pump Tubing String 4112" 12.6#, LSO, IBT 58" ID, 3.833" Drift -Sand Casing Exit 11 ~MD.3120'ND, aD' Sand Lateral 83 deg innc T' % 8" RAM Hanger 5. "Lateral Drih ID / 41/3" 11.6#, ~0 BTC, Ld0 Slotted Liner 3. Mainbore Drift ID ( R...e^ea>,~ :,...,,,~ y II 3.562" D fipple ifi ti E i t S 4Y:" z 9-518 M Seal Bore pec ca ons gu omen DiverterlSBD) wi 3.68"Seal Bore 7" X 9-518" RAM Junction ML Production Anchor '\ Mainbore Daft: 3.68" l2" t26# IBTM Tubing Lateral Drift: 5.80" RAM Hangerl8eal Bore Diverter OD: 8.375" Seal Assembly 7" X 9-518" MLZ%P 4.75" Seal OD Overall Length of RAM Junction: 38.3 h Liner Hanger Packer 3.875" ID Seal Bore Diverter Running Tool: FJD Set at+l- 77,440 RAM Hanger Running Tool: HRD-E 4-112" Lateral Entry Module Sealbo a Receptacle LEM OD: 6.99" 75" ID Mainbore Drif[ wlo Diverters: 3.68" Mainbore Drift wl Isolation Diverter: 2.50" 9-518" Casin SI Lateral Drih wl "FB" Diverter: 3.68" OD of Divarters: 1.68" V ~~ ~,~ Baker Oil Tools . ~." Lateral Acc A95lmblY 8nala _ 9b/8"ML TOrr•ueMaater ess "FB" Diverter lka in LEMI Ilnslalle~din~I.EM) r Px9er poaiCrv. Latcmrq covet maicaka coned Locano" snap Imsnap out Orienting Pralik Paa Rive Loraling Colkl (Amonmtlc Aligomenl or lEM In Lateral Diverler Lateral lsoklion RFM angea Ramp Upper 9eala seal gore fm Lateral Isolation Diverler " Snap INSnap Out 7.89 ID Poaitlve Locating covet talent Acce:a wneow IPIOV1Eaa POSltlve Lw-Y attass V6 _ La[eral laolatbn TM„TUtlng ONMarI j Lower Seala (seals insitle RAM al B Diverler) S _ , ~', Note: GS Spear used for running and pullin e g diverlers 4112" Guide Shce, 6.00" OD 41/2" Casing Shoe, 11.6#, L-80 BTCM 19691' MD, 3079' ND As Planned 5-113" 15.5#, BTC, L-80 Slotted Liner 5-112" Eccentrk 1 1,9.., 5112" Cas ~1 40.0#, L-80 BTC ND, 84 deg inc 15.5#, L-80 BTC% 3156' ND i • • ~-• M ... .-• N 0 ti V 0 O •.+ W Q Q a W ° 0 0 o 0 ° 0 0 0 o ° ° ° o L° o ` ~ ~ ~ ~ ~ O O O O O 0 O O O 0 ti 0 0 0 0 c~ 0 0 0 0 0 0 0 0 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~ ~ ~~ PTD# ~ 7 ~ ~ 7` y Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Atl dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (.Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13200? ~ ~ ^^ rn N o ~ , ~ ; c. . c Q ~ N. c ' o, ~ , ~ ~ 'n, a~ -, a, E '3, ~ ~ ~ ( ' ~ - ° ~ ~ m ~. °, r 5 ~; ; a o ~, 3, w' o i c i ~ N _ ~ L, o' ~ y as ~ c d ~ °, ~, t i ~ a° D ~ ~ Q m i ° o ~ ; ; a E a E O . T ° c ~ , , . o ~o ~ o ° a >, o, o, • ° ° o ~ ~ i o. ~; ° ~ ~ aNi N c . ~ ~, ~ in <o' c O ~; ~ o O ~ ~ d C.1 >; a s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ f6 3' ~ O u' ~ ~~ m ~ ~ a. c _ , ~ N U ~ ~ c 3 m ~ ~ ~ ~ 3, .°~ x y, ~ c' ~ ~ ~ ~ ~ ~ ~ ~ ~ - ~ Q. °, U. n ~ ~~ ~ ~ N. ~ m' ~ N, a~ ° ~' X. a~ ~ a ~ _ ° ° aY ~ ~. C• - T ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ -p. L. ~ ~~ ~ C. o N. W j. T m ~ ~ ~ ~ N• ~ ~ Q N. O, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N. ~, ~ , ~ Of ~. = d~ N O ~ ~ J' i y, _~ Q ~ ~ ~ ~ ~ ~ ~ v ~ ~ ~ d ~ C. W, ~ ~, ~ ~ O. ~~ ~~ ~ ~ Y Q. ~ a~ 3. 3 a~ ~, ; i ~ ; 'o. v ~ ~ ~, ~ ~ ~ a. ~ T 3 . c. ~ a~, Z r ~, n. _, a o, ~ ~ ~ c' . ~ c' ., ~, f ~; ~ y O N O ~ O, ~~ - N. ~~ ~ ~ ~ ~ ~ ~ ~ ~ O. ~ ~ O. ~ ~, ~ T ~ N. . O ~ 0 ~ O d Y, ~, ~ O V` ~~ d ~, X d ( N O N O = Z ~ ' ~' T O' O~ , ~ . ~ ~ ~ ~ I ~ __~ ~ ~ . m ~ O, f0. ~ ~ N' ~ O' ~~ _~ 1 ~ ~ ~ N tq. tp, UA N~ Q; o a~, o, o, a~, N N~ N~ a~ a~, a~, N~ O~ a~, a~, N~ a~, t~ o Q. Q; Q; Q N~ ~ d, Q. N~ a~, ~ o, o N~ tq~ a~, a~, N~ Q a~, N, UD N~ a~ a~, a~, UL y, a~, a~. y a~ o; Q; y~ N, a~, a~, Q; Q, Q T Z, Z } } }. } } } } } } } } z z z z } z } Z Z } } z } } } } } } } Z Z ~ >-, Z, Z Z ~ O' I , ~ E. ° : , O, $. ~ . >i ~ O ~ ' c O Y c, o, ` - ~, Z, ~, D, a, a~, a i ~ Z, ~' is ! \ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ `~, ui, Q' O1 ~~ ~~ °, ~~ o~~ o. °~ ; ; a ° o, t ° c. ° rn 3. •~ o, ~, 3 ~ ~ a o ~ ~ o; N a ~ ~ o. ~ 1 a g o ~, i a ~ N, ~ V N ~ ~ _~ t, 3 ~ N f0 `, ~, N' T f6 j, . N, it i, ?~~ ~ ~ ~~ a C~ °~ L~ °~S~ ~ ~ N ~ y' ~~ > ~ ` O~ ~; ~~ ~' I ' ~ Q' 7 to f/i ' ' ' ~ ~ ~ ~ ~ ~ -` ~ p. 01 , ~ C. - , , a fU, O N. d ~ ~ O. C. ' m. ~ C O: O. O CS + ' d' 7 ~ L ' y N O N O, C, ~ Q) ~ ` JJww.. Y ~ Z - O ~ ~ ° _ N, ~ ° O N~ :p E t!") ,, .0 >, w, M, ~ ~ C' U ~ ~~. N .?~ ~ ' a, ~ ° ~ N N, ~ ~ ~~ a., . C N~ ~~ C O, d O O ' ' ° a p~ N C E, E a c C r . N O C y F- C O KS ~ N .C C ~ Q 4. to a~; w w ~ o, c' ~' c, c 7 o ui o o' Q' ~ o' ~' ~ ° c a a °, U °~ m. c a~ m, f6 :?' ~, Q. m %a ~~ Q' >' ~°' ~' a o. ~ °, Y °~ ~ '~ a~ ,~ O, ~ >r O 3 a N N. ~ ~ ~ -Y, m, c fl: O. O ~ w, N. ' Y , ~ Q °, m' • ~, • _o m. m' , ~ a, ~, ° ' ' ~' ' ' m' oo ' ar ~' d 3, ' w' o' o' ' ' 3, ' ~ E O o (~ ° ui ui ' ` 3' ~ • 3; a~ a~; ~ v ar a? 3 m ~ O ° v ° : ° a~ m a~ o . w V ° n. a, o c, cam; ° -a ° a~ >; o' ~, cu `o. a of a m' o ~, '~ o ~, I o ~ o o, ~ a o a~ `t N o' m, -°o. E' a~ ~ ° E' o rn c ' ,c o ' i a n y; ~ o ~ a~, c a J ° d a' ~ ~: a~ s: ° a~ a~ o, °, ° a e ~ o, i v ~ o' a ~i m' Y' - a' a~ ~ ~' m' 'o E' m o' _ ~ :. ; ~ °, c o ti o' ~i ~ , L' ~ N• d d U. ~, O. O, O ~, .,k' d ~ °. ~ N ~ d f6 .C , r 'O' N, ~ C, ~ O: f0 f6 (0 f6~ O N' O N~ Q1 C. U ~ ' ' ~' N' ~~ j y' O' N' O. I t, ~ p ~ ~, ~, .S. d d m N, ~ N, ° ~y a~ 3, S -°, rn " c a Q m c ~; ~ ~ .= n t ~ o ~ o' o. •° aai, >. '' a i ii U m. .Q, -, a. a. a. v. •-, c' m' .Q, a a a. ~, ° ;~ •y a~ a~ >, .4? ~ s. ~ ~ ° '~ ~ ° n, c, ° ~ ~, ~ ~ z c c~' ° v , o, o, ° ~' o , ~, m. o ~' v' ~ v vi a' c, o v, a~, o ' o; ~ 3, ca m v, m °~ vi 'C, °s ~ ° .~ 3, , ~, y ~ ~ O U ~ _ o ° o o 3 ° c > > > > rn ~ N ~ d / Y ~, af6i .~ °~' °~' °~' ~ ~ ~; ° a o- ~, m ~ ~ ' . ~ o o. ~~ ~; ~; ~' m a, f°' a `o' •~ O O, .c°; °' °' ~' ' ' ~; m; '~; m o; m p U = a, ~ ~ ; ~; ; cn, -, O, O; a, a; U ~ , Q; a; z: c~, cn; v, c~, v; v; Q, "=; ¢, w -, o; m; °°, v, ; ~ ~; ~ a, o, cn, c~; U Q ~ O N M V ~ CO f~ i W O O N M V to O ~ W O O N M d' ! to O~ C+0 O V ° ~__ N_ M~~ (p h 00 O r _ N N N N N N N N N N _M M M M M~ M M M M M_ r+ N ~' N ,N N U C ~e,~~ O ~ r ~ N ~ N ~ N O N W _ i ~ ~ t q U" 4. ~ i O C ' ~ ~ ° E N o N y ~ ~ ~ C7 0 '~1 J ~# o ~ E °. ~ rn a~ a a O U `~ W ~ a ¢ a ~ w a ~ ~ ¢ ~ Well I-lisiory File APPENDIX ~~ Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. 1J-174.tapx Sperry-Sun ~rilliny Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 12 11:43:39 2008 Reel Header service name .............LISTPE Date . ...................08/03/12 Ori gin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/03/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF comment Record TAPE HEADER Kuparuk River Unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000527561 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON MWD RUN 6 JOB NUMBER: MW-000527561 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: Scientific Technical services Library. scientific Technical services 1J-174 500292337400 conocoPhillips Alaska, Inc Sperry Sun 12-MAR-08 MWD RUN 3 MWD RUN 4 MW-000527561 MW-000527561 R. WILSON R. WILSON M. THORNTON M. THORNTON 35 11N l0E 1724 2471 0 Page 1 ~o-~-_ ~y3 ~1~~5 1J-174.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 121.53 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 10.750 3927.0 2ND STRING 8.500 9.625 12080.0 3RD STRING 8.500 9.625 12080.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2-6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND AT -BIT GAMMA (ABG). MWD RUN 5 EXPERIENCED TOOL FAILURE- NO DATA IS PRESENTED. THIS WELL BORE EXITS 1J-174 PB1 AT 15140'MD/3194'TVD, AND FROM 1J-174 PB2 AT 17700'MD/ 3170'TVD. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4, & 6 REPRESENT WELL 1J-174 WITH API#: 50-103-20450-03. THIS WELL REACHED A TOTAL DEPTH (TD) of 19708'TVD/3157'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 Page 2 s ~ 1]-174.tapx FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPM RPS RPD FET ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3994.0 4008.0 4008.0 4008.0 4008.0 4013.0 4031.0 STOP DEPTH 19704.0 19663.0 19663.0 19663.0 19663.0 19663.0 19708.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3994.0 12089.0 3 12089.0 15140.0 4 15140.0 17700.0 6 17700.0 19708.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 Page 3 • 17-174.tapx RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3994 19708 11851 31429 3994 19708 ROP MWD FPH 0 10615.6 231.899 31355 4031 19708 GR MWD API 22.62 109.98 67.4389 31421 3994 19704 RPX MWD OHMM 2.59 2000 39.2965 31254 4008 19663 RPS MWD OHMM 0.46 2000 39.561 31254 4008 19663 RPM MWD OHMM 1.57 2000 38.8057 31254 4008 19663 RPD MWD OHMM 3.06 2000 37.3595 31254 4008 19663 FET MWD HR 0.11 173.99 0.869375 31244 4013 19663 First Reading For Entire File..........3994 Last Reading For Entire File...........19708 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3994.0 12053.5 RPS 4008.0 12046.0 RPD 4008.0 12046.0 RPx 4008.0 12046.0 RPM 4008.0 12046.0 FET 4013.0 12046.0 ROP 4031.0 12089.0 Page 4 17-174.tapx LOG HEADER DATA DATE LOGGED: 26-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME); Memory TD DRILLER (FT); 12089.0 TOP LOG INTERVAL (FT): 3994.0 BOTTOM LOG INTERVAL (FT): 12089.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 86.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3927.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 60.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.146 123.8 MUD FILTRATE AT MT: 1.700 75.0 MUD CAKE AT MT: 2.000 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames. per record .............undefined Absent value ......................-999.25 Depth units. .. .. ... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel Page 5 17-174.tapx DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MwD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MwD020 OHMM 4 1 68 24 7 FET MwD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3994 12089 8041.5 16191 3994 12089 ROP MWD020 FPH 0 10615.6 229.026 16117 4031 12089 GR MWD020 API 22.62 109.98 65.1933 16120 3994 12053.5 RPX MwD020 OHMM 2.82 60.69 11.0878 16077 4008 12046 RPS MWD020 OHMM 1.3 115.97 13.5712 16077 4008 12046 RPM MwD020 OHMM 1.57 110.82 14.2945 16077 4008 12046 RPD MWD020 OHMM 5.6 1394.79 14.7648 16077 4008 12046 FET MwD020 HR 0.13 80.46 0.726401 16067 4013 12046 First Reading For Entire File..........3994 Last Reading For Entire File...........12089 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........sTSLIB,003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12057.5 RPS 12075.0 RPM 12075.0 FET 12075.0 STOP DEPTH 15107.5 15099.5 15099.5 15099.5 Page 6 • • 17-174.tapx RPD 12075.0 15099.5 RPX 12075.0 15099.5 ROP 12090.0 15140.0 LOG HEADER DATA DATE LOGGED: 04-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15140.0 TOP LOG INTERVAL (FT): 12089.0 BOTTOM LOG INTERVAL (FT): 15140.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.35 MUD VISCOSITY (S): 74.0 MUD PH: .O MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): .000 .O MUD AT MAX CIRCULATING TER MPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units ....................... Page 7 • • 17-174.tapx Datum specificat ion Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MwD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12057.5 15140 13598.8 6166 12057.5 15140 ROP MWD030 FPH 0 1402.14 257.876 6101 12090 15140 GR MwD030 API 38.64 104.06 68.3547 6101 12057.5 15107.5 RPX MWD030 OHMM 2.59 2000 76.581 6050 12075 15099.5 RPS MWD030 OHMM 0.46 2000 73.9366 6050 12075 15099.5 RPM MwD030 OHMM 8.65 2000 68.0132 6050 12075 15099.5 RPD MwD030 OHMM 3.06 2000 64.002 6050 12075 15099.5 FET MwD030 HR 0.11 173.99 1.51001 6050 12075 15099.5 First Reading For Entire File..........12057.5 Last Reading For Entire File...........15140 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 15100.0 17699.5 Page 8 • • 17-174.tapx RPM 15100.0 17699.5 RPS 15100.0 17699.5 RPD 15100.0 17699.5 FET 15100.0 17699.5 GR 15108.0 17699.5 ROP 15140.5 17700.0 LOG HEADER DATA DATE LOGGED: 06-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17700.0 TOP LOG INTERVAL (FT): 15140.0 BOTTOM LOG INTERVAL (FT): 17700.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 92,2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 81.0 MUD PH: .O MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT): .000 .O MUD AT MAX CIRCULATING TER MPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 9 • • 1~-174.tapx Max frames per record ........ .....undefined Absent value ... .............. .....-999.25 Depth units. .. .. ..... Datum specifica tion Block sub -type...0 Name service order units Size N sam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPx MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15100 17700 16400 5201 15100 17700 ROP MWD040 FPH 0.35 432.63 215.325 5120 15140.5 17700 GR MWD040 API 43.61 99.63 70.001 5184 15108 17699.5 RPX MWD040 OHMM 10.7 2000 70.1717 5200 15100 17699.5 RPS MWD040 OHMM 12.68 2000 68.5977 5200 15100 17699.5 RPM MWD040 OHMM 14.65 2000 69.1477 5200 15100 17699.5 RPD MWD040 OHMM 15.83 2000 60.9136 5200 15100 17699.5 FET MWD040 HR 0.15 9.14 0.729371 5200 15100 17699.5 First Reading For Entire File..........15100 Last Reading For Entire File...........17700 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. .. .........LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 Page 10 i • 17-174.tapx FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 17700.0 19704.0 FET 17700.0 19663.0 RPS 17700.0 19663.0 RPX 17700.0 19663.0 RPD 17700.0 19663.0 RPM 17700.0 19663.0 ROP 17700.5 19708.0 LOG HEADER DATA DATE LOGGED: 11-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 19708.0 TOP LOG INTERVAL (FT): 17700.0 BOTTOM LOG INTERVAL (FT): 19708.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.30 MUD VISCOSITY (S): 81.0 MUD PH: .O MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ........ ..0 Data Specification Block Type... ..0 Logging Direction ............... ..DOwn Page 11 • 1.7-174. tapx optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD060 FPH 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MwD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17700 19708 18704 4017 17700 19708 ROP MWD060 FPH 1.65 359.36 225.143 4016 17700.5 19708 GR MWD060 API 47.25 96.89 71.7478 4009 17700 19704 RPX MWD060 OHMM 10.53 1862.83 56.4569 3927 17700 19663 RPS MWD060 OHMM 11.93 116.43 54.5529 3927 17700 19663 RPM MWD060 OHMM 13.84 110.55 53.9778 3927 17700 19663 RPD MWD060 OHMM 16.64 109.2 57.6261 3927 17700 19663 FET MWD060 HR 0.15 98.82 0.652755 3927 17700 19663 First Reading For Entire File..........17700 Last Reading For Entire File...........19708 File Trailer service name... .......STSL2B.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/03/12 Origin ...................STs Scientific Technical services Page 12 • Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIs Physical EOF Physical EOF End Of LIS File 1]-174.tapx writing Library. scientific Technical services Page 13 e ! 1J-174PBl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 17 15:48:04 2008 Reel Header Service name .............LISTPE Date . ...................08/04/17 Origin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header service name .............LISTPE Date . ...................08/04/17 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: Mw-000527561 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~o-~- r-~-~3 scientific Technical Services scientific Technical services 1J-174 PB1 500292337470 ConocoPhillips Alaska, Inc Sperry Sun 17-APR-08 MWD RUN 3 MW-000527561 R. WILSON F. HERBERT 35 11N l0E 1724 2471 .00 121.53 81.00 Page 1 ~ /~~2~ C~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J-174PBl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 10.750 3927.0 8.500 9.625 12080.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED, 4. MWD RUNS 2-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND AT -BIT GAMMA (ABG). 1J-174 PB2 EXITS THIS WELL BORE AT 15140'MD/3194'TVD, 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1J-174 PB1 WITH API#: 50-029-23374-70. THIS WELL REACHED A TOTAL DEPTH (TD) of 15308'TVD/3188'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/17 Maximum Physical Record..65535 File Type ................L0 Page 2 17-174PBl.tapx Previous File Name.......STSLi6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3994.0 15274.0 RPD 4008.0 15266.5 RPS 4008.0 15266.5 RPM 4008.0 15266.5 RPX 4008.0 15266.5 FET 4013.0 15266.5 ROP 4031.0 15308.0 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 MERGE TOP MERGE BASE 2 3994.0 12089.0 3 12089.0 15308.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3994 15308 9651 22629 3994 15308 RPD MWD OHMM 3.06 2000 28.6312 22461 4008 15266.5 Page 3 • • 17-174PBl.tapx RPM MWD OHMM 1.57 2000 29.5113 22461 4008 15266.5 RPS MWD OHMM 0.46 2000 30.6247 22461 4008 15266.5 RPX MWD OHMM 2.59 2000 29.613 22461 4008 15266.5 FET MWD HR 0.11 173.99 0.936674 22451 4013 15266.5 GR MWD API 22.62 109.98 66.1552 22561 3994 15274 ROP MWD FPH 0 10615.6 235.994 22555 4031 15308 First Reading For Entire File..........3994 Last Reading For Entire File...........15308 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/17 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/17 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3994.0 12053.5 RPx 4008.0 12046.0 RPS 4008.0 12046.0 RPM 4008.0 12046.0 RPD 4008.0 12046.0 FET 4013.0 12046.0 ROP 4031.0 12089.0 LOG HEADER DATA DATE LOGGED: 26-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12089.0 TOP LOG INTERVAL (FT): 3994.0 BOTTOM LOG INTERVAL (FT): 12089.0 BIT ROTATING SPEED (RPM): Page 4 ~ ~ 1.7-174PBl.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 86.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3927.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 60.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.146 123.8 MUD FILTRATE AT MT: 1.700 75.0 MUD CAKE AT MT: 2.000 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing ........ ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999.25 Depth Units. .. .. ..... Datum specification Block sub-type ...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Page 5 ~ ~ 17-174PBl.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3994 12089 8041.5 16191 3994 12089 RPD MWD020 OHMM 5.6 1394.79 14.7648 16077 4008 12046 RPM MWD020 OHMM 1.57 110.82 14.2945 16077 4008 12046 RPS MWD020 OHMM 1.3 115.97 13.5712 16077 4008 12046 RPx MWD020 OHMM 2.82 60.69 11.0878 16077 4008 12046 FET MWD020 HR 0.13 80.46 0.726401 16067 4013 12046 GR MWD020 API 22.62 109.98 65.1933 16120 3994 12053.5 ROP MWD020 FPH 0 10615.6 229.026 16117 4031 12089 First Reading For Entire File..........3994 Last Reading For Entire File...........12089 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/17 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 3 .5000 VENDOR TOOL CODE START DEPTH GR 12057.5 RPx 12075.0 RPD 12075.0 RPM 12075.0 FET 12075.0 RPS 12075.0 ROP 12090.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): STOP DEPTH 15274.0 15266.5 15266.5 15266.5 15266.5 15266.5 15308.0 04-DEC-07 Incite 6.02 Memory 15308.0 Page 6 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA EWR4 ELECTROMAG BOREHOLE AND CASING DATA 17-174PBl.tapx 12089.0 15308.0 85.6 92.4 TOOL NUMBER RAY 216262 RESIS. 4 10505932 OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.35 MUD VISCOSITY (S): 99.0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 122.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999.25 Depth Units. .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 Page 7 17-174PBl.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12057.5 15308 13682.8 6502 12057.5 15308 RPD MwD030 OHMM 3.06 2000 63.5513 6384 12075 15266.5 RPM MWD030 OHMM 8.65 2000 67.8321 6384 12075 15266.5 RPS MWD030 OHMM 0.46 2000 73.5708 6384 12075 15266.5 RPX MWD030 OHMM 2.59 2000 76.2653 6384 12075 15266.5 FET MWD030 HR 0.11 173.99 1.46588 6384 12075 15266.5 GR MWD030 API 38.64 104.06 68.5549 6434 12057.5 15274 ROP MWD030 FPH 0 1402.14 253.471 6437 12090 15308 First Reading For Entire File..........12057.5 Last Reading For Entire File...........15308 File Trailer Service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of ~eneration.......08/04/17 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/17 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/04/17 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical Services Page 8 z 1J-174PB2.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Thu Mar 20 12:19:03 2008 Reel Header Service name .............LISTPE Date . ...................08/03/20 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/03/20 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000527561 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical Services scientific Technical services 1J-174 P62 500292337471 ConocoPhillips Alaska, Inc Sperry Sun 20-MAR-08 MWD RUN 3 MWD RUN 4 Mw-000527561 Mw-000527561 R. WILSON R. WILSON M. THORNTON M. THORNTON 35 11N l0E 1724 2471 .00 121.53 81.00 Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J-174PB2.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 10.750 3927.0 8.500 9.625 12080.0 8.500 9.625 12080.0 C 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND AT -BIT GAMMA (ABG). THIS WELL BORE EXITS 1J-174 PB1 AT 15140'MD/3194'TVD, 1J-174 FINAL WELL BORE EXITS THIS WELL AT 17700'MD/3170'TVD. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-174 WITH API#: 50-029-23374-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18141'TVD/3181'TVD. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SESP = SMOOTHED SEMP = SMOOTHED SEDP = SMOOTHED SFXE = SMOOTHED TIME-HOURS SLIDE = NON-ROT. RATE OF PENETRATION WHILE DRILLING DUAL GAMMA RAY COMBINED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SHALLOW PHASE SHIFT RESISTIVITY MEDIUM PHASE SHIFT RESISTIVITY DEEP PHASE SHIFT RESISTIVITY RESISTIVITY FORMATION EXPOSURE TED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Page 2 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP 1 17-174PB2.txt clipped curves; all bit runs merged. .5000 START DEPTH 3994.0 4008.0 4008.0 4008.0 4008.0 4013.0 4031.0 STOP DEPTH 18107.5 18099.5 18099.5 18099.5 18099.5 18099.5 18141.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 3994.0 3 12089.0 4 15140.0 REMARKS: MERGED MAIN PASS. MERGE BASE 12089.0 15140.0 18141.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD units size Nsam Rep Code offset FT 4 1 68 0 FPH 4 1 68 4 API 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 OHMM 4 1 68 20 OHMM 4 1 68 24 HR 4 1 68 28 Page 3 Channel 2 4 6 8 First Last 17-174PB2.txt Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3994 18141 11067.5 28295 3994 18141 ROP MWD FPH 0 10615.6 233.261 28221 4031 18141 GR MWD API 22.62 109.98 67.0313 28228 3994 18107.5 RPX MWD OHMM 2.59 2000 37.187 28127 4008 18099.5 RPS MWD OHMM 0.46 2000 37.7344 28127 4008 18099.5 RPM MWD OHMM 1.57 2000 37.0406 28127 4008 18099.5 RPD MWD OHMM 3.06 2000 34.8445 28127 4008 18099.5 FET MWD HR 0.11 173.99 0.887632 28117 4013 18099.5 First Reading For Entire File..........3994 Last Reading For Entire File...........18141 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3994.0 12053.5 RPD 4008.0 12046.0 RPM 4008.0 12046.0 RPS 4008.0 12046.0 RPx 4008.0 12046.0 FET 4013.0 12046.0 ROP 4031.0 12089.0 LOG HEADER DATA DATE LOGGED: 26-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12089.0 Page 4 r~ TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 17-174PB2.txt BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. Down optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 3994.0 12089.0 76.3 86.0 TOOL NUMBER 124724 63122 12.250 3927.0 Fresh water Gel 8.90 60.0 10.1 200 .0 1.900 72.0 1.146 123.8 1.700 75.0 2.000 74.0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 RPX MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPM MWD020 OHMM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 FET MWD020 HR 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 Page 5 • 17-174PB2.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3994 12089 8041.5 16191 3994 12089 GR MWD020 API 22.62 109.98 65.1933 16120 3994 12053.5 RPx MWD020 oHMM 2.82 60.69 11.0878 16077 4008 12046 RPS MWD020 OHMM 1.3 115.97 13.5712 16077 4008 12046 RPM MWD020 OHMM 1.57 110.82 14.2945 16077 4008 12046 RPD MWD020 OHMM 5.6 1394.79 14.7648 16077 4008 12046 FET MWD020 HR 0.13 80.46 0.726401 16067 4013 12046 ROP MWD020 FPH 0 10615.6 229.026 16117 4031 12089 First Reading For Entire File..........3994 Last Reading For Entire File...........12089 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12057.5 15107.5 FET 12075.0 15099.5 RPD 12075.0 15099.5 RPM 12075.0 15099.5 RPS 12075.0 15099.5 RPx 12075.0 15099.5 ROP 12090.0 15140.0 LOG HEADER DATA DATE LOGGED: 04-DEC-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite Page 6 • 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: 17-174PB2.txt 6.02 Memory 15140.0 12089.0 15140.0 85.5 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.35 MUD VISCOSITY (S): 74.0 MUD PH: .O MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 Page 7 17-174PB2.txt RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 12057.5 15140 13598.8 6166 12057.5 15140 ROP MWD030 FPH 0 1402.14 257.876 6101 12090 15140 GR MWD030 API 38.64 104.06 68.3547 6101 12057.5 15107.5 RPX MWD030 OHMM 2.59 2000 76.581 6050 12075 15099.5 RPS MWD030 OHMM 0.46 2000 73.9366 6050 12075 15099.5 RPM MWD030 OHMM 8.65 2000 68.0132 6050 12075 15099.5 RPD MwD030 OHMM 3.06 2000 64.002 6050 12075 15099.5 FET MWD030 HR 0.11 173.99 1.51001 6050 12075 15099.5 First Reading For Entire File..........12057.5 Last Reading For Entire File...........15140 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 15100.0 18099.5 RPD 15100.0 18099.5 RPM 15100.0 18099.5 RPS 15100.0 18099.5 RPX 15100.0 18099.5 GR 15108.0 18107.5 ROP 15140.5 18141.0 LOG HEADER DATA Page 8 U 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: 17-174PB2.txt • 06-DEC-07 Insite 6.02 Memory 18141.0 15140.0 18141.0 87.5 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 12080.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 81.0 MUD PH: ,0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Page 9 • 17-174PB2.txt RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 15100 18141 16620.5 6083 15100 18141 ROP MWD040 FPH 0.35 949.18 219.645 6002 15140.5 18141 GR MWD040 API 43.61 99.63 70.6136 6000 15108 18107.5 RPX MWD040 OHMM 10.7 2000 67.3972 6000 15100 18099.5 RPS MWD040 OHMM 12.68 2000 65.9756 6000 15100 18099.5 RPM MWD040 OHMM 13.57 2000 66.7579 6000 15100 18099.5 RPD MWD040 OHMM 13.82 2000 59.2477 6000 15100 18099.5 FET MWD040 HR 0.14 9.14 0.691813 6000 15100 18099.5 First Reading For Entire File..........15100 Last Reading For Entire File...........18141 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/20 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/20 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/03/20 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF writing Library. writing Library. Page 10 Scientific Technical Services Scientific Technical services 17-174PB2.txt Physical EOF End Of LIS File Page 11
