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
202-210
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 08/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number PBU 14-08AL1 202-210 50-029-20330-60-00 PBU 14-08AL1PB1 202-210 50-029-20330-72-00 x Definitive Directional Surveys (11/28/2002 + 11/30/2002) Folder Contents: Please include current contact information if different from above. T39429 T39430 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 14:29:17 -08'00' STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMM! REPORT OF SUNDRY WELL OPERATI llt 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 1 202-210 3. Address: P.O.Box 196612 Anchorage, Development Exploratory 0 I AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: ' 50-029-20330-60-00 7. Property Designation(Lease Number): •ADL 028312&028314 8. Well Name and Number • PBU 14-08AL1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14180' feet Plugs measured 10926' fe true vertical 8977' feet Junk measured None feet , - s Effective Depth: measured 10926' feet Packer measured 10322',10867' feet �' i.I true vertical 8824' feet Packer true vertical 8421'.8785' feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 78' 20" 31'-109' 31'-109' 1530 520 Surface 2678' 13-3/8" 30'-2708' 30'-2707' 4930 2670 Intermediate 11023' 9-5/8" 28'-11051' 28'-8906' 8150/6870 5080/4760 Liner 1358' 7" 10842'-12200' 8768'-8986' 7240 5410 Liner 1169' 4-1/2" 12033'-13202' 9003'-8970' 8430 5410 Liner 2031' 2-7/8" 12149'-14180' 8992'-8977' 13450 13890 Perforation Depth: Measured depth: 13325'-14148' feet True vertical depth: 8970'-8977' feetCA # `/1`j1 t, U 1.6 Tubing(size,grade,measured and true vertical depth) 4-1/2",12.6#13Cr85/L-80 26-12019 26-9004 Packers and SSSV(type,measured and 9-5/8"x 4-1/2"HES AHC Packer 10322' 8421' true vertical depth) 7"x 4-1/2"Baker Premier Packer 10867' 8785' 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: 0 0 0 20 260 Subsequent to operation: 0 0 0 PO 260 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 12f Exploratory ❑ Development Q — Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 '16.Well Status after work: Oil IZI • Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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 McLaughlin,Sean M Email Sean.Mclaughlin@bp.com Printed Name Joe Lastufka Title Drilling Technologist Signature k Phone +1 907 564 4091 Date //Pi/5 Form 10-404 Revised 5/2015 VP— l,/ ��_ RBDM EP 10 2015 Submit Original Only • 14-08A�//AL1, Well History (Pre-Rig Workover) T/I/0=230/200/285 Temp=S/I (Pre RWO/E-line Tbg Cut) CMIT-TxIA to 3500 psi (PASSED) MIT- OA to 1200 psi in progress. Pumped 15.8 bbls of 20*diesel down IA to reach test pressure for CMIT- TxIA. 1st 15 min T/IA lost 78/83 psi. 2nd 15 min T/IA lost 35/34 psi for a total loss of 113/117 psi in 4/2/2015 30 min. Bled back - 12 bbls. MIT-OA to 1200 psi (PASSED) Pumped 30.3 bbls of 20"diesel down OA to reach test pressure. 1st 15 min OA lost 55 psi. 2nd 15 min OA lost 21 psi for a total loss of 76 psi in 30 min. Bled back- 5 bbls. Tags hung on casing valves and wing valve. AFE sign hung on master. SV WV SSV= closed. 4/3/2015 MV IA OA=open. DSO notified. FWHPS=350/360/280 T/I/O= SSV/310/250, Temp: SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre RWO. PPPOT-T: Stung into test void, (0+ psi) bled void to 0 psi. Monitored test void for 10 minutes, void stayed at 0 psi. Functioned LDS, 1 stuck in and 1 stuck out flagged. The rest moved freely. Torqued LDS to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. Stung into tubing hanger lower test void, (400 psi) bled void to 0 psi. Pressured void to 5,000 psi. Lost 200 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (0+ psi) bled void to 0 psi. Monitored test void for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 50 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. Ball check in alemite on casing head not checking. Will need to be replaced once 4/4/2015 WHP's are at 0 psi. (E-LINE RCT). RIG UP ELINE. RIH AND SHOOTATUBING PUNCH FROM 10790-10792 4/5/2015 BEGIN POOH. (E-LINE RCT). POOH W/TUBING PUNCH. STANDBY FOR WIND. DECISION MADE TO RIG 4/6/2015 DOWN DURING SHORT BREAK IN HIGH WINDS. TUBING CUT WITH RADIAL CUTTING TORCH (E-LINE). RIG UP ELINE. PRESSURE TEST 4/8/2015 AND ARM RCT. RIH WITH RCT TUBING CUTTER. CONTINUE RIH RCT TOOLS. CUT 4-1/2" TUBING @ 10,804' USING 2-1/2" RCT CUTTER. TIED 4/9/2015 INTO TUBING TALLY DATED 14-NOV-02. T/I/0=155/200/258 Temp=S/I (Circ Out/Pre RWO) CMIT-TxIA to 1000 psi. Pumped 4 bbls diesel 4/10/2015 down TBG to achieve CMIT-TxIA test pressure of 1000 psi. (Circ Out/Pre RWO) CMIT-TxIA to 1000 psi ***PASSED*** Pumped 4 bbls diesel down Tbg to achieve CMIT-TxIA test pressure of 1000 psi. 1st 15 min TxIA lost 22/21 psi. 2nd 15 min TxIA lost 7/ 6 psi for a total pressure loss of 29/27 psi over a 30 min test. Pumped 5 bbls of meth followed by 1080 bbls of 95*F 1%kcl down Tbg up IA taking returns to 14-07's flowline to circ out well. Pumped 250 bbls of 90*F diesel down IA up Tbg taking returns to 14-07's flowline then U-tubed for 1 hr for TxIA freeze protect. Pumped 2 bbls of diesel to 14-07 to freeze protect hardline. SV,WV,SSV=closed MV=open IA,OA=otg Hardline valves=closed FWHP=500/500/300. Tags 4/11/2015 hung and DSO notified of well status on departure. T/I/O=Vac/0/0, Temp=SI. Repair LDS, pre RWO. DHD bleeding TBG, IAP &OAP to 0 psi, holding open bleed. Stung into TBG hanger test void (0+ psi), bled to 0 psi. 2 stuck LDS (flagged), freed up both stuck LDS. Replaced one LDS with a complete assembly. The second LDS was stuck in the out position. Was able to free up LDS and function but unable to run it all the way in. Left in the out position (1"). PT void to 5000 psi, no leaks. Replaced Alemite fitting on IC test void, PT'd void to 4/24/2015 3500 psi, no leaks. T/1/O=Vac/2/260. Temp=SI. Assist Cameron (LDS extraction). AL spool dropped. IA has integral installed =inspection current. TBG FL near surface. IA FL @ surface. Bled IAP to 0 psi in -2 min. Maintained open bleed on IA for Cameron for 6 hrs. Bled OAP from 260 to 0 psi in 1 hr. Maintained open bleed on OA for 2 hrs. Final WHPs=Vac/0/0. 4/24/2015 SV, SSV, WV=C. MV=O. IA&OA=OTG. NOVP. 1830. i • 14-08A /AL1, Well History (Pre-Rig Workover) T/I/O=0/0/8. Bleed OA Down to 0 PSI. Verify VR Plug In IA and OA Companion side. P/T IA and OA VR plugs to 300 and 3500. (PASSED). Install 3" Temp IA Piggy back valve#52. Install 3" Temp OA Piggy back valve#67. Torque all flanges to API SPECS. Test IA and OA Piggy back valve to 300 low, 3500 high. (PASSED). Pressure up tubing going through IA to 300 PSI. Set 5" K BPV#601 7/16/2015 @135". RDMO. Final T/I/O=BPV/295/0. T/I/O= BPV/200/0. Start barriers list= BPVxMV. NU Dry-hole tree 5"x7" temp valve#53. Torqued 7/16/2015 and PT'd to API specs. RDMO. Final T/I/O= BPV/200/0. T/I/O = BPV/200/23. Temp = SI. Bleed WHPs to 0 psi (pre RWO). Weilhouse , flowline, AL, and tree scaffold removed. Drayhole tree no SSV. IA FL @ surface. OA FL near surface. Bled IAP to 0+ psi in 5 min (10 gal). Bled OAP to 0+ psi in 15 min (all gas). During bleed IAP increased 2 psi. Monitored for 30 min. IAP increased 1 psi, OAP increased 3 psi. Final WHPs = BPV/3/3. IA, OA= 7/21/2015 OTG. 0400. • • S North America-ALASKA-BP Page 1 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/31/2015 00:00 - 06:00 6.00 MOB P PRE PREP RIG AND PAD FOR UPCOMING MOVE FROM THE MAINTENANCE POSITION TO SPOTTING OVER WELL 14-08 SKID RIG FLOOR INTO MOVING POSITION. -PJSM WITH RIG CREW. PREPARE AND SKID RIG FLOOR TO MOVING POSITION. *SIMOPS: -LAY AND POSITION MATS FOR DANCE FLOOR,TO MOVE OFF MAINTENANCE POSITION ,-MOVE ALL EQUIPMENT NEEDED FOR MAINTENANCE OUT OF THE WAY. 1 PRE MOVE CHECKS: MOVE RIG OFF OF MAINTENANCE POSITION AND INTO POSITION FOR SPOTTING OVER 14-08 -CONTACT DSO TO WITNESS RIG MOVING i I 1 i ONTO WELL 14-08 *DSO WAIVED WITNESS. --PJSM WITH RIG CREWAND REVIEW RIG MOVE SOP. -WSL AND TP VERIFY WELL PRESSURES AND ENSURE ALL VALVES ON WELL ARE SHUT. *TBG,IA AND OA PRESSURES=0 PSI -VERIFY GOOD COMMUNICATION VIA RADIOS,WITH ALL PERSONNEL. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG.TEST PASS. 1-MOBE RIG OFF OF MAINT POSITION& SPOT OVER WELL#8 06:00 - 12:00 6.00 RIGU P PRE !SKID RIG FLOOR INTO DRILLING POSITION. -HOOK UP SERVICE LINES TO RIG FLOOR -SPOT ROCK WASHER,RU CIRCULATION MANIFOLD -R/U COMMUNICATIONS IN WSL OFFICE. -PJSM WITH RIG CREWAND HARD LINE CREW. -HARD LINE CREW,R/U HARD LINE FROM SKID MANIFOLD TO FLOWBACK TANK. -HARDLINE CREW,PRESSURE TEST HARDLINE FORM SKID MANIFOLD TO FLOWBACK TANK TO 250/4,000 PSI FOR 5 CHARTED MINS EACH. HOLD H2S RIG EVACUATION DRILL WITH AAR *24 HR BOPE TEST NOTIFICATION SUBMITTED AT 06:50 **RIG ACCEPTED AT 12:00 Printed 8/17/2015 10.48.22AM . . • ' North America-ALASKA-BP Page 2 of 12 Operation Summary Report . ...-..__...-._. Common Well Name: 14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 .X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table t 73.00usft(above Mean Sea Level) Date From To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)-- 12:00 - 18:00 6.00 RIGU P PRE RIG UP FOR TESTING THE BPV -SIM OPS:INSTALLING SAVER SUB AND TORQUE IBOP'S -TAKE ON FLUID TO THE PITS-290 BBLS OF SEAWATER -FLUID PACK THE MUD LINES FOR TESTING H2S/RIG EVACUATION DRILL -SIMULATED H2S RELEASE,LEADING TO RIG ' I EVACUATION,FOLLOWED BYAAR. :18:00 - 19:30 1.50 RIGU P PRE TIGHTEN PULSATION DAMPENER BOLTS _ SIM OPS:TESTING GAS ALARMS. 19:30 - 22:30 , 3.00 RIGU P r PRE I TEST MUD PUMP HARDLINES PRIOR TO 1 1 TESTING THE BPV -PJSM FOR TESTING LINES AND PRESSURE i !TESTING THE BPV I I REVIEW DDI TEST SOP AND PRESSURE I CROSS CHECK LIST. -TEST MUD PUMP LINE,ADDRESS LEAK FOUND IN LINE -RE-TEST THE LINES.TO 3500 PSI-GOOD EST TEST K STYLE BPV FROM BELOW-TO 250 MPSI LOW,3500 PSI HIGH FOR 5 CHARTED MIN-GOOD TEST 22:30 23:30 1.00 RIGU P PRE RIG DOWN TEST EQUIPMENT -BLOW DOWN LINES 23:30 - 00:00 0.50 RIGU ,, PRE PJSM FOR NIPPLE DOWN OF THE DRY HOLE i TREE AND ADAPTER FLANGE -PREP JOB FOR ONCOMING CREW 8/1/2015 00:00 - 02:30 2.50 WHSUR P DECOMP NIPPLE DOWN TREE&ADAPTER FLANGE -PJSM FOR ND OPERATIONS-REVIEW DDI , PROCEDURE-DISCUSS DROPPED OBJECT PREVENTION PLAN ' CAMERON TECH'S FUNCTIONED ALL OF THE ,LOCK DOWN SCREWS AND GLAND NUTS- ' TAKE MEASUREMENTS AND POST AT DRILLERS STATION ' -CLEAN AND INSPECT THREADS(ACME)ON THE TUBING HANGER,INSTALL TEST DART I ON TOP OF K STYLE BPV -INSTALL 5-1/2"RH ACME XO AND DOCUMENT TURNS FOR MAKE UP.(15-3/4) 02:30 - 06:00 3.50 BOPSUR P DECOMP N/U BOPE STACK PJSM FOR N/U BOPE,DISCUSS LIFTING , HAZARDS AND DROPPED OBJECTS. -NU BOPE STACK AND SPACER SPOOL. 06:00 - 14:00 8.00 BOPSUR P , DECOMP NU BOPE STACK CHOKE AND KILL LINES -PJSM FOR MAKING UP CHOKE AND KILL LINES -NU CHOKE LINE AND KILL LINE. -INSTALL NEW LOW PRESSURE RISER INTO , THE BELL NIPPLE SIMP OPS:PU SUB RACKS,SLIP RACKS,DOG COLLARS,BAIL,LIFTING EYES AND ! 'ELEVATORS Printed 8/17/2015 10:48:22AM North America-ALASKA-BP Page 3 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(11840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:OOAM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table©73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 18:00 4.00 BOPSUR P DECOMP INSTALL VARIABLE BORE RAMS IN THE BOP !STACK -PJSM FOR INSTALLIATION OF VBR'S RAM CONFIGURATION FROM TOP: 13-5/8"5K STACK. -ONE ANNULAR PREVENTER -ONE RAM-TYPE PREVENTER DRESSED WITH 3-1/2"X 6"RAMS -BLIND SHEAR RAM-TYPE PREVENTER -MUD CROSS WITH OUTLETS FOR CHOKE AND KILL LINES -ONE RAM-TYPE PREVENTER DRESSED WITH 2-7/8"X 5"RAMS !MAKE UP FOSVS ON RIG FLOOR FOR I TESTING 18:00 - 21:00 3.00 BOPSUR P DECOMP 1PJSM FOR TESTING BOPE -FLUID PACK ALL THE LINES, -(D1)BOP DRILL,TOOK 6 BBLS TO FILL TEH MUD GAS SEPERATOR SHELL TEST BOP STACK LOOK FOR I i VISABLE LEAKS. 21:00 - 00:00 3.00 BOPSUR P DECOMP 'BOPE TEST PRESSURE TEST BOPE TO 250 LOW,3500 PSI HIGH FOR 5 MIN EACH I -TEST WITH 4"AND 4.5"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESSED BY AOGCC REP LOU GRIMALDI -TEST GAS ALARMS WITH STATE INSPECTOR 8/2/2015 00:00 - 04:00 1 4.00 BOPSUR P DECOMP BOPE TEST -PRESSURE TEST BOPE TO 250 LOW,3500 PSI HIGH FOR 5 MIN EACH -TEST WITH 4"AND 4.5"TEST JOINTS '-ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESSED BY AOGCC REP LOU GRIMALDI -TEST GAS ALARMS WITH STATE INSPECTOR 04:00 - 08:00 4.00 BOPSUR P DECOMP PRESSURE TESTING -PJSM FOR PRESSURE TESTING HIGH PRESSURE LINES.REVIEW DDI HAZARD RECOGNITION WORKSHEET AND PRESSURE CROSS CHECK LIST. -TEST HIGH PRESSURE LINES.5 MIN LOW 250 PSI,10 MIN HIGH 5000 PSI. -ALL MUD LINES,STAND PIPE,KELLY HOSE, CEMENT LINES AND HOSE,INJECTION LINES -TEST CHOKE MANIFOLD AND HOSE TO 250 LOW,5000 PSI HIGH.-10 MIN CHARTED-NO LEAKS -BLOW DOWN MUD LINES,INJ LINES AND CEMENT LINE.BREAK DOWN FOSV'S,DART VALVE AND TEST EQPT OA IS OPEN AND LINED UP TO A BLEED TRAILER FOR UPCOMING TUBING SWAP ON WELLHEAD AT 0700. Printed 8/17/2015 10:48:22AM North America-ALASKA-BP Page 4 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 - Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date � From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) _ (usft) 08:00 - 12:00 4.00 BOPSUR P DECOMP PU MU DUTCH RISER&VALVE SHOP LUBRICATOR WITH QUICK TEST SUB PJSM FOR DUTCH RISER OPERATIONS& TESTING.-REVIEW PRESSURE CROSS CHECK CHECK LIST -PRESSURE TEST THE LUBRICATOR TO 250 LOWAND 3500 HIGH,5 MIN CHARTED- j CONFIRMED GOOD LEAK TIGHT TEST -BREAK LUBRICATOR AT THE QUICK TEST SUB I CIW REP DRY ROD OUT THE K-VALAVE TEST DART -MAKE UP LUBRICATOR,TEST QTS AND PULL , THE BPV '-R/D LUBRICATOR,CLEAN RIG FLOOR -PULL DUTCH RISER AND L/D TO PIPE SHED_ 12:00 - 14:30 2.50 I BOPSUR P I DECOMP I PICK UP TOOLS FOR UPCOMING JOB -PJSM FOR GETTING TOOLS TO RIG FOR I UPCOMING OPERATIONS -PJSM AND R/U IN THE CELLAR FOR I UPCOMING OPERATIONS 14:30 - 17:30 3.00 BOPSUR P DECOMP CIRCULATE OUT FREEZE PROTECT I-PJSM FOR CIRCULATING OUT FREEZE PROTECT FROM WELLBORE CIRCULATE 50 BBLS 95 DEGREE 8.5 PPG 'SEAWATER DOWN THE IA;CIRC 5 BPM W/ 1010 PSI AND SWAP LINES CIRCULATE 300 BBLS 8.5 PPG SEAWATER 95 DEGREE ICP;CIRC 7.6 BPM W/1870 PSI FCP 7.6 BPM W/2020 PSI DOWN THE TUBING I -10 MINUTE FLOW CHECK-WELL BORE STATIC 17:30 - 19:30 2.00 BOPSUR P DECOMP R/D LINES,MU XO FOR FOSV'S,MU LINK TILT i CLAMPS BLOW DOWN CIRCULATING LINES FREE OF FLUID -PICK UP BOT SPEAR ASSY TO RIG FLOOR -PICK UP 4-1/2"HANDLING EQUIP TO RIG FLOOR 19:30 - 22:00 2.50 PULL P DECOMP I MU&RIH WITH BOT SPEAR ASSY -PJSM TO MU/RIH W/BOT SPEAR ASSY W/ I 3.947"GRAPPLE -RIH AND TAGGED UP 31'DOWN,2'INSIDE THE HANGER W/3K WOB,PULL UP AND I ATTEMPT TO RUN PAST MARK , , -PULL SPEAR ASSY TO RIG FLOOR AND MOBE SMALLER GRAPPLE -SIM OPS- RIG UP STACK TONGS 22:00 - 23:30 1.50 PULL P DECOMP CHANGE OUT GRAPPLE SIZE AND RIH WITH , NEW BOT SPEAR ASSY -CHANGE GRAPPLE SIZE F/3.947" T/3.885" GRAPPLE -RIH AND ENGAGE GRAPPLE,PULL 10K OVER TO ENSURE ENGAGED,SLACK OFF 15K, -CIW BOLDS,LDS OUT,PULL ON HANGER TO I 225K,SLACK OFF AND PULL 225K,PULLED ' 245K AND HANGE BROKE FREE ' -PULLED AGAIN AT 225K AND TUBING FREE PULLED AT 175K ' MONITOR WELL 10 MIN- -PU ON STRING 2'AND SHUT ANNULAR Printed 8/17/2015 10:48 22AM 411) 4111 • North America-ALASKA-BP Page 5 of 12 Operation Summary Report Common Well Name: 14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 I 0.50 PULL P DECOMP CIRCULATE BOTTOMS UP LINE UP AND CIRCULATE THRU MUD GAS SEPERATOR -CLOSEANNULAR PREVENTER '- 6 BPM WITH 1130 PSI MW 8.5 PPG IN/OUT 8/3/2015 00:00 - 02:00 2.00 PULL P DECOMP CIRCULATE BOTTOMS UP -CBU AFTER PULLING THE HANGER OFF SEAT -6 BPM,1080 PSI '-MW8.5PPG IN/OUT • I-CIRCULATE THROUGH THE MUD GAS SEPERATOR WITH ANNULAR CLOSED -NO GAS OR HYDROCARBONS OBSERVED AT BOTTOMS UP. FLOW CHECK THE WELL 10 MIN-WELL STATIC OPEN ANNULAR PREVENTER 02:00 - 04:00 I 2.00 PULL P DECOMP PULL HANGER TO THE RIG FLOOR ,-REMOVE&LD BAKER OIL TOOL SPEAR • ASSY .-BREAK AND LD TUBING HANGER. -CHANGE OUT ELEVATORS TO 4.5"TUBING, DRILLER AND LEAD FLOOR HAND VERIFIED CORRECT ELEVATOR SIZE. BLOW DOWN TOP DRIVE AND CHOKE. 04:00 - 09:00 5.00 PULL P DECOMP ,PULL AND LAY DOWN 4.5"COMPLETION PJSM FOR LAYING DOWN TUBING,REVIEW DDI PROCEDURE,DISCUSS AND AGREE ON DISPLACEMENT VOLUMES TO BE USED FOR TRIP SHEETS. -POOH FROM 10,804' -PUW-175K,SOW-135K 09:00 - 10:00 1.00 PULL P DECOMP •UNANNOUNCED DRILL: -HIGH GAS TO THE PITS ALARM,WSLAND TOOL PUSHER SET UP DRILL SCENARIO WHERE THEY INTRODUCED GAS AT THE PIT SENSOR. -20%,40%WHERE THE CREW SHUT IN THE WELL,THE DRILL WAS ESCALATED UP TO 75%,WHERE THE CREW SIMULATED ESD FUNCTION - FULL ABANDONMENT CONDUCTED -HELD AAR FOLLOWING THE DRILL 10:00 - 13:00 3.00 PULL P DECOMP PICK UP&RUN IN THE HOLE AND SET THE 9-5/8"HES RTTS -PJSM FOR RUNNING RTTS:DISCUSSED WELL CONTROL&PROPER HANDLING OF THE RTTS -RUN IN THE HOLE WITH THE RTTS ON 3 JOINTS OF 4"DP -SET RTTS PER THE DIRECTION OF THE HALLIBURTON HAND.1/4 TURN TO THE RIGHT,SLACK OFF TO BLOCK WT,21 TURNS TO THE LEFT. -RACK BACK STAND -CLOSE THE BLIND SHEAR RAMS,LINE AND TEST THE RTTS FROM ABOVE -250 PSI LOW,3000 PSI HIGH FOR 5 CHARTED MIN-GOOD TEST • -BLOW DOWN CHOKE AND KILL LINES Printed 8/17/2015 10:48:22AM • North America-ALASKA-BP Page 6 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:OOAM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 17:30 4.50 PULL P ' DECOMP NIPPLE DOWN THE BOP STACK AND THE TUBING SPOOL. -PJSM FOR NIPPLE DOWN OPERATIONS. -SIM OPS:WORKING ON RIG FLOOR C-SECTION IN ATTEMPTS TO LEVEL THE I DERRICK.,SIM OPS:CHANGING OUT THE KR VALVE ON THE ACCUMULATOR,ALSO WORKING ON THE GUN LINE CONNECTIONS IIN THE CENTRIFUGAL ROOM. **INJURED PERSON:DDI FLOOR HAND HAD A MIS STEP IN THE CELLAR THAT LED TO HIM HITTING HIS FACE ON THE IA:HE WAS SENT TO THE MEDIC FOR EVALUATION.IR-5062814 17:30 18:00 j 0.50 PULL P DECOMP I CHANGE OUT THE INNER CASING PACK OFF PJSM WITH CAMERON AND DDI TO I DISCUSS JOB TASK AND PROCEDURE. **INJURED PERSON:CAMERON REP WAS INJURED WHEN HE PUT HIS HANDS IN THE WELL HEAD TO WIPE OUT SOME GREASE AND CHECK THE LOCK DOWN SCREW STATUS.THE CASING GREWABRUPTLY BY TWO INCHES AND PINCHED HIS FINGER.HE WAS SENT TO THE MEDIC FOR EVALUATION. i ,IR-5063104 18:00 - 00:00 6.00 PULL N HMAN DECOMP OPERATIONS STOPPED TO INVESTIGATE INJURED CAMERON -NOTIFICATIONS WERE MADE TO WORK OVER SUPERINTENDENT&BP SAFETY. -ALL FURTHER OPERATIONS WERE STOPPED UNTIL FURTHER NOTICE -SAFETY STAND DOWN WAS CALLED INTO EFFECT.CREW WAS CALLED TO A MEETING ' TO DISCUSS THE RECENT INCIDENTS AND A SAFE WORK PLAN GOING FORWARD. . -CREWS WERE INSTRUCTED BY DDI MANAGEMENT TO CONDUCT INDEPENDENT AUDITS OF EACH WORK AREA TO IDENTIFY 'OTHER RISKS THAT MIGHT BE MISSED. 8/4/2015 00:00 - 16:00 16.00 WHSUR N HMAN DECOMP SAFETY STAND DOWN. -HOLD SAFETY MEETING WITH ALL CREWS AND DISCUSS RECENT INCIDENTS. -SAFETY EXPECTATIONS GIVEN TO BOTH CREWS BY RIG LEADERSHIP. I -EACH INDIVIDUAL DOCUMENT PERSONAL COMMITMENT TO SAFETY. PERFORM HAZARD HUNT AROUND RIG AND DISCUSS FINDINGS. -REVIEWING PROCEDURES FOR UPCOMING OPERATIONS. -PERFORM LIGHT CLEANING/ HOUSEKEEPING. **HOLD RIG FIRE DRILL.** 16:00 17:00 1.00 1 WHSUR P DECOMP PJSM AND PREP TO REMOVE PACKOFF. -CLEAN IN CELLAR AND CLEAN WELLHEAD ' AROUND PACKOFF. 17:00 - 18:30 1.50 WHSUR P DECOMP PJSM AND PULL PACKOFF. -RU PACKOFF PULLING TOOL TO JOINT OF DP. -ENGAGE TOOL AND PULL PACKOFF WITH 10K#. Printed 8/17/2015 10:48:22AM 4110 North America-ALASKA-BP • Page 7 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table t 73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 23:00 4.50 WHSUR +. CO. - FF. P �DECOMP PJSM AND INSTALL NEW PACKOFF. -MAKE NOTIFICATION TO CAMERON TOWN ENGINEERING TO VERIFY INNER SEAL ORIENTATION. 1-PICK UP NEW PACKOFF AND ATTEMPT TO INSTALL OVER CASING HANGER STUB USING TUGGER. -9-5/8"CASING HAS"GROWN"-1 INCH. •MANDREL LIFTED OFF SHOULDER IN CASING SPOOLAND CASING STUB NOT CENTERED IN WELLHEAD.CANNOT WORK PACKOFF DOWN OVER STUB. -REMOVE PACKOFF.INSPECT SAME AND WELLHEAD. -MU PACKOFF TOOL TO DP AND SCREW IN WITH TOP DRIVE. -PICK UP PACKOFF AND ATTEMPT TO INSTALL OVER HANGER STUB.SET DOWN 10K#-NO GO. -REMOVE PACKOFF AND FIND DAMAGED INNER SEALS. '-REMOVE INNER SEALS AND TEST FIT PACKOFF-SEATED CORRECTLY WITHOUT ISSUE. CALL AND NOTIFY FIELD SUPERINTENDENT. DECIDE TO CUT THREADS OF 9-5/8"HANGER STUB. 23:00 - 00:00 1.00 WHSUR N l WAIT I DECOMP MOBILIZE SPARE PACKOFF AND WACHS CUTTER TO LOCATION. -SIMOPS:CONTINUE HOUSEKEEPING. 8/5/2015 00:00 - 01:30 1.50 WHSUR N WAIT DECOMP MOBILIZE SPARE PACKOFF AND WACHS CUTTER TO LOCATION. -SIMOPS:CONTINUE HOUSEKEEPING AND RIG SCHEDULED MAINTENANCE. 01:30 - 03:00 1.50 WHSUR P DECOMP PJSM AND CUT THREADS FROM CASING HANGER STUB. -INSTALL WACHS CUTTER. -MAKE CUT ON STUB JUST BELOW THREADS. -DRESS BEVEL WITH FILE. 03:00 - 04:00 1.00 WHSUR P • DECOMP PJSM AND INSTALL NEW PACKOFF. -PICK UP NEW PACKOFF AND INSTALL OVER CASING HANGER STUB USING TUGGER. -SEATED CORRECTLY WITHOUT ISSUE. -9-5/8"CASING HAS"GROWN"-1 INCH. UNABLE TO RILDS. -MU PACKOFF TOOL TO DP AND SCREW IN WITH TOP DRIVE. SET DOWN 20K#AND SEAT 9-5/8"HANGER IN CASING SPOOL. -RILDS.TORQUE LDS AND GLAND NUTS TO SPEC. 04:00 - 07:00 3.00 WHSUR P DECOMP PJSM AND INSTALL NEW TUBING SPOOL. -PU NEW TUBING SPOOL AND INSTALL WITH BRIDGE CRANE. -TORQUE FLANGE BOLTS TO SPEC. -PRESS TEST PACKOFF VOID TO 250/3500 PSI FOR 5/30 MIN. 07:00 - 12:00 5.00 BOPSUR P DECOMP PJSM AND NU BOPE STACK. -NU BOPS.TAKE NEW RKB MEASUREMENTS. -INSTALL IA VALVES. Printed 8/17/2015 10:48:22AM • III North America-ALASKA-BP Page 8 of 12 Operation Summary Report Common Well Name: 14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011 C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table©73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 12:00 - 13:30 1.50 BOPSUR P DECOMP PJSM AND SHELL TEST BOPE FLANGE, TUBING SPOOL,AND IA VALVES. I RIG UP TO PRESS TEST AGAINST B/S RAMS. -FIND LEAK ON OUTER IA VALVE. 13:30 15:30 2.00 BOPSUR N SFAL ;DECOMP PJSM AND REPLACE OUTER IA VALVE. 1-MOBILIZE NEW IA VALVE TO LOCATION. REMOVE FAULTY VALVE AND INSTALL NEW. 15:30 - 16:30 1.00 BOPSUR N SFAL DECOMP PJSM AND SHELL TEST BOPE FLANGE, TUBING SPOOL,AND IA VALVES. -PRESS TEST TO 250/3500 PSI FOR 5/5 MIN. PASSED. RD TEST EQUIPMENT. 16.30 - 21.00 4.50 PULL P II DECOMP PJSM AND SLIP N CUT DRILL LINE. -SLIP N CUT DRILL LINE.CLEAR EXCESS LINE FROM FLOOR. -CALLIBRATE BLOCK HEIGHT AND I CROWN-O-MATIC. -SERVICE TOP DRIVE AND BLOCKS. 21:00 - 22:30 I 1.50 PULL P DECOMP PJSM AND PERFORM ACCUMULATOR DRAWDOWN. 1-OBTAIN BASELINE FOR PREVENTER CLOSURE TIME WITH NEW BOP STACK 22:30 23:00 0.50 PULL P DECOMP 4 RU TO RETRIEVE RTTS. l-PREP FLOOR VALVE AND CHOKE MANIFOLD. ; -CLEAN AND CLEAR RIG FLOOR FOR BEFORE CONTINUING DECOMPLETE. 23:00 - 00:00 1.00 PULL N RREP DECOMP REPAIR ACCUMULATOR. -AFTER DRAWDOWN,ACCUMULATOR PUMP CONTROLLER NOT PERFORMING AS 1 , DESIGNED. _ TROUBLESHOOT ACCUMULATOR. I —r--, 8/6/2015 00:00 - 04:00 4.00 PULL N , RREP DECOMP REPAIR ACCUMULATOR. , 1 -AFTER DRAWDOWN,ACCUMULATOR PUMP ICONTROLLER NOT PERFORMING AS DESIGNED. 1-TOUBLESHOOT ACCUMULATOR. -REPLACE KR VALVE. SIMOPS: -WSL OPEN WELL WORK TRANSFER FOR 14-32 WITH PAD OPERATOR. -WSL LO/TO 14-13 FOR WO ON 14-32. 04:00 - 04:30 0.50 PULL P DECOMP FUNCTION TEST BOPE. ACCUMULATOR FUNCTION AS DESIGNED. 04:30 - 06:00 1.50 PULL P DECOMP PJSM AND RETRIEVE 9-5/8"RTTS. -RIH WITH RETRIEVAL TOOL. -STAB TIW VALVE.STING INTO RTTS WITH 19 TURNS TO RIGHT. -OPEN TIW VALVE AND CHECK FOR PRESURE.NO PRESSURE. -CLOSE ANNULAR AND RELEASE RTTS. -MONITOR WELL FOR 10 MIN-STATIC. -OPEN ANNULAR AND PULL 9-5/8"RTTS. -LD 3 JTS 4"DP.LD RTTS. 06 00 - 06'30 0.50 PULL P DECOMP RU TO PULL 4-1/2",12.6#,IBT,L-80 TUBING. -RU SLIPS,POWER TONGS,ELEVATORS. -RU WELL CONTROL X-OVER,FOSV,AND SAFETY JOINT. Printed 8/17/2015 10:48:22AM • • ' North America-ALASKA-BP Page 9 of 12 Operation Summary Report Common Well Name: 14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840;000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table©73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 13:00 6.50 PULL P DECOMP PJSMANDPULL4-1/2"COMPLETION. -POOH FROM 6,700'MD TO SURFACE. -TOTAL PIPE RECOVERED FROM WELL:255 FULL JTS,1 CUT JT(12.62'),6 GLM'S,1 X-NIPPLE,3 PUP JTS,TUBING HANGER. -ALL MATERIAL NORMED-NOT I RADIOACTIVE. WSL REMAIN ON FLOOR FOR 30 JTS AND VERIFY DISPLACEMENT. 13:00 - 15:30 2.50 RIGU P RUNCMP RD FROM PULL COMPLETION.RU TO RUN COMPLETION. -OFFLOAD OLD TUBING AND STAGE IN YARD. -CLEAN AND CLEAR FLOOR. -RECONFIGURE WELL CONTROL EQUIPMENT FOR VAM TOP CONNECTIONS. T 15:30 - 18:30 3.00 RIGU N I SFAL RUNCMP TROUBLESHOOT POWER TONGS. -UNABLE TO SET POWER TONG TORQUE TO PROPER VALUE.DUMP VALVE NOT FUNCTIONING CORRECTLY. I -SWAP POWER TONGS FOR NEW SET. -SET UP AND TEST NEW TONGS.TORQUE 'SET TO 4440 FT-LB. 18:30 - 20:30 2.00 RUNCOM P RUNCMP PJSM AND RUN 4-1/2",12.6#,13CR-85,VAM TOP COMPLETION. -RIH FROM SURFACE TO 662'MD. PU OVERSHOT,10 JTS TUBING,X-NIPPLE, HES AHC PACKER,X-NIPPLE. -BAKERLOK ALL CONNECTIONS BELOW PACKER. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -TORQUE VAM TOP CONNECTIONS TO 4440 I FT-LB. i I -SEA WATER:8.5 PPG IN,8.5 PPG OUT. -WSL REMAIN ON FLOOR FOR 30 JTS AND 1 VERIFY DISPLACEMENT. 20:30 - 21:00 0.50 RUNCOM I P RUNCMP "COMPLEX KICK WHILE TRIPPING DRILL" -HOLD KICK WHILE TRIPPING DRILL. SIMULATE HYDRAULIC CHOKE FAILURE. LINE UP TO MANUAL CHOKE. -SIMULATE MANUAL CHOKE FAILURE.LINE UP TO CHOKE SKID. -HOLD AAR. 21:00 - 00:00 3.00 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR-85,VAM TOP COMPLETION. RIH FROM 662'TO 1,120'MD. -SPACE OUT GLM'S AS PER TALLY. -BAD PIN ON JT#10.KICK OUT AND REPLACE WITH SPARE JT#265. -USE JET LUBE SEAL GUARD THREAD , COMPOUND. TORQUE VAM TOP CONNECTIONS TO 4440 FT-LB. -SEA WATER:8.5 PPG IN,8.5 PPG OUT. WSL REMAIN ON FLOOR FOR 30 JTS AND VERIFY DISPLACEMENT. Printed 8/17/2015 10 48:22AM North America-ALASKA-BP Page 10 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table(g73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) usft : 8/7/2015 00:00 - 06:00 6.00 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR-85,VAM TOP COMPLETION. RIH FROM 1,120'TO 5,300'MD. -SPACE OUT GLM'S AS PER TALLY. i !-USE JET LUBE SEAL GUARD THREAD ,COMPOUND. -TORQUE VAM TOP CONNECTIONS TO 4440 `FT LB. SEA WATER:8.5 PPG IN,8.5 PPG OUT. -WSL REMAIN ON FLOOR FOR 30 JTS AND I VERIFY DISPLACEMENT. 06:00 - 19:00 13.00 RUNCOM P RUNCMP I RUN 4-1/2",12.6#,13CR-85,VAM TOP ,COMPLETION. -RIH FROM 5,300'MD. TAG 5K AT 10,813'MD. ROTATE QUARTER TURNS UNTIL OVERSHOT SWALLOWS TUBING STUB CLEAR INDICATION OF SHEARED PINS WITH 10 K WOB AT 10,817'MD&10,825'MD i -NO-GO ON TOP OF TUBING STUB AT 10,827' MD I-POOH TO 10,803'MD. I I i I i 19:00 - 21:00 I 2.00 RUNCOM P RUNCMP SPACE OUT AND LAND 4-1/2",12.6#,VAMTOP ICOMPLETION: -PICK UP 19.41'AND 7.72'PUPS,JOINT 239& HANGER/PUP (GRAY 12"X 4.5"TCII TOP AND BTM). RUN IN HOLE ON LANDING JOINT AND LAND TUBING HANGER WITH BOTTOM OF OVERSHOT AT 10,822'MD &TUBING STUB 5 FT OFF OF NO-GO. CAMERON REPS RUN IN LOCKDOWN , SCREWS. 1 ; -FINAL PICKUP WEIGHT=165 K,SLACKOFF= 140 K -HES AHC 9-5/8"X 4-1/2" PACKER AT 10,325' MD. I -'X'NIPPLE AT 10,362'MD HAS RHC-M PLUG INSTALLED. -NOTE:ALL CONNECTIONS BELOW PACKER ARE BAKER-LOK'D. 21.00 - 00:00 3.00 T WHSUR I P OTHCMP REVERSE CIRCULATE DIESEL FREEZE .I PROTECT I , -PJSM WITH LITTLE RED AND RIG CREW, IREVIEW PRESSURE CROSSCHECK RIG UP LINES THROUGH LANDING JOINT AND CHOKE SKID FOR DIESEL PUMPING AND U-TUBE LRS TEST LINES 250 PSI LOWAND 1500 PSI HIGH REVERSE CIRCULATE 152 BBLS DIESEL -LRS PUMP AT 3 BPM AND 740 PSI i 8/8/2015 00:00 - 02:00 2.00 WHSUR P OTHCMP PUMP DIESEL FREEZE PROTECT. -LRS PUMP 152 BBLS DIESEL DOWN IA TAKING RETURNS UP TUBING. -ALLOW DIESEL TO U-TUBE FOR 1 HOUR. Printed 8/17/2015 10:48:22AM • • North America-ALASKA-BP Page 11 of 12 Operation Summary Report Common Well Name: 14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:OOAM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table c73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 02:00 04:30 2.50 W-ISUR P OTHCMP 'SET AND TEST TWO WAY CHECK ! -PJSM WITH CAMERON. -CAMERON TECH INSTALL TWO WAY CHECK IN GRAY HANGER. , -PRESS TEST TWC FROM ABOVE TO 250/3500 PSI FOR 5/5 MIN. I -PRESS TEST TWC FROM ABOVE TO 250/3500 PSI FOR 5/5 MIN. -PUMP 0.8 BBLS TO PRESS UP FOR LOW PT I(CALC 0.7 BBLS). I I-PUMP 10.7 BBLS TO PRESS UP FOR HIGH PT I I(CALC 10.0 BBLS). ' I-BLEED OFF 10 BBLS TO TIGER TANK. 04:30 - 05:30 1.00 WHSUR P OTHCMP PJSM AND RD FROM PRESSURE TESTING. SUCK OUT STACK I BLOW DOWN CHOKE/KILL./BLEEDER LINES. '-BLOW DOWN MUD PUMPS LINES AND CIRC ' LINES IN CELLAR. -BLOW DOWN HARDLINE TO TIGER TANK OTHCMP RD PRESS TESTING EQUIPMENT. 05:30 13:00 7.50 BOPSUR P PJSM AND C/O RAMS FOR NEXT WELL 14-32. I -LD MOUSE HOLE.REMOVE RISER AND 'TURN BUCKLES. -REMOVE UPR AND LRP FROM CAVITIES. I REBUILD 2-7/8"X 5"VBR'S. INSTALL 2-7/8"X 5"VBR'S IN UPPER RAM CAVITIES. , -INSTALL 3-1/2"X 6"VBR'S IN LOWER RAM ! CAVITIES. -SIMOPS:CLEAN PITS.PREP FOR MOVE. II 13:00 - 14:30 1.50��BOPSUR ' P � OTHCMP PJSM AND ND BOP STACK. I-ND BOP STACK AND SECURE IN CELLAR __ I WITH BRIDGE CRANE. 14:30 17:30 3.00 WHSUR ' P OTHCMP I PJSMAND INSTALL ADAPTER FLANGE AND I ,DRY HOLE TREE. I INSTALL ADADPTER FLANGE AND TREE. I -PRESS TEST HANGER VOID TO 250/5000 PSI FOR 5/30 MIN-GOOD TEST. -INITIAL=5050 PSI. I -15 MIN=4915 PSI. -30 MIN=4892 PSI. -SIMOPS:PREP RIG FLOOR FOR MOVE. CLEAN DRIP PAN AND IN PIPE SHED. 117:30 - 20:30 3.00 WHSUR P OTHCMP PJSM AND PRESS TEST TREE. RU TESTING EQUIPMENT. ' -LEAVE 2 BOTTLES OF HEET ON TOP OF TWC. -FILL TREE WITH DIESEL. -PRESS TEST TREE TO 250/5000 PSI FOR 5/5 MIN-GOOD TEST. Printed 8/17/2015 10:48:22AM • North America-ALASKA-BP Page 12 of 12 Operation Summary Report Common Well Name:14-08 AFE No Event Type:WORKOVER(WO) Start Date:7/31/2015 End Date:8/8/2015 X4-011C8-E:(1,840,000.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:DOYON 14 Spud Date/Time:5/6/1979 12:00:00AM Rig Release:8/8/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292033000 Active datum:Kelly Bushing/Rotary Table©73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 20:30 - 21:00 0.50 WHSUR P OTHCMP SECURE CELLAR AND RELEASE RIG. -RD PRESS TESTING EQUIPMENT. -CLEAN AND SECURE CELLAR. 1-DRESS TREE WITH NEEDLE VALVES AND GAGES. -RELEASE DOYON 14 RIG AND END WO EVENT AT 21:00 ON 08/08/2015. -PREP RIG TO MOVE TO DS 14-32. -ALL TREE AND WELLHEAD VALVES LEFT CLOSED WITH PRESSURE GAUGES. FINAL OA/IA/TPRESS=0/0/0 PSI. TREE,WELLHEAD,AND CELLAR CLEAN. WELL SIGN RETURNED TO OPERATIONS. Printed 8/17/2015 10 48 22A WIEILFfAD= GRAYYGB4 2 • 14-08A NOTES: WELL ANGLE>70'@ 11264' *"'" ACTUATOR= AXELSON(OW STYLE), Ll MAX DOGLEG 20.1-@ 12899'"""CHROME TBG OKB.ELEV= 73' E3F.ELE_l/_ 21$7' -{4-1/2'I$X PIP,D=3.813" KOP= 13202' Max Angle= 95°@ 13543' 20-COND. 112' GAS LIFT MAM S Datum MD 1099G, 94#,Fl-00, [ ST MD WO DEV TY PE VLV LATCH PORT DATE Datum TVD= � -� 8800 SS D=19.124' 7 3589 3559 26 MAG DMY RK 0 08/07/15 6 5204 4748 45 MAG DMY RK 0 08/07/15 13-3/8"CSG,72#.L-BO BTC,D=12.347' H 2708' - 5 6281 5503 45 MM3 DMY RK 0 08/07/15 4 6942 5984 41 MAG DMY RK 0 08/07/15 3 7895 6683 43 MMG DW RK 0 08/07/15 Minimum ID = 2.372" @ 12154' 2 9011 7498 43 MM3 OW RK 0 08/07/15 2-7/8" CENTRALIZERS 1 10128 8290 47 WAG DMY RK 0 08/07/15 I I 10291' -J4-1/2 HES X PP,D=3.813' 10322' -9-5/8'X 4-1/2"IES AHC PKR,D=3.903' 4-1/2'TBG,12.6#,13CR-85 VAMTOP, H 10804' ' r 10358' H4-112'FES X PP,D=3.813' .0152 bpf,D=3.958' 4-1/2'TBG STUB(04/09/15) - 10804' ( 1 - 10819' H9-5/8'X 4-1/2'lJr O E OVERSFDT 9-5/8"X 7'BKR LIP&HGFT,D=6.25' H 10842' 10845' -4-117 HES X NP(9CR),D=3.813' ' E 10865' Hr X 4-1/2'BKR PREM FKR D=3.875' 10893' -4-12"FES X NP(9CR),I)=3.813' I 9-5/8-W-PSTOCK(XX/XX/98) - 11051' , 10907'SLM H4-1/2'JUNK CATC1-U w/PRONG(09/16/14) 9-5/8"CSG,47#,L-801 S00-95 BTC,I)=8.681' - -11051flill.----------410926' -4-1/2'EVO TREEVE PLUG(09/15/14) TOP OF 4-12'LNR - 12033' \ MLLOUT WINDOW(14-08A) 11051'-11067' 4-1/2'TBG, 12.6#,L-80 STL,.0152 bpi,D=3.958' -4 12034' TOP OF 2-7/8'LNR - 12155' PERFORATION SUIMAiRY 12033' -7'X 4-1/2'BKR ZXP LW&I- 4C HGR,D= REF LOG: ON XX/XX/XX •1 i ANGLE AT TOP F$ZF:WA 12034' -4-12"WLEG,D=3.958' Note:Refer to Production DB for historical pert data N .1 12068' H5-X 4-12'XO,D=3.958' SIZE SW ZONE r'11U VAL Opn/Sgz SHOT SQZ 14-08A f 12149' -3.7'BKR DEPLOY SLV,0=3.00' 2-3/4' 4 Z4Bu 12230- 12510 0 10/15/98 12155' f--3-12'X 2-7/8'XO,D=2.380" 2-314" 4 12565- 12700 0 10/15/98 k 2-3l4" 4 13320-13680 0 10/15/98 MLLOUT NTDOW(14-08AL1) 13202'-13209' 2-3/4" 4 " 13720-13883 O 10115/98 2-3/4' 4 " 13913-14240 0 10/15/98 2-3/4' 4 14270- 14603 0 10/15/98 f i N.T----------------------....ss. 2-3/4' 4 " 14638-14890 0 10/12/98 2-3/4" 4 " 14920- 15300 0 10/12/98 14- 11 2-3/4'5101 SAG/i 13325- 141481 SLID 12/01/02 i P13P1371) H T 14148' -.±.- 7'LNR,26#,L-80 BT-M,.0383 bpf,V=6.276' -I 12200' %�4�A% 2-7/8'LNR,6,16#,180 STL, - 14180' 4-12 W "TtW KS-WS PERM PKR,D=2.375' - 13202' k4.4.4�4.4 .0058 bpi,D=2.441' 4-1/2'LNR, 12,8#,L-80 13T-M,.0152 bpf,0=3.958' --- 15435' DATE REV BY OOMENTS DATE REV BY COMMENTS PRUDHOEBAY LINT 08/02/79 ORIGINAL COMPLETION 08/11/15 JAC DRLG HO CORRECTIONS KELL 14-08A/L1 1D/15/98 N-22E SIDETRACK(14-08A) 08112/15 SMIJMD FINAL ODE APPROVAL FERMT No: 1981250/2022100 11115/02' N1 E'er F9NO(14-08A) AFI No: 50-029-20330-01 (60) 12/01/02 NORDIC CID ML(14-08AL1) SEC 9,T10N,R14E,1961'FNL&1080'FEL 08/08/15 D.14 FINO 08/10/15 JM) ADDED DEPTHS FER RIG TALLYEP Exploration(Alaska) BP Exploration (Alaska) Inc. - Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 Mr. Tom Maunder _ :. ,~ . ~;~..:;~sl~t~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ~~ ~.. ~~ Subject: Corrosion Inhibitor Treatments of GPB DS 14 / ~_ ~ t~ Dear Mr. Maunder, n Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # 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 na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-o6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 14-to 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-2tA 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA t4-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20!2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corum. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08 3S-08A 3S-08B,3S-14, - - 3S-15. 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 3S-03: dò3 -aD¡ I -d: ¡4(~/~d. Digital Log Images: SCAN.aED FEB 0 1 2007 50-103-20458-00 3S-06: Ü:rc.. 903 -()~7- p:. t.../'-/'d3 Digital Log Images: 50-103-20454-00 3S-06A: UI<!.. QO'3-()'£s'~ ~ /L.JLJd-1 Digital Log Images: 50-103-20454-01 3S-08 3S-08A 3S-08B: dð3 -Odd. I dD3 -O~ I dö"3-o43 Digital Log Im~ges: ~ ¡'-{'IdS /¿,,/4Q(P 4LI;;7 50-103-20450-00,01,02 3S-14: UIC.dÓ~-d!O 'Jt¡,-f/2)O Digital Log Images: 50-103-20439-00 3S-15: .;)D8 -(;)54 rl 1'-/L/fJ'i Digital Log Images: 50-103-20444-00 t 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom e . WELL LOG TRANSMITTAL /jOQ /j-(() 1357Ò To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite] 00 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 14-08A Ll PBl, The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 14-08A Ll PBl: LAS Data & Digital Log hnages: 50-029-20330-61 50 - 0/)9 - 1J·033(1- {cO 1 CD Rom ~Q~lo ~\tõ - . WELL LOG TRANSMITTAL J D:J - dlÖ / 35LcA February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 14-08A L1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 14-08A L1: LAS Data & Digital Log Images: 50-029-20330-60 1 CD Rom :~ l~ {!1i®ti(> .. a 19:1/0G . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc / J~~ç- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022100 MD 14180"""'-' -- Well Name/No. PRUDHOE BAY UNIT 14-08AL1 Operator BP EXPLORATION (ALASKA) INC TVD 8979/ Completion Date 12/1/2002 ,.. Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Samples No Directional Survey Yes Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RES Well Log Information: API No. 50-029-20330-60-00 UIC N (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name -------~ ~/ ~b; D R6i ..£.[) D ~. Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments ~ PB1 ROP, DGR, EWR Horizontal Presentation, Repeat Section - MWD ROP, DGR, EWR Horizontal Presentation, Repeat Section - MWD 13219 14180 Open 11/7/2003 ROP, DGR, EWR- MWD ~ectional Survey t~'f804 LIS Verification ~ectional Survey (A1805 LIS Verification LIS Verification 1 13423 14180 Open 1/3/2003 3 13187 13619 Open 7/24/2003 1 13188 13665 Open 1/3/2003 6 13187 14138 Open 7/24/2003 6 13187 14138 Open 7/24/2003 3 13187 13619 Open 7/24/2003 25 13218 14180 Open 11/7/2003 25 13218 14180 Open 11/7/2003 LIS Verification ¡f""ED C Pdf ("'12253 Rate of Penetration \ / \ . V/ ED C Pdf c,/f2253 Induction/Resistivity ~ED C Asc ----~--- J.2253 LIS Verification 25 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received PB1 PB1 ;'-" Permit to Drill 2022100 MD 14180 TVD 8979 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? "-Y"rl~r"" Analysis .~ Received? ----- Comments: -------- --~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANC'E REPORT 1/6/2005 Well Name/No. PRUDHOE BAY UNIT 14-08AL1 Operator. BP EXPLORATION (ALASKA) INC Completion Date 12/1/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? ZJN ~/N Formation Tops lL Date: API No. 50-029-20330-60-00 UIC N ~j '?JM-.~ S- ~ .) ~1f~ut ~~ fÆ~!Æ~rA!Æ ) AT,AS&.&. OIL AND GAS CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar NS08 Sundry Number: 304-488 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on liday or weekend. A person may not appeal a Commission decision to Superio ot:.rt unless rehearing has been requested. ( DATED this~y of December, 2004 Encl. ~G/t-. ¡ 2-/27{~()O4 ) STATE OF ALASKA .''\ RECEIVED 10 ALASfv\ OIL AND GAS CONSERVATION COI...AISSION DEC 2 1 2004 ....~ ~ APPLICATION FOR SUNDRY APPRQVAhG C ~ 20 AAC 25.280 ,as ons. Commission ~ 1. Type of Request: ./tr.chorsgt:J Abandon D Suspend D / Operation Shutdown 0 PerforateD WaiverD Annular DisposalD Alter Casing D Repair Well ŒJ / Plug Perforations D StimulateD Time ExtensionD OtherO Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended WellD 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. / 202-0210 /' Development ]] ~ Exploratory 0 '. ~, 2. Operator Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12030 Casing Length Stratigraphic 0 Service 0 9. Well Name and Number: NS08 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11942 11127.0 MD TVD 6. API Number / 50-029-23068-00-00 Total Depth TVD (ft): 11270.3 Plugs (md): Junk (md): None None Burst Collapse Liner 1720 Lin~ n6 Production 9879 Surface 3288 Perforation Depth MD (ft): 11755 - 11785 11785 - 11815 11815 - 11845 11845 - 11875 11875 - 11895 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 5-1/2" HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal ŒJ 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Detailed Operations Program D Size 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10998.1 11027.7 11027.7 11057.4 11057.4 11087.1 11 087.1 11116.7 11116.7 11136.5 top bottom top bottom 9741 11461 9085.7 10708.1 7240 5410 11293 12029 10543.1 11269.3 8430 7500 40 9919 40.0 9248.6 6870 4760 40 3328 40.0 3220.1 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 9603 11297 5.5" 17# 13Cr80 40 9603 Packers and SSSV MD (ft): 11249 11293 1992 9741 BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentŒJ / ServiceD January 3, 2005 / 15. Well Status after proposed work: Oil Œ] GasD WAG D GINJD Plugged D Abandoned D WINJD WDSPLD Prepared by Garry Catron 564-4657. Date: Contact Michael Francis Printed Name Michael Francis Signature '1'YJf-J.ð>.J 9 ~ I p.£.. Title Phone Petroleum Engineer 564-4240 12/20/04 Commission Use Only Sundry Number: -~'I..ø' Conditions of approval: Notify Commission so that a representative may witness Form 10-403 Revised 06/2004 Other: BOP TestD Mechanciallntegrity Test D Location Clearance D BY ORDER OF THE COMMISSION Date ~ðf tvn~ÞM..5 ~ SUBMIT IN DUPLICATE . '1) ,o. TREE: ABB-VGI 5 1/8" 5ksi ")... WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS08 13 3/8" TAM Port Collar at +/-1582'MD 13 3/8", 68#/ft, L-80, BTC @ 3328'MD ~ 5.5", 17#/ft, 13-Cr, Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBLlFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT ~ I: 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813" ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WLEG, @ 11297' MD 3.958" ID - J B 7", 26#/ft L-80, BTC-M @ 11461'MD iI ¡:m:æA.1X)\JSM/AR( ÆFLffi SNSlBT (2I18Œ) A!\I3..EA TKPFER=: N:te: Rfer to R'cx::k..x::tia1 œ fa" histc:rica perf dàa htia R3rf - ~ 2OC6 FONer.Æt, I-M<; Rretratia1: 2J"; H:1e: .21:'1'; R1ase: 00 ~ SIZE s:F NTffiIAL M) NTffiIAL lVD Qn'&¡z 288 6 117ffi' -11800 1œE -11121:'1 QJ1 rnlE 3fZ2fMQ PBTD @ 11943' MD TD @ 12029'MD j DATE 1/16/02 3/13/02 3/27/02 12/20/02 COMMENTS ~S08 Proposed Updated Depths Updated Perfs Updated KB Information REV. BY BMH EMF EMF EMF 41118 ~ "' RKB. ELEV = 56' )B-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1992' MD, 1989' TVD w/ HRQ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD w/ 4.62" ID ~ ) / 51/2" x 41/2" XO @ 9603'MD, 8959' TVD ~ - 7" LINER TOP @ 9741'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') -;;- - 7" PACKER, 13 Cr @ 11249' MD, .- 10500' TVD . '£ V I 4.5" LINER TOP @ 11293'MD ~ r ~ 4.5",12.6#, 13CrVam Ace Northstar WFI I : NS08 API NO: 50-029-23068-00 BP Exploration-{Alaska) bp ') December 21 , 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS08 Leak Repair ) .,. ,\If.'''. -...~,~. ~...- ~411;- 4t.411;-- ~.~ F"'-' .'1''''.\' ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVED DEe.2 1 2D04 Alaska Oil & Gas C ans. Commission Anchorage BP Exploration Alaska, Inc. proposes to use a tubing patch to repair a very minor leak between the 5.5" tubing and 9-5/8" casing. The location of this leak is a tubing connection. The procedure includes the following major step: . Set a patch across the leaking tubing connection I' Sincerely, 4~L~ Michael J. Fra~is, P.E. Senior Petroleum Engineer BPXA, ACT, Northstar ) ') f!)cø-8\O WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Oakland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 14, 2003 RE: MWDFormationEvaluationLogs: 14-08ALl & 14-08ALl PBI, AK-MW-22187 14-08A Ll: Digital Log Images: 50-029-20330-60 1 CD Rom 14-08A Ll PBi: Digital Log Images: 50-029-20330-61 ." ) ~ j f:)(ý$ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: S perry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: I \ -. 7- rJ3 " Signed~ð\ u ^"~'-~ NOV 0 7 ~~~\'f\~ ) STATE OF ALASKA ") ALA5h.Á OIL AND GAS CONSERVATION COMI....6SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter Casing D Change Approved Program D SuspendL:] RepairwellD Pull TubingD Operation ShutdownD Plug perforationsD Perforate New PoolD 4. Current Well Class: PerforateD VarianceD Stimulate[!j Time ExtensionD Re-enter Suspended WellO 5. Permit to Drill Number: Annular Disposal D OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 Development 00 ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: NS-08 10. Field/Pool(s): Northstar 202-0210 6. API Number 50-029-23068-00-00 7. KB Elevation (ft): 56 8. Property Designation: ADL-2799 11. Present Well Condition Summary: Total Depth 1 Northstar Effective Depth measured 12030 feet true vertical 11270 feet Plugs (measured) measured 11942 feet Junk (measured) true vertical 11 071 feet Length Size MD TVD Burst Collapse 3287.9 13-3/8" 68# L-80 40 3328 40 - 3220.1 4930 2270 9878.9 9-5/8" 47# L-80 40 9919 40 - 9248.6 6870 4760 736 4-1/2" 12.6# 13Cr80 11293 - 12029 10543.1 - 11269.3 8430 7500 1720 7" 26# L-80 9741 11461 9085.7 - 10708.1 7240 5410 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Measured depth: 11755' -11785',11785' -11815',11815' -11845',11845' -11875',11875' -11895' Packers & SSSV (type & measured depth) True vertical depth: 10998.09' -11027.74' ,11027.74' -11057.39' , 11057.39' -11087.05' ,11087.05' -11116.72' 11116.72' - 11136.51' 5-1/2" 17# 13Cr80 @ 40.1' - 9603' 4-1/2" 12.6# 13Cr80 9603' - 11297' 7" Liner. Top Packer @ 11196' MD/7" Liner Top ~~s~~r,¡;@~~,~"4J~ ~p~. 4-1/2" Lmer Top Packer @ 11293' MD /5-1/2" HRc) !SSl. 'ij)"iœ'9~' tJlllt~> Tubing: ( size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: (See Attachment) 9 13 Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 6,025 39,600 28 6,025 39,600 28 ,Ô.::; f'>¡~ ;",; n ~,' ;',\ t!, . Tubing p'ressure 1784 1784 Prior to well operation: Subsequent to operation: 14. Attachments: Signature Michael J. Francis, P.E. ~¡;:;;]~~ 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] Service D 16. Well Status after proposed work: Operational Shutdown D Oiloo GasO WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-242 Copies of Logs and Surveys run - Daily Report of Well Operations - X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Senior Petroleum Engineer /RE. Phone 564-4240 Date 9/26/03 ORIGINAL ~t~ Form 10-404 Revised 4/2003 ') ^') NS-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/22/03 Acid Treatment, well shut in on arrival with 3500 psi, Pump pickle per procedure, 3 bbls meth, 18 bbls DAD Acid, 133 bbls SW, 97 bbls Diesel, flow pickle back to production. Start main Acid treatment and continue. 08/23/03 Acid Treatment, Pickle pumped and flowed back, continue with main DAD Acid treatment per procedure, 33 bbls 120/0 DAD Acid, 253 bbls SW, shut down for 30min soak, 186 bbls SW, 97 bbls Diesel, leave well shut in for 4 hours, turn over to production. FLUIDS PUMPED BBLS 3 51 572 194 820 Methonal 120/0 DAD Acid Sea Water Diesel TOTAL Page 1 ) ') ~oa.-alt> , , 80t WELL WG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation COmIn. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska July 21, 2003 RE: MWDFormationEvaluationLogs 14-08ALl PB1, AK-MW-22187 1 LDWG formatted Disc with verification listing. PlPI#:50-029-20330~1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 RECE'VED Date: JUL 24 2.003 Signed: . ~ Alaska OrÎ & Gas Cons. commission Anchorage BP Exploration (Alaska) Inc. Petro-Teclmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~¿/( ") ") 8J)~-à.ro I t gO$" WElL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West T Avenue~ Suite 100 Anchorage~ Alaska July 21, 2003 RE: MWDFonnationEvaluationLogs 14-08AL1, AK-MW-22187 1 LDWG fonnatted Disc with verification listing. ~I#: 50-029-20330-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~~9518 JUL Z 4 2.00~ A1a~f&~i:Gas Cons. C{)mrniØcfi h,d)~ BPExploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: f8wo TUBING (24-6246, 00:3.500, 10:2.992) ~OOUCTlON (26-6879, 00:7.000, Wt:26.00) GasUft lAandrelNalvE 1 (6113$114, 00:5.968) NIP (6159-6160, 00:4.520) SEAL (6197-6199, 00:5.870) PBR (6199-6213, J 00:5.870) Ancoor Nipple (6213-6214, 00:4.740) PACKER (6214-6219, 00:5.956) NIP (62æ-6239, 00:4.500) SHOE (687~79, 00:7.000) ", Qirt.~ò.PhjÎlijt:,~kØ~:iåö* :~~~:~ ); " .'.:;. I] '.," .'.':~~ :;";.; \J! . ',':- .:::: :.\ '~tt1¡~ ') ') ~Otf--8 10 KRU 38-14 3S-14 API: 501032043900 SSSV Type: NIPPLE Well Type: SVC Orig Completion: LastW/O: Ref Log Date: TO: 6895 ftKB Max Hole Angle: 34 deg @ 2355 Rev Reason: Depth changes Last Update: 1/17/2003 Angle @ TS: 24 deg @ 6559 Angle @ TO: 23 deg @ 6895 Annular Fluid: Reference Log: 24.33' RKB Last Taç¡: Last Tag Date: Casing String - ALL STRINGS Description Size PRODUCTION 7.000 SURFACE 9.625 CONDUCTOR 16.000 Tubing String - TUBING Size I Top I Bottom 3.500 24 6246 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 6113 5464 CAMCO MMG 1. Sheared Other ()Iugs,equip., etc.\. JEWELRY Depth TVD Type 24 24 HANGER 496 495 NIP 6159 5505 NIP 6197 5539 SEAL 6199 5541 PBR 6213 5554 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION BAKER 80-40 MILL OUT EXTENSION NIP CAMCO '0' NIPPLE WINO GO PROFILE WLEG WIRELlNE GUIDE W/SHEAR OUT SUB lTL SHOE Top 26 29 29 Bottom 6879 2808 108 TVD 6161 2556 108 wt Grade Thread 26.00 L-80 BTCM 40.00 L-80 BTC 62.50 H-40 WELD TVD 5584 I Wt I Grade I 9.30 L-80 Thread EUE8RD V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt RK 0.000 0 12/26/2002 (1) OCR 1.5 Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE LOCATOR SUB & PBR 12' SEAL ASSEMBLY BAKER PBR 80-40 KBH-22 ANCHOR TUBING SEAL NIPPLE ID 3.500 2.875 2.812 3.500 2.970 2.993 6214 5555 6219 5559 6238 5576 6245 5583 6246 5584 6878 6160 General Notes Date Note 1/8/2003 TREE: FMC I WKM f GEN 51 SM TREE CONNECTION: TOP 5.75" ACME WITH 3.5" EUE8RD THREAD 3.250 3.730 2.750 2.992 2.992 6.151 RECEIVED MAR 1 4 2003 Alaska o;~ & Ga¡¡ CenE. Commieeion Anch~ ) ) Casing Detail .9 5/8'1 Surface Casinq ~PHILLIPS Alaska, Inc. ~ A subsidiary of PHILLIPS PETROLEUM COMPANY Jt. Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 66 Nabors 7ES RKB to Landing Ring 29.101 FMC Gen V Hanger 9-5/811 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/81140# L-80 BTC Csg Davis Lynch Float Shoe 64 Jts Jts 1 to 2 2 Jts TO 12 1/411 Surface Hole 12-1/4" T.D. @ 28201 MD 25661 TVD 9-5/8" Shoe @ 28081 MD 25551 TVD RUN TOTAL 13 BOWSPRING CENTRALlZERS- 2 on jt.#1 (31 to 51 above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #12 (Total of 13 centralizers & 2 Stops) Total of 82 Jts. On location (Including extra float equip.) Total of 7 Jts. Outside shed (Including extra float equip.) Total of 75 Jts. Inside shed Run Total of 66 Jts. Total of 9 Jts. Left out inside shed Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 125k On Wt - 93k Block Wt - 30k Drifted all casing to 8.679" Well: 38-14 Date: 12/20/2002 LENGTH 29.10 2.27 2692.23 1.50 81.81 1.70 DEPTH TOPS 29.10 31.37 2723.60 2725.10 2806.91 2808.61 2820.00 Supervisor: Mike Thornton I Peter Wilson ,',' , " ) 'ConocoPhillips Alaska' .',' , , , ': 'C~mentil1g Report Legal Well Name: 3S-14 Common Well Name: 38-14 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: , Primary 12.250 (in) 2,808 (ft) 12/20/2002 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ) , ", ,~. , . ~',Page,1of 3, Report #: Start: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Cement Job Type; ,Primary Squeeze Open Hole Hole Size: SO TMD: (ft) SO Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos Cmtd. Csg: Plug Hole Size: Top Set: BTMset: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating (ft) (ft) Rot Time Start:: Time End:: RPM: Rec Time Start: 1 0:15 Time End: 13:38 SPM: 1 . ~: ' Type: Cement Casing Volume Excess %: 350.00 Meas. From: 227 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 410 (psi) , , Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 125 (Ibs) Start Mix Cmt: 12:35 Start Slurry Displ: 12:35 Start Displ: 13:55 End Pumping: 14:30 End Pump Date: 12/20/2002 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 9.4 (ppg) Visc: 72 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud " Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) y 430 (psi) 1,000 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: 103 (Ibs) Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: 227.00 (bbl) Ann Flow After: N Mixing Method: TUB Density Meas By: Densometer PVIYP: 31 (cp)/23 (lb/10Qft2) Gels 10 sec: 9 (lb/100ft2) Gels 10 min: 14 (lb/10Qft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 205.60 (bbl) ,Mud Data ' I ...', . ~ '. " , , ' ":~ ,',;'~~~~e N~: 1 ~ ~'~~rYNo:',1.:~f :~ " , - To: (ft) Description: CW100 Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: -. ; I , ' Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:59:12 PM ') t..' '. ~' .. . .. . ~. . Legal Well Name: 38-14 Common Well Name: 38-14 Event Name: ROT - DRILLING .'. Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: ) . . . . . ConocoPhilUps Alašk~ . Cementi.ng. RepQrt.. -, \- .. '~. ¡ . " Page 2:~f~ Report #: Start: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 38.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) . "'.:',' '.". .'" .- . :'::.:;,.~Ùt~e':;~:ò::.,1. :!'~I~r:~Y:'.~~,:::3...:6f;:4 . . Description: ARCTIC SET Class: G To: 1,661.00 (ft) Cmt Vol: 435.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (fP/sk) Slurry Vol570 (sk) Water Vol: 262.4 (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) . Trade Name D79 S001 D46 D65 D124 D53 D44 I '.." Time Compressive Strength 1: Compressive Strength 2: Temp (OF) eF) Stage No: 1 Slurry No:3 of 4 - Additives type . Concentration' . Units . Liquid Conc. 1.5C %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.1 C %BWOC 30.00 %BWOC %BWOC 'Stage No:.1 SiLirry No: 4 of..4 . Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 1,661.00 (ftJro: 2,808.00 (ft) Cmt Vol: 99.7 (bbl) Water Source: Slurry Vol250 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 12.00 (ppg) Yield: 2.24 (fP/sk) Water Vol: 44.2 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 19.34 (gal) Foam Job: N Pressure (psi) (psi) Units. 9.00 %BWOW Purpose: TAIL Mix Water: 7.44 (gal) Foam Job: N Pressure (psi) (psi) Printed: 1/31/2003 2:59:12 PM c, ...~ r.¡r ; , " Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Trade Name D79 D46 D124 D65 D164 ~:;11!~:¡.',~ii'¡j~~~iij~:fi~~;'¡;!\'. , " Test Press: (psi) For: (min) Cement Found between Shoe and Collar: ~~J;;ttf;¡':~~t~4~~~~\~y,~I~~'196;. ,. CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: ") ") , , ,', -- :>qono.coPhilliPS Ala'sk~ ,,:,Cementing R~port . Page'3'of3" Report #: Start: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Stage .No: 1 Slurry No: 4 of 4 - Additives Type Concentration Units Units Liquid Conc. 0.50 %BWOC 0.60 %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC .. ',. .'¡'>-:.' " .,~,.,..' '-~'.'" ~'"., I - , ,; ;;'..J.¡~~t~~;1:~~!;;.;:..,;f:/ ;:,,<",;["~~'~'r~,s~,:. ' '-", . Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: . ..,¡jQi~rPt~~i¡~~~.~;hiñ~~"'.'.. Tool: Tool: . . , ,~." ., , , , " (ft) Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: , Remarks, Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 72, YP from 48 to 23, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 5 bbls CW 100 Chern Wash, Tested Lines to 3,500 Psi, Pumped 45 bbls CW 100 Chern Wash at 8.3 ppg, 5.5 Bpm @ 155 Psi, Dropped Btm Plug, Pumped 38 bbls of 10.5# Mudpush spacer @ 3.0 bpm @ 125 Psi with Red Dye in Spacer, Mixed & Pumped 435 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 140 Psi, Reciprocated Pipe until cmt. to surface, then Pipe got Tight-Landed Pipe, Observe Nut Plug and Red Dye Markers at Shakers, Pumped Lead Cmt until Cmt to Surface-31 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 6 Bpm @ 275 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 185.6 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 780 Psi, Slowed to 3 bpm @ 430 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 227 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 1430 Hrs 12/20/02 Printed: 1/31/2003 2:59:12 PM '.. Conoc()P"i,Ui~s, Alaska . . DaUy Dr~lling Report WELL NAME 3S-14 I JOB NUMBER I EVENTODCRODE 124 HRS PROG TMD I TVD I DFS 2,820.0 2,566.0 3.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Mike Thornton/Peter Wils n1268@conocop Nabors 7ES Kuparuk River 6,918.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Testing BOP's 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL PU 8 1/2" BHA TIH, Test Csg, Drill Out Fit Equip, LOT 12/18/2002 339,231 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 10027622 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 12/19/2002 2,732.05 30.320 349.980 9.625 (in) @ 2,808.0 (ft) 7.000 (in) @ 6,918.0 (ft) ...~e~.sl!"(pp~) .1.. .9:4?, Il~~/¡ ".,. .1:Êþrrl."JMU~..~~,.AI~AI~.~.~O~T,1 0.00 "'C"1r:7ÜM.'.:~.:.C,.'c'.:.O.,..a:S.:.."....:."T.'.,...".:..J:.::,.,.:.."H'."Z','S'. ".'.'."". "....O".'U' ,..OMO E'.'.'.' "...~'S~.'....' '?~~~Y:f)~\~'!l!~,;;: ,::)(;~4$.t: ':i;W~Jt;ff.','~.':FèmSØ.L:,:\.()ILlWp.t ,,0; ..~;'~~~~~1':>:' :;: /':Phlprill:L~', '.Pf/Mf " . .. 72 31/23 9/14 6.41 2/ I 120.0 8.5/ / x: :;«::: ,:~ <-":,,,":"::T',:.::,::.':o...'\:..,:'.,:'.",...,:','" :,!;.','H".' :o"",.:,.u:,:.'.'.i,R".'.:S..".." '¡.", ' '. '. . '" '.: .: .,.';'; 'O...".B."p".'..','H~.':::A',R,'. .s:",.,.,.ft(,'E,',...r,:.:"'.,'..~.,.,°",'.;:. 'N.: :S.:,::~.S~M.'."fJI~Ä~"" . ,o'e"s' 'C:..'RI"P' ...TJ'" .0'.' ..:Ni..',:.: . . !~~Ø~~i .. . : '.":¡þ:Ó.P~"-: ~.Ó~BL:E ":;$~B'. .. .. 00:00 01 :00 1.00 CASE P RURD SURFAC Fin Ru Nabors Csg Equipment & GBR Fill up Tool, Held PJSM 01 :00 04:00 3.00 CASE P RUNC SURFAC MU 9 5/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, While RIH with Csg, Started taking Wt at 1,580', Attempted to Circ & Fill Up Tool Malfunctioned RUNC SURFAC LD Fill Up Tool & MU Circ Swedge, Washed & Worked Csg Thru Base of Permafrost from 1,580' to 1,780', MU Fill Up Tool with Check Valve Removed RUNC SURFAC Cont RIH with 9 5/8" Csg, Landed Csg in Head - Ran a Total of 66 Jts to 2,808.61' Landed Csg wI FS @ 2,808', FC @ 2,723'. RURD SURFAC RD Fill Up Tool & MU Cmt Head CIRC SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 72, YP from 48 to 23, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg PUMP SURFAC RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,500 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg, 5.5 Bpm @ 155 Psi, Dropped Btm Plug, Pumped 38 bbls of 10.5# Mudpush spacer @ 3.0 bpm @ 125 Psi with Red Dye in Spacer, Mixed & Pumped 435 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 140 Psi, Reciprocated Pipe until cmt. to surface, then Pipe got Tight-Landed Pipe, Observe Nut Plug and Red Dye Markers at Shakers, Pumped Lead Cmt until Cmt to Surface-31 bbls Late. Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 6 Bpm @ 275 Psi, SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 185.6 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 780 Psi, Slowed to 3 bpm @ 430 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eft on Rig Pumps, Had 227 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 14:30 Hrs 12/20/02 SURFAC Checked Floats & Held, RD Cmtg & Csg Equipment, LD Landing JT SURFAC Flushed Divertor System with Water SURFAC Cleaned Rig Wind Walls & Mud Pits SURFAC ND 21 1/4" Divertor & 16" Line & Removed Starting Head SURFAC Installed FMC 11" 5M Gen V Wellhead & 11" 5M Tbg Spool & Set on BOP Stack, NU Wellhead & Tbg Spool & Tested Seals to 1,000 Psi, Good Test ,--' I ~ 04:00 07:30 3.50 CASE Np 07:30 09:30 2.00 CASE P 09:30 10:00 0.50 CASE P 10:00 12:00 2.00 CEMENT P 12:00 14:00 2.00 CEMENT P 14:00 14:30 0.50 CEMENT P 14:30 17:00 17:00 17:30 17:30 19:30 19:30 22:00 22:00 00:00 CEMENT P CEMENT P RIGMNT P WELCTL P WELCTL P 2.50 0.50 2.00 2.50 2.00 -) ') . Page.'1 01'.2.""" I REPT NO. I DATE 4 12/20/2002 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 603,968 AUTH. LAST BOP PRES TEST DISP RURD OTHR RSRV NUND NUND Printed: 1/31/2003 3:05:10 PM ~) ') .\' ", . , , .. 38-14 . . Conoco~~iUip'~, ..~~'a~ka' . DailY 'Drilling Report . JOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~820.0 Page 2'°1 2 . . , . . WELL NAME TVD IDFS REPTNO. DATE 2,566.0 3.00 4 12/20/2002 24 HR SUMMARY: Ran & Cemented 9 5/8" Csg to 2,808', Had 227 bbls of Cmt Back, Bumped Plugs & Floats Held, CIP @ 14:30 Hrs, RD Csg Tools, Cleaned Around Rig, ND Divertor & Line, MU Gen V Wellhead & Tbg Spool, RIG CAMP WENT ON HIGHLlNE POWER @ 09:15 12/20102 COMPANY ConocoPhillips Nabors Doyon Universal SERVICE PERSONNEL DAT~ NO. HOURS COMPANY 2 Sperry Sun 32 Baroid 6 APC SERVICE NO. HOURS 4 2 2 ;~q~¿1~:;~~i;;:~:~%;;,;,:j:'!!"~~¿{::',,:.¡!:i~'1~~i~~:,~~~~~~~~!£~~~~~~I~~"i:' Fuel gals 3,499 17,076 Fuel (camp) Water, Drilling bbls 1,018 92 Water, Potable . ~. ,¡ . '"" . ,I.:' :: ':,: . . ~ ~ .~. ,:,: ;~'>.;' '.:::} :. .. . :; ,', ,~. .. .:~: -'.: '~. . ":.~: ;",;; .: .,:-,:,,',- ," ',' ~~. ,"uNì~..' gals gals :;¡i;4#.~~E ':'0<::.: <d~::~Af1Þ.;>J':: 442 2,056 4,740 15,660 . . ,I': ..",.~. :~ð~~..~~~'~~~Ó~.~~~ti!!:~~:ERYAL:OAT~~.. 2306 2.5 750 psi 0 0 0 0 . ,"".""'1,~ -, . . ",,,,,.. . ',1' "~:1'.. ::~. I .: : .. " ...' ::". ,': . '.' ,:;:;::.. >: :'~ih~.~E~VOJ~:~ÀM~; :.: 38-07 1 R-18 G & I Prudhoe Bay '.' . '. ~ I : ", . , . '. ~ "':' ~ . , . ' 3S-14 3S-14 3S-14 Printed: 1/31/2003 3:05:10 PM PRESSURE INTEGRITY TEST PHilLIPS Alaska, Inc. Well Name: 3S-14 Rig: NABORS 7ES Date: 12121/2002 I Volume_'nput Volume/Stroke Pump Rate: Drilling Supervisor: MIKE THORNTON/PETER WILSON. I Pump used: I #1 Mud Pump I. Strokes 'Y 0.0698 Bbls/Strk 'Y 8.0 Strk/min 'Y Type of Test: I Casing Shoe Test LOT/FIT 1....1 Pumping down I annulus and DP. I"" Casing Test Pressure Integrity Test Hole Size: I USE PICK LIST I'" Casing Shoe Depth I Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 27.0 Ft 2,808 Ft-MD 2,555 Ft-TVD 2,840 Ft-MD 2,583 Ft-TVD Strks psi Min psi Strks psi Min psi CasinQ Size and Description: 19-5/8" 40#/Ft L-80 BTC 1...1 0 0 0 2550 0 0 0 480 Casin9 Test Pressure InteQritvTest 7 545 1 2550 3 '!J3Ù 230 0.25 430 Mud Weight: 9.4 ppg Mud Weight: 9.3 ppg 14 950 2 2550 5 ,\ 400 0.5 430 Mud10minGel: 14.0 Lb/100Ft2 Mud10minGel: 8.0 Lb/100Ft2 21 1345 3 2550 7\~565 1 430 Test Pressure: 2,500 psi Rotating Weight: 98,000 Lbs 28 1815 4 2550 9 \65""725 1.5 420 Rotating Weight: 98,000 Lbs BlockslTop Drive Weight: 25,000 Lbs 35 2350 5 2550 12 ,;5 860 2 420 BlockslTop Drive Weight: 25,000 Lbs Desired PIT EMW: 18.0 ppg 37 2550 6 2550 14 '\S- 935 2.5 420 Estimates for Test: 1.7 bbls Estimates for Test: 1156 psi 0.8 bbls 7 2550 21 464 3 420 r .1 I. 8 2550 28 460 3.5 420 EMW = !-eak-off Pressure + Mud Weight = 935 + 9 3 PIT 15 Second 9 2550 35 450 4 420 0.052 x TVD 0.052 x 2555. Shut-in Pressure, psi 10 2550 42 436 4.5 420 EMW at 2808 Ft-MD (2555 Ft-TVD) = 16.3 ppg 430 15 2550 49 443 5 420 - Lost 0 psi during test, held 100% - 20 2550 57 440 5.5 420 of test pressure. 25 2550 6 420 I 30 2550 6.5 410 7 410 7.5 410 8 410 8.5 410 9 410 9.5 410 10 410 3000 2500. / / ¡r;"'''w''''''" 2000 - UJ 0:: ::J ~ 1 500 UJ 0:: a.. 500 T 1 000 - 0 0 2 Barrels 30 4 ---CASING TEST -8-LEAK-OFF TEST 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 0 Comments: 0 ume Volume 0 ume Pumped Bled Back Pumped 2.6 t:Sbls 2.6 I:Sbls 4.0 t:Sbls Minimum acceptable LOT is 14.1 ppg t:.MW for this well. I he point at 725 psi could be interpreted as the leak-off point (14.8 ppg EMW). Vo ume Bled Back 0.5 I:Sbls ,-"",' í '--" ) ) Ca'sing Detail 7" Intermediate Casina ConocoPhillips Alaska Jt Number Num of Jts Jts 5 to 162 Jts 1 to 4 Remarks: 158 Jts 4 Jts Up Wt = 205k COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LOS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 402 Float Collar 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 303 Float Shoe TD of 8-1/2" hole @ 6,895' MD 6175' TVD 7" Shoe @ 68791 MD 6160' TVD Total Centralizers 1- 7" Bowspring cent.! stop rings 10 above FS jt # 1 & 10 below FC 0 Bowspring centralizer over collar on joints #2 , #3 and #5 thru #32 7" x 8-3/8" Centering guide on every jt. From #97 thru #101 (Total of 5) 7" x 8-3/8. Centering guide on every 3rd Jt. # 152,155,158,161. (Total of 4) Totals: 32 Bowspring, 9 centering guides, 2 Stop collars Total of 181 jts.on location Total of 162 jts. Ran in hole Total out: 19 Its. (last jt on tally # 170 in shed - [11 jts Outside shed not on tally) ( Including xtra float equip. Use "Run-N-Seal" pipe dope Drifted to 6.151" Dn Wt = 125k Block Wt= 30k Well: 38-14 Date: 12/25/02 LENGTH 26.40 1.85 6679.21 1.27 169.61 1.46 DEPTH TOPS 26.40 28.25 6707.46 6708.73 6878.34 6879.80 Supervisor: Mike Thornton / G. Rízek ) ') Co~ocoPhillips Alaskä. "'Cêm'énting Report Legal Well Name: 3S-14 Common Well Name: 38-14 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 6,879 (ft) 12/25/2002 Production Casing 7.000 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Page 1.of 3. Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) SQ Date: SO Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: SO Date: Cmtd. Csg: Cementer: Rick Gallegos Cmtd. Csg: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating ...... ",.... . .', . . , ' ": . ~".. " . ¡ ..'. ': '. . ::. :,:': / ¡ : '.' ;.,::::",:,"'~'..r;',,~':::::.'~(~è;:;~i~Y~'I11\~QJ".,.".': ,. Rot Time Start: : Time End:: RPM: Rec Time Start:20:00 Time End: 06:45 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 205 (Ibs) L¡I Type: Cement Casing Volume Excess %: 45.00 Meas. From: Time Circ Prior To Cementing: 9.00 Mud Circ Rate: 167 (gpm) Mud Circ Press: 385 (psi) Stage No: 1 of 1 Start Mix Cmt: 04:15 Start Slurry Displ: 04:47 Start Displ: 05:38 End Pumping: 06:53 End Pump Date: 12/26/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.50 (bbl/min) 4.50 (bbl/min) y 1,650 (psi) 2,300 (psi) 5 (min) y (ft) (ft) Max Torque: (ft-Ibf) Drag Down: 125 (Ibs) Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: Densometer Type: Non-Disp. LS Density: 11.7 (ppg) Visc: 46 (s/qt) PV/yP: 15 (cp)/16 (lb/10Oft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 12 (lb/100ft2) Bottom Hole Circulating Temperature:115 (OF) Bottom Hole Static Temperature: 145 (OF) Displacement Fluid Type:Seawater Density: 8.4 (ppg) Volume: 265.10 (bbl) . Mud Data . - . .. : :..,:~J~.9.~',N.6: 1 ~~~~..ry':.N6: 1.' Ói;3 ': Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 3,741.00 (ftJTo: 4,183.00 (ft) Cmt Vol: 10.0 (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: eF) Temperature: (OF) Temperature: (OF) Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: - . Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:59:03 PM ) ) , , ~.' ; , " , Conoco,Ptlillips Alaska, . ., ; ~ ' .. I'. .,: .. " "Ceni'enting Report Page ,2 of 3 . : ! Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: Stage No: 1 $'Iurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 4,183.00 (ft}To: 5,510.00 (ft) Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: eF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) . . ", .\'. , .' .~. ~. .' . .: ' '",'~:,:.'. ':,;::»~~.~~>:~.ò_~:'}:i:;:~:,~yt~:~9~::i~>'<?~,.,3.:" Slurry Data Fluid Type: TAIL Description: G w/ Gasblock + 1/4 #/sac Class: G Slurry Interval: 5,510.00 (ft}To: 6,879.00 (ft)CmtVol: 51.0 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Source: Slurry Vol246 (sk) Water Vol: 30.3 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 4.12 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) , Stage No: 1 'Slurry N():,3 of 3 - Additives Trade Name "Type Con'centration ' , . Units, liquid Cone. Units 065 8155 ,0600 D47 O.3C %BWOC 0.02 %BWOC 2.0C G P S 0.20G P S Printed: 1/31/2003 2:59:03 PM ') ) J. ,~ - . .' ~'C~ryocóPhillips.Alaska . ..Oementing:Reþort . Page 3 of 3 ',~ . , ' .' - \~ . . " . Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: C~sing Test. . Shoe Test . Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ~ : . Remarks Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 30 bbls MudPUSH @ 12.5 ppg, 246 sxs (51 bbls) @ 15.8 ppg Class NG" GasBLOK and 1/4 #/sack celloflakes wI + .300%BWOC D65, .020%BWOC B155, 2.000 gal/sk D600G, .200 gal/sk 047, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 30 bbls MudPUSH at rate of 4 bpm at 475 psi, Drop #2 btm plug, Pump 51 bbls cmt at rate of 4.5 bpm at 390 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 181 bbls seawater at rate of 4.5 bpm at 990 psi until MudPush around shoe, Slowed rate to 3.0 bpm @ 1050 psi until last 30 bbls of displacement then slowed rate to 2 bpm @ 1650 psi & bumped plug wi total of 265.1 bbls, Bumped plug wI 2300 psi, Bled back 2.0 bbls for a total of 263.1 total bbls displaced (Calculated 263.3 bbls), CIP @ 0653 hrs 12/26102, Had good circ. thru out job- no noticeable mud loss, Displaced entire job with Dowell. Worked casing 10' thru out entire job until last 10 bbls of displacement, then landed in hanger. Check flow- Well static. Printed: 1/31/2003 2:59:03 PM . ",. " . . '~.;: ". : :,"C~n.~~Ò~l1i1~.i.P.è, .~Iaska . , '~à:nÿ Drillh~g'Aepórt JOBNUMBER EVENTODCRODE 24HRSPROG TMD TVD IDFS 6,895.0 6,175.0 9.00 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Kuparuk River 6,918.0 0.00 ACCIDENTS LAST 24 HRS. ? DAILY INT W/O MUD Rigging up fl injectivity test 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Finish work on well, freeze protect, secure well, UD DP, RR 12/22/2002 447,446 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 16.34 10027622 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 12/23/2002 6,895.00 22.080 346.760 9.625 (in) @ 2,808.0 (ft) 7.000 (in) @ 6,918.0 (ft) 12/21/2002 DENSITY(ppg) I 8.50 I PP I I ECD I I MUD CAT A I DAILY COST I 0.00 I CUM COST I 0.00 FV. PV/YP GELS WUHTHP FClT.SOL OIUWAT %SandIMBT Ph/pM PflMf CI Ca H2S LIME ES 28 / I I I I I I ¡~~t~;';:;¿~i' ..;~~~;:';;;~~i;i;~~J~"~;};.~~;;i~r~~~!~~~:~~~~~~~;.... . ..\:?¡~~;~~;~~~rI';.".'.. 00:00 01 :00 1.00 CEMENT P CIRC PROD Continue to circ and condition hole prior to cement job on 7" 26 # L-80 BTC-Mod casing. Reducing MW f/12 ppg to 11.7 ppg Recip 10' wi PU 205 k & SO 125 k Circ one bottoms up after 11.7 ppg all the way around @ 4.5 bpm 390-420 psi. Gas 17-20 units ') ;'I~: .;:, .. . t...' . ~ ,,''; . .' . . .. . '.. ; ~ -:. WELL NAME 3S-14 SUPERVISOR I RIG NAME Be. NO. Mike Thornton/G. Rizek n1268@conocop Nabors 7ES CURRENT STATUS 01 :00 01 :30 0.50 CEMENT P 01 :30 05:00 3.50 CEMENT P RURD PROD CIRC PROD 05:00 08:00 3.00 CEMENT P PUMP PROD ) . .. . P.àge 1 012 . REPT NO. DATE 10 12/26/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,722,075 AUTH. RID Frank's fillup tool. RU Dowell cement head. Well flowing(Breathing) while changing out head. Flowed back 7.3 bbls in 30 minutes. Continue to circ wI Dowell cement head. Recip casing. First movement off hanger after changing out head req'd 240 k. Then normal PU wt of 190k-205k. SO 120K-125K. 155 bbls into circulation, max gas units of 153. (Guage hole would indicate 6194') Decressed to 50 units by 180 bbls pumped and progressive back to 0-20 units. Circ @ 4 bpm 380-390 psi Dowell batch mix 10 bbls CW 100 @ 8.3 ppg, 30 bbls MudPush @ 12.5 ppg, 246 sx (51 bbls) @ 15.8 ppg Class "G" GasBlok WI .3%BWOC D65, .02%BWOC B155, 2.0 gal/sk D600G, .2 gal/sk D47 & 1/4 #/sx celloflakes PJSM on cemeting 7" casing. Dowell pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump 5 bbls CW100 @ 8.3 ppg, drop bttm plug, reload head wi another bttm and top pug. Dowell pump 30 bbls MudPush @ 12.5 ppg @ rate of 4 bpm wi 475 psi. Drop another bttm plug, pump 51 bbls Class KG" GasBlok @ 15.8 ppg wi additives at rate of 4.5 bpm with 390 psi, shut down, flush lines to rig floor wi seawater. Drop top plug, Dowell displace first 181 bbls seawater @ 8.4 ppg at rate of 4.5 bpm with 990 psi until MudPush around shoe, then slowed rate to 3 bpm with 1050 psi until last 30 bbls of the displacement. For the last 30 bbls of displacement the rate was 2 bpm with 1650 psi. Bumped plug wi total of 265.1 bbls, bumped wI 2300 psi. Bled back 2 bbls for total of 263.1 bbls displaced (Calculated 263.3 bbls). CIP @ 0653 hrs 12/26/02. Had good circ throughout job. No noticable mud losses. Displaced entire job wi Dowell. Recip casing 10' stroke throughout entire job until last 10 bbls of displacement, then landed hanger. Printed: 1/31/2003 3:04:33 PM ) ) ,.-' - , , " 3S-14 , , ' , , , ' , "- 'COnOCOPhilUpS." ~I~'ska, Da'ily Dril.iin'g Aeport ' IJOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~895.0 ~~ge2 of 2, f ., ' I, ; WELL NAME ITVD IDFS REPTNO. DATE 6,175.0 9.00 10 12/26/2002 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PftASE' DESCRIPTION 08:00 09:30 1.50 CEMENT P OTHR PROD Flush out BOP stack wI water, mud pump # 2, kill & choke lines to get mud out of system. UD Landing jOint. Install FMC packoff on 7" casing hanger. RILDS. Test to 5000 psi fl 15 min. PU tubing equip. RU to run 31/2" completion. PJSM on running 31/2" completion. Run 31/2" 9.3#/ft L-80 EUE 8rd-mod completion equip (197 joints wi jewlery) to 6245.67'. PU wt 80 K SO wt 65 K RU & Pressure test 7" casing to 3500 psi fl 30 min test. Chart test. Plot test. Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 6213.78' Slowly pressure 3 1/2" tubing to 2500 psi. Wait 10 min. Slack off 20k, then continue to pressure tubing string to 3000 psi and hold fl 15 min. Bleed pressure to 1000 psi. PU to 105k to shear PBR. Slack off, tag locator wi 10k. Pressure to 3676 psi to shear ball seat. Bleed off all pressure. SOHO PROD Pull joint 197 out of hole (pulling 12' seal assembly out of polished bore recepticle). MU 31/2" FMC tubing hanger on joint # 196. Use joint # 197 as landing joint. RIH and land tubing wI locator 2' above fully located in PBR. RILDS. OTHR PROD Pressure 31/2" tubing to 3500 psi fl 15 min. Bleed pressure to 1500 psi. Pressure 7" x 31/2" annulus to 3500 psi fl 15 min (Pressure on tubing increased to 2100 psi). Bleed tbg pressure to zero. RP sheared wI tubing pressure @ 500 psi. Bleed both sides to zero. All tests were charted. 09:30 10:30 1.00 WELCTL P OTHR PROD 1 0:30 11 :30 1.00 CMPL TN P RURD PROD 11:30 12:00 0.50 CMPL TN P SFTY PROD 12:00 19:30 7.50 CMPL TN P RUNT PROD 19:30 21 :00 1.50 CMPL TN P OTHR PROD 21 :00 22:00 1.00 CMPL TN P PCKR PROD 22:00 23:00 1.00 CMPL TN P 23:00 00:00 1.00 CMPL TN P 24 HR SUMMARY: Recip 7" csg @ 6880' wi circ , MU cmt head, circ, cmt 7" csg-CIP @ 0653 hrs, Flush BOP's, chng bales, RID cmt equip, UD Ind jt, inst packoff , RU/Run 31/2" compl, test 7", set pkr, shear PBR, shear ball seat, PU/MU hanger, Lnd, RILDS, test tbg, test ann ," ITEM: USAGE 2,267 409 . ,. . . , PERSONNELDATA ' NO: '", HOl)RS' <COMPANY 2 Sperry Sun 33 Baroid 6 APC MATERI.ALSICQNSUM~TION , ,ON HAND,: ',', " ITEM" ' 9,355 Fuel (camp) 642 Water, Potable SERVICE NO. ,'HOURS 3 2 2 , COMPANY ConocoPhillips Nabors Doyon Universal , SERVICE . '. . , . Fuel Water, Drilling UNITS gals bbls ',UNITS gals gals USAGE > I. , ON 'HAND . '. . - 1,932 14,310 4,680 " hESERVOIR NAME 3S-07 1 R-18 G & I Prudhoe Bay 38-14 3S-14 38-14 :'RESERVOIR' ANDINTERVAL'DAT A , , , ZONE TOP, 'BASE, ' ' , 795 1.5 950 0 0 0 0 COMMENTS Printed: 1/31/2003 3:04:33 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Well Name; 38-14 Rig: Nabors 7ES Date: 12/27/2002 I Volume Input Volume/Stroke Drilling Supervisor: Mike Thorton/ Granville Rizek Pump used: I #1 Mud Pump I... Strokes'" 0.0698 Bbls/Strk ... Type of Test: I Annulus Leak Off Test for Disposal Adequacy ... Pumping down annulus. ... Casinf Test Pressure Integrity Test Hole Size: IS-1/2'; I. Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 27.0 Ft 2,808 Ft-MD 2,555 Ft-TVD 5,510 Ft-MD 4,941 Ft-TVD Strks psi Min psi Strks psi Min psi Casin~ Size and Description: 19-5/S" 40#/Ft L-SO BTC I. 0 50 0 860 0 50 0 500 Chan~es for Annular Adequacv Test Pressure InteQritvTest 2 90 1 810 2 90 0.25 400 Enter outer casing shoe test results in comments Mud Weight: 11.7 ppg 4 100 2 800 4 200 0.5 375 Casing Description references outer casing string. Inner casing OD: 7.0 In. 6 125 3 800 6 310 1 350 Hole Size is that drilled below outer casing. 8 200 4 780 8 350 1.5 325 Use estimated TOC for Hole Depth. 10 250 5 760 10 450 2 310.~ Enter inner casing 00 at right. Desired PIT EMW: 18.0 ppg 11 300 6 750 12 490 2.5 300 Estimates for Test: 837 psi 0.4 bbls 12 310 7 730 14 500 3 300 1.1 13 350 8 725 16 500 3.5 300 14 375 9 710 18 500 4 300 15 400 10 710 20 500 4.5 300 16 410 151 r 22 500 5 300 17 425 20 24 500 5.5 300 18 450 25 26 500 6 290 19 490 30 28 500 6.5 290 20 510 30 500 7 290 21 530 32 500 7.5 290 22 575 34 500 8 285 23 590 36 500 8.5 280 24 600 38 500 9 275 25 630 40 500 9.5 275 26 690 42 500 10 275 27 710 44 500 28 725 46 500 29 730 48 500 r 30 780 50 500 31 800 52 500 32 810 54 500 33 850 56 500 34 860 57 500 Volume Volume Volume Pumped Bled Back Pumped 2.4 Bbls - Bbls 4.0 Bbls 95/8" @ 2808' TVD of 2555 was 16.3 EMW - TOC in 8-1/2" x 7" annulas calculated at 5510' MD 4941' TVD Casing test Data indicates first attempt at 7" x 9-5/8" injection test and turned into a FIT, Rocked 850 psi (18.0 EMW) several times and pressure broke down at 490 psi for EMW of 15.4 PP9 Note; Mud in 7" x 9-5/811 annulas contained 10-20 ppb LCM l. EMW = Leak-off Pressure + Mud Weight = 490 + 11 7 0.052 x TVD 0.052 x 2555 . EMW at 2808 Ft-MD (2555 Ft-TVD) = 15.4 PIT 15 Second Shut-in Pressure, psi 400 1000 ' - Lost 860 psi during test, held 0% of test pressure. ,J/& ", LLI c:: ::J V) V) UJ c:: c.. 500 . ,. 0 0 2 Barrels 4 0 10 15 20 25 Shut-In time, Minutes 0 PIT Point ---CASING TEST -8-LEAK-OFF TEST ~omments: Pump Rate: 8.0 Strk/min .. ~' 30 Volume Bled Back 0.5 I::Sbls Scblumbepgep NO. 2655 Schlumberger Technology Corporation, by and through is Geoquest Division . 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 02/12/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# Field: Date BL Sepia 01/26/03 1 01/30/03 1 02/04/03 1 01/28/03 1 02/02/03 1 02/01/03 1 01/24/03 1 01/31/03 Log Description 1 B-11 2B-10 2G-17 3N-18 35-07 35-14 35-26 35-14 ~ d. O~-aID J5l',J~to LDL J~-O~q STATIC BHP SURVEY ¿;Iod -a4 ~'": PERF RECORD & SBHP J)l/".. cA.:l, STATIC BHP SURVEY ~- J 'XI PRODUCTION PROFILE ~f'h "dl 0 CROSSFLOW DETERMINATION LOG aOJ-040 PRODUCTION PROFILE j?¡{')~S" SCMT Sl~ U OOQ(MJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color ~" 1 ~ RECEIVED FEB 1 4 2003 Ai88ka on & Gas Cons. Commiaeion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well œ'J Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface~.~"..:~,.,,:.,,:,,'-",,:,:,,~ 1966' SNL 1080' WEL SEC. 09 T10N R14E UM .~ G:):,f¡~U::"!"W¡\j \ X=675411, Y= 5938378 At top of productive interval ' , , i. LÞ':,:::: ~ 1605' SNL, 1049' EWL, SEC. 15, T10N, R14E, UM J..l!:;:~:~tL2.:! x = 677664. Y = 5933512 10. Well Number At total depth @ VEì»éiSfJ ~ 14-08AL 1 4338' SNL, 584' EWL, SEC. 15, T10N, R14E, UM t:~.:.2~~:-:-"~' ~ X=677269, Y= 5930768 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 70.5' ADL 028314 '12. Date Spudded" 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/26/2002 ' 11/30/2002 I 12/1/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14180 8979 FT 14180 8979 FT œ'J Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 94# H-40 Surface 73' 30" 250 sx Arcticset II 13-3/8" 72# L-80 Surface 2708' 17-1/2" 4965 sx Arcticset 9-5/8" 47# L-80 I SOO-95 Surface 11051' 12-1/4" 915 sx Class 'G' T' 26# L-80 10842' 12200' 8-1/2" 285 sx Class 'G' 4-1/2" 12.6# L-80 12033' 13202' 6" 420 sx Class 'GI 2-7/8" 6.16# L-80 12149' 14180' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) 2-7/8" Slotted Section 4-1/2", 12.6#, L-80 12034' MD TVD MD TVD 13325' - 14148' 8972' - 8979' Classification of Service Well 7. Permit Number 202-210 8. API Number 50- 029-20330-60 9. Unit or Lease Name Prudhoe Bay Unit 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2209' MD 1900' (Approx.) 77 wI:~~ 1:3 1/'13 'PI» fJ'170 '-rv.õ AMOUNT PULLED PACKER SET (MD) 10865' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production December 7, 2002 Date of Test Hours Tested 1/16/2003 6 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BsL TEST PERIOD 939 Flow Tubing Casing Pressure CALCULATED Press. 234 24-HoUR RATE 28. CORE DATA D ~ \/ E Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~t (Ej i~,,", OIL -BSL GAs-McF 4,476 GAs-McF WATER-BsL 2,819 WATER-BsL CHOKE SIZE 75° OIL GRAVITY-API (CORR) GAS-OIL RATIO 4,768 No core samples were taken. ("'"I, t... Alaska Oil & Gas Cons. Commissíon Am~horage &, F Form 10-407 Rev. 07-01-8~BOM5 Drl JAN Î- 8 20m Submit In Duplicate ) ') ............-....,~ ~.....,..,.......,.". , Jti.....-~-, ~-..-J/o¿¡-[~ I Marker Name Geologic Markers Measured Depth 30. l Formation Tests 29. " ~~ True Vertical , 'uE!p~- I Incfude interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. .............~....~, No new marker pies. i & 31. List of Attachments: Summary of Pre-Rig Work ànd DailyÖrHling Reports, Surveys 32. I hereby certify that the ~ng ,is truer. I1ll r1. d correct to the best of my knowledge SIgned Terrie Hubble ~ 1\JlLL ~Uc( Tit!e""Technical Assista~t Date 0 t . ~~"O3 14-08AL1 202-210 Prepared By NamelNumber: Terrie Hubble, 564-4628 Well Number Pe~mJ! ~No, I Approyal N? Drilling Engineer: Dan Kara, 564-5667 INSTRUCTIONS GENERAl: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. IrEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals tor only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. IrEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). 'TEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. liEM 27: MethOd of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-'explain. IrEM 28: If no cores taken, indicate 'none'. Form 10.407 Rev. 07-01.80 ) ) Well: Field: API: Permit: 14-08AL 1 Prudhoe Bay Unit 50-029-20330-60 202-210 Rig Accept: 11/25/02 Rig Spud: 11/26/02 Rig Release: 12/01/02 Drilling Rig: Nordic #1 PRE-RIG WORK 11/18/02 PULLED BALL AND ROD. PULL STA 1, DCK SHEAR VLV. SET 1 1/2" DGLV STA 1 AT 3079'. ATTEMPT TO PT IA WI TRIPLEX. 2 BBLS AWAY. NO PRESSURE INCREASE. HB&R MITIA. PASSED @ 3000 PSI. BLEED BACK IA TO 1000 PSI. PULL RHC PLUG @ 10,883' SLM. RDMO. WELL LEFT SHUT IN. . MIT-IA @ 3000 PSI. W/21 BBLS NEAT METH/CRUDE. PASSED! 11/21/02 RIH WI 3" DJN. CLEAN OUT TO 12915 USING XS KCL AND FLO-PRO. 11/22/02 CONTINUE CLEAN OUT TO 13300. LAY FLO-PRO ACROSS PERFS FROM 13300 UP TO 12100. POH JETTING AT 80%. JET ALL JEWELRY AS POH. PU 3.68 WHIPSTOCK DRIFT ASSEMBLY AND RIH. DRIFT TO 13,300 NO PROBLEMS. POOH. PU PDS MEM GR I CCL AND RIH. LOG TIE IN PASS FROM 13300-12100 CTMD. FLAG PIPE AND POH. VERIFY DATA. GOOD DATA. 11/24/02 MU AND RIH WITH TIW KS-WS PACKER. SET PACKER AT 13210'. POOH. PACKER LOCATOR SLOT ORIENTED 145 DEG LEFT OF HIGH SIDE. PU TIW KSWS ORIENTATION LATCH ASSEMBLY AND WEATHERFORD WHIPSTOCK AND RIH. LATCH UP AND SET WHIPSTOCK WITH TOP AT 13193. (NOTE: RA TAG AT 13203.) POH. RDMO. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-08 14-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/25/2002 Rig Release: 12/1/2002 Rig Number: N1 Spud Date: 7/25/1998 End: 12/1/2002 Date Frönl~Tö Hours 11/25/2002 00:00 - 06:30 6.50 MOB N WAIT PRE Waiting on cleanup of fluids from tanks and rig up from service coil job, and pad prep. 06:30 - 07:00 0.50 MOB P PRE Safety meeting prior to moving rig. 07:00 - 08:30 1.50 MOB P PRE MIRU Nordic 1 on DS 14-08AL 1. Accept Rig at 08:30, 11-25-2002. 08:30 - 10:00 1.50 RIGU P PRE Rig up on well. 10:00 - 16:30 6.50 BOPSUB P DECOMP Pressure test BOP stack. Test witnessing waived by AOGCC, Jeff Jones. Sent test report to AOGCC. 16:30 - 17:00 0.50 STWHIP P WEXIT Make up Baker CTC. Pull test to 40 klbs ok. Fill coil. 17:00 - 17:20 0.33 STWHIP P WEXIT Pre spud safety meeting re-hazards associated with this well and drillsite. 17:20 - 18:00 0.67 STWHIP P WEXIT Continue to fill coil. PT CTC to 3500 psi, PT inner reel valve. 18:00 - 18:20 0.33 STWHIP P WEXIT Crewchange and Pre spud safety meeting with the night crew. 18:20 - 19:20 1.00 STWHIP P WEXIT Make up milling BHA. BHA #1 =Hughes D0261 window mill - WF String mill - WF mud motor - DISC - @ Jts PH6 - CHKS - Baker CTC. BHA = 85.91 ft. 19:20-21:45 2.42 STWHIP P WEXIT RIH with BHA #1, 3.80" diamond window mill and 3.80" string reamer on straight motor. Up WT = 36K at 13100'. Dwn wt = 19K. 21:45 - 23:00 1.25 STWHIP P WEXIT Tag whipstock at 13,235'. correct depth to 13193' [-42' CTD]. Ease down with 3.80" mill at 2.5 bpm 11900 psi. Flag CT at 13,193.0 ft. Start window milling at 13,193' at top of 4-1/*2" whipstock. 2.6/ 2.5 bpm, 2080 - 2300 psi. 1-2K WOB. Milled to 13194.5'. No Stalls. 23:00 - 00:00 1.00 STWHIP P WEXIT Milling 3.80" window. 2.6/2.4 bpm, 2080 - 2250 psi, 1-2K WOB. 6 BPH mud loss. Milled to 13,195.5'. 11/26/2002 00:00 - 01 :45 1.75 STWHIP P WEXIT Milling 3.80" horizontal window. 2.6 I 2.4 bpm, 2250 - 2550 psi, milled to 13197.4'. Pick up and check free spin and down wt. Up Wt = 32K, Dwn wt = 13K, Free spin = 2030 psi. 01:45 - 03:00 1.25 STWHIP P WEXIT Milling, 2.6/2.5 bpm, 2030 - 2400 psi, Losing 7 BPH to open perfs above whipstock. Milled to 13,198'. 03:00 - 03: 15 0.25 STWHIP P WEXIT H2S Drill. DS 14 is an H2S area. Checked all workers had H2S meter. H2s alarms checked during BOP test. Review procedure for H2S rig evacuation. 03:15 - 03:30 0.25 STWHIP P WEXIT Milling, 2.6/2.5 bpm, 2080 - 2500 psi, Milled to 13199'. Pick up, free spin = 2080 psi, Up wt 33K, Dwn wt. = 16K, Ream window. Clean down to 13,199'. 03:30 - 04:00 0.50 STWHIP P WEXIT Milling, 2.6 I 2.5 bpm, 2080 - 2500 psi, 7 BPH mud loss, Milled to 13,200'. Exit liner at 13,200 ft. No Stalls for entire window. Top of window at 13,193'. Bottom of window at 13,200'. 04:00 - 04:20 0.33 STWHIP P WEXIT Mill formation, 2.6/2.5 bpm, 2080 - 2400 psi, 25 FPH, Milled to 13,210 ft. 04:20 - 05:30 1.17 STWHIP P WEXIT Back ream window at 20 FPH from 13,203-13,989'. 2.6/2.5 bpm, 2150 - 2200 psi. 7 BPH fluid loss with 2 PPB Biozan. Ream down at 20 FPH to 13,210'. 05:30 - 06:00 0.50 STWHIP P WEXIT Swap well to re-conditioned FloPro while reaming window. 2.6 12.5 bpm, 2200 psi. Reamed window up / down 3 times. Clean window. RIH thru window clean with no pump. Dry tag Printed: 12/6/2002 1:59:44 PM ~) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 14-08 14-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/25/2002 Rig Release: 12/1/2002 Rig Number: N1 Spud Date: 7/25/1998 End: 12/1/2002 FrOm-TO RoLïts Task' Code NPT 11/26/2002 05:30 - 06:00 06:00 - 08:25 08:25 - 08:40 08:40 - 10:20 10:20 - 12:40 12:40 - 13:35 13:35 - 14:10 14:10 - 14:20 14:20 - 14:50 14:50 - 16:20 16:20 - 16:55 16:55 - 17:40 17:40 - 18:15 18:15 - 18:30 18:30 - 20:00 20:00 - 20:40 20:40 - 23:30 23:30 - 00:00 11/27/2002 00:00 - 01 :45 01 :45 - 02:20 02:20 - 04:40 04:40 - 04:55 0.50 STWHIP P 2.42 STWHIP P WEXIT WEXIT 0.25 STWHIP P WEXIT 1.67 STWHIP P WEXIT 2.33 DRILL P PROD1 0.92 DRILL P PROD1 0.58 DRILL P 0.17 DRILL P PROD1 PROD1 0.50 DRILL N FLUD PROD1 1.50 DRILL N 0.58 DRILL N 0.75 DRILL N FLUD PROD1 FLUD PROD1 FLUD PROD1 0.58 DRILL N FLUD PROD1 0.25 DRILL N 1.50 DRILL P PROD1 PROD1 0.67 DRILL P 2.83 DRILL P PROD1 PROD1 0.50 DRILL P PROD1 1.75 DRILL P 0.58 DRILL P PROD1 PROD1 2.33 DRILL P 0.25 DRILL P PROD1 PROD1 TD at 13,210 ft. Back ream thru window. POH while circ. FloPro. Flag CT at 13,000' EOP. POH continue taking dirty returns to vac trucks, displacing flopro in hole. Tag up at surface, no flow test ok. Safety meeting re-Rigging down milling BHA, rigging up drilling BHA #1, (BHA #2). Lay down BHA #1, both mills recovered in gauge at 3.80", with a classic swirl pattern on the face indicating a good window exit. Rig up BHA #2; Smith M09 bit, BHI mud motor at 2 deg, Sperry Gr/Directional, MHA, Baker CTC. RIH with BHA #2. Shallow hole test at 450 and 3500', passed ok. Circ pressure high during shallow hole test. (4000 psi at 2.2 bpm) Check mud. LSRV turns out to be 120 klsrv. OOPS! MI reports problem in mixing at plant. Call for 3% KCL to dilute mud back. RIH pumping minimum rate. No mud losses while RIH. Stop at 10940', start down logging tie in MAD pass over gamma charecter at TSAD in original DS14-08 wellbore. Tie in to 1979 BHC sonic log for DS14-08. Pumping at 2.2 bpm and 4400 psi. Getting back 0.9 bpm. Loosing mud. Make -34' correction. Drop rate to minimum, returns 100%, RIH. Run thru window slick with pumps down. Dry tag bottom at 13218'. Kick on pumps to 2.3 bpm, free spin pressue=2230 psi, returns are 0.5 bpm. Can't drill like this. Tag for depth control at 13218' again. PUH at 60 fpm, laying in mud at 1.1bpm in, with 0.4 bpm returns out. Plan to PUH to 6500', circulate the top half of the well to standard LSRV fluid, then get the bottom half. PUH to 6500'md & circ out hi-vis mud with diluted system. RIH to 9500'. Circ out hi-vis mud with diluted sytem @ 2.1/2.0bpm & 3150psi. RIH to circ out hi-vis mud. Tagged TD @ 13214' - correct to 13218'. Orient to left Drilling from 13218' 2.5/2.2/3300/11 OL. See RA at 13211.0' which is "on depth" to 1979 BHCS according to Harry. Therefore, revised TOWrrOWS is 13202' and BOW is 13209'. Drill to 13280' Orient and can't get clicks. Go to window and get them Drilling from 13280' 2.5/2.3/3340/70L. Slow penetration and stacking. Have to go to window to get clicks. Drill to 13348' and penetration rate too slow POOH for bit. Flag at 13100' EOP. Backream to EOT at 12034' POOH for bit Change bit and orientor. Bit was 0-3-1 (poor/unnecessary redesign). Hole taking 6 bph static RIH wI BHA #3 (2.0 deg motor, DS49 bit) See flag at 13207', corr to 13165' (-42'). RIH clean thru window at 36L. Precautionary ream to TD while work on charge pump 2.6/2.3/3600/139R. Tag TD at 13340'. Corr to 13348' (+8') Printed: 12/6/2002 1:59:44 PM ) ) Legal Well Name: 14-08 Common Well Name: 14-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From,.. To Hours Task Code NPT 11/27/2002 04:55 - 05:45 0.83 DRILL P PROD1 05:45 - 07:00 1.25 DRILL P PROD1 07:00 - 07:30 0.50 DRILL P PROD1 07:30 - 08:40 1.17 DRILL P PROD1 08:40 - 09:30 0.83 DRILL P PROD1 09:30 - 11 :30 2.00 DRILL P PROD1 11 :30 - 11:45 0.25 DRILL P PROD1 11 :45 - 13:40 1.92 DRILL P PROD1 13:40 - 16:10 2.50 DRILL P PROD1 Start: 11/25/2002 Rig Release: 12/1/2002 Rig Number: N1 Spud Date: 7/25/1998 End: 12/1/2002 16:10 - 16:20 16:20 - 17:20 0.17 DRILL N 1.00 DRILL N DFAL PROD1 DFAL PROD1 17:20 - 18:25 1.08 DRILL P PROD1 18:25 - 19:15 0.83 DRILL N DFAL PROD1 19:15 - 19:25 0.17 DRILL P PROD1 19:25 - 20:10 0.75 DRILL P PROD1 20:10 - 21 :30 1.33 DRILL P PROD1 21 :30 - 21 :45 0.25 DRILL P PROD1 21:45 - 22:50 1.08 DRILL P PROD1 22:50 - 23:20 0.50 DRILL P PROD1 23:20 - 00:00 0.67 DRILL P PROD1 11/28/2002 00:00 - 00:25 0.42 DRILL P PROD1 00:25 - 01 :00 0.58 DRILL P PROD1 01 :00 - 02:50 1.83 DRILL P PROD1 02:50 - 03:50 1.00 DRILL P PROD1 03:50 - 04:35 0.75 STKOH P PROD1 04:35 - 07:15 2.67 STKOH P PROD1 07:15 - 08:00 0.75 STKOH P PROD1 08:00 - 08:30 0.50 STKOH P PROD1 Orient to left. Go to window to get clicks Drill to 13415' @ 60'/hr wI 10k positive string wt 2.4/2.2/3450/75-90L. Continue driling to 13448' with 90L TF, 2.6/2.4bpm, 3300/4100psi, 4k WOB & 64fph ave ROP. Add 100 bbls fresh mud to make up for losses. Orient TF to HS. Had to PUH & orient several times to get clicks. Continue driling to 13482' with 20L TF, 2.8/2.6bpm, 3300/3800psi, 45fph ave ROP. Estimate ca 100degs @ the bit. POOH to P/U lateral BHA. Held PJSM for BHA changeout. OOH. Checked motor - OK. Checked bit - 0-2-1. Adjust motor bend to 1.04 degs. C/O MWD, P/U resistivity tools & initialize same. M/U coil. Had ca 0.1 bpm static losses. RIH with BHA #4 with same DS49 bit to 3600'. SHT - OK. Continue RIH. -40' correction @ flag. RIH thru window & tag btm @ 13479'. Attempt to MAD pass turn section - MWD not pulsing. PUH into casing to see if we'll get MWD pulses. Switch tool data rate & observe good pulses in csg. RBIH in OH & tool still pulsed good till 13470'. PUH & tool start pulsing intermittently from 13420'. Pull into csg. Switch pumps & MWD pulses bounce back. RBIH & troubleshoot and get MWD to finally respond. Log up & MAD pass turn section with 2.6/2.4bpm, 3650psi & 160fph. Not getting res signal in (Sperry claims) high DLS area (a whopping 24 DLS). Continue MAD pass of recorded data. Then, MWD signal quit before tie-in. RIH and relog tie-in Add 6.5'. RIH and tag TD at 13485' Orient from 167R. No clicks at TD. PUH to window Drill from 13485' at 98-100 deg 2.4/2.2/3480/1 OOL continuing invert to find TSAD. Add 100 bbls fresh mud to make up for losses. Drill to 13582' and stacking 1 00' wiper Drill from 13582-631' and slowly losing push 2.6/2.4/3580/80L Wiper to window Drill from 13631' and seeing pyrite in samples, getting close to objective. Drilling wI avg neg 5k to 13650' Continue drilling from 13650' 2.4/2.2/3450/80L with avg -7k wt. Drill to 13665' and see TSAD at 13610' (8875' TVD). Confirm wI samples. PVT 218 Wiper to window. Flag at 13100' EOP. Backream 7" to EOT POOH for sidetrack BHA LD drilling BHA. Download res data MU sidetrack drilling assy RIH wI BHA #5 (1.69 deg motor, HC R60ST bit). Set down at 10810' (GLM #1). Continue RIH. -40.6' correction @ flag. RIH thru window to 13300'. Log up & tie-into the RA Pip tag & added 5' to CTD. Work hole 2x, circ @ min rate from 13480' & 13410' to remove any CT stretch. Target sidetrack pt = +1-13470' with original Printed: 12/6/2002 1:59:44 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-08 14-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From ..~ To Hburs Task Code NPT Phase 11/28/2002 08:00 - 08:30 08:30 - 08:50 08:50 - 09:50 0.50 STKOH P 0.33 STKOH P 1.00 STKOH P PROD1 PROD1 PROD1 09:50 - 12:30 2.67 STKOH P PROD1 12:30 - 13:00 0.50 STKOH P PROD1 13:00 - 13:30 0.50 STKOH P PROD1 13:30 - 14:00 0.50 STKOH P PROD1 14:00 - 16:00 2.00 STKOH P PROD1 16:00 - 17:30 1.50 STKOH P PROD1 17:30 - 20:00 2.50 STKOH P PROD1 20:00 - 20:45 0.75 STKOH P PROD1 20:45 - 20:55 0.17 STKOH P PROD1 20:55 - 21 :20 0.42 STKOH P PROD1 21 :20 - 21 :45 0.42 STKOH P PROD1 21 :45 - 22:50 1.08 STKOH N DFAL PROD1 22:50 - 23:40 0.83 STKOH N PROD1 23:40 - 00:00 0.33 STKOH N PROD1 11/29/2002 00:00 - 00: 1 0 0.17 STKOH N DFAL PROD1 00:10 - 00:45 0.58 STKOH N DFAL PROD1 00:45 - 01 :05 0.33 STKOH P PROD1 01 :05 - 02:00 0.92 STKOH P PROD1 02:00 - 02:25 0.42 DRILL P PROD1 02:25 - 02:55 0.50 DRILL P PROD1 02:55 - 03:25 0.50 DRILL P PROD1 03:25 - 03:55 0.50 DRILL P PROD1 03:55 - 04:15 0.33 DRILL P PROD1 04:15 - 04:30 0.25 DRILL P PROD1 04:30 - 04:40 0.17 DRILL P PROD1 04:40 - 04:55 0.25 DRILL P PROD1 04:55 - 05: 15 0.33 DRILL P PROD1 05:15 - 05:30 0.25 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 Start: 11/25/2002 Rig Release: 12/1/2002 Rig Number: N1 Spud Date: 7/25/1998 End: 12/1/2002 Descriptibhbf Oþeration$ Hole TF of HS. Orient TF to 100L. Scribe/troug h from 13440' to 13460' @ 105-11 OL TF, 2.5/2.3bpm, 3600psi, & 60fph ROP. Seeing motor work @ 13460'. Backream trough several times to 13440' with TF holding OK. Added 150bbls of new Flopro mud to system. Set brake for 10mins @ 13460' & time drill from 13460' to 13465' @ 0.1 '/3min, 1 05L TF, 2.51 2.3bpm & 3600/3700psi. Seeing reactive TF & slight motor work - looks like we've sidetracked. Time drill from 13465' to 13467' @ 0.1'/1min, 105LTF, 2.51 2.3bpm & 3600/3700psi. Wt stacking. P/U & confirm freespin @ 3700psi. Drill to 13477' @ 105-11 OL TF, 2.5/2.3bpm & 3700/3900psi & 18fph ave ROP. Getting reactive TF to 115L. Backream from 13477' to 13410' @ 105LTF. RBIH clean thru SIT pt & tag up @ 13477'. Backream again to 13410' & call it good. POOH sidetrack BHA#5. Paint EOP flag @ 12970'. OOH. UO sidetrack bit - 0-2-1. C/O motor & adjusted bend to 1.37degs. M/U MWD & used DS49 bit. P/U resistivity tools & initialize same. M/U coil. RIH with BHA #6 to 3000'. SHT - OK. Continue RIH. Corr -34' at 13134'. RIH thru window, clean to 13275' Log up from 13285' 2.4/2.2/3070/12R. Corr -32' Precautionary ream to 13440' Note: ' WIPER' not available in picklist for Activity Ream 1.0'/min 2.4/2.2/3044/114L from 13440' to TD tagged at 13475.8'. The drilling Gods were favorable on TF Orient one click. Had to go to window to get it RBIH and Sperry MWD quit again. Work to get restarted POOH for MWD Check tool at 10100' and worked. Sperry recommends drilling. RBIH Set down at 13202' (WS). PUH and check TF (129R) and tool worked Orient around Slow ream 13440' 2.5/2.2/3320/1 OOL to motor work at 13473' Slow drill to 13497' 2.5/2.2/3300/90L Slow wiper to 13430', 3 clicks Drilling 2.5/2.2/3320/44L 80-1 OO'/hr at 90 deg. Drill to 13542' Orient around Drilling from 13542' 2.5/2. 1 13300/84L at 93 deg. Losses have increased due to orienting. Drill to 13600' Orient to right Drilling from 13600' 2.5/2.1/3350/103R Drill to 13631' Wiper to window. MWD stopped working 200' oft bottom. Cycle before tie-in and revived it Log tie-in up from 13265' 2.4/2.2/3240/82L Add 5'. Orient to 1 OR. RI H to TD tagged at 13636' at 161 L TF Orient to right Drilling from 13636' 2.5/2.1/3250/41 R. Est target intercept at 13670', Drill to 13681' and a few stalls-must be pyrite Printed: 12/6/2002 1:59:44 PM ') ) Legal Well Name: 14-08 Common Well Name: 14-08 Spud Date: 7/25/1998 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 12/1/2002 Contractor Name: NORDIC CALISTA Rig Release: 12/1/2002 Rig Name: NORDIC 1 Rig Number: N1 Däte From-To Hours Task Code NPT Phase Descri ption. ofOþeratiops 11/29/2002 06:00 - 07:00 1.00 DRILL P PROD1 Drilling from 13681' 2.5/2.1/3300/90R-120R. Drill to 13726'. 07:00 - 07:10 0.17 DRILL P PROD1 Orient TF to 160R. Geo wants to knock down angle to 88-89degs to get back into good sand. 07:10 - 07:30 0.33 DRILL P PROD1 Drill to 13754' with 140R TF, 2.5/2.1bpm, 3300/3700psi & 90fph ave ROP. 07:30 - 08:00 0.50 DRILL P PROD1 Wiper clean to window & RBIH. Reduce rate to 0.6bpm thru 13310' -13350' (36deg DLS) to keep MWD pulsing. 08:00 - 08:30 0.50 DRILL P PROD1 Orient TF to 90R. 08:30 - 09: 15 0.75 DRILL P PROD1 Drill to 13781' with 60-80R TF, 2.5/2.1bpm, 3300/3550psi & 35fph ave ROP. Start pumping down 150bbls of new flopro mud. 09:15 -10:15 1.00 DRILL P PROD1 Orient & drill to 13817' with 70-90R TF, 2.5/2.1 bpm, 3300/3600psi & 35fph ave ROP. Geo wants 86degs to get out of pyrite & drop into sand zone. 10:15-10:20 0.08 DRILL P PROD1 Orient TF to 155R. 10:20 - 10:40 0.33 DRILL P PROD1 Drill to 13847' with 135R TF, 2.5/2.1bpm, 3350/3700psi & 90fph ave ROP. 10:40 - 11 :00 0.33 DRILL P PROD1 Orient TF to 11 OR. 11 :00 -.11: 1 0 0.17 DRILL P PROD1 Drill to 13851' with 100R TF, 2.5/2.1 bpm, 3350/3700psi & 90fph ave ROP. 11:10-12:00 0.83 DRILL N DFAL PROD1 Attempt to orient TF to 90R. MWD tool stop pulsing. Troubleshoot - increase flow, check transducers - no luck. Decide to PUH to see if MWD will be revived. 12:00 - 12:20 0.33 DRILL N DFAL PROD1 PUH to 13100' & MWD still not pulsing. 12:20 - 15:10 2.83 DRILL N DFAL PROD1 POOH for MWD. Paint EOP flag @ 13000'. POOH to 9000' & service injector. Continue POOH & observe MWD tool pulsing again. 15:10 - 16:05 0.92 DRILL N DFAL PROD1 OOH. Download resistivity tool. Reduced Visibility: Phase 1 on Spine road & Phase 2 on all access roads & pads. 16:05 - 17:00 0.92 DRILL N DFAL PROD1 C/O MWD probe, flow tube & orienter. LIO bit - 2-4-1. M/U new DS49 bit. Check 1.37degs bent motor - OK. M/U resistivity tools. Meanwhile take-on additional 150bbls of new flopro mud. 17:00 - 18:30 1.50 DRILL N DFAL PROD1 Attempt to initialize resistivity tools - getting error. Try again & communicate OK. M/U coil. 18:30 - 20:40 2.17 DRILL N DFAL PROD1 RIH with BHA #7. SHT, orientor too 20:40 - 21 :20 0.67 DRILL N DFAL PROD1 Corr at 13127' to 13090' (-37'). RIH to window and park, circ 0.4/0.2/1500 Work on wt celllgooseneck adjustment 21 :20 - 21:40 0.33 DRILL N DFAL PROD1 RIH thru window, clean to 13275'. Log up from 13265' 2.5/2.1/3400/89L. Add 3.0'. Orient to high right 21 :40 - 21 :55 0.25 DRILL N DFAL PROD1 RIH to TD. Tag at 13853' and the TF Gods are favorable again 21 :55 - 22:35 0.67 DRILL P PROD1 Drilling 2.5/2.2/3420/65-74R to 13920' 22:35 - 23:45 1.17 DRILL P PROD1 Orient to left, twice. Drill 7' and see high ohm shift on res. Orient around to straight down 23:45 - 00:00 0.25 DRILL P PROD1 Drilling 2.6/2.2/3540/175L. Drill to 13942' 11/30/2002 00:00 - 00:45 0.75 DRILL P PROD1 Continue drilling from 13942-47' 175L. Orient to 90L. Drill to 13978' while adding 125 bbls new mud to make up for losses 00:45 - 01 :20 0.58 DRILL P PROD1 Wiper to window Log up from 13835' and 13795' to verify res tool repeatablilty 01 :20 - 01 :40 0.33 DRILL P PROD1 Finish wiper to window 01 :40 - 02:00 0.33 DRILL P PROD1 Orient from 90L to high side. RIH to TD, clean 02:00 - 02:30 0.50 DRILL P PROD1 Orient around Printed: 12/6/2002 1:59:44 PM -) ) Legal Well Name: 14-08 Common Well Name: 14-08 Spud Date: 7/25/1998 Event Name: REENTER+COMPLETE Start: 11/25/2002 End: 12/1/2002 Contractor Name: NORDIC CALISTA Rig Release: 12/1/2002 Rig Name: NORDIC 1 Rig Number: N1 Date From'-To Hours Task ,Code NPT Description of Oper~tions 11/30/2002 02:30 - 05:25 2.92 DRILL P PROD1 Drill from 13978' 2.4/2.1/3440/71 L Drill to 14135' (8909' TVD) Geo's advise there's enough pay zone, but want to find out where we are so will point up and look for Shublik 05:25 - 05:45 0,33 DRILL P PROD1 Wiper to window 05:45 - 06:15 0.50 DRILL P PROD1 Log tie-in up from 13265', add 3' 06: 15 - 06:40 0.42 DRILL P PROD1 RIH to sidetrack point and orient around to 11 OL. 06:40 - 07:00 0.33 DRILL P PROD1 Continue RIH to btm. 07:00 - 07: 15 0.25 DRILL P PROD1 Orient TF to 10R. PVT = 222bbls. 07:15 - 08:30 1.25 DRILL P PROD1 Drill to 141790' with 18R TF, 2.6/2.2bpm, 3600/3970psi & 45fph ave ROP. 08:30 - 08:50 0.33 DRILL P PROD1 Backream 100'. 08:50 - 08:55 0.08 DRILL P PROD1 Orient TF to 85R. PVT = 185bbls. 08:55 - 10:05 1.17 DRILL P PROD1 Attempt to drill past 14181' - not getting any motor work. Seeing motor stator rubber pieces in cuttings. 10:05 - 10:15 0.17 DRILL P PROD1 Wiper trip clean to window. Meanwhile consult with town team & call it TD as we've already drilled >500' of good sand. 10:15 - 10:40 0.42 DRILL P PROD1 Log-up & tie-into pip tag. Add l' to CTD. 10:40 - 11 :20 0.67 DRILL P PROD1 RBIH to SIT pt & orient TF to 11 OL. Continue RIH & tagged TD @ 14180'. 11 :20 - 14:30 3.17 DRILL P PROD1 POOH to run Liner. Log up memory resisitivity data from 14100' to 13650' for quality check. Flag CT EOP flag @ 11000'. Continue POOH chasing cuttings @ 2.6bpm. 14:30 - 15:30 1.00 DRILL P PROD1 OOH. Download resistivity tool. 15:30 - 16:30 1.00 DRILL P PROD1 LlO BHA#7. Bit grades - 1-2-1. 16:30 - 16:45 0.25 CASE P COMP R/U to run liner. 16:45 - 17:00 0.25 CASE P COMP PJSM on running liner completion. 17:00 - 19:50 2.83 CASE P COMP Fill hole with 9bbls of mud. M/U 1 solid liner shoe jt, O-ring sub, 26 pre-drilled liner jts, 1 x 10' pup jt & 39 solid 2-7/8" 6.16# L-80 STL liner jts. 19:50 - 20:20 0.50 CASE P COMP MU Baker Deployment sleeve and CTLRT. Check CTC 20:20 - 22: 1 0 1.83 CASE P COMP RIHw/liner on CT 22:10 - 22:25 0.25 CASE P COMP Corr to flag at 13040' -47.8' 43K, 20k. RIH clean thru window with nary a bobble to set down at 14169' CTD (still had 17k string wt while RIH at TD) Note: Top of solid liner at 12149' with slotted liner 13314-14148' 22:25 - 23:05 0.67 CASE P COMP Load 5/8" steel ball and circ to seat 2.5/2.2/2430. Seat sheared at 3050 psi. PUH 38k and confirm release from liner 23:05 - 23:30 0.42 CASE P COMP Begin displacement to 2% KCI water 2.8/2.5/2520 23:30 - 00:00 0.50 CASE P COMP POOH while fin displ to KCI 2.9 bpm 2550 psi 12/1/2002 00:00 - 01 :30 1.50 CASE P COMP Continue POOH jetting 2% KCI while finish displacement 01 :30 - 02:00 0.50 CASE P COMP FP wi MeOH from 2000' while POOH 02:00 - 02:15 0.25 CASE P COMP LD Baker CTLRT and load out. Secure tree 02:15 - 03:15 1.00 RIGD P COMP MU nozzle assy. PT DS N2 @ 2500 psi. Blow down CT wI N2. Bleed down 03:15 - 05:00 1.75 RIGD P COMP Cut off CTC. Unstab CT. Remove gooseneck. Set injector in box 05:00 - 06:00 1.00 RIGD P COMP ND BOPE. NU tree cap and test. Rig released at 0500 hrs 12/1/2002 06:00 - 0.00 RIGD P COMP Begin RD. Further comments shown on K-20 report Printed: 12/6/2002 1 :59:44 PM ) ) ó]oa~JÔ 30-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-08AL 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 13,423.20' MD Window / Kickoff Survey 13,443.40 I MD (if applicable) Projected Survey: 14,180.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager lT~c ~/Vt:.: . AI . v~4¡VO~ D 'ViJ.cL . ,r r. {>ltO 1"'1.:' . V "":!Îi~ '> '-'J¡ ~ 1"'\. . (.. .. \ /. 'j \:f¿'''' .>. . '" 47-: ," (;Q!;~~~ "'~';.-. ",fJOr;..-, ... ...."¡1~ . Q~'!;) . .:.1.11',.. v loP .<..~t()11 Attachment(s) 0 r:;: - ..'J 88!1211 V: 1J!1';'l'I ¡.. . ... Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-08AL1 ~ Job No. AKMW22187, Surveyed: 30 November, 2002 Survey Report 27 December, 2002 Your Ref: API 500292033060 Surface Coordinates: 5938377.79 N, 675410.53 E (70014' 14.2624" N, 148035' 00.9165" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 938377.79 N, 175410.53 E (Grid) Surface Coordinates relative to Structure Reference: 1227.345, 1231.00 E (True) Kelly Bushing: 70.50ft above Mean Sea Level Elevation relative to Project V Reference: 70.50ft Elevation relative to Structure Reference: 70.50ft spe""y-sul"1 DRIL..LiNG se~vlc:es A Halliburton Company Survey Ref: svy11409 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 -14-08AL1 Your Ref: API 500292033060 Job No. AKMW22187, Surveyed: 30 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 13423.20 92.420 158.740 8899.90 8970.40 7008.72 S 1340.13 E 5931402.14 N 676913.34 E 7094.29 Tie On Point -13443.40 92.330 153.630 8899.06 8969.56- 7027.18 S 1348.28 E 5931383.87 N 676921.92 E 25.279 7114.33 Window Point 13464.35 91.190 147.820 8898.42 8968.92 7045.44 S 1358.51 E 5931365.86 N 676932.57 E 28.248 7134.78 13490.25 89.070 142.710 8898.36 8968.86 7066.72 S 1373.26 E 5931344.93 N 676947.82 E 21.359 7159.44 13542.85 95.070 134.600 8896.46 8966.96 7106.13 S 1407.94 E 5931306.33 N 676983.40 E 19.165 7207.27 13573.45 93.220 127.910 8894.25 8964.75 7126.24 S 1430.87 E 5931286.76 N 677006.79 E 22.627 7233.21 .~-/ 13600.70 90.840 124.560 8893.28 8963.78 7142.34 S 1452.83 E 5931271.18 N 677029.12 E 15.073 7255.02 13633.60 88.370 131 .250 8893.51 8964.01 7162.54 S 1478.77 E 5931251.59 N 677055.53 E 21.674 7281.92 13662.85 91.980 134.600 8893.42 8963.92 7182.45 S 1500.18 E 5931232.18 N 677077.40 E 16.836 7307.22 13703.95 93.130 144.650 8891.58 8962.08 7213.69 S 1526.75 E 5931201.57 N 677104.68 E 24.587 7344.86 13741.80 87.580 150.280 8891.35 8961.85 7245.57 S 1547.09 E 5931170.17 N 677125.76 E 20.882 7381.30 13779.43 88.020 149.930 8892.79 8963.29 7278.17 S 1565.83 E 5931138.01 N 677145.25 E 1 .494 7417.95 13805.18 89.600 159.800 8893.33 8963.83 7301.45 S 1576.75 E 5931115.00 N 677156.71 E 38.809 7443.41 13834.55 87.400 165.610 8894.10 8964.60 7329.47 S 1585.47 E 5931087.19 N 677166.08 E 21.145 7472.75 13862.43 86.870 168.430 8895.49 8965.99 7356.60 S 1591.73 E 5931060.21 N 677172.97 E 10.279 7500.53 13894.08 88.720 177.600 8896.71 8967.21 7387.96 S 1595.57 E 5931028.95 N 677177.54 E 29.535 7531.64 13941.78 86.430 182.710 8898.73 8969.23 7435.59 S 1595.44 E 5930981.32 N 677178.52 E 11.730 7577.16 13972.43 85.550 175.480 8900.88 8971.38 7466.14 S 1595.92 E 5930950.79 N 677179.71 E 23.705 7606.51 14005.78 86.870 167.550 8903.08 8973.58 7499.03 S 1600.83 E 5930918.03 N 677185.38 E 24.053 7639.39 14036.65 87.310 162.970 8904.65 8975.15 7528.84 S 1608.67 E 5930888.41 N 677193.91 E 14.886 7670.19 14068.25 89.340 155.390 8905.58 8976.08 7558.34 S 1619.89 E 5930859.18 N 677205.82 E 24.822 7701.68 14095.98 86.960 149.400 8906.47 8976.97 7582.89 S 1632.73 E 5930834.94 N 677219.22 E 23.232 7728.91 14125.55 86.260 145.170 8908.22 8978.72 7607.72 S 1648.68 E 5930810.49 N 677235.74 E 14.475 7757.32 14156.73 91.100 145.530 8908.94 8979.44 7633.35 S 1666.39 E 5930785.27 N 677254.05 E 15.566 7787.02 ~ 14180.00 91.100 145.530 8908.49 8978.99 7652.53 S 1679.56 E 5930766.40 N 677267.66 E 0.000 7809.21 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 163.000° (True). Magnetic Declination at Surface is 26.055°(25-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 14180.00ft., The Bottom Hole Displacement is 7834.68ft., in the Direction of 167.621° (True). 27 December, 2002 - 8:17 Page 2 of 3 Dril/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-08AL 1 Your Ref: API 500292033060 Job No. AKMW22187, Surveyed: 30 November, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~ Comment 13423.20 13443.40 14180.00 8970.40 8969.56 8978.99 7008.72 S 7027.18 S 7652.53 S 1340.13 E 1348.28 E 1679.56 E Tie On Point Window Point Projected Survey '-" Survey toolproQram for 14-0BAL 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10997.50 0.00 10997.50 8874.01 14180.00 8874.01 AK-1 BP _HG - BP High Accuracy Gyro(14-08) 8978.99 MWD Magnetic(14-08APB2) ~ 27 December, 2002 - 8:17 Page 3 of 3 DrillQuest 3.03.02.004 ) , ') dJ (9-- ~7 0 30-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-08AL 1 PB 1 Dear: Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 13,188.89' MD 13202' MD (if Applicalble) 13,665.00' MD Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager attachments Rl:CEIVt.::11 ~f!...-J JAN O~! r",",,, AI v",;,;.' r¡¡s,,¡.. . 4., V ...; ..' \O.1i8 /'\..' .fi r. \,;ï, r.!l Ui''''''' ~ ~~Jf~'8 ~";-,~. Ar'^h' . ""...¡(JNi". . .w," ora.{f~ ."..4:;-t10t} v'" () ¡:.'C r \J ~ V.: , y,.,.~ " ~ - Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-0BAL1PB1 ~ Job No. AKMW22187, Surveyed: 28 November, 2002 Survey Report 27 December, 2002 Your Ref: API 500292033072 Surface Coordinates: 5938377.79 N, 675410.53 E (70014' 14.2624" H, 148035' 00.9165" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 '-4" Surface Coordinates relative to Project H Reference: 938377.79 H, 175410.53 E (Grid) Surface Coordinates relative to Structure Reference: 1227.34 S, 1231.00 E (True) Kelly Bushing: 70.50ft above Mean Sea Level Elevation relative to Project V Reference: 70.50ft Elevation relative to Structure Reference: 70.50ft SpE!I'I'V-SUI! DRIL.L.ING SERVIc:eS A Halliburton Company Survey Ref: svy11408 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 ~ 14~08AL 1PB1 Your Ref: API 500292033072 Job No. AKMW22187, Surveyed: 28 November, 2002 BPXA North Slope Alaska Measured Sub~Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13188.89 92.080 210.880 8901.94 8972.44 6785.37 S 1369.21 E 5931626.11 N 676937.22 E 6889.20 Tie On Point 13202.00 91.900 211.920 8901 .48 8971.98 6796.55 S 1362.39 E 5931614.77 N 676930.66 E 8.046 6897.90 Window Point 13231.72 90.840 204.290 8900.77 8971.27 6822.74 S 1348.40 E 5931588.27 N 676917.28 E 25.912 6918.85 13266.38 88.030 195.680 8901.11 8971.61 6855.28 S 1336.57 E 5931555.46 N 676906.21 E 26.127 6946.51 13299.75 89.600 192.750 8901.80 8972.30 6887.61 S 1328.37 E 5931522.94 N 676898.77 E 9.960 6975.04 13328.33 90.310 182.350 8901.83 8972.33 6915.91 S 1324.62 E 5931494.57 N 676895.68 E 36.474 7001.00 .~ 13359.00 89.870 175.480 8901.78 8972.28 6946.55 S 1325.21 E 5931463.95 N 676896.98 E 22.446 7030.47 13390.15 92.160 166.140 8901.22 8971.72 6977.26 S 1330.17 E 5931433.36 N 676902.66 E 30.866 7061.29 13423.20 92.420 158.740 8899.90 8970.40 7008.72 S 1340.13 E 5931402.14 N 676913.34 E 22.386 7094.29 13457.34 95.590 154.690 8897.52 8968.02 7040.00 S 1353.58 E 5931371.19 N 676927.52 E 15.041 7128.13 13492.21 100.970 145.170 8892.49 8962.99 7069.82 S 1370.83 E 5931341.77 N 676945.46 E 31.102 7161.70 13522.21 99.030 142.710 8887.28 8957.78 7093.70 S 1388.22 E 5931318.30 N 676963.40 E 10.345 7189.62 13549.69 97.890 139.180 8883.23 8953.73 7114.81 S 1405.34 E 5931297.60 N 676981.01 E 13.366 7214.80 13582.51 98.150 133.900 8878.65 8949.15 7138.39 S 1427.69 E 5931274.55 N 677003.90 E 15.950 7243.89 13608.99 98.940 133.020 8874.72 8945.22 7156.40 S 1446.70 E 5931256.98 N 677023.32 E 4.439 7266.67 13643.39 99.560 129.490 8869.18 8939.68 7178.78 S 1472.22 E 5931235.20 N 677049.35 E 10.287 7295.54 13665.00 99.560 129.490 8865.59 8936.09 7192.34 S 1488.66 E 5931222.03 N 677066.11 E 0.000 7313.31 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 163.000° (True). ~. Magnetic Declination at Surface is 26.055°(25-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13665.00ft., The Bottom Hole Displacement is 7344.78ft., in the Direction of 168.306° (True). 27 December, 2002 - 8:18 Page 2 of 3 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-08AL 1PB1 Your Ref: API 500292033072 Job No. AKMW22187, Surveyed: 28 November, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13188.89 13202.00 13665.00 8972.44 8971.98 8936.09 6785.37 S 6796.55 S 7192.34 S 1369.21 E 1362.39 E 1488.66 E Tie On Point Window Point Projected Survey .~ $urvev tool program for 14-0BAL 1 PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10997.50 0.00 10997.50 8874.01 13665.00 8874.01 AK-1 BP _HG - BP High Accuracy Gyro(14-08) 8936.09 MWD Magnetic(14-08APB2) .~ 27 December, 2002 - 8:18 Page 3 0(3 DrillQuest 3.03.02.004 ) ~~!Æ~E Iif !Æ~!Æ~~~fÆ AIßASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 14-08AL1 BP Exploration (Alaska), Inc. Pennit No: 202-210 Surface Location: 1966' SNL, 1080' WEL, Sec. 09, T10N, R14E, UM Bottomhole Location: 4583' SNL, 612' EWL, Sec. 15,T10N, R14E, UM Dear Mr. Kara: Enclosed is the approved application for pennit to redrill the above development well. . This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. The pennit is for a new wellbore segment of existing well 14-08A, Pennit No 198-125, API number 50-029-20330-01. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, Ún"'I ~. Iv. (J r Camm~echsli Tay~ Chair BY ORDER OF THE COMMISSION DATED thi~ay of October, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. W6A- f 01 ti/O'L Hole 3-3/4" '), STATE OF ALASKA, ALASKA L..~ AND GAS CONSERVATION COMMk,jION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 70.48' Prudhoe Bay field I Prudhoe 6. Property Designation Bay Pool ..'/ ADL 028314 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-08AL 1 y/' 9. Approximate spud date 11/01/02 "../ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14450' MD / 8901' TVDss 17. Anticipated pressure {~20 AAC 25.035 (e) (2)} 101 0 Maximum surface 2375 psig, At total depth (TVD) 8800' / 3428 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 1240' 13210' 8901' 14450' 8901' Uncemented Slotted Liner '" 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1966' SNL, 1080' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1606' SNL, 1047' EWL, SEC. 15, T10N, R14E, UM At total depth 4583' SNL, 612' EWL, SEC. 15, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028312, 4583' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 13200' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 2-7/8" 6.16# L-80 ST-L Number U-630610 Size Cemented Rf(EIVrD OCT 0 4 2002 _01& Gas Gons. CommIsSion ., Ancho~Be TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 15435 feet 9007 feet 15391 feet 9008 feet Length Plugs (measured) Junk (measured) 73' 20" 250 sx Arcticset II (Approx.) 73' 73' 2708' 13-3/8" 4965 sx Arcticset 2708' 2708' 11051' 9-5/8" 915 sx Class 'G' 11 051' 8909' 1358' 7" 285 sx Class 'G' 10842' - 12200' 8773' - 8988' 3402' 4-1/2" 420 sx Class 'G' 12033' - 15435' 9005' - 9007' 20. Attachments 12230' - 12510', 12565' - 12700', 13320' - 13680', 13720' - 13883', 13913' - 14240', 14270'- 14603', 14638' - 14890', 14920' - 15300' true vertical 8985' - 8968', 8966' - 8972', 8972' - 8968', 8966' - 8972', 8975' - 8981', 8981' - 8996', 8999' - 9004', 9004' - 9008' 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify th8( t~~e;,~ true and correct to the be~t of my kn~~ledge . / ' I Signed Dan Kara (t Ä) ~ . Title CT Dnlllng Engineer Da~e /0 D<I/öG.. .' .'.' '.'. .;:~),,_.i,~~,~:: ", Permit Number API Number ApP'r~'1~~1e See cover letter 2..() .2- - ¿ / <:5 50- 029-20330-60 I Cy~O ;;;- for other reauirements Conditions of Approval: Samples Required 0 Yes S No Mud Lug Hequired 0 Yes )8J No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required "5a Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:Te~ t- F:~ PE to '~5"O pi &' . 009'"81 Signed BY by order of Cammy Oechsli Taylor Commissioner the commission Perforation depth: measured Approved By Form 10-401 Rev. 12-01-85 Date /OÞ,2þ;2- SU~;I;?riPlicate ') ) BP 14-08a L 1 CTD Sidetrack vJ.(jj(' Summary of Operations: V A CrD through tubing lateral is pla¡tned for 14-08a. The coil sidetrack, 14-~8a L 1, will exit the 4-1/2" liner in zone and target Zone 4 attic oil. Prior to CTD sidetracking the well, a workover rig will do a tubing swap to install 4-1/2" L-80 and run the tubing tail into the 4-1/2" liner top to create a 4-1/2" monobore completion. / KOP will be in the horizontal section of the existing wellbore from a retrievable whipstock/Approximately 1400' of 3-3/4" open hole is planned to access reserves trapped at the top of Zone 4. Potential for lost circulation is low given no mapped faults will be crossed. The lateral will be completed with a 2 7/8" slotted liner, with the top of liner left outside the window. The mechanical whipstock will then be retrieved to allow production from and access to the existing wellbore. Phase 1: Prep work. Planned for October 15, 2002. 1. Install plug in 4-1/2" liner to isolate/protect open perforations. 2. Rig workover to replace 4-1/2" 13-Cr with 4-1/2" L-80 and run tail pipe into 4-1/2" liner. 3. CT install retrievable whipstock at 13,200'. Phase 2: Mill window, Drill and Complete sidetrack: Planned for November 01, 2002. Drilling coil will be used to mill the window in the 4 Y2" liner then drill and complete the directional hole as per attached plan. Maximum hole angle will be -100 degrees. Mud Program: "" . Phase 1 : Seawater and 8.6 ppg Flo-Pro . Phase 2: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be 2 7/8" ST -L pre-drilled liner from TD to approx. 13210' MD (8901' ss, just outside the 4-1/2" window. This will allow for whipstock retrievability and access to the existing horizontal wellbore. Well Control: / . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is -100 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. . Logging . An MWD Gamma Ray will be run over all of the open hole section. Resistivity will be run over part of the open hole. No cased hole logs are planned. H~~:-08a measured~m H2S on 2/09/02. Well 14-07 measured ."fo1pm in July 2001. . Lost circulation ri~'is considered to be minimal based on fault ori~~n and regional history. . Potential for pen~trating the Shublik interval increases risk of sloughing shale trouble. Reservoir Pressure Res. press. is estimated to be 3428 at 8800'ss (7.5 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2375 psi. TREE = GRAY GEN 2 WB...LHEAD = rv'CEVOY Ã-êfUA:tðR-;,__m'Ax'ELSON kËCECEV;;^"'^-^'WW_'~"^^-W^'7Õ' 'BF~-^ELËV'-;;'^-"-^~'^'^,^^^^^^'^m^,^ , ....w..... ...",........ ....,.......,.... ,'''''''-- ...- """",,,,,,",,,,,,",W""""".""''''''''''''''''''',,",,,..,,"W'.WN''''. KOP = 2997' --"""'""""""..............""~,w..".."-,~~""^"."""""",,,,,,,,,,,,,,,,,,^v ,^~ax A~~^~_=-,,^..^.~~~...!.?^9^~~'. Datum MD = 10992' ÖäiÙmfVÖ';';"" "ï~8ÖÖï"SS ~~r~ ~p\e -\,QY\ 14-08A (:pre. .~ ~ Crt> ~ì ') SAFETY NOTES: HORIZONTAL W ELL, 70° @ 11253' AND 90° @ 11442'- CHROMETBG . . 2192' H 4-1/2" HES X NIP, ID = 3.813" 1 I 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2708' ~ ~ ST rvD 1VD 1 3106 3102 2 5869 5217 3 8069 6810 4 9181 7621 5 10286 8402 6 10761 8721 GAS LIFT MANDRELS DEV TY Æ VL V LATCH FORT DATE 12 CAM-IVTv1G RK 46 CAM-IVTv1G RK 44 CAM-IVTv1G RK 44 CAM-IVTv1G RK 47 CAM-IVTv1G RK 50 CAM-IVTv1G RK L ITOP OF 7' LNR H 10830' 1 I I MILLOur WINOOW 11051'- 11067' Minimum ID = 3.813" @ 2192' HES X NIPPLE z :8: 1 10911' H 7" X 4-1/2" BAKER 8-3 PKR 1 . 1 10934' H 4-1/2" HES X NIP, ID = 3.813"1 / I 4-1/2"lBG, 12.6#, 13-CR, 0.0152 bpf,lD =3.958" H I 8" WHIPSTOCK H I 8-5/8" CSG, 47#, L-80, ID = 8.525" H 10956' 11051' 11051' I 10956' H 4-112" WLEG I H ELMDTT NOT LOGGED 1 ITOPOF 4-112" LNR H 12028' 1 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" H 12200' 1 PERFORA llON SlJv1MA. RY RB= LOG: ANGLEA TTOPPERF: 97 @ 12230' Note: Refer to Production œ for historical perf data SIZE S~ INTERVAL Opn/Sqz DATE 2-3/4" 4 12230-12510 0 10/12/98 2-3/4" 4 12565-12700 0 10/12/98 2-3/4" 4 13320-13680 0 10/12/98 2-3/4" 4 13720-13883 0 10/12/98 2-3/4" 4 13913-14240 0 10/12/98 2-3/4" 4 14270-14603 0 10/12/98 2-3/4" 4 14638-14890 0 10/12/98 2-3/4" 4 14920-15300 0 10/12/98 IPBTD H 15391' 14-112ILNR,12.6#,L-80,0.0152bPf,ID=3.958" H 15435' 1 Dt\1E 04/80 10/15198 12/29/00 02/22/01 01/06102 REV BY DATE REV BY CúMrvENTS PRUDI-DE BAY !.NIT WELL: 14-08A PERMT I\b: 198-1250 APII\b: 50-029-20330-01 SEC 9, TION, R14E 5207.6 FEL 351.06 FN... BP Exploration (Alaska) COMrvENlS ORIGINAL COMR..EnON SIŒTRAO< SIS-QAA CONVER1ED TO CANV AS SIS-LG REVISION RNIlP CORRECllONS x 5Ll1 L TREE = GRA Y GEN 2 WELLHEAD = MCEVOY 'ACTOATÕR~"-'-~"AXECs6N 'KE3:'a:BT';;"W"~-""-'W~WW'"W'76~ .,.n . ,..,.." .. . ,. M',.,.,...~.'_',w.'-'-','.",.....,.';',~" ~. '"'''',''' ,. . BF. ELEV = w.......'.w.w...'.'.'.w.'.w.'.w.'''''.'.'...w.w.'.'~.'...w...w.''',"".W,""'.'.W.'.'N.w.,o"'''.W^',',',',--,.....,,v..,,,W'o',.... KOP = 2997' :~~:,~,~~!~:~~".:.:~~::~:,i~,~:~~~ Datum MO = 10992' "U, ",,,,,,,,,,,w~,,,,,,~,,,w,,,,,,,,,,,,,"'MW".W.W''''''''''''''~-''''''''' .... ".w.....'.W~.,..". U,." Wu.'", DatumìVD = 8800' SS ) 14-08A Proposed Tubing Swap I . I 13-3/8" CSG, 72#, L-80, ID = 12.347" l-t 2708' ~ l I TOP OF 7" LNR 1-1 10830' I "I Minimum ID = 3.813" @ 2192' HES X NIPPLE / I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 -12034' ~ I 8" WHIPSTOCK 1-1 11051' 8 I 8-5/8" CSG, 47#, L-80, ID = 8.525" l-t 11051' 1 r ITOPOF4-1/2"LNRH 12028' 1 ~l \ 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" 1-1 12200' t--- ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 97 @ 12230' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-3/4" 4 12230-12510 0 10/12/98 2-3/4" 4 12565-12700 0 10/12/98 2-314" 4 13320-13680 0 10/12/98 2-3/4" 4 13720-13883 0 10/12/98 2-3/4" 4 13913-14240 0 10/12/98 2-3/4" 4 14270-14603 0 10/12/98 2-3/4" 4 14638-14890 0 10/12/98 2-3/4" 4 14920-15300 0 10/12/98 14-112" LNR 126#, L-80, 00152bpf, V=3~:~ :~ :::: 1~ DA TE REV BY COMMENTS 04/80 ORIGINAL COMPLETION 10/15/98 SIDETRACK 12/29/00 SIS-QAA CONY ERTED TO CANVAS 02/22/01 SIS-LG REVISION 01/06/02 RN/TP CORRECTIONS DA TE REV BY z" COMMENTS I ,) SAFETY NOTES: HORIZONTAL WELL, 700 @ 11253' AND 900 @ 11442' 2192' 1-1 4-1/2" HES X NIP, 10 = 3.813" I ~ ST MD ìVO 1 3106 3102 2 5869 5217 3 8069 6810 4 9181 7621 5 10286. 8402 6 10761 8721 GAS LIFT MANDRELS DEV ìYPE VLV LATCH 12 CAM-MMG RK 46 CAM-MMG RK 44 CAM-MMG RK 44 CAM-MMG RK 47 CAM-MMG RK 50 CAM-MMG RK PORT DA TE MILLOUT WINDOW 11051' - 11 067' 1 11974' 1-1 7" X 4-1/2" BAKERS-3 PKR I 1 -12,000' 1-1 4-1/2" HES X NIP, ID = 3.813" I t>o~t. Rwo- - ~ -\0 L-80 .u,l \~ - ~ ~l~ ~ dC\IJf1 \f\.1o ~\(L L...ne.r- -rex- . a.. f'{\Ö'(\.~ ~'e1G"'1\ PRUDHOE BAY UNIT WELL: 14-08A PERMIT No: 198-1250 API No: 50-029-20330-01 SEC 9, TION, R14E 5207.6 FEL 351.06 FNL BP Exploration (Alaska) TREE = GRA Y GEN 2 WELLHEAD = MCEVOY . ACTDATÖR^';;'^'-~--'AX~ELSÕÑ^ """"','.'"",w<,,,wu,",''''''',',',W'''''''''.''''''','.''W.,w.w.'.".'.w.'.-~~., ,.. ,.. ~w.yn.='.w.'''''''.'.W .. KB. ELEV = 70' . BF:~ELBi';;' '.",,,..'. ".. ..w....""w...................w.w",w......,.....=.'.W.WN.W.'.'.~'.'"',",",".W.","...._,W.W,',',","....."''',,, KOP = 2997' .f§~=~~~~!~^~' :'.',~.'~~~,~~!~~~~"i Datum MD = 10992' w.W.,^,.'"""'.v.......'.'.W.W,".....w.'...w.....'.W,'"~",,,,,""'W'VN."W.'.W.............'.'.'.",'".~V.'.'.'..'''''''.''',',''''''' Datum TVD = 8800' SS ) 14-08A & A L1 Proposed CTD Sidetrack I I. I 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2708' ~ L 1 TOP OF 7" LNR 1-1 10830' I .. I Minimum ID = 3.813" @ 2192' HES X NIPPLE I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 -12034' ~ I 8" WHIPSTOCK 1-1 11051' I 8-5/8" CSG, 47#, L-80, ID = 8.525" 1-1 11051' 1 ~ g" ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: 97 @ 12230' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 12230-12510 0 10/12/98 2-3/4" 4 12565-12700 0 10/12/98 2-3/4" 4 13320-13680 0 10/12/98 2-314" 4 13720-13883 0 10/12/98 2-3/4" 4 13913-14240 0 10/12/98 2-3/4" 4 14270-14603 0 10/12/98 2-3/4" 4 14638-14890 0 10/12/98 2-3/4" 4 14920-15300 0 10/12/98 ¿ IPBTD I.., 15391' ~(~ 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I.., 15435' DATE 04/80 10/15/98 12/29/00 02/22/01 01/06/02 DA TE REV BY COMMENTS COMMENTS ORIGINAL COMPLETION SIDETRACK SIS-QAA CONVERTED TO CANVAS SIS-LG REVISION RNITP CORRECTIONS REV BY -, SAFETY NOTES: HORIZONTAL WELL, 70° @ 11253' AND 90° @ 11442' 2192' I.., 4-1/2" HES X NIP, ID = 3.813" 1 ~- GAS LIFT MANDRELS DEV TYÆ VLV LATCH 12 CAM-MMG RK 46 CAM-MMG RK 44 CAM-MMG RK 44 CAM-MMG RK 47 CAM-MMG RK 50 CAM-MMG RK PORT DATE ST MD TVD 1 3106 3102 2 5869 5217 3 8069 6810 4 9181 7621 5 10286 8402 6 10761 8721 MILLOUT WINDOW 11051'- 11067' I 11974' I.., 7" X 4-1/2" BAKERS-3 PKR I I -12,000' I.., 4-1/2" HES X NIP, ID = 3.813" I i 13,200' 1-1 Window in 4-1/2" liner 13210' I.., 2-7/8" liner outside of w indowl I 2-7/8" Pre-drilled Liner 1-1 14450' I 0000000 "Ph,~J C-Th ~~ ~\e..,,,ð'l\ PRUDHOE BAY UNrr WELL: 14-08A ÆRMrr No: 198-1250 API No: 50-029-20330-01 SEC 9, TION, R14E 5207.6 FEL 351.06 FNL BP Exploration (Alaska) BP Amoco .......1 _""111' Tie Oil MDI MLLPATH Dfl'AlLS PI.." tU'A!. t 800282033080 14008" 1a181..' 1118' Ref. D.t.. 22 I .. 8I28f..... OltSO v.....~~ ~~ ~~= 1n.'" 0." 0.00 :::~ 0.00 REFERENCE INFORMATION Co-ordinate (NtEI Reference: Well Centre: 14-08, True North v~:r~~g ~:¡:;:~~: ~ro:~~ã %~J.g~ð~)el Measured Depth Reference: 22: 08 9/28/1998 05:30 70.50 Calculation Method: Minimum Curvature MO Inc .. 11'''' ~.01 ltD." :I .. 81.81 IUl.oa :I n." au." . 10.00 '88." . 80.00 t".'7 . 1U1 101.21 ,...... 7 union Is.n 118.17 . 1H1"" ".08 1M.10 . ,.....,U 10.00 "".OJ: 'to ......., '"'' 1u.ol 11 ........00 72.11 '08.'. ANNOTATION' TVO MD "".....1I0tI '''1.M 1ItA'" TIP '"1''' 11_'" KOP '..1of' 1111'''' 1 A..... 1IH2.11 I _.II 11411.11 I ....... 1"'1.11 4 ....... 11711.11 . AII.a, 11"1.33 . 1I1'..01_.n , lI.t.a8 14U'.12 . '_"1 1""'''' TD 8300 8350 :: 8400--' 8450 . - I: - i 8600- . t 8650 a ii 8700 Co) 1: 8750':: .. > 8800 - .. e 8850 to- 8900 ~-;~,----' 8950- 9000 9050. DL.. TFiIe. Y8ec T.....t --------,--., ~., ..-,---'-'-----------'-",-"-,.,.",;;,,'.~.,-", ,,=.1,-. " ---"-, --7",:;;~:~~-~.! -=--~:-~:~~::~---~--^T-M------~mg~~~~~~~e2~~1~ ..... / I . ¡ 14-08 (14-08A) , , 0 ~:.:.- ""'" i --- 14-08 (14-08APB1) ¿ " ,"i.':"'.'.>,i. ". bp- ""'"'",,,,.," """"i.""""""'i"".' ".,", ,'"..," '., ."",""",.", 'i. :,'"",,"" .',;'.,! ,'.',.i,',' ¡ - 14-08 (14-08AÞB2) Magnetic Field ",' , ',',.', ' ' .'! ~'¡;<. i - 1t~~i~i~k) Strength: 57536nT .' ',',i".".'.", ",. ¡~./ .~~ ! PIan#614-08AL1 Dip Angle: 80.79° ______m____I:"TEQ : ,.~.:~----~--:~-j - Þ~n#6 ---~---~-- MJ~~e~d~~~gg~ "~ '.~ 6600 6650 6700 6750 6800 6850 6900 6950 7000 7050 7100 7150 7200 7250 7300 7350 7400 7450 7500 7550 7600 7650 7700 7750 Vertical Section at 163.000 [50ft/in] ------_--____n_~____------------------1-0t2./2-002- I :38 2M..---J 0.00 0.00 "".1. 11.'" 11&.18 8818.88 20.00 M&.OO 180S.1. 28.00 211.00 ."'.82 41:::. :::: ~m:~: '1.00 HS.OO 7a1LS. 11.00 10.00 '118." fa.GO 111.00 7882.81 '1:1.00 ,.1.00 '''1.3' 1LOO U&OO 8OS1... .E¡.W Shape ~::t~ ~~ 1 882g-~ :;¿~-:~ ;~~~1: ~ i::tHi:! =.a ~.l!:~1 H~H! æi -~~- Plan: Plan #6 (14-08/Plan#614-08AL 1) Created By: Brij Polnís Date: 10/2/2002 .------------- Contact Information: Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 -6500-::- . -6600-:-- - - + -7300-- - .c: 1:: -7400 - 0 ~ -7500--::'- - - . !" -7600-= ... - :I 0 -7700 U) 1000 1100 1200 1300 1400 1500 1600 1800 2000 West(-)/East(+) [100ft/In] ~ ---------~----'------~-----'-----'--~-~- ¡ Company: BP Amocol)ate: 101212002 Timet 16:38:54 I Field: PrOdho&Bay Ç~-o~d.nate(NE)Referençe: Well:1+OS,TrUeNprth I Site: PB DS 14 Yei1ical(TVP)R~f~ncè: System: Mean S~L~vel . Well:. .14-08 . . . Section(VS) Refèrence: .' W~n(0~OON;0.00E.163;00Azi) l__~e~~~~-=-PI~~~~~08~~~___--_.- ---_--c-_------------~~~!r~£alenlàtion Method: _~~~um Curvature Db: I Field:- Prudhoe Bay -- -----.-- - I North Slope r UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Geo Datum: NAD27 (Clarke 1866) Coordinate System: .. -~rs_-~~!~~~___.~ean Se~__~~_~-~!_--_._----_.- --------_....._------------_......__._---------------~~~~!~~5.~odel: r-Sit~~-------'- PB DS 14 ----.---------------.---------------- TR-10-14 UNITED STATES: North Slope Site Position: Northing: 5939577.43 ft From: Map Easting: 674150.48 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft ') BP Baker Hughes INTEQ Planning Report ....---..--------- -~-.--- -) ,. IN'fEQ Page: 1 Oracle Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 14 26.346 N 148 35 36.726 W True 1.32 deg - --.-~--_.__..._,--~.._------_.._._._.~---_.__._._._----- -_._._.._~-~_..- 14-08 14-08 Well Position: Slot Name: '-'''---'._---______M''_.~_-_._''----''~--_W_-,-,---'_'--..--- 08 Well: +N/-S -1227.79 ft Northing: 5938378.51 ft Latitude: +E/-W 1232.12 ft Easting: 675410.55 ft Longitude: Position Uncertainty: 0.00 ft 70 14 14.270 N 148 35 0.915 W Wellpath: Plan#6 500292033060 Current Datum: 22: 089/28/199805:30 Magnetic Data: 10/2/2002 Field Strength: 57536 nT Vertical Section: Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Height 70.50 ft Above System Datum: Declination: Mag Dip Angle: +N/-S +E/-W ft ft ------'--------"-----'._-----. 0.00 0.00 -_..,.__.__._----~.__.__..~.._--------- Targets f----O--"7----~O'-~-------'-------'- ------------~-~-------------- ~ap. Map DeScriptiÓli TVD. +N/;'S +E/-W Northing Easting Dip. Dir. ft ft ft ft ft ---_.__.~--- ~----._------ -- ----------_.-," -'._--"'--------~--'._'"-"-----------~--------'------~~~-_._~ 14-08AL 1 Polygon6.1 0.00 -7135.55 1273.88 5931274.99 676849.99 -Polygon 1 0.00 -7135.55 1273.88 5931274.99 676849.99 -Polygon 2 0.00 -7040.34 1481.16 5931374.99 677054.99 -Polygon 3 0.00 -7382.02 1763.31 5931039.99 677344.99 -Polygon 4 0.00 -7954.46 1860.03 5930469.99 677454.99 -Polygon 5 0.00 -7948.06 1585.08 5930470.00 677179.99 -Polygon 6 0.00 -7406.78 1537.66 5931009.99 677119.99 Name 14-08AL 1 T6.2 14-08AL 1 T6.3 14-08AL1 T6. 1 14-08AL 1 T6.4 Annotation MD TVD ft 13188.89 8901.94 TIP 13200.00 8901.59 KOP 13210.00 8901.16 1 13262.33 8899.58 2 13412.33 8899.58 3 13462.33 8894.66 4 13712.33 8856.56 5 13962.33 8832.29 6 14068.53 8827.60 7 14268.53 8851.28 8 14450.00 8900.61 TD 8825.00 -7510.82 1710.29 5930909.99 677294.99 8850.00 -7716.01 1715.52 5930704.99 677304.99 8900.00 -6812.24 1351.43 5931599.99 676919.99 8900.00 -7896.21 1721.33 5930524.99 677314.99 . ---~._-_._-_._.-------_._..- ---'._'.___0_____'-------.--.---'-.- -.-...-.......-------.-.---.----.-- - . ---'--'"----'---""""--"-'--. 14-08A 13188.89 ft Mean Sea Level 26.11 deg 80.79 deg Direction deg 163.00 <--Latitude--> ~ Longitu(le ';'~.' I Deg MinSec DegMinsec ! ~-------------'-'--- 70 13 4.090 N 70 13 4.090 N 70 13 5.026 N 70 13 1.665 N 70 12 56.035 N 70 12 56.099 N 70 13 1.422 N 148 34 23.926 W 148 34 23.926 W 148 34 17.906 W 148 34 9.716 W 148 34 6.912 W 148 34 14.894 W 148 34 16.268 W 70 13 0.399 N 148 34 11.256 W 701258.380N 1483411.106W 70 13 7.270 N 148 34 21.672 W 70 12 56.608 N 148 34 10.938 W .-.--.----.--..----..-.---------- --.----..1 -~-_o_._"- ~- ---..-.--.,----..-----.-.....-....-.-..--...--.-..-----..------.-.....-.--.---..-.---.-------.-..-.-..----...----.-----,--,,-,-~,,--,-,,---,----,,-------,'--'-----'---'_._'--~"-------_._--- ----...-. ----.---.--.-.--- -) ') bp BP Baker Hughes INTEQ Planning Report i Company: SP Amoco ¡ Fiëld: Prudhoe' Say ! Site: PS DS14 i . Well: 14-08 I Wëllpatb: PIan#614-08AL 1 l_;:=:=-..:=~-==,-..:::..=~==-_._~-_._._-_.~_._--=- Plan: Plan #6 Identical to Lamar's Plan #6 Principal: Yes '~'1?ED Date:> 1012/2002 Time: .'1a;38:54 Page: C~rdinate(NE) R..,fe"en~:. Well: 14;;Q8.TrueNorth YÇrtical (I'YD) Referenee: . Sy~tem;M~nSea Level .~tion(VS);Rere..en~: WeU(0.ooN,O.00E,163,00Azi) Su-o'ëy CakalationMethOd: Minimum Curvatùre Db: Oracle --'-'-----'--'-----"-'--'- Plan Section Information r--:---:---'-- ----.--- IMD locI Azim TVD : ft deg deg ft r -13-1-8ã~89-----92~08------i1O:88---8901. 94 113200.00 91.51 212.02 8901.59 113210.00 93.44 211.50 8901.16 I 13262.33 90.00 198.87 8899.58 ! 13412.33 90.00 161.37 8899.58 13462.33 101.31 156.02 8894.66 13712.33 95.83 126.17 8856.56 13962.33 95.05 156.30 8832.29 14068.53 90.00 168.02 8827.60 14268.53 76.51 188.05 8851.28 14450.00 72.31 165.85 8900.61 Date Composed: Version: Tied-to: 10/2/2002 4 From: Definitive Path 2 +N/.;S ft -6785.36 -6794.83 -6803.32 -6850.55 -6997.89 -7044.16 -7233.90 -7425.71 -7526.50 -7723.49 -7896.77 +E/.WDLS-----Baild TurnTFO Target ft deg/100ftdeg/100ftdeg/10Qft deg, , ..' -c-1369~24 ------ 0.00- 0.00 O.-õO--'--'-QÒo--~--------------1 1363.45 11.47 -5.13 10.26 116.56 1358.19 20.00 19.32 -5.18 345.00 1335.98 25.00 -6.58 -24.13 255.00 1335.67 25.00 0.00 -25.00 270.00 1353.69 25.00 22.63 -10.71 335.00 1507.41 12.00 -2.19 -11.94 262.00 1661.38 12.00 -0.31 12.05 90.00 1693.80 12.00 -4.76 11.03 113.00 1701.05 12.00 -6.75 10.02 125.00 1709.92 12.00 -2.32 -12.23 256.00 -------'-'-'-"'.~ . Survey [------- MO'------ï;;.'----A;¡;---'- SSTVD NIS ft deg deg ft ft - --.-_._---_._-_..__._..~-~ ---~------~-_._--_._----------_.._-"-._~ 13188.89 92.08 210.88 8901.94 -6785.36 13200.00 91.51 212.02 8901.59 -6794.83 13210.00 93.44 211.50 8901.16 -6803.32 13225.00 92.46 207.88 8900.38 -6816.33 13250.00 90.82 201.84 8899.67 -6839.00 _.._----~-_._.__.-_._._._---~_.~_.._.'----'_."'-~-----^---~---,,~._--_._---- EIW ft 1369.24 1363.45 1358.19 1350.77 1340.27 VS ft 6889.19 6896.56 6903.15 6913.42 6932.02 DLS deg/100ft 0.00 11.47 20.00 25.00 25.00 1 Tool TFO deg -~---- 0.00 TIP 116.56 KOP 345.00 1 255.00 MWD 254.81 MWD 13262.33 90.00 198.87 8899.58 -6850.55 1335.98 5931561.33 676905.44 6941.82 25.00 254.64 2 13275.00 90.00 195.70 8899.58 -6862.65 1332.22 5931549.15 676901.96 6952.29 25.00 270.00 MWD 13300.00 90.00 189.45 8899.58 -6887.04 1326.77 5931524.65 676897.09 6974.02 25.00 270.00 MWD 13325.00 90.00 183.20 8899.58 -6911.87 1324.02 5931499.76 676894.91 6996.96 /25.00 270.00 MWD 13350.00 90.00 176.95 8899.58 -6936.86 1323.98 5931474.78 676895.46 7020.85 25.00 270.00 MWD 13375.00 90.00 170.70 8899.58 -6961.70 1326.67 5931450.00 676898.72 7045.39 25.00 270.00 MWD 13400.00 90.00 164.45 8899.58 -6986.11 1332.04 5931425.74 676904.66 7070.30 25.00 270.00 MWD 13412.33 90.00 161.37 8899.58 -6997.89 1335.67 5931414.04 676908.56 7082.63 25.00 270.00 3 13425.00 92.87 160.03 8899.26 -7009.84 1339.85 5931402.19 676913.02 7095.28 25.00 335.00 MWD 13450.00 98.53 157.36 8896.78 -7033.01 1348.88 5931379.24 676922.58 7120.08 25.00 334.97 MWD MapN ft 5931627.29 5931617.68 5931609.07 5931595.89 5931572.99 M~pE ft 676937.17 676931.60 676926.54 676919.43 676909.46 13462.33 101.31 156.02 8894.66 -7044.16 1353.69 5931368.20 676927.65 7132.15 25.00 334.70 4 13475.00 101.10 154.49 8892.19 -7055.45 1358.89 5931357.04 676933.11 7144.46 12.00 262.00 MWD 13500.00 100.65 151.46 8887.48 -7077.32 1370.04 5931335.44 676944.77 7168.63 12.00 261.70 MWD 13525.00 100.17 148.45 8882.96 -7098.60 1382.35 5931314.45 676957.57 7192.59 12.00 261.13 MWD 13550.00 99.67 145.45 8878.65 -7119.24 1395.78 5931294.13 676971.47 7216.25 12.00 260.59 MWD 13575.00 99.14 142.46 8874.57 -7139.18 1410.29 5931274.53 676986.44 7239.56 12.00 260.07 MWD 13600.00 98.58 139.47 8870.71 -7158.36 1425.85 5931255.72 677002.44 7262.45 12.00 259.58 MWD 13625.00 98.01 136.50 8867.11 -7176.74 1442.40 5931237.73 677019.42 7284.87 12.00 259.12 MWD 13650.00 97.41 133.53 8863.75 -7194.26 1459.91 5931220.62 677037.33 7306.74 12.00 258.69 MWD 13675.00 96.79 130.57 8860.66 -7210.88 1478.33 5931204.44 677056.13 7328.02 12.00 258.29 MWD 13700.00 96.15 127.62 8857.84 -7226.54 1497.61 5931189.23 677075.76 7348.63 12.00 257.93 MWD 13712.33 95.83 126.17 8856.56 -7233.90 1507.41 5931182.10 677085.74 7358.54 12.00 257.60 5 13725.00 95.83 127.70 8855.27 -7241.48 1517.49 5931174.77 677095.98 7368.73 12.00 90.00 MWD 13750.00 95.82 130.71 8852.73 -7257.20 1536.76 5931159.50 677115.61 7389.40 12.00 90.16 MWD 13775.00 95.78 133.73 8850.21 -7273.91 1555.18 5931143.22 677134.41 7410.76 12.00 90.46 MWD 13800.00 95.74 136.74 8847.70 -7291.57 1572.69 5931125.97 677152.33 7432.77 12.00 13825.00 95.67 139.76 8845.21 -7310.13 1589.25 5931107.81 677169.32 7455.36 12.00 13850.00 95.59 142.77 8842.76 -7329.53 1604.82 5931088.77 677185.33 7478.47 12.00 13875.00 95.50 145.79 8840.34 -7349.73 1619.34 5931068.92 677200.32 7502.03 12.00 13900.00 95.39 148.80 8837.97 -7370.67 1632.79 5931048.30 677214.25 7525.99 12.00 13925.00 95.26 151.81 8835.65 -7392.29 1645.12 5931026.97 677227.08 7550.27 12.00 --------- _.-_."-------.-~- -'--'''.''-.--------''-''-'----~--'--'''------------''- 90.77 MWD 91.07 MWD 91.37 MWD 91.66 MWD 91.96 MWD 92.24 MWD ) BP Baker Hughes INTEQ Planning Report .,.-.-,--,..- 13950.00 95.12 154.82 8833.39 13962.33 95.05 156.30 8832.29 13975.00 94.45 157.70 8831.24 14000.00 93.27 160.47 8829.56 N/S ft -7414.53 -7425.71 -7437.33 -7460.63 ') ... ~ IN'TEQ Date: 1 01212002 Time: 16;38:54 Page: 3 I Co~r~iria*~E)Refërenee: Wetl:14..08, True North Vertieal(TV)))~efere~~~.. . Systßm:.M(: EiRSeatevel . . I Seetion(VS) Re(èrence: . . '. ~el.I(0~00N.0.00E.163;00Azi) .. . Su~c:~_~~ltulationMetbOd:... _.~Mtn!T~~_Curvat~~:~~~__,~b: _Or~cle ~~J EIW ft 1656.30 1661.38 1666.31 1675.22 MapE VS ft ft ------------...--- 677238.77 7574.81 677244.11 7586.98 677249.32 7599.54 677258.76 7624.42 Tool I MapN ft. 5931005.00 5930993.94 5930982.44 5930959.35 DLS deg/100ft 12.00 12.00 12.00 12.00 TFO deg ------.--- - 92.52 MWD 92.79 6 113.00 MWD 113.12 MWD 14025.00 92.08 163.22 8828.39 -7484.36 1683.00 5930935.82 677267.09 7649.39 12.00 113.30 MWD 14050.00 90.89 165.98 8827.74 -7508.45 1689.63 5930911.89 677274.28 7674.37 12.00 113.43 MWD 14068.53 90.00 168.02 8827.60 -7526.50 1693.80 5930893.94 677278.87 7692.85 12.00 113.50 7 14075.00 89.55 168.65 8827.62 -7532.84 1695.11 5930887.63 677280.32 7699.29 12~00 125.00 MWD 14100.00 87.83 171.11 8828.19 -7557.44 1699.50 5930863.14 677285.28 7724.10 12.00 125.00 MWD 14125.00 86.12 173.58 8829.51 -7582.18 1702.83 5930838.49 677289.19 7748.73 12.00 124.94 MWD 14150.00 84.41 176.05 8831.58 -7606.99 1705.08 5930813.74 677292.02 7773.12 12.00 124.81 MWD 14175.00 82.71 178.54 8834.38 -7631.80 1706.25 5930788.96 677293.77 7797.19 12.00 124.61 MWD 14200.00 81.03 181.05 8837.91 -7656.55 1706.34 5930764.23 677294.43 7820.88 12.00 124.33 MWD 14225.00 79.36 183.58 8842.17 -7681.16 1705.35 5930739.60 677294.01 7844.13 12.00 123.97 MWD 14250.00 77.71 186.14 8847.14 -7705.57 1703.28 5930715.15 677292.51 7866.86 12.00 123.54 MWD 14268.53 76.51 188.05 8851.28 -7723.49 1701.05 5930697.18 677290.70 7883.35 12.00 123.03 8 14275.00 76.32 187.28 8852.79 -7729.73 1700.21 5930690.93 677290.00 7889.07 12.00 256.00 MWD 14300.00 75.62 184.27 8858.86 -7753.86 1697.77 5930666.75 677288.12 7911.43 12.00 256.18 MWD 14325.00 74.96 181.25 8865.20 -7778.00 1696.60 5930642.58 677287.52 7934.18 12.00 256.91 MWD 14350.00 74.34 178.20 8871.82 -7802.11 1696.72 5930618.49 677288.20 7957.27 12.00 257.68 MWD 14375.00 73.77 175.14 8878.69 -7826.10 1698.12 5930594.54 677290.15 7980.62 12.00 258.49 MWD 14400.00 73.23 172.06 8885.79 -7849.92 1700.79 5930570.79 677293.37 8004.18 12.00 259.33 MWD 14425.00 72.75 168.96 8893.11 -7873.50 1704.73 5930547.31 677297.86 8027.88 12.00 260.20 MWD 14450.00 72.31 165.85 8900.61 -7896.77 1709.92 5930524.17 677303.60 8051.65 12.00 261.11 TD , . ) BOP-Tree ") KB Elevation ,Vi:")""J . ...~i~~I~or, ,I) ....' .'. I~m, .,.:... ...:.:., . .,., ,:, ..:r:::::::\:::':::':::::::::::..::::::::::.:1 1 I I L.ú.I.L.I .~~ Lubricator ID = 6.375" with 6" Otis Unions J"~I,~,,,J \71/16" 5000 psi BOP's, ID = 7,06" I I I ~:i}:¡:::¡:¡:¡:i:¡:¡:?w?l.:.~ 1'71 (1.6" 5000 psi, ,RX-46 - L.. .:.:' '. '. ;i~:¡~IIII¡~¡:!~~'.:.:::. '.:".<. .'. ".I // I$.M5.9.p~tp.~tH " ,.., ,,' ,----- r I J l::Q]~ II L~M":"::: ' , , : ' : 1~:~~5(}?:) :t::t,ll,Æ::\ OJ, I:......l. m ".....~..........,......~ ""........":"",,,',',',',',",',",',", i I~ e" 'IHCRIL( .' í': . ... ~ I :COO:~i::I/!~' 1:;:~:~i"n:OOP:i. RX_2~li Ir . : ,: '.' ",""~'~.:',' . , , 7 1/16" 5000 psi (RX-46) or I ~QI [()I llQJ I-.-.-.....IIII'I~IIÞ"III'..-.-. I Swab Valve I Tree Size I SSV I I Master Valve I I I .........,' ,":yy" : ' ,..., """"'. 1 tlf," .. Base Flange I Page 1 H 207121 DATE 9/20/02 CHECK NO. H207121 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET H 9/20/02 INV# CK091602M PERMIT TO DRILL FEE ~ L.f~o84 L \ f~' THE AITACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ i""""", FIRST NATIONAL BANK OF ASHLAND ÁN'AFFIUATEOF NATIONAL CllY BANK CLEVI;LANP. OHIO No. H 207121 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT SEPT. 20, 2002 ****$100.00**** ~T \(~I IJ) AFT¡::R 1? ,::'\:.;r~:J!jj :.¡¡::.;:....."... ,. ... ~~\:;~~¥:.\\~:'~;~\~~:,::¡;;:~~:i III 20 ? ~ 2 ~ III I: 0 ~ ~ 2 0 3 a c¡ 51: 00 a ~ ~ ~ c¡ III ) -') / TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER A1q WELL NAME /~- o?A¿ / PTD# - 2-0' ;¿ - Z-I ð CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates "CLUE" The permit is for a new well bore segment of existing wen/~- Ó 1/1 Permit Nol11-/2.5 APINo. .fe; -O¿7-¿ð 330-ð} Production should continue to be reported as a function' of the original API number. stated above. In accordance with 20 AAC 25.005(t), all records, data and logs. acquired for the pilot hole must. be clearly differentiated in both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY 1$ f )I WELL NAME ¡J Au / ,/-()<¡.lJLl PROGRAM: Exp - Dev X Redrll - Re-Enter - Serv - Wellbore seg ~ ' FIELD & POOL C7'I'"J)5ð INITCLASS /)~/./ /"'ð¡/ GEOLAREA ~/n UNIT# /¡Ctj'ð ON/OFFSHORE~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . fY N 2. Lease number appropriate. .. . . . . .. . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . .. . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . , . . . . Y N 1)~/ /. ~ J ~ 8. If deviated, is wéllbore plat included.. . . . . . . . . . . . . . Y N ~ /~<- 9. Operator only affected party.. . . . . ... . . . . . . . . . . . Y N 10. Operator has appropriate bond in force.. . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . W N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#--:.. Ý .Þf /LI.. ft. (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. Y/N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . .. . . . . . . &. N 16. Surface casing protects all known USDWs. . . . . . . . . . . éfJ N ~ J 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . .y N 'Ii/A-- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥-N- .JJ 19. CMT will cover all kno.wn productive horizons. . . . . . . .. . ~¥ N sl <77{£c/ 20. Casing designs adequate for C, T, B & permafrost. . .. . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N v,<r- () {Á 22. If a re-drill, has a 10-403 for abandonment been approved.. . .k*- rJllr 23. Adequate wellbore separation proposed.. . . . . . . . . . . . œ N 24. If diverter required, does it meet regulations.. . . . . . . . . --¥-N- #/k- 25. Drilling fluid program schematic & equip list adequate. . . . . ~ N fI{~ Ø1/d -R, 7 r P7 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N f:> APPR DATE 27. BOPE press rating appropriate; test to .!>SOO psig. . N ¡lh/;r Z '3 7 ~ (J ~ . ,. / 28. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . 1!i2 N 1dC?A- lIP II Ot. 29. Work will occur without operation shutdown. . . . . . . . . . . Ci2 N 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . c:;P N 31. Mechanical condition of wells within AOR verified. . . . . . . . ~--¥-N- ¡..tlk- If þ, Il. (Service Well Only) GEOLOGY APPR DATE 4 /ðh~2.- I' (É~ploratory b~Îy) 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR Rev: 07/12/02 SFD- WGA y/ MJW G:\geology\permits\checklist.doc COMMISSIONER: COT DTS 101 ?'G/u<-. M¿..ð /o/z.2-/ø-z,.. ) Comments/lnstructions: ') ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special' effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan utility áod.-é^tD 'I 8°cf $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 01 10:49:42 2003 Reel Header Service name... ... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ...... .... .....UNKNOWN Continuation Number......01 Previous Reel Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name.. .... .... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... .... ......UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 14-08ALlPB1 500292033061 BP Exploration Sperry Sun 30-MAY-03 (Alaska), Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MWOOOO022187 M. ALLEN SARBER/WHITL MWD RUN 2 MWOOOO022187 M. ALLEN EGBEJIMBA/SE MWD RUN 3 MWOOOO022187 M. ALLEN EGBEJIMBA/SE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 10N 14E 1966 1080 MSL 0) 70.50 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.500 13202.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 & 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. ) 3. MWD RUNS 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY DATA (SGRC) IS NOT PRESENTED FOR RUNS 1 & 2 DUE TO A TOOL FAILURE RATE OF PENETRATION ONLY IS PRESENTED FOR MWD RUN 1 & 2. 5. GAMMA RAY DATA (SGRC)DATA FROM 13187' MD, 8901' SSTVD TO 13441' MD, 8899' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 3 AND IS APPENDED TO MWD RUN 3 DATA TO COMPLETE THE GAMMA RAY DATA. 6. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 13192' MD, 8902' SSTVD TO 13454' MD, 8898' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 3 AND IS APPENDED TO MWD RUN 3 DATA TO COMPLETE THE RESISTIVITY DATA. 7. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE OF 12-02-02 FROM D. SCHNOOR OF BP EXPLORATION ALASKA, INC.. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM 14-08A AT 13202' MD, 8901' SSTVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL 14-08AL1PB1 WITH API # 50-029-20330-61. THIS WELL REACHED A TOTAL DEPTH OF 13665' MD, 8866' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. ... ..03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name... ... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM 1 clipped curves; all bit runs merged. .5000 START DEPTH 13187.0 13192.5 13192.5 STOP DEPTH 13619.5 13633.5 13633.5 ) ') RPS RPX FET ROP $ 13192.5 13192.5 13192.5 13219.5 13633.5 13633.5 13633.5 13665.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 13219.5 2 13348.5 3 13482.5 MERGE BASE 13348.0 13482.0 13665.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.... .......... ....0 Data Specification Block Type.....O Logging Direction... .... ....... ...Down Optical log depth units. ...... ... .Feet Data Reference Point.......... ... .Undefined Frame Spacing..................... 60 . lIN Max frames per record........ .... .Undefined Absent value...................... -999 Depth units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13187 13665 13426 957 13187 13665 ROP MWD FT/H 0 187.08 53.9096 892 13219.5 13665 GR MWD API 23.69 532.03 78.5522 866 13187 13619.5 RPX MWD OHMM 0.16 2000 51. 364 883 13192.5 13633.5 RPS MWD OHMM 0.16 2000 65.9451 883 13192.5 13633.5 RPM MWD OHMM 0.44 1858.85 26.6822 883 13192.5 13633.5 RPD MWD OHMM 0.2 2000 94.4763 883 13192.5 13633.5 FET MWD HR 0.42 28.72 11. 7631 883 13192.5 13633.5 First Reading For Entire File. ....... ..13187 Last Reading For Entire File.. ........ .13665 File Trailer Service name.... ... ... ...STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.. .... ... ..STSLIB.002 Physical EOF File Header -) Service name.. ......... ..STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .....STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 -) header data for each bit run in separate files. 1 .5000 START DEPTH 13219.5 STOP DEPTH 13348.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ...... .......0 Data Specification Block Type.....O Logging Direction..... ..... .... ...Down Optical log depth units. .... ..... .Feet Data Reference Point.. ...... ......Undefined Frame Spacing.................... .60 .lIN Max frames per record.. ..... .... ..Undefined 26-NOV-02 Insite 4.3 Memory 13348.0 88.0 91. 9 TOOL NUMBER 82758 3.750 13202.0 Flo Pro 8.60 65.0 9.0 20000 8.0 .000 .000 .000 .000 .0 177.0 .0 .0 ') Absent value...................... -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOI0 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWDOI0 FT/H Min 13219.5 1. 91 Max 13348 70.37 Mean Nsam 13283.8 258 35.5362 258 First Reading For Entire File.. ... .....13219.5 Last Reading For Entire File..... '.' ...13348 File Trailer Service name.. ...........STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation.......03/07/01 Maximum Physical Record..65535 File Type................ LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name........ .....STSLIB.003 Service Sub Level Name... Version Number... .... ....1.0.0 Date of Generation. ......03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name.. .....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 13348.5 STOP DEPTH 13482.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-NOV-02 Insite 4.3 Memory 13482.0 89.9 95.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 ") First Reading 13219.5 13219.5 Last Reading 13348 13348 -'~) DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ... .......... ...0 Data Specification Block Type. ....0 Logging Direction..... ........ ....Down Optical log depth units.. .... .... .Feet Data Reference Point. ... .... ..... .Undefined Frame Spacing..... ... .......... ...60 .1IN Max frames per record.. .... ... ....Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 13202.0 Flo Pro 8.60 65.0 9.0 20000 8.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD020 FT/H Min 13348.5 2.24 Max 13482 96.66 First Reading For Entire File... ....., .13348.5 Last Reading For Entire File...... .....13482 File Trailer Service name... ... ...... .STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation... ....03/07/01 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name.. .....,... ..STSLIB.004 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.......03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.003 Mean Nsam 13415.3 268 64.3351 268 .0 187.3 .0 .0 First Reading 13348.5 13348.5 Last Reading 13482 13482 ) Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 ') header data for each bit run in separate files. 3 .5000 START DEPTH 13187.0 13192.5 13192.5 13192.5 13192.5 13192.5 13482.5 STOP DEPTH 13619.5 13633.5 13633.5 13633.5 13633.5 13633.5 13665.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction... ............. . Down Optical log depth units....... ....Feet Data Reference Point.. ...... ... ...Undefined Frame Spacing. ...... .... ....... ...60 .1IN Max frames per record....... ... ...Undefined Absent value...................... -999 28-NOV-02 Insite 4.3 Memory 13665.0 97.9 101. 0 TOOL NUMBER 74165 PB00417R3 3.750 13202.0 Flo Pro 8.70 65.0 9.0 20000 5.6 .300 .122 .150 .210 68.0 177.0 68.0 68.0 ) Depth Unit s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13187 13665 13426 957 13187 13665 ROP MWD030 FT/H 0 187.08 59.2274 366 13482.5 13665 GR MWD030 API 23.69 532.03 78.5522 866 13187 13619.5 RPX MWD030 OHMM 0.16 2000 51. 364 883 13192.5 13633.5 RPS MWD030 OHMM 0.16 2000 65.9451 883 13192.5 13633.5 RPM MWD030 OHMM 0.44 1858.85 26.6822 883 13192.5 13633.5 RPD MWD030 OHMM 0.2 2000 94.4763 883 13192.5 13633.5 FET MWD030 HR 0.42 28.72 11. 7631 883 13192.5 13633.5 First Reading For Entire File.... .... ..13187 Last Reading For Entire File.. ... ... ...13665 File Trailer Service name.... ..... ....STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record..65535 File Type................ LO Next File Name.. .... .....STSLIB.005 Physical EOF Tape Trailer Service name.. ....... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. ... ...... .... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.. ......... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ..... ... . UNKNOWN Continuation Number......Ol Next Reel Name......... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 01 10:43:32 2003 Reel Header Service name. ....... ... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ... . UNKNOWN Continuation Number.. ... .01 Previous Reel Name. ..... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ... . UNKNOWN Continuation Number.. ... .01 Previous Tape Name.. ... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING MWD RUN 1 MWOOOO022187 M. ALLEN SARBER/WHITL MWD RUN 4 MWOOOO022187 S. LATZ EGBEJIMBA/SE MWD RUN 6 MWOOOO022187 M. ALLEN EGBEJIMBA/SE MSL 0) Writing Library. Writing Library. 14-08AL1 500292033060 BP Exploration Sperry Sun 01-JUL-03 MWD RUN 2 MWOOOO022187 M. ALLEN EGBEJIMBA/SE MWD RUN 5 MWOOOO022187 M. ALLEN EGBEJIMBA/SE 9 10N 14E 1966 1080 70.50 .00 .00 ) òlÞõ\. -~tO l(SÒ5 Scientific Technical Services Scientific Technical Services (Alaska) Inc. MWD RUN 3 MWOOOO022187 M. ALLEN EGBEJIMBA/SE MAD RUN 6 MWOOOO022187 M. ALLEN EGBEJIMBA/SE OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.500 13202.0 ) ) 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. NO TVD LOG PRESENTED DUE TO MINIMAL CHANGE IN TVD. 3. MWD RUNS 1, 2, AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUNS 3, 5, AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 5. GAMMA RAY DATA (SGRC) IS NOT PRESENTED FOR RUNS 1 & 2 DUE TO A TOOL FAILURE. RATE OF PENETRATION ONLY IS PRESENTED FOR MWD RUN 1 & 2. 6. GAMMA RAY DATA (SGRC) IS NOT PRESENTED FOR RUN 4 DUE TO MINIMAL FOOTAGE DRILLED. RATE OF PENETRATION ONLY IS PRESENTED FOR MWD RUN 4. 7. GAMMA RAY DATA (SGRC) DATA FROM 13187' MD, 8901' SSTVD TO 13441' MD, 8899' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 3 AND IS APPENDED TO MWD RUN 3 DATA TO COMPLETE THE GAMMA RAY DATA. 8. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 13192' MD, 8902' SSTVD TO 13443' MD, 8899' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 3 AND IS APPENDED TO MWD RUN 3 DATA TO COMPLETE THE RESISTIVITY DATA. 9. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE OF 12-02-02 FROM D. SCHNOOR OF BP EXPLORATION ALASKA, INC.. 14-08AL1 IS TIED INTO 14-08AL1PB1 AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM 14-08A AT 13188' MD, 8901' SSTVD (TOP OF WHIPSTOCK) . THIS WELL KICKS OFF FROM 14-08AL1PB1 AT 13443' MD, 8899' SSTVD. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 10. A MADPASS (MAD) WAS PERFORMED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUN 6. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 11. MWD RUNS 1 - 6 REPRESENT WELL 14-08AL1 WITH API # 50-029-20330-60. THIS WELL REACHED A TOTAL DEPTH OF 14180' MD, 8908' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) $ ) ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. ... ..03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.OOO Corrunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM FET RPD ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 13187.0 13192.5 13192.5 13192.5 13192.5 13192.5 13219.5 STOP DEPTH 14138.5 14153.0 14153.0 14153.0 14153.0 14153.0 14180.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 5 6 MERGE TOP 13219.5 13348.5 13443.0 13443.5 13477.5 13851.5 MERGE BASE 13348.0 13443.0 13443.0 13477.0 13851.0 14180.0 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 .1IN Max frames per record... ........ ..Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 ') ) RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13187 14180 13683.5 1987 13187 14180 ROP MWD FT/H 1 444.34 70.4353 1922 13219.5 14180 GR MWD API 23.69 167.85 55.1962 1904 13187 14138.5 RPX MWD OHMM 0.16 2000 82.0316 1922 13192.5 14153 RPS MWD OHMM 0.16 2000 53.9451 1922 13192.5 14153 RPM MWD OHMM 0.44 1858.85 30.0592 1922 13192.5 14153 RPD MWD OHMM 0.2 2000 123.605 1922 13192.5 14153 FET MWD HR 0.27 28.72 6.49971 1922 13192.5 14153 First Reading For Entire File. ..... ... .13187 Last Reading For Entire File.. ..... ... .14180 File Trailer Service name. ... .... .....STSLIB.001 Service Sub Level Name... Version Number.... ... ... .1.0.0 Date of Generation..... ..03/07/01 Maximum Physical Record. .65535 File Type. ....'..' ...... .LO Next File Name... ....... .STSLIB.002 Physical EOF File Header Service name... ....'.' ...STSLIB.002 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET RAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 13628.0 13646.0 13646.0 13646.0 13646.0 13646.0 13 67 6.5 STOP DEPTH 14060.0 14076.0 14076.0 14076.0 14076.0 14076.0 14107.5 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP 6 0 13628.0 MERGE BASE 14180.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type...... ... ... ......0 Data Specification Block Type.....O Logging Direction.. .... ..... ... ...Down Optical log depth units..... .... ..Feet Data Reference Point.. ..... .......Undefined Frame Spacing..................... 60 .lIN ') ') Max frames per record... ....... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 13628 14107.5 13867.8 960 13628 14107.5 RAT MAD FT/H 596.25 1642.82 777.827 863 13676.5 14107.5 GR MAD API 23.61 118.43 48.7572 865 13 62 8 14060 RPX MAD OHMM 4.96 83.32 22.7143 861 13646 14076 RPS MAD OHMM 5.64 116.41 33.382 861 13646 14076 RPM MAD OHMM 6.03 172 .19 35.4617 861 13646 14076 RPD MAD OHMM 10.39 2000 273.764 861 13646 14076 FET MAD HR 7.54 30.57 19.0539 861 13 64 6 14076 First Reading For Entire File........ ..13628 Last Reading For Entire File......... ..14107.5 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.... ...03/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name..... .... ..STSLIB.003 Physical EOF File Header Service name. ....... '..' .STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation.. .....03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.002 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 13219.5 STOP DEPTH 13348.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 26-NOV-02 Insite 5.3.5 4.3 Memory 13348.0 ) 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 GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... .... ... ....0 Data Specification Block Type.....O Logging Direction... ........ .... ..Down Optical log depth units. ... .... ...Feet Data Reference Point... ........ ...Undefined Frame Spacing..................... 60 . lIN Max frames per record... .... ... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 88.0 91. 9 TOOL NUMBER 82758 3.750 13202.0 Flo Pro 8.60 65.0 9.0 20000 8.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 13219.5 1. 91 Max 13348 70.37 First Reading For Entire File. ........ .13219.5 Last Reading For Entire File....... ....13348 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation. ......03/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Mean Nsam 13283.8 258 35.5362 258 ) .0 177.0 .0 .0 First Reading 13219.5 13219.5 Last Reading 13348 13348 ') Physical EOF File Header Service name. ...... ..... .STSLIB.004 Service Sub Level Name... Version Number..... ... ...1.0.0 Date of Generation. ..... .03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 4 ) header data for each bit run in separate files. 2 .5000 START DEPTH 13348.5 STOP DEPTH 13443.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.. ...0 27-NOV-02 Insite 5.3.5 4.3 Memory 13443.0 89.9 95.6 TOOL NUMBER 82758 3.750 13202.0 Flo Pro 8.60 65.0 9.0 20000 8.0 .000 .000 .000 .000 .0 187.3 .0 .0 ) ') Logging Direction.... ..... .... ... . Down Optical log depth units...... .....Feet Data Reference Point... .......... .Undefined Frame Spacing...... ... ...... .... ..60 .1IN Max frames per record... ....... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD020 FT/H Min 13348.5 2.24 Max 13443 96.66 Mean Nsam 13395.8 190 69.1903 190 First Reading 13348.5 13348.5 Last Reading 13443 13443 First Reading For Entire File... ...... .13348.5 Last Reading For Entire File......... ..13443 File Trailer Service name. ... ....... ..STSLIB.004 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ... .03/07/01 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name.. ....... ..STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.. .... .....1.0.0 Date of Generation..... ..03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.004 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPD RPM RPX FET $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 13187.0 13192.5 13192.5 13192.5 13192.5 13192.5 STOP DEPTH 13443.0 13443.0 13443.0 13443.0 13443.0 13443.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 28-NOV-02 Insite 5.3.5 4.3 Memory 13443.0 ~) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ... ............0 Data Specification Block Type.. ...0 Logging Direction.. ........... ... . Down Optical log depth units.......... .Feet Data Reference Point.. ........... . Undefined Frame Spacing... ..... ............ .60 .1IN Max frames per record......... ... . Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ') 97.9 101. 0 TOOL NUMBER 74165 PB00417R3 3.750 13202.0 Flo Pro 8.70 65.0 9.0 20000 5.6 .300 .122 .150 .210 68.0 177.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 RPX MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPM MWD030 OHMM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 FET MWD030 HR 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13187 13443 13315 513 13187 13443 GR MWD030 API 23.69 155.11 61.1726 513 13187 13443 RPX MWD030 OHMM 0.16 2000 82.043 502 13192.5 13443 RPS MWD030 om1M 0.16 2000 98.7595 502 13192.5 13443 RPM MWD030 OHMM 0.44 1858.85 26.8104 502 13192.5 13443 RPD MWD030 OHMM 0.2 2000 41. 966 502 13192.5 13443 FET MWD030 HR 10.21 28.72 18.5056 502 13192.5 13443 First Reading For Entire File.. ""." .13187 Last Reading For Entire File..... ......13443 File Trailer ) Service name... ..........STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation. ..... .03/07/01 Maximum Physical Record..65535 File Type................ LO Next File Name... ....... .STSLIB.006 Physical EOF File Header Service name.. ..... ... ...STSLIB.006 Service Sub Level Name... Version Number... .... ... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.005 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 6 ) header data for each bit run in separate files. 4 .5000 START DEPTH 13443.5 STOP DEPTH 13477.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 28-NOV-02 Insite 5.3.5 4.3 Memory 13477.0 95.0 95.0 TOOL NUMBER 82758 3.750 13202.0 Flo Pro 8.70 65.0 9.0 20000 5.6 .000 .000 .000 .000 .0 176.0 .0 .0 EWR FREQUENCY (HZ): # REMARKS: $ ') # Data Format Specification Record Data Record Type.... .......... ....0 Data Specification Block Type. ....0 Logging Direction..... ... ..... ... . Down Optical log depth units...... .... .Feet Data Reference Point............ ..Undefined Frame Spacing..................... 60 . lIN Max frames per record........... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD040 FT/H Min 13443.5 1. 03 Max 13477 28.64 Mean Nsam 13460.3 68 5.68493 68 First Reading For Entire File... ..... ..13443.5 Last Reading For Entire File.... .... ...13477 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/07/01 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name. .......... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM FET RPD ROP $ # LOG HEADER DATA DATE LOGGED: 7 header data for each bit run in separate files. 5 .5000 START DEPTH 13443.5 13443.5 13443.5 13443.5 13443.5 13443.5 13477.5 STOP DEPTH 13806.0 13820.0 13820.0 13820.0 13820.0 13820.0 13851.0 29-NOV-02 ) First Reading 13443.5 13443.5 Last Reading 13477 13477 - ~) SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type... ..... ... ... ....0 Data Specification Block Type. ....0 Logging Direction.... ... ...... ....Down Optical log depth units.......... .Feet Data Reference Point.... ...... ....Undefined Frame Spacing.. .......... ..... ....60 .1IN Max frames per record.. ..... ..... .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ) Insite 5.3.5 4.3 Memory 13851.0 88.4 95.1 TOOL NUMBER 74165 PB00417R3 3.750 13202.0 Flo Pro 8.70 65.0 9.0 20000 6.6 .250 .094 .160 .300 65.0 183.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13443.5 13851 13647.3 816 13443.5 13851 ROP MWD050 FT/H 1 337.26 86.9678 748 13477.5 13851 GR MWD050 API 30.18 167.85 62.7656 726 13443.5 13806 RPX MWD050 OHMM 4.27 21. 24 10.4973 754 13443.5 13820 ) RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HR 4.75 5.16 7.48 0.27 22.27 22.77 23.28 18.35 First Reading For Entire File.. .... ....13443.5 Last Reading For Entire File.. ..... ....13851 File Trailer Service name....... .... ..STSLIB.007 Service Sub Level Name... Version Number.. ... .... ..1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type......... ...... .LO Next File Name. ........ ..STSLIB.008 Physical EOF File Header Service name.... ... ..... .STSLIB.008 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 8 11.051 11. 2493 12.3433 2.39688 754 754 754 754 ) 13443.5 13443.5 13443.5 13443.5 13820 13820 13820 13820 header data for each bit run in separate files. 6 .5000 START DEPTH 13806.5 13820.5 13820.5 13820.5 13820.5 13820.5 13851.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 14138.5 14153.0 14153.0 14153.0 14153.0 14153.0 14180.0 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 30-NOV-02 Insite 5.3.5 4.3 Memory 14180.0 85.6 91.1 TOOL NUMBER 82758 PB00417R3 3.750 13202.0 ) ') MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.70 65.0 9.5 23000 10.8 .110 .041 .140 .230 65.0 186.0 65.0 65.0 # 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 .1IN Max frames per record. ....... .....Undefined Absent value................. .....-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13806.5 14180 13993.3 748 13806.5 14180 ROP MWD060 FT/H 1. 77 444.34 72.3765 658 13851.5 14180 GR MWD060 API 26.43 101. 69 42.322 665 13806.5 14138.5 RPX MWD060 OHMM 7.38 2000 163.009 666 13820.5 14153 RPS MWD060 OHMM 10.48 618.13 68.7278 666 13820.5 14153 RPM MWD060 OHMM 11. 67 184.14 53.8032 666 13820.5 14153 RPD MWD060 OHMM 8.8 2000 311.103 666 13820.5 14153 FET MWD060 HR 0.31 11. 6 2.0952 666 13820.5 14153 First Reading For Entire File. .........13806.5 Last Reading For Entire File. ........ ..14180 File Trailer Service name.... ........ .STSLIB.008 Service Sub Level Name... Version Number. .... ......1.0.0 Date of Generation..... ..03/07/01 Maximum Physical Record..65535 File Type................ LO Next File Name.... ... ... .STSLIB.009 Physical EOF ) I File Header Service name. .... ....... .STSLIB.009 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. .... ..03/07/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.... ...STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET RAT $ 9 ') header data for each pass of each run in separate files. .5000 6 0 START DEPTH 13628.0 13646.0 13646.0 13646.0 13646.0 13646.0 13676.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 14060.0 14076.0 14076.0 14076.0 14076.0 14076.0 14107.5 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 30-NOV-02 Insite 5.3.5 4.3 Memory 14180.0 85.6 91.1 TOOL NUMBER 82758 PB00417R3 3.750 13202.0 Flo Pro 8.70 65.0 9.5 23000 10.8 .110 .041 .140 .230 65.0 186.0 65.0 65.0 ') ) # Data Format Specification Record Data Record Type. ... ...... ........0 Data Specification Block Type.....O Logging Direction..,.. ........ ... . Down Optical log depth units..... .... ..Feet Data Reference Point.... ..... ... ..Undefined Frame Spacing..................... 60 . UN Max frames per record... ... .... ...Undefined Absent value...................... -999 Depth units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD060 FT/H 4 1 68 4 2 GR MAD060 API 4 1 68 8 3 RPX MAD060 OHMM 4 1 68 12 4 RPS MAD060 OHMM 4 1 68 16 5 RPM MAD060 OHMM 4 1 68 20 6 RPD MAD060 OHMM 4 1 68 24 7 FET MAD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13628 14107.5 13867.8 960 13628 14107.5 RAT MAD060 FT/H 596.25 1642.82 777.827 863 13 67 6.5 14107.5 GR MAD060 API 23.61 118.43 48.7572 865 13628 14060 RPX MAD060 OHMM 4.96 83.32 22.7143 861 13646 14076 RPS MAD060 OHMM 5.64 116.41 33.382 861 13646 14076 RPM MAD060 OHMM 6.03 172 .19 35.4617 861 13 64 6 14076 RPD MAD060 OHMM 10.39 2000 273.764 861 13 64 6 14076 FET MAD060 HR 7.54 30.57 19.0539 861 13 64 6 14076 First Reading For Entire File... ...... .13628 Last Reading For Entire File... ...... ..14107.5 File Trailer Service name.. .... ... ....STSLIB.009 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.. ...... ...STSLIB.OI0 Physical EOF Tape Trailer Service name.. ... ...... ..LISTPE Date.................... .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. .... ... ... ... . UNKNOWN Continuation Number... ...01 Next Tape Name..... ... ...UNKNOWN Conunents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.. ..... ... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... ......... . UNKNOWN Continuation Number. .....01 Next Reel Name........ ...UNKNOWN Conunents.... ...... ... ....STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ") )
