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Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] '----11/7r Sent: Saturday, September 22, 2012 4:49 PM l To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Doran, Zack (Alaska) Cc: AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C); Clingingsmith, Mike J Subject: OPERABLE: V -03 (PTD #2022150) Tubing Integrity Confirmed All, Producer V -03 (PTD #2022150) passed a TIFL on 09/21/2012 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator d 20 p,PR WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@ BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, September 14, 2012 6:47 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field 0: M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GP: East Wells Opt Engr; Doran, Zach; AK, OPS Well Pad LV Cc: AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C) Subject: UNDER EVALUATION: V -03 (PTD #2022150) Sustained Casing Pressur: on IA Above MOASP All, Producer V -03 (PTD #2022150) is confirmed to have sustaine• asing pressure on the IA above MOASP. The tubing /IA /OA pressures were equal to SSV /2040/600 on 09 1/2012. At this time the well is reclassified as Under Evaluation while work is performed to restore inta :rity. The plan forward: 1. Operation: Place well on production 2. Downhole Diagnostics: TIFL once well is tabilized 1 • PriJ z.Z► Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, September 14, 2012 6:47 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Doran, Zach; AK, OPS Well Pad LV Cc: AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C) Subject: UNDER EVALUATION: V -03 (PTD #2022150) Sustained Casing Pressure on IA Above MOASP Attachments: V -03 TIO Plot 09- 14- 12.docx; V- 03.pdf All, Producer V -03 (PTD #2022150) is confirmed to have sustained casing pressure on the IA above MOASP. The tubing /IA /OA pressures were equal to SSV /2040/600 on 09/11/2012. At this time the well is reclassified as Under Evaluation while work is performed to restore integrity. The plan forward: � ,�aWI ED WAY, 0'7 2011 1. Operation: Place well on production 2. Downhole Diagnostics: TIFL once well is stabilized 3. Well Integrity Engineer: Evaluate gas lift valve change out pending TIFL results A TIO Plot and welibore schematic is attached for reference: «V - 03 TIO Plot 09 14 12.docx» «V 03.pdf» i Thank you, S'el Mehreen Vazir SCE 40 r5 BP Alaska - Well Integrity Coordinator ,btTAI z ?ZSU WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator PBP.com 1 PBU V -03 PTD #2022150 9/14/2012 TIO Pressures Plot Well: Va► I — 1 I I 7000 — 4,— Tbp —E— IA - -- OA 2,600 OOA — 4 -- 000A - On 1.000 - I 1 i 06//61 676ft2 C6,2112 06 +30.12 07,'07172 07 14112 0727;72 0712812 08+04112 08/11/12 081472 0825/12 09811/12 09708 +12 1 TREE= 4-1/16" CIW • WELL HEAD= FMC: SA OTES: WELL ANGLE> -70° @ 10138'. ACTUATOR = WA, V -43 KB. ELEV = 82.0', BE ELEV = 53.5'j kOP = 2800'1 Max Angle = 101 ° @ 11,169'1 . r ri --1 964' — 9-5/8' TAM PORT COLLAR 1 Datum ND = Datum ND = SS I r 2208' 4-1/2' HES X1111 D , = 3.813" 1 9 - 5/8' CSG, 40#, L - 80, D = 8 835' H 2751' ■ GAS LFT M4NDRELS ST MD ND DEV TYPE VLV LATCH PORT [ATE Minimum ID = 2.45" Ld'i 9475' , 6 3007 3007 2 KBG-2 DOW Bf< 0 08/08/12 5 3850 3820 23 KBG-2 DONE BK 0 08/08/12 4 -1/2" BKR PATCH 4 5736 5498 34 KBG-2 DOME BK 0 08/08/12 3 7790 ; 7195 34 KBG-2 DOME BK 0 08/08/12 4 - 1/2' BKR PATCH, ID = 2.45' (06/14/07) -- 9475 - 9510' 2 1C, 2 8803 7993 40 KBG-2 SO BK 22 1 °=/08/12 1 9489 8520 41 KBG-2 z "DM Y BK 0 , 01/22/08 rC "'STA #1 = HAS EXT= s •. PACKING AND IS COV ■ BY PATCH I I I 9557' -- 14 HES X NP, 0= 3.813" �� 9568' 7" X 4-1/2" BKR PR£M PKR, D = 3.890' I 1 9595' 4 -1/2' HES X NP, D = 3.813' I 1 9616' 4- 1 /2 " HES XNN',D =3.725' 9619' '-17° X 5" BKR ZXP LNR TOP PKR 1 14 -1/2" TBG, 12:6#, L -80, ,0152 bpf, ID= 3.958" H 9629' I 9629' 741/2' WLEG, D = 4.0" [7' CSG, 26#, L -80, 0383 bpf, ID= 6.276' H 9763' PERFORATION SUMWARY REF LOG SWS MI31 GR/CCL ON 12/30/02 4741p. 7 z so I ANGLE AT TOP "a °': 55° © 10000' '' Note* Refer to Production CB for historical pert data [ 1 0596 — MARKER J7 W/ RA TAG SIZE . SW INTERVAL Opn/Sqz DATE 2 -7/8' 4 10000 - 10124 0 12/31/02 ' 2 -7/8' 4 10124 - 10220 0 12/31/02 1.75" 6 10250 - 10270: 0 08/12/10 1.75" 6 10310 - 10330 0 08/12/10 11111' 1 MARKER JT W/ RA TAG 2 -7/8" 4 10390 - 10460 0 12/31/02 ` 2 -7/8" 4 10590 - 11030 0 12/31/02 135" 6 11050 - 11070 0 08/12/10 ` 11827' [ MARKF32 JT W/ RA TAG 2 -7/8' 4 11119 - 11415 0 12/31/02 ` 1.75" 6 11175 - 11195 0 08/12/10 ` 1.75" 6 11275 - 11295 0 08/12/10 PBTO I— 12505' I 1.75' 6 11355- 11375 0 08/12/10 ` 1.75" 6 11445 - 11465 0 08/12/10 IIMIIM 1.75" 6 11660 -11680 0 08/12/10 *IaMO 2 -718' 4 11700 - 11803 0 12/31/02 *maws 2 -7/8" 6 11803 - 11900 0 12/31/02 2 -7/8" 4 11970 - 12070 0 12/31/02 1.75" 6 11990 - 12010 0 08/12/10 2 -7l8' 4 12184 - 12480 O 12/31/02 I4 -1/2" LAIR, 12. L -80, 0152 bpi, D = 3,958" . 1— 12589' 1.75" 6 12215 - 12235 O 08/12/10 DATE REV BY COMMENTS DATE REV BY ' COMMENTS PRUDHOE BAY UNIT , 12/07102 JCM /KR ORIGINAL COMPLETION 08/30/10 CJC/PJC PERFS (08/12/10) WELL V -03 05/03/07_ MGSTILH GLV 00 & WRP COO CT1ON 08/14/12 RCT /JMD GLV C/0 (08/08/12) PERT M' 022150 06/02/07 DTR/FAG FULL WRP @ 9590 (05/31/07) AR Nr 50-029- 23124-00 06/14/07 RRLYPJC SET BKR PATCH @ 9475' SEC 11, T11N, R11E, 4892' NSL & 1562' WEL 06/25/07 SPF/ PJC GLV CIO & MIN D CORRECTION 02/09/08 TEIIPJC GLV 00 (0122/08) BP Exploration (Alaska) 2.02.21 z. 1 ogvc 24 -AUG -2011 Schhohe�r No. 5782 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 - Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 11 -09A BCRC -00086 PPROF W/ DEFT & GHOST 16-Jul-11 1 1 MPJ -15 BD88 -00141 IPROF 25-Jul-11 1 1 MPJ -18 BCRC -00108 (PROF 24-Jul-11 1 1 MPI -08 BAUJ -00096 (PROF 26-Jul-11 1 1 3- 31/K -32 BBSK -00082 PPROF WI DEFT & GHOST 26-Jul-11 1 1 M -08 BCRJ -00104 SBHPS 8- Aug -11 1 1 01 -28A BUTT -00001 PPROF WI DEFT & GHOST 2- Aug -11 1) 1 01 -28A BUTT -00001 CEMENT BOND LOG 3- Aug -11 1 1 2- 34/P -14 BCRC -00109 IPROF 27-Jul-11 1 1 r''') Z -12 BJGT -00058 IPROF 2- Aug -11 1 1 V -03 W -34A 17 -02 BG4H -00066 SBHPS 29-Jul-11 •11 1 1 BINC -00054 PRIMARY DEPTH CONTROL 26-Jul-11 1 1 1 AWJI -00151 PPROF WIDEFT 14-Jul-11 1 1 A -11 BSM4 -00018 IPROF 1-Aug-11 1 1 Pt -07A AWJI -00152 XFLOW 8- Aug -11 1 1 F -29A BG4H -00072 SBHPS 10- Aug -11 1 1 11 -11 BBSK -00085 PPROF WIDEFT 1-Aug-11 1 1 Z -06 BD88 -00146 TEMP SURVEY 3- Aug -11 1 1 — Z -20 BBSK -00085 SBHPS 31-Jul-11 1 1 MPF -13 BUTT -00003 (PROF 9- Aug -11 1 1 MPL -15 BUTT -00003 IPROF 5- Aug -11 1 1 MPK -33 BJGT -00056 USIT 30Jul -11 i. 1 1 L2-18A AWJI -00153 LEAK DETECTION LOG 11- Aug -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: • BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. • Anchorage, AK 99503 -2838 s age JUN 0 3 M3 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: ~ Name: Development ^ Exploratory ^ ~~ 202-2150 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23124-00-00 8. Property Designation (Lease Number) : ' 9. Well Name and Number: ~ ADLO-028240 PBU V-03 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12591 feet Plugs (measured) None feet true vertical 9015.8 feet Junk (measured) None feet Effective Depth measured 12505 feet Packer (measured) 9568 true vertical 9007.89 feet (true vertical) 8579 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 2724 9-5/8" 40# L-80 27 - 2751 27 - 2751 5750 3090 Intermediate Production 9737 7"26# L-80 26 - 9736 26 - 8707 7240 5410 Liner 2970 4-1 /2" 12.6# L-80 9619 - 12589 8618 - 9016 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# L-80 SURFACE - 9629 SURFACE - 8625 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR PREM PKR 9568 8579 .~, 12. Stimulation or cement squeeze summary: _'~l J ~ ~, 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: 396 428 739 298 Subsequent to operation: 399 432 745 327 14. Attachments: 15. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 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: NA Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 8/25/2010 ~,,,, ,~-T~~~.,,~~ „~~~~ RBDMS AUG ~ 6 1010~~j ~ ~z~ ~~~~~ V-03 202-215 PFRF ATTAf_NMFNT • • Sw Name Perf Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V-03 PER 12/31/02 10,000. 10,220. 8,891.63 8,981.52 V-03 PER 12/31/02 10,390. 10,460. 8,989.23 8,995.48 V-03 PER 12/31/02 10,590. 11,030. 9,007.81 8,968.09 V-03 PER 12/31/02 11,119. 11,415. 8,953.16 8,920.99 V-03 PER 12/31/02 11,700. 11,803. 8,947.16 8,955.95 V-03 PER 12/31/02 11,803. 11,900. 8,955.95 8,963.47 V-03 PER 12/31/02 11,970. 12,070. 8,968.25 8,975.82 V-03 PER 12/31/02 12,184. 12,480. 8,984.38 9,005.78 V-03 BPS 5/30/07 9,590. 12,480. 8,595.54 9,005.78 V-03 BPP 5/31/09 9,590. 12,480. 8,595.54 9,005.78 V-03 APF 8/7/10 11,990. 12,010. 8,969.69 8,971.19 V-03 APF 8/7/10 12,215. 12,235. 8,986.22 8,987.32 V-03 APF 8/8/10 11,355. 11,375. 8,921.47 8,921.04 V-03 APF 8/8/10 11,445. 11,465. 8,921.57 8,922.25 V-03 APF 8/8/10 11,660. 11,680. 8,942.67 8,944.96 V-03 APF 8/9/10 11,175. 11,195. 8,942.72 8,939.06 V-03 APF 8/9/10 11,275. 11,295. 8,927.13 8,925. V-03 APF 8/10/10 10,310. 10,330. 8,987.78 8,987.9 V-03 APF 8/10/10 11,050. 11,070. 8,964.92 8,961.66 V-03 APF 8/11/10 10,250. 10,270. 8,985.04 8,986.4 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • u V-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/1 0/201 0 3T/I/0=240/1400/700. Temp=112°. TIFL (pre acid). On line with AL. Initial IA FL @ 8803' sta# 2, so (155 bbls). Unable to start job due to 1/2" threads in tree cap are bad, call grease crew to replace cap, continue to monitor well. Tree cap ;has been replaced. Out of time for TIFL. Job incomplete SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP 7/11 /2010 T/I/0=280/1400/700. Temp=112°. TIFL PASSED (pre acid). On line with AL. Initial IA FL @ 8803' sta# 2, so (155 bbls). SI wing and AL casing valves. Jumper hose from AL to tree cap and stacked out TBG to 1430 psi in 2.5 hrs. Bled IAP to production from 1280 psi to 330 psi in 1 hr. IA FL unchanged, during bleed TP decreased 30 psi, OAP decreased 40 psi. SI and monitor for 1 hr. IAP increased 50 psi and IA FL remained unchanged. Final WHPs=1410/380/660. Give well back to FO. Job complete SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP 7/16/2010****WELL FLOWING ON ARRIVAL****(pre-ctu-acid) }R/U SLICKLINE FW HP=2500/1500/720 ****CONT JOB ON 7-17-10**** 7/17/2010****CONT JOB FROM 7-16-10****(pre-ctu-acid) DRIFT W/ 2'x 1.50" STEM, 2.48" CENT, 1 3/4" S-BAILER TO 6463' SLM (unable to pass, s-bailer empty) DRIFT W/ 2'x 1.50" STEM, 2.25" CENT, 1 3/4" S-BAILER TO 10190' SLM (stop due to dev). ,DRIFT W/ KJ, 2.35" CENT, 2'x 1.50" STEM, 2.361" GAUGE RING TO 10189' SLM (stop due to dev) FW HP=1000/1500/720 *****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** 8/6/2010CTU 5, 1.75" CT, JOB SCOPE: 200' Adperf, Acid treatment ;Move from SLB yard to V-03. MIRU. Perform BOP test, witnessed by WSL. RIH ~w/ SLB GR/CCL to 12355'. Log up to 11450'. POH. LD logging tool. MU 20' X2.0"pert gun and RIH. Continued on 8/7/2010 8/7/2010 i ASRC Test unit #3, move to V-pad, spot on edge of pad and standby for CTU to 'complete perforating **job in progress** **inlet well V-03, outlet V-106** • • CTU #5 w/ 1.75" CT 200' Add pert/acidize Fin RIH w/ 2.0" pert gun #1 and perforate 12215-12235'. RIH w/ pert gun #2 and perforate 11990-12010'. RIH w/ pert gun #3 Drop 2 balls, no indication of guns firing. POOH to check guns. Perf gun had not fired. Recovered both balls on top of firing pin. Cut off 50' of CT for CT management. RIH w/ MGR/CCL CTU #5 w/ 1.75" CT 200' Add pert/acid stim Log MGR/CCL over 11850-11050'. Rerun pert gun #3 and perforate 11660- 11680'. RIH and perforate gun # 4 11445-11465'. RIH and perforate gun #5 11355-11375'. LD mast. Spot ASRC #3 seperator unit ASRC Test unit #3, unit on-edge of pad and standby for CTU to complete perforating, move in -begin rig up **job in progress"* ''''inlet well V-03, outlet V-106"'' 8/9/2010 CTU #5 w/ 1.75" CT :200' Add pert/acid stim RU ASRC flow cross. Raise mast. RIH w/ MGR/CCL and log from 10950- 11400'. RIH w/ pert run #6 (2" 2006PJ) and pert 11275'-11295'. POOH. RIH w/ lperf gun #7 and perforate 11175-11195'. 8/9/2010°ASRC Test unit #3 rig up complete, standby for CTU to complete perforating I'*job in progress"* **inlet well V-03, outlet V-106"" 8/10/2010ASRC Test unit #3 standby for CTU to complete perforating **job in progress*'" "*inlet well V-03, outlet V-106*" [Well Control Drill] N _ _ ____.-~ - 8/10/20101CTU #5 w/ 1.75" CT X200' Add pert/acid stim ~ RIH and perforate w/gun #8 11050-11070'. Log from 10750 to 9950 with GR/CCI, paint flag at 10205 ft. RIH and perforate w/gun #9 from 10310-10330'. RIH w/ gun #10 8/11 /2010 CTU #5 w/ 1.75' CT 200' Add pert/acid stim Finish RIH w/ pert gun #10 and perforated 10250-10270'. RIH w/ 2.25' nozzle assy Perform first stage of 3 stage. mud acid stim with wax bead diversion. Saw slight whp increase from 200psi to 270 psi. Problems with SLB pump required changing out pump prior to starting stage 2 treatment. DO NOT DELETE REPORT (This is part two of two) • • 8/11 /20101 CTU #5 w/ 1.75" CT 200' Add pert/acid stim ,Finish RIH w/ pert gun #10 and perforated 10250-10270'. RIH w/ 2.25' nozzle 'assy 'Pumped second and third stages of acid job DO NOT DELETE REPORT(This is part one of two) 8/11/2010'ASRC Test urnt #3 standby for CTU to complete perforating/Acid pump schedule **job in progress** **inlet well V-03, outlet V-106** 8/12/2010 ASRC Test unit #3 CTU RDMO. Well POP, begin acid flowback. Well S/I -insert tee in outlet line to V-106, continue flowback **job in progress** **inlet well V-03, outlet V-106** ~w~ _ 8/12/2010 CTU #5 w/ 1.75" 200' Add pert/acid stim Finish acid treatment. POH Turn well over to ASRC. RDMO to W-45 8/13/2010~ASRC Test unit #3 continue acid flowback, pH-5. Shipping liquid returns to tanks **job in progress** ~ **inlet well V-03, outlet V-106** • • 8/16/2010 i `ASRC Test unit #3 continue acid flowback, pH-6. Shipping liquid returns to tanks **job in progress** **inlet well V-03, outlet V-106** -.ASRC Test unit #3 continue acid flowback, pH-6. Shipping liquid returns to tanks **job in progress** **inlet well V-03, outlet V-106** ASRC Test unit #3 continue acid flowback, pH-7. Divert liquids to production, begin increasing inlet choke. **job in progress** **inlet well V-03, outlet V-106** (Well Control Drill) ..~.__~~m®.~~_~ ~.___..._W_ .~..__._____ 8/17/2010,ASRC Test unit #3 stabilize well at full open choke, optimize gas lift rate for lstable flow. Obtain 6 hour test - RDMO **job complete** **inlet well V-03, outlet V-106** 8/19/2010!T/I/O=240/1370/670. Temp=161°. TIFL -PASSED (post-Acid). ALP=Online. Initial IA FL @ 8803' (sta #2, SO) (155 bbls). SI wing & AL casing valves; stacked-out Tbg from 240 psi to 1480 psi in 2 hrs. Bled IAP from 1270 psi to 360 psi in 1 hr. During the bleed the IA FL remained the same, TBG pressure decreased 80 psi, & the OAP decreased 90 psi. SI AL lateral valve & bled the ~AL dogleg simultaneously w/IAP. Monitored for 1 hr, IA FL remained the same, IAP increased 10 psi, ALP increased 190 psi, TBG & OAP remained the same. =Final T/I/0=1400/360/580. ** Note: Well given back to Production. ~** Job is Complete ** ~SV, WV=C. SSV, MV=O. IA, OA=OTG. C~ 8/22/20101T/I/O=920/800/550. Scale Inhibitor Treatment. Pump: Preflush- 30 bbls of 1% !Techni-wet 4353 in 1 %KCI. Scale Inhibitor Slug- 70 bbls of 10% Scaletrol w/ 0.25% Techni-wet 4353 in 1 %KCI. Overflush- 330 bbls of 1 %Techni-wet 4353 "in 1 %KCI. Wax bead diversion- 12 bbls of 450# DS Wax beads in 30# HEC gel. Preflush- 30 bbls of 1 %Techni-wet 4353 in 1 %KCI. Scale Inhibitor Slug- 70 bbls of 10% Scaletrol w/ 0.25% Techni-wet 4353 in 1 %KCI. Overflush- 330 bbls of 1 %Techni-wet 4353 in 1 %KCI. Wax bead diversion- 12 bbls of 450# DS 9 jWax beads in 30# HEC gel. Preflush- 30 bbls of 1%Techni-wet 4353 in 1%KCI. !Scale Inhibitor Slug- 70 bbls of 10% Scaletrol w/ 0.25% Techni-wet 4353 in 1% KCI. Overflush- 330 bbls of 1 %Techni-wet 4353 in 1 %KCI. Tbg displacement- ~ 160 bbls of 1 %KCI. Freeze protection- 30 bbls of diesel. Notified Pad op to gPOP in 12 hours per program. Notified CIC for sampling. FLUIDS PUMPED BBLS 50 50/50 METH 360 1 % KCL W/SAFELUBE 655 NH4CL 87 DIESEL 1152 Total TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR=~ N/A KB. ELEV = 82.0' BF. ELEV = 53.5' KOP = 2800' Max Angle = 101° @ 11,169' Datum MD = Datum TV D = SS 9-518" CSG, 40#, L-80, ID = 8.835" ~~ 2751' (- Minimum ID = 2.45" ~ 9475' 4-1 /2" BKR PATCH 4-1/2" BKR PATCH, ID = 2.45' (06/14!07} 9475' - 9510' ~ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ( 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: SWS MEM GR/CCL ON 12/30/02 ANGLE AT TOP PEf2F: 55 @ 10000' Nate: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10000 - 10124 O 12/31/02 2-7/8" 4 10124 - 10220 O 12/31/02 2-7/8" 4 10390 - 10460 O 12/31/02 2-7/8" 4 10590 - 11030 O 12/31/02 2-7/8" 4 11119 - 11415 O 12/31/02 2-718" 4 11700 - 11803 O 12!31!02 2-7i8" 6 11803 - 11900 O 12!31 /02 2-718" 4 11970 - 12070 O 12/31102 2-7i8" 4 12184 - 12480 O 12131102 V-03 SAFETY ES; HORIZONTAL WELL. 964' ~ 9-5/8" TAM PORT COLLAR 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3007 3007 2 KBG-2 DOME BK 16 01!22/08 5 3850 3820 23 KBG-2 DMY BK 0 01/22(08 4 5736 5498 34 KBG-2 DOME BK 16 01122!08 3 7790 7195 34 KBG-2 DOME BK 16 01/22/08 2 8803 7993 40 KBG-2 SO BK 20 01/22/08 1 9489 8520 41 KBG-2 **DMY BK 0 01/22/08 "*STA #1 =HAS IXTENDm PACKING AND IS COVERED BY PATCH 9557' 4-1 /2" HES X NIP, ID = 3.813" 9616' 9619' 9629' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" X 4-1/2" BKR PREM PKR, ID = 3.890" 4-112" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID = 3.725" 7" X 5" BKR ZXP LNR TOP PKR 4-1/2" WLEG, ID = 4.0'1 MARKER JT W/ RA TAG 11111' I-I MARKER JT W/ RA TAG 11827' I-I MARKER JT W/ RA TAG I PBTD I 12589' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/07/02 JDM/KK ORIGINAL. COMPLETION 05/03107 MGS/TLH GLV C!O & WRPCORRECTION 12131!02 CS/KAK IPERFS 06/02/07 DTR/PAG PULL WRP @ 9590 (05/31/07} 12!31/02 DRS/TP ADD PERF 06/14/07 RRD/PJC SEf BKR PATCH @ 9475' 02/06/03 TLH(TP PERF CORRECTION 06125/07 SPF/ PJC GLV C/O & MIN ID CORRECTION 02/07/07 DRF/TLH GLV C/O (01/30/07) 02/09/08 TEL/PJC GLV C/O (01/22/08) 05/02/07 BSE/PJC SET WRP @ 9590' PRUDHOE BAY UNff WELL: V-03 PERMIT No: "022150 API No: 50-029-23124-00 SEC 11, T11N, R11E, 4892' NSL & 1562' WEL BP Exploration (Alaska) 10/01//01 Schlumaerger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Gemba11 Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 2838 Attn: Christine Mahnken ATTN: Bath 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date 8L Color CD K -11 AY1M -00033 SBHP SURVEY I /_-(t f[ia 09/12/09 1 1 L4-30 AWL8 -00031 PRODUCTION PROFILE ,y' a 08/06/09 1 1 P2 -31 AP3Q -00045 LDL L/ (p -u 07/11/09 1 1 01 -29 B6JE -00009 PRODUCTION PROFILE 08/11/09 1 1 J -22A B69K -00013 PRODUCTION PROFILE g 08/30/09 1 1 W -44 81413-00071 INJECTION PROFILE 1.z ofie 09/06/09 1 1 12 -25 B581-00010 INJECTION PROFILE L a 08/22/09 1 1 15 -33 AYKP -00051 SBHP SURVEY 09/01/09 1 1 lb P2-48 1369K-00015 SBHP SURVEY "rimer! t�� 09/01/09 1 1 2 -28 B69K00016 INJECTION PROFIL ;y 09/19/09 1 1 Q -02A AP3Q -00054 BP/LDL 07!24!09 1 1 N-10A AXBD -00040 M PROD PR FILE a 3 p P, Q 08/25/09 1 1 W -24 AWJI -00044 M INJECTION PROFILE r t 18/15/09 1 1 V03 B2NJ00021 4 J T 09/03/09 1 1 H-14B B2WY -00026 PROD PROFILE 1 08/27/09 1 1 P101 AY1M -00031 N.ECTION PROFILE 6 J. 08/20/09 1 1 P1-05 B581-00009 I. N F .og 08/20/09 1 1 NK -10 B2WY -00023 MEM INJECTION PROFILE 14/ L/ /ts 08/22/09 1 1 13-27A B2NJ-00019 MEMORY SCMT 1 -q 08!13!09 1 1 18.028 B2WY -00021 MEMORY SCMT a 01 08/19/09 1 1 NK -38A AYKP -00049 USIT _t3 4 j 4 08/17/09 1 1 06-09 SWL8 -00028 USIT 44 07/30/09 1 1 13 -03A 09AKA0150 OH MWD/LWD EDIT riIi =�ri Ar l 07/06/09 2 1 1-35/0-25 B69K-00011 1•Ciw! 08/26/09 1 1 04 -35A AXED -00025 MCNL d 69 Aa 05/13/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambol! Street, Suite 400 II 900 E. Benson Blvd. Anchorage, AK 99503 -2835 i1! 1 rJ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 &~~;a'r~: l«f~1ii~ `'~i ~ '•- `'=; ~U~~:s August 14, 2009 n u bp ~~~`f~~~ OCT 0 5 2Q09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Als~ta dil & Gas Cons. ~Q1~~'ti0~'tan Anchorap~ dti~D2.'" `~`. ~~ ~~ o~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad 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) Date V-pad 8/13/2009 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 V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10l2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 12 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-t12 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-t 19 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-201 2012220 5002923054000o SC leak NA 4 NA 90.6 8!7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-2o5 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 500292335oW00 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ",-'~^ 2080200 50029233830000 NA 1.75 NA ~5 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 ~~~ I ~ . STATE OF AlAS~A . ~~....,_AUG 0 9 2007 AlA~ Oil AND GAS CONSERVATION COM~SION þ1'1)1 ¡; G 'ssion REPORT OF SUNDRY WELL OPERA TIO~8ka Oil &. Gas Cons. Comnu D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 82 KB 8. Property Designation: ADLO-028240 11. Present Well Condition Summary: Total Depth measured true vertical 12591 _ feet 9015.8 _ feet Effective Depth measured 12505 /' feet true vertical 9007.89 - feet Casing Length Size Conductor 110' 20" 91.5# H-40 Surface 2724' 9-5/8" 40# L-80 Production 9737' 7" 26# L-80 Liner 2970' 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10000 - 12480 True Vertical depth: 8891.63 - 9006 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations OiI-Bbl 288 287 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphie Stimulate D Other " Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 202-2150 - 6. API Number: 50-029-23124-00-00 9. Well Name and Number: PBU V-03 - 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) None None MD Surface - 110' 27' - 2751' 26' 9736' 9619' - 12589' T~O. Surfacê - 110' 27' - 2751' 26' - 8707' 8618' - 9016' Burst 1490 5750 7240 8430 Collapse 470 3090 5410 7500 SCANNED AUG 1 62007 - - 4-1/2" 12.6# L-80 SURFACE - 9629' 7"X4-1/2" BKR PREM PKR o o o 9568' o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 725 32 0 722 32 0 15. Well Class after oroposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 298 268 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. W INJ WDSPl Contact Gary Preble Signature Title Data Management Engineer Phone 564-4944 Date 8/6/2007 ORIGINAL RBDMS BFL AUG 1.5 20D7 Submit Original Only . . V-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/3/2007 CTU # 8 Con't WSR from 8/2/07 RIH for drift run w/ 2" jsn Tagged up @ 10200' attempt to jet thru w/ 12% HCL.Unable to jet thru spot 15 more bbls of 12% HCL. Unable to get past 10238' w / HCL & jetting POOH for motor & mill.M/U motor & mill. RIH with 2.3" OD mill. Flow well through ASRC test seperator. RIH without seeing any motor work, sending frequent 5 bbls sweeps of 150K LSRV flopro. Continue down to 10620' ctmd. While POOH for short trip, tools became hung up at 10103' ctmd. Pull free from 10116' PUH hang up in patch @ 9515for awhile pull free continue OOH. At surface UD mill BHA & P/U 2" nozzle & checks """"'''''''JOB IN PROGRESS"""""""" 8/3/2007 Test Unit #3, Assist CTU 8/4/2007 T/I/O= 370/900/500 Assist Coil/Load IA Pumped 140 bbls crude down IA FWHP's = 320/0/515 8/4/2007 #8, Acid ... Cont' from 08/03/07... MU and RIH 2.0" OD JSN. Drift with 2.0" nozzle down the bottom at 12495' ctmd. PUH above patch to 9000' ctmd. Flush tubing with 3% NH4CL. While fluid packing well, coil pressured up to pump pressure. Troubleshoot and determine that downhole check valves were probably leaking. Opt to POOH and inspect. At surface and found that coil connector was leaking. Change out BHA. MU and RIH with 2.0" JSN. Underbalance well with diesel. PT all surface equip to 5000 psi & N2 to 6000 acid treatment. ... Cont' on WSR 08/05/07 ... Test Unit #3, assisting acid w/flowback 8/5/2007 #8, ... Cont' from 08/04/07 ... pumping 60 stage acid stimulation over 11 intervals as per procedure. Stimulated perf intervals with a total of 225 bbls of 9:1 mud acid and 225 bbls of 12% HCL. Each interval consisted of 5 stages: starting with 12% HCL followed by 9: 1 mud acid, 3% NH4CL with L66 scale inhibitor overflush, foam diverter (70% quality) with oilseeker, and a 3% NH4CL spacer. Observed a gradual increase in WHP as each diverter stage entered the perfs. POOH while pumping diesel down the backside to replace voidage. Turn well of to ASRC for acid flowback. RDMO. *** Job Complete *** FLUIDS PUMPED BBLS 30 DIESEL 225 9:1 MUD ACID 225 12% HCL 480 TOTAL ~ I \.I-VI-I " I-LJ . STATE OF ALASKA .~.;JS~ JUN 2 1 2007 ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERA TIONSaska Oil & Gas Cons. Commission o o o -C~ JI/J.""'" 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 82 KB 8. Property Designation: ADlO-028240 11. Present Well Condition Summary: Total Depth measured 12591 ' feet true vertical 9015.8 . feet Effective Depth measured 12505 feet true vertical 9007.89 . feet Casing length Size Conductor 110' 20" 91.5# H-40 Surface 2724' 9-5/8" 40# l-80 Production 9737' 7" 26# l-80 Liner 2970' 4-1/2" 12.6# l-80 Perforation depth: Measured depth: 10000' - 12480' True Vertical depth: 8892' - 9006' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl Shut in Shut in x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Tubing Stimulate 0 Other Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2150 . r Exploratory Service 6. API Number: 50-029-23124-00-00 / 9. Well Name and Number: V-03 /' 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) None Junk (measured) None SCANNED JUL 06 2007 MD Surface - 110' 27' 2751' 26' - 9736' 9619' - 12589' TVD Surface - 110' 27' - 2751' 26' - 8707' 8618' - 9016' Burst 1490 5750 7240 8430 Collapse 470 3090 5410 7500 4-1/2" 12.6# l-80 Surface - 9629' 7"x4-1/2" bkr prem pkr o o o 9568' o o o RBDMS BFL JUl 0 6 2007 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory r Development P' 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure o o Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Contact Gary Preble Signature Form 10-404 Revised 04/2006 Title Data Management Engineer Phone 564-4944 Date 6/20/2007 Át-~(<o Submit Original Only . . .-~ ."- V-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/14/2007 ****V-03 SBHPS, PATCH**** WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 150/1650/400 CURRENTLY RUNNING STATIC PRESSURE SURVEY AT 9984' AND 9836'. JOB IN PROGRESS. ****JOB CONTINUED ON 06-15-07 AWGRS**** 6/14/2007 *** JOB FROM PREVIOUS DA Y*** WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 150/100/400 RUN STATIC PRESSURE SURVEY AT 9984' AND 9836' PRESSURE AT 9984' = 3312 PSI PRESSURE AT 9836' = 3277 PSI SET BAKER PATCH OVER GLM#1 FROM 9475'-9510' MID-ELEMENT TO MID- ELEMENT SHUT IN UPON COMPLETION OF JOB. FINAL T/I/O: 150/100/400 **** JOB COMPLETE**** FLUIDS PUMPED BBLS I 1 DI ESEL 1 TOTAL Schlumberger NO. 4290 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 Z007 Comm\5$iQjfj Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay o BL CI CD Well Job# Log DescriptIon ate o or L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-0BA 11686747 LDL OS/20/07 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE OS/22/07 1 04-10 11594498 LDL 05/19/07 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A N/A LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 <:rf-"'NNE(J JUN 2 1 2007 900 E. Benson Blvd. ..,uru Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: r____ -- Date Delivered: --- ~Ód- -8-'5 ~~ 06/07/07 . . . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker.doc Permit to Drill 2022150 MD 12591.-" ---------- ~-...~-~---- -- '> { J O'v"' )..Ò~ , DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 5fJ(Ad I~ NêifMV{~ API No. 50-029-23124-00-00 Well Name/No. PRUDHOE BAY UNIT V-03 Operator BP EXPLORATION (ALASKA) INC TVD 9016 /" Completion Date 12/31/2002 / Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFORMATION Samples No Mud log No Directional Survey Q --------- ------~---~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, PWD, RES, Memory GR, CCl (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type./Med/Frmt Number Name ~----- See Notes ~rr~"-rr' E.D.",-,'c Rpt % C Tf ,g5. C Pds ..¿ ,log itXog "s;y C Pds -~--~-~- Log Log Run Scale Media No Blu 1 Interval OH / Start Stop CH Received Comments 9440 10237 Case 3/25/2003 Static Survey - PresslTemp with Jewelry log ~ .~ ~éctional Survey £;t1592 See Notes Directional Survey 0 12591 Open 12/12/2002 9408 12504 Open 3/7/2003 Digital Well logging Data 0 12591 Open 12/12/2002 108 12591 Case 8/25/2003 lDWG edit of lWD ARC and PowerPulse Ù7137 LIS Verification '1-2137 Induction/Resistivity Induction/Resistivity 25 108 12591 Case 8/25/2003 25 Blu 108 12591 Case 8/25/2003 25 Blu 108 12591 Case 8/25/2003 25 108 12591 Case 8/25/2003 Vision Resistivity Vision Resistivity See Notes Vision Resistivity-MD Borehole Profile Vision Resistivity-MD Borehole Profile A137 See Notes Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION y~ Daily History Received? (~N 7f>N Chips Received? Analysis Received? --------_._~ -----.'~------------ ~ Formation Tops , Y II" DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022150 Well Name/No. PRUDHOE BAY UNIT V-03 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23124-00-00 MD 12591 TVD 9016 Completion Date 12/31/2002 Completion Status 1-01L Current Status 1-01L UIC N Comments: Compliance Reviewed By: ~ Date: I «4 ~ f ,-~.~---~~-------~~---- __F_~--_--~"._------- '~ -- tjô&- -é9 \5 08/20/03 Sc~lullbe'øep NO. 2949 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ Well Job# Log Description Color Date Blueline Prints CD 12/05/02 1 /ô J~~-t 12/05/02 1 12/05/02 1 12/05/02 1 V-03 V-03 V-03 V-03 22539 LDWG EDIT ARC & POWERPULSE 22539 MD VISION RESISTIVITY 22539 TVD VISION RESISTIVITY 22539 MD BOREHOLE PROFILE ~, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Date Delivered: Ä' , I r-. r>.. r £11\ f\ 7- \v~ ,: ~~¡ LtiVv J..\IaSt\~ (J~ CommiMioo Received ~~-, ,~,(~ C~~/V\. AnC'íiijfag~ 2- Schlumbspgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 ATTN: Beth Well A-20 f <¿d ~OJ3 PWDW2-1 J Î '" -:Olr .~ V-03 ~œ-a I ~ 1-51N-20 ¡q;J -IJ q R-14A ~- i~~ R-14A R-14A R-14A ~/ Job# Log Description GLS LDL STATIC SURVEYITEMP/PRESS INJECTION PROFILE 23086 LDWG EDIT ARC RESISTIVITY DATA 23086 MD VISION RESISTIVITY 23086 TVD VISION RESISTIVITY 23086 MD VISION RESISTIVITY (BHP) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: r . ;/"""'"r-\\¡rrD. . R- 1'"..w! -;;- HI F"'. . $ ¡¡"",.,.v~' '#-. r :- ''''''''17- MAK Z v LUVV .A1a~ka Or: & Gas Cons. Commi~n Anchorage 03/18/03 NO. 2702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott Color Date Blueline Prints CD 03/05/03 1 02107/03 1 03/03/03 1 03/07/03 1 11/11/02 11/11/02 1 11/11/02 1 11/11/02 1 ~' ~~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receiv~d¥. L~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well L-02 ?/?,-aD7 2-32/SN-03 l ( ()- J ~ 2-22/L-14 j~ ,,08 'i D.S.7-22 <=6 ~""Ot-~ 9 V-03 ~_rlI5 Job# Log Description Date TEMP/PRESS PROFILE LDL INJECTION PROFILE 23023 RST-SIGMA 23082 PERF MGRlCCL 02/16/03 03/04/03 03/02/03 12/16/02 12/30/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: - BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED t"'AR 0 7 2003 Ala!i<! Oii & Gas Cons. eommi!8ton Anchorage Blueline NO. 2691 Company: 03/06/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK. 99501 Field: Prudhoe Bay Sepia Color Prints 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth Reœ~ CD '-" -"~ I~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of Well Ia Oil 0 Gas 0 Suspended 0 Abandoned r..[J,SelYjç~L. ",=. .,._, 2. N:;~';::I~~~:t~~laSka) Inc. '.'.~, :.,:.¿~..:-.~.j..:,~¡\t..~.:.. 7. ~~~~1~umber 3. Address .t' ~~" ¡ ~, .1 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ",~,:", .. ~~.~1!Ø.J~ "'m'~~' 50-029-23124-00 ~:..'~' ~:"("m. . - . ..'. > .,.. .... ",,,,.,,..... '...' .~..: 4. Location of well at surface . . 9. Unit or Lease Name 4893' NSL, 1562' WEL, SEC. 11, T11 N, R11 E, UM X = 590739, Y = 5970142 Prudhoe Bay Unit At top of productive interval 1619' NSL, 1399' EWL, SEC. 01, T11N, R11E, UM X = 593673, Y = 5972184 10. Well Number -. At total depth W ~, 3539' NSL, 306' W,ø:, SEC. 01 , T11 N, R11 E, UM X = 592555, Y = 5974091 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB = 82' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/12/2002 I 11/29/2002 . 12/3112002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12591 9016 FT 12505 9008 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, PWD, RES, Memory GR, CCL Classification of Service Well V-03 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2208' MD 1900' (Approx.) 23. CASING SIZE 20" 9-5/8" WT. PER FT. 91.5# 40# 26# 12.6# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM Size Surface 108' 42" 27' 2751' 12-1/4" 26' 9763' 8-1/2" 9619' 12589' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 467 sx Permafrost 'L'I 298 sx 'G' 605 sx Class 'G', 249 sx 'G' 303 sx Class 'G' AMOUNT PULLED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 4 spf 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 10000 - 10124' 8892' - 8954' 11803' - 11900' 8956' - 8963' 10124' - 10220' 8954' - 8981' 10390' - 10460' 8989' - 8996' 10590' - 11030' 9008' - 8968' 11119' - 11415' 8953' - 8921' 11700' - 11803' 8947' - 8956' 11970' - 12070' 8968' - 8976' 12184' - 12480' 8984' - 9006' SIZE 4-1/2", 12.6#, L-80 TUSING RECORD DEPTH SET (MD) 9629' PACKER SET (MD) 9568' 25. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 8, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL 1/9/2003 4 TeST PERIOD 4,529 Flow Tubing Casing Pressure CALCULATED OIL-BSL Press. 24-HoUR RATE GAs-McF 3,346 GAs-McF WATER-BsL 192 WATER-BsL CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 739 ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core <ìfJp~;: ~ \, No core samples were taken. Form 10-407 Rev. 07-01-80 RBOMS 8Fl t. ~FEB j I ~tv Submit In Duplicate ,) Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu Ugnu M Schrader Bluff N Schrader Bluff 0 Base Schrader I Top Colville HRZ Kalubik 2953' 40571 4318' 4496' 4908' 6776' 7011' 2952' 4010' 4252' 4418' 4799' 6360' 6556' Kuparuk D Kuparuk C Kuparuk B Kuparuk A 7095' 7098' 7214' 7356' 6626' 6628' 6722' 6836' Miluveach Kingak Sag River Shublik Eileen Sadlerochit 7450' 8550' 9725' 9773' 9949' 9990' 6913' 78011 8699' 8735' 8861' 8886' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble -iO~ ~ ~ Title Technical Assistant Date O~. o&,.. O\..~ V-03 202-215 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Phil Smith, 564-4897 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. ITEM 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 for 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. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: V-03 Common Name: V-03 Test Date 11/15/2002 11/23/2002 LOT FIT Test Type Test Depth (TMD) 2,751.0 (ft) 9,763.0 (ft) BP EXPLORATION Leak-Off Test Summary TesfDepth (TVP) 2,751.0 (ft) 8,729.0 (ft) AMW 9.70 (ppg) 9.20 (ppg) SurfacePrêssure 670 (psi) 620 (psi) .l..eêÌl{QffF>reØ$Ûr~(~tiP) 2,056 (psi) 4,792 (psi) Page 1 of 1 EMW 14.39 (ppg) 10.57 (ppg) "'~ ~ Printed: 12/9/2002 9:03:52 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 11/12/2002 02:30 - 04:30 04:30 - 07:30 07:30 - 14:00 14:00 - 15:30 15:30 - 16:30 16:30 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 00:00 11/13/2002 00: 00 - 08: 30 08:30 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 17:00 17:00 - 18:00 18:00 - 19:00 11/14/2002 19:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 06:30 06:30 - 07:00 07:00 - 10:30 10:30 -14:30 14:30 -16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 21 :00 21 :00 - 00:00 11/15/2002 00:00 - 00:30 Phasé 2.00 MOB P 3.00 RIGU P PRE PRE 6.50 RIGU P PRE 1.50 RIGU P PRE 1.00 DIVRTR P SURF 2.50 DRILL P 0.50 DRILL P 0.50 DRILL P SURF SURF SURF 4.00 DRILL P SURF 8.50 DRILL P SURF 1.00 DRILL P 1.00 DRILL P 1.00 DRILL P 5.50 DRILL P SURF SURF SURF SURF 1.00 DRILL P 1.00 DRILL P SURF SURF 1.00 DRILL 1.00 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 1.50 CASE SURF SURF SURF SURF SURF SURF P P P P P P 4.00 CASE P SURF 0.50 CASE P 3.50 CEMT P 4.00 CEMT P SURF SURF SURF 2.00 CEMT P SURF 1.50 CEMT P 0.50 CEMT P 2.50 BOPSURP 3.00 BOPSUR P SURF SURF INT1 INT1 0.50 BOPSUR P INT1 Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Move rig from V-109 to V-03 Rig Up on V-03. N/U Diverter, Remove ladder on off-set well house. Rig up inter - connect lines. ACCEPT RIG @ 07:30 HRS. Take on water. Shorten Div. riser. Complete N/U Diverter. Change Boot to 20". Mix Spud Mud. Cut & Slip 75' of Drilling Line. Service Top Drive, Blocks & Crown. Bring BHA #1 to Floor. Function Teat Diverter. Witnees of test waived by Lou Grimaldi, AOGCC. P/U & MIU BHA #1. Pre Spud Metting with all Personnel. Fill Surface Lines & Hole. Circulate & Check for leaks. Shallow test MWD. Spud Well. Drill from 108' to 446'.690 GPM @ 1400 psi. Rotate All - 2.25 Hrs. Drill from 446' to 1653'. 665 GPM @ 2240 psi. 80 RPM TO. = 5K, PU = 85K, ON = 85K, ROT = 94K AST = 0.80 Hrs. ART = 6.7 Hrs. Circulate Weighted Sweep - 665 GPM & 90 RPM. Wipe Hole to 260'. Tight @ 1020'. Wipe twice - OK. RIH to 1560'. Wash last stand to bottom - No Fill. Drill from 1653' to 2765' - TD. 675 GPM @ 3010 psi. TO = 4K PU = 98K, DN = 94K, ROT = 96K. ALL ROT. = 3.71 HRS. Circulate Weighted Sweep. Wipe Hole to 906'. Max 20K over - pull up to 1653'. Clean above. RIH to 2660'. Wash last stand to bottom - No Fill. Circulate weighted Sweep. POH - 20K over-pull @ 1830. Work through - OK. Stand back HWDP & DC's. Flush Anadrill Tools. LID MWD. Complete LID BHA # 1, Clear & Clean Rig Floor. Rig Up to run 9 5/6" Surface Casing. P/U Hanger & Landing Jt., Make dummy run. Run 66 Jts. 95/8" casing as per program to 2750'. No Mud Losses. Rig Down fill up tool, R/U Cement Head Circulate & Condition Mud for Cement Job = 14 YP. PJSM with all Hands. Switch to HOWCO. Pump 10 bbls. water, Test lines to 3500 psi., Pump 10 bbls water. Pump 75 bbls 10.0 ppg Alpha Spacer. Drop bottom plug then pump 342 bbls (465 sx) 10.7 ppg, Permafrost' L' lead Slurry followed by 61 bbls. (300 sx) 15.8 ppg Premium' G' Tail Slurry. Drop Top Plug and allow Howco to displace lines wi 10 bbls water. Switch to Rig pumps and displace wi 192 bbls Mud. Bump Plug wi 500 psi over. Check Floats - OK. 80 bbls. good Cement to surface. Rig Down Cement Head. Flush stack ect. LID Landing Jt. Clear floor of Casing equip. C/O Bails. N/D Diverter System and remove from cellar. N/U Split Speed head. Test Metal to Metal Seal to 1000 psi. N/U 13 5/8" BOPE. R/U Test Equip. Test BOPE - 250 14000 psi. - 3500 Annular. Witness waived by John Crisp, AOGCC. Complete testing BOPE. Printed: 12f9f2002 9:04:01 AM ') ') Legal Well Name: V-03 Com mon Well Name: V-03 Spud Date: 11/12/2002 Event Name: DRILL +COMPLETE Start: 11/12/2002 End: 12/7/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/7/2002 Rig Name: NABORS 9ES Rig Number: 9ES Date FrOm- To Hoùrs 11/15/2002 00:30 - 01 :00 0.50 BOPSUR P INT1 RID Test Equip. Install Wear Bushing. 01 :00 - 09:00 8.00 DRILL P INT1 P/U & Stand Back 229 Jts. 4" DP. 09:00 - 11 :30 2.50 DRILL P INT1 P/U & M/U BHA # 2. RIH & shallow test MWD. 11 :30 - 13:00 1.50 DRILL P INT1 Cut & Slip Drilling Line. Service Top Drive. 13:00 - 14:00 1.00 DRILL P INT1 RIH, pickig up singles from shed, to 2450'. 14:00 - 15:00 1.00 CASE P INT1 R/U & Test Casing to 3500 psi. for 30 minutes. RID Test Equip. 15:00 - 16:30 1.50 DRILL P INT1 Wash Down, tag cement @ 2660'. Drill Cement, Float, Shoe & Cleanout rathole. Drill 20" of new hole to 2785'. 16:30 - 17:00 0.50 DRILL P INT1 Displace hole with new 9.7 ppg. LSND Mud. 17:00 - 17:30 0.50 DRILL P INT1 Perform LOT to 14.38 ppg EMW. 17:30 - 18:00 0.50 DRILL P INT1 Circulate & Obtain initial Benchmark ECD readings. Clean hole ECD @ Drilling circ. rate & RPM calculates to 10.12 ppg 18:00 - 00:00 6.00 DRILL P INT1 Drill from 2785' to 3663'.590 GPM @ 2340 psi. TO = 3.5 K P/U = 117K, DN = 105K, ROT = 108K AST = 1.75 Hrs. ART = 0.88 Hrs Calc. ECD = 10.13. Avg. ECD while drilling = 10.45 Backream each stand, Lo I Hi Vis Sweep every 300'. 11/16/2002 00:00 - 22:30 22.50 DRILL P INT1 Drill from 3663' to 6558'. 590GPM @ 3560 psi. TO = 7 P/U = 156K DN = 130K ROT = 142K, 100 RPM, 10 -15K WOB Weight Up Mud to 10.3 ppg. wI spike fluid while drilling last stand. Still sweeping every 300' and backreaming prior to connections. AST = 6.22 Hrs. ART = 7.08 Hrs. Calculated ECD wI 10.3 ppg mud = 10.78, Actual = 11.19 22:30 - 23:30 1.00 DRILL P INT1 Circulate Hi Vis Sweep. ECD = 11.06 ppg. 23:30 - 00:00 0.50 DRILL P INT1 Monitor well, Begin Wiper trip to shoe. 11/17/2002 00:00 - 02:30 2.50 DRILL P INT1 Wiper Trip to Shoe. Attempting to swab intermittently - 1st 9 Stands with 15 to 20 K Over-pull. Wiped stand second time - OK. Pulled total 41 stands. Hole in good shape. 02:30 - 04:30 2.00 DRILL P INT1 Service Top Drive, Crown & Draw-works. Change lube filter, adjust brakes, change out & test swivel packing. 04:30 - 06:00 1.50 DRILL P INT1 RIH to 6464'. No problems. 06:00 - 07:30 1.50 DRILL P INT1 Wash last stand to bottom & circulate Hi-Vis sweep. 07:30 - 00:00 16.50 DRILL P INT1 Drill from 6558' to 8148'.590 GPM @ 3960 psi TO = 6 to 9 K. P/U = 178K DN = 146K ROT = 160K 100 RPM 25K WOB. Hi - Vis Sweeps every 300', Backream 30' every stand. AST = 4.1 Hrs. ART = 6.4 Hr Calc. ECD = 10.76 ppg Avg. ECD while Drilling = 11.1 ppg. Reservoir meeting with both Crews & Service Hands. 11/18/2002 00:00 - 20:30 20.50 DRILL P INT1 Drill from 8148' to 9765'.570 GPM @ 4100 psi. TO = 8 to 10K P/U = 218K DN = 152K ROT = 178K WOB = 15 - 25K, 100 RPM. Calc. ECD = 10.94ppg. Drlg. ECD = 11.17 ppg. AST = 8.57 Hrs. ART = 6.03 Hrs. Hi-Vis Sweep every 300'. 20:30 - 22:30 2.00 DRILL P INT1 Circulate up samples for Geologist - In SAG River- TD. 22:30 - 00:00 1.50 DRILL P INT1 Monitor Well - Wiper Trip to 6350' ( incomplete) - Hole in great shape - No Drag - No Swab. 11/19/2002 00:00 - 00:30 0.50 DRILL P INT1 Complete Wiper - POH to 6270'. Hole in Great Condition. 00:30 - 01 :30 1.00 DRILL P INT1 RIH to 9702'. No Problems. 01 :30 - 03:30 2.00 DRILL P INT1 Wash to bottom. Circ. Hi-Vis Sweep. Spot Shale Inhibiting Pill. 03:30 - 05:30 2.00 DRILL P INT1 POH to 5158'. No Drag - No Swabbing. Hole Clean. 05:30 - 06:30 1.00 DRILL P INT1 Spot" Steel Seal" Pill across Schrader. 06:30 - 08:30 2.00 DRILL P INT1 Continue POH to BHA. Printed: 12/9/2002 9:04:01 AM ') ') Legal Well Name: V-03 Common Well Name: V-03 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Daté From ~ To Hours Task Code NPT 11/19/2002 08:30 - 11 :00 2.50 DRILL P INT1 11 :00 - 12:00 1.00 CASE P INT1 12:00 - 13:30 1.50 CASE P INT1 13:30 - 14:30 1.00 CASE P INT1 14:30 - 15:00 0.50 CASE P INT1 15:00 - 00:00 9.00 CASE P INT1 11/20/2002 00:00 - 11 :30 11.50 CASE P INT1 11 :30 - 20:00 8.50 CASE N DPRB INT1 20:00 - 00:00 4.00 CASE P 11/21/2002 00:00 - 02:30 2.50 CASE P INT1 02:30 - 07:00 4.50 CASE N DPRB INT1 07:00 - 08:30 1.50 CASE P INT1 08:30 - 09:00 0.50 CASE P INT1 09:00 - 13:00 4.00 CEMT P INT1 13:00 - 16:30 3.50 CEMT P INT1 16:30 - 17:30 17:30 - 18:30 1.00 CEMT P 1.00 CEMT P 18:30 - 20:00 20:00 - 00:00 1.50 CEMT P 4.00 CEMT P INT1 INT1 INT1 INT1 INT1 Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Descri ption ofOþératiÞns Stand Back HWDP, Lay Down BHA. Clear & Clean Floor. M/U ported Jet Tool, Flush Stack & Riser. Pull Wear Ring. Install test Plug. cIa Top Rams to 7". Test Bonnet seals to 3500 psi. R/U to run 7" Casing. PJSM with all Hands. Run 7" Intermediate Casing as per Program - 1.5 min per Jt., Circ for 15 min. every 15 Jts. & CBU every 30 Jts. 100 Jts Ran with no Mud loss. Continue running 7" casing. Circ pipe down as per plan. Pipe displacement correct - no losses. Pipe started taking weight at 8630' on Jt #212. (Approx 80' in to Kingak). PU & try to break circ using Franks tool. Hole packed off almost immediately. Bleed off pressure and work pipe free. No Circ. - Packing off. Pull out & LID 3 Jts. Est. Circ @ 8485'. Attempt to go down - packed off. Pull out wI 5 more Jts to 8320'. Stage up pumps to 7 BPM @ 860 psi. CBU. RIH circ each Jt to 8415' starting to pack-off, work pipe and regain full circ. Continue RIH with Casing, circulating every Jt down @ 5 BPM 680 psi. Running 4' to 5' per minute. Running smoothly, taking no weight and not packing off. 216 Jts ran @ 8814'. Note: All the time circulating - saw very little shale over shakers - mostly sand and NOT copious amounts. Run 7" Casing to 9330', circulating down every Jt. Packed off while Circ. prior to conn. POH to 9170' to re-establish circulation. Circ. to clean hole. Run casing to TD @ 9765'. RID Fill Up Tool, R/U Cement Head. With Shoe @ 9763: Establish Circulation. Stage up to 6 BPM @ 793 psi. Switch to HOWCO. Pump 5 Bbls KCL water & test lines to 4000 psi. Pump 30 Bbls, 11.0 ppg. ALPHA Spacer. Load & launch 1 st. stage By-Pass Plug & Pump 125 Bbls 15.8 ppg., "G" class, CBL Cement. Close Annular & Load 1 st. Stage Shut-Off Plug. Open Annular & kick out plug wI 10 bbls water from HOWCO to clear their lines. Switch to Rig Pumps & displace. Hole packed off after pumping 265 Bbls Mud. worked Casing & regained partial returns. Continued pumping & bumped plug with 2400 psi. bleed pressure - Float OK. Pressure up to 3180 psi to open ES Cementer. Circulate through ES Cementer @ 6.5 BPM and 430 psi. Switch back to HOWCO. Pump 5 bbls. KCL water, then 25 bbls. 11.0 ppg ALPHA Spacer. Pump 54 bbls, 15.6 ppg, LXT Cement. Release Closing plug. Displace with 195 bbls Mud. Bump and Close ES Cementer wI 2100 psi. Bleed presure & confirm ES cementer closed. No Mud Losses throughout Job. Cement in Place @ 18:30 HRS. RID and Off-Load from floor all Cement and Casing Equipment. wac - While wac; cIa valves & seats on #2 Pump, service Mud Manifold Choke & Stack. cIa & Test 2" Demco valve on Mud Manifold & Test. Clean Pits. Inject 30 bbls Mud Down 7" X 9 5/8" Annulus. Broke down @ 500 psi. FCP = 575 psi. 4 bbls Printed: 12/9/2002 9:04:01 AM ) ) Legal Well Name: V-03 Common Well Name: V-03 Spud Date: 11/12/2002 Event Name: DRILL +COMPLETE Start: 11/12/2002 End: 12/7/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/7/2002 Rig Name: NABORS 9ES Rig Number: 9ES Date From"- To Hours 11/21/2002 20:00 - 00:00 4.00 CEMT P INT1 bled back. 11/22/2002 00:00 - 01 :00 1.00 CASE P INT1 N/D BOPE 01 :00 - 02:30 1.50 CASE P INT1 Set Emergency Slips with 120K Ibs. of Tension on Casing String. Cut & bevel Casing. 02:30 - 03:30 1.00 CASE P INT1 Install Pack-Off. Set Stack. R.I.L.D.S. Test P/O to 4325 psi. 03:30 - 05:00 1.50 CASE P INT1 N/U BOP. Change Top Rams to 3.5" X 6" Variables. 05:00 - 08:00 3.00 CASE P INT1 Test BOPE to 250 - Low, 4000 psi. High, Annular to 3500 psi. Witness of Test waived by John Spaulding, AOGCC. RID test equipment. Install Wear Bushing. 08:00 - 10:00 2.00 DRILL P PROD1 P/U & M/U BHA #3. 10:00 - 11 :30 1.50 DRILL P PROD1 Cut & Slip Drilling Line 75 ft. Service Top Drive 11 :30 - 15:30 4.00 DRILL P PROD1 Pick up Dp from Shed & RIH to 5000'. 15:30 - 17:00 1.50 DRILL P PROD1 Wash Down & Tag Cement @ 5065'. Drill Cement, Tag ES cementer @ 5102'. Drill out. 17:00 - 18:30 1.50 DRILL P PROD1 RIH to 9505'. 18:30 - 20:00 1.50 DRILL P PROD1 Circulate & Test Casing to 4000 psi. for 30 Minutes. 20:00 - 21 :30 1.50 DRILL P PROD1 Wash Down & tag Cement @ 9658'. Drill Cement, LlC, FIC & Shoe. C/O Rat Hole to 9765. 21 :30 - 22:00 0.50 DRILL P PROD1 Circulate Bottoms Up - Clean Hole. 22:00 - 23:30 1.50 DRILL P PROD1 Pump Sweep & Displace well with 9.2 ppg., 7 % KCL BARADRILLn Mud 23:30 - 00:00 0.50 DRILL P PROD1 Monitor Well, Clean Possum Belly, Under Shakers, Trough & Suction Pit. 11/23/2002 00:00 - 02:00 2.00 DRILL P PROD1 Clean Pits for New Mud. Change Shaker Screens 02:00 - 03:00 1.00 DRILL P PROD1 Circulate EP Mud Lube Sweeps. 03:00 - 03:30 0.50 DRILL P PROD1 Drill 20' of New Hole to 9785'. 03:30 - 04:00 0.50 DRILL P PROD1 Circulate Bottoms Up. 04:00 - 04:30 0.50 DRILL P PROD1 Perform FIT to 10.57 ppg. EMW. 04:30 - 05:00 0.50 DRILL P PROD1 Take ECD Baseline Readings. 40 RPM I 300 GPM = 10.27 ECD 05:00 - 00:00 19.00 DRILL P PROD1 Drill 6 1/8" Directional Hole from 9,785' to 10,050'. 300 GPM @ 2650 psi. P/U = 187K On = 150K ROT = 168K TQ = 5300 Calc. ECD = 10.24 Drlg. ECD = 10.42. AST = 9.74 Hrs. ART = 3.93 Hrs. NOTE: Hole started taking fluid @ 9889'. Worst loss was 23 BPH. Added Barafiber. Losses down to 4 BPH. Total lost to Hole = 89 Bbls. 11/24/2002 00:00 - 03:30 3.50 DRILL P PROD1 Slide from 10,050' to 10,096'. Difficult to keep differential on bit. Not making needed build. AST = 1.06 Hrs. 03:30 - 04:00 0.50 DRILL P PROD1 Unable to slide. CBU - No Losses. 04:00 - 08:30 4.50 DRILL P PROD1 POH - Stop at 7" shoe and observe well for 10 minutes. Continue POH. 08:30 - 10:30 2.00 DRILL P PROD1 C/O Bit & Motor Stab. Down Load LWD. 10:30 - 18:30 8.00 DRILL P PROD1 RIH to 2500'. Fill pipe - Gas Cut Mud to Surface. Stage in Hole. CBU @ 2600',5100',7450',8293',9039' & Shoe @ 9763'. 18:30 - 19:30 1.00 DRILL P PROD1 Wash to bottom @ 10,096'. No Gas Cut Mud. 19:30 - 00:00 4.50 DRILL P PROD1 Slide from 10,096' to 10,251'. Raise Mud Weight to 9.3 ppg. Achieving desired angle & direction at good ROP. 300 GPM @ 2400 psi. 30K - WOB P/U = 191 K DN = 153K ROT = 170K "0" Losses 11/25/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Slide from 10,251' TO 10,346'. Angle and Direction made indicates tripping for 1.5 Deg Motor & PDC Bit necessary. 01 :30 - 02:30 1.00 DRILL P PROD1 Circulate Bottoms Up & weight Mud up to 9.4 ppg. for Trip Printed: 12/9/2002 9:04:01 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) Page50f9 Bp.EXPLORATION 9peràtion$ Summary RepQrt V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From ~ To Hours Task Code NPT Phase 11/25/2002 01 :30 - 02:30 02:30 - 07:30 07:30 - 09:00 09:00 - 12:30 12:30 - 14:00 14:00 - 16:00 16:00 - 00:00 11/26/2002 00:00 - 00:00 11/27/2002 00:00 - 00:00 11/28/2002 00:00 - 19:00 19:00 - 23:30 23:30 - 00:00 11/29/2002 00:00 - 11 :00 11 :00 - 11 :30 11 :30 - 14:00 1.00 DRILL P 5.00 DRILL P 1.50 DRILL P PROD1 PROD1 PROD1 3.50 DRILL P 1.50 DRILL P PROD1 PROD1 2.00 DRILL P PROD1 8.00 DRILL P PROD1 24.00 DRILL P PROD1 24.00 DRILL P PROD1 19.00 DRILL P PROD1 4.50 DRILL P PROD1 0.50 DRILL P PROD1 11.00 DRILL P PROD1 0.50 DRILL P I PROD1 2.50 DRILL P PROD1 Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 DescriptiOn of Operations Margin POH UD PWD, MWDI LWD, Motor & Bit. P/U BIT, Motor, Lead Clr, MWD 1 LWD. Surface Test - OK. RIH - Breaking circ every 2500'. Cut & Slip Drilling Line Inspect Brakes & Drawworks. Service Top Drive & Crown. RIH @ 10,0025' - Obstruction. M/U Top Drive, work pipe & wash to bottom @ 10,346'. Slide from 10,346' to 10,504'. 300 GPM @ 2330 psi. Calc. ECD = 10.36 Sliding ECD = 10.66 WOB = 5K AST = 4.75 Hrs Drill from 10,504' to 11,065'. WOB 5-7K, RPM (TD) 60, GPM 300 PSI 2500. Calc. ECD = 10.7 Sliding ECD = 10.81. AST = 13.0 Hrs ART = 1.15 Hrs Some difficulty sliding from 10,753' to 10,910'. No geological changes. Increased lubes in mud from 3% to 5% with EP mud lube and EZ glide. ROP increasd to acceptable range but still difficult to slide. Total mud lost, 72 bbl. Pump 15 bbl high vis sweeps to control ECD. Drill from 11,065' to 11,455'. WOB 5-7.5K, RPM (TD) 60, GPM 300 PSI 2520. Calc. ECD = 10.67 Sliding ECD = 10.71. AST = 12.01 Hrs ART = 0.33 Hrs Sliding for most of this interval. No geological changes. Lubes in mud 5%. Total mud lost, 98 bbl. Pump 15 bbl high vis sweeps to control ECD. Drill ahead - slidng from 11455' to 11700'. Difficulty sliding. Add EZ glide lubricant. ROP increased. Back ream every stand drilled. Noted an increase in losses from 5 to approx 9 bph starting at -11575'. Start stringing in Barafiber at 5 sxlhr and losses stabilised by 11630' MD at 5-6 bph. Continue sliding to 11650' MD. ROP 10-40 fph. Dumped 300 bbl mud from system and replaced with new mud. New mud contains 2% lube, adding lubricants to increase to 5%. Drill ahead- sliding from 11700' to 11813'. Note gas cut returns, no flow. Increase mud weight to 9.5 ppg. Noted an increase in losses from 6 to approx 11 bph starting at -11755'. Start stringing in Barafiber at 5 sxlhr. Drill ahead- Rotate from 11813' to 11844'. Back ream each stand. Pump high vis sweeps to control ECD. Survery every stand. Continue stringing in Barafiber at 5 sxlhr, losses stablised at 6 bph while drilling. Drilling ahead from 11844' to 12311'. Well still shows slight flow with MW at 9.5 ppg when not circulating. Increase MW to 9.6 ppg. Dynamic losses at 10-15 bbl/hr. Flowcheck well on conn. Well is flowing an est 1 bbl/hr stream with no pump and MW at 9.6+ ppg. Flow does not diminish with time so not thought to be breathing from losses. Drill from 12311' to 12435'. Weight up mud to 9.8 ppg while drilling & flowcheck on next conn - appears to be stable. Difficulty sliding Printed: 12/9/2002 9:04:01 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Daté FromjTo HoUrs Task Code NPT Phase 11/29/2002 14:00 - 15:00 1.00 DRILL P PROD1 Circulate and add EP Mudlube to system, 5.5% total lubricants. 15:00 - 19:30 4.50 DRILL P PROD1 Drill from 12435' to 12591'. Rotate and slide to maintain direction and angle. Difficulty sliding. Flow check on connections, well flowing. Increase mud weight to 9.9 ppg while drilling. 19:30 - 21 :30 2.00 DRILL P PROD1 Circulate. Pump around high vis sweep prior to trip. 21 :30 - 22:30 1.00 DRILL P PROD1 Flow check, well flowing suspect breathing. Shut in well and observe pressure build up for 15 minutes. SIDP 147 psi, SICP 220 psi. Bleed of pressure, open well and allow to flow for 30 minutes, 11 bbl return. Shut in well and observe pressure build up for 15 minutes. SIDP 35 psi. Suspect ported float plugged. SICP 310 psi. Bleed off pressure, open well to circulate bottoms up. Gas to surface after pumping 60 bbl. Shut in well. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 Initiate well kill procedure to circulate out kick using Driller's method. Circulate well surface to surface with 9.9 ppg mud and remove gas from well bore. 11/30/2002 00:00 - 03:30 3.50 DRILL N DPRB PROD1 Circulate out kick using Driller's method. Circulate well surface to surface with 9.9 ppg mud and remove gas from well bore. 03:30 - 04:30 1.00 DRILL N DPRB PROD1 Shut in well, monitor pressure SIDPP=114 psi, SICP=183 psi 04:30 - 06:30 2.00 DRILL N DPRB PROD1 Weight up mud to 10.2 PPG - based on 9.9 ppg mud + SIDPP. 06:30 - 09:30 3.00 DRILL N DPRB PROD1 Pump kill weight mud @ 3 BPM, 10 BBL loss while killing well. Monitor for returns, well static. 09:30 - 18:00 8.50 DRILL N DPRB PROD1 Circulate and condition mud. Monitor losses, 12 BPH. Add LCM to control loss 18:00 - 18:30 0.50 DRILL N DPRB PROD1 Monitor well for flow. Well flowing 3 BPH. 18:30 - 21 :00 2.50 DRILL N DPRB PROD1 Circulate bottoms up @ 200 GPM, gas cut returns. Circulate to remove gas from wellbore. 21 :00 - 22:00 1.00 DRILL N DPRB PROD1 Circulate at reduced rate of 1 BPM - 480 psi to observe effect of lower ECD. Losses 4 BPH. 22:00 - 00:00 2.00 DRILL N DPRB PROD1 Circulate at reduced rate of 1/2 BPM - 230 psi to observe effect of lower ECD. Losses 2.5 BPH 12/1/2002 00:00 - 05:00 5.00 DRILL N DPRB PROD1 Circulate at reduced rate of1 /2 BPM - 230 psi to observe effect of lower ECD. Losses 1.8 BPH. 05:00 - 14:00 9.00 DRILL N DPRB PROD1 Stop pumps and observe well for 5 minutes. Flowing very slowly. Resume circulating at 1/2 BPM, 270 psi to observe effect of lower ECD. Gas cut mud to surface after pumping 76 bbl. Losses 2.5 BPH. 14:00 - 14:30 0.50 DRILL N DPRB PROD1 Stop pumping. Monitor well, flowing. Shut in well and observe pressures. SIDPP=20 psi, SICP= 20 psi. Bleed off pressure. 14:30 - 15:30 1.00 DRILL N DPRB PROD1 Observe well and establish flow rate of 2 BPH while pumping across top of well using trip tank. 15:30 - 17:00 1.50 DRILL N DPRB PROD1 Circulate at reduced rate of 1/2 BPM - 270 psi through one pit. Increase mud weight in surface system from 10.2 ppg to 10.5 ppg. 17:00 - 00:00 7.00 DRILL N DPRB PROD1 Start pumping 10.5 ppg kill weight mud around at 1/2 BPM. Noted an increase of losses to 4 BPH and and increase of circulating pressure to 280 psi when kill weight mud started up annulus from bit. 12/2/2002 00:00 - 12:30 12.50 DRILL N DPRB PROD1 Pump 10.5 ppg mud down hole for trip margin. Pump @ 0.5 BPM to minimise ECD on formation. Losses averaging -4 BPH, pumped in excess of surface to surface strokes, accounting for losses and mud weight returns maintain 10.2+ Printed: 12/9/2002 9:04:01 AM ') ) Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Date From'" To Hours Task . CodeNPT Phase Desëriptionof Opér~tiohs 12/2/2002 00:00 - 12:30 12.50 DRILL N DPRB PROD1 ppg. 12:30 - 13:30 1.00 DRILL N DPRB PROD1 Stage up pipe rotation to 50 RPM to see if return MW increases - no success and losses increase to 8 BPH. 13:30 - 16:15 2.75 DRILL N DPRB PROD1 Continue pumping 10.5 ppg mud to well at 0.5 BPM looking for 10.5 ppg returns. Now -140 bbls past surf»surf accounting for losses and still only 1 0.1 + ppg returns. Confer with Anchorage. 16:15 - 22:30 6.25 DRILL N DPRB PROD1 Stage up pump rate gradually from 0.5 to 3.0 BPM looking for improvement in return MW. Losses increased initially to 15-20 BPH but dropped back to 12 BPH possibly as SteelSeal went across open hole. Started getting back 10.5 ppg increasing to 12.4 ppg. Corresponds to bottoms up after raising rotary speed to 50 RPM. Circulate while stripping calcium carbonate weight material from mud and adding KCL, mud returns 10.5 ppg. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 Stop pump. Monitor well, static. POH first 2 stands at 4ft/min, pumping at 2.5 BPM and rotating at 55 RPM. Check for flow after pulling each stand. Well static. Continue POH at 7 ft/min two more stands, increase in pressure, torque and drag, hole packing off. Work pipe and increase pump rate to 4 BPM. Lost 28 bbl mud on first 4 stands. 12/3/2002 00:00 - 09:00 9.00 DRILL N DPRB PROD1 POH back reaming from 12497' to 12190'at 7 ft/min. Increase in pressure, torque and drag, hole packing off. Work pipe and pump at 4 BPM. POH continue back reaming at 15 ft/min from 12190' to 9763' pumping at 258 gpm. 09:00 - 10:00 1.00 DRILL N DPRB PROD1 Circulate and condition mud at 7" casing shoe. 10:00 - 12:30 2.50 DRILL N DPRB PROD1 Monitor well for flow or losses. Lost 7 bbl. 12:30 - 14:30 2.00 DRILL P PROD1 RIH to 11100', 15 stands. First 5 stands no returns, next 10 stands correct displacement. 14:30 - 15:30 1.00 DRILL P PROD1 Fill pipe, break circulation and stage pump up to 126 gpm for 10 minutes. 15:30 - 17:00 1.50 DRILL P PROD1 RIH to 12404'. Wash last two stands to bottom at 260 gpm. 17:00 - 19:30 2.50 DRILL P PROD1 Circulate and condition mud 19:30 - 20:00 0.50 DRILL P PROD1 Monitor well for flow or losses. Well static. 20:00 - 00:00 4.00 DRILL P PROD1 POH back reaming. Pilling pipe at 15 ft/min, pumping 250 gpm. Dynamic losses averaged 9 bph. 12/4/2002 00:00 - 05:00 5.00 DRILL P PROD1 POH back reaming to 11844'. Pulling pipe at 15 ft/min, pumping 250 gpm. Well packing off, work pipe through tight spots. Dynamic losses averaged 9 bph. Continue POH to 7" casing shoe back reaming, 55 RPM, 250 gpm. 05:00 - 06:00 1.00 DRILL P PROD1 Circulate surface to surface volume at 7" casing shoe. Monitor for gains and losses. No gas on bottoms up. 06:00 - 10:00 4.00 DRILL P PROD1 Monitor well while circulating over top of well to trip tank. 9 bbl mud lost. 10:00 - 19:30 9.50 DRILL P PROD1 POH to 5000'. Pump out every stand at 170 gpm. 45 bbllost to formation while POH. 19:30 - 00:00 4.50 DRILL P PROD1 POH to BHA at 40 ft/min, no pump no rotation. No flow no losses. 12/5/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Lay down BHA and bit. 01 :00 - 02:00 1.00 CASE P COMP Rig up to run 4 1/2" liner. PJSM with crew and casing crew. 02:00 - 07:00 5.00 CASE P COMP Run 41/2" 12.6# L80 IBT-M Liner. Check floats. Fill pipe on every joint. 07:00 - 07:30 0.50 CASE P COMP Make up Baker 7" x 5" HMC Hydraulic liner hanger with ZXP liner top packer and tie back sieve. Rig down liner running tools and power tong. Printed: 12/9/2002 9:04:01 AM .') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Date FrOm ..'"To Hours TaSk Code NPT Phase DØscri ptiÒn.. of Operation? 12/5/2002 07:30 - 08:00 0.50 CASE P COMP Circulate liner volume, record up and down weights. 08:00 - 15:00 7.00 CASE P COMP RIH with 4 1/2" liner on 4" drill pipe to 7" casing shoe. Fill pipe every 10 stands. 15:00 - 16:30 1.50 CASE P COMP Circulate drill pipe and liner volume 1.5 times. 16:30 - 20:00 3.50 CASE P COMP Make up cement head and cross over to pup joint and lay down same on skate. RIH with 4 1/2" liner on 4" drill pipe at 20 ftlmin. Work liner through intermittent tight spots from 11160' to 12483'. 20:00 - 20:30 0.50 CASE P COMP Wash last stand to 12576'. Make up cement head and lines with pup joint and wash to bottom at 12591'. 20:30 - 23:00 2.50 CEMT P COMP Circulate and condition mud at 250 gpm. Reciprocate pipe 30' strokes. 23:00 - 00:00 1.00 CEMT P COMP Pump 5 bbl fresh water, test lines to 4000 psi. Pump 30 bbls, 11.5 ppg weighted Alpha Spacer. Mix and pump 82 bbl (310 sx) Premium Cement with 35% SSA-1, 0.5% LAP 1,0.5% Halad-413, 0.75% USC, 0.5#/sx Super CBL and 0.5% HR-5 at 15.9 ppg at 4.5 BPM. Drop wiper dart and displace with 137 bb110.5 ppg mud. Bump plug with 3500 psi. SIP 24:00 hrs 12/5/2002 with 4 1/2" liner shoe at 12589' and liner top at 9614'. 12/6/2002 00:00 - 00:30 0.50 CASE P COMP Pressure up to 3500 psi to set Baker HMC Hydraulic Liner Hanger. Rotate to release running tool. Pick up to unsting from seals and circulate 30 bbl mud. Set ZXP liner top packer with 50,000 Ibs down weight. 00:30 - 01:00 0.50 CASE P COMP Circulate out 25 bbl excess cement form liner top, continue circulating to clean mud. 01 :00 - 01 :30 0.50 CASE P COMP Lay down cement head and lines. 01 :30 - 03:30 2.00 CASE P COMP POH and lay down 111 joints 4" drill pipe. 03:30 - 04:00 0.50 BOPSUR P COMP Make up RTTS packer on drill pipe and set at 5' below well head and test to 1000 psi. 04:00 - 04:30 0.50 BOPSUR P COMP Pull wear bushing and install test plug. 04:30 - 08:00 3.50 BOPSUR P COMP Test BOP and associated equipment to 250 psi low and 4000 psi. Test annular to 250 psi low and 3500 psi high. Choke manifold tested while POH and lay down drill pipe. Test witness waived by AOGCC John Crisp. 08:00 - 08:30 0.50 BOPSUR P COMP Retrieve RTTS and lay down same. 08:30 - 09:30 1.00 CASE P COMP Slip and cut drilling line. 09:30 - 10:00 0.50 CASE P COMP POH and lay down 21 joints drill pipe. 10:00 - 14:00 4.00 CASE P COMP RIH with drill pipe from derrick to 9518' 14:00 - 15:00 1.00 CASE P COMP Test casing, liner and liner top packer to 3500 psi for 30 minutes. 15:00 - 16:30 1.50 CASE P COMP Displace well from top of liner with 8.5 ppg sea water. 16:30 - 00:00 7.50 CASE P COMP POH 25 stands and stand in derrick. Continue POH and lay down 4" drill pipe. Stand back 7 stands of HWDP. Lay down Baker liner running tools. 12/7/2002 00:00 - 01 :00 1.00 RUNCOrvP COMP Pull wear bushing. Make dummy run with landing joint and tubing hanger. 01 :00 - 02:00 1.00 RUNCOrvP COMP Rig 41/2" tubing tools and power tong. PJSM with crew, Baker rep and tong operator. 02:00 - 10:00 8.00 RUNCOrvP COMP Run 227 joints 41/2" 12.6# L80 IBT-M tubing completion as per program. 10:00 - 11 :00 1.00 RUNCOrvP COMP Connect circulating head to string and pump down to top of liner. Space out completion string with WLEG at 9628'. Printed: 12/9/2002 9:04:01 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-03 V-03 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date Frorn;.Tó Hours Task Cdde NPT Phase 12/7/2002 1.00 RUNCOIVP COMP 11 :00 - 12:00 12:00 - 14:00 2.00 RUNCOIVP COMP 14:00 - 16:00 2.00 RUNCOIVP COMP 16:00 - 16:30 0.50 WHSUR P COMP 16:30 - 18:00 1.50 WHSUR P COMP 18:00 - 20:00 2.00 WHSUR P COMP 20:00 - 20:30 0.50 WHSUR P COMP 20:30 - 22:00 1.50 WHSUR P COMP 22:00 - 23:00 1.00 WHSUR P COMP 23:00 - 00:00 1.00 WHSUR P COMP Start: 11/12/2002 Rig Release: 12/7/2002 Rig Number: 9ES Spud Date: 11/12/2002 End: 12/7/2002 Land completion string on tubing hanger. Run in lock down screws. Reverse circulate and spot 120 bbl corrosion inhibited sea water in annulus. Pressure up tubing to 4200 psi and set Production Packer and hold for 30 minutes. Pressure up annulus to 3500 psi and hold for 30 minutes. Shear out DCK-2 valve in gas lift mandrel at 5736'. Install two way check and test from below with 2700 psi. Nipple down BOP, flow line and riser. Install 11 " adapter flange and 4 1/8" 5M production tree and test to 5000 psi. Rig up lubricator and pull Two Way Check. Rig up hot oil lines and test. Freeze protect 7" x 4 1/2" annulus with 106 bbl diesel. Allow to "U" tube from annulus to tubing. Rig up lubricator, install back Pressure Valve and test from below with 2800 psi. Secure tree and prepare to move rig to well V-113. Rig released at 24:00 hrs 12/07/2002 Printed: 12/9/2002 9:04:01 AM ) ) BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-03 V-03 COMPLETION NORDIC CALISTA NORDIC 1 Start: 12/27/2002 Rig Release: 12/31/2002 Rig Number: N1 Spud Date: 11/12/2002 End: 12/31/2002 Daté FrQm~To Hóurs. Task .CO,dé NPT Phase Dé$þriptîöné..qf'<:Jþ$tâtiøri$ 12/28/2002 00:00 - 02:00 2.00 MOB P PRE Jack up rig. Move off Pt Mac 1 Pad onto access road and head to K Pad road 02:00 - 05:30 3.50 MOB P PRE Fix-a-flat at road junction 05:30 - 12:00 6.50 MOB P PRE Resume rollin down K-Pad road 12:00 - 15:30 3.50 MOB P PRE Turn onto Spine Road at Frontier corner 15:30 - 18:30 3.00 MOB P PRE Crossing Kuparuk River Bridge 18:30 - 21 :00 2.50 MOB P PRE Let traffic pass at W Pad turnoff then resume move 21 :00 - 21 :30 0.50 MOB P PRE Off of Spine and onto V Pad access road. Park Rig in front of well. 21 :30 - 21:45 0.25 MOB P PRE PJSM on moving rig over well 21 :45 - 23:00 1.25 MOB P PRE Move rig over well, set down. 23:00 - 00:00 1.00 MOB P PRE ACCEPT RIG AT 23:0012/28/2002. ND Tree cap. Install new flange/lubricator to top of Hydril. MIRU camp and gen 3. 12/29/2002 00:00 - 01 :00 1.00 RIGU P PRE NU BOPE 01 :00 - 07:30 6.50 BOPSURP PRE BOPE test to 4000 psi. Witness waived by AOGCC 07:30 - 09:00 1.50 RIGU P PRE Change out packoffs, thaw frozen hardline on rig side, Pump CT dart (58.6bbls CT volume) 09:00 - 10:00 1.00 BOPSUR P PRE RE-test Blind rams to 4000psi, test MV and tree to 4000psi. 10:00 - 10:30 0.50 CLEAN P COMP Pre spud and PJSM. Cold weather -26degF ambient. Discuss fluid transfers and avoiding frozen lines. 10:30 - 11 :00 0.50 CLEAN P COMP PU 2-7/8" motor, 3.625" D331, MHA, Baker CTC. 11 :00 - 14:00 3.00 CLEAN N WAIT COMP Wait on VECO drill site maintenance to pressure test hardlines to flowback (tiger) tank. (DSM crew held up by MVA). Attempt to pressure test from rig test pump. Block valve leaking on flowback tank side. Continue waiting on DSM. (-32degF, -60 WC making things difficult.) DSM arrives at 13:30, replace block valve, PT hardlines. Good test. 14:00 - 17:00 3.00 CLEAN P COMP RIH @ 100fpm, 0.7bpm taking returns to flowback tank. At 3100 slow RIH speed to 80fpm, 1.5bpm to 9600'md. IA=205psi, OA=320psi. At 9600' slow to 60fpm, 2.5bpm to PBTD at 12538'md. Depth correct CT to 12505'md. Pumped a total of 298bbl of 1 %KCL. Did not see any obstructions or motor work in the liner. 17:00 - 18:40 1.67 CLEAN P COMP Backream from PBTD to 9600 at 60fpm, 2.5bpm taking returns to tiger. Fill pits with 9.3ppg Brine. IA=420, OA=335psi. RBIH at 80fpm at 2.1bpm. Tag PBD at12505'. PUH 52k 18:40 - 19:45 1.08 CLEAN P COMP Backream 30'/min to 11000' finishing off 600 bbls 1 % KCI and then swap to 9.3# 3% KCI/NaCI from pits. RBIH to TD and tag at 12502'. PUH 51 k atter 20 bbls past mill 19:45 - 22:00 2.25 CLEAN P COMP POOH while fin displacing well bore to 9.3# 3% KCI/NaCI @ 2.5 bpm/2200 22:00 - 22:20 0.33 CLEAN P COMP LD motor/mill. PVT 248 22:20 - 22:50 0.50 CLEAN P COMP RU and PT wellbore w/1.4 bbls to 2550 psi w/9.3 ppg brine for 10 min. IA rose from 123 to 320 psi, OA remained stable at 380 psi. Wellbore lost 30 psi in 10 min while IA decreased to 290 psi. Bleed off press and IA decreased to 80 psi and falling (ECD/temperature effect) 22:50 - 23:00 0.17 EVAL P COMP Safety mtg re: PU logging tools 23:00 - 23:25 0.42 EVAL P COMP MU SWS carrier w/ memory GRlCCL tool and 2.125" nozzle on MHA 23:25 - 00:00 0.58 EVAL P COMP RIH w/logging tool 0.6/205. IA 10, OA 367 12/30/2002 00:00 - 01 :00 1.00 EVAL P COMP Continue RIH w/ SWS memory GRlCCL 0.6/205 01 :00 - 02:00 1.00 EVAL P COMP Log down from 9400' 0.6/230 circ'ing fresh Flo Pro mud to Printed: 1/2/2003 1 :30:01 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: [Date ) Bp..EXPLORATION , Q~~~ÊJ~ilq,n$....$u",l'nijl~R~pØrt V-03 V-03 COMPLETION NORDIC CALISTA NORDIC 1 Front- To Hours Tåsk Code NPT Phäse 12/30/2002 01 :00 - 02:00 02:00 - 03:00 03:00 - 04:15 04: 15 - 04:45 04:45 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 11 :30 11 :30 - 13:45 13:45 -14:20 14:20 -17:00 17:00 - 19:45 12/31/2002 19:45 - 20:00 20:00 - 20:15 20: 15 - 23:00 23:00 - 23:40 23:40 - 23:50 23:50 - 00:00 00:00 - 03:40 03:40 - 05:20 05:20 - 05:30 05:30 - 07:00 07:00 - 07:30 1.00 EVAL P 1.00 EVAL P COMP COMP 1.25 EVAL P 0.50 EVAL P 1.25 PERF P COMP COMP COMP 2.00 PERF P 0.50 PERF P COMP COMP 3.00 PERF P 2.25 PERF P COMP COMP 0.58 PERF P COMP 2.67 PERF P COMP 2.75 PERF P COMP 0.25 PERF 0.25 PERF 2.75 PERF 0.67 PERF 0.17 PERF 0.17 PERF 3.67 PERF COMP COMP COMP COMP COMP COMP COMP P P P P P P P 1.67 PERF P COMP 0.17 PERF P 1.50 PERF P COMP COMP 0.50 PERF P COMP Start: 12/27/2002 Rig Release: 12/31/2002 Rig Number: N1 Spud Date: 11/12/2002 End: 12/31/2002 E?esctiptìön ØfQp$têl~iørl$ nozzle. Tag at 12537.9', corr to 12505'. PUH 45k Log up from 12505' at 60'/min leaving 30 bbls fresh mud in liner. Flag at 10000' EOP. Log to 9400' POOH LD logging tool. PVT 246 Load 382-7/8" SWS perf guns in pipeshed while check for data and download memory correlation log. RU to run perf guns. Determine PBD at 12506' and flag at 10001' based on GR spikes over 11300-600' tied into Vision log Wind 17-32, -28F, -70CF Crew change. SWS replace transport caps on guns PJSM: Discuss procedure, ensure safety jUs ready to go, 2-7/8" guns are new for us, stop the job if something does not look right, signs on cellar. Cold Weather. PU BHA #3. 382-7/8" perf guns/blanks, MHA. Phz 1 RIH with BHA #3. Correct CT depth to EOP flag, -37.7ft. Continue RIH, Tag PBTD, Correct CT depth to CCL/GR log. On depth, drop 5/8" steel ball, circ. 10bbls high vis pill on both sides of ball (20bbls total). CT Vol.=59.5bbls, slow pumps at 45bbls away, ball on seat at 53.2bbls. Ball on seat, pressure up to 3160psi, good indication. PIT VOL= 311 Perforate: 11700-11900, 11970-12070, 12184-12480. Schumberger HSD 2-7/8" guns are 4spf, 90deg phasing, PowerJet (PJ2906) charges, with the exception of 11803-11900 which is 6spf, 60deg phasing. POH at 55fpm. Losing fluid at 9bph. Stop at 9800'md, monitor well, no flow at surface. Continue POH. Losses slowing to 7bph. Phase II Conditions (-18degF, -60WC). Stop at 200ft and circulate 1.0/1.0/310. Load 2nd set of guns into pipe shed and replace end caps, 4 bph loss Safety mtg re: perf guns Fin POOH. RU to pull guns PVT 219 LD 38 perf guns-all shots fired PVT 206 Losing 2 bbls/hr Load out spent guns, Phz 1/2 Safety mtg re: perf guns MU perf guns PVT 205 MU 682-7/8" SWS perf guns. Losing 2 bph Phz 1 @ 0025 hrs RIH wI perf guns on CT 0.3/80 PVT 210 At 5000' see gas and crude in returns, MW out 8.6 ppg At 10000' 49.6k, 23.7k, MW out 8.7 Corr at flag -30.5'. PUH 45.5k to perf depth Park at perf depth. CBU 1.5/1.5/620 to clean up returns. PVT 256. Bottoms up. 1.5/1.5/670, consistent 9.29 out density on micro-motion. PVT 252. Losing 2.5bph while on bottom circulating. IA=1 psi, OA=322psi. Shut down pumps, monitor returns, no flow. 15bbls high vis pill, drop 5/8" ball, launch, follow with 10 bbls high vis. CT Vol= 59. Ball on seat at 50bbls. PVT 252. Shear ball seat at 3000psi. Printed: 1/2/2003 1:30:01 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Bp.EXPLOR1XJ110N ~RØt~~iØfl~....Su~ffl:Î:tWR~pø~ V-03 V-03 COMPLETION NORDIC CALISTA NORDIC 1 Start: 12/27/2002 Rig Release: 12/31/2002 Rig Number: N 1 Spud Date: 11/12/2002 End: 12/31/2002 Date Frortli.To 'Hours. Task Code NPT [)è~çrip~ipr)()f...~ÞørClti(j)hs 12/31/2002 07:00 - 07:30 07:30 - 09:48 09:48 -10:10 10:10 -10:20 10:20 - 18:30 0.50 PERF P COMP 2.30 PERF P 0.37 PERF P COMP COMP 0.17 PERF P 8.17 PERF P COMP COMP 18:30 - 19:20 0.83 PERF P COMP 19:20 - 19:40 0.33 RIGD P COMP 19:40 - 20:30 0.83 RIGD P COMP 20:30 - 22:00 1.50 RIGD P COMP 22:00 - 00:00 2.00 RIGD P COMP Perforated: 10000-10220, 10390-10460, 10590-11030, 11119-11415. 4SPF, 90deg phasing, PJ2906 charges. POH with guns Stop at 200', circulating .9bpm. PJSM: Discuss LD spent perf guns, beware of trapped pressure, burrs on guns and pinch point. 2-7/8" gun weighs 2201bs. Keep hole full and circulate across the top. continue POH. RU to circulate CT and Circulate across the top to keep hole full. Stand back injector. Start laying down perf guns. We lost 24bbls after perforating. 7bph Fin LD guns-all shots fired. PVT 128 Load out guns RU nozzle assy RIH wi nozzle assy to 2000' and FP with MeOH OOH. SI swab and master 23.5 turns PT DS N2 @ 3500 psi. Displace CT wi N2 and bleed off ND BOPE. NU tree cap and PT 4000 Rig released at 2400 hrs 12/31/02 Prep to move to W-32 Printed: 1/2/2003 1 :30:01 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well.....................: V-03 API number.. .............: 50-029-23124-00 Engineer. . . . . . . . . . . . . . . . .: St. Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference.... . . . . . .: Drill Floor GL above permanent.......: 53.50 ft KB above permanent.......: N/A DF above permanent.......: 82.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 310.00 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 1-Dec-2002 12:56:40 Spud date. . . . . . . . . . . . . . . . : Last survey date....... ..: Total accepted surveys...: MD of first survey.......: MD of last survey.... ....: Page 1 of 8 12 -Nov- 02 30 -Nov- 02 194 0.00 ft 12591.00 ft .~ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date.. ....... ...: 12-Nov-2002 Magnetic field strength..: 1149.69 HCNT Magnetic dec (+E/W-).....: 25.75 degrees Magnetic dip..... ........: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R..............: Dip. . . . . . . . . . . . : of G...... . . . . . : of R...... . . . . . : of Dip..... . . . . : Criteria --------- 1002.68 mGal 1149.69 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.75 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.75 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 '.~" ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 2 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- --------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 197.65 0.53 72.33 197.65 197.65 -0.49 0.28 0.87 0.91 72.33 0.27 MWD IFR MSA 3 292.43 0.42 67.66 94.78 292.42 -0.88 0.54 1.61 1.70 71.38 0.12 MWD IFR MSA 4 386.83 0.73 74.68 94.40 386.82 -1.39 0.83 2.51 2.64 71.64 0.34 MWP_IFR_MSA 5 477.63 0.81 77.52 90.80 477.61 -2.11 1.12 3.69 3.86 73.07 0.10 MWD IFR MSA 6 569.60 1.15 80.41 91.97 569.57 -3.10 1.42 5.24 5.43 74.85 0.37 MWD IFR MSA 7 662.13 1.44 87.88 92.53 662.07 -4.57 1.62 7.32 7.49 77.54 0.36 MWD IFR MSA ~~4 8 754.10 0.70 114.22 91.97 754.03 -5.96 1.43 8.98 9.10 80.96 0.95 MWD IFR MSA 9 846.19 0.80 116.33 92.09 846.11 -7.13 0.91 10.07 10.11 84.82 0.11 MWD I FR MSA 10 941.33 1.05 116.98 95.14 941.24 -8.62 0.22 11.45 11.45 88.89 0.26 MWD IFR MSA 11 1034.63 1.28 111.04 93.30 1034.52 -10.44 -0.54 13.18 13.19 92.34 0.28 MWD IFR MSA 12 1128.51 1.20 115.34 93.88 1128.38 -12.39 -1.34 15.05 15.11 95.08 0.13 MWD IFR MSA 13 1221.45 1.21 113.38 92.94 1221.30 -14.27 -2.14 16.83 16.96 97.26 0.05 MWD IFR MSA 14 1314.52 0.32 248.63 93.07 1314.36 -15.08 -2.63 17.49 17.68 98.54 1.56 MWD IFR MSA 15 1406.89 0.90 271.04 92.37 1406.72 -14.40 -2.71 16.52 16.74 99.31 0.67 MWD IFR MSA 16 1501.00 0.94 253.12 94.11 1500.82 -13.40 -2.92 15.04 15.32 100.98 0.31 MWD IFR MSA 17 1593.29 0.86 265.45 92.29 1593.10 -12.49 -3.19 13.63 14.00 103.19 0.23 MWD IFR MSA 18 1686.39 1.14 270.68 93.10 1686.19 -11.28 -3.24 12.01 12.44 105.09 0.32 MWD IFR MSA 19 1780.07 1.19 269.72 93.68 1779.85 -9.82 -3.23 10.10 10.61 107.74 0.06 MWD IFR MSA 20 1872.54 1.25 270.48 92.47 1872.30 -8.31 -3.23 8.13 8.75 111.65 0.07 MWD IFR MSA 21 1965.58 0.99 273.78 93.04 1965.32 -6.87 -3.17 6.32 7.07 116.62 0.29 MWD IFR MSA '~ 22 2058.74 1.12 276.95 93.16 2058.46 -5.46 -3.00 4.61 5.50 123.08 0.15 MWD IFR MSA 23 2152.29 1.35 273.57 93.55 2151.99 -3.81 -2.82 2.60 3.84 137.34 0.26 MWD IFR MSA 24 2244.39 1.16 271.33 92.10 2244.07 -2.21 -2.73 0.59 2.80 167.88 0.21 MWD IFR MSA 25 2337.43 1.30 264.67 93.04 2337.09 -0.73 -2.81 -1.41 3.14 206.56 0.21 MWD IFR MSA 26 2431.16 1.23 267.10 93.73 2430.79 0.75 -2.96 -3.47 4.56 229.52 0.09 MWD IFR MSA 27 2523.80 1.17 269.25 92.64 2523.41 2.20 -3.02 -5.41 6.20 240.79 0.08 MWD IFR MSA 28 2617.89 1.20 268.18 94.09 2617.48 3.66 -3.07 -7.35 7.97 247.36 0.04 MWD IFR MSA 29 2707.47 1.17 271.74 89.58 2707.04 5.08 -3.07 -9.20 9.70 251.56 0.09 MWD IFR MSA 30 2844.43 1.24 265.19 136.96 2843.97 7.23 -3.15 -12.08 12.48 255.38 0.11 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 3 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ --------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2935.59 0.41 31.88 91.16 2935.13 7.97 -2.96 -12.89 13.22 257.08 1.67 MWD IFR MSA - 32 3029.17 2.20 72.27 93.58 3028.68 7.06 -2.13 -11.00 11.20 259.07 2.04 MWD IFR MSA - 33 3122.99 4.47 74.11 93.82 3122.33 4.05 -0.58 -5.77 5.80 264.30 2.42 MWD IFR MSA - 34 3217.20 7.03 71.10 94.21 3216.06 -0.99 2.30 3.22 3.95 54.47 2.74 MWD IFR MSA - 35 3310.59 10.08 63.71 93.39 3308.41 -7.23 7.77 15.96 17.75 64.03 3.46 MWD IFR MSA 36 3403.35 13.32 61.57 92.76 3399.23 -14.42 16.45 32.63 36.55 63.24 3.52 MWD IFR MSA 37 3497.62 16.13 60.04 94.27 3490.39 -22.90 28.17 53.53 60.49 62.25 3.01 MWD IFR MSA "-'" - 38 3591.10 19.06 61.14 93.48 3579.49 -32.86 42.02 78.16 88.74 61.73 3.15 MWD IFR MSA 39 3683.96 22.04 59.81 92.86 3666.43 -44.24 58.11 106.50 121.32 61.38 3.25 MWD IFR MSA - 40 3778.54 23.16 59.13 94.58 3753.75 -56.35 76.57 137.81 157.65 60.94 1.22 MWD IFR MSA 41 3871.35 23.14 59.55 92.81 3839.08 -68.43 95.18 169.19 194.13 60.64 0.18 MWD IFR MSA 42 3963.88 22.76 59.54 92.53 3924.29 -80.50 113.47 200.29 230.20 60.47 0.41 MWD - IFR MSA 43 4058.26 22.43 60.26 94.38 4011.43 -92.84 131.65 231.67 266.46 60.39 0.46 MWD IFR MSA 44 4152.26 21.97 59.56 94.00 4098.46 -104.94 149.46 262.40 301.98 60.33 0.56 MWD - IFR MSA 45 4246.73 21.77 59.86 94.47 4186.13 -116.81 167.21 292.78 337.16 60.27 0.24 MWD IFR MSA 46 4341.41 21.65 58.58 94.68 4274.09 -128.34 185.13 322.87 372.18 60.17 0.52 MWD IFR MSA - 47 4435.13 21.77 58.37 93.72 4361.17 -139.32 203.26 352.42 406.83 60.03 0.15 MWD IFR MSA 48 4529.02 21.33 59.80 93.89 4448.49 -150.59 220.98 382.01 441.31 59.95 0.73 MWD IFR MSA - 49 4621.76 20.95 57.60 92.74 4534.99 -161.32 238.34 410.58 474.75 59.86 0.95 MWD IFR MSA - 50 4715.02 21.10 58.07 93.26 4622.04 '-171.57 256.16 438.91 508.19 59.73 0.24 MWD IFR MSA 51 4808.41 22.66 58.33 93.39 4708.70 -182.44 274.49 468.49 542.98 59.63 1.67 MWD IFR MSA - "~ 52 4901.60 24.62 56.05 93.19 4794.07 -193.45 294.76 499.87 580.30 59.47 2.32 MWD IFR MSA - 53 4994.08 27.16 56.46 92.48 4877.26 -204.76 317.18 533.45 620.62 59.26 2.75 MWD IFR MSA - 54 5087.34 29.84 60.02 93.26 4959.22 -218.74 340.55 571.30 665.09 59.20 3.40 MWD IFR MSA - 55 5179.67 32.94 60.35 92.33 5038.03 -235.34 364.45 613.02 713.17 59.27 3.36 MWD IFR MSA 56 5273.88 34.31 59.91 94.21 5116.47 -253.29 390.43 658.26 765.33 59.33 1.48 MWD IFR MSA - 57 5367.46 34.99 60.27 93.58 5193.45 -271.57 416.96 704.37 818.54 59.38 0.76 MWD IFR MSA - 58 5460.93 34.96 58.38 93.47 5270.05 -289.29 444.29 750.45 872.11 59.37 1.16 MWD IFR MSA - 59 5551.68 34.51 59.38 90.75 5344.62 -306.02 471.02 794.72 923.81 59.35 0.80 MWD IFR MSA - 60 5644.70 33.54 59.43 93.02 5421.72 -323.32 497.51 839.52 975.86 59.35 1.04 MWD - IFR MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 4 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------- -------- -------- ---------------- ---------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ --------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ----------------- --------------- ------ 61 5737.37 33.63 57.65 92.67 5498.92 -339.61 524.26 883.24 1027.12 59.31 1.07 MWD IFR MSA 62 5830.66 33.24 57.15 93.29 5576.77 -354.99 551.95 926.54 1078.49 59.22 0.51 MWD IFR MSA 63 5924.07 33.60 55.16 93.41 5654.74 -369.29 580.61 969.27 1129.86 59.08 1.23 MWD IFR MSA 64 6018.29 35.32 54.25 94.22 5732.42 -382.82 611.42 1012.77 1183.02 58.88 1.91 MWD IFR MSA 65 6112.06 34.62 54.09 93.77 5809.26 -395.97 642.88 1056.35 1236.59 58.68 0.75 MWD IFR MSA 66 6206.05 32.74 53.86 93.99 5887.47 -408.56 673.53 1098.50 1288.54 58.49 2.00 MWD IFRMSA 67 6298.04 32.45 54.71 91.99 5964.97 -420.79 702.46 1138.73 1337.97 58.33 0.59 MWD IFR MSA .-...-? 68 6393.11 33.93 54.54 95.07 6044.53 -433.93 732.59 1181.17 1389.90 58.19 1.56 MWD IFR MSA 69 6486.78 36.12 55.04 93.67 6121.23 -447.66 763.58 1225.09 1443.57 58.07 2.36 MWD IFR MSA 70 6582.19 35.45 54.61 95.41 6198.63 -461.93 795.71 1270.69 1499.27 57.95 0.75 MWD IFR MSA 71 6675.64 33.53 52.93 93.45 6275.65 -474.55 826.97 1313.39 1552.05 57.80 2.29 MWD IFR MSA 72 6769.41 33.29 54.26 93.77 6353.93 -486.68 857.61 1354.94 1603.55 57.67 0.82 MWD IFR MSA 73 6862.84 32.84 54.35 93.43 6432.23 -499.28 887.36 1396.34 1654.43 57.56 0.48 MWD IFR MSA 74 6956.29 32.69 55.17 93.45 6510.81 -512.16 916.54 1437.64 1704.95 57.48 0.50 MWD IFR MSA 75 7048.07 34.12 56.32 91.78 6587.43 -525.88 944.97 1479.41 1755.45 57.43 1.70 MWD IFR MSA 76 7141.21 36.42 56.79 93.14 6663.47 -541.21 974.60 1524.29 1809.23 57.41 2.49 MWD IFR MSA 77 7234.94 36.81 57.58 93.73 6738.70 -557.73 1004.90 1571.27 1865.13 57.40 0.65 MWD IFR MSA 78 7328.08 36.48 58.17 93.14 6813.43 -574.79 1034.46 1618.35 1920.72 57.41 0.52 MWD IFR MSA 79 7421.21 35.37 58.15 93.13 6888.85 -591.82 1063.28 1664.77 1975.35 57.43 1.19 MWD IFR MSA 80 7513.81 34.14 58.66 92.60 6964.92 -608.48 1090.94 1709.73 2028.13 57.46 1.36 MWD IFR MSA 81 7607.74 32.85 59.49 93.93 7043.25 -625.42 1117.59 1754.19 2079.95 57.50 1.46 MWD IFR MSA .~ 82 7702.15 33.61 59.28 94.41 7122.23 -642.59 1143.94 1798.71 2131.66 57.54 0.81 MWD IFR MSA 83 7795.59 33.74 59.71 93.44 7199.99 -659.88 1170.24 1843.35 2183.44 57.59 0.29 MWD IFR MSA 84 7889.59 34.25 60.98 94.00 7277.92 -678.15 1196.23 1889.03 2235.93 57.66 0.93 MWD IFR MSA 85 7982.97 35.39 61.55 93.38 7354.58 -697.49 1221.86 1935.78 2289.15 57.74 1.27 MWD IFR MSA 86 8077.32 36.66 60.90 94.35 7430.89 -717.58 1248.58 1984.41 2344.54 57.82 1.41 MWD IFR MSA 87 8171.18 38.16 58.47 93.86 7505.44 -736.76 1277.37 2033.62 2401.52 57.87 2.24 MWD IFR MSA 88 8264.74 37.76 58.36 93.56 7579.21 -754.94 1307.52 2082.64 2459.06 57.88 0.43 MWD IFR MSA 89 8357.56 37.86 56.37 92.82 7652.54 -771.92 1338.20 2130.56 2515.96 57.87 1.32 MWD IFR MSA 90 8451.46 38.94 53.97 93.90 7726.14 -787.17 1371.52 2178.42 2574.21 57.81 1.96 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 5 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------~------ --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8544.69 41.50 54.07 93.23 7797.32 -801.75 1406.88 2227.13 2634.28 57.72 2.75 MWD IFR MSA 92 8637.98 41.19 54.43 93.29 7867.35 -816.92 1442.89 2277.14 2695.79 57.64 0.42 MWD IFR MSA 93 8730.61 40.63 55.06 92.63 7937.36 -832.36 1477.90 2326.68 2756.38 57.58 0.75 MWD IFR MSA 94 8823.48 40.10 54.71 92.87 8008.12 -847.81 1512.50 2375.88 2816.46 57.52 0.62 MWD IFR MSA 95 8917.44 38.69 53.86 93.96 8080.73 -862.53 1547.30 2424.30 2876.00 57.45 1.61 MWD I FR MSA 96 9009.57 38.87 51.75 92.13 8152.55 -875.32 1582.19 2470.26 2933.51 57.36 1.45 MWD IFR MSA 97 9103.18 40.01 50.59 93.61 8224.85 -886.83 1619.48 2516.57 2992.63 57.24 1.45 MWD IFR MSA - I 98 9194.43 39.85 49.95 91.25 8294.82 -897.27 1656.91 2561.62 3050.78 57.10 0.48 MWD IFR MSA 99 9288.57 39.50 50.61 94.14 8367.28 -908.00 1695.32 2607.84 3110.46 56.97 0.58 MWD IFR MSA 100 9380.33 40.62 51.12 91.76 8437.51 -919.13 1732.59 2653.65 3169.19 56.86 1.27 MWD IFR MSA 101 9473.35 41.27 50.36 93.02 8507.77 -930.49 1771.17 2700.85 3229.80 56.74 0.88 MWD IFR MSA 102 9567.69 41.24 49.05 94.34 8578.69 -940.98 1811.40 2748.30 3291.55 56.61 0.92 MWD IFR MSA 103 9660.03 39.05 48.37 92.34 8649.28 -950.00 1850.67 2793.03 3350.52 56.47 2.42 MWD IFR MSA 104 9691.93 39.88 49.20 31.90 8673.90 -953.10 1864.03 2808.28 3370.62 56.43 3.08 MWD IFR MSA 105 9797.44 43.18 49.49 105.51 8752.88 -964.46 1909.60 2861.35 3440.04 56.28 3.13 MWD Inc. Only 106 9828.46 41.52 49.57 31.02 8775.80 -967.92 1923.16 2877.25 3460.79 56.24 5.35 MWD IFR MSA 107 9858.56 41.83 49.03 30.10 8798.28 -971.15 1936.21 2892.42 3480.66 56.20 1.58 MWD IFR MSA 108 9889.82 45.31 47.80 31.26 8820.93 -974.30 1950.51 2908.53 3502.00 56.15 11.46 MWD IFR MSA 109 9919.82 48.04 44.29 30.00 8841.52 -976.58 1965.67 2924.22 3523.48 56.09 12.46 MWD IFR MSA 110 9950.49 50.67 41.51 30.67 8861.49 -977.75 1982.72 2940.05 3546.13 56.01 10.99 MWD IFR MSA III 9984.03 53.20 39.58 33.54 8882.17 -977.99 2002.78 2957.21 3571.58 55.89 8.80 MWD I FR MSA - - '~ 112 10016.08 55.19 37.68 32.05 8900.92 -977.36 2023.09 2973.43 3596.41 55.77 7.85 MWD IFR MSA 113 10044.88 57.31 36.96 28.80 8916.92 -976.24 2042.13 2987.94 3619.13 55.65 7.65 MWD IFR MSA 114 10074.59 60.36 36.59 29.71 8932.30 -974.81 2062.49 3003.16 3643.19 55.52 10.32 MWD IFR MSA 115 10106.48 63.47 33.86 31.89 8947.31 -972.46 2085.48 3019.38 3669.58 55.37 12.33 MWD IFR MSA 116 10137.85 68.83 30.81 31.37 8959.99 -968.62 2109.72 3034.70 3695.98 55.19 19.26 MWD IFR MSA 117 10169.36 73.35 27.06 31.51 8970.20 -962.89 2135.80 3049.10 3722.72 54.99 18.23 MWD IFR MSA 118 10200.61 77.86 22.00 31.25 8977.98 -954.81 2163.32 3061.65 3748.82 54.76 21.31 MWD IFR MSA 119 10232.79 83.16 17.01 32.18 8983.28 -943.69 2193.22 3072.23 3774.76 54.48 22.47 MWD IFR MSA 120 10258.79 86.12 12.90 26.00 8985.71 -932.73 2218.23 3078.91 3794.76 54.23 19.42 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 6 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- ---------------- ------ 121 10295.11 88.35 5.80 36.32 8987.47 -914.25 2254.00 3084.79 3820.53 53.85 20.47 MWD I FR MSA 122 10322.40 89.90 2.93 27.29 8987.88 -898.35 2281.20 3086.87 3838.31 53.54 11.95 MWD I FR MSA 123 10359.50 89.18 1.18 37.10 8988.18 -875.54 2318.27 3088.20 3861.53 53.10 5.10 MWD IFR MSA 124 10387.30 87.09 1.65 27.80 8989.08 -858.22 2346.05 3088.89 3878.81 52.78 7.71 MWD IFR MSA 125 10420.10 84.68 0.88 32.80 8991.44 -837.75 2378.75 3089.61 3899.25 52.41 7.71 MWD IFR MSA 126 10451.01 83.92 3.10 30.91 8994.51 -818.81 2409.49 3090.68 3918.92 52.06 7.56 MWD IFR MSA 127 10483.21 83.13 5.22 32.20 8998.14 -800.08 2441.40 3093.00 3940.44 51.71 6.99 MWD I FR MSA ~ 128 10513.86 83.85 7.81 30.65 9001.62 -783.28 2471.65 3096.45 3961.95 51.40 8.72 MWD IFR MSA 129 10542.86 84.61 7.17 29.00 9004.53 -767.77 2500.26 3100.21 3982.79 51.11 3.42 MWD IFR MSA 130 10575.95 86.54 5.88 33.09 9007.08 -749.57 2533.03 3103.96 4006.35 50.78 7.01 MWD I FR MSA 131 10607.66 88.80 5.40 31.71 9008.37 -731.69 2564.56 3107.08 4028.76 50.46 7.29 MWD IFR MSA 132 10636.71 90.34 2.88 29.05 9008.59 -714.68 2593.53 3109.17 4048.87 50.17 10.17 MWD IFR MSA 133 10670.66 92.09 2.55 33.95 9007.87 -694.12 2627.44 3110.78 4071.90 49.81 5.25 MWD IFR MSA 134 10701.35 92.92 0.60 30.69 9006.53 -675.06 2658.08 3111.62 4092.38 49.49 6.90 MWD IFR MSA 135 10732.87 93.91 359.85 31.52 9004.65 -654.93 2689.55 3111.75 4112.98 49.16 3.94 MWD IFR MSA 136 10763.34 95.26 356.80 30.47 9002.22 -634.74 2719.90 3110.86 4132.23 48.84 10.92 MWD IFR MSA 137 10795.29 96.22 357.27 31.95 8999.02 -613.07 2751.65 3109.22 4151.96 48.49 3.34 MWD IFR MSA 138 10826.16 96.67 352.98 30.87 8995.55 -591.44 2782.20 3106.61 4170.33 48.15 13.89 MWD IFR MSA 139 10857.47 96.77 351.18 31.31 8991.89 -568.36 2813.00 3102.33 4187.77 47.80 5.72 MWD IFR MSA 140 10888.85 96.43 348.46 31.38 8988.28 -544.42 2843.68 3096.82 4204.38 47.44 8.68 MWD IFR MSA 141 10919.84 97.33 346.84 30.99 8984.57 -520.06 2873.73 3090.24 4219.94 47.08 5~95 MWD IFR MSA 142 10950.21 98.64 344.23 30.37 8980.35 -495.59 2902.85 3082.73 4234.35 46.72 9.54 MWD IFR MSA ,.~" 143 10985.29 98.88 339.92 35.08 8975.00 -466.22 2935.83 3072.06 4249.31 46.30 12.16 MWD IFR MSA 144 11013.40 98.85 337.39 28.11 8970.67 -441.85 2961.70 3061.95 4259.95 45.95 8.89 MWD IFR MSA 145 11045.00 99.17 335.19 31.60 8965.72 -413.87 2990.27 3049.40 4270.90 45.56 6.95 MWD IFR MSA 146 11075.45 99.59 332.57 30.45 8960.76 -386.40 3017.25 3036.18 4280.44 45.18 8.60 MWD IFR MSA 147 11106.76 100.28 332.08 31.31 8955.36 -357.87 3044.56 3021.85 4289.63 44.79 2.69 MWD IFR MSA 148 11138.51 100.66 328.85 31.75 8949.58 -328.63 3071.72 3006.46 4298.17 44.38 10.08 MWD IFR MSA 149 11169.19 101.01 328.74 30.68 8943.82 -300.10 3097.49 2990.85 4305.77 44.00 1.19 MWD IFR MSA 150 11200.06 100.07 326.30 30.87 8938.17 -271.16 3123.09 2974.56 4312.97 43.60 8.35 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 7 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ----_.- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- -----------~--- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 11231.53 98.82 325.23 31.47 8933.01 -241.29 3148.75 2957.09 4319.61 43.20 5.20 MWD IFR MSA 152 11262.82 97.33 324.59 31.29 8928.61 -211.35 3174.10 2939.28 4326.00 42.80 5.17 MWD IFR MSA 153 11293.28 95.64 323.30 30.46 8925.17 -181.98 3198.57 2921.47 4331.95 42.41 6.96 MWD IFR MSA 154 11324.10 93.26 322.25 30.82 8922.78 -152.01 3223.03 2902.88 4337.59 42.01 8.44 MWD IFR MSA 155 11355.02 91.62 321.38 30.92 8921.46 -121.78 3247.31 2883.79 4342.96 41.61 6.00 MWD IFR MSA 156 11386.60 90.31 319.60 31.58 8920.93 -90.73 3271.67 2863.70 4347.94 41.20 7.00 MWD IFR MSA 157 11417.67 89.38 318.64 31.07 8921.01 -60.06 3295.16 2843.36 4352.34 40.79 4.30 MWD I FR MSA -~ 158 11449.14 88.15 316.95 31.47 8921.69 -28.89 3318.47 2822.23 4356.28 40.38 6.64 MWD IFR MSA 159 11480.39 87.53 314.01 31.25 8922.87 2.20 3340.73 2800.34 4359.17 39.97 9.61 MWD IFR MSA 160 11511.73 86.26 312.78 31.34 8924.57 33.43 3362.23 2777.60 4361.15 39.56 5.64 MWD IFR MSA 161 11542.50 84.02 311.96 30.77 8927.17 64.06 3382.89 2754.95 4362.76 39.16 7.75 MWD IFR MSA 162 11574.19 82.37 311.52 31.69 8930.93 95.52 3403.84 2731.47 4364.29 38.75 5.39 MWD IFR MSA 163 11604.70 81.78 309.64 30.51 8935.14 125.73 3423.50 2708.52 4365.36 38.35 6.40 MWD IFR MSA 164 11636.85 82.02 309.16 32.15 8939.67 157.56 3443.70 2683.93 4366.06 37.93 1.66 MWD IFR MSA 165 11667.62 83.44 306.87 30.77 8943.56 188.06 3462.49 2659.88 4366.21 37.53 8.71 MWD IFR MSA 166 11698.50 83.78 305.12 30.88 8947.00 218.67 3480.53 2635.05 4365.50 37.13 5.74 MWD IFR MSA 167 11729.49 84.57 301.18 30.99 8950.14 249.28 3497.38 2609.24 4363.47 36.73 12.90 MWD IFR MSA 168 11761.12 85.81 299.76 31.63 8952.80 280.36 3513.37 2582.08 4360.15 36.31 5.95 MWD IFR MSA 169 11791.43 85.61 298.12 30.31 8955.06 310.02 3527.99 2555.63 4356.37 35.92 5.44 MWD IFR MSA 170 11823.00 85.60 296.37 31.57 8957.48 340.72 3542.40 2527.65 4351.73 35.51 5.53 MWD IFR MSA 171 11854.47 85.47 296.46 31.47 8959.93 371.22 3556.36 2499.55 4346.89 35.10 0.50 MWD IFR MSA 172 11885.23 85.54 296.74 30.76 8962.35 401.05 3570.09 2472.13 4342.46 34.70 0.94 MWD IFR MSA ~4 173 11917.33 85.95 296.53 32.10 8964.73 432.19 3584.44 2443.51 4338.08 34.28 1.43 MWD IFR MSA 174 11948.44 86.36 297.67 31.11 8966.81 462.45 3598.58 2415.88 4334.31 33.88 3.89 MWD IFR MSA 175 11979.99 85.85 298.45 31.55 8968.96 493.24 3613.39 2388.10 4331.24 33.46 2.95 MWD IFR MSA 176 12009.59 85.61 300.68 29.60 8971.16 522.27 3627.95 2362.43 4329.33 33.07 7.56 MWD IFR MSA 177 12040.62 85.61 301.11 31.03 8973.54 552.82 3643.84 2335.88 4328.27 32.66 1.38 MWD IFR MSA 178 12072.06 85.47 300.61 31.44 8975.98 583.77 3659.91 2308.98 4327.39 32.25 1.65 MWD IFR MSA 179 12102.79 85.30 298.73 30.73 8978.45 613.90 3675.08 2282.36 4326.13 31.84 6.12 MWD IFR MSA 180 12133.83 85.30 299.07 31.04 8981.00 644.26 3690.03 2255.28 4324.65 31.43 1.09 MWD_IFR MSA ANADRILL SCHLUMBERGER Survey Report 1-Dec-2002 12:56:40 Page 8 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- ---------------- ------ 181 12165.17 86.50 300.48 31.34 8983.24 675.02 3705.55 2228.15 4323.86 31.02 5.90 MWD IFR MSA 182 12195.81 86.54 302.10 30.64 8985.10 705.25 3721.43 2202.01 4324.11 30.61 5.28 MWD IFR MSA 183 12228.38 86.91 301.65 32.57 8986.96 737.44 3738.60 2174.40 4324.95 30.18 1.79 MWD IFR MSA 184 12259.15 86.57 300.99 30.77 8988.71 767.81 3754.57 2148.16 4325.67 29.78 2.41 MWD IFR MSA 185 12288.78 84.99 299.48 29.63 8990.89 796.93 3769.45 2122.63 4326.00 29.38. 7.37 MWD IFR MSA 186 12320.88 85.06 299.55 32.10 8993.67 828.37 3785.21 2094.80 4326.20 28.96 0.31 MWD IFR MSA 187 12352.21 85.16 298.87 31.33 8996.34 859.03 3800.44 2067.55 4326.44 28.55 2.19 MWD IFR MSA .~ 188 12383.10 85.71 302.01 30.89 8998.80 889.40 3816.04 2041.01 4327.57 28.14 10.29 MWD IFR MSA 189 12414.35 85.71 301.56 31.25 9001.14 920.24 3832.45 2014.52 4329.66 27.73 1.44 MWD IFR MSA 190 12445.66 86.19 301.66 31.31 9003.35 951.14 3848.82 1987.92 4331.89 27.32 1.57 MWD I FR MSA 191 12476.54 85.75 304.34 30.88 9005.52 981.71 3865.60 1962.09 4335.05 26.91 8.77 MWD IFR MSA 192 12508.21 84.61 303.48 31.67 9008.18 1013.09 3883.20 1935.90 4339.01 26.50 4.50 MWD I FR MSA 193 12538.34 84.75 301.68 30.13 9010.98 1042.83 3899.36 1910.62 4342.29 26.10 5.97 MWD IFR MSA Projected to TD: 194 12591.00 84.75 301.68 52.66 9015.80 1094.72 3926.90 1866.00 4347.70 25.42 0.00 MWD_Proj. [(c)2002 Anadrill IDEAL ID6_1C_10J .~ õ V-03 Schlumberger Survey Report - Geodetic Report Date: 1-Dec-02 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 310.000° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure / Slot: V-Pad / V-03 TVD Reference Datum: KB Well: V-03 TVD Reference Elevation: 82.000 ft relative to MSL Borehole: V-03 Sea Bed / Ground Level Elevation: 55.000 ft relative to MSL UWI/API#: 500292312400 Magnetic Declination: +25.747° Survey Name / Date: V-03/ December 01,2002 Total Field Strength: 57507.444 nT Tort / AHD I DDII ERD ratio: 307.202° /6213.62 ft / 6.426 / 0.689 Magnetic Dip: 80.772° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Fee1 Declination Date: November 19, 2002 ,~¡ Location Lat/Long: N 701941.368, W 149 1550.744 Magnetic Declination Model: BGGM 2002 Location Grid NIE YIX: N 5970142.030 ftUS, E 590738.620 ftUS North Reference: True North Grid Convergence Angle: +0.69295860° Total Corr Mag North -> True North: +25.747° Grid Scale Factor: 0.99990935 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970142.03 590738.62 N 70 19 41.368 W 149 1550.744 197.65 0.53 72.33 197.65 -0.49 0.28 0.87 0.27 5970142.32 590739.49 N 701941.370 W 149 1550.718 292.43 0.42 67.66 292.42 -0.88 0.54 1.61 0.12 5970142.59 590740.22 N 70 19 41.373 W 149 15 50.697 386.83 0.73 74.68 386.82 -1.39 0.83 2.51 0.34 5970142.89 590741.12 N 70 19 41.376 W 149 15 50.670 477.63 0.81 77.52 477.61 -2.11 1.12 3.69 0.10 5970143.20 590742.30 N 701941.379 W 149 1550.636 569.60 1.15 80.41 569.57 -3.10 1.42 5.24 0.37 5970143.51 590743.84 N 701941.382 W 1491550.591 662.13 1.44 87.88 662.07 -4.57 1.62 7.32 0.36 5970143.73 590745.92 N 701941.384 W 149 1550.530 754.10 0.70 114.22 754.03 -5.96 1.43 8.98 0.95 5970143.57 590747.59 N 701941.382 W 149 1550.48" 846.19 0.80 116.33 846.11 -7.13 0.91 10.07 0.11 5970143.06 590748.68 N 70 19 41.377 W 149 15 50.45~ 941.33 1.05 116.98 941 .24 -8.62 0.22 11.45 0.26 5970142.39 590750.06 N 70 19 41.370 W 149 15 50.410 1034.63 1.28 111.04 1034.52 -10.44 -0.54 13.18 0.28 5970141.65 590751.80 N 70 19 41.362 W 149 1550.359 1128.51 1.20 115.34 1128.38 -12.39 -1.34 15.05 0.13 5970140.88 590753.68 N 701941.355 W 1491550.304 1221.45 1.21 113.38 1221.30 -14.27 -2.14 16.83 0.05 5970140.09 590755.47 N 70 19 41.347 W 149 1550.252 1314.52 0.32 248.63 1314.36 -15.08 -2.63 17.49 1.56 5970139.61 590756.14 N 701941.342 W 149 1550.233 1406.89 0.90 271.04 1406.72 -14.40 -2.71 16.52 0.67 5970139.52 590755.17 N 701941.341 W 149 1550.261 1501.00 0.94 253.12 1500.82 -13.40 -2.92 15.04 0.31 5970139.29 590753.70 N 701941.339 W 149 1550.305 1593.29 0.86 265.45 1593.10 -12.49 -3.19 13.63 0.23 5970139.00 590752.29 N 70 1941.336 W 1491550.346 1686.39 1.14 270.68 1686.19 -11.28 -3.24 12.01 0.32 5970138.94 590750.66 N 701941.336 W 149 1550.393 1780.07 1.19 269.72 1779.85 -9.82 -3.23 10.10 0.06 5970138.92 590748.76 N 70 1941.336 W 1491550.449 V-03 ASP Final Surveys.xls Page 1 of 6 12/10/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azlm TVO VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 1872.54 1.25 270.48 1872.30 -8.31 -3.23 8.13 0.07 5970138.90 590746.79 N 701941.336 W 1491550.506 1965.58 0.99 273.78 1965.32 -6.87 -3.17 6.32 0.29 5970138.94 590744.97 N 701941.337 W 149 1550.559 2058.74 1.12 276.95 2058.46 -5.46 -3.00 4.61 0.15 5970139.08 590743.26 N 70 1941.338 W 149 15 50.609 2152.29 1.35 273.57 2151.99 -3.81 -2.82 2.60 0.26 5970139.24 590741 .26 N 701941.340 W 1491550.668 2244.39 1.16 271.33 2244.07 -2.21 -2.73 0.59 0.21 5970139.30 590739.24 N 701941.341 W 149 1550.727 2337.43 1.30 264.67 2337.09 -0.73 -2.81 -1.41 0.21 5970139.20 590737.25 N 701941.340 W 149 1550.785 2431.16 1.23 267.10 2430.79 0.75 -2.96 -3.47 0.09 5970139.03 590735.19 N 701941.339 W 149 1550.845 2523.80 1.17 269.25 2523.41 2.20 -3.02 -5.41 0.08 5970138.94 590733.25 N 701941.338 W 149 1550.902 2617.89 1.20 268.18 2617.48 3.66 -3.07 -7.35 0.04 5970138.87 590731.31 N 701941.338 W 149 1550.958 2707.47 1.17 271.74 2707.04 5.08 -3.07 -9.20 0.09 5970138.85 590729.45 N 701941.338 W 149 15 51.012 ~' 2844.43 1.24 265.19 2843.97 7.23 -3.15 -12.08 0.11 5970138.73 590726.58 N 701941.337 W 1491551.096 2935.59 0.41 31.88 2935.13 7.97 -2.96 -12.89 1.67 5970138.92 590725.77 N 701941.339 W 1491551.120 3029.17 2.20 72.27 3028.68 7.06 -2.13 -11 .00 2.04 5970139.77 590727.65 N 701941.347 W 1491551.065 3122.99 4.47 74.11 3122.34 4.05 -0.58 -5.77 2.42 5970141.38 590732.86 N701941.362 W1491550.912 3217.20 7.03 71.10 3216.06 -0.99 2.30 3.22 2.74 5970144.37 590741.81 N 701941.390 W 1491550.650 3310.59 10.08 63.71 3308.41 -7.23 7.77 15.96 3.46 5970149.99 590754.48 N 70 19 41 .444 W 149 15 50.278 3403.35 13.32 61.57 3399.23 -14.42 16.45 32.63 3.52 5970158.88 590771.05 N 70 1941.530 W 149 1549.791 3497.62 16.13 60.04 3490.39 -22.90 28.17 53.53 3.01 5970170.84 590791.80 N 701941.645 W 1491549.181 3591.10 19.06 61.14 3579.49 -32.86 42.02 78.16 3.15 5970184.99 590816.26 N 701941.781 W 149 1548.462 3683.96 22.04 59.81 3666.43 -44.24 58.11 106.50 3.25 5970201.41 590844.40 N 701941.939 W 149 1547.635 3778.54 23.16 59.13 3753.75 -56.35 76.57 137.81 1.-?2 5970220.26 590875.48 N 70 19 42.121 W 149 1546.721 3871.35 23.14 59.55 3839.08 -68.43 95.18 169.19 0.18 5970239.24 590906.63 N 70 19 42.304 W 149 15 45.804 3963.88 22.76 59.54 3924.29 -80.50 113.47 200.29 0.41 5970257.90 590937.51 N 70 19 42.484 W 149 15 44.896 4058.26 22.43 60.26 4011.43 -92.84 131.65 231.67 0.46 5970276.46 590968..65 N 70 1942.663 W 149 1543.981 4152.26 21.97 59.56 4098.46 -104.94 149.46 262.40 0.56 5970294.64 590999:17 N 70 19 42.838 W 149 15 43.083 .~ 4246.73 21.77 59.86 4186.13 -116.81 167.21 292.78 0.24 5970312.75 591029.33 N 70 1943.012 W 1491542.196 4341.41 21.65 58.58 4274.09 -128.34 185.13 322.87 0.52 5970331.03 591059.20 N 70.1943.188 W 149 1541.318 4435.13 21.77 58.37 4361.17 -139.32 203.26 352.42 0.15 5970349.51 591088.53 N 70 19 43.367 W 149 15 40.455 4529.02 21.33 59.80 4448.49 -150.59 220.98 382.01 0.73 5970367.59 591117.89 N 70 1943.541 W 1491539.591 4621.76 20.95 57.60 4534.99 -161.32 238.34 410.58 0.95 5970385.30 591146.25 N 701943.712 W 149 1538.757 4715.02 21.10 58.07 4622.04 -171.57 256.16 438.91 0.24 5970403.45 591174.36 N 70 1943.887 W 1491537.930 4808.41 22.66 58.33 4708.70 -182.44 274.49 468.49 1.67 5970422.14 591203.71 N 70 19 44.067 W 149 15 37.067 4901.60 24.62 56.05 4794.07 -193.45 294.76 499.87 2.32 5970442.79 591234.84 N 70 19 44.267 W 149 15 36.150 4994.08 27.16 56.46 4877.26 -204.76 317.19 533.45 2.75 5970465.61 591268.14 N 70 1944.487 W 149 1535.170 5087.34 29.84 60.02 4959.22 -218.74 340.55 571.30 3.40 5970489.43 591305.70 N 701944.717 W 149 1534.065 V-03 ASP Final Surveys.xls Page 2 of 6 12/10/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ("/100ft) (ftUS) (ftUS) 5179.67 32.94 60.35 5038.03 -235.34 364.45 613.02 3.36 5970513.83 591347.13 N 70 19 44.952 W 149 15 32.847 5273.88 34.31 59.91 5116.47 -253.29 390.43 658.26 1.48 5970540.36 591392.04 N 70 19 45.207 W 149 1531.526 5367.46 34.99 60.27 5193.45 -271 .56 416.96 704.38 0.76 5970567.44 591437.84 N 70 1945.468 W 1491530.180 5460.93 34.96 58.38 5270.05 -289.29 444.29 750.45 1.16 5970595.32 591483.57 N 70 1945.737 W 149 1528.834 5551.68 34.51 59.38 5344.63 -306.02 471.02 794.72 0.80 5970622.58 591527.51 N 70 1946.000 W 149 1527.542 5644.70 33.54 59.43 5421.72 -323.32 497.51 839.52 1.04 5970649.61 591571.98 N 70 19 46.260 W 149 15 26.234 5737.37 33.63 57.65 5498.92 -339.61 524.26 883.24 1.07 5970676.89 591615.37 N 70 19 46.523 W 149 15 24.957 5830.66 33.24 57.15 5576.77 -354.99 551.95 926.55 0.51 5970705.10 591658.34 N 70 1946.796 W 149 1523.693 5924.07 33.60 55.16 5654.74 -369.29 580.61 969.27 1.23 5970734.26 591700.71 N 701947.077 W 149 1522.446 6018.29 35.32 54.25 5732.42 -382.82 611.42 1012.77 1.91 5970765.59 591743.83 N 701947.380 W 149 15 21.175~J 6112.06 34.62 54.09 5809.26 -395.97 642.88 1056.35 0.75 5970797.58 591787.02 N701947.690 W1491519.903 6206.05 32.74 53.86 5887.47 -408.56 673.53 1098.50 2.00 5970828.73 591828.79 N 70 1947.991 W 149 15 18.672 6298.04 32.45 54.71 5964.98 -420.79 702.46 1138.73 0.59 5970858.14 591868.67 N 701948.275 W 149 15 17.498 6393.11 33.93 54.54 6044.53 -433.93 732.59 1181.17 1.56 5970888.78 591910.73 N 701948.572 W 149 1516.259 6486.78 36.12 55.04 6121.23 -447.66 763.58 1225.09 2.36 5970920.29 591954.27 N 70 1948.876 W 149 15 14.976 6582.19 35.45 54.61 6198.63 -461.93 795.71 1270.69 0.75 5970952.98 591999.48 N 70 1949.192 W 1491513.644 6675.64 33.53 52.93 6275.66 -474.55 826.97 1313.39 2.29 5970984.75 592041.79 N 70 1949.500 W 149 1512.398 6769.41 33.29 54.26 6353.93 -486.68 857.61 1354.94 0.82 5971015.89 592082.96 N701949.801 W1491511.184 6862.84 32.84 54.35 6432.23 -499.27 887.36 1396.34 0.48 5971046.12 592123.99 N 701950.094 W 149 159.976 6956.29 32.69 55.17 6510.81 -512.16 916.54 1437.64 0.50 5971075.80 592164.94 N 70 19 50.380 W 149 158.770 7048.07 34.12 56.32 6587.43 -525.88 944.97 1479.41 -t70 5971104.73 592206.36 N 70 19 50.660 W 149 157.550 7141.21 36.42 56.79 6663.47 -541.21 974.60 1524.29 2.49 5971134.90 592250.87 N 701950.951 W 149 156.239 7234.94 36.81 57.58 6738.70 -557.73 1004.90 1571 .27 0.65 5971165.76 592297.48 N 70 1951.249 W 149 154.868 7328.08 36.48 58.17 6813.43 -574.79 1034.46 1618.35 0.52 5971195.89 592344.19 N 70 19 51.540 W 149 153.493 7421.21 35.37 58.15 6888.85 -591.82 1063.28 1664.77 1.19 5971225.27 592390.25 N 70 1951.823 W 14915 2.13i 7513.81 34.14 58.66 6964.92 ~608.48 1090.94 1709.73 1.36 5971253.47 592434.87 N 70 19 52.095 W 149 150.824"-"" 7607.74 32.85 59.49 7043.25 -625.42 1117.59 1754.19 1.46 5971280.65 592479.00 N 70 19 52.357 W 149 14 59.526 7702.15 33.61 59.28 7122.23 -642.59 1143.94 1798.71 0.81 5971307.53 592523.20 N 70 1952.616 W 1491458.226 7795.59 33.74 59.71 7199.99 -659.88 1170.24 1843.35 0.29 5971334.36 592567.51 N 70 19 52.875 W 149 14 56.922 7889.59 34.25 60.98 7277.92 -678.15 1196.23 1889.03 0.93 5971360.91 592612.87 N 70 19 53.130 W 149 1455.589 7982.97 35.39 61.55 7354.58 -697.49 1221.87 1935.78 1.27 5971387.10 592659.30 N 70 19 53.382 W 149 14 54.223 8077.32 36.66 60.90 7430.89 -717.58 1248.58 1984.41 1.41 5971414.40 592707.61 N 70 19 53.645 W 149 14 52.803 8171.18 38.16 58.47 7505.44 -736.76 1277.37 2033.62 2.24 5971443.78 592756.45 N 70 1953.928 W 1491451.366 8264.74 37.76 58.36 7579.21 -754.94 1307.52 2082.64 0.43 5971474.51 592805.11 N 70 1954.224 W 149 1449.935 8357.56 37.86 56.37 7652.54 -771.92 1338.20 2130.56 1.32 5971505.77 592852.64 N 70 19 54.526 W 149 14 48.535 V-03 ASP Final Surveys.xls Page 3 of 6 12/10/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVD VSec N/.S EJ.W DLS Northing Easting Latitude longitude (ft) n (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 8451.46 38.94 53.97 7726.13 -787.17 1371.52 2178.42 1.96 5971539.67 592900.09 N 70 19 54.853 W 1491447.138 8544.69 41.50 54.07 7797.32 .801.75 1406.88 2227.13 2.75 5971575.61 592948.37 N 70 19 55.201 W 149 1445.715 8637.98 41.19 54.43 7867.35 -816.92 1442.89 2277.14 0.42 5971612.22 592997.94 N 70 19 55.555 W 149 14 44.254 8730.61 40.63 55.06 7937.36 .832.36 1477.90 2326.68 0.75 5971647.83 593047.04 N 70 19 55.899 W 149 14 42.808 8823.48 40.10 54.71 8008.12 .847.81 1512.50 2375.88 0.62 5971683.01 593095.81 N 701956.239 W 149 1441.371 8917.44 38.69 53.86 8080.73 -862.53 1547.31 2424.30 1.61 5971718.40 593143.80 N 701956.581 W 149 1439.957 9009.57 38.87 51.75 8152.55 -875.32 1582.19 2470.26 1.45 5971753.83 593189.33 N 701956.924 W 1491438.614 9103.18 40.01 50.59 8224.85 -886.83 1619.48 2516.57 1.45 5971791.67 593235.19 N 701957.291 W 149 1437.262 9194.43 39.85 49.95 8294.82 -897.27 1656.91 2561.62 0.48 5971829.64 593279.78 N 701957.659 W 149 1435.946 9288.57 39.50 50.61 8367.28 -908.00 1695.32 2607.85 0.58 5971868.60 593325.53 N 70 1958.037 W 149 1434.596'-"'/ 9380.33 40.62 51.12 8437.51 -919.13 1732.59 2653.65 1.27 5971906.42 593370.88 N 70 19 58.403 W 149 14 33.258 9473.35 41.27 50.36 8507.77 -930.49 1771 .17 2700.85 0.88 5971945.57 593417.60 N 701958.782 W 1491431.879 9567.69 41.24 49.05 8578.69 -940.97 1811.40 2748.30 0.92 5971986.36 593464.56 N701959.178 W1491430.493 9660.03 39.05 48.37 8649.28 -950.00 1850.67 2793.03 2.42 5972026.17 593508.81 N 701959.564 W 1491429.187 9691 .93 39.88 49.20 8673.90 -953.09 1864.03 2808.28 3.08 5972039.71 593523.90 N 701959.695 W 149 1428.741 9797.44 43.18 49.49 8752.88 -964.46 1909.60 2861.35 3.13 5972085.91 593576.40 N70200.143 W1491427.191 9828.46 41.52 49.57 8775.80 -967.92 1923.16 2877.25 5.35 5972099.66 593592.13 N 70200.276 W 1491426.727 9858.56 41.83 49.03 8798.28 -971 .15 1936.21 2892.42 1.58 5972112.90 593607.15 N 70 20 0.405 W 149 14 26.284 9889.82 45.31 47.80 8820.93 -974.30 1950.51 2908.53 11.46 5972127.39 593623.08 N 70200.545 W 1491425.813 9919.82 48.04 44.29 8841 .52 -976.58 1965.67 2924.22 12.46 5972142.73 593638.59 N 70 20 0.694 W 149 14 25.355 9950.49 50.67 41.51 8861.49 -977.74 1982.72 2940.05 10-.-99 5972159.97 593654.21 N 70200.862 W 149 1424.892 9984.03 53.20 39.58 8882.17 -977.99 2002.78 2957.21 8.80 5972180.24 593671.12 N 70201.059 W 149 1424.391 10016.08 55.19 37.68 8900.92 -977.36 2023.09 2973.43 7.85 5972200.74 593687.09 N 7020 1.259 W 149 1423.917 10044.88 57.31 36.96 8916.92 -976.24 2042.13 2987.94 7.65 5972219.96 593701 .37 N 70 20 1 .446 W 149 14 23.493 10074.59 60.36 36.59 8932.30 -974.81 2062.49 3003.16 10.32 5972240.50 593716.34 N 70 20 1.646 W 149 14 23.048 ",-,,/ 1 01 06.48 63.47 33.86 8947.31 -972.46 2085.48 3019.38 12.33 5972263.68 593732.28 N 70201.872 W 149 1422.575 10137.85 68.83 30.81 8959.99 -968.62 2109.72 3034.70 19.26 5972288.09 593747.30 N 76 20 2.111 W 149 14 22.127 10169.36 73.35 27.06 8970.20 -962.88 2135.80 3049.10 18.23 5972314.35 593761.39 N 70202.367 W 1491421.706 10200.61 77.86 22.00 8977.98 -954.80 2163.32 3061.65 21.31 5972342.02 593773.60 N 70202.638 W 149 1421.339 10232.79 83.16 17.01 8983.28 -943.69 2193.22 3072.23 22.47 5972372.04 593783.82 N 70202.932 W 1491421.030 10258.79 86.12 12.90 8985.71 -932.73 2218.23 3078.91 19.42 5972397.12 593790.19 N 70203.178 W 1491420.835 10295.11 88.35 5.80 8987.4 7 -914.25 2254.00 3084.79 20.47 5972432.96 593795.65 N 70203.529 W 149 1420.662 10322.40 89.90 2.93 8987.88 -898.35 2281.20 3086.87 11.95 5972460.18 593797.39 N 70 20 3.797 W 149 1420.601 10359.50 89.18 1.18 8988.18 -875.54 2318.27 3088.20 5.10 5972497.27 593798.27 N 70 20 4.161 W 149 1420.562 10387.30 87.09 1.65 8989.09 -858.21 2346.05 3088.89 7.71 5972525.04 593798.62 N 70 20 4.435 W 149 1420.542 V-03 ASP Final Surveys.xls Page 4 of 6 12/10/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (O'100ft) (ftUS) (ftUS) 10420.10 84.68 0.88 8991.44 -837.74 2378.75 3089.61 7.71 5972557.75 593798.95 N 70204.756 W 149 1420.520 10451.01 83.92 3.10 8994.51 -818.81 2409.49 3090.68 7.56 5972588.50 593799.65 N 7020 5.059 W 149 14 20.489 10483.21 83.13 5.22 8998.14 -800.07 2441.40 3093.00 6.99 5972620.43 593801.58 N 7020 5.372 W 149 1420.421 10513.86 83.85 7.81 9001.62 -783.27 2471.65 3096.45 8.72 5972650.72 593804.67 N 70205.670 W 149 1420.319 10542.86 84.61 7.17 9004.53 -767.77 2500.26 3100.21 3.42 5972679.37 593808.08 N 70205.951 W 149 1420.209 10575.95 86.54 5.88 9007.09 -749.57 2533.03 3103.96 7.01 5972712.18 593811.44 N 70206.274 W 149 1420.099 10607.66 88.80 5.40 9008.37 -731.69 2564.56 3107.08 7.29 5972743.74 593814.17 N 70206.584 W 149 1420.008 10636.71 90.34 2.88 9008.59 -714.67 2593.53 3109.17 10.17 5972772.73 593815.91 N 70206.869 W 149 1419.946 10670.66 92.09 2.55 9007.87 -694.11 2627.44 3110.78 5.25 5972806.65 593817.11 N 70207.202 W 149 14 19.899 10701.35 92.92 0.60 9006.53 -675.06 2658.08 3111.62 6.90 5972837.30 593817.58 N 70207.503 W 149 14 19.874',,-,,/ 10732.87 93.91 359.85 9004.65 -654.93 2689.55 3111.75 3.94 5972868.76 593817.33 N 70207.813 W 149 14 19.870 10763.34 95.26 356.80 9002.22 -634.74 2719.90 3110.86 10.92 5972899.10 593816.07 N 70 20 8.111 W 149 1419.896 10795.29 96.22 357.27 8999.02 -613.07 2751.65 3109.22 3.34 5972930.82 593814.04 N 70208.424 W 149 1419.943 1 0826.16 96.67 352.98 8995.55 -591.43 2782.20 3106.61 13.89 5972961.34 593811.07 N 70 20 8.724 W 149 1420.019 10857.47 96.77 351 .18 8991.89 -568.36 2813.00 3102.33 5.72 5972992.08 593806.41 N 70209.027 W 149 1420.144 10888.85 96.43 348.46 8988.28 -544.42 2843.68 3096.82 8.68 5973022.69 593800.53 N 70209.329 W 149 1420.304 10919.84 97.33 346.84 8984.57 -520.06 2873.73 3090.24 5.95 5973052.66 593793.59 N 7020 9.624 W 149 14 20.496 10950.21 98.64 344.23 8980.35 -495.59 2902.85 3082.73 9.54 5973081.68 593785.73 N 70 20 9.911 W 149 1420.715 10985.29 98.88 339.92 8975.01 -466.22 2935.83 3072.06 12.16 5973114.53 593774.67 N 702010.235 W 149 1421.026 11013.40 98.85 337.39 8970.67 -441.85 2961.70 3061.95 8.89 5973140.27 593764.25 N 702010.490 W 149 1421.321 11045.00 99.17 335.19 8965.72 -413.87 2990.27 3049.40 .~.95 5973168.68 593751.35 N 702010.771 W 149 1421.687 11075.45 99.59 332.57 8960.76 -386.40 3017.25 3036.18 8.60 5973195.49 593737.81 N 702011.036 W 149 1422.073 11106.76 100.28 332.08 8955.36 -357.87 3044.56 3021.85 2.69 5973222.63 593723.15 N 702011.305 W 149 1422.491 11138.51 100.66 328.85 8949.59 -328.62 3071.72 3006.46 10.08 5973249.60 593707.44 N 702011.572 W 149 1422.940 11169.19 101.01 328.74 8943.82 -300.10 3097.49 2990.85 1.19 5973275.18 593691.52 N 70 20 11.825 W 149 14 23.39( 11200.06 100.07 326.30 8938.17 -271 .16 3123.09 2974.56 8.35 5973300.57 593674.92 N 702012.077 W 149 1423.871'-'-'/ 11231.53 98.82 325.23 8933.01 -241.28 3148.75 2957.09 5.20 5973326.02 593657.14 N 702012.330 W 149 1424.381 11262.82 97.33 324.59 8928.61 -211.35 3174.10 2939.28 5.17 5973351.15 593639.03 N 7020 12.579 W 149 14 24.901 11293.28 95.64 323.30 8925.17 -181.98 3198.57 2921.47 6.96 5973375.40 593620.93 N 7020 12.820 W 149 14 25.421 11324.10 93.26 322.25 8922.78 -152.01 3223.03 2902.88 8.44 5973399.63 593602.05 N 7020 13.060 W 149 14 25.963 11355.02 91.62 321 .38 8921.47 -121.78 3247.31 2883.79 6.00 5973423.68 593582.66 N 70 20 13.299 W 149 14 26.521 11386.60 90.31 319.60 8920.93 -90.73 3271.67 2863.70 7.00 5973447.79 593562.28 N 702013.539 W 149 1427.107 11417.67 89.38 318.64 8921.02 -60.05 3295.16 2843.36 4.30 5973471.03 593541.66 N 702013.770 W 1491427.701 11449.14 88.15 316.95 8921.70 -28.88 3318.47 2822.23 6.64 5973494.08 593520.25 N 702013.999 W 149 1428.318 11480.39 87.53 314.01 8922.87 2.20 3340.73 2800.34 9.61 5973516.07 593498.09 N 702014.218 W 149 1428.957 V-03 ASP Final Surveys.xls Page 5 of 6 12/10/2002-11 :49 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S EI.W DLS Northing Easting Latitude Longitude (ft) (") (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 11511 .73 86.26 312.78 8924.57 33.44 3362.23 2777.60 5.64 5973537.29 593475.10 N 70 20 14.430 W 149 1429.621 11542.50 84.02 311.96 8927.18 64.07 3382.89 2754.95 7.75 5973557.68 593452.20 N 70 20 14.633 W 149 14 30.282 11574.19 82.37 311.52 8930.93 95.52 3403.84 2731.47 5.39 5973578.34 593428.47 N 70 20 14.839 W 149 14 30.968 11604.70 81.78 309.64 8935.14 125.73 3423.50 2708.52 6.40 5973597.71 593405.29 N 702015.033 W 149 1431.638 11636.85 82.02 309.16 8939.67 157.56 3443.70 2683.93 1.66 5973617.61 593380.46 N 70 2015.231 W 149 1432.356 11667.62 83.44 306.87 8943.56 188.06 3462.49 2659.88 8.71 5973636.12 593356.19 N 70 2015.416 W 1491433.058 11698.50 83.78 305.12 8947.00 218.67 3480.53 2635.05 5.74 5973653.85 593331.14 N 702015.594 W 149 1433.783 11729.49 84.57 301.18 8950.15 249.28 3497.38 2609.24 12.90 5973670.39 593305.14 N 702015.760 W 149 1434.537 11761.12 85.81 299.76 8952.80 280.36 3513.37 2582.08 5.95 5973686.04 593277.78 N 702015.917 W 1491435.330 11791.43 85.61 298.12 8955.07 310.02 3527.99 2555.63 5.44 5973700.34 593251.16 N 702016.061 W 14914 36.102'~ 11823.00 85.60 296.37 8957.49 340.72 3542.40 2527.65 5.53 5973714.41 593223.01 N 70 2016.203 W 149 1436.919 11854.47 85.47 296.46 8959.94 371.22 3556.36 2499.55 0.50 5973728.03 593194.75 N 702016.340 W 149 1437.740 11885.23 85.54 296.74 8962.35 401 .05 3570.09 2472.13 0.94 5973741.42 593167.16 N 70 2016.475 W 149 1438.541 11917.33 85.95 296.53 8964.73 432.19 3584.44 2443.51 1.43 5973755.42 593138.38 N 70 2016.616 W 149 1439.376 11948.44 86.36 297.67 8966.82 462.45 3598.58 2415.88 3.89 5973769.23 593110.58 N 702016.756 W 149 1440.183 11979.99 85.85 298.45 8968.96 493.25 3613.39 2388.10 2.95 5973783.70 593082.63 N 7020 16.901 W 149 14 40.994 12009.59 85.61 300.68 8971 .16 522.27 3627.95 2362.43 7.56 5973797.95 593056.79 N 70 20 17.045 W 149 14 41.744 12040.62 85.61 301.11 8973.54 552.82 3643.84 2335.88 1.38 5973813.51 593030.05 N 702017.201 W 149 1442.519 12072.06 85.47 300.61 8975.98 583.77 3659.91 2308.98 1.65 5973829.26 593002.95 N 702017.359 W 149 1443.305 12102.79 85.30 298.73 8978.46 613.90 3675.08 2282.36 6.12 5973844.10 592976.16 N 702017.508 W 149 1444.082 12133.83 85.30 299.07 8981.00 644.26 3690.03 2255.28 1,,,09 5973858.72 592948.90 N 702017.655 W 149 1444.873 12165.17 86.50 300.48 8983.24 675.02 3705.55 2228.15 5.90 5973873.91 592921.59 N 702017.808 W 149 1445.665 12195.81 86.54 302.10 8985.10 705.25 3721.43 2202.01 5.28 5973889.47 592895.27 N 7020 17.964 W 149 14 46.428 12228.38 86.91 301.65 8986.96 737.44 3738.60 2174.40 1.79 5973906.31 592867..45 N702018.133 W1491447.235 12259.15 86.57 300.99 8988.71 767.81 3754.57 2148.16 2.41 5973921.96 592841 .02 N 702018.291 W 149 14 48.001.~ 12288.78 84.99 299.48 8990.89 796.93 3769.45 2122.63 7.37 5973936.53 592815.31 N 702018.437 W 149 1448.747 12320.88 85.06 299.55 8993.67 828.37 3785.21 2094.80 0.31 5973951.94 592787.30 N 7020 18.592 W 149 14 49.559 12352.21 85.16 298.87 8996.35 859.04 3800.44 2067.55 2.19 5973966.84 592759.87 N 702018.742 W 149 1450.355 12383.10 85.71 302.01 8998.80 889.40 3816.04 2041.01 10.29 5973982.12 592733.14 N 702018.895 W 1491451.130 12414.35 85.71 301.56 9001 .14 920.24 3832.45 2014.52 1.44 5973998.21 592706.46 N 702019.057 W 149 1451.904 12445.66 86.19 301 .66 9003.35 951.14 3848.82 1987.92 1.57 5974014.25 592679.67 N 702019.218 W 1491452.681 12476.54 85.75 304.34 9005.52 981.71 3865.60 1962.09 8.77 5974030.71 592653.64 N 7020 19.383 W 149 14 53.435 12508.21 84.61 303.48 9008.19 1013.09 3883.20 1935.90 4.50 5974048.00 592627.24 N 702019.556 W 149 1454.200 12538.34 84.75 301.68 9010.98 1042.84 3899.36 1910.62 5.97 5974063.85 592601 .77 N 702019.715 W 149 1454.938 12591.00 84.75 301.68 9015.80 1094.72 3926.90 1866.00 0.00 5974090.84 592556.82 N 702019.986 W 149 1456.241 V-03 ASP Final Surveys. xis Page 6 of 6 12/10/2002.11 :49 AM .) ') éXoa-~/5 MWD/lWD log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-03 Date Dìspatche 10-Dec-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppìes Surveys 2 RECEIVED DEC 12 2002 Alaska O;t & Gas t~""t^ {:"m . . VWt Y. vv. mISSIOn Ancho"sge Received BYc¥(~~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 V-03 ) ) Subject: V -03 Date: Mon, 2 Dee 2002 14:31 :54 -0600 From: "Franks, James D" <FranksJD@BP . com> To: "'winton - aubert@admin.state.ak.us'" <winton - aubert@admin.state.ak.us> Wt-L1Ç Winton, On the BHPChartTVD tab there is a plot that I have placed notes on outlining the operations over the past weekend. If you have some questions or need clarification on anything, let me know. We believe that the method of getting gas back in the well is in a breathing phenomenon with losing mud to the Shublik and getting gas back. Thanks, james «V-03 Geosurvey - stearns. ZIP» James Franks BP GPB Rotary Drilling - 9ES office: 907-564-4468 cell: 907-440-0187 --- ~- -"- -- - - --- --- - --- -. "-- ____n___---______n- ----- ---- - - -- - -- ------ - -- - - --- - -- - -- -- - - -- -- --- - -- -- - --- - - ___n - -- -______n_m --- - - - - .. -- - ---" _"___n- -- --- ---- -" - _0., Name: V -03 Geosur\'t?y - steams. ZIP ' '~V-03 Geosurvey - steaJl1s.ZIP Type: Zip Compressed Data (applieation/x-zip-eompressed)~ Encoding: base64 ~ .=~=".......... ..... "~"""""'~'*'"'=='~"""'-"-"""'~'1>="""'~~~"'''''''4~'''''''''''.z~».:'=h~¡:,o.:.»»;,o.:.:,,,,~.=~ Borehole Profile - MD vs TVD ,\- T ! ! . ¡ ¡ Î ! I . I I í { F 3Ul! !t4 -- ,~~t 40' t!HU\'¡ '-J.. - LJ "---r ~~~~----~-f------+:;;--l , 1 drill from 11700' La 11813'. G.(}S (:ul ITII.ld to "unacl!. \ ¡ . Increase mw to 9.5 noted an mere-él'5-!." 111 1055('$ , ¡ . from 6bph to 11 IJph@11755' \; I . ,. , .. I ---_J~'~~--~~:i \. . -- l dnllto 11844' losse5 stabilized@6bpl!.Drilíto \. I \.! 12311 with some slight flow InCr.easp. mw fO 9.6 . I ! /. ppg. Losses @ 10.15 bpll tlynarrm; :! \ . . ¡. . ! I r,,;i~.I>' 111"'1 !(. ~I.~ for trip margin . flow check-1hph ¿¡.~d not ~irn,i,nishi~ìg. with time. \ \ I.: .' \ - /.- ... ¡-jl)!1 .fëf bil <"HP.1 !n,ltor minor to . Not thought to he brcatllll1g . Welgnt lip to 9.!i I ~; I. ,( r ..'- no IOS~('5 -;, while drilling to 12435' - appears lo be stahle . ! j636.85 J ¡ ";, .(,-,": . - I I'\.. ~ .; 1 '50. ~..ø6- -~. ¡ ---.._---.------~i\-~ ..~ 10.2. Clre at redueod rate -- 1/.2 hprn losses 1.75 . \-- \:>:.--~. ~ I r : . l \ ~~. '. ¡ bpll. Shut in well - flowing slightly. ,! ¡ I . "--. : ; '~."''''jWcllpl'\lIr;I/..'. ... . . ,.." ~ ..1"- -.\ I í .:.. ..\.0 ..~',J. ¡- . ¡. 9000- .1 Rod'!:o C~rrif'élt)le fnrJ Plan\ ---------~- 7-- - ---_---._----_---.+.---- _1' --l------------------------- - ...-- -- ---- .----------~---------..,---- --_:- ------- -~¡Iiddelt() -,110=6:',iboILotl -- ~ .,. I . J [II os:= 1':. ,} ~;. . '. ¡ "-.... 1, ! I, 11:-,75' o:;,~(>S 9° lrom:, to ~~ bp "j, P " - t , , ." . .... i I - .' . ll!np \',::.;;; ~;"NH:>p~ 0 , --. *,,' 0 I t 5lrH1!J 111 b,:lIiltlbN Lo';;:>,-.'''; ~till- il;lt': control f:crJ I -- - . '~ -----I---:'-------r~'--J-----r @ .~"~~h:~ 1 ;"'. -~L-' - - n ---k 13500 13000 12500 12000 11500 11000 10500 10000 8750 . -. -.- " .'--'--. ! I c¿¡~,in~J p'->illl 97G3' fIl1U.~;11 ~ --. : 'I ¡ 8MO 8850 ~~ ~ 9050 - 14000 T~- ----- ---------- j I r ,>LH1 t3hir\(..I k'~.~,,';; (~;2~'.bph. -rr<::'[itpd b~jck kG .i bp~¡ . f trip ¡or ü,! 1~10096', Ca!> nit mud 10 ,>u,f,,(;~. S¡,~~j'? hJ.::k In. nt' 9¿H> cut rmJ(Ì. ¡';¡;jj<,!:, mll(j \.'\fE¡i~iht to 9 ~ iO:~$('s MD TSGR] -...-.v ~ ~ --"-~ ~oo .~ ~1r!Æ ~ æ (ill ~ !Æ l!Æ~ æ TONY KNOWLES, GOVERNOR ATßASIiA OIL AlO) GAS CONSERVATION COJDIISSION B ill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit V-03 BP Exploration (Alaska), Inc. Permit No: 202-215 Surface Location: 4892' NSL, 1562' WEL, Sec. 11, T11N,R11E, UM Bottomhole Location: 4091' NSL, 722' WEL, Sec. 02, T11N, RIlE, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional 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 fight to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title ?O, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ CammfOechsli Taylor Chair BY ORDER~r THE COMMISSION DATED thi~ day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " WGA- ullR{o'1- ~ '0, STATE OF ALASKA ...~. ALASKA ,-1 AND GAS CONSERVATION COMM._~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 82' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / V-03 9. Approximate spud date 11/05/02/ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 43722' MD 18947' TVD 0 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 103 Maximum surface 2774 psig, At total depth (TVD) 6860' I 3460 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2747' 2747' Surface Surface 9798' 875T 9648' 8642' 13722' 8947' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 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 4892' NSL, 1562' WEL, SEC. 11, T11 N, R 11 E, UM At top of productive interval 1684' NSL, 1450' EWL, SEC. 01, T11N, R11E, UM At total depth 4091' NSL, 7221 WEL, SEC. 02, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028238, 11881 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 28001 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina 20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 TC-II Number 2S100302630-277 Hole 42" 12-1/4" 8-1/2" 6-1/8" Lenath 801 2719' 9770' 4074' Quantitv of Cement (include staae data) ,260 sx Arctic Set (Approx.) 486 sx Permafrost ILl, 295 sx 'G' 582 sx Class 'G', 183 sx 'G' 467 sx Class IG' /' 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 feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED OCT 2 32002 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I h. .e. re..b.Y... certify..t..h. at. the.. .{o...lwgc..e..go.i..n..~...i.S.. ".'-..u. e.... and correct to th.e be....st of m..y..~..n.owl~.. dge . '. Signed BiIIlsaacsonk ; ~ ~ -~ .c, , Title S~nlor" Dnlllng E~gl~eer - Date - J () I 'z z J 0 '- "/-'{i'~""('<.-<":' .......\).:.~,;;',';..<.;-i':'~L',~::;<..,.' - .., ..: :,eommi$siØD-UM:ØftIy\>:f;-~";':'..~.."<': . . . Permit Number. API Number APff]~ D9¡te See cover letter ..2 0.2 - ;2... / ,5 50- 0.2 7 - 2. .3/2-71 \ I JÎ) ,7\ for other requirements Conditions of Approval: Samples Required 0 Yes E No Mud Log Re Ulred 0 Yes ŒI No Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE .. 0 2K 0 3K. D4K 0 5K 0 10K P 15K.D 3.5K psi for CTU ~::;~ -Ie 1./010 p,;. þ N ..".tT"", \l.I e..<, W--;'y~~r'::o¡. t OIL ....:d. . ~0 /,0. .') Approved By Commissioner the commission Date' I [.,' /\ Form 10-401 Rev. 12-01-85 fO: ' R..'. ... I tLJ~' 1 i\! l\ l Sub it n Triplicate . ,\ ~ II ~ ¡\ '-. " -) ..\tAt!. bp ~~~ . ~~. ..~ F'" ."1-\- ) To: Winton Aubert, AOGCC Date: Oct. 21 2002 From: J ames Franks Subject: Dispensation for 20 AAC 25.035 (c) on V-03 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter / system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the Borealis/Kuparuk wells at L-pad or V -pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All of the Borealis Development were drilled to the shale underlying the SVl sands. The shale underlying the SVl is the deepest planned surface casing setting depth for. future pad development wells. This casing point is :t200' TVD above the U gnu horizon. ~ RFT's from NWE 1-02 recorded po~e e. sures of 1,275 psi at 2782' TVDSS~Ppg EMW) and 1).87 psi at 3059' TVDs (8. ppg EMW) in the Ugnu. V-03 is p~ed to reach a 9.5 ppg mud weight before T aí- -2,683' TVDss. This request is being made based on V-Pad data submitted regarding mud weight, surface open hole logging in the Borealis development (PEX/Dipole sonic), and a meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, J ames Franks GPB Rotary Drilling Engineer 564-4468 ) ) IWell Name: Iv-03 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer / Surface Location: As-Staked Target Location: Top Sadlerochit Bottom Hole Location: x = 590,738.40' Y = 5,970,142.23' 4892' FSL (387' FNL), 1562' FEL (3718' FWL), Sec. 11 T11 N, R11 E X = 593,722.84' Y = 5,972,250.29' 1684' FSL (3595' FNL), 3830' FEL (1450' FWL), Sec. 1, T11N, R11E X = 591,520' Y = 5,974,630' 4091' FSL (1188' FNL), 7221 FEL (4558' FWL), Sec. 2, T11 N, R11 E I AFE Number: 1 PBD4P2023 1 I Estimated Start Date: 111/5/2002 I I MD: 113722' I I TVD: 18947' I I Rig: 1 Nabors 9ES ../ I Operating days to complete: 127.2 I RT/GL: 128.5' 1 1 RKB: 182.0' I Well DesiQn (conventional, slim hole, etc.): 1 Ultra Slimhole Horizontal I Objective: 1 Single zone producer into the Ivishak formation. Directional: Ver. Anadrill P6 KOP: 2800' Maximum Hole Angle: Close Approach Wells: 103.37 deg at 11,158' MD All wells pass major risk crite" The nearest well is: V-103 - 60.13 ctr-ctr@ 500' None IFR-MS corrected surveys will be used for survey validation. Logging Program: Surface Production Hole Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: MWD I GR None None MWD/GR/PWD/RES None Intermediate Hole MWD/GR/PWD/RES None V-03 Drilling Permit Page 1 ) Mud Program: 12 1fi¡" Surface Hole (O-2747'): Densitv Viscosity (ppg) (seconds) 8.5 - 9.2 250-300 9.0 - 9.5 /1 200-250 9.5 max 150-200 Initial Base PF to top SV SV toTO ) Fresh Water Surface Hole Mud Yield Point (lb/1 OOft~) 50 - 70 30 - 45 20 - 40 API FL (mls/30min) 15 - 20 <10 <10 PH 8.5 -9.5 8.5-9.5 / 8.5- 9.5 83.4 " Production Hole (2747' - 9798'): LSND Interval Density Tau 0 YP PV pH API 10' Gel (ppg) Fi It rate Upper 9.7 4-7 25-30 1 0-15 8.5-9.5 6-10 10 Interval 10.3 / Top of HRZ 3-7 20-25 1 0-15 8.5-9.5 4-6 10 toTO 6 1/8" Production Hole (9798' - TD'): Interval Density Tau 0 YP (ppg) 9.0 Upper Interval 5-8 22 - 30 Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill A V GPM Pipe (fpm) 550 4" 17.5# 90 650 4" 17.5# 110 Pump PSI 1800 2400 0-1782' 1782'-2747' Production Hole: 8 %" Interval Pump Drill Pipe GPM 2747' - 9798' 600 4" 17.5# AV (fpm) 240 Pump PSI Production Hole: 6-1/8" Interval Pump Drill Pipe GPM 325 4" 17.5# AV (fpm) 370 Pump PSI 9798' - TO' V-03 Drilling Permit PV 5-8 ECD ppg-emw 10.0 10.2 3400 ECD ppg-emw 11.2 3400 ECD ppg-emw 12.5 pH 8.5 - 9.0 BaraDrillN API MBT Filtrate NC <3 Motor Jet Nozzles ("/32) N/A N/A TFA (in2) 18,18,18,16 .942 18,18,18,16 .942 Motor Jet Nozzles ("/32) N/A TFA (in2) 3x14,3x15 .969 Motor Jet Nozzles ("/32) N/A 6x11 TFA (in2) .552 Page 2 ") ) CasinglTubing Program: Hole Csgl Wt/Ft Gr~e Conn Length Top Btm Size Tbg O.D. MDrrVD MDrrVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 12 %" 9 5/8" 40# L-80 BTC 2719' GL 2747'/2747' 8Y2" 7" 26# L-80 BTC-m 9770' GL 9798'/8757' 6 1 /8" 4Y2" 12.6# L-80 IBT-m 4074' 9648'/8642' 13722'/8947' Tubing 4 Y2" 12.6# L-80 TC-II 9620' GL 9648'/8642' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from surface shoe LOT 11.8 ppg Intermediate Casing Shoe 20' min from intermediate shoe FIT 10.5 ppg Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 19-518" Surface String I Basis: Lead: Based on conductor set at 110', 1782' of annulus in the permafrost @ 250% / excess and 218' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD(>500'TVD) open hole volume+~% excess + 80' shoe track volume. Tail TOC: At -2000' MD ./} Total Cement Volume: Lead 359 bbl I 2016 fe f. 486 sk$" of Halliburton Permafrost L at 10.7 ppg and 4.115 cf/sk./ Tail 60.5 bbl I 339 ftC/ 295 sk...... s of Halliburton 'G' at 15.8 ppg and 1 .15 cf/sk. . ¿ ---""'--/ Casinq Size 17" Intermediate String I Basis: Stage 1: Based on TOC 750' MD above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: Tail from shoe to 6377' MD Total Cement Volume: Tail 123.5 bbl I 693 fe /582 sks of Halliburton 'G' at 15.8 ppg and 1 .19 cf/sk. I :' Basis: Stage 2: Based on TOC 500'MD above top of Ma Sapds + 300/0 excess Cement Placement from 200' MD below Schrader Bluff formation to 3541' MD Total Cement Volume: Tail 40 bbl I 223 fe Æ 18B/~ks of Halliburton 'G' at 15.6 ppg and 1.20 cf/sk. \.<~i Casinq Size 14 %" Production Liner I Basis: Based on TOC 200' above top of Liner + 30% excess + 80' shoe - Liner top 150' above 7" shoe Cement Placement: Tail from shoe to 9648' MD (top/of liner) Total Cement Volume: Tail 96 bbl I 537 fe I 46,?! sks of Halliburton 'G' at 15.8 ppg and 1 .16 cf/skt I V-03 Drilling Permit Page 3 ') ) / Formation Markers: Estimated Hydrocarbon Estimated Estimated Formation Tops Uncertainty Bearing Pore Press. Pore Press. Formation (tvdss) (feet) (Yes/No) (Psi) (ppg EMW) SV5 -1550 +1-50' SV4 -1680 +/-50' Base Permafrost -1700 +/-50' No 740 8.4 SV31 -2075 +/-50' Yes 910 8.4 SV21 -2240 +/-50' Yes 980 8.4 SV11 -2565 +/-50' Yes 1120 8.4 UG4 -2865 +/-50' Yes 1250 8.4 UG4A -2895 +1-50' Yes 1270 8.4 UG3 -3230 +1-50' Yes 1410 8.4 UG1 -3655 +/-50' Yes 1600 8.4 Ugnu Ma -3915 +1-25' Yes 1700 8.4 Ugnu Mb1 -3960 +/-25' Yes 1720 8.4 Schrader Na -4170 +/-25' Yes 1840 8.5 Schrader OA (WS1) -4340 +1-25' Yes 1920 8.5 Schrader Bluff OBa -4405 +/-25' Yes 1940 8.5 Schrader Bluff OBd -4555 +/-25' Yes 2020 8.5 Base Schrader Bluff (OBf base) -4700 +/-25' No 2070 8.5 CM2 -5035 +1-50' No 2220 8.5 CM1 -5715 +/-50' No 2520 8.5 (O'~ THRZ -6260 +1-50' No 2780 8.5 BHRZ -6465 +1-50' No 2850 8.5 Top Kuparuk Fm. (TKUP)2 -6535 +/-50' Yes 2900 8.5 LCU2 -6670 +/-50' No 3350 9.7 TML V2 -6860 +/-50' No 3460 9.7 Top Kingak (TKNG) -7660 +/-50' No 3370 8.5 T JG (not present) n/a n/a No TJF -7825 +/-50' No 3440 8.5 TJE -8125 +1-50' No 3580 8.5 TJD -8255 +/-50' No 3660 8.5 TJC -8530 +/-50' No 3750 8.5 TJB -861 0 +/-50' No 3800 8.5 T JA - Faulted Out n/a n/a No Top Sag River (TSGR)3 -8670 +1-50' Yes 3940 8.7 '1.0 Shublik A -8700 +/-50' Yes 3940 8.7 Shublik B4 -8771 +/-50' Yes 3960 8.7 Shublik C -8789 +/-50' Yes 3990 8.7 Shublik D -8812 +1-50' Yes 3995 8.7 Top Eileen Ss (TElL) -8830 +/-50' Yes 3995 8.7 Top Sadlerochit (TSAD)3 -8845 +1-50' Yes 4000 8.7 TZ4a -8965 +/-50' Yes 8.5+ HOT -8965 +1-25' POWC -8965 +/-25' TZ3 (not reached) -9030 +1-50' No V-03 Drilling Permit Page 4 ) ) Well Control: /' Surface hole will be drilled without diverter - pending receipt of waiver from the AOGCC. The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for f~,re fracture stimulation treatment, the BOP equipment will be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3460 psi @ 6860' TVOss - Kuparuk A Sands . Maximum surface pressure: 2774 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) / . Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi as required for fracture stimulation.) . Planned completion fluid: 9.8 ppg filtered seawater / 6.8 ppg diesel for 100 psi O/B Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-03 Drilling Permit Page 5 ') ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor to be installed in Oct. 2002. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up spool (diverter waiver requested). PU 4" DP as required and stand back in derrick. 3. MU 12 1,4" drilling assembly with MWD/LWD (page 2) and directionally drill surface hole to approximately 100' TVD below the SV1 Sand9' An intermediate wiper/bit trip to surface for a will be performed prior to exiting the Permafrost. / 4. Run and cement the 9-5/8", 40# surface casing back to surface. ./ 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. ~5~~::~;~~~~n~i~~~:s~b~With MWD/L~,~~~~ 2) and RIH to float collar. Test the 9-5/8" casing to 7. Drill out shoe joints and displace well tei'9.7 ~ drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. ~-~. 8. Drill ahead to first wiper trip. 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD just below the top of the Sag River - estimated at 8733' TVD. 11. Condition hole for running 7" 26# intermediate casing. ~ 12. Run and cement the 7" intermediate casing in two stages. (To be reviewed based on log/operational results.) Displace the cement with drilling fluid. / 13. MU 6-1/8" drilling assembly with MWD/LWD(page 2) and RIH to float collar. Test the 7" casing to 4000 psi for 30 minutes. 14. Drill out shoe joints and displace well to 9.0 ppg drilling fluid. Drill new formation to 20' below 7" shoe and perform Formation Integrity Test. 15. Drill horizontally to TD with the assistance of the on-site Geologist. 16. Run and cement the 4-1/2" L-80 production liner - 150' overlap of the 7" casing. 17. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. ..-/ 18. Test the 4 Y2" and 7" casing from the 4 Y2" landing collar to surface to 4000 psi for 30 minutes. 19. RIH w/3 3M" bit on 2/78" drillstring and cleanout the liner to PBTD, Change well to 9.8 ppg brine. 20. PU Halliburton perf guns and RIH on DP. Perforate -1500' of Zone 4b in the horizontal section, POOH LD DP / 21. Run the 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. 22. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 23. RU hot oil truck and freeze protect well by pumping 3000' of diesel. Allow to equalize. 24. Rig down and move off. / V-03 Drilling Permit Page 6 ') ) V-03 Drilling Program Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location is V-103, 30' to the West. )- Check the landing ring height on V-03. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~~"_'lW._--"",_W.'M"_'_WW>.''''^'''^'-*''-'''''''''''''''''''.'''''-''''''''''''<'».<W~'_w.,'''',,,,''''w>' Job 2: Drillinq Surface Hole )- There is one nearby well issue in the surface hole. Refer to page 2 for details. )- Camera Based Gyro survey may be required per the directional plan to 1000' MD or until the magnetic interference at the surface has dissipated. (To be confirmed). )- Gas hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations ''''''_k~w.'.<o.«o».YM'^''-''''-'' Job 3: Install Surface CasinQ Hazards and Contingencies )- It is critical that cement is circulated to surface for well integrity. 2500/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at :1:1 OOO'MD to allow remedial cementing. )- "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" »^--- V-03 Drilling Permit Page 7 ) ) Job 4: DrillinQ Intermediate Hole Hazards and Contingencies ~ V-03 will cross the following fault.: Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. In the Ugnu - 3435 TVDss - estimated throw of 75' with 150' MD of uncertainty. This fault has been crossed many times in the Borealis project. No losses have been encountered and none are expected. In the Colville - 6304'TVDss - estimated throw of 40' with 150' MD of uncertainty. Historically while drilling on the Borealis project, faults in the Colville have not been problematic with respect to losses. Lost circulation is considered low to medium risk. In the Kingak - 8702' TVDss - estimated throw of 100' with 150' MD of uncertainty. This fault has not been crossed. Lost circulation is considered low to medium risk. ~ KICK TOLERANCE: In the scenario of 9.7 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 11.8 ppg at the surface casing shoe, 10.3 ppg mud in the hole the kick tolerance is 26.2 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 11.8 ppg. V-Pad development wells have "kick tolerances" in the 30-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ Drilling too far into the Sag River formation prior to setting casing has been problematic in the past. When getting close to the anticipated casing point, slow the drilling rate and monitor cuttings to ensure that casing is set at the optimum depth to allow cementing of the long column needed to cover the Kuparuk. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HrZ" Job 6: Case & Cement Intermediate Hole Hazards and Contingencies ~ The interval is planned to be cemented in a two stages. The first stage is to cover the interval from TD to 750' above the TKUP. This slurry is to be a 15.8 ppg slurry. The second stage is designed to cover the Schrader Bluff formation from 200'MD below the formation via a stage tool to 500' MD above the Ma Sands and is to be a 15.6 ppg slurry. ~ Ensure a minimum hydrostatic equivalent of 10.3 ppg during pumping of cement preflushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" V-03 Drilling Permit Page 8 ) .:. "Freeze Protecting an Outer Annulus" -~-~~ Job 7: DrillinQ Production Hole Hazards and Contingencies ~ V-03 crosses one fault in the horizontal section of the well. This fault is to be expected at - 11845' MD based on P2 from Anadrill. This fault is anticipated to be upthrown about 40'. Relative uncertainty of the fault is 150' MD. No losses are anticipated when crossing this fault, but follow the Lost Circulation Decision Tree should losses occur. This fault is considered to be risky due to not having crossed it before. ~ KICK TOLERANCE: In the scenario of 8.7 ppg pore pressure at the Top Sadelrochit target depth, gauge hole, a fracture gradient of 10.5 ppg at the surface casing shoe, 9.0 ppg mud in the hole the kick tolerance is infinite. ~ After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead crude (2300' MD, 2221 'TV D) , the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance /1 to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. ,_.'1<-»»>~»>,»»»""",,*,,,,,,,,,,----, Job 9: Case & Cement Production Hole Hazards and Contingencies ~ Minimize the time the pipe is left stationary while running the liner on the off chance that differential sticking is encountered. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Modified Conventional Liner Cementing" RP .:. "Handling and Running 13-Cr" V-03 Drilling Permit Page 9 ) ~) Job 10: DPC Perforate Well Hazards and Contingencies Hazards and Contingencies ~ The well will be perforated balanced. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. Essentially personnel only should be present on the rig floor while making up DPC guns. ~ Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Reference RPs .:. "Drill pipe Conveyed Perforating" ,""'"*,'''''",*,",,,,,,.,,~,,,,,,,,,,,,,,''''''W<V#_--'''''-'''W''''''~~).._'''''''''''''''''M'''''-,-,,,,,,,,,,,,,,,,,,,_w.~~~ Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus .h>.*-'._~"',*---.'»,""'~-''¡': V-03 Drilling Permit Page 1 0 I I I 9-5/8" CSG, 40#, L-80, ID= 8.835" I.., 2747' ~ I 4-1/2" L-80, 12.6 Ib/ft, TC-II Tubing l-i 9648' L TREE = 4-1/16" CIW ~~§~~.~~,[) ~ "^' mmm~^wwwm FMC ACTUA TOR = N/A kïr~a::BT,;^w,.m,~w,m..w "w~'ã~röí .W"".'.W.W.'.'.'.'.'.'.W"'W.W.W.'.'.'.'.WM","^".W.~'.~~'.',.w.'.w..,~,.'.'.'.'.'.'.'...wm.W.'.'.V.'.'.W.W.'.'.W.W,',W BF. ELEV = " "".',wn.,'.w."" "'W"W """^W,""w,.,"^".,.,',',.,',.,','.~..,w,.,'.w,',"'-W-"'." KOP = 2800' '..mw",w,w,'"",'''''.w.'.w...."..',',.V.Wm.W,W''''''.-w.v,..','"v,w.....wo','",'""',.."""w",,....w,,","'.'.w.,w.,,' Max Angle = 'Di1iumrJiö;w".m,,,m,,, ." ~w...'...w",.'.'.w.'.W.W.W"M''''''''''''''N.'''''''''MW.W.'.w.'","""W.W.WN.W' ," Datum TVD = ') SS Minimum ID = 3.725" XN Nip I 7" CSG, 26#, L-80, 0.0383 bpf, 10=6.276"1.., 9798' ÆRFORA TION SUMIV1ARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE DATE REV BY COMMENTS 10121/02 PGS HORIZ COMPLETION V-03 SAF~)NOTES: - / I 1000' H 9-518" TAM Port Collar - 1 2200' ~14-1/2" HES X Nippple, ID= 3.813" ~ GAS LIFT IV1ANDRELS DEV TYÆ VLV LATCH PORT DATE ST MD TVD 1 2 3 4 5 6 9568' ~14-1/2" X Nipple (3.813" ID) I ~ ] C / \ . ... 9588' ~I Baker S-3 Packer 9608' 9628' 1"'4-1/2" X Nipple (3.813" ID) I 1"'4-1/2" XN Nipple (3.725" ID) I I 9648' I.., ZXP Liner top Packer .. .. PBTD I.., 13642' 1 l 4-1/2" L-80, 12.6#, IBT-m 1-1 13722' I DA TE REV BY COMMENTS PRUDHOE BA Y UNIT W8...L: V -03 ÆRMITNo: API No: BP Exploration (Alaska) ) ') V-03 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Intermediate Hole Section: . A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The intermediate section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the Kingak shale and to cover the Kuparuk 9.7 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices have contributed to favorable hole conditions. Production Hole Section: . Swabbing of fluid into the horizontal well is a concern. Gas in this formation is likely. The horizontal portion of the well allows for a storage area for the gas and may not be noticed until a horizontal section is full starts to enter the vertical section. . HYDROGEN SULFIDE - H2S This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies õ I KBE SV5 SV4 Base Permafrost SV3 SV2 SV1 9-5/8" Csg pt KOP 1.25/100 Bid 2.5/100 UG4 UG4A UG3 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE YIX: Grid Convergence Angle: Grid Scale Factor: V-03 Proposed Well Profile - Geodetic Report October 17, 2002 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) stdy Vertical Section Origin: V-Pad / Plan V-03 818ty. TVD Reference Datum: V-03 8 I TVD Reference Elevation: V.03 Fea51 bl Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: V-03 (P6) / October 17, 2002 Total Field Strength: 195.341 ° /7301.83 ft /6.336/ 0.80E Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.32815826, W 149.26409723 Magnetic Declination Model: N 5970142.230 ftUS, E 590738.400 ftUS North Reference: +0.69295694° Total Corr Mag North.> True North: 0.99990935 Local Coordinates Referenced To: Schlumberuer Minimum Curvature / Lubinski 60.000° N 0.000 ft, E 0.000 ft KB 82.0 ft relative to MSL 55.000 ft relative to MSL 25.752° 57507.229 nT 80.772° November 14, 2002 BGGM 2002 True North +25.752° Well Head ~ Grid Coordinates Geographic Coordinates MD I Incl I Azim I TVD I VSec I N/-S I E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 59.00 0.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 1632.00 0.00 59.00 1632.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 1762.00 0.00 59.00 1762.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 1782.00 0.00 59.00 1782.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2157.00 0.00 59.00 2157.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2322.00 0.00 59.00 2322.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2647.00 0.00 59.00 2647.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2747.00 0.00 59.00 2747.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2800.00 0.00 59.00 2800.00 0.00 0.00 0.00 0.00 5970142.23 590738.40 N 70.32815826 W 149.26409723 2900.00 1.25 59.00 2899.99 1.09 0.56 0.93 1.25 5970142.80 590739.32 N 70.32815979 W 149.26408969,,-,) 2947.03 2.43 59.00 2947.00 2.60 1.34 2.23 /2.50 5970143.60 590740.61 N 70.32816192 W 149.26407915 2977.07 3.18 59.00 2977.00 4.07 2.09 3.49 2.50 5970144.36 590741.86 N 70.32816397 W 149.26406893 3000.00 3.75 59.00 2999.89 5.45 2.81 4.67 2.50 5970145.10 590743.04 N 70.32816594 W 149.26405936 3100.00 6.25 59.00 3099.50 14.17 7.30 12.14 2.50 5970149.68 590750.45 N 70.32817821 W 149.26399879 3200.00 8.75 59.00 3198.64 27.21 14.02 23.33 2.50 5970156.53 590761.56 N 70.32819657 W 149.26390805 3300.00 11.25 59.00 3297.11 44.58 22.96 38.21 2.50 5970165.65 590776.33 N 70.32822099 W 149.26378738 3315.19 11.63 59.00 3312.00 47.59 24.51 40.80 2.50 5970167.23 590778.90 N 70.32822522 W 149.26376638 3400.00 13.75 59.00 3394.73 66.21 34.11 56.77 2.50 5970177.02 590794.75 N 70.32825145 W 149.26363687 Station ID V-03 (P6) report1.xls Page 1 of3 10/17/2002-2:28 PM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim TVD I VSec I N/-S E/-W I DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 3500.00 16.25 59.00 3491.32 92.09 47.44 78.95 2.50 5970190.62 590816.76 N 70.32828787 W 149.26345701 3600.00 18.75 59.00 3586.68 122.15 62.92 104.72 2.50 5970206.41 590842.34 N 70.32833015 W 149.26324803 3700.00 21.25 59.00 3680.64 156.35 80.54 134.04 2.50 5970224.38 590871.44 N 70.32837829 W 149.26301027 End Bid 3730.00 22.00 59.00 3708.53 167.40 86.23 143.51 2.50 5970230.18 590880.84 N 70.32839383 W 149.26293347 UG1 3760.70 22.00 59.00 3737.00 178.90 92.16 153.37 0.00 5970236.23 590890.63 N 70.32841003 W 149.26285352 Ma 4041.12 22.00 59.00 3997.00 283.93 146.26 243.42 0.00 5970291.41 590980.01 N 70.32855782 W 149.26212326 Mb1 4089.66 22.00 59.00 4042.00 302.11 155.62 259.00 0.00 5970300.96 590995.48 N 70.32858339 W 149.26199692 Na 4316.15 22.00 59.00 4252.00 386.94 199.32 331.73 0.00 5970345.53 591067.66 N 70.32870277 W 149.26140711 OA 4499.50 22.00 59.00 4422.00 455.62 234.70 390.60 0.00 5970381.61 591126.10 N 70.32879942 W 149.26092970 Crv 3/100 4861.89 22.00 59.00 4758.00 591.35 304.61 506.96 0.00 5970452.92 591241.59 N 70.32899039 W 149.25998605 Obf Base 4887.84 22.77 58.71 4782.00 601.23 309.73 515.42 3.00 5970458.14 591249.99 N 70.32900437 W 149.25991744 '-' 4900.00 23.13 58.58 4793.19 605.97 312.19 519.47 3.00 5970460.65 591254.01 N 70.32901109 W 149.25988459 5000.00 26.11 57.63 4884.09 647.60 334.22 554.82 3.00 5970483.10 591289.09 N 70.32907127 W 149.25959791 5100.00 29.08 56.86 4972.71 693.86 359.29 593.76 3.00 5970508.64 591327.72 N 70.32913975 W 149.25928211 5200.00 32.07 56.22 5058.79 744.63 387.35 636.19 3.00 5970537.21 591369.80 N 70.32921640 W 149.25893800 CM2 5269.49 34.14 55.84 5117.00 782.49 408.55 667.66 3.00 5970558.79 591401.01 N 70.32927431 W 149.25868278 End Crv 5292.28 34.82 55.73 5135.79 795.36 415.81 678.33 3.00 5970566.17 591411.59 N 70.32929414 W 149.25859624 CM1 6097.72 34.82 55.73 5797.00 1254.01 674.82 1058.39 0.00 5970829.74 591788.45 N 70.33000161 W 149.25551381 Top HRZ 6785.97 34.82 55.73 6362.00 1645.92 896.15 1383.15 0.00 5971054.96 592110.48 N 70.33060612 W 149.25287971 Base HRZ 7041.77 34.82 55.73 6572.00 1791.59 978.41 1503.86 0.00 5971138.66 592230.18 N 70.33083078 W 149.25190060 Top Kuparuk 7127.04 34.82 55.73 6642.00 1840.14 1005.84 1544.10 0.00 5971166.58 592270.08 N 70.33090570 W 149.25157420 LCU 7200.13 34.82 55.73 6702.00 1881.76 1029.34 1578.58 0.00 5971190.49 592304.27 N 70.33096988 W 149.25129452 TMLV 7492.48 34.82 55.73 6942.00 2048.24 1123.35 1716.53 0.00 5971286.15 592441.06 N 70.33122662 W 149.25017554 Crv 3/100 8297.41 34.82 55.73 7602.79 2506.60 1382.21 2096.35 0.00 5971549.56 592817.69 N 70.33193354 W 149.24709447 8300.00 34.90 55.73 7604.91 2508.07 1383.04 2097.58 3.00 5971550.41 592818.91 N 70.33193581 W 149.24708449 8400.00 37.90 55.72 7685.39 2567.24 1416.46 2146.61 3.00 5971584.41 592867.52 N 70.33202707 W 149.24668675 End Crv 8470.01 40.00 55.72 7739.84 2611.13 1441.24 2182.97 3.00 5971609.63 592903.58 N 70.33209474 W 149.24639179 '-" Top Kingak 8472.83 40.00 55.72 7742.00 2612.94 1442.26 2184.47 0.00 5971610.67 592905.07 N 70.33209752 W 149.24637962 Top Sag River 9791.29 40.00 55.72 8752.00 3458.06 1919.60 2884.75 0.00 5972096.40 593599.46 N 70.33340093 W 149.24069836 7" Csg pt 9797.82 40.00 55.72 8757.00 3462.25 1921.97 2888.21 0.00 5972098.81 593602.89 N 70.33340740 W 149.24067028 Crv 15/100 9820.01 40.00 55.72 8774.00 3476.47 1930.00 2900.00 0.00 5972106.98 593614.58 N 70.33342932 W 149.24057463 Shublik 9830.58 41.58 55.54 8782.00 3483.36 1933.90 2905.70 ----15.00 5972110.95 593620.23 N 70.33343997 W 149.24052838 9848.23 44.22 55.27 8794.93 3495.33 1940.72 2915.59 15.00 5972117.89 593630.04 N 70.33345859 W 149.24044814 9848.84 44.22 55.27 8795.37 3495.76 1940.96 2915.94 0.00 5972118.13 593630.38 N 70.33345925 W 149.24044530 9900.00 46.99 45.24 8831 .20 3531.68 1964.33 2943.92 15.00 5972141.84 593658.08 N 70.33352306 W 149.24021827 V-03 (P6) report1.xls Page 2 of 3 10/17/2002-2:28 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD I VSec N/-S I E/-W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 10000.00 54.53 28.44 8894.69 3602.13 2026.23 2989.54 15.00 5972204.28 593702.94 N 70.33369212 W 149.23984804 TElL 10030.88 57.29 23.94 8912.00 3623.36 2049.18 3000.81 15.00 5972227.36 593713.93 N 70.33375480 W 149.23975655 V-03 Tgt 1 10059.71 60.00 20.00 8927.00 3642.74 2072.00 3010.00 15.00 5972250.29 593722.84 N 70.33381714 W 149.23968193 TSAO 10059.73 60.00 20.00 8927.01 3642.75 2072.02 3010.01 15.00 5972250.31 593722.85 N 70.33381719 W 149.23968185 10100.00 65.52 17.23 8945.44 3669.59 2105.94 3021.41 15.00 5972284.36 593733.84 N 70.33390984 W 149.23958927 10200.00 79.40 11.24 8975.53 3735.77 2198.13 3044.60 15.00 5972376.81 593755.91 N 70.33416167 W 149.23940086 End Crv 10239.49 84.91 9.06 8980.92 3760.98 2236.63 3051.49 15.00 5972415.39 593762.34 N 70.33426684 W 149.23934484 Crv 10/100 10549.38 84.91 9.06 9008.39 3955.47 2541.45 3100.07 0.00 5972720.75 593807.22 N 70.33509953 W 149.23894976 10600.00 88.08 6.53 9011.49 3986.42 2591.50 3106.92 8.00 5972770.87 593813.47 N 70.33523626 W 149.23889403 V-03 Tgt 2 10630.66 90.00 5.00 9012.00 4004.34 2622.00 3110.00 8.00 5972801.40 593816.18 N 70.33531958 W 149.23886894 10700.00 91.91 359.79 9010.85 4041.47 2691.24 3112.90 8.00 5972870.67 593818.24 N 70.33550873 W 149.23884518 "-" 10800.00 94.63 352.25 9005.14 4085.24 2790.75 3105.99 8.00 5972970.08 593810.13 N 70.33578059 W 149.23890090 10900.00 97.27 344.66 8994.77 4116.72 2888.13 3086.12 8.00 5973067.20 593789.08 N 70.33604665 W 149.23906176 11000.00 99.78 336.98 8979.93 4135.29 2981.46 3053.67 8.00 5973160.12 593755.51 N 70.33630165 W 149.23932470 11100.00 102.11 329.19 8960.91 4140.59 3068.94 3009.29 8.00 5973247.05 593710.08 N 70.33654069 W 149.23968444 End Crv 11157.89 103.37 324.61 8948.14 4137.54 3116.22 2978.47 8.00 5973293.95 593678.69 N 70.33666989 W 149.23993431 Crv 8/100 11167.65 103.37 324.61 8945.88 4136.65 3123.96 2972.97 0.00 5973301.62 593673.10 N 70.33669104 W 149.23997891 11200.00 101.28 323.06 8938.98 4133.25 3149.48 2954.32 8.00 5973326.91 593654.14 N 70.33676078 W 149.24013012 11300.00 94.76 318.36 8925.03 4117.24 3226.03 2891.63 8.00 5973402.69 593590.54 N 70.33696997 W 149.24063846 V-03 Tgt 3 11372.84 90.00 315.00 8922.00 4100.48 3278.95 2841.72 8.00 5973455.00 593540.00 N 70.33711460 W 149.24104320 11400.00 88.92 313.11 8922.26 4093.02 3297.83 2822.20 8.00 5973473.64 593520.25 N 70.33716619 W 149.24120150 11500.00 84.98 306.14 8927.58 4058.29 3361.48 2745.36 8.00 5973536.35 593442.65 N 70.33734016 W 149.24182469 End Crv 11569.81 82.26 301.23 8935.34 4027.56 3399.95 2687.66 8.00 5973574.12 593384.50 N 70.33744531 W 149.24229269 Crv 8/100 12239.30 82.26 301.23 9025.48 3708.28 3743.91 2120.40 0.00 5973911.16 592813.17 N 70.33838548 W 149.24689398 12300.00 87.12 301.09 9031.09 3679.13 3775.17 2068.70 8.00 5973941.79 592761.10 N 70.33847092 W 149.24731336 V-03 Tgt 4 12336.06 90.00 301.00 9032.00 3661.68 3793.76 2037.82 8.00 5973960.00 592730.00 N 70.33852173 W 149.24756386 End Crv 12383.88 93.58 299.64 9030.51 3638.01 3817.89 1996.56 8.00 5973983.63 592688.46 N 70.33858768 W 149.24789856 J TO 13721.94 93.58 299.64 8947.00 2963.11 4478.40 835.90 0.00 5974630.00 591520.00 N 70.34039273 W 149.25731472 Leaal Description: Northina tV) rftUSl Eastina eX) rftUSl Surface: 4892 FSL 1562 FEL S11 T11N R11E UM 5970142.23 590738.40 V-03 Tgt 1: 1684 FSL 3830 FEL S1 T11N R11E UM 5972250.29 593722.84 V-03 Tgt 2: 2234 FSL 3729 FEL S1 T11 N R11 E UM 5972801.40 593816.18 V-03 Tgt 3: 2891 FSL 3997 FEL S1 T11 N R11 E UM 5973455.00 593540.00 V-03 Tgt 4: 3406 FSL 4800 FEL S1 T11 N R11 E UM 5973960.00 592730.00 TO / BHL: 4091 FSL 722 FEL S2 T11N R11E UM 5974630.00 591520.00 V-03 (P6) report1.xls Page 3 of 3 10/17/2002-2:28 PM 9-1i18" Csg Pt ;f-=~~~~;- - - :;",~~::: - - _:::::::::: -ð ~- - - O"tmpaltrlre- - - SV12647MD2647 TVD - - - - - - ~. ~2Ii1WO = = :-= = = = = = ~~~~~~W9:: = = = :004=;2941'=M9=2~NEI lJG4X 2§'fr Mï5 2~ ND = = = 1 departure d 0- 1200 - ------- - - -- - - -- ----- 2400 ~ - - -- ----- ----- ----- - ..... 0)- .æ æ 3600- 8~ -------- C\I ( ) ~ > II .8 c: CO :;:4: -- 0 Hold Angle 22.000 .!:~ ã. ~ 4800-- 0)- ~~ ~~ :e~ 0) > > ~ ~ 6000- I... I- ') VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: V-03 (P6) Field: Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 60.00 deg Date: October 17, 2002 Schlumberger ----- - -SV5ï63'2"'M1Jì6j2""TIJl) - - - - - - - - - -------- - - - - - - - - ----- ----- "Sv49762'Mcf'i762'l"'iB' B~e p~mafrost~7a2MD1782 TVD = ----- ----- -------..----- ----- - - - """UGn3f5"MIJ33'f2 Ti7D --------- ----- ------ ----- - - -- ----- ----------- Hold Angle 34.820 ----- - - -- -------- ----- - - -- ----- - - -- - - - - ----- 7200 - -------+- I I, I I, I I \ =======t= =======r 0 8400 - -1200 - UG13761MD3737TVD --------- ------- ------ - ::&1a:lD4œO::399DVC:: ~bnoéiMÖ=40~nm = = = - - cry 3/100 - - - - Na 4316MD4252TVD - ~- 4SS2 MO 4Z584J1D- - OA 450õ"MD4422-TVD - 22.00. 59.00. az 591 departure ----- ----- ----'------ --- -.- - --,- - . . - --_...,,----,. . - - ...... . '''''''ODfBãs'?"sã8MD'-4782TVÖ -, ------- - - - .. End Cry ~ 5292 MD 5136 TVD ~ - - ~~~~~. ~ - -C~5259 MIJ 5ffi 1VD - - ------- ------------- -cMT 6098 MD 5797TVD - - ------ - -TopHRz6iã6MD6362TVD - - ~Base HRZ 1O'I21\i1t) 6572T'i1D- - - = =.= = =[m<~u~~'1ð~~~T\D - - -- -TMLV 7492MD 6942TVD - Cry 31100 -8297MD~03~-D- - - - - -TõPKiiiQakS473MDT742TVD 34,82' 55. . az I 7" Csg Pt =;~ n~WD I .... V=:::!~VO - - - - -~;~~~~~:az Hold Angl1 40.000' .~. 1 - - -:: : t: : : :: : f: :~~ '¡j:-:; oØ:~: :; i 1200 2400 3600 4800 Vertical Section Departure at 60.00 deg from (0.0, 0.0). (1 in = 1200 feet) ö VERTICAL SECTION VIEW BP Exploration Alaska V-03 (P6) Client: Well: Field: Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 310.00 deg Date: October 17, 2002 7200-- ----- ._~~~-_._----~---_.~_._-- - -P-°PRingãk å473MD 7742TVD- - ----- - - - - --------- i 7800 -- - ------------./--- -_.~-_._-- I Hold Ang~e 40.00° - ã>:::¡ ~cn O~ 0 Q) «> > II 0 C-C . - CO ~-:a= -0 .cO +oJ . a.N Q)CO Oar ëõ~ . ~ .¡..: t Q) Q)~ > > Q) Q) ::1- ,-W I- : j I I 1 i Cr~8I100 i ---t---- 7"CSgPt, ! 11h88MD 8946TVD ---- ¡ ¡ 9798 MD 8757 TVD! ---~--J----.Cnr-15l1OO-- , . 24.61' az! ! 8400----~~~~~:;';~~;~-~-T.., ----0- -- !... ~~~0~~5~~4:¡:VD ~;..93:epa~ure. EndCrv i..."'.'. I'.",. I -981 departure i 11570 MD 89~5 TVD i ¡ ! / :;''',:,.':::t'' i -- - - -- = ¡ - - L - = = = = = :i: = 1 = = = = :i> ....",.;¡:,,,, "'" ""! ,""'. o@ MÕ"" "" = = = = = =.~ L : =~ r = ~ =~ - <> t -,,= = = ~ ~ + ~ ::: = = ~ = = = = = = 9000":.~= =-7/--' / \° \ -K I I \0~,". ,..,,~, I ""' Ow ,.., "'" I ",.. MD ..","" 1oo60MD 8~7TVD I'. !\,.. 11158MD 8948TVD 11373MD 8922TVD ! ¡ 93.58. 299.64.az W.O. '".00 æ : ',,,.,,. "''''" "00" '''.00"" ; ; ""-. -974 departure End ~rv i -279 departu'e 59 departure Ctv 81100 V.o3 Tgt 4 ¡ 102~9MD 8981TVD ¡ V.o3Tgt2 - 12239MD 9025TVD 12336MD ~32TVD 84.9j. 9.06"az Crv81100 I 10631 MD 9012TVD 82.26. 301.23.az 9000. 301po.~7 -900:departure 10549 MD 9008¡TVD 90.00. 5-00. az 782 departure 878 departui,e 1__- 84.91' 9.06" R7j -697 departure : ---- --,---- -741 departure! ; 9600 -- 10200 -1800 ~ -1200 ¡ -600 J 600 I 1200 I 0 Vertical Section Departure at 310.00 deg from (0.0, 0.0). (1 in = 600 feet) 1800 Schlumberger .....L.---------- TO 13722 MD 8947 TVD 93.58. 299.64. az 2238 departure ¡ ======~=== ¡ TElL 10031 MD 8912TVD - - -= = ~ = =¡ = = =rSAD 10060MD 8927TVD 0 F ~ 2400 ò -2000 . ¡ I I ¡ ì i ¡ 4000 -+-- ^ I ^ ! ^ ¡ I i I- I a:: 3000 -+-- 0 I Z I 2000 ---+-~--~ I I- ::> 0 : --- CJ) 1000 ------¡ V V V i 0 ---r- I -2000 Client: Well: Field: Structure: Scale: Date: PLAN VIEW BP Exploration Alaska V-03 (P6) lehluDlberger Prudhoe Bay Unit - WOA V-Pad 1 in = 1000 ft 17-0ct-2002 -1000 , True North Mag Dec ( E 25.75° ) ~ i ¡ ; End Bid i : 3730 MD 37091D : 22.00. 59.00. az I ~OP 1.251100 86 N 144 E\! 2~. 00 MD 2900 TVD i ~i~.1~900.~az I i KOP 1]251100 2800 ~D 2800 TVD 0.00. 159.00. az ON olE , ::.t;""D ~ \ ~:,'. 0.00. 5P. .00. az ~ ~ J \ ON °'l ~¿r' : ~ I 0 0 , ¡ TD 13722 MD 8947 TVD 93.58. 299.64. az 4478 N 836 E Cry 3/100 4862 MD 4758 TVD 22.00. 59.00. az 305 N 507 E V~3 Tgt 1 10060 MD 8927 TVD 60.00. 20.00. az 2072 N 3010 E 2000 , 3000 . 4000 V-03 Tgt 4 : 12336 MD 90~ TVD 90.00. 301.00i az 3794 N 2038 ~ End Cry 11570 MD 8935 TVD 82.26. 301.23. az / 3400 N 2688 E V~3 Tgt 3 11373 MD 8922 TVD 90.00. 315.0D. az 3279 N 284~ E Crv8/100 11168 M~ 8946 TVD 103.37. \324.61. az :-------.... 3124 N ¥973 E ------- End C~ ~~~53~~~2::~ :~D :~ . 311612978E ~Vjo3T9t2 . 1Ø631 MD 9012 TVD " 99.00" 5.00. az Crv151100 ;. ~. 2$22N 3110E 9820 MD 8774 TVD --- I 40.00. 55.72. az ¡ ì ø 'Crvlsi1oo 1930 N 2900 E I:, ~ I. . 1054,:.. 9 MD 9008 TVD ! \ 1 ~'1~ ~1:~Z II ~~ I'.. I... 10239 'lA, D 8981 TVD 7' \; ~~71~¡ ~~:;: 1 7UCs! PI ' :.:.. 9798 ;" D 8757 TVD ' , 40.00~ 55.72. az , End Cry 1922 ~ 2888 E 8470 MD 7740 WD 40.00. 55.72. azl Cry :>1100 1441 N 2183 E , 8297 MD 7603 TVD ¡ 34.82. 55.73. az 1382 N 2096 E -1000 ~ . End Cry 5292 MD 5136 TVD 34.82. 55.73. az I 416N 678E 1000 «< WEST I 2000 3000 EAST »> 4000 5000 . .---. - 4000 3000 2000 .~ 1000 0 5000 '" ") Schlumberger Anticollision Report ') Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan V-03 (N-W), True North V-û3 Plan 82.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 13721.94 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/7/2001 Validated: No Planned From To Survey ft ft 28.50 13721.94 Version: Toolcode 4 Tool Name Planned: Plan #6 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points TVD Diameter Hole SiZe Name ft in in 2747.00 2747.00 9.625 12.250 95/8" 9797.82 8757.00 7.000 8.500 7" 13721.94 8947.00 4.500 6.125 41/2" Summary < - Offset Wellpath :> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft EX WKUPST -01 WKUPST-01 WKUPST -01 V1 Out of range PB V Pad Plan V-109 (S-E) Plan V-109 V1 Plan: PI 2634.48 2700.00 140.09 43.97 96.18 Pass: Major Risk PB V Pad V-100 V-100 V7 2798.10 2800.00 199.69 39.39 160.49 Pass: Major Risk PB V Pad V-101 V-101 V7 699.27 700.00 324.20 11.15 313.09 Pass: Major Risk PB V Pad V-102 V-102 V5 847.47 850.00 210.00 15.41 194.61 Pass: Major Risk PB V Pad V-103 (N-S) V-103 V6 499.27 500.00 60.13 8.34 51.83 Pass: Major Risk PB V Pad V-104 V-104 V13 449.68 450.00 266.38 7.19 259.20 Pass: Major Risk PB V Pad V-105 V-105 V13 1790.29 1800.00 105.04 25.87 79.18 Pass: Major Risk PB V Pad V-106 V-106 V10 648.99 650.00 88.26 9.82 78.46 Pass: Major Risk PB V Pad V-107 (N-J) V-107 V5 898.91 900.00 234.11 13.79 220.32 Pass: Major Risk PB V Pad V-108 V-108 V7 249.68 250.00 357.26 4.23 353.03 Pass: Major Risk PB V Pad V-201 V-201 V8 448.45 450.00 221.99 7.13 214.88 Pass: Major Risk H 207125 DATE 9/20/02 CHECK NO. H207125 DATE INVOICE I CREDIT MEMO DESCRIPTION VENDOR DISCOUNT NET GROSS 9/20/02 INV# CK091602I PERMIT TO DRILL FEE ý~03 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ItÞ- BP EXPLORATION, (ALASKA)JNC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 CONSOLIDATED COMMERCIAL ACCOUNT PAY TO THE ORDER OF 118 20 ? ~ 2 5/11 I: 0 a. ~ 2 0 j a q 5 I: 00 a a. a. ~ q ,,8 H ';:~-4 ~'. ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME f~u tV 'C>- ~ PTD# 202--2/5 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates "CLUE " The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the. original API number stated above. 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 (50 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 peñorate 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 .ßp X WELL NAME /l¿4 V - 6...3 PROGRAM: Exp - Dev X Redrll - Re-Enter - Serv - Wellbore seg - FIELD & POOL C 9(") /.~ rJ INIT CLASS LJ8t/ /-~// GEOL AREA? /,0 UNIT# //~c;'"rj ON/OFF SHORE ð~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y 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 /þ~ /J>. / -. J 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N #L- ~~~ 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.. . . . .. \:!J}1Y N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #- Y /L/. ~ (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . ., . N ( ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Æ. N r¿,o i(@ilð. 16. Surface casing protects all known USDWs. . . . . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~(Q) 19. CMT will cover all known productive horizons. . . . . . . " . œ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . &.. N 'L. 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . CI! N IL/ (1¡,.f/(J yç q £ ç 22. If a re-drill, has a 10-403 for abandonment been approved. . . V N NtÆ- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . æ.. N . ..,.. I 24. If diverter required, does it meet regulations. . . . . . . . . .¥-N- Wt.ti \tw. ye'b~s:teò: t)GNi t;D . 25, Drilling fluid program schematic & equip list adequate. . . . . æ N f1Il.lJ.--K. fYfAtJ ¡ () j ~ P Pl' 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ð2 N . 27. BOPE press rating appropriate; test to 'i 000 p sig. 11<.. N JIÞI,¥; P 'l77í.f Ii S / . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 29. Work will occur without operation shutdown. . . . . . . . . . . ~ N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y .§lJ (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . Y N /\LIlt- GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . Q N APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . l I/J J'/J .. /~ 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y Þ II n \ /-L ¿ /<!;)/~.1...-?'2.., 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . NN (Exploratory Iy) 36. Contact name/phone for weekly progress reports. . . . . . . . APPR DATE ~t\- It I If 0(.... GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR COMMISSIONER: Comments/Instructions: Rev: 10/15/02 SFD- / WGA v MJW COT I DTS Dt-.ó' ¡ 1/1 Q ~ MLB PI-'ft 1//7/° ~ G:\geology\permits\checklist.doc
