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203-077
Image ~ .bject Well History File Ct,Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ CJ:.3 - 0 11 Well History File Identifier Page Count from Scanned File: <g<:b (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES NO Helen~ Date:7 I, ~ ðS Is! V14P If NO in stage 1 page(s) discrepancies were found: YES NO Organizing (done) o Two-sided 1111111111111111111 R7CAN ~ Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. I o Other, NolType: o Poor Quality Originals: o Other: NOTES: BY: Helen ~_ Project Proofing BY: Helen (Maria) Scanning Preparation ~ x 30 = /IJ1) BY: Helen ~( Mari~ ") Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed I· OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: D Other:: , Date: 7 I ~ "SI./S' MP Date: 7 I~ OS /s/ ~p , . + ~ 7 = TOTAL PAGES <6·7 (coun7c.:as. n~tJInCIU. de cover sheet) 1'/\ A.P· Date: I Sf¡ OS /5/ r VI . I· Date: /5/ II! 1111111111111111 111111111111111111I I I Date: /5/ Quality Checked 1111111111111111111 RECEIVED STATE OF ALASKA I I 1 A•KA OIL AND GAS CONSERVATION COM•ON DEC 1 1 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well L✓J Plug Perforations Li Perforate Li Other -!-L Pmf Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 203 -077 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 23153 -00 -00 7. Property Designation (Lease Number): ., 8. Well Name and Number: ADL0028240 ORIN V -202 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, SCHRADER BLUF OIL 11. Present Well Condition Summary: Total Depth measured 8985 feet Plugs measured None feet true vertical 4662.95 feet Junk measured None feet Effective Depth measured 4841 feet Packer measured See Attachment feet true vertical 4324.05 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 215.5# A -53 29 - 109 29 - 109 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 5940 7 -5/8" 29.7# L -80 26 - 5966 26 - 4617.69 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 6021 - 8941 feet True Vertical depth 4624.98 - 4660.95 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 4934 24 - 4366.96 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 11 2013. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 957 295 765 1030 461 Subsequent to operation: 102 74 X 76 at �._, -.. _...._..- 1584 247 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development 0 , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . is Gas ❑ WDSPLI J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron • Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564 -4424 Date 12/11/2012 RRI-WS DEC 1 p # , 1 4 -(L Form 10-404 Revised 10/2012 r / 7--" , e&-- Submit Original Only • • Packers and SSV's Attachment ADL0028240 SW Name Type MD TVD Depscription V -202 PACKER 4932 4283.79 5 -1/2" BAKER ZXP PACKER V -202 PACKER 5123 4355.19 5 -1/2" BAKER ZXP PACKER V -202 PACKER 5869 4520.75 4 -1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0028240 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 215.5# A -53 29 - 109 29 - 109 LINER 196 4 -1/2" 12.6# L -80 4921 - 5117 4361.29 - 4435.57 8430 7500 LINER 762 4 -1/2" 12.6# L -80 5112 - 5874 4433.96 - 4603.78 8430 7500 LINER 3118 4 -1/2" 12.6# L -80 5862 - 8980 4602.04 - 4662.72 8430 7500 PRODUCTION 5940 7 -5/8" 29.7# L -80 26 - 5966 26 - 4617.69 6890 4790 SURFACE 2815 10 -3/4" 45.5# L -80 28 - 2843 28 - 2734.03 5210 2480 SURFACE 2815 10 -3/4" 45.5# L -80 28 - 2843 28 - 2734.03 5210 2480 • TUBING 4910 4 -1/2" 12.6# L -80 24 - 4934 24 - 4366.96 8430 7500 L1 LINER 743 4 -1/2" 12.6# L -80 5131 - 5874 4440.02 - 4463.99 8430 7500 L2 LINER 3981 4 -1/2" 12.6# L -80 4954 - 8935 4375.49 - 4433.09 8430 7500 • 1 1 • • Daily Report of Well Operations ADL0028240 DRIFTED WITH STRADDLE PACKER W/ MANDREL TO 4,700' SLM 10/20/2012 ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS * ** ** *WELL SHUT IN ON ARRIVAL * ** (E -LINE PACKER) INITIAL T /I /O = 450/400/600 PSI SET 4.5" BAKER KB LOWER STRADDLE PACKER MID - ELEMENT AT 4649'. CCL TO M.E. = 9.58'. CCL STOP DEPTH = 4639.42'. TOP OF PACKER= 4646.2' CORRELATED TO TUBING TALLY DATED 12/9/2003 CORRELATION AND SETTING PASS LOGGED FROM 4705'- 4500'. FINAL T /I /O = 330/400/600 PSI WELL SHUT IN ON DEPARTURE 10/31/2012 ** *JOB COMPLETE * ** ***WELL SHUT IN ON ARRIVAL ** *(patch) SET 4 1/2" X- KEYLESS CATCHER @ 4621' SLM. PULL BK -DGLV FROM STA #1(4608' SLM/4628' MD) 11/6/2012 * * * *CONT JOB ON 11- 7- 12 * * ** * * * *CONT JOB FROM 11- 6 -12 * ** *(patch) PULL 4 1/2" X- KEYLESS CATCHER FROM 4621' SLM. SET BAKER GL- STRADDLE PATCH W/ UPPER KB PACKER @ 4626' SLM/4646' MD. MIT -IA TO 3000 psi - failed. MIT -T TO 3000 passed. PULL & RESET BK -DGLV FROM INSIDE STRADDLE PATCH © 4606' SLM. 11/7/2012 * * * *CONT JOB ON 11- 8- 12 * * ** T /I /0= 220/220/620 Temp =Sl Assist SLine w/ MIT -IA to 3000 psi. (PATCH TUBING / LINER) Pumped 4.2 bbls of 50* crude down IA for 2 failed MIT -IA to 3000 psi. Both Tests failed with in 15 mins. Pumped 1.2 bbls of 50* crude down Tbg for 2 MIT -T to 3000 psi. MIT -T to 3000 psi PASSED 2nd Test (15 mins Tbg lost 43 psi / IA lost 20 psi. 30 min Tbg lost 23 psi / IA lost 0 psi. Total Test Tbg lost 66 psi / IA lost 20 psi ** *PASS * * *) Pumped 3.2 bbls of 50* crude down IA for 3 MIT -IA tests to 3000 psi. While bringing IA pressure up on IA, Tbg pressure would come up. On 3rd Test MIT - IA PASSED but due to Tbg coming up 1800 psi while bringing pressure on IA up for Test SLine is pulling dummy valves and resting them. 11/7/2012 ** *Continued on 11 -08 -12 WSR * ** * * * *CON1 JOB FROM 11- 6 -12 * ** *(patch) PULL 4 1/2" X- KEYLESS CATCHER FROM 4621' SLM. SET BAKER GL- STRADDLE PATCH W/ UPPER KB PACKER © 4626' SLM/4646' MD. MIT -IA TO 3000 #(FAIL) * *see log for details ** PULL & RESET BK -DGLV FROM INSIDE STRADDLE PATCH © 4606' SLM. 11/7/2012 * * * *CONT JOB ON 11- 8- 12 * * ** ?/I/0= 300/350/600, Temp =SI. PPPOT -T (PASS), assist SL. SL has control of well. PPPOT -T: Stung into test void (150 psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in 11/8/2012 second 15 min (PASS). Bled void to 0 psi, did not function LDS. • • Daily Report of Well Operations ADL0028240 * * * *CONT JOB FROM 11- 7 -12 * ** *(patch) ATTEMPT MIT -IA TO 3000 psi (FAIL) SET 4 -1/2" X- KEYLESS CATCHER ON PACKER @ 4585' SLM. PULL & RESET BK -DGLV IN STA #2(3677' SLM/3698' MD). ATTEMPT MIT -IA TO 3000 psi (FAIL) PULL & RESET BK -DGLV IN STA #3(2546' SLM/2565' MD). ATTEMPT MIT -IA TO 3000 psi (FAIL) PULL EMPTY 4 1/2" X- KEYLESS CATCHER FROM 4581' SLM. PULL 4 1/2" BAKER GL- STRADDLE PATCH W/ UPPER KB PACKER FROM 4585' SLM. EQUALIZE & PULL 2 -3/8" XX -PLUG FROM NIPPLE REDUCER @ 4859' SLM/4882' MD. SET 4 -1/2" CAT STANDING VALVE W/ BAKER 45 KB PACKER LTTP @ 4619' SLM. 11/8/2012 * * * *CONT JOB ON 11- 9- 12 * * ** ** *Continued from 11 -07 -12 WSR * ** MIT IA to 3000psi (PATCH TUBING LINER) SSL set DMY valve in station #1 TBG patch. Pumped 3.2 bbls 40* crude down IA to reach test psi. IA lost 415 psi and TBG gained 250 psi in 10 min. (failed). SSL move to next station. SSL set station #2 valve. Pumped 3.2 bbls 40* crude down IA to reach test psi. IA lost 440 psi and TBG gained 320 psi in 15 min. (failed). SSL move to next station. SSL set station #3 valve. Pumped 3.3 bbls 40* crude down IA to reach test psi. IA lost 451 psi and TBG gained 0 psi in 15 min. IA lost 33 psi and TBG gained opsi in 30 min. (Failed). 11/8/2012 ** *Continued on 11 -09 -12 WSR * ** * * * *CONT JOB FROM 11- 8 -12 * ** *(patch) LRS ATTEMPT CMIT -TxIA TO 3000 psi (PASS) SET BAKER 4 -1/2" 45 KB UPPER STRADDLE PACKER W/ 2 -3/8" WFD SMR -1 B GL MANDREL @ 4624' SLM. LRS MIT -IA TO 3000 PSI (PASS) PULL BK -DGLV & SET BK -OGLV IN STA #1(4808' SLM) SET 4 1/2" X- KEYLESS CATCHER @ 4584' SLM. PULL BK -DGLV FROM STA #2(3698' MD) & STA #3(2565' MD). SET BK -LGLV IN STA #3(2565' MD) & STA #2(3698' MD). PULL EMPTY 4 1/2" X- KEYLESS CATCHER FROM 4584' SLM. 11/9/2012 * ** *WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED * * ** ** *Continued from 11 -08 -12 WSR * ** Assist Slickline CMIT -Tx IA to 3000 psi (PASSED) MIT -IA to 3000 psi (PASSED) Pumped 18.2 bbls 20* crude down IA to reach CMIT -TxIA test psi. 1st 15 min TBG /IA lost 145/144 psi. 2nd 15 min TBG /IA lost 53/53 psi for a total loss of 198/197 psi in 30 min. Pumped 4 bbls crude down TBG to assist SSL. Pumped 5.3 bbls of 40* crude down IA to reach 3000 psi for MIT IA 1st test 1st 15 min lost 123 psi 2nd 15 min lost 38 psi fora total of 161 psi in 30 11/9/2012 min Bleed IAP off S -line on well on dep. Final Whp's= 100/0/580 TREE= , EE 4 -1116" aw WELLHEAD = 11' F3uC III S. NOTES: WELL ANGLE > 70" 0 5075'. ACTt1RT0_R = BAKF3R V -202, L 1, L2 02 8 PRESSURE GAUGES IN- OPERABLE AS OF K R B. EV = .___. _____M 82.30' BF. F3EV__ _ ----- _ 53.80' KOP = _e._ 160 I I J X18' H4 -1/2" 1 - E S X N P , D= 3.813" Max Angle = - - 95° @ 6213' I Datum 1A3= 5273' GAS LIFT MANDFIiS Datum ND= 440 0' SS ST ND ND DEV TYPE VLV LATCH PORT DATE 0 3 2565 2493 30 KGB -2 DONE BK 12 11/09/12 (20# CONDUCTOR I 114' ' 2 3698 3485 29 KGB -2 SO BK 16 11/09/12 *1 4628 4206 52 KGB -2 EM9Y 11/09/12 110-3/4. CSG 45.5#, L-80 BTC, D= 9.95" H 2843' 1 4627 4206 52 SM -1B SO 1 BK I 16 11/09/12 Minimum ID =1.875" @ 4882' ° STA # 1 ft 4628' = ENPIY POCKET (MIND GL STRADDLE) 2-3/8" NIPPLE REDUCER 4611' - 4645 'I- 4- 1/2 ° BKR GL STRADDLE PATCH, D =1.94" (11/08/12) PHCE1+L( DISCHARGE PRESS 4733' GAUGE, D = 3.85" I I I }4 -1/2" BKR CND SLDING SLV, D = 3.813" I PHOE NIX MAKE PRESSURE, 0 I II 4744' 4 792 7 -5/8 X 4-1/2" BKR PREM PKR, D = 3.875" Ufi� ► � ► t ' " " I GAUGE, D = 3.833" I 4861' H4-1/2" HIM X NP, D = 3.813" I 4882' H 4-1/2" HES X NIP, D = 3.813" I 7/5/8" RA TAG 4867' gall 4882' — 12 -3/8" N1' REDUCER, D = 1.875' I 4-1/2" TBG, 12.61 L-80 BT -M, --1 4934' 0152 bpf, D = 3.958' @ 4921' H7 -5/8" X 4 -112" BKR ZXP LTP w /TFS3K, D = 5.750" I 15-1/2" X 4-1/2" XO, ID= 3.930" H 4940' I 4934' H4-1/2" MULE SHOE, D = 3.958 L2 (OA) LENT WINDOW 65° BKR HOOK HANGER H 4954' I- L2 ( ©A) 1 4959' - 4970' w / L2 NON SEALNG LEM, D = 3.71" OPENING WDTH = 3.33" OA FWD 8933' 7/5/8" RA TAG 5062' 4959' - 8935' 6 -3/4" OA LATERAL, ID = 3.958" 17-5/8" X 5-1/2" BKRZXPLTP, ID= 5.75' H 5112' I / 1 15-1/2* X 4-1/2" XO, ID= 3.9 0" H 5131' I I 5117' H4-1/2" MILE SHOE, D = 3.958" I L1 (OBa) LEM WINDOW 72° BAKER HOOK HANGER 5143' I Li (OBa) 5148' - 5159' w / Li NON SEALING LEA, D = 3.71' OPENING WDTH = 3.33' 7/5/8" RA TAG 5191' OBa PBTD 8963' 7/5/8" RA TAG 5719' 5148' - 8965' 6 -3/4" OBa LATERAL, ID = 3.958" I7" IEBACK SLEEVE, D= 5.75" H 5862' I PERFORATION SUMMARY — 6869' H7-5/8" X 5-1r2" BKR ZXP LIP, D = 4.90" I REF LOG: ANGLE AT TOP PERF: 'N I 5874' H4-1/2" MULE SHOE D = 3.958" Note: Refer to Production DB for historical perf data \ 1 5882' H5 -1/2" X 4-1/2" XO, 0=3.958" I NE SIZE SPF ZO INTERVAL Opn/Sqz DATE - ■ 4-1/2" SLID OA 5031 -8892 0 12/08/03 p 5971' H4 -1/2" HES XN NP, D = 2.750" ( 4-1/2" SLID OBa 5220 - 8922 0 12/01/03 4-1/2" SLID 08d 6021 - 8941 0 05/17/03 I I 7- 518" CSG, 29.7#, 1-80 BTC -M D= 6.875" H 5966' I I I v I 5966' - 8980' 6 OBd LATERAL, ID = 3.958" 4-1/2" LNR, 12.6#, L -80 BT, H 8980' CI" l .0152 bpf, D = 3.958" DATE REV BY COMMENTS DATE REV BY 0O11443ITS ORION UNIT 05/02103 N9ES ORIGINAL COMPLETION 11/10/12 PJC 7 -5/8" D/ PATCH OOF ITONS WELL: V -202, 11, L2 12110103 NOES LATERALS (V -20211 & L2) 11/12/12 WE C/ PJC UPPER PATCH' PILL XX (11/08/12) I4321'IT No: 2030770 (1740) (1750) 03/10/10 JUN/PJC CSG CORRECTION API No: 50- 029 - 23153-00 (60X61) 07/25/12 TQ/JND GLV C/O (07/21- 24/12) SEC 11, T11N, RI1E, 460' F1& & 1848' FE. 10/23/12 CO NJND SET MP RED & XX PLUG (10/06/12) 11/05/12 RWMJM3 SET LWR PKRASSY (10131 /12)11 BP Bcploration (Alaska) DATE: 23- Aug -12 Stephanie Pacillo TRANS#: 6044 Data DelivpryServieesTechnician -,, 47 IVLakanaIC Bender Schlumberger Oilfield Services Natural Resources Technician IT `VIR[LINC r Adalilf, _ ! (ail & C3,: C,c;lr:;f;1 v701 ( :(i lirrl'?:vit 2525 Gambell 5t, Stn, 400 'IT 7 A'; e : i ( )( ) 1-J :f ' •:.(; , Anchorage, AK 99503 ..,; W: Office: (907) 273 -1770 \a, WEU1, ;SERVICE .? ,; OH, " RESERV (NI. '.,, : LOG DESCRIPTION DATE B/W NAME _ ORDER It DIST DIST D IST DIST LOGGED PRINTS PRINTS G - 25B _ BAUJ .00145 X MEMORY (PROF 25- Jul -12 1 1 CD • E -09 6C 00.00024 X PPROF/IPROF MCNL 12- Jul -12 1 1 CD G -046 C600.00026 x MEMORY PPROF / IPROF MCNI. 10-Jul-12 1 1 CD K -1OC BAUJ•00138 X MEMORY PPROF W/ GHOST 29- Jun -12 1 1 CD V -202 . - C000�00039 X MEMORY LISL 22- Jul -12 1 • - 06A C8)(140016 C8)(140016 . X MEMORY PPROF 13 Jul - 12 1 1 CD 1 CD W - 02A CSXI:0001R X MEMORY LEAK DETECTION 15- Jul -12 1 1 CD 14 -33A - C3XI - 00046 X MEMORY PPROF 13- Jun -12 1 1 CD 05 -23B BAUJ•00140 X MEMORY PPROF W/ GHOST 3- Jul -12 1 1 CD H -09 C2JCs00027 X PROF 23- Jun -12 1 1 CD MPS -01 8281.00021 X - 2 - — - ..- .. _ _. .. PDC CORRELATION 9- Jul -12 1 1 CD NI PS-0111 8ze1.00021 X USIt _ 11-Jul-12 1 1 CD 05 - 221 BCRe- 00198 _ X - MEMORY PPROF 9-Jul-12 1 _ 1 CD P1 -08 _ BY` 4.00041 _ _ - X _ XFL OW W/ IBP SET RECORD _ 20-Jun-12 1 _ 1 CD L1-21 9 ovve.o004i,. _ _ X _ PPROF 16- Jul -12 1 _ 1 CD -- PBSURVE __. . .. - . X PPROF 26- Juh -12 1 1 CD • N -12 .._ APBSURVEEI. X PPROF _ 19- Jul-12 1 1 CD O8 BCI C MEMORY PPROF W/ GHOST 9-Jul-12 1 1 CD 18 -29A 11996389 X SCMT 13- Mar -08 1 1 CD G -258 BAUJ•00149 X _ MEMORY PPROF W/ GHOST 24-Jul-12 1 _ 1 CD Z -13A BAUJ=00142 X MEMORY LEAK DETECTION 7- JUI -12 1 1 CD j / X x / , , i , --- 4 r J) _ 't.-::-..,',..-(:....-=" -:. Please returh a signed copy to: Please return a signed copy'to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson} Blvd Anchorage AK 99503 Anchorage AK 99508 SCANNED APR 0 3 2013 N .LA/ J v J ~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 n r ~ ~, n~- August 14, 2009 ~;~~+~,u~s~' ~ ° '` t ~ `~V~ . bp ~~~~~~~~ OCT 0 ~ 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~ Oil & Gas Con~. CQmmi~~ion A~~ehorApe ~.~~-~77 ~~~~~ 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 7l1012009 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 6t29/2009 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-109 2022020 50029231200000 NA 1.2 NA t0.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 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-119 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-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-2o~ 2012220 5002s230540000 SC leak NA 4 NA 90.6 8/7l2009 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-2~5 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 1 t.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V414 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-2t6 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 50029233500000 NA 2 NA 17.9 7l12l2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ~9 2080200 50029233830000 NA 1.75 NA ~ 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 • • ~._ •~ ~ - MICROFILMED 03/01/2008 DO NOT PLACE Tom...., .~+-~ ~_.- ` ANY NEW MATERIAL UNDER THIS PAGE F:~I,aserFiche\C~rPgs_Inserts\Microfilm_Marker.doc \ C\ ~~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030770 Well Name/No. PRUDHOE BAY UN ORIN V-202 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23153-00-00 MD 8985 TVD 4663 Completion Date 5/19/2003 Completion Status 1-01L Current Status 1-01L UIC N - -- - -~------ -------- REQUIRED INFORMATION Directional SU~Yes )/ Mud Log No Samples No ------- ----- ------- ""'- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, AIM, DPC MDT (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Logl Electr -~ Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments / Formation Tester 25 Col 4359 5940 Open Modular Formation Dynamics Tester ¡ED C Lis 11840 L~ VcrifiGdtiuJI ~_ þ~nç ~'t:;s-;.~-- 108 8984 Open 8/8/2003 " j :ED C Pds 11840 See Notes 2 5750 8942 Open 8/8/2003 Vision Borehole Profile ~ See Notes 2 Blu 5750 8942 Open 8/8/2003 Vision Borehole Profile I g i~ C Pds 11840 Density 25 2840 8942 Open 8/8/2003 Vision Density Neutron ED C Pds 11840 Density 25 2840 8942 Open 8/8/2003 DELETE :19?-- Density 25 Blu 2840 8942 Open 8/8/2003 Vision Density Neutron ! ,Leg-- - _ ---- ._------- Density ~ 25 Blu 2840 8942 Open 8/8/2003 DELETE 'Ef{ C Pds 11840 Neutron 25 2840 8942 Open 8/8/2003 Vision Density Neutron ,~1840 Neutron 25 2840 8942 Open 8/8/2003 DELETE --- ~ Neutron 25 Blu 2840 8942 Open 8/8/2003 Vision Density Neutron , Log Neutron 25 Blu 2840 8942 Open 8/8/2003 DELETE ~ C Pds 11840 I nd uction/Resistivity 25 108 8942 Open 8/8/2003 Vision Resistivity ; Ef}-" C Pus 11840 Ifl6octien/Resistivity 25 108 8942 Open 8/8/2003 DELETE ~ Induction/Resistivity 25 Blu 108 8942 Open 8/8/2003 Vision Resistivity ¡ Log I nd uction/Resistivity 25 Blu 108 8942 Open 8/8/2003 DELETE ~ Cement Evaluation 5 Col 4700 5270 Case 12/22/2003 Slim Cement Mapping Tool- Gamma Ray, CCL "ED D Las 12377 Production 6005 8913 Case 1/20/2004 Production Profile þD 0 Las 12377 Spinner 6005 8913 Case 1/20/2004 Production Profile I ~....ED 0 Las 12377 Temperature 6005 8913 Case 1/20/2004 Production Profile - --- -------~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030770 Well Name/No. PRUDHOE BAY UN ORIN V-202 Operator BP EXPLORATION (ALASKA) INC MD 8985 TVD 4663 Completion Date 5/19/2003 Completion Status 1-01L 12377 Pressure fi ED 0- - Las---- -1-2377 Casing collar locator ~ Las Production --- -- -- --- Well CoreslSamples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? --rrr::r- Analysis Received? --Y/N - ----- ------ Comments: - -- - -- ----"-- Compliance Reviewed By: _ ~ 5 BM Interval Start Stop Sent Received Daily History Received? Formation Tops API No. 50-029-23153-00-00 Current Status 1-01L UIC N 6005 8913 Case 1/20/2004 Production Profile 6005 8913 Case 1/20/2004 Production Profile 6005 8913 Case 1/20/2004 Production Profile Sample Set Number Comments ~N ØN Date: ---- JJ ~ ts~ Ä~)- ~' '-) ST A TE OF ALASKA ALASKA ,'_ AND GAS CONSERVATION COM!\' )ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: ~ Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25,105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4820' NSL, 1848' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 2005' NSL, 2493' WEL, SEC. 02, T11 N, R11 E, UM (OBd) Total Depth: 4971' NSL, 1380' WEL, SEC. 02, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590453 y- 5970066 Zone-___~~~~ TPI: x- 589776 y- 5972523 Zone- ASP4 -. "'''.-...-"''....,.-.-.---- Total Depth: x- 590850 y- 5975502 Zone- ASP4 .~__....w_._.,_____" __'_ 18. Directional Survey 0 Yes ~ No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, AIM, DPC MDT 22. One Other 5. Date Comp., Susp., or Aband. 5/19/2003 6. Date Spudded 5/4/2003 7. Date TD. Reached 5/16/2003 8. KB Elevation (ft): 82.3' 9. Plug Back Depth (MD+ TVD) 8985 + 4663 10. Total Depth (MD+TVD) 8985 + 4663 11. Depth where SSSV set (Nipple) 2218' MD 19. Water depth, if offshore N/ A MSL CASING SIZE 20" X 34" 10-3/4" 7-5/8" 4-1/2" 7-5/8" x 4-1/2" GRADE A53 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTINGD¡;:PTH.N1D SETTINGDEP.rHTVD .. HOLl; Top, BOTTOM, ;50þ,r BOiTOM;,SIZE',' Surface 108' Surface 108' 48" 28' 2843' 28' 2734' 13-1/2" 26' 5966' 26' 4618' 9-7/8" 5862' 8980' 4602' 4663' 6-3/4" 5112' 5874' 4434' 4464' N/A WT. PERF'T~ 215.5# 45.5# 29.7# 12.6# 29.7# /12.6# 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 5220' - 5302' 4462' - 4470' 5312' - 8922' 4470' - 4519' 27. Revised: After ML's added, New Tubing & Corrections 1 b. Well Class: ~ Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-077 13. API Number 50- 029-23153-00-00 14. Well Name and Number: PBU V-202 15. Field / Pool(s): Prudhoe Bay Field / Orion Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED CEMEN,TING1REC:.0RD 260 sx Arctic Set (Approx.) 590 sx PF 'L', 352 sx Class 'G' 435 sx Class 'G' Uncemented Slotted Liner Uncemented Tieback Liner 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 4934' 4792' 4-1/2", 12.6#, L-80 4921' - 5117' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 5945' AMOUNT & KIND OF MATERIAL USED Set IBP (To isolate original perfs while drilling multilaterals) GAs-McF 1,290 GAs-McF 2,211 W ATER-BBl -0- W ATER-BBl -0- CHOKE SIZE 176 GAS-Oil RATIO 1,082 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 4,2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl 11/11/2003 14 TEST PERIOD -+ 1,193 Flow Tubing Casing Pressure CALCULATED ........ Oll-BBL Press. 338 24-HoUR RATE""'" 2,045 OIL GRAVITy-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RE C E IVE 0 JAN 2 3 2004 GØJMSBFl ,ÆB (:»t 1~~h OR\G\NAL ,/ ~v None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE Alaska Oil & Gas Cons. Commission Anchorage 28. GEOLOGIC MARKERS ) 29. JRMA TION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3085' 2945' None Ugnu M 4288' 3973 Schrader Sluff N 4643' 4215' Schrader Sluff OA 4960' 4378' Schrader Sluff OS 5155' 4447' OSa 5155' 4447' OSb 5287' 4487' OSc 5467' 4539' OBd 5807' 4595' RECE\VED JAN 2 3 1.004 . (: I' ommisS\on ska Œ\ & Gas ~on;). u A\a Anchorage 30. List of Attachments: Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~t2IIIILt. ~ Title Techniæl Assistant Date 01- ')..3--{)Lf PBU V-202 203-077 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Oq,~~'~';~L ) ) Well: Field: API: Permit: V-202L 1 & V-202L2 Prudhoe Bay Field 50-029-23153-60 & 50-029-23153-61 203-174 & 203-175 Accept: Spud: Release: Rig: 11/22/03 11/26/03 12/1 0/03 Nabors 9ES . ~ -. . - ." . PRE-RIG WORK 11/11/03 RIH WITH 2.5" JS NOZZLE. TAG BTM AT 8970' CTM. RIH WITH MEM/PPROF LOGGING TOOLS. MAKE STOP COUNTS AT 4700',5900',6000',6500',70001,7500',8000',8900'. MAKE SPINNER PASSES UP/DN FROM 8900' - 6000' AT 30 FPM, 8900' - 6000' AT 60 FPM, 8900'-6000' AT 90 FPM. LOG TIE IN AS POH FROM 6500 TO 5800 AT 40 FPM. FLAG COIL AT 5800 AND POH. VERIFY DATA. 11/12/03 RIH WITH BAKER 2.5" IBP WITH TWO 6" RUBBER ELEMENTS. (1.375" FN). TIE IN TO FLAG AND SET IBP AT 5945 CTMD. POH/LD IBP SET TOOL. MU/ RIH WITH 3" NOZ, CHECK IBP IN PLACE AT 5945'. POH CHANGE WELL OVER TO 1 % KCL AND FREEZE PROTECT WELL TO 2500' WITH DIESEL AND FLOWLINE WITH MEOH. RDMO. 11/13/03 SET 41/211 WHIDDEN CATCHER SUB @ 4840' SLMD. PULL 111 S/O VALVE FROM STA. # 2. BK LATCH, 22/64" PORT (4641 MD) PULL 1" DOME VALVE FROM STA. # 4. BK LATCH, 16/64" PORT. TRO = 1764 PSI.(2585 MD). SET DGLV IN STA. # 4. BK LATCH. 11/14/03 SET DGLV IN STA. # 2.4641' MD. BK LATCH. PULL CATCHER SUB. ATTEMPT MITIA TO 3000 PSI - FAILED THREE TESTS (TUBING AND OA PRESSURES DID NOT CHANGE, SUSPECT GAS IN IA). T/I/0=800/1200/400. PUMP 45 BBLS SEAWATER DOWN IA. PUMP 80 BBLS DIESEL DOWN IA. U- TUBE DIESEL FROM IA TO TBG FOR 1 HR. MIT IA TO 3000 PSI. FAILED. LOST 250 PSI IN 15 MINUTES. BLEED IA DOWN TO 1900 PSI. FREEZE PROTECT FL W/ 10 BBLS METH & 10 BBLS DIESEL. T/1/0=800/1900/400. 11/15/03 A SCMT WAS RUN FROM 4700-5270' TO EVALUATE CEMENT FOR POSSIBLE SIDETRACK. JEWELRY LOG WAS MADE FROM 4901'- 4700' TO CHEM CUT THE PREMIER PACKER. TIE WAS MADE TO TUBING TALLEY. POSITIVE INDICATION OBSERVED ON SURFACE AFTER FIRING CHEMICAL CUTTER. WELL WAS LEFT SHUT IN ON DEPARTURE. PAD OP NOTIFIED. T/I/0=800/1800/400. RIG UP 1/211 LINE FROM IA TO FL ON V-101 TO BLEED GAS. LOAD IA W/ 12 BBLS DIESEL. MIT IA TO 3000 PSI. PASSED. LOST 125 PSI IN 15 MINUTES & 30 PSI IN SECOND 15 MINUTES. BLEED IA DOWN TO 600 PSI. FWP=800/600/400. 11/17/03 T/I/0=750/560/420, TEMP=SI. BLEED TBG, IA & OA (PRE-RWO). TBG FL AT 460', IA FL AT 160', BLED IA FROM 560 PSI TO 300 PSI (GOT FLUID) AND TBG TRACKED TO 500 PSI. BLED TBG FROM 500 PSI TO 250 PSI (GOT FLUID), CONTINUED TO BLEED TBG & IA ALTERNATELY FOR 3 HOURS. BLED TBG TO 0+ PSI (GAS & 0.5 BBL). BLED IA TO 20 PSI (GAS & 1 BBL OF FLUID). OA FL AT 400', BLED OA TO 10 PSI IN 3 HOURS (ALL GAS). FINAL WHP'S=0+/20/10. Legal Name: V-202 Common Name: V-202 Test Date 5/8/2003 5/14/2003 11/26/2003 12/3/2003 11/26/2003 12/3/2003 LOT FIT FIT FIT FIT FIT Test Type Test Depth (TMD) 2,843.0 (ft) 5,975.0 (ft) 5,154.0 (ft) 4,965.0 (ft) 5,154.0 (ft) 4,965.0 (ft) BP Leak-Qff'T't!$t.$i.Jjl1'lrtJ8P¡ Test Depth(TVD) 2,733.0 (ft) 4,620.0 (ft) 4,448.0 (ft) 4,380.0 (ft) 4,448.0 (ft) 4,380.0 (ft) AMW 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) SUrfacèPressul"e . 450 (psi) 550 (psi) 533 (psi) 525 (psi) 533 (psi) 525 (psi) I..EtakOffPl'essure (BAP) 1,756 (psi) 2,758 (psi) 2,659 (psi) 2,618 (psi) 2,659 (psi) 2,618 (psi) EMW 12.37 (ppg) 11.49 (ppg) 11.51 (ppg) 11.51 (ppg) 11.51 (ppg) 11.51 (ppg) --' --' Printed: 12/17/2003 9:15:14 AM ) ) BP c>perationsSummaryReport Page 1 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From - To Hours Task Code NPT Phase 11/22/2003 09:00 - 12:00 3.00 RIGU P DECOMP 12:00 - 14:00 2.00 RIGU P DECOMP Description. of Operations Release rig from V-114a at 09:00 hrs on 11-22-03. Held PJSM with Rig Crew & Peak. Move mud pits and Sub-base to well V-202. Lay herculite. Spot sub base over V-202. Set and level rig. Spot pit module, camp & cuttings tank. HU power,water, steam and mud lines. 22:30 - 00:00 1.50 PULL P ACCEPT RIG @ 14:00 hrs on 11-22-03. Take on seawater in pits. RlU cellar & rig floor. R/U DSM lubricator on 4-1/16" 5m Tree. Pull BPV. RID lubricator. Finish taking on seawater & R/U to reverse out diesel freeze protection from 4.5" tubing & 4.5" x 7-5/8" annulus. SAFETY--- Held PJSM with rig crew & service personnel regarding the displacement of the diesel freeze protect & decompletion of well. Purge HP circulating lines from rig to production tree with seawater. Test to 3500 psi. Line up & pump 12 bbl seawater down 4.5" x 7-5/8" annulus before observing any pressure on well. Continue pumping @ 2 bpm. Pressure increased to 500 psi with slight returns from tubing. Decrease pump rate to 1 bpm, annulus pressure increased to 1000 psi with slight returns from tubing. Manually bled off pressure on annulus to 0 psi. Line up to pump down tubing. Start pumping @ 1 bpm. Pressure increased immediately to 350 psi with no bleed-off observed. Manually bled off tubing pressure to 0 psi. Blow down all lines. DECOMP SAFETY--- Held PJSM with rig crew & Halliburton Slickline personnel regarding R/U & testing lubricator + slickline operations. DECOMP RlU HES lubricator from tree to rig floor. Install Slickline BOP. Continue R/U sheaves & related Slickline equipment. 14:00 -16:30 2.50 RIGU P DECOMP 16:30 - 17:30 1.00 RIGU P DECOMP 17:30 - 19:00 1.50 WHSUR P DECOMP 19:00 - 19:30 0.50 WHSUR P DECOMP 19:30 - 22:00 2.50 WHSUR P DECOMP 22:00 - 22:30 0.50 PULL P 11/23/2003 00:00 - 01 :00 1.00 PULL P NOTE: The plan is to RIH with slickline & set XN Catcher tool in X-nipple @ 4862'. Then pull Dummy valve from GLM @ 4641'. Displace diesel FP from well. RIH & set Dummy valve back in the GLM @ 4641'. Pull XN Catcher tool. R/D Slickline. Continue with de-completion plan. DECOMP Finish RlU HES Slickline equipment. 02:30 - 04:00 1.50 PULL P NOTE: The plan is to RIH with slickline & set XN Catcher tool in X-nipple @ 4862'. Then pull Dummy valve from GLM @ 4641'. Displace diesel FP from well. RIH & set Dummy valve back in the GLM @ 4641'. Pull XN Catcher tool. RID Slickline. Continue with de-completion plan. DECOMP Test lubricator to 3000 psi. HES Slickline RIH with 4.5" XN Catcher tool. Set in X-nipple @ 4862'. POOH to surface. Close Swab valve on tree. Drain lubricator & disconnect above SL BOP. DECOMP Change tools. RIH with a 4.5" OK-6 Kickover tool w/1.25" JDC Pulling tool on slick-line. Latch & pull free the Dummy valve from GLM #2 @ 4641'. POOH to surface. Close Swab valve on tree. Drain lubricator. 01 :00 - 02:30 1.50 PULL P Printed: 12/17/2003 9:15:25AM ) ) BP Page2of15 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From - To Hours Task Code NPT Phase· Description. of Operations 11/23/2003 04:00 - 04:30 0.50 PULL P DECOMP Disconnect lubricator above SL BOP's. Re-dress JDC tool with new Dummy valve. M/U lubricator & test to 3000 psi. 04:30 - 05:00 0.50 PULL P DECOMP Attempt to reverse circulate down 4.5" x 7" annulus. Unable to circulate. Trouble shoot problem. Found discharge line coming off C/K manifold going to cuttings tank (flare line) had froze up. Bleed-off all pressure on C/K manifold & all HP lines from rig floor going to tree. 05:00 - 07:00 2.00 PULL N HMAN DECOMP R/U steam hoses to HP discharge line. Spray steam on outside of flare line & thaw out same. 07:00 - 12:00 5.00 PULL P DECOMP Line up to reverse out. All returns routed through C/K manifold. Pump 48 bbl seawater down 4.5" x 7-5/8" annulus taking diesel returns & contaminated fluid to cuttings tank. Stop pumping & line up to pump down the 4.5" tubing. Pump 59 bbl seawater down tubing (Tbg vol F/4641, = 71 bbl) @ 3 bpm. Observed gas at cuttings tank. Line up to take returns from C/K manifold into Gas Buster. Continue circulating @ 4.5 bpm w/270 psi. Circulate a total of 480 bbl seawater (4.5" x 7-5/8" annulus vol F/4641' = 122 bbl) to clean up well. Monitor well. Well static. Blow down flare line. 12:00 - 12:30 0.50 PULL P DECOMP Blow down all circulating lines & C/K manifold. R/D 2" HP hose coming off Flare line to cuttings tank. Secure Flare line outlet with bull plug. 12:30 - 14:30 2.00 PULL P DECOMP Test HES lubricator to 3000 psi. RIH w/ HES Slickline with Dummy valve & set in GLM @ 4641'. POOH. Close swab valve on tree. Drain lubricator. Disconnect lubricator above SL BOP. 14:30 - 18:00 3.50 PULL P DECOMP HES change tools. Test lubricator to 3000 psi. RIH w/ HES Slickline & 4.5" XN Catcher tool. Tag up on XN Catcher @ 4862'. POOH to surface. Close Swab valve on tree. Drain lubricator & disconnect above SL BOP. Did not recover XN Catcher. Re-pin Catcher tool. M/U lubricator. Test same to 3000 psi. RIH. Latch on to XN Catcher. POOH. Close swab valve on tree. Drain lubricator. Disconnect lubricator above SL BOP. Recovered XN Catcher. RID HES Slickline & related equipment. 18:00 - 18:30 0.50 WHSUR P DECOMP Blow down all surface equipment. Install TWC valve in 4.5" tubing hanger. 18:30 - 20:00 1.50 WHSUR P DECOMP N/D CIW 4-1/16" 5m Production Tree & adapter flange. Inspect TCII threads in hanger-OK. 20:00 - 22:00 2.00 BOPSUR P DECOMP N/U 13-5/8" 5m BOP stack & related equipment. 22:00 - 22:30 0.50 BOPSUR P DECOMP M/U BOP test plug on 4" DP. Run & set same. RlU to test BOP. 22:30 - 00:00 1.50 BOPSUR P DECOMP Test BOPE to 250 psi Low /3500 psi High, Annular 250 psi Low / 3500 psi High. Witnessed of test waived by Jeff Jones, AOGCC. 11/24/2003 00:00 - 02:30 2.50 BOPSUR P DECOMP Finish testing BOPE & all surface related equipment to 250 psi Low / 3500 psi High. Witness of test waived by Jeff Jones of the AOGCC. RID test equipment. 02:30 - 03:00 0.50 WHSUR P DECOMP RlU DSM lubricator & pull TWC valve. RID same. 03:00 - 04:00 1.00 PULL P DECOMP Change out elevator bails & RlU to pull 4.5" tubing string. 04:00 - 04:30 0.50 PULL P DECOMP FMC backed out lock down screws on wellhead. 04:30 - 06:30 2.00 PULL P DECOMP Pull 11 " x 4.5" tubing hanger free with 95k, pull hanger above rotary table. Monitor well. No flow, well static. Attempt to circulate, tubing pressuring up. Stop pumping & bleed-off Printed: 12/17/2003 9:15:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) B P Page 30f15 Operatiol1s.Summary Report V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/24/2003 04:30 - 06:30 2.00 PULL P DECOMP pressure from tubing. Work tubing string up & down (15' stroke) several times to relax packer element. Break circulation & stage up pumps slowly to 3 bpm w/165 psi. No gas or oil observed coming from well while circulating. Circulated a total of 303 bbl. 06:30 - 07:30 1.00 PULL P DECOMP Monitor well-Static. Pump slug. R/D circulating lines & blow down same. POOH to 4425'. LID 11" x 4.5" tubing hanger + 1 0 Jts of 4.5" 12.6# L-80 tubing. 07:30 - 08:00 0.50 PULL P DECOMP Change out long elevator bails to short elevator bails. 08:00 - 13:30 5.50 PULL P DECOMP Continue POOH laying down 4.5" 12.6# L-80 IBT-M tubing (114 Jts total), 4 each GLM, Baker Premier packer, 3 each X-Nipple assemblies, 1 each sliding-sleeve & WLEG. 13:30 - 14:00 0.50 PULL P DECOMP R/D 4.5" tubing handling equipment. 14:00 - 14:30 0.50 BOPSUR P DECOMP R/U & test Lower pipe rams (2-7/8" x 5" VBR) TO 250/3500 PSI. Witness of test waived by Jeff Jones-AOGCC. RID test equipment. 14:30 - 15:00 0.50 WHSUR P DECOMP Run & install wear bushing. Place BOT mills & other BHA componets on rig floor. 15:00 - 18:00 3.00 STWHIP P WEXIT M/U BOT's 6-3/4" Mill assembly + MWD (7-5/8" casing cleanout run) consisting of the following items: 6-3/4" Flat-bottom Mill + Bit Sub + 6-3/4" Watermelon mill + XO Sub + 2 each Boot Baskets + 7-5/8" Casing scraper + MWD + Stab + Oil Jar + 12 x 4-3/4" DC + 15 x 4" HWDP. Totallenght = 910.31'. 18:00 - 22:30 4.50 STWHIP P WEXIT TIH with 6-3/4" Mill assembly picking up 4" DP to 5792'. M/U TDS. Break circulation. Wash down from 5792'. Tag-up on 4.5" ZXP tieback sleeve @ 5862'. P/U Wt 125k S/O Wt 100k 22:30 - 23:30 1.00 STWHIP P WEXIT Pump a 25 bbl HV sweep & circulate hole clean with seawater from 5862' w/ 340 gpm @ 1450 psi. Reciprocate drill string while circulating. 23:30 - 00:00 0.50 STWHIP P WEXIT Clean mud pits & circulating system in preparation for taking on 9.2 ppg MOBM. 11/25/2003 00:00 - 02:00 2.00 STWHIP P WEXIT Clean mud pits & circulating system in preparation for taking on 9.2 ppg MOBM. 02:00 - 04:00 2.00 STWHIP P WEXIT Take on 9.2 ppg MOBM into the rig's mud pit system. 04:00 - 04:30 0.50 STWHIP P WEXIT Pump spacer. Displace hole with 9.2 ppg MOBM @ 340 gpm w/ 2290 psi FCP. Reciprocate drill string once MOBM reached bit. 04:30 - 05:00 0.50 STWHIP P WEXIT Take Slow Pump Rates & prepare to POOH to 5000'. 05:00 - 05:30 0.50 STWHIP P WEXIT Flow check. Well static. POOH to 5000'. 05:30 - 07:30 2.00 STWHIP P WEXIT M/U TDS. Break circulation. Circulate & logging down with MWD from 5000' to 5300' to comfirm RA Tag position for calculating space-out requirements for whipstock. 07:30 - 09:00 1.50 STWHIP P WEXIT POH to LD BHA #1 09:00 - 10:00 1.00 STWHIP P WEXIT Stand back HWDP and DC's 10:00 - 10:30 0.50 STWHIP P WEXIT LD BHA, recovered 1.5 gal. of grit and sand 10:30 - 12:00 1.50 STWHIP P WEXIT Clean and clear rig floor. RU long bails. Bring whipstock and jewelry to rig floor. 12:00 - 14:30 2.50 STWHIP P WEXIT MU whipstock and BHA #2. Orient MWD with whipstock. RU short bails 14:30 -18:00 3.50 STWHIP P WEXIT RIH with whipstock, 130 klbs up, 95 klbs down 18:00 - 19:00 1.00 STWHIP P WEXIT MU top drive, stage pumps to 300 gpm @ 1750 psi. Orient Printed: 12/17/2003 9:15:25AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/25/2003 11/26/2003 ) ) Page 4 of15 BP Operations Sum maryReport V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 18:00 - 19:00 From - To Hours Task Code NPT Phase WEXIT 19:00 - 00:00 00:00 - 00:30 1.00 STWHIP P 5.00 STWHIP P WEXIT 0.50 STWHIP P WEXIT 00:30 - 01 :00 0.50 STWHIP P WEXIT 01 :00 - 01 :30 0.50 STWHIP P WEXIT 01 :30 - 02:30 1.00 STWHIP P WEXIT 02:30 - 04:30 2.00 STWHIP P WEXIT 04:30 - 06:00 1.50 STWHIP P WEXIT 06:00 - 06:30 0.50 STWHIP P WEXIT 06:30 - 06:45 0.25 STWHIP P WEXIT 06:45 - 09:00 2.25 STWHIP P WEXIT 09:00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 00:00 2.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 0.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT 0.50 STWHIP P 8.00 DRILL P WEXIT PROD1 Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Descri ptionof Operations whipstock to 17 degrees left. Stab dummy seal assembly into tie-back sleeve. Set down 25 klbs to set whipstock anchor. PU to verify anchor set. Set down 40 klbs to shear whipstock lug. PU up 115 klbs and rotate at 20 rpm to verify shear Mill window from 5148' to 5160' and drill 16' of new hole to 5176'. RPM = 60-120 Torque = 4-7k FtLb GPM = 280 @ 1500 psi Rotate 106 klbs Pump hi-vis sweep around, circ hole clean at 145 spm, 350 gpm, 2175 psi, work string in & out of window w/ pumps, up wt 120 k, dn wt 90 k, without pumps 130 k, dn wt 100 k, recovered approx.170 Ibs of metal shavings. Perform FIT at 5154' MD /4448" TVD w/ 9.2 ppg OBM to 533 psi, 11.5 ppg EMW Monitor well, POH w/ 2 stds to 5017' MADD pass f/5017' to 4934',140 spm, 345 gpm, 2180 psi, RA tag at 4860', up wt 130 k, dn wt 100 k Slug pipe, POH to milling BHA POH LD Milling BHA, clear and clean rig floor Flush BOP with ported sub. PU BHA #3, 6-3/4" directional assembly At 06:45 a roustabout was injured when he got his foot caught between an I-beam and the pipe skate elevator. An accident investigation was conducted and a safety stand down was held to review the incident with the crew. Continue MU BHA #3 RIH with stands from derrick. Shallow test MWD Safety stand down and incident review with daylight tour. Continue RIH to 5022'. Fill DP at 3000' MU TDS and fill pipe. Orient MWD to 17 degrees left to exit window. Exit window and RIH to 5160 without any problems. Establish baseline ECD of 10.29 ppg @ 275 gpm. 113 klbs up, 92 klbs down. Wash down through undergauge hole from 5160' to 5176' Drill 6-3/4" directional hole from 5176' to 5486'. Slide as required to maintain inclination & azimuth. WOB = 3-12k RPM = 60 Torque off Btm = 3.3k FtLb, Torque on Btm = 4.6k FtLb GPM = 275 @ 2500 psi on Btm, 2300 psi off Btm P/U 118k S/O 89k ROT 104k P/U 128k S/O 92k Without Pumps Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 5486' = 10.29, Actual ECD = 10.61 Landed wellbore -3' lower than plan at 4481' TVD, exiting the Oba sand, turned up hard increasing azimuth to 94 degrees to Printed: 12/17/2003 9:15:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP Operations Summary · Report V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Page 50f 15 Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From ~ To Hours Task Code NPT Phase Description of Operations 11/26/2003 16:00 - 00:00 8.00 DRILL P PROD1 regain Oba contact and maintain directional plan. ART = 0.50 Hrs AST = 3.80 Hrs. Drilling Time last 24 Hrs= 4.30 hrs 11/27/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6-3/4" directional hole from 5486' to 6858'. Slide as required to maintain inclination & azimuth. WOB = 5-20 klbs RPM = 60 Torque off Btm = 3.5k FtLb, Torque on Btm = 4.2k FtLb GPM = 275 @ 2480 psi on Btm, 2430 psi off Btm P/U 116k S/O 86k ROT 103k P/U 124k S/O 90k Without Pumps Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 6858' = 10.52, Actual ECD = 10.75 ART = 6.88 Hrs AST = 8.18 Hrs. Drilling Time last 24 Hrs= 15.06 hrs AIM tool Failure at 17:30 hrs, will continue drilling ahead until the base of the upper Oba sand is seen on logs, then will trip for AIM tool. 11/28/2003 00:00 - 00:30 0.50 DRILL N DFAL PROD1 AIM tool failure. Circulate hi-vis sweep surface to surface at 275 gpm and 2375 psi while reciprocating DP at 60 rpm. Calculated ECD 10.50, actual ECD after circulating 10.70. 120 klbs up, 90 klbs down. 00:30 - 02:00 1.50 DRILL N DFAL PROD1 Monitor well - static. Slug DP and POH to 5111', pass through window with no problems. 130 klbs up, 95 klbs down. Pulled 15 klbs over at 5860', 5600', 5520' able to wipe through all tight spots with no problems. 02:00 - 02:30 0.50 DRILL N DFAL PROD1 Drop ball to open circ sub. Circulate csg clean at 450 gpm and 1830 psi. 02:30 - 04:30 2.00 DRILL N DFAL PROD1 Monitor well - static. Slug DP and POH. 121 klbs up, 99 klbs down. 04:30 - 04:45 0.25 DRILL N DFAL PROD1 PJSM with Anadrill and all rig personnel on unloading and loading RA source. 04:45 - 05:30 0.75 DRILL N DFAL PROD1 unload RA source from ADN tool. 05:30 - 06:30 1.00 DRILL N DFAL PROD1 LD BHA #3 06:30 - 07:00 0.50 DRILL N DFAL PROD1 Clean and clear rig floor. 07:00 - 09:30 2.50 DRILL N DFAL PROD1 MU BHA #4. RIH with collars and jars. Shallow test MWD. 09:30 - 11 :30 2.00 DRILL N DFAL PROD1 RIH with DP to 5022' 11 :30 - 12:00 0.50 DRILL N DFAL PROD1 MU TDS and fill pipe. Orient to 17 degrees left. Pass through window no problem. 119 klbs up, 95 klbs down. 12:00 - 13:00 1.00 DRILL N DFAL PROD1 Continue RIH to 6795'. MU TDS and fill pipe, staging pumps to 275 gpm. Wash last stand to bottom at 6858'. 13:00 - 00:00 11.00 DRILL P PROD1 Drill 6-3/4" directional hole from 6858' to 7729'. Slide as required to maintain inclination & azimuth. Printed: 12/17/2003 9:15:25AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Page 6 of 15 Operations SUmmary Rep.ort V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From"-To Hours Task Code NPT Phase Description of Operations 11/28/2003 13:00 - 00:00 11/29/2003 00:00 - 13:00 13:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 19:00 11.00 DRILL P PROD1 WOB = 10-15 klbs RPM = 60 Torque off Btm = 4.1 k FtLb, Torque on Btm = 5.7k FtLb GPM = 275 @ 2720 psi on Btm, 2660 psi off Btm P/U 122k SIO 80k ROT 99k P/U 132k SIO 87k Without Pumps Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 7728' = 10.70, Actual ECD = 11.26 At 15:00 hrs. second AIM tool failed. Continued drilling ahead surveying every joint 13.00 DRILL P ART = 2.6 Hrs AST = 1.87 Hrs. Drilling Time last 24 Hrs= 4.47 hrs PROD1 Drill 6-3/4" directional hole from 7729' to 8985'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs RPM = 60 Torque off Btm = 5k FtLb, Torque on Btm = 6.1 k FtLb GPM = 275 @ 2900 psi on Btm, 2700 psi off Btm P/U 130k S/O 79k ROT 100k P/U 135k SIO 86k Without Pumps Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8985' = 10.72, Actual ECD = 11.01 1.50 DRILL P ART = 4.08 Hrs AST = 2.62 Hrs. Drilling Time last 24 Hrs= 6.70 hrs PROD1 Circulate hi-vis sweep surface to surface. Pumping 300 gpm at 3108 psi, increased rpm to 80 while reciprocating DP. Started experiencing 8 bph losses at 300 gpm. Reduced rate to 275 gpm at 2700 psi, no losses noted. Total losses = 4 bbl P/U 130k SIO 79k 2.00 DRILL P Calculated ECD = 10.72, Actual ECD = 10.76 prior to POH PROD1 Monitor well- static. Slug DP and POH for short trip to 6611'. Intermintent drag of 5-10 klbs throughout trip, 10-15 klbs drag at 8713',8490' and 8401'. 1.00 DRILL P P/U 135k SIO 85k PROD1 RIH from 6611' to 8985', washing last stand down. Took 30 klbs down at 8471',8565',8658' and 8846'. PROD1 Circulate hole clean, 275 gpm at 3000 psi. Reciprocate DP at 80 rpms. 1.50 DRILL P P/U 135k SIO 85k Printed: 12/17/2003 9:15:25AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP Page? of 15 Operations Summary Report V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From- To Hours Task Code NPT Phase Descri ptionof Operations 11/29/2003 17:30 - 19:00 1.50 DRILL P PROD1 Calculated ECD = 10.72, Actual ECD = 10.90 prior to POH 19:00 - 21 :00 2.00 DRILL P PROD1 POH to circ sub at 5148' P/U 140k SIO 85k 21 :00 - 22:00 1.00 DRILL P PROD1 Orient tool face to 17 degrees left. Drop ball and open circ sub. Circulate across whipstock face to clean retrieval slot. Reciprocate DP 8' without rotating while pumping 300 gpm at 1000 psi 22:00 - 22:30 0.50 DRILL P PROD1 Shut down pumps and POH to 5114', bringing the bit inside 7 -5/8" csg 22:30 - 00:00 1.50 DRILL P PROD1 Cut and slip 93' of drilling line. Service top drive 11/30/2003 00:00 - 00:30 0.50 DRILL P PROD1 Circulate hi-vis sweep surface to surface. 315 gpm @ 990 psi 00:30 - 02:30 2.00 DRILL P PROD1 Monitor well - static. Slug DP and POH. Record PU and SO weights every 1000'. 02:30 - 02:45 0.25 DRILL P PROD1 PJSM with Anadrill and all rig personnel on unloading and transfering RA source. 02:45 - 04:00 1.25 DRILL P PROD1 Unload RA source. LD BHA #4 04:00 - 04:30 0.50 DRILL P PROD1 Clean and clear rig floor. 04:30 - 05:00 0.50 DRILL P PROD1 PJSM with BOT, Anadrill and all rig personnel on PU whipstock retrieval BHA. 05:00 - 07:00 2.00 STWHIP P PROD1 MU whipstock retrieval BHA. Orient and shallow test MWD. 07:00 - 08:30 1.50 STWHIP P PROD1 RIH to 100' above top of window. 08:30 - 09:30 1.00 STWHIP P PROD1 Fill DP, break circulation and orient retrieval hook. Wash down 7' past retrieval slot. Jet retrieval slot on whipstock face for 10 minutes P/U 120k SIO 94k 255 gpm @ 1540 psi 09:30 - 10:00 0.50 STWHIP P PROD1 Orient lug with whipstock face. RIH and engage lug in retrieval slot. slack off and verify the lug is latched up. Pick up to release whipstock, pulled free at 175 klbs string weight. Monitor well - static. Slug DP and blow down top drive. 10:00 - 13:30 3.50 STWHIP P PROD1 POH with whipstock. Limit running speed and easy on and off the slips, no slacking off. 13:30 - 14:00 0.50 STWHIP P PROD1 Stand back HWDP and 4-3/4" Dc's 14:00 - 14:30 0.50 STWHIP P PROD1 LD magnet, jars, bumper sub and MWD 14:30 - 16:00 1.50 STWHIP P PROD1 Change to long bails to LD whipstock. LD whipstock 16:00 - 17:30 1.50 STWHIP P PROD1 Change bails and LD 21 jts of DP and seal assembly. 17:30 - 18:00 0.50 DRILL P PROD1 Clean and clear rig floor 18:00 - 19:00 1.00 CASE P PROD1 RU to run 4-1/2" 12.6# slotted liner 19:00 - 19:30 0.50 CASE P PROD1 PJSM with BOT and all rig personnel on running slotted liner and hook hanger. 19:30 - 23:00 3.50 CASE P PROD1 PU and MU 4-1/2", 12.6#, L-80, IBT-M slotted liner as per running orders. 23:00 - 23:30 0.50 CASE P PROD1 Change elevators and MU flanged hook hanger assembly. P/U 77k SIO 66k 23:30 - 00:00 0.50 CASE P PROD1 Change out elevators to RIH with DP from derrick. 12/1/2003 00:00 - 00:30 0.50 CASE P PROD1 Service top drive, blocks and crown 00:30 - 01 :00 0.50 CASE P PROD1 RIH with 4-1/2", 12.6# slotted liner on DP. At 4800' P/U 93k SIO 79k Printed: 12/17/2003 9:15:25AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP . Page 8 of15 Operations Summary Report V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 ··Date From - To Hours Task Code NPT Phase Description. of Operations 12/1/2003 01 :00 - 01 :30 0.50 CASE P PROD1 Stage pumps 200 gpm @ 540 psi and circulate a DP volume. P/U 96k SIO 79k ROT 89k Torque = 2k ftlbs 01 :30 - 02:00 0.50 CASE P PROD1 RIH with slotted liner attempting to pass through window. Tag up on tie back sleeve at 5862' 02:00 - 02:20 0.33 CASE P PROD1 POH to 5100' for attempt #2 02:20 - 03:00 0.67 CASE P PROD1 Position bent joint at the window. Rotate liner looking for increase in torque. RIH and tag up on tie back sleeve at 5862' 03:00 - 03:20 0.33 CASE P PROD1 POH to 5100' for attempt #3 03:20 - 03:50 0.50 CASE P PROD1 RIH while rotatating slowly 200-300 ftlb increase in torque observed, attempt to RIH. Tag up on tie back sleeve at 5862' 03:50 - 04: 1 0 0.33 CASE P PROD1 POH to 5100' for attempt #4 04: 1 0 - 07:30 3.33 CASE P PROD1 RIH in l' increments from 5140' to 5156', stopping and rotating after each foot observing torque. RIH past 5862'. Continue running 4-1/2" slotted liner until the hook hanger is 30' above TOW. 07:30 - 08:30 1.00 CASE P PROD1 Slack off slowly to 8965', verify the hook hanger is engaged in the window. Drop ball and pump onto seat, pressure up to 3000 psi to release setting tool. PU and verify setting tool released. Continue pressure up to shear ball seat, sheared at 4600 psi. P/U 115k SIO 94k TOW @ 5148' BOW @ 5160' 08:30 - 10:30 2.00 CASE P PROD1 Monitor well - static. Slug DP and POH with setting tool. 10:30 - 11 :30 1.00 CASE P PROD1 Break out and LD Baker liner running tool. Clean and clear rig floor. 11 :30 - 12:30 1.00 CASE P PROD1 Change out elevators and RU 4-1/2" liner running equipment. 12:30 - 13:30 1.00 CASE P PROD1 MU and run mule shoe and 16 jts 4-1/2", 12.6#, L-80 tie back assembly. MU LEM and ZXP Packer assembly. P/U 50k SIO 45k 13:30 - 18:30 5.00 CASE P PROD1 Run LEM assembly on DP. Pass through hook hanger at 5143' with no problems. The mule shoe entered the tie back sleeve at 5862' with no problems. Continue running to set the LEM into the hook hanger collet with the mule shoe at 5874'. 18:30 - 19:00 0.50 CASE P PROD1 Land LEM and PU 1 Ok to verify set. Slack off 30k, drop ball and pump onto seat. Pressure up to 3000 psi to set ZXP packer. Continue pressuring up to blow ball seat, ball seat sheared at 4600 psi. PU and verify packer set. Slack off at 15 rpm to set rotating dogs. P/U 125k SIO 95k Top of Tie Back sleeve @ 5111.5' 19:00 - 20:00 1.00 CASE P PROD1 POH 20' and circulate a bottoms up. 250 gpm @ 800 psi. 20:00 - 22:00 2.00 CASE P PROD1 POH with liner running tool. P/U 120k S/O 1 OOk 22:00 - 22:30 0.50 DRILL P PROD1 Clean and clear rig floor. 22:30 - 23:00 0.50 BOPSUR P PROD1 Pull wear bushing. Install test plug. Printed: 12/17/2003 9:15:25 AM ) ) BP Page gof 15 Operations SUl11maryReport P/U 122k SIO 98k DFAL WEXIT Slug DP and blow down top drive. POH slowly using extrema caution, watching for over pull. At 5046' pulled 20k over, attempted to slack off as per BOT Rep. recomendation. Unable to work string without shearing whipstock lug. DFAL WEXIT MU and fill DP. Establish circulation, 253 gpm, 1510 psi. whipstock oriented 9 degrees left. DFAL WEXIT Pulled 35k over and sheared off of whipstock DFAL WEXIT Mill up to mill off whipstock lug, 70 rpm, 265 gpm at 1521 psi. Mill 5 minutes, reduced torque. PU with a decrease in PU weight from 122k to 117k. Unable to tag up on whipstock, chase whipstock down. Tagged up on top of whipstock at 4927', putting the seal assy at 5088' Monitor well - static. Slug DP and POH to LD milling assembly. LD milling BHA. Starting mill shows wear on top where the whipstock lug was milled and is missing a few buttons and shows some wear on the sides. PU hook assembly. RIH with hook assembly Work hook down whipstock slide attempting to latch into retrieval slot. Make three attempts rotating DP 1/4 turn after each attempt. On the third attempt latched into whipstock, PU 60k over to release anchor. PU and verify whipstock free, increase in PU weight from 117k to 120k. CBU, 196 gpm at 826 psi Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -202 V -202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From ~To Hours Task Code NPT Phase 12/1/2003 23:00 - 00:00 1.00 BOPSUR P PROD1 12/2/2003 00:00 - 02:30 2.50 BOPSUR P PROD1 02:30 - 03:00 0.50 BOPSUR P PROD1 03:00 - 03:15 0.25 STWHIP PROD1 03:15 - 04:45 1.50 STWHIP P WEXIT 04:45 - 05:30 0.75 STWHIP P WEXIT 05:30 - 08:45 3.25 STWHIP P WEXIT 08:45 - 09:00 0.25 STWHIP P WEXIT 09:00 - 09:30 0.50 STWHIP P WEXIT 09:30 - 10:30 1.00 STWHIP N 10:30 - 12:00 1.50 STWHIP N 12:00-12:15 12:15-12:30 0.25 STWHIP N 0.25 FISH N 12:30 - 15:00 2.50 FISH N DFAL WEXIT 15:00 - 15:30 0.50 FISH N DFAL WEXIT 15:30 - 16:00 0.50 FISH N DFAL WEXIT 16:00 - 18:00 2.00 FISH N DFAL WEXIT 18:00 -18:15 0.25 FISH N DFAL WEXIT 18:15-18:45 0.50 FISH N DFAL WEXIT 18:45 - 21 :30 2.75 FISH N DFAL WEXIT 21 :30 - 22:00 0.50 FISH N DFAL WEXIT 22:00 - 23:00 1.00 STWHIP N DFAL WEXIT 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT 12/3/2003 00:00 - 03:00 3.00 STWHIP N DFAL WEXIT 03:00 - 03:30 0.50 STWHIP N DFAL WEXIT Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Description of Operations Test BOPE to 250 psi low and 3500 psi high. Witness of BOP test waived by John Crisp with AOGCC. Continue test BOPE to 250 psi low and 3500 psi high. Pull test plug, RD test equipment. Install 7-1/16" wear bushing. PJSM with BOT and all rig personnel on PU and running whipstock. PU whipstocklmilling BHA RIH with 4-3/4" DC's and HWDP. Shallow test MWD. RIH with whipstocklmilling BHA @ 1 minlstand Fill DP and orient whipstock to 15 degrees left. RIH and tag tie back sleeve at 5111', stab seal assy into tie back and continue RIH 11'. Slack off 22 klbs to set anchor. PU to verify anchor set, no over pull does not appear anchor set. Set down again with 25 klbs to set anchor, again it does not appear the anchor set. P/U 120k SIO 97k Monitor well - static. Slug DP and POH with whipstock. LD hook and whipstock. Inspect seal assembly. MU whipstock/milling BHA RIH whith whipstock/milling BHA. Shallow test MWD. Continue RIH with whipstock at 1-1/2 minutes/stand. Orient whipstock to 13 degrees left. Slack off and start seal assy into tie back at 5111. Continue slacking off to 5121', seal assembly bottomed out in tie back sleeve. Slack off 20k to set Printed: 12/17/2003 9:15:25AM ) ) BP Page 10of15 o perati ons .51.1 mma ryRe port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V -202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From - To Hours Task CodeNPT Phase Descri ptionofOperations 12/3/2003 03:00 - 03:30 0.50 STWHIP N DFAL WEXIT whipstock anchor, PU 10k to verify set. Slack off 30k to shear whipstock lug. PU to free point and rotate to verify lugs sheared. 03:30 - 07:30 4.00 STWHIP P WEXIT Obtain slow pump rates. Mill window from 4959' to 4971'. Continue dressing window and drill new hole to 4990'. WOB = 1-10 klbs RPM = 100 Torque = 6k FtLb GPM = 258 @ 1373 psi Whip stock oriented 13 degrees left of high side TOW = 4959' BOW = 4971' 07:30 - 08:30 1.00 STWHIP P WEXIT Circulate 50 bbl hi-vis sweep surface to surface monitoring returns for metal. Continue circulating another bottoms up. Reciprocate DP @ 120 RPM Torque = 3k FtLb GPM = 275 @ 1690 psi Wipe through window with no problems. 280 Ibs metal returns while milling window. 08:30 - 09:30 1.00 DRILL P PROD1 POH to top of window and perform 11.5 ppg EMW FIT. 525 psi pump pressure, 9.2 ppg MOBM at 4380' TVD 09:30 - 11 :00 1.50 STWHIP P WEXIT Monitor well - static. Slug DP and POH to PU 6-3/4" steerable BHA. 11 :00 - 12:00 1.00 STWHIP P WEXIT Stand back HWDP and DC's 12:00 - 14:00 2.00 STWHIP P WEXIT LD milling BHA. Clean and clear rig floor. Flush stack with ported sub. 14:00 - 15:00 1.00 STWHIP P WEXIT PU 6-3/4" Drilling BHA #9 15:00 - 15:30 0.50 STWHIP P WEXIT PJSM with Anadrill and all rig personnel on loading RA source. Load source. 15:30 - 16:00 0.50 STWHIP P WEXIT Continue MU BHA #9. Shallow test MWD 16:00 - 18:00 2.00 STWHIP P WEXIT RIH to 4923', 35' above the window. 18:00 - 19:30 1.50 STWHIP P WEXIT Cut and slip 85' of drilling line. Service top drive and crown. 19:30 - 20:00 0.50 STWHIP P WEXIT Orient 13 degrees left and pass through window with no problems. RIH to 4975' 20:00 - 00:00 4.00 DRILL P PROD2 Wash and ream through under gauge hole from 4975' to 4990'. Drill 6-3/4" directional hole from 4990' to 5050'. Sliding to build inclination to 93 degrees. WOB = 5-10 klbs GPM = 275 @ 2050 psi on Btm, 1997 psi off Btm P/U 115k SIO 89k P/U 123k SIO 98k Without Pumps Calculated ECD = 10.11, Actual ECD = 11.15 ART = 0.00 Hrs AST = 1.58 Hrs. Drilling Time last 24 Hrs= 1.58 hrs 12/4/2003 00:00 - 06:00 6.00 DRILL P PROD2 Drill 6-3/4" directional hole from 5050' to 6732'. Slide as Printed: 12/17/2003 9:15:25 AM ) ) BP Page 11 of 15 Operations Sum mary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From- To Hours Task Code NPT Phase Description· of Operations 12/4/2003 00:00 - 06:00 6.00 DRILL P PROD2 required to maintain inclination & azimuth. WOB = 5-15 klbs RPM = 60 Torque off Btm = 3.4k FtLb, Torque on Btm = 7-8k FtLb GPM = 275 @ 2444 psi on Btm, 2175 psi off Btm P/U 121 k SIO 90k ROT 103k P/U 131 k SIO 92k Without Pumps Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ = 10.33, Actual ECD = 10.80 No AIM tool being run taking surveys every joint ART = 3.86 Hrs AST = 7.96 Hrs. Drilling Time last 24 Hrs= 11.82 hrs 12/5/2003 00:00 - 00:00 24.00 DRILL P PROD2 Drill 6-3/4" directional hole from 6732' to 8612'. Slide as required to maintain inclination & azimuth. WOB = 10-20 klbs RPM = 60 Torque off Btm = 5k FtLb, Torque on Btm = 7k FtLb GPM = 260 @ 2530 psi on Btm, 2440 psi off Btm P/U 123k SIO 81 k ROT 102k P/U 130k SIO 89k Without Pumps Backream every stand at 260 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ = 10.43, Actual ECD = 10.51 No AIM tool being run taking surveys every joint to maintain inclination and azimuth. At 06:00 started losing fluid sporadically, average losses 6 bph. Reduced MW from 9.2 ppg to 9.0 ppg and reduced pump rate to 260 gpm. No losses with reduced MW and pump rate. Total losses 87 bbl ART = 8.37 Hrs AST = 3.83 Hrs. Drilling Time last 24 Hrs= 12.20 hrs 12/6/2003 00:00 - 05:00 5.00 DRILL P PROD2 Drill 6-3/4" directional hole from 8612' to 8965'. Slide as required to maintain inclination & azimuth. WOB = 15-20 klbs RPM = 60 Torque off Btm = 5.2k FtLb, Torque on Btm = 6.5-8k FtLb GPM = 260 @ 2530 psi on Btm, 2260 psi off Btm P/U 123k SIO 83k ROT 103k P/U 130k SIO 82k Without Pumps Printed: 12/17/2003 9:15:25 AM -) ) BP Page 12 of 15 OperationsSÜ mmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From- To Hours Task Code NPT Phase Description. of· Operations 12/6/2003 00:00 - 05:00 5.00 DRILL P PROD2 Backream every stand at 260 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.43, Actual ECD = 10.51 TO L2 at 8965' as per directional plan ART = 1.35 Hrs AST = 1.60 Hrs. Drilling Time last 24 Hrs= 2.95 hrs 05:00 - 07:30 2.50 DRILL P PROD2 Ciculate and condition hole. 275 gpm @ 2515 psi, reciprocate DP at 80 rpm. Calculated ECD = 10.69, Actual ECD = 10.82 Prior to POH 07:30 - 10:00 2.50 DRILL P PROD2 Monitor well- static. POH to 8500', no problems. Slug DP and continue POH to 5100'. stage pumps to 260 gpm, orient to 13 degrees left. POH to above the whipstock, passing through the window with no problems. 10:00 - 10:30 0.50 DRILL P PROD2 Service top drive. 10:30 - 12:30 2.00 DRILL P PROD2 Monitor well - static. RIH to 8875', break circulation at 7200'. No hole problems noted. 12:30 - 14:30 2.00 DRILL P PROD2 Monitor well - static. POH to 8500', no problems. Slug DP and continue POH to 5100'. stage pumps to 260 gpm, orient to 13 degrees left. POH to above the whipstock, passing through the window with no problems. 14:30 - 17:00 2.50 DRILL P PROD2 Service top drive. 17:00 - 18:30 1.50 DRILL P PROD2 Monitor well - static. RIH to 8875', break circulation at 7200'. No hole problems noted. 18:30 - 20:30 2.00 DRILL P PROD2 20:30 - 21 :00 0.50 DRILL P PROD2 21 :00 - 22:30 1.50 DRILL P PROD2 Unload RA source and LD BHA. 22:30 - 23:00 0.50 DRILL P PROD2 Clean and clear rig floor. 23:00 - 23:30 0.50 STWHIP P PROD2 Bring whipstock retrieval BHA to rig floor 23:30 - 00:00 0.50 STWHIP P PROD2 Service top drive and blocks 12/7/2003 00:00 - 01 :30 1.50 STWHIP P PROD2 PU whipstock retrieval BHA. Shallow test MWD 01 :30 - 03:30 2.00 STWHIP P PROD2 RI H to 4839' 03:30 - 03:45 0.25 STWHIP P PROD2 Stage up pumps to 230 gpm @ 1200 psi. Orient lug and wash down over whipstock face. P/U 118k SIO 99k 03:45 - 04:00 0.25 STWHIP P PROD2 PU and engage whipstock. Continue PU, pulling 60k over to release whipstock anchor. PU and pull seal assembly out of tie back sleeve. P/U 122k 04:00 - 04:30 0.50 STWHIP P PROD2 CBU, 250 gpm @ 2300 psi 04:30 - 06:30 2.00 STWHIP P PROD2 Monitor well - static. Slug DP and POH with whipstock. 06:30 - 08:30 2.00 STWHIP P PROD2 Stand back HWDP. LD whipstock retrieval BHA. 08:30 - 10:30 2.00 CASE P PROD2 Clean and clear rig floor. Rig up 4-1/2" liner equipment 10:30 - 11 :00 0.50 CASE P PROD2 PJSM with BOT and all rig personnel on running 4-1/2", 12.6#, L-80 tbg and setting hook hanger. 11 :00 - 16:30 5.50 CASE P PROD2 PU and MU 4-1/2", 12.6#, L-80 slotted liner at 90 ftlmin. RUN Printed: 12/17/2003 9:15:25 AM ) ) BP Page 130f15 Operations Summary Rep()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From:.; To Hours Task Code NPT Phase Description of Operations 12/7/2003 11 :00 - 16:30 5.50 CASE P PROD2 slotted liner on DP to 30' above the top of the window. P/U 99k SIO 86k 16:30 - 16:45 0.25 CASE P PROD2 RIH with slotted liner attempting to pass through window. Tag up on tie back sleeve at 5111'. POH above window for attempt #2 16:45 - 17:00 0.25 CASE P PROD2 Rotate the DP 1/4 turn and RIH with slotted liner attempting to pass through window. Tag up on tie back sleeve at 5111'. POH above window for attempt #3. 17:00 - 17:20 0.33 CASE P PROD2 Rotate the DP 1/4 turn and RIH with slotted liner attempting to pass through window. Tag up on tie back sleeve at 5111'. POH above window for attempt #4. 17:20 - 20:00 2.67 CASE P PROD2 Rotate the DP 1/4 turn and RIH with slotted liner attempting to pass through window. Successfully pass through window and continue running slotted liner at 60 ftImin to 30' before hook hanger engages window. P/U 137k SIO 84k 20:00 - 20:10 0.17 CASE P PROD2 RIH with slotted liner attempting to engage hook hanger in window. RIH 10' past engagement point. POH 15' above window for attempt #2 20: 1 0 - 20:20 0.17 CASE P PROD2 RIH with slotted liner attempting to engage hook hanger in window. RIH 10' past engagement point. POH 15' above window for attempt #3 20:20 - 20:30 0.17 CASE P PROD2 RIH with slotted liner attempting to engage hook hanger in window. RIH 10' past engagement point. POH 15' above window for attempt #4 20:30 - 21 :30 1.00 CASE P PROD2 RIH with slotted liner and engage hook hanger in window, set down 16k over string weight. Drop ball and pump onto seat. Pressure up to 2200 psi to release HR setting tool. switch to test pump and continue pressure up to 4600 psi to blow the ball seat. PU and verified setting tool released. P/U 116k SIO 86k 21 :30 - 00:00 2.50 CASE P PROD2 POH with running tool 12/8/2003 00:00 - 00:30 0.50 CASE P PROD2 RU 4-1/2" tbg equipment 00:30 - 01 :00 0.50 CASE P PROD2 PJSM with BOT and all rig personnel. MU 4-1/2" 12.6# tbg and LEM assembly 01 :00 - 01 :30 0.50 CASE P PROD2 RD 4-1/2" tbg equipment 01:30 - 05:10 3.67 CASE P PROD2 RIH with LEM and tbg tie back on DP. Reduce running speed to prevent DP from running over. 05: 10 - 05:20 0.17 CASE P PROD2 With mule shoe 1 stand above hook hanger establish string weights and RIH passing mule shoe through hook hanger. 06:00 - 07:30 1.50 CASE P P/U 116k SIO 99k PROD2 Continue RIH placing LEM inside hook hanger. PROD2 PU 10k over string weight and verify LEM latched in hook hanger. PROD2 SO 10k and drop ball and pump onto seat. Pressure up to 3300 psi to set packer. PU to release seeting tool, rotate at 15 rpm and SO 50k to set rotating dogs. Stand back 1 stand, RU test pump and pressure up to 5000 psi to blow ball seat. 05:20 - 05:40 05:40 - 06:00 0.33 CASE P 0.33 CASE P Printed: 12/17/2003 9:15:25AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP Page 14 of 15 Operations Summary Report V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 Date From - To· Hours . Task Code NPT Phase· Descri ption of Operations 12/8/2003 07:30 - 10:30 3.00 CASE P PROD2 Monitor well - static. Slug DP and POH, standing back 9 stands. Continue POH laying down DP. 10:30 - 13:30 3.00 CASE P PROD2 MU ported sub and RIH with DP stands from derrick 13:30 - 16:00 2.50 CASE P PROD2 Break circulation and displace well to 9.2 ppg brine. Pump 25 bbls LVT oil, 25 bbl hi-vis pill, 50 bbls brine treated with soap, followed by 25 bbl viscosified pill. Chase with brine, 220 gpm @ 500 psi. Reciprocate DP at 60 rpm. P/U 107k SIO 94k ROT 102k 16:00 - 18:00 2.00 DRILL P PROD2 Clean MOBM from shakers, possum belly, trough and the rig floor 18:00 - 23:00 5.00 CASE P PROD2 POH laying down DP 23:00 - 00:00 1.00 BOPSURP COMP PU test joint and pull wear bushing. Clean and clear rig floor. 12/9/2003 00:00 - 00:30 0.50 RUNCOrvP COMP Clean MOBM from rotarty table, under pipe racks and all sumps. 00:30 - 02:30 2.00 RUNCOrvP COMP RU I-wire spool and sheave. RU all completion equipment. Change out bails. Make dummy run with tbg hanger and landing joint. 02:30 - 03:30 1.00 RUNCOrvP COMP PJSM with Centrilift, Cameo, BOT, Nabors Csg and all rig personnel on running 4-1/2", 12.6# completion and making uplrunning I-wire and Phoenix gauges 03:30 - 13:00 9.50 RUNCOrvP COMP MU & RIH with 5-1/2" Mule Shoe on 4-1/2" 12.6# L-80 IBT-M production tubing with Baker 7-5/8" x 4.5" Premier packer. Make up and test I-wire and Phoenix gauges. Continue RIH with 4-1/2" completion string with 3 each GLM assemblies & related completion jewelry (Test I-wire every 1000'). Tag up at 4939'. P/U & space out. M/U FMC 11" x 4.5" Tubing Hanger with 1 Ft of Blast Rings on Pup Jt below hanger ( Top thread on hanger is 4.5" TC-II). 13:00 - 14:30 1.50 RUNCOrvP COMP Run final test on I-wire & Phoenix gauges. Land Tubing Hanger. RILDS. P/U Wt = 90k SIO Wt = 78k. 14:30 -15:30 1.00 RUNCOrvP COMP Rig up to reverse circulate. Reverse circulate down 7-5/8" annulus & up tubing string @ 3 bpm wI 225 psi with 25 bbl 9.2 ppg brine + 3 bbl of treated 9.2 ppg corrosion inhibited brine followed by 122 bbls of 9.2 ppg clean filtered brine to put corrosion inhibitor in the annulus between top of packer @ 4792' & DCK Shear valve @ 4627' MD. 15:30 - 17:00 1.50 RUNCOrvP COMP RID tubing pump-in sub. Drop 1-7/8" Ball-rod & allow to gravitate on seat. UD the 4.5" Tubing Landing Jt. Pressure up on tubing to 4200 psi to set Baker Premier packer. Manually bled off tubing pressure to 3500 psi. Hold pressure test for 30 minutes. Test was API. Manually bled off tubing pressure to 2500 psi. Pressure up 4.5 x 7-5/8" annulus to 3500 psi. Hold test for 30 minutes to test casing integrity. Test was API. Manually bled off pressure on both tubing & annulus to 0 psi. Pressure up 4.5" x 7-5/8" annulus to 2200 psi & sheared DCK valve in the GLM @ 4627'. Circulate @ 3 bpm @ 1800 psi. Manually bled off pressure to 0 psi on tubing & annulus. 17:00 - 17:30 0.50 RUNCOrvP COMP Blow down all surface lines. UD 4.5" Tubing Landing Jt. FMC install TWCV. Test TWCV from below to 1000 psi-OK. 17:30 - 19:30 2.00 BOPSURP COMP PJSM. NID BOP's. Set back & secure. 19:30 - 22:30 3.00 WHSUR P COMP FMC Service Rep terminate I-wire through exit bore (DHCV) in 11" 5k x 4-1/16" 5k Tubing Head adapter. N/U Tubing Head Printed: 12/17/2003 9:15:25 AM BP OperatiQnsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date V-202 V-202 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/22/2003 Rig Release: 12/10/2003 Rig Number: Spud Date: 5/4/2003 End: 12/10/2003 12/9/2003 From- To Hours Task Code NPT Phase 19:30 - 22:30 3.00 WHSUR P COMP 22:30 - 23:30 1.00 WHSUR P COMP 23:30 - 00:00 0.50 RUNCOrvP COMP 00:00 - 01 :30 1.50 RUNCOrvP COMP Description of Operations 01 :30 - 03:00 1.50 WHSUR P adapter & 4-1/16" 5k Production tree. Test tubing head adapter pack-off & tree body to 5000 psi. R/U DSM lubricator & pull TWCV. PJSM. R/U to freeze protect IA. R/U Little Red Hot Oil & test lines to 3000 psi. Freeze protect 4-1/2" x 7-5/8" annulus. Reverse circulate 93 bbl of diesel down 4.5" x 7" annulus @ 3 bpm wI 2200 psi FCP. Let well U-Tube & equalize. Well freeze protected to 2235' MO I 2200' TVO. Install BPV in Tubing Hanger. Test to 1000 psi. Install VR plugs in Tubing Spool valve outlet. RID Hot Oil line. Secure well. 12/1 012003 COMP Release Rig 9ES from V-202 @ 03:00 hrs on December 10, 2003. Printed: 12/17/2003 9:15:25 AM -, V-202 V..202 L 1 V-202 L2 - From Drlg I sAFl ì )OTES : TREE = FMC4-1/6" 5M W8..LHEAD = FMC GI3'J 5 '¡.\'CfUA TOR ;;.,-".,~,._.,.. KB. ELEV = 82.30' 'BF. ELST;' 53.8Õ: KoP'-;-'"~"-""''''' .""~~,........",,,-,........ MaX-Angie = 9Š-@ 649'4': DatumMD= 5713' \O~· .., Datum TVD = 4500' SS 120# CONDUCfOR H ;d I 110-3/4" CSG. 40#. L-80. ID = 9,95" H 2843' Minimum ID = 2.750" @ 5971' 4-112" HES XN NIPPLE 14.5"PHOENIX DSCHRGE-ffiESS SUB.ID = 3.85" 1-1 H 14.5" PHNIX MLl TI-PRESS SI3'JSOR, ID = 3.833" IRA TAG 1--1 17-5/8" x 5.5" BKR ZXP PACKER, ID = 5.5" IBKR HUGHES HOOKWALL HGR, ID = 5.64" 1-1 IRA TAG I., 17-5/8" x 5.5" BKR ZXP PACKER. ID = 5.5" 1-1 I BKR HUGHES HOOKW ALL HGR, ID = 5.64" 1-1 IRA TAG I" IRA TAG 1-1 ~ L 4733' (I I 4768' ~ 4867' ~ ~ H :~~: ~ 5062' 1- 5112' ~ ~ ~ 5143' 5191' 5719' ÆRFORA 1l0N SLlvUvlARY RB= LOG: ANGLEA T TOP PERF: 67 @ 7201' Note: Refer to Production œ for historical perf data SIZ E SPF INTER\! AL Opn/Sqz DATE 4-1/2" SLTD OBA 5031 - ~ ge4'Z. 12/07/03 4-1/2" SLTD OBC5220 -~ e«ftz:z. 12/01/03 4-1/2" SLTD OBD6021 -B98(7 <ò<¡q, 05/19/03 175/8" CSG, 26#. L-80. ID = 6.276" H 5966' ~ J.{·Yi' \2 ..~. £.....80 ~ 8980' DATE OS/20/03 06/15/03 07/16103 11/12/03 11/24/03 12/10/03 REV BY COMI'ÆNTS DAO'KK ORIGINAL COMA-EriON JM/KA K 0'0 SPM3 JCMrrLH Go..V C/O JGMrrLH SET BP M-f/PA G Go.. V C/O TA ADD L 1 & L2 DATE REV BY I I 2218' H4-1/2" I-ESX NIP, D =3.813" I ~ GAS LIFT MA.NDR8..S ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 2565 2493 30 KBG-2 D0<2 BEK 12/09103 2 3698 3484 29 KBG-2 DMY BK-5 0 12/09103 1 4628 4206 52 KBG-2 DMY BK-5 0 12/09103 ¡ 4744' H4-1/2" BKR crvo SLæ.\IE, ID = 3.813" Z---J 4792' 1~7.625"X 4.5" BKRPRM A<R, ID= 3.875" I 4861' H4-1/2" HES X NIP, D = 3.813" I I 4882' H4-1/2" HESX NIP, ID=3.813" I ~ I 4934' H4-1/2" MJleShoe ~..'/4tf IZ..(¡,·L.-..·go L l i - - - ~~ ;¡;,,- -, i:~· "L: ~ I 7" WNDOW @ 4959' J""'"' - -Sh"o;.-ci+-s:iQ3S- -..,...Uërf' ei".s 4959' - 8965 6-3/4".Q87!I: LATERAL, 10 = 3.958" t'JA I 5117' H4-1/2" MJle Shoe, .q.'/1J" 12,." ð: Á"",et:> . fu- -- - ~: iïi·; -12.~ ï.,,¡. -ciP I 7" WINDOW @ 5148' ~. --SJjÕ....-Q¡.-šë¡~s---~q+ 89ß~ 5148' - 8965' 6-3/4" Gdet LATERAL, ID = 3.958" ()~ 5862' H7.625" X 5.5" BKRZXPLNR TOPPKR, ID = 4.810" I 5874' H4-1/2" Mule Shoe, q"~J" 12..(,1L(,....C¿3D ~I 5882' H5-1/2" X4-1/2"XO, ID= 3.958" I I 5971' H4-1/2"I-ESXNNIP,ID=2.750" I I I 15945' CTM H2.5" IBP I I I I I I ~ l ~ 5966' - 8980' 6-3/4" oarfLATERAL, ID = 3.958" ned " COWMI3'JTS ORION UNIT WELL: V-202. V -202 L 1, V -202 L2 PERrv1IT No: 203077 (174) (175) AR No: 50-029-23153-00 (60) (61) SEC 11. T11N, R11E, 4820' NSl & 1848' WEL BP Exploration (Alas ka) TREE = FMC4 -1/6" 5M • V -202 ' WELLI AD = FMCGBJ 5 SAF OTES: I V ®202 Li ACTUATOR = KB. ELEV = 82.30' V-202 L2 - From Drlg Oc\J`rvq ( Dr' 11 BF. ELEV = 53. LtI ( f rI c012 b..<5 / 0 ac KOP = - 1 — . e.61 Max Angle = 95 @ 6494' Datum MD= 5713' LC. (U9 1"'Q5 , OFF) Datum TVD = 4500' SS 120# CONDUCTOR H,p$ 1 1 t l n,C S-Pri D9s Ct) I I 2218' — 14 -1/2" I-ESX NIP, D = 3.813" 110 -3/4" CSG. 40#, L -80, ID = 9.95" h 2843' GAS LIFT MANDRELS Minimum ID = 2.750" @ 5971 ST MD TVD DEV TYPE VLV LATCH PORT DATE ' I 3 2565 2493 30 KBG-2 DCK2 BEK 12/09/03 4-1/2" HES XN NIPPLE L i 2 3698 3484 29 KBG-2 DMY BK -5 0 12/09/03 1 4628 4206 52 KBG-2 DMY BK -5 0 12/09/03 14.5 "PHOENIX DSCHRGE -FRESS SUB, ID = 3.85" H 4733' , ---- 4744' H4 - 1/2" BKRCMD SLEEVE, ID= 3.813" I 14.5" PH NIX MULTI -PRESS SENSOR, ID = 3.833" H 4768' I X I 4792' H7.625" X 4.5" BKR PRM FKR ID = 3.875" I RA TAG 4867' I I 4861' H4 -1/2" HESX NIP, D= 3.813" I Lf gp 7 -5/8" x 5.5" BKR ZXP PACKER, ID = 5.5" I 4921' I I 1 4882' ( 14 1 /2" HESX NIP, ID = 3.813" I 4. 01: ∎Z' 0 4934' —14-1/7 Mule Shoe I Floe ct4 ©1 35 - BKR HUGHES HOOKWALL HGR ID = 5.64" H 4954' I ; L.Z. y,, /Ln 1 Z (o* L -80 7" WNDOW @ 4 IRA TAG H 5062' I 4959' - 8965 6 -3/4" OBtC'LATERAL, ID = 3.958" I7 -5/8" x 5.5" BKR ZXP PACKER, ID = 5.5" H 5112' 5117' —14-1/2" Mule Shoe 4 y2;' 112. Vim- L- ED .-- A - a{ 8%5 I BKR HUGHES HOOKWALL HGR ID= 5.64" H 5143' I : t,,1 y.� /t,: t2 ' L•54:711 7" WINDOW @ 5148' RA TAG 5191' 111 . / -r + 99 s 5148' - 8965' 6 -3/4" OBC LATERAL, ID = 3.958" IRA TAG I 5719' hRA. PERFORATION SUMMARY 5862' H7.625 " X5.5" BKRZXPLNRTOPPKR ID= 4.810" 1 RE LOG: � I 5874' H4 -1/2" Mule Shoe I4• /Z, (t•` 1 SO ANGLEAT TOP PERF: 67 @7201' 5882' H5-1/2" X 4-1/2" XO, ID = 3.958" 1 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE I 5971' H4 -1/2" HES XN NIP, ID= 2.750" 1 4 -1/2" SLTD OBA 5031 - 8.995 8892• 12/07/03 4 -1/2" SLTD OBC 5220 - 8985 g9 12/01/03 I CTM 1- 12 .5 " IBP I 4 -1/2" SLTD OBD6021 -8980- 8941 05/19/03 , 5966' - 8980' 6 -3/4" Q. LATERAL, ID = 3.958" 17 5/8" CSG, 26#, L -80, ID = 6.276" H 5966' I • , &Ad c(.t /L " 1Z.4.. L -$O IF$TD H 8980' I DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 05/20/03 DAGKK ORIGINAL COMPLETION WELL: V -202, V -202 L1, V -202 L2 06/15/03 JM /KAK C/O SPMG PERMIT No: 203077 (174) (175) 07/16/03 JCM/TLH GLV C/O AR No: 50- 029 - 23153 -00 (60) (61) 11/12/03 JGM/TLH SET BP SEC 11, T11N, R11E, 4820' NSL & 1848' W8_ 11/24/03 MH /PAG GLV C/O 1 12/10/03 TA ADD L1 & L2 BP Exploration (Alaska) 1,.)5 ~ ·1'- ) WELL LDG TRANSMITTAL 803 r-O 1"~1 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 V-202 11-11-03 Res. Eva!. CH 1 JrY<-~ 71- 1 1 Mech. CH 1 Caliper Survey Signed: ~,r- ______ ,~F:;\ ~Y'\ \-') ,---C; ~ ~'~--'''v,,",,\ RECEIVED Date: Print Name: 1~)! 2(1 2004 ..... .; , '-' Alaska Oil & Gas Cons. ComrniIion Anchorage PRoACTivE DiAGNOSTic SERvicEs, INC., PO Box 1 ~ó9 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.cc:n ~~~(,\~ 12/15//03 SChlumberger NO. 3071 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm A ttn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Field: Polaris Borealis Orion Date BL Color CD 04/16/03 1 11/12/03 2- J éì .?S9( 11/15/03 2 11/17/03 t 1 J(~.~¿ D W-207 ~. C)~'êf'lq 10564457 USIT V-114APB1 t\~ '--- r3t:=S 10687655 CH EDIT USIT (PDCL) V-202 "(), ~ 'D1 T 10662969 SCMT V-114A a.~--\ 3,~ 10662970 CH EDIT CBUSONIC GR '-" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 ~ r::.'~ ~ p~, IE D k~ {"¡r-~ V~_ J ..~ ~""'""t~1t.:j.-':" ~.J ~~ -~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Date Delivered: DEC 22 2003 Received b~,ê'~~"'-~ .~~ C't~~ ~~~ í\\ ~ :jJeska .J¡i ii \;;!:1S 1..Xm3. l..OmmlS..,~n Anchomge bp ) }03 -077- o ", r.:t:""W':r~, .'''''''1:.. r'.~', 1-' r.o: Þ' ~ 1: j.:;,,' f ·,If":.",~ 'j .' i \ :.., ,.... "P,' l ! !.: .' f (o' f C,' oJ.":.'-.J ¡ \¡.f v (": ~"" " :",;..'ó1 ~. 'uI' ~L\ ~..: .: ~ BP Exploration (Alaska) Inc, 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561 -5111 " t .. ... -' ~ ......, ~~;." ... I\, ., September 30, 2003 Mark Myers, Director Division of Oil and Gas Department of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 RE: Orion V-201N-202 Tract Operations Status Report Prudhoe Bay Unit Dear Dr. Myers: BP Exploration (Alaska) Inc. (BPXA), Operator of the Prudhoe Bay Unit, hereby submits the status report requested in your May 14, 2003 letter approving and continuing tract operations for the Orion V-201 and V-202 Wells. The attached status report is similar in content to our April 1 0, 2003 presentation to the Division of Oil & Gas concerning the Orion V-201N-202 Wells. Any questions concerning this status report should be directed to either Gary Gustafson at 564-5304 or Jonathan Williams at 564-5854. Sincerely, I. ~- [). (.- Brian Huff Satellite Resource Manager Greater Prudhoe Bay Attachment: Orion V-201N-202 Status Report Cc: M. Vela, ExxonMobil K. Griffin, Forest Oil D. Kruse, CPAI G.M. Forsthoff, Chevron \:i. 'ustafson, BP R. Jacobsen, BPXA J. Williams, BPXA ") Orion V-201N-202 Status Report BP Exploration (Alaska) Inc. (BPXA), Operator of the Prudhoe Bay Unit, received approval on May 14, 2003 to continue Tract Operations of the Orion V-201 Well and to conduct Tract Operations for the Orion V-202 Well. This approval required that BPXA provide the DO&G with a status report of the V-201 and V- 202 Tract Operations on or before October 1, 2003. This status report is similar in format to the April 10, 2003 presentation to the DO&G. Exhibit I shows the current mechanical configuration of the V-201 and the V-202. V-201 is a vertical well with multiple fracture stimulations over the entire 0 Sand interval. V-202 was drilled as a single 3000' lateral to test the productivity of the OBd interval. V-201 was put on production on April 10, 2002. A location map and summary of operations for V-201 is shown in Exhibit II. The well had an initial production rate of over 1,000 bId of 21.5 API oil. Operations on V-201 were problematic on gas lift as it experienced hydrate formation as a result of low wellhead temperatures. The well was converted to jet pump lift and has stable production since the conversion. V-201 currently produces over 600 bId and has a cumulative recovery of 208 mbo as of September 1, 2003. V-202 was put on production on July 4, 2003. A location map and summary of operations for V-202 is shown in Exhibit III. The well had an initial production rate of over 7,000 bId of 22.9 API oil from the OBd interval. V-202 was drilled with oil-based mud as a single long horizontal lateral in the OBd. V-202 currently produces under gas lift at a rate of over 1,700 bId and has cumulative recovery of 162 mbo as of September 1, 2003. Plans for V-202 are to drill two additional horizontal laterals in the OA and Oba in before year-end 2003 to further test the impact of oil-based mud and understand the performance of tri-Iateral wells. The historical production performance for the V-201 and the V-202 is shown in Exhibit IV. The historical performance of these wells and the current production rate of over 2,300 bId, demonstrates that the V-201 and the V-202 Wells are capable of sustained commercial production in sufficient quantities to justify development and continued production from the reservoir. ~ ,. Orion ¡ . \'.\ .......A-. \ ~ 'r--_u-t \.' ) 1,.. ~ \ i' '-. Exhibit I: V-201 & V-202 Well bore Schematics ~,b~~~~'7ë'"}3't'tT"";'!'F'c·"· - -~·-·2<~~~:~~~~~~~~;~~(fW~~~0~1~~~~~~~~-."r_._ ~~_ }¡-;1"{\¡L::-;·· k:~ V·201 1'*YTrY:1TØ" 4-f.,U \:10\' l"M0G!f-l t. ~"'t" . ~ t ~t f1r.. :)}.t-IO"J"': t'.r:·Þ G''(¡:;~~ :I. I ò9:4' Hu;:- ':3¡¡:O:~iArr.<¡:¡2~."=>,,;,~'i."'· I l1ur· 'I.-.uu-r.o.lja "l;11J.I, ILn- Œ.-lLa' .. ~ _ a..a" . IV::IP- Yo....."'" . ~k.mf.t¡- 'c.UnT''''!:·- tk'A V -202 8NETYI'fJTæi: IP«::UHATION o 70 ŒG@ 5D75'. 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TAG!; t- 41367' mli2' 5'I~' !ii"1!1 II-t -~ 1~\~,:~~~>;~~~" I Jr I 4T4~' ri4-IQ·III<ft:~G~....U.311'~Ð I IMlnImUmID= 2.150" q:Þ5971' I 4-1tJ.n HES XN nIPPLE W/NO·GQ g 2>---1 U7'1 Hrx -4-1oT CKI'I~f!d 11':1'1. D~ ~J51'~! 4941' H4- \7 HI!;. )!~r.", "-~!iU' I 4!i:i2' t-f+ li7 ~»j 1tP, D· ~1.W I .. I «IQ 2' Hk\'iê ....u:G, p-""V I B:'----i søEIJ' J-iT')t ~ ~"ZXI'L~ 'J:t'~R, V-¡!·3!O' :::: g---f .\1 H ...·;L;~·'''".èH!k~§'''''Ú"''"~»'",,''''> I -----i tœ' tI!·,,,- ,~",:"I>'f.',.;·¡'''' I -----1 ~ tlU~" d>k .;~,>~,,,.~.~<% I 1~'¡r~.I2!(lj,L-M, mS:;¡bp',IJ-.1!Q;" H 4Q01' J---r Jr.",,'!" Jfc1 '.lit .~ t',:'" ,z.,.¡:'.;" H "n' I-----? '----+ '\II' H L Ç.t.ló,; ':-'e ". dl' I 2 , ""~,ZU i,L-<'I[OI:<~r-2~' H 9166' t-----' .~f! ...." '!'",-.¡ -(, '.INfr"-. :1' ¡:'.-;". i·~í1.~~ ~;; ~:.y ,:rr: !.. .:.,~. L: !l:J71' H4-:y·... He;:o;'4 ¡, p. I 1:.!:1Y PKC rJJ:¡~ ~.1~ P.J.:..rx:· I-1W.'DTTfDTL¡:¡¡;;':Z~ . '''' . L l ~ R!f' LO:;'~ I I I I l. l ...... ....... ...............- ...... - ~... 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(.oåahl) Confidential l Orion ¡ ., '~'\-~r-"J '.r·\ f' \" .- .--" =xhi :>it :::: Orion V...202 o Be: S"'o-us _~~~,;~!?)~~~ß1?~~~~~~[?:.:\~~~~~:l~:~·~-:~~;t:~r::t?~:~:~~;~~:r~~~--:~": :.,-::- . -" ~,~:::~~P~~?~'-':~~r~?f~~f~~~gm?"ßà-~'c~~~~~~~~~ V -202 Objectives 5,978,000 · Stand Alone Test of OBd Sand. · Usage of oil-based mud and effects on well productivity · 1 st Orion Horizontal (will be a Tri- Lateral - lats 2&3 to be drilled in Oct.) - ~~ ~'- IP (7/4/03): 7000 BOPD x OO¡oWC x 400 GOR (API = 22.9) Current Production : 1721 BOPD x OO¡oWC x 400-600 GOR (9/1/03) 162 mbo Cumulative Production to 9/1103 Completion: - 7 5/8" longstring wi 4 ~" tubing -3000' 4 ~" slotted liner -Gas Lift Completion -Gas Lift WHT = 59F Confidential --' 5,976,000 5,974,000 5,972,000 '-' 5,970,000 586,000 588,000 594,000 590,000 592,000 Schrader Bluff Top OA Depth Structure Map With Planned V-202 Multi-Lateral Producer 8/3/2003 7/3/2003 o 6/3/2003 o a:: W I I- : _ _ _ _ _ _ ~_ _ _ _ _ _ _ _ _ _,\ _ r _ <C 3000 - - - - -- -- - - -- --- - - -- -- - u_ ---:- ~ - "e ~ ~ ::::=~~~~~~~~~~~~~~~~~~~~~~~~~~~:~;~~~~~~~~~~~~~~~~~~~~~_____~____________________________-500 I I - 3 - 1500 ~ ~ a. 1 _ 1000 _ ~-----------~---------~ I 4000 - - - - - - - - - - - - - - - - - - - - - - - - - - - -1- - - - - - - - 1 ~/ V-202 8000 - - - -'--"." - .----- ------------~------_._M-----------____r- 3500 : . : 7000 - - - - - - - - - - - - - - - - - - - - - - - - - - - -:- fu- - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - ..-;..:::. - - - - - - - - - - - - 3000 I I I I :::: = ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I - ~ _ - - - ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ J ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~- 2500 ~ -" 1400 --------------,-------,---- I I - i - -- 2500 1 I I I I I I I I I I I I I I 1200----------'-K-ï-------------ï-------------ï-------------r-------------ï-------------- -, I I I I I - 2000 I I I I I 1000--------------+-------------~-------------+-------------~-------------+-------------- . I , I I I G) . 1 I I I _ 1500 » 800 - - - - - - - - - - - -. -- 1. - - - - - - - - ,L - - - - - - - - - - - - - f - - - - - - .- -,- - - ~ - - - - - - - - - - - - - f - - - - - - - - - - - - - - ~ 600 - - --- - - - - - .~ -- -! - - --- ~ -- ~ \.~.~.::~=,:;.~.) --- - --.. --- - 4 --- ~ _J - - ~- _ 1000 ~ 1 ; : : Wi -ª 400--------- ,----+-------------~------ ------.-------------~~------------+-------------- I I I I I . I I I - 500 200 ---------r~[-~~--r:-=~- 5l-"~--V~ . t------C---~-A'--------~ o - I I ..., , ,- 0 3/3/2003 4/3/2003 5/3/2003 6/3/2003 7/3/2003 8/3/2003 V -201 ......<_~~,~>:~i'fD';'f;(";':",~~', x""'· --Oil -WATER -- GAS .. TEST Oil .. ··'?."F:'B}'!;W"7f~W~'f%~q;;~~&~~ _ n ....es ts =xhi~i- :V: V-201 & V-202 We . __. - 0- _ _ _ _ _ __ Confidential S' - t/) ::ë .a - :t;' (ñ :is :e. ~ w ~ ~ õ ! ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 08/04/03, Put on Production 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4820' NSL, 1848' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 1206' NSL, 2391' WEL, SEC. 02, T11N, R11E, UM X = 589888, Y = 5971725 10. Well Number At total depth 4971' NSL, 1380' WEL, SEC. 02, T11 N, R11 E, UM X = 590850, Y = 5975502 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Orion (Undefined) KBE = 82.3' ADL 028240 ,12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/4/2003 5/16/2003 5/19/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8985 4663 FT 8985 4663 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, PWD, AIM, DPC MDT CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 1081 481' 28' 2843' 13-1/2" 261 5966' 9-7/8" 5869' 8980' 6-3/4" Classification of Service Well 7. Permit Number 203-077 8. API Number 50- 029-23153-00 9. Unit or Lease Name X = 590453, Y = 5970066 Prudhoe Bay Unit V-202 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2237' MD 1900' (Approx.) 23. CASING SIZE 20" X 34" 10-3/4" 7-5/8" 4-1/2" WT. PER FT. 215.5# 45.5# 29.7# 12.6# GRADE A53 L-80 L-80 L-80 CEMENTING RECORD 260 sx Arctic Set (Approx.) 590 sx PF 'L., 352 sx Class 'G' 436 sx Class 'G' Uncemented Slotted Liner AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 4902' PACKER SET (MD) 4773' 25. MD TVD 6021' - 8941' 4625' - 4661' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10-3/4" X 7-5/8" Annulus Freeze Protected with 90 Bbls Dead Crude 2250' 4-1/2" x 7-5/8" Annulus Freeze Protected with 90 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 4, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl 8/1/2003 4 TEST PERIOD 1,980 2,333 -0- Flow Tubing Casing Pressure CALCULATED Oll-BBL GAs-McF WATER-BBL Press. 324 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. CHOKE SIZE 176 Oil GRAVITY-API (CORR) GAS-Oil RATIO 1,178 No core samples were taken. r- '} ~R.o.~1~ : ,:\~~-=)r: ~';~\I'};:,., I ~,p ç. If:\:. ' : \ 1,'1 -'~ 1"'" , Form 10-407 Rev. 07-01-80 OK\G\NAL \,f Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 3085' 2945' MDT was ran, log will be supplied to AOGCC upon receipt from vendor, for detail. (Per Greg Bernaski) Ugnu M 4288' 3973 Schrader Bluff N 4643' 4215' Schrader Bluff OA 4960' 4378' Schrader Bluff OB 5155' 4447' OBa 5155' 4447' OBb 5287' 4487' OBc 5467' 4539' OBd 5807' 4595' r II' . I 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 renieHubble ~. ~ Trtle Technical Assistant Date Og-Otf-03 V-202 203-077 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Michael Triolo, 564-5774 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 prtinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, 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. l-;OEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 OR\G\Nt\L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well iii Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4820' NSL, 1848' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 1206' NSL, 2391' WEL, SEC. 02, T11 N, R11 E, UM X = 589888, Y = 5971725 10. Well Number At total depth 49711 NSL, 13801 WEL, SEC. 02, T11 N, R11 E, UM X = 590850, Y = 5975502 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Orion (Undefined) KBE = 82.3' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/4/2003 5/16/2003 5/19/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8985 4663 FT 8985 4663 FT iii Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, PWD, AIM, DPC MDT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" x 34" 215.5# A53 Surface 1081 48" 10-3/4" 45.5# L-80 281 2843' 13-1/2" 7-518" 29.7# L-80 261 5966' 9-7/8" 4-1/2" 12.6# L-80 58691 8980' 6-3/4" Classification of Service Well 7. Permit Number 203-077 8. API Number 50- 029-23153-00 9. Unit or Lease Name X = 590453, Y = 5970066 Prudhoe Bay Unit V-202 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2237' MD 19001 (Approx.) CEMENTING RECORD ~60 sx Arctic Set (Approx.) 590 sx PF 'LI, 352 sx Class IG' 436 sx Class 'G' Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section 25. SIZE 4-1/2", 12.6#, L-80 TUSING RECORD DEPTH SET (MD) 49021 PACKER SET (MD) 47731 MD TVD 6021' - 8941' 4625' - 4661' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10-3/4" x 7-518" Annulus Freeze Protected with 90 Bbls Dead Crude 2250' 4-1/2" x 7-5/8" Annulus Freeze Protected with 90 Bbls Diesel 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BSl TEST PERIOD GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-Bsl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, ~oroS.ity,f~ctUres, apparent dips and presence of oil, gas or water. SUbmit" ~I\S E ! ' ,. No core samples were taken. i .4;ik ;",~§~,' 28. \/' f~" ,;~~) fII)MS 8Fl 19r~ JUN 2. S 2!J03 Jut 21 1003, ' ". {ld2SlC3 U¡j Gi, c '~~ n :..~ ~ C s ~: ~'d f\nch 'Ora ~\8 Form 10-407 Rev. 07-01-80 OR1G\NA- Submit In Duplicate ) ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. . Ugnu 3085' 2945' MDT was ran, log will be supplied to AOGCC upon receipt from vendor, for detail. (Per Greg Bernaski) Ugnu M 4288' 3973 Schrader Bluff N 4643' 4215' Schrader Bluff OA 4960' 4378' Schrader Bluff OB 5155' 4447' OBa 5155' 4447' OBb 5287' 4487' OBc 5467' 4539' OBd 5807' 4595' JUN ,2 ;5 7003 31. List of Attachments: Summary of Daily Drilling Reports, SUlveys 32. I ~erebY certify that the for~oin: is true and correct to the best of my knowledge Signed Terrie Hubble rfQJvv 1( _ ~ Title Technical Assistant Date Olp"';¡S ~Q ~ V-202 203-077 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Michael Tri%, 564-5774 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 ettachments. ITEM 16 AND 24: Ifthis 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.), lìEM 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 OR\G\NAL Legal Name: V-202 Common Name: V-202 Test Date 5/8/2003 5/14/2003 LOT FIT Test Type Test Depth (TMD) 2,843.0 (ft) 5,975.0 (ft) BP Leak-Off TestSÜmmary Test Depth (TV D) 2,733.0 (ft) 4,620.0 (ft) AMW 9.20 (ppg) 9.20 (ppg) Surface Pressure 450 (psi) 550 (psi) Leak Off Pressure (BHP) 1,756 (psi) 2,758 (psi) EMW 12.37 (ppg) 11.49 (ppg) ---' ~ Printed: 5/27/2003 10:22:08 AM ) ) BP Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/3/2003 12:00 - 15:00 3.00 RIGU P PRE Unpin Blocks. Bridle up. Prepare rig for derrick down, Move Camp and Mudpits to V-202 and spot camp. 15:00 - 16:00 1.00 RIGU P PRE Move rig off W-23 and position to lay derrick down into wind. Lay down derrick and prepare for road trip to V-202. 16:00 - 20:00 4.00 RIGU P PRE Move rig from W-23 to V-202. 20:00 - 22:30 2.50 RIGU P PRE Layout herculite. Position mats. Raise derrick and pin chute. 22:30 - 00:00 1.50 RIGU P PRE Spot and level pits. Plug in shop, camp and pits. Begin rigging up for drilling operations on V-202. 5/4/2003 00:00 - 06:30 6.50 RIGU P PRE Nipple up 20" diverter system and flowline. Take on fresh water to mix spud mud. Load 4" DP in shed. Bring BHA to floor. Accept rig @ 00:01 hrs. 06:30 - 10:00 3.50 RIGU P PRE P/U 4" DP 1 x1 and rack back in derrick. Mix spud mud and prepare pits for drill out. 10:00 - 10:30 0,50 BOPSUR P PRE Function test 20" hydril and knife valve. Perform accumulator test. John Crisp with AOGCC waived witness of Diverter test. 10:30 - 12:30 2.00 DRILL P SURF Slip and cut 98' of drilling line. Check and adjust brakes. Clean and service drawworks. Service topdrive. Adjust and service Crown-a-matic. 12:30 - 13:30 1.00 DRILL P SURF Pick up and clean all work areas in preparation for spudding. 13:30 - 14:00 0.50 DRILL P SURF Fill hole with mud and integrity test surface lines and equipment. 14:00 - 14:30 0.50 DRILL P SURF Pre-spud meeting with drilling crew and support group. 14:30 - 16:00 1.50 DRILL P SURF P/U, orient and shallow test 13 1/2 Hughes bit, 1.83 degree motor, Mwd and UBHO sub. 16:00 - 17:00 1.00 DRILL P SURF P/U Schlumberger E-line sheaves and hang in derrick. R/U Gyro Data equipment. 17:00 - 21 :30 4.50 DRILL P SURF Spud well and drill from 108 to 361. 21 :30 - 22:30 1.00 DRILL P SURF RIH with Gyro Data. Toolface data from Gyro showing 180 off MWD tool. POH and check tattletale pin on end of Gyro. No indication of good seat into UBHO sub. Re-run at quicker TIH speeds-- still not giving good toolfaces. POH and change tattletale on bottom of Gyro tool to a hollow slimmer design. Re-run Gyro. Toolfaces coming up consistant with MWD, POH--Good survey and tattletale indicating good seat in UBHO sub. 22:30 - 00:00 1.50 DRILL P SURF Drill ahead in 13 1/2 surface hole from 361 to 455. Pea gravel and sand coming over shakers. Drilling with following: WOB==10-20 RPM==60 GPM==650@1,100 TRQ==500 / 3,000 ART==1.96 AST==.34 5/5/2003 00:00 - 10:30 10.50 DRILL P SURF Drill 13 1/2 surface hole from 455 to 1,568. Run Gyro survey as needed. Drilling parameters: WOB==35K RPM==60 GPM==650 @ 1850/2060 TRQ==2K off and 5.5K on bottom UP==80K DWN==72K ROT==76K 10:30 - 11 :30 1.00 DRILL P SURF Circulate 2 times bottoms up while rotating and reciprocating string at 60 RPM and pumping 650 GPM. 11 :30 - 12:00 0.50 DRILL P SURF E-line survey with Gyro/data. 12:00 - 13:30 1.50 DRILL P SURF POH to BHA with intermittent 5-10K drag, 13:30 - 14:30 1.00 DRILL P SURF Break and grade bit. Clear floor of all excess vendors equipment. 14:30 - 15:00 0.50 DRILL P SURF Sevrice Topdrive. 15:00 - 16:00 1.00 DRILL P SURF Make up new MXC-1 Hughes bit and shallow test BHA. Printed: 5/27/2003 10:22:19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) BP Operations Summary Report V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Page 2 of 9 Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 5/512003 16:00 - 17:30 1.50 DRILL P SURF 17:30 - 19:00 1.50 DRILL P SURF 19:00 - 20:00 1.00 DRILL P SURF 20:00 - 00:00 4.00 DRILL P SURF 5/6/2003 From - To Hours Task Code NPT Phase 00:00 - 01 :00 01 :00 - 04:00 1.00 DRILL P SURF 3.00 DRILL P SURF 04:00 - 05:00 1.00 DRILL P SURF 05:00 - 08:00 3,00 DRILL P SURF 08:00 - 10:30 2.50 DRILL P SURF 10:30 - 12:30 2.00 CASE P SURF 12:30 - 16:30 4.00 CASE P SURF 16:30 - 17:00 17:00 - 20:00 20:00 - 21 :00 21 :00 - 00:00 0.50 CASE P 3.00 CASE P SURF SURF 1.00 CASE P SURF 3,00 CEMT P SURF Description of Operations Continue RIH. Fill pipe. Precautionary wash to bottom. Continue drlg fl 1568' to 2125'. Surveys still spotty. Continue wI Gyro. On last Gyro, hung up @ 2010'. Worked loose & POH taking surveys. RD SWS. IFR corrected surveys looked good. Continue drlg fl 2125' to TD @ 2854'. PUW: 1051; SOW: 80k; RTW: 91 k; 650 GPM. 2600 psi off; 3000 psi on; Tq off: 2.5k; Tq on: 7-9k. 1.72 hrs sliding; 2.34 hrs rotating Circulate hole clean while rotating and reciprocating string at 60 RPM and pumping 650 GPM. Up==105 DWN==80 ROT==91 TRQ==2,500 off 3,000 on Short trip back to 700 ft.. Pull slowly to prevent swabbing in well. Worked small areas with 10 to 30K overpulls, from 2,030 to 1,940 and again at 1,190 to 1,100. RIH seeing intermittent down drag from 1,500 to bottom. Wash last 100 ft. to bottom. No fill. Circulate and condition mud for running casing. Add water for vis. and wt. control. Rotate and reciprocate sting at 60 RPM and 550-650 GPM. POH to run casing. Wipe minor overpulls from 1900 to 1840 and 1,260 to 1,200. Hole in good shape, POH standing back jars and collar. Break and grade bit and lay down all remainging BHA and clear floor of all excess vendors equipment. Change out bails, RIU Franks tool. Make dummy run with landing joint and hanger. Bakerlok shoe track and check floats. RIH with casing with no adverse hole conditions or fill, Average M/U torque @ 6,200. Run a total of 67 jts. 10 3/4 45.5 # L-80, float equipment, 2 pup jts. and hanger. Lay down "Franks" circulating tool and P/U cement head. Break circulation and stage pumps up to 10 BPM @ 563 PSI. Circulate and conditon mud to drop Vis. to 50 and YP to 10 for cement job. Hold PJSM with Halliburton and rig crew. Reciprocate throughout circulation. Wait for second hot water truck to arrive from hot water plant. Delay due to backup of trucks waiting to load. Continue to circulate at reduced rate while waiting. Prime up and pump cement as follows: Pump 5 bbls. pre-flush and pressure test lines to 3,500. Pump remaining 5 bbls, pre-flush, 75 bbls. weighted Alpha Spacer (10.2), and drop bottom plug. Pump 436 bbls, 10.7 Lead, 72 bbls. 15.8 tail and kick out top plug with 10 bbls water. Displace with rig pumps at 8 BPM, Reciprocate string until 356 bbls. cement had gone outside.( Down wt.progressively dropped from 120 to 60K). Land with 152 bbls. to bump. Pumped final 100 bbls. at 5.5 BPM due to flowline 1 shaker restrictions. Bump plug to 1 ,500 PSI with 96% eff, Hold pressure for 5 minutes and bleed and check floats. App. 80 bbls. good cement at surface with another 70 bbls, contaminated. CIP @ 24:00 HRS. Printed: 512712003 10:22:19 AM ) ) BP Operations Summary Report Page 3 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date From -To Hours Task Code NPT Phase Description of Operations 5/7/2003 00:00 - 05:00 5.00 BOPSURP SURF Hold bump pressure on plug for 5 minutes. Bleed pressure to zero and confirm floats are holding. Flush drilling nipple and open 4" valves at base of diverter system. Wash cement returns from drilling nipple flowline and shakers. Layout landing joint. R/D & LID casing equipment. N/D 20" diverter. Move wellhead equipment into cellar area. 05:00 - 09:00 4.00 BOPSUR P SURF Nipple up 11" x 5,000 PSI wellhead spool and SSH. Test metal to metal seal to 1000 for 10 minutes. Install test plug and prepare to test BOP equipment with AOGCC Representative. 09:00 - 10:30 1.50 BOPSUR N MISC SURF Small fire broke out in interconnect. Crew members responded with extinguishers and fire fighting equipment and extinguished blaze. Monitor firesite and evaluate/ repair fire damage as needed. Minimal damage to equipment. Ugh bulb rated higher than output capacity of fixture had been installed, Resulted in melting of plastic cover, which caused a small fire. Emergency response team discussed incident and secured AFE number. 10:30 - 14:30 4.00 BOPSUR P INT1 Test BOP as per policy with AOGCC as a witness, 14:30 - 21 :30 7,00 DRILL P INT1 RIH and rack back 4" DP in derrick. Move HWDP to other side of derrick. 21 :30 - 00:00 2.50 DRILL P INT1 P/U 1.5 degree motor and Smith S-73 bit. Build BHA. P/U and install Nuke source. Shallow test BHA. 5/8/2003 00:00 - 00:30 0.50 DRILL P INT1 Complete shallow test of MWD and P/U "Ghost Reamer". 00:30 - 02:30 2.00 DRILL P INT1 RIH to 2,700. 02:30 - 03:30 1.00 EVAL P INT1 Break circulation and circulate out air. Test 10 3/4" casing to 3,500 for 30 minutes. No pressure loss. 03:30 - 04:00 0.50 DRILL P INT1 Service Topdrive. 04:00 - 06:00 2,00 DRILL P INT1 Drill plugs at 2755 and remaining shoe track. Drill 20' of new hole from 2854 to to 2,874. Drilling with 550 GPM @ 1,900 PSI, 50 RPM and 4-6,500 torque on bottom. 06:00 - 06:30 0.50 DRILL P INT1 Swap mud system over to 9.2 ppg reconditioned LSND mud @ 10 BPM @ 680 PSI. 06:30 - 07:00 0.50 DRILL P INT1 Pull up inside shoe and perform LOT: 450 psi over 9.2 ppg mud for 12.37 ppg EMW. 07:00 - 10:00 3.00 DRILL P INT1 Get benchmark ECD and SPR. Drill 9 7/8 intermediate hole from 2,874 to 3,192. Backreaming each connection and pumping 25 bbl. Hi-Vis sweeps every 300 ft. or as hole dictates. Keeping ECD ceiling @ <.7ppg over calculated. Drilling with following parameters: Up==117 Dwn==86 Rot==99 GPM==650 @ 1,580 off and 1,800 on TQ==5-7,000 ART==1.91 AST==.24 10:00 - 11 :30 1.50 DRILL N RREP INT1 Snail on charge pump # 1 washed out. Permit area for Hot work and patch weld washed area of snail. 11 :30 - 00:00 12,50 DRILL P INT1 Drill 9 7/8 intermediate hole from 3,192 to 4,687, Up==117 Dwn==86 RT==99 GPM==650 @ 1580 RPM==80 TQ==7k on and 4k off Drilling hrs. last 24 hours==AST 2.54 ART 5.38 ADT 7.92 5/9/2003 00:00 - 15:00 15.00 DRILL P INT1 Drill 9 7/8 intermediate hole from 4,687 to 5,975. Pump 25 bbl. Hi-vis sweeps every 300 ft. Keep ECD's < .7 over calculated. Backream each stand and circulate as needed to remain under ECD ceiling. WOB==5-15 RPM==80 GPM==650 @ 2,800 TQ==7,OOO off 9,000 on Up==140K DW==85K RT==104K Printed: 5/27/2003 10:22:19 AM ) ) BP Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date From- To Hours Task Code NPT Phase Descri ption of Operations 5/9/2003 00:00 - 15:00 15.00 DRILL P INT1 ART==2,62 AST==7,15 ADT==9.77 15:00 - 16:00 1.00 DRILL P INT1 MAD pass from 5,889 to 5,975. 16:00 - 17:30 1.50 DRILL P INT1 Circulate sweep S-S @ 650 GPM @ 2,850 PSI while rotating string at 110 RPM. 17:30 - 21 :00 3.50 DRILL P INT1 Pull 10 stands. Pump dry job. POH with 5-15 intermittent drag. Hole in good shape. No backreaming or working required. Monitor well at shoe. RIH with no adverse hole conditons or fill. 21 :00 - 23:00 2.00 DRILL P INT1 Pump 25 bbl. Hi-vis sweep S-S while pumping at 650 GPM while rotating string at 110 RPM's. Lots of wall cake and cuttings seen at bottoms up. Shakers cleaned up good. Shut down and observe well. Gas breaking out of mud. Circulate bottoms up. Observe well. Static. Calculated ECD==9.9 Actual ECD==10.17. 23:00 - 00:00 1.00 DRILL P INT1 Pull 5 stands. Pump dry job. POH to run Drillpipe conveyed MDT. 5/10/2003 00:00 - 01 :30 1.50 DRILL P INT1 POH to run drillpipe conveyed MDT. Hole in good shape. 01 :30 - 04:00 2.50 DRILL P INT1 Lay down BHA. Remove nuke source. Break and grade bit. Clear floor of all vendors excess equipment. Bit Grade: 3 8 BT S X 1 CT TD 04:00 - 05:00 1.00 EVAL P INT1 PJSM with Schlumberger on drillpipe conveyed logging, P/U and R/U Schlumberger equipment for TLC logging. 05:00 - 06:30 1.50 EVAL N DPRB INT1 Open blinds and observe gas breaking out in bell nipple. As gas bubbled and broke out the fluid level dropped slightly. Shut well in to check for pressure build up. Pressure up to 4.5 pounds after 30 minutes. Down to 2 pounds after 1 hour. 06:30 - 08:00 1.50 DRILL N DPRB INT1 Build clean out assembly with "Dull" tri-cone bit and RIH to casing shoe. 08:00 - 09:00 1.00 DRILL N DPRB INT1 Circulate out gas at 6 BPM @ 250 PSI. Circulate until gas has cleared backside. (One bottoms up) Monitor well. 09:00 - 09:30 0.50 DRILL N DPRB INT1 Stage into hole to 3,800. No adverse hole conditions. 09:30 - 10:00 0.50 DRILL N DPRB INT1 CBU at 440 GPM @ 940 PSI. Gas breaking out in bell nipple. No pit gain. Monitor well. 10:00 - 11 :00 1.00 DRILL N DPRB INT1 RIH to 5975. 11 :00 - 12:30 1.50 DRILL N DPRB INT1 Circulate hole at 450 GPM 1400 PSI. Small amounts of gas breaking out during initial circulation. No gas on second round. 12:30 -13:00 0.50 DRILL N DPRB INT1 Observe well. (Static with no flow) Drop rabbit. Pump dry job. 13:00 - 17:30 4.50 DRILL N DPRB INT1 POH with hole taking proper fill. Observe well at casing shoe. Small hydrate bubbles breaking out of mud with no flow, Continue to TOH. Stand back clean out assembly and lay down all excess vendors equipment. 17:30 - 19:30 2,00 EVAL P INT1 PJSM, P/U and RIU Schlumberger MDT tool string, Plug into MDT and confirm communication between tool and logging unit. 19:30 - 21 :00 1.50 EVAL P INT1 RIH with MDT on drillpipe to 2843. ( 1.5 minutes per stand) 21 :00 - 21 :30 0.50 EVAL P INT1 Break circulation and pump 1.5 times DP volume. Hang sheave from derrick. Up wt.== 85K Dwn wt.==70K. 21 :30 - 22:30 1.00 EVAL P INT1 RIH to 4,000 with no adverse hole conditons. 22:30 - 00:00 1.50 EVAL P INT1 P/U side door entry sub. Latch up wet connect. 5/11/2003 00:00 - 00:30 0.50 EVAL P INT1 Confirm contact between wet connect and MDT tools. 00:30 - 13:00 12.50 EVAL P INT1 RIH from 4,000 and begin taking pressure readings at 4,353. Record pressures as follow: Printed: 5/27/2003 10:22:19 AM ) ) Legal Well Name: V-202 Common Well Name: V-202 Spud Date: 5/4/2003 Event Name: DRILL +COMPLETE Start: 5/4/2003 End: 5/19/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/19/2003 Rig Name: NABORS 9ES Rig Number: HoUrs Task Code NPT Phase 5/11/2003 00:30 - 13:00 12.50 EVAL P INT1 MD Depth TVD Formation pressure 4353 4021 1789 4390 4047 1796 4443 4084 1817 4478 4108 1825 4579 4175 1848 4774 4289 1955 4975 4384 1812 5005 4396 1820 5049 4412 1955 5175 4453 1901 5231 4470 1914 5298 4490 1934 5330 4499 1935 5509 4549 1919 5817 4596 1951 5905 4608 1956 13:00 -15:30 2.50 EVAL P INT1 Take sample # 1 @ 5,905. Up wt. 130K Dwn. wt. 88K. 15:30 - 16:30 1.00 EVAL P INT1 POH to 4975 and positon for sample #2. Up wt. 135K Dwn. wt. 90K. 16:30 - 20:30 4.00 EVAL P INT1 Collect sample #2 @ 4975. 20:30 - 22:30 2.00 EVAL P INT1 RIH to 5175 and collect sample # 3. Down wt. 85K 22:30 - 00:00 1.50 EVAL P INT1 RIH to 5298 and collect sample # 4. Down wt. 88K 5/12/2003 00:00 - 01 :30 1.50 EVAL P INT1 Collect sample # 4 @ 5298. Logging tool failed while collecting sample # 4. Pump that collects sample failed completely. It was showing signs of failure while collecting sample # 3. Anchorage Geologist group contacted. Abort and POH for wiper trip. Will not run back in for additional samples. 01 :30 - 03:30 2.00 EVAL P INT1 POH slowly to side entry sub. (Slight tool drag when initially pulling out, dropped down hole to break wall contact.) POH with no adverse hole conditions. 03:30 - 05:00 1.50 EVAL P INT1 Spool up Schlumberger line and layout side entry sub. RID sheave from derrick and layout all excess vendors equipment. 05:00 - 08:00 3.00 EVAL P INT1 POH with MDT logging tools @ 60 ft. per minute. Hole taking proper amount of fill. 08:00 - 10:00 2.00 EVAL P INT1 Layout MDT logging tools. 10:00 -12:00 2.00 DRILL P INT1 P/U "Dull" MXC-1 97/8 tri-cone, NB stab, 1 ea. 5" HWDP, Jars, 1 ea. 5" HWDP, XO, 21 ea. 4" HWDP. RIH to casing shoe @ 2843. 12:00 - 13:00 1.00 DRILL P INT1 Circulate bottoms up, while observing gas cut mud, Monitor static well. Up wt.==90 Dwn wt.==75 13:00 - 14:00 1.00 DRILL P INT1 Service top drive and cut drilling line. 14:00 - 16:00 2.00 DRILL P INT1 RIH breaking circ. every 10 stands and pump 80 bbls. No losses. 16:00 - 18:00 2.00 DRILL P INT1 Tag bottom at 5975 and stage pumps up to 500 GPM with no losses. Blend in 300 bbls, of new 9.3 mud with watered/centrifuged back surface mud. Displace well Dumping app. 300 bbls. of 9.8 to 10 ppg. mud. Pump 500 GPM 1640 PSI while rotating and reciprocating string at 80 RPM. Water and centrifuge back surface system to 9.3 ppg. 18:00 - 18:30 0.50 DRILL P INT1 Observe well for 30 minutes. Gas breaking out of bell nipple. Printed: 5/27/2003 10:22: 19 AM ) ) BP Operations Summary Report Page 6 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2003 18:00 - 18:30 0.50 DRILL P INT1 No flow. Level dropped down bell nipple. 18:30 - 22:00 3.50 DRILL P INT1 Pull 5 stands with hole taking proper fill. Pump dry job. Continue TOH with hole taking proper fill. Wiped small section pulling 20K over at 4560. Did not see on second pass. Observe well at shoe. No gas. 22:00 - 22:30 0.50 DRILL P INT1 Break and layout clean out assembly. 22:30 - 23:30 1.00 BOPSURP INT1 Flush stack and wear ring area. Pull wear ring and install test plug, 23:30 - 00:00 0.50 BOPSURP INT1 Change top rams to 7 5/8. 5/13/2003 00:00 - 00:30 0.50 BOPSURP INT1 Change top rams to 7 5/8 and test door seals, R/U to run casing, RIH with 7 5/8 intermediate casing as per running tally. 00:30 - 02:00 1.50 CASE P INT1 R/U to run 7 5/8 intermediate long string. PJSM 02:00 - 06:30 4.50 CASE P INT1 Make up and Bakerlok shoe track and check floats. RIH to shoe at 2843' with 7 5/8 29.7 # L-80 BTC-Mod casing, spacing out RA tags and long joints as per program. Fill each joint and break circulation every 20 joints. 06:30 - 07:30 1.00 CASE P INT1 Stage pumps to 7 bpm and 350 psi, circulate 1.5 times csg volume at the shoe, no losses while circulating. 120 klbs up 100 klbs down. 07:30 - 14:15 6.75 CASE P INT1 Continue RIH with 7-5/8" csg. fill each joint, break circ every 5 joints, circ 15 minutes every 15 joints and CBU every 30 joints. 14:15 - 14:45 0.50 CASE P INT1 Land casing. RD fill up tool and RU cement head. 14:45 - 16:00 1.25 CASE P INT1 Break circulation at 4 bpm, 175 psi. circulate 1.5 times bottoms up. 16:00 - 16:15 0.25 CEMT P INT1 Switch to HOWCO. Pump 5 bbl water and test lines to 3500 psi. Pump 25 bbl1 0.2 ppg alpha spacer at 6 bpm, 250 psi. 16:15 - 16:45 0,50 CEMT P INT1 Release bottom plug. Mix and pump 121 bbls (561 sxs) of 15,6 ppg premium class G cement at 5 bpm, 250 psi 16:45 - 17:00 0.25 CEMT P INT1 Release top plug and kick out with 10 bbls of water to clear lines. 17:00 - 17:30 0.50 CEMT P INT1 Switch to rig pumps and displace with 260 bbls of seawater. Reciprocate pipe throughout pumping cement and 220 bbls of displacement. Bump plug on calculated strokes, Pressure up to 1500 psi. Bleed off pressure and check floats - OK. CIP @ 17:30 hrs. 17:30 - 18:30 1.00 CEMT P INT1 RD Cmt head, landing joint and csg equipment. 18:30 - 19:00 0.50 WHSUR P PROD1 Install packoff and test to 5000 psi - OK 19:00 - 21 :00 2.00 CASE P PROD1 Clean under rotary table, right angle drive and pipe racks 21 :00 - 22:30 1.50 BOPSUR P PROD1 Flush BOP stack. Circulate seawater through kill line, choke line and choke manifold. MU test joint 22:30 - 23:30 1.00 BOPSURP PROD1 Change top rams from 7-5/8" to 3-1/2" X 6" variables 23:30 - 00:00 0.50 BOPSUR P PROD1 Fill BOP stack with water. RU BOPE test equipment, 5/14/2003 00:00 - 03:30 3,50 BOPSUR P PROD1 Test BOPE to 250 psi low and 3500 psi high. Witness of BOP test waived by Jeff Jones, AOGCC. 03:30 - 04:00 0.50 BOPSUR P PROD1 RD BOP test equipment. Install wear bushing 04:00 - 04:30 0.50 DRILL P PROD1 Service top drive. 04:30 - 06:00 1.50 DRILL P PROD1 Clean mud pits. Berm and Spot SWACO vacuum unit. 06:00 - 08:00 2.00 DRILL P PROD1 Inject 60 bbls 9.2 ppg mud down 7-5/8" X 10-3/4" annulus. 4 bpm, 810 psi FCP. Annulus shut in with 600 psi 08:00 - 10:30 2.50 DRILL P PROD1 MU BHA #5, shallow test MWD - OK 10:30 - 14:00 3.50 DRILL P PROD1 RIH with DP, tag cement @ 5779' 14:00 - 14:30 0.50 CASE P PROD1 Test 7-5/8" csg to 3500 psi. Kelly hose developed a leak and the test was aborted. Printed: 5/27/2003 10:22:19 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date FrOni-To HÖUrs Task Code··. NPT Phase Descriptionöf Operations 5/14/2003 14:30 - 14:45 0.25 CASE N SFAL PROD1 PJSM with NAD personnel on repairing leaking kelly hose 14:45 - 16:00 1.25 CASE N SFAL PROD1 Rig repair. Break top union on kelly hose and replace rubber gasket. MU and test hose. 16:00 - 17:00 1.00 CASE P PROD1 Test 7-5/8" csg to 3500 psi for 30 minutes 17:00 - 19:30 2.50 DRILL P PROD1 Displace well with 9.2 ppg MOBM. Pump; 20 bbl base oil through pumps to flush lines, a 30 bbl viscosified spacer followed by 240 bbls 9.2 ppg MOBM. 19:30 - 20:00 0.50 DRILL P PROD1 Establish baseline ECD of 10.05 ppg. Take slow pump rates 20:00 - 22:30 2.50 DRILL P PROD1 Drill cement and float equipment from 5779' to 5975'. Drill 20' of new hole for FIT. 22:30 - 23:30 1.00 DRILL P PROD1 CBU X 2 to condition mud for FIT 23:30 - 00:00 0.50 DRILL P PROD1 Perform FIT to 11.5 ppg EMW. A casing shoe TVD of 4620' with 9.2 ppg mud in the hole = 550 psi surface pressure 5/15/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 5995' to 800T. Geosteering to maintain Schader OBd sand interval. Backream each stand. 126 klbs up, 84 klbs down, 104 klbs rotate. 112 SPM, 275 gpm, 2650 psi. Calculated ECD 10.5 ppg, maintaining actual ECD's below 11,0 ppg. ART last 24 hrs. = 4.52 hrs. AST last 24 hrs. = 6.38 hrs. Total Drilling Time = 11.05 hrs 5/16/2003 00:00 - 12:30 12.50 DRILL P PROD1 Directional Drill from 800T to 8846'. Geosteering to maintain Schrader OBd sand interval. Backream each stand. Between 8007' and 8474' the formation dip was less than anticipated causing the wellbore to drop below the lower OBd interval. The wellsite geologist conferred with Anchorage geology staff, corrections were made and the wellbore was brought back into the OBd sand interval. From 8474' to 8846' the dip angle in the formation increased, the wellbore inclination was dropped to maintain the OBd sand interval. 135 klbs up, 72 klbs down, 104 klbs rotate. 275 gpm @ 2690 psi. 12:30 - 14:00 1.50 DRILL P PROD1 Circulate and condition mud to reduce ECD. Calculated ECD = 10.74 ppg, actual ECD's = 11.2 ppg, circulate to bring ECD < 0.5 ppg over calculated. ECD after circulating 11.03 ppg. 14:00 - 14:30 0.50 DRILL P PROD1 Directional drill from 8846' to 8985' (TD) at reduced pump rate to lower ECD, 245 gpm @ 2370 psi. Backream each stand. Held inclination constant with increasing formation dip so the wellbore exited the top of the lower OBd sand at TD. 14:30 - 16:00 1.50 DRILL P PROD1 Circulate bottoms up while reciprocating DP. 245 gpm on the up stroke, reduce rate to 175 gpm on down stroke. Calculated ECD = 10.74 ppg, ECD after circulating 11.00 ppg. 16:00 - 16:15 0.25 DRILL P PROD1 Monitor well - static 16:15 - 18:00 1.75 DRILL P PROD1 Short trip to 7-5/8" csg shoe @ 5966'. 145 klbs up, 75 klbs down. Pulled 25k over intermittently throughout trip, worked through tight spots no problem. 18:00 - 18:30 0.50 DRILL P PROD1 Service top drive and crown. 18:30 - 21 :00 2.50 DRILL P PROD1 RIH to 6470'. Make MAD pass on the way in from 6470' to 6530'. Continue RIH to 8985'. Taking 25k down weight intermittently from 7130' to 8500'. 21 :00 - 22:30 1.50 DRILL P PROD1 CBU X 2. First BU @ 200 gpm, 1830 psi, calculated ECD = 10.74 ppg. actual ECD = 11.33 ppg. Increased rate on second BU to 275 gpm, 2700 psi. Actual ECD on second BU 10.9 ppg. Printed: 5/27/2003 10:22:19 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 5/16/2003 22:30 - 22:45 0.25 DRILL P PROD1 Monitor well - static. 22:45 - 00:00 1.25 DRILL P PROD1 POH to open circ sub at csg shoe. 140 klbs up, 75 klbs down. 5/17/2003 00:00 - 01 :30 1.50 DRILL P PROD1 POH to csg shoe @ 5966'. No tight spots noted on TOH 01 :30 - 02:00 0.50 DRILL P PROD1 Drop ball and rod to open circ sub. Pump out 2 stands to bring bit into csg. 115 klbs up, 95 klbs down, 105 klbs rotate. 02:00 - 03:00 1.00 DRILL P PROD1 Circulate 40 bbl Hi-vis sweep at 465 gpm and 2480 psi. Continue circulating until clean returns. 03:00 - 06:00 3.00 DRILL P PROD1 Pump dry job and drop Mud Dog. Continue POH standing back DP. 06:00 - 06:15 0.25 DRILL P PROD1 PJSM with SWS and rig personnel regarding unloading of radioactive sources and laying down BHA 06:15 - 08:30 2.25 DRILL P PROD1 LD BHA #5 08:30 - 09:30 1.00 DRILL P PROD1 Clean and clear rig floor. 09:30 - 10:30 1.00 CASE P COMP RU to run 4-1/2" slotted liner 10:30 - 10:45 0.25 CASE P COMP PJSM with BOT and rig personnel on running slotted liner. 10:45 - 13:30 2.75 CASE P COMP PU and MU 4-1/2" 12.6# slotted liner assembly 13:30 - 14:00 0.50 CASE P COMP PU and MU Baker HMC Hydraulic liner hanger on 1 stand of DP and circ through. 70 klbs up, 60 klbs down 14:00 - 16:00 2.00 CASE P COMP Run liner on DP to 7-5/8" csg shoe @ 5966. 105 klbs up, 85 klbs down 16:00 - 16:30 0.50 CASE P COMP Circulate 1-1/2 bottoms up. stage pumps up to 5 bpm @ 715 psi. 16:30 - 19:30 3.00 CASE P COMP Continue running liner on DP. Reduce running speed to 1.5 minutes per stand. MU top drive to each stand to prevent mud from running over the top. Tag bottom at 8985' 19:30 - 20:30 1.00 CASE P COMP PU to 8980' to position liner hanger just above float collar in 7-5/8" csg. Drop ball and pump onto seat, pressure up to 1700 psi to set liner hanger. Rotate DP 15 turns to position dogs, PU 6' to release dogs and slack off 60 klbs to set ZXP packer. Liner top at 5861'. 125 klbs up, 80 klbs down. 20:30 - 22:00 1.50 CASE P COMP Dispace well to 9.2 ppg brine. Pump 20 bbl LVT-200 bas oil, 20 bbl 9.2 ppg viscosified brine sweep, 50 bbls safe-surf, another 25 bbl 9.2 ppg viscosified brine sweep at 4 bpm @ 300 psi. Followed by 236 bbls 9.2 brine pumped at 8 bpm @ 1000 psi. 22:00 - 00:00 2.00 CASE P COMP Clean MOBM from pits and all surface equipment. 5/18/2003 00:00 - 01 :00 1.00 CASE P COMP Finish cleaning MOBM from mud pits 01 :00 - 04:30 3.50 CASE P COMP POH laying down 189 joints of DP. 04:30 - 05:00 0.50 CASE P COMP LD liner setting tool and clear floor 05:00 - 06:00 1.00 CASE P COMP RIH with 7 stands of HWDP and 31 stands of DP from derrick to come out laying down singles. 06:00 - 06: 15 0.25 CASE P COMP PJSM with rig personnel on cut and slip drilling line 06:15 - 07:00 0.75 CASE P COMP Rig service, cut and slip drill line 07:00 - 09:30 2.50 RUNCO~ COMP POH laying down 93 joints of DP and 21 joints of HWDP 09:30 - 10:00 0.50 RUNCO~ COMP Clean and clear rig floor 10:00 - 10:30 0.50 BOPSUR P COMP Pull wear bushing. Make dummy run with tbg hanger 10:30 - 11 :00 0.50 RUNCO~ COMP RU to run tbg. Hold PJSM with BOT and rig personnel 11 :00 - 16:00 5.00 RUNCO~ COMP MU and run 114 Jts 4-1/2" 12.6# L-80 tubing and completion jewelry as per running order. 16:00 - 17:00 1.00 RUNCO~ COMP MU tbg hanger/landing joint. Land tbg. RILDS and torque. 17:00 - 18:00 1,00 RUNCO~ COMP Reverse circulate 80 bbls clean 9.2 ppg brine around. Spot 25 bbls corrosion inhibited brine above production packer. 3 bbl/min max rate @ 200 psi. 18:00 - 21 :00 3.00 RUNCO~ COMP Drop ball & rod. LD landing joint. Close blind rams and Printed: 5/27/2003 10:22:19 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-202 V-202 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/4/2003 Rig Release: 5/19/2003 Rig Number: Spud Date: 5/4/2003 End: 5/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/18/2003 18:00 - 21 :00 3.00 RUNCOrvP COMP pressure up tbg to 4200 psi to set packer. Bleed pressure to 3500 psi and hold 30 minutes to test tbg - OK, Bleed tbg pressure to 2000 psi and pressure up 4-1/2" X 7-5/8" annulus to 3500 psi, hold for 30 minute packer test - OK. Bleed tbg & annulus pressure to O. Shear DCK valve by pressuring up 4-1/2" X 7-5/8" annulus to 2800 psi. Install TWC and pressure test to 1000 psi - OK. 21 : 00 - 21 : 15 0.25 RUNCOrvP COMP PJSM with Little Red and rig personnel on freeze protecting inner and outer annulus. 21 :15 - 22:00 0.75 RUNCOrvP COMP Pump 90 bbls dead crude down 10-3/4" X 7-5/8" annulus at 2.5 bpm and 900 psi to freeze protect. Shut in annulus w/ 900 psi. 22:00 - 00:00 2.00 BOPSURP COMP ND BOPE 5/19/2003 00:00 - 01 :00 1.00 BOPSURP COMP ND BOPE 01 :00 - 01 :30 0.50 WHSUR P COMP Move adapter flange & tree into cellar 01 :30 - 03:00 1.50 WHSUR P COMP NU tree & adapter flange 03:00 - 03:30 0.50 WHSUR P COMP Pressure test tree & adapter flange to 5000 psi. Install VR plug in unused side of tbg spool with DSM 03:30 - 04:00 0.50 WHSUR P COMP RU DSM and pull TWC through lubricator 04:00 - 06:30 2.50 WHSUR P COMP RU Little Red and pump 90 bbls diesel down 4-1/2" X 7-5/8" annulus and allow to U-tube to freeze protect tubing and IA to 2250', 06:30 - 08:00 1.50 WHSUR P COMP RU DSM and install BPV through lubricator. RD Little Red and DSM 08:00 - 09:00 1.00 WHSUR P COMP RU DSM and install 2nd VR plug in tbg spool outlet. RD DSM and secure cellar. RIG RELEASED @ 09:00 5/19/2003 Printed: 5/27/2003 10:22:19 AM SCHLUMBERGER Survey report Client...................: BP Exploration (alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: ORION Well. . . . . . . . . . . . . . . . . . . . .: V-202 API number...............: 50-029-23153-00 Engineer. . . . . . . . . . . . . . . . .: E. Roux Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alas ka ----- 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.......: 54.00 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 82.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.32795887 Departure (+E/W-)........: W 149.2664177 Azimuth from rotary table to target: 4.75 degrees 16-May-2003 17:13:49 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 7 4-May-03 16-May-03 162 0.00 ft 8985.00 ft ~' ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2002 Magnetic date.... ........: 04-May-2003 Magnetic field strength..: 1150.31 HCNT Magnetic dec (+E/W-) .....: 25.58 degrees Magnetic dip......... ....: 80.78 degrees ----- MWD survey Reference Reference G..............: Reference H.... ..........: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.31 HCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 25.57 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.57 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlurnberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~' SCHLUMBERGER Survey Report 16-May-2003 17:13:49 Page 2 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Inc1 angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2066.41 2159.31 2252.98 2345.36 2439.30 2531.58 2626.27 2719.40 2794.91 2869.32 0.00 0.19 0.34 1.97 3.13 3.01 2.24 0.43 0.17 0.74 2.32 3.30 4.82 6.42 9.51 12.19 13.12 14.07 16.89 20.03 20.27 22.26 24.14 26.95 29.02 29.61 29.77 29.81 29.84 29.47 0.00 118.51 136.62 167.60 165.82 180.12 196.02 208.64 333.97 359.12 13.87 12.71 6.36 2.16 0.76 0.91 0.10 355.37 352.10 346.96 349.12 352.87 353.77 355.28 356.56 354 :28 354.03 354.06 354.51 354.55 0.00 200.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 66.41 92.90 93.67 92.38 93.94 92.28 94.69 93.13 75.51 74.41 0.00 200.00 300.00 399.98 499.87 599.73 699.63 799.60 899.60 999.59 1099.55 1199.43 1299.18 1398.70 1497.72 1595.92 1693.49 1790.69 1887.06 1981.91 2044.25 2130.83 2216.92 2300.26 2383.21 2463.68 2545.94 2626.76 2692.27 2756.93 0.00 -0.13 -0.40 -2.24 -6.46 -11.66 -16.20 -18.46 -18.67 -17.90 -15.26 -10.41 -3.36 6.42 20.25 39.03 60.88 84.18 110.36 140.85 162.76 195.48 231.64 270.85 314.40 358.98 405.08 450.54 487.47 523.70 0.00 -0.16 -0.45 -2.35 -6.67 -11.95 -16.45 -18.66 -18.85 -18.07 -15.46 -10.69 -3.71 6.06 19.91 38.73 60.63 84.10 110.61 141.69 164.07 197.34 233.99 273.64 317.60 362.63 409.29 455.31 492. 67 529.32 0.00 0.29 0.64 1.21 2.25 2.92 2.37 1.65 1.41 1.33 1.81 2.92 4.02 4.70 5.02 5.30 5.48 4.52 1.54 -4.32 -9.06 -14.28 -18.56 -22.33 -25.45 -29.07 -33.84 -38.64 -42.38 -45.89 0.00 0.33 0.78 2.64 7.04 12.30 16.62 18.73 18.91 18.12 15.57 11.08 5.47 7.67 20.53 39.09 60.88 84.22 110.62 141.76 164.32 197.85 234.72 274.55 318.62 363.79 410.68 456.94 494.49 531.31 0.00 118.51 125.26 152.66 161.35 166.29 171.80 174.94 175.74 175.79 173.34 164.70 132.66 37.82 14.15 7.79 5.17 3.08 0.80 358.25 356.84 355.86 355.47 355.33 355.42 355.42 355.27 355.15 355.08 355.04 DLS (degl 100f) 0.00 0.09 0.17 1.69 1.16 0.77 1.05 1.82 0.55 0.59 1.62 0.98 1.58 1.65 3.10 2.68 0.95 1.46 2.95 3.53 1.18 2.59 2.04 3.12 2.29 1.37 0.21 0.05 0.30 0.50 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIP GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO ~ GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA -- MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 16-May-2003 17:13:49 Page 3 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2930.67 3024.18 3117.12 3210.90 3305.16 3398.85 3491.82 3585.06 3679.05 3771.21 3863.41 3958.46 4051.94 4145.02 4238.98 4332.54 4426.15 4516.31 4613.48 4705.32 4800.40 4892.65 4984.65 5075.07 5170.36 "5264.07 5352.13 5451.79 5545.16 5638.03 29.39 28.94 28.61 28.81 29.18 28.92 27.70 27.13 28.82 30.26 30.68 32.04 33.61 36.75 39.69 44.54 45.59 48.26 51.22 55.34 58.74 62.80 66.30 70.08 72.76 73.11 71.29 74.87 78.48 82.15 354.40 353.94 353.93 350.37 341.16 334.57 329.62 325.63 324.91 325.21 325.51 325.84 326.94 330.75 332.34 333.71 334.70 336.31 337.55 337.98 339.61 339.69 338.79 340.34 343.87 349.08 352.95 354.58 357.33 0.62 61.35 93.51 92.94 93.78 94.26 93.69 92.97 93.24 93.99 92.16 92.20 95.05 93.48 93.08 93.96 93.56 93.61 90.16 97.17 91.84 95.08 92.25 92.00 90.42 95.29 93.71 88.06 99.66 93.37 92.87 2810.36 2892.02 2973.48 3055.74 3138.23 3220.15 3302.01 3384.79 3467.79 3547.97 3627.44 3708.60 3787.15 3863.23 3937.04 4006.43 4072.54 4134.11 4196.91 4251.81 4303.53 4348.57 4388.10 4421.69 4452.05 4479.57 4506.50 4535.50 4557.02 4572.65 553.37 598.16 642.10 686.05 729.13 769.66 806.77 840.99 875.01 909.98 946.11 984.51 1024.25 1067.70 1116.35 1169.72 1226.79 1284.25 1349.83 1415.42 1487.15 1560.04 1634.99 1710.95 1794.30 1879.33 1960.75 2054.33 2144.10 2235.15 559.33 604.66 649.15 693.76 737.92 780.01 818.95 855.20 891.43 928.68 967.14 1008.00 1050.20 1096.10 1147.22 1203.13 1262.79 1322.72 1390.94 1459.07 1533.44 1608.90 1686.57 1765.22 1851.15 1938.22 2021.01 2115.78 2206.38 2297.89 -48.79 -53.42 -58.15 -64.30 -75.53 - 92. 64 -113.22 -136.19 -161.31 -187.33 -213.90 -241.79 -269.83 -297.50 -325.17 -353.59 -382.42 -409.70 -438.74 -466.58 -495.41 -523.40 -552.85 -582.14 -609.87 -630.81 -643.91 -654.25 -660.64 -662.27 561.45 607.02 651.75 696.73 741.77 785.49 826.74 865.98 905.91 947.38 990.52 1036.59 1084.31 1135.76 1192.41 1254.01 1319.43 1384.72 1458.50 1531.86 1611.48 1691.90 1774.87 1858.73 1949.03 2038.29 2121.11 2214.62 2303.17 2391.42 355.01 354.95 354.88 354.70 354.16 353.23 352.13 350.95 349.74 348.60 347.53 346.51 345.59 344.81 344.17 343.62 343.15 342.79 342.49 342.27 342.10 341.98 341.85 341.75 341.77 341.97 342.33 342.82 343.33 343.92 DLS (deg/ 100f) 0.18 0.54 0.36 1.84 4.75 3.43 2.84 2.06 1.83 1.57 0.48 1.44 1.80 4.11 3.30 5.28 1.35 3.24 3.20 4.50 3.85 4.40 3.91 4.47 4.50 5.33 4.67 3.92 4.81 5.27 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA -...v MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA SCHLUMBERGER Survey Report 16-May-2003 17:13:49 Page 4 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (de g) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5735.17 5824.60 5902.23 5943.83 5965.21 5996.02 6027.44 6061.08 6087.36 6121.74 6152.77 6184.71 6213.10 6246.69 6277.40 6306.57 6337.63 6368.82 6399.66 6430.11 6461.90 6493.89 6525.50 6556.34 6588.85 6619.32 6649.30 6680.39 6711.71 6742.42 83.01 82.12 81.29 81.26 81.10 81. 62 86.65 87.75 88.33 90.01 92.00 93.89 94.89 95.02 95.09 94.06 94.10 94.85 93.99 94.23 94.78 95.30 93.58 90.11 86.99 86.92 87.40 88.78 87.92 86.61 5.89 9.39 15.14 16.75 17.58 19.46 20.04 20.94 22.16 22.84 23.77 24.36 24.23 23.36 22.42 20.52 20.36 20.59 21.80 23.03 23.82 23.57 24.56 24.81 23.90 23.70 24.01 24.52 25.13 24.65 97.14 89.43 77.63 41.60 21.38 30.81 31.42 33.64 26.28 34.38 31.03 31.94 28.39 33.59 30.71 29.17 31.06 31.19 30.84 30.45 31.79 31.99 31.61 30.84 32.51 30.47 29.98 31.09 31.32 30.71 4585.20 4596.77 4607.98 4614.29 4617.57 4622.20 4625.41 4627.05 4627.95 4628.45 4627.91 4626.27 4624.09 4621.19 4618.48 4616.16 4613.95 4611.51 4609.14 4606.96 4604.46 4601.65 4599.20 4598.21 4599.03 4600.65 4602.13 4603.17 4604.07 4605.54 2331.41 2419.96 2496.08 2536.42 2557.05 2586.64 2616.82 2649.16 2674.30 2707.04 2736.45 2766.55 2793.22 2824.86 2853.93 2881.77 2911.60 2941.53 2971.02 2999.96 3029.98 3060.12 3089.86 3118.83 3149.45 3178.21 3206.50 3235.79 3265.19 3293.99 2394.02 2481.90 2556.93 2596.46 2616.65 2645.53 2674.94 2706.41 2730.84 2762.60 2791.09 2820.21 2846.01 2876.63 2904.81 2931.87 2960.90 2990.03 3018.70 3046.78 3075.86 3105.04 3133.81 3161.81 3191.42 3219.26 3246.64 3274.97 3303.38 3331.21 -656.79 -645.01 -628.70 -617.41 -611.17 -601.50 -590.94 -579.18 -569.53 -556.37 -544.10 -531.09 -519.45 -505.95 -494.05 -483.41 -472.59 -461.71 -450.59 -439.01 -426.41 -413.61 -400.76 -387.89 -374.48 -362 :21 -350.10 -337.33 -324.18 -311.27 2482.48 2564.34 2633.09 2668.86 2687.08 2713.05 2739.43 2767.69 2789.60 2818.07 2843.63 2869.79 2893.03 2920.79 2946.53 2971.46 2998.38 3025.47 3052.14 3078.24 3105.27 3132.46 3159.33 3185.52 3213.31 3239.57 3265.46 3292.29 3319.25 3345.72 344.66 345.43 346.19 346.62 346.85 347.19 347.54 347.92 348.22 348.61 348.97 349.34 349.66 350.02 350.35 350.64 350.93 351.22 351.51 351.80 352.11 352.41 352.71 353.01 353.31 353.58 353.85 354.12 354.40 354.66 DLS (deg/ 100f) 5.45 4.01 7.41 3.83 3.91 6.26 16.11 4.22 5.14 5.27 7.08 6.20 3.55 2.61 3.06 7.39 0.53 2.51 4.80 4.11 3.02 1.80 6.27 11.28 10.00 0.69 1.91 4.73 3.37 4.54 ------ ------ Srvy Tool tool Corr type (de g) ------ ------ MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD Incl. Only MWD Incl. Only MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA .~ MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA -- MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 16-May-2003 17:13:49 Page 5 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Inc1 angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 6775.19 6806.53 6837.44 6869.53 6909.37 6931.24 6962.11 6992.65 7024.06 7054.98 7085.83 7116.15 7146.81 7177.52 7209.90 7241.58 7271.38 7303.09 7334.80 7365.17 7396.60 7427.83 7459.38 7489.98 7520.95 "7553.93 7583.61 7617.32 7646.00 7677.40 85.31 86.03 87.03 87.16 84.03 84.03 84.45 85.06 85.62 86.48 87.75 88.91 90.56 89.70 86.99 85.93 86.27 86.72 86.99 87.20 88.09 88.98 90.08 90.39 90.46 88.64 87.51 86.58 89.80 92.24 23.04 23.48 24.52 23.94 22.78 20.19 18.90 18.09 18.29 18.13 17.13 16.07 15.71 16.58 16.85 16.39 16.68 17.23 17.04 16.12 16.85 17.39 15.89 16.75 16.26 16.77 17.80 20.06 20.70 21.80 32.77 31.34 30.91 32.09 39.84 21.87 30.87 30.54 31.41 30.92 30.85 30.32 30.66 30.71 32.38 31.68 29.80 31.71 31.71 30.37 31.43 31.23 31.55 30.60 30.97 32.98 29.68 33.71 28.68 31.40 4607.85 4610.21 4612.08 4613.71 4616.77 4619.04 4622.14 4624.94 4627.49 4629.62 4631.17 4632.05 4632.19 4632.13 4633.06 4635.02 4637.04 4638.98 4640.72 4642.26 4643.55 4644.35 4644.61 4644.48 4644.25 4644.51 4645.51 4647.25 4648.15 4647.59 3324.88 3354.51 3383.64 3413.85 3451.49 3472.32 3502.02 3531.56 3562.01 3592.00 3622.04 3651.70 3681.78 3711.89 3743.54 3774.49 3803.59 3834.53 3865.45 3895.14 3925.89 3956.38 3987.25 4017.23 4047.55 Z!079.83 4108.79 4141.42 4169.03 4199.13 3361.10 3389.81 3418.00 3447.22 3483.69 3503.92 3532.87 3561.71 3591.45 3620.75 3650.11 3679.16 3708.64 3738.14 3769.14 3799.44 3827.94 3858.21 3888.47 3917.54 3947.65 3977.49 4007.71 4037.08 4066.77 4098.39 4126.71 4158.55 4185.42 4214.68 -298.06 -285.72 -273.17 -260.02 -244.27 -236.30 -226.03 -216.38 -206.61 -196.97 -187.64 -178.98 -170.58 -162.04 -152.74 -143.69 -135.23 -126.00 -116.67 -108.02 -99.11 -89.92 -80.88 -72.28 -63.49 -54.11 -45.30 -34.38 -24.40 -13.02 3374.29 3401.83 3428.90 3457.02 3492.24 3511.88 3540.09 3568.27 3597.39 3626.10 3654.93 3683.51 3712.56 3741.65 3772.23 3802.15 3830.33 3860.27 3890.22 3919.03 3948.89 3978.50 4008.53 4037.73 4067.27 4098.75 4126.96 4158.70 4185.49 4214.70 354.93 355.18 355.43 355.69 355.99 356.14 356.34 356.52 356.71 356.89 357.06 357.22 357.37 357.52 357.68 357.83 357.98 358.13 358.28 358.42 358.56 358.71 358.84 358.97 359.11 359.24 359.37 359.53 359.67 359.82 DLS (deg/ 100f) 6.31 2.69 4.66 1.85 8.38 11.78 4.37 3.31 1.89 2.83 5.24 5.18 5.51 3.98 8.41 3.65 1.50 2.24 1.04 3.10 3.66 3.33 5.90 2.99 1.60 5.73 5.15 7.24 11.45 8.52 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA ~ MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 16-May-2003 17:13:49 Page 6 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Inc1 angle (deg) -------- ------ -------- ------ 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 7710.74 7742.18 7770.31 7801.37 7835.28 7862.61 7893.86 7925.75 7956.70 7986.22 8017.53 8048.03 8079.93 8110.85 8141.88 8173.66 8204.78 8235.25 8266.83 8297.65 8328.30 8360.08 8391.32 8421.83 8452.81 8483.81 8514.07 8545.64 8577.08 8608.12 91.55 91.69 92.21 90.08 89.46 89.81 90.29 89.19 88.09 88.16 88.71 88.67 89.19 88.09 87.95 90.77 92.27 92.41 93.51 94.37 94.47 91.73 90.63 90.80 91.21 90.22 86.79 86.31 86.48 85.51 Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) ------- ------ -------- -------- ---------------- ------- ------ -------- -------- ---------------- 21.74 21.49 21.39 21.26 21.56 21.10 21.22 21.53 21.82 21.99 21.57 21.08 20.96 20.95 20.73 21.84 21.53 21.72 21.69 21.79 21.31 21.51 22.02 22.21 22.39 22 . 2"3 19.65 19.70 19.71 19.24 33.34 31.44 28.13 31.06 33.91 27.33 31.25 31.89 30.95 29.52 31.31 30.50 31.90 30.92 31.03 31.78 31.12 30.47 31.58 30.82 30.65 31.78 31.24 30.51 30.98 31.00 30.26 31.57 31.44 31.04 4646.49 4645.60 4644.65 4644.03 4644.16 4644.34 4644.31 4644.45 4645.19 4646.15 4647.01 4647.71 4648.30 4649.04 4650.11 4650.46 4649.64 4648.39 4646.76 4644.64 4642.28 4640.56 4639.92 4639.54 4639.00 4638.61 4639.40 4641.30 4643.28 4645.44 4230.99 4261.06 4287.99 4317.76 4350.24 4376.43 4406.41 4436.97 4466.57 4494.76 4524.69 4553.91 4584.53 4614.21 4644.01 4674.47 4704.23 4733.36 4763.53 4792.93 4822.18 4852.58 4882.45 4911.57 4941.10 4970.65 4999.70 5030.15 5060.46 5090.41 4245.63 4274.84 4301.01 4329.94 4361.51 4386.96 4416.11 4445.80 4474.56 4501.93 4530.99 4559.40 4589.17 4618.04 4647.02 4676.63 4705.53 4733.83 4763.13 4791.69 4820.12 4849.66 4878.66 4906.93 4935.58 4964.26 4992.51 5022.18 5051.72 5080.91 -0.66 10.92 21.19 32.49 44.86 54.80 66.09 77.71 89.14 100.14 111.76 122.84 134.28 145.34 156.37 167.91 179.40 190.62 202.28 213.67 224.90 236.48 248.06 259.55 271.30 28 3 :07 293.88 304.49 315.07 325.39 At Azim (deg) --------------- --------------- 4245.63 4274.86 4301.06 4330.06 4361.74 4387.31 4416.60 4446.48 4475.44 4503.04 4532.37 4561.05 4591.13 4620.32 4649.65 4679.64 4708.95 4737.67 4767.43 4796.46 4825.36 4855.42 4884.97 4913.79 4943.04 4972.33 5001.15 5031.40 5061.54 5091.32 359.99 0.15 0.28 0.43 0.59 0.72 0.86 1.00 1.14 1.27 1.41 1.54 1.68 1.80 1.93 2.06 2.18 2.31 2.43 2.55 2.67 2.79 2.91 3.03 3.15 3.26 3.37 3.47 3.57 3.66 DLS (deg/ 100f) 2.08 0.91 1.88 6.87 2.03 2.11 1.58 3.58 3.68 0.62 2.21 1.61 1.67 3.56 0.84 9.54 4.92 0.77 3.48 2.81 1.60 8.64 3.88 0.84 1.45 3.23 14.18 1.53 0.54 3.47 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA ~ MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) ------ ------ Incl angle (de g) ------- ------- Azimuth angle (de g) ------ ------ Course length (ft) 16-May-2003 17:13:49 -------- -------- TVD depth (ft) -------- -------- Vertical section (ft) Page ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) 7 of 7 --------------- --------------- Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 151 152 153 154 155 156 157 158 159 160 161 162 8635.11 8670.20 8701.55 8732.38 8763.46 8795.60 8829.39 8860.88 8889.55 8923.26 8934.67 8985.00 86.13 86.65 88.67 88.95 88.95 88.36 86.89 85.72 86.44 87.20 87.40 87.40 19.47 20.02 20.80 21.15 21.36 21.77 22.68 22.54 22.14 21.80 22.42 22.42 [(c)2003 IDEAL 108 OC 07] 26.99 35.09 31.35 30.83 31.08 32.14 33.79 31.49 28.67 33.71 11.41 50.33 4647.41 4649.62 4650.90 4651.54 4652.11 4652.86 4654.26 4656.29 4658.25 4660.12 4660.66 4662.94 5116.46 5150.28 5180.44 5210.04 5239.83 5270.59 5302.79 5332.70 5359.97 5392.11 5106.31 5139.27 5168.63 5197.41 5226.37 5256.25 5287.50 5316.51 5342.97 5374.18 5402.99 5384.74 5450.90 5431.22 334.31 346.14 357.06 368.10 379.36 391.17 403.94 416.02 426.90 439.49 5117.24 5150.91 5180.94 5210.42 5240.12 5270.78 5302.91 5332.76 5359.99 5392.12 443.78 5402.99 462.95 5450.91 3.75 3.85 3.95 4.05 4.15 4.26 4.37 4.47 4.57 4.68 4.71 4.87 DLS (deg/ 100f) 2.45 2.15 6.91 1.45 0.68 2.24 5.12 3.74 2.87 2.47 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA . - / 5.70 MWD IFR MSA 0.00 Projected to TD bp V·202 Schlumbepuep Survey Report - Geodetic Report Date: 16-May-03 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 4.870° Field: Prudhoe Bay Unit· WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0,000 f1 Structure / Slot: V-Pad I V-202 TVD Reference Datum: KB Well: V-202 TVD Reference Elevation: 82.300 ft relative to MSL Borehole: V-202 Sea Bed / Ground Level Elevation: 54,000 ft relative to MSL UWVAPI#: 500292315300 Magnetic Declination: +25,558° Survey Name / Date: V-2021 May 16, 2003 Total Field Strength: 57515.204 nT Tort / AHD / DDI/ ERD ratio: 268,514° 15813,80 ft 16.478/1.247 Magnetic Dip: 80,778° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: May 21,2003 "-.,...' Location Lat/Long: N 70.32795887, W 149.26641772 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970065.800 ftUS, E 590453.170 ftUE North Reference: True North Grid Convergence Angle: +0.69077098° Total Corr Mag North -> True North: +25,558° Grid Scale Factor: 0.99990929 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing I Easting Latitude I Longitude (ft) (0) (") (ft) (ft) (ft) (ft) r/100ft) (ftUS) (ftUS) 0,00 0,00 0.00 0,00 0.00 0,00 0,00 5970065.80 590453.17 N 70,32795887 W 149.26641773 200.00 0,19 118.51 200,00 -0,13 -0,16 0.29 0,09 5970065.65 590453.46 N 70,32795844 W 149.26641536 300,00 0.34 136.62 300,00 -0.40 -0.45 0.64 0,17 5970065.35 590453.82 N 70.32795763 W 149.26641253 400.00 1,97 167,60 399,98 -2,24 -2,35 1.21 1,69 5970063.47 590454.41 N 70,32795246 W 149.26640788 500,00 3.13 165,82 499,87 -6.46 -6.67 2.25 1,16 5970059,15 590455.50 N 70,32794064 W 149,26639947 600.00 3.01 180,12 599.73 -11.66 -11.95 2.92 0,77 5970053,89 590456.23 N 70.32792623 W 149.26639409 700,00 2,24 196.02 699.63 -16.19 -16.45 2,37 1.05 5970049,38 590455.74 N 70.32791393 W 149.26639851 800.00 0.43 208,64 799.60 -18.45 -18.66 1.65 1.82 5970047,17 590455.05 N 70.32790790 W 149.26640434 900.00 0.17 333,97 899,60 -18.67 -18.85 1.41 0,55 5970046.97 590454,80 N 70,32790736 W 149.26640633 -" 1000.00 0,74 359,12 999,59 -17,90 -18.07 1.33 0.59 5970047,74 590454,72 N 70,32790949 W 149.26640693 1100.00 2,32 13.87 1099,55 -15.25 -15.46 1,81 1.62 5970050,36 590455.16 N 70,32791662 W 149.26640308 1200.00 3.30 12.71 1199.43 -10.40 -10,69 2,92 0.98 5970055,15 590456,22 N 70,32792966 W 149.26639401 1300.00 4,82 6.36 1299,18 -3.35 -3,71 4.02 1,58 5970062.14 590457,24 N 70.32794874 W 149.26638510 1400.00 6.42 2,16 1398.70 6.43 6.06 4.70 1.65 5970071,91 590457,80 N 70,32797541 W 149:26637962 . 1500,00 9.51 0,76 1497.72 20,26 19,91 5.02 3.10 5970085.76 590457.95 N 70,32801325 W 149.26637702 1600.00 12,19 0,91 1595,92 39,04 38,73 5.30 2.68 5970104.58 590458,00 N 70,32806467 W 149,26637477 1700,00 13,12 0,10 1693.49 60,88 60,63 5.48 0.95 5970126.49 590457.92 N 70,32812451 W 149,26637325 1800,00 14.07 355,37 1790.69 84.18 84.10 4,52 1.46 5970149.94 590456.68 N 70.32818862 W 149,26638105 Schlumberger Private Page 1 of 6 V-202 ASP Final Survey,xls 6/4/2003-3:45 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nt-S E/-W DLS Northing Easting Latitude Longitude (ft) (") (0) (ft) (tt) (ft) (ft) (0/1oott) (ttUS) (ftUS) 1900.00 16,89 352,10 1887,06 110.34 110,61 1,54 2.95 5970176.41 590453.38 N 70,32826104 W 149,26640520 2000,00 20.03 346,96 1981.91 140.81 141.69 -4.32 3.53 5970207.42 590447.14 N 70,32834596 W 149.26645274 2066.41 20,27 349,12 2044,25 162.71 164,07 -9.06 1,18 5970229.73 590442.14 N 70.32840709 W 149.26649116 2159.31 22,26 352,87 2130,83 195.41 197.34 -14.28 2,59 5970262,93 590436.52 N 70.32849798 W 149.26653351 2252.98 24.14 353.77 2216,92 231.57 233,99 -18,56 2.04 5970299.52 590431 ,79 N 70,32859810 W 149,26656822 2345.36 26.95 355,28 2300.26 270.75 273,64 -22,33 3,12 5970339,12 590427,54 N 70,32870642 W 149,26659882 2439,30 29.02 356,56 2383.21 314.29 317,60 -25.45 2.29 5970383,04 590423.89 N 70,32882653 W 149,26662412 2531.58 29.61 354.28 2463.68 358.85 362,63 -29.07 1,37 5970428,02 590419.74 N 70,32894954 W 149,26665344 2626.27 29.77 354.03 2545.94 404.94 409,29 -33.84 0.21 5970474,61 590414.40 N 70.32907700 W 149.26669218 2719.40 29.81 354,06 2626,76 450.38 455,31 -38,64 0.05 5970520.56 590409,04 N 70,32920272 W 149.26673111 '--, 2794.91 29.84 354,51 2692.27 487.30 492.67 -42,38 0.30 5970557.88 590404.85 N 70,32930481 W 149.26676144 2869.32 29.47 354.55 2756.93 523.52 529.32 -45.89 0,50 5970594.48 590400,90 N 70.32940493 W 149,26678990 2930.67 29,39 354.40 2810,36 553,17 559.33 -48,79 0.18 5970624.45 590397.64 N 70,32948690 W 149.26681344 3024,18 28,94 353,94 2892,02 597.94 604.66 -53.42 0,54 5970669.72 590392.47 N 70.32961075 W 149.26685097 3117.12 28,61 353.93 2973.48 641.87 649,15 -58.15 0.36 5970714.14 590387.20 N 70.32973229 W 149.26688930 3210.90 28.81 350,37 3055.74 685,79 693.76 -64,30 1,84 5970758.67 590380.51 N 70.32985416 W 149.26693922 3305.16 29.18 341 . 16 3138.23 728,84 737.92 -75.53 4,75 5970802.69 590368.76 N 70,32997480 W 149.26703026 3398.85 28,92 334,57 3220,15 769.32 780,01 -92.64 3.43 5970844,56 590351.15 N 70.33008978 W 149,26716901 3491.82 27.70 329,62 3302.01 806.39 818,95 -113.22 2.84 5970883.25 590330.09 N 70.33019618 W 149.26733595 3585.06 27.13 325,63 3384.79 840.55 855.20 -136.19 2.06 5970919.22 590306.70 N 70,33029520 W 149,26752219 3679.05 28.82 324.91 3467,79 874,52 891.43 -161,31 1,83 5970955.14 590281,14 N 70.33039417 W 149.26772594 3771.21 30,26 325.21 3547,97 909.42 928.68 -187.33 1,57 5970992,07 590254.68 N 70,33049593 W 149,26793698 3863.41 30,68 325.51 3627.44 945.49 967.14 -213.90 0.48 5971030.21 590227.64 N 70.33060102 W 149,26815251 3958.46 32.04 325,84 3708,60 983.83 1008,00 -241.79 1.44 5971070.71 590199.27 N 70.33071262 W 149,26837871 4051.94 33.61 326.94 3787,15 1023.50 1050,20 -269.83 1.80 5971112.57 590170,72 N 70,33082791 W 149.26860612 4145.02 36.75 330,75 3863,23 1066.89 1096.10 -297,50 4.11 5971158.14 590142.50 N 70,33095331 W 149,26883054 -- 4238.98 39.69 332,34 3937.04 1115.47 1147.22 -325.17 3,30 5971208.91 590114.22 N 70.33109294 W 149,26905497 4332.54 44.54 333.71 4006.43 1168.77 1203.13 -353.59 5,28 5971264.47 590085.13 N 70,33124569 W 149,26928548 4426.15 45,59 334.70 4072,54 1225.77 1262.79 -382.42 1,35 5971323,77 590055.59 N 70,33140869 W 149.26951933 4516.31 48,26 336.31 4134,11 1283.17 1322,72 -409.70 3,24 5971383.37 590027.59 N 70,33157241 W 149.26974064 4613.48 51,22 337.55 4196,91 1348.67 1390,94 -438.74 3,20 5971451.22 589997.73 N 70.33175877 W 149.26997617 4705.32 55.34 337,98 4251.81 1414.19 1459.07 -466.58 4,50 5971519.01 589969,07 N 70.33194489 W 149.27020203 4800.40 58,74 339,61 4303.53 1485.85 1533,44 -495.41 3,85 5971593.01 589939,35 N 70,33214805 W 149.27043590 4892.65 62,80 339.69 4348.57 1558.66 1608.90 -523.40 4.40 5971668.13 589910.46 N 70.33235421 W 149.27066295 4984.65 66,30 338,79 4388,10 1633,54 1686.57 -552,85 3.91 5971745.42 589880,08 N 70,33256637 W 149,27090185 Schlumberger Private V-202 ASP Final Survey.xls Page 2 of 6 6/4/2003-3:45 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ·S E/·W DLS Northing Easting Latitude LQngitude (ft) n (") (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 5075.07 70.08 340.34 4421.69 1709:42 1765.22 -582.14 4.47 5971823.71 589849,85 N 70.33278123 W 149,27113947 5170.36 72.76 343.87 4452.05 1792.70 1851.15 -609.87 4.50 5971909.30 589821,09 N 70.33301600 W 149.27136440 5264.07 73,11 349,08 4479,57 1877.67 1938.22 -630.81 5.33 5971996.10 589799.1 0 N 70.33325385 W 149.27153430 5352,13 71.29 352.95 4506.50 1959,05 2021,01 -643,91 4.67 5972078,72 589785.00 N 70,33348002 W 149.27164066 5451,79 74.87 354,58 4535.50 2052.59 2115.78 -654.25 3.92 5972173.34 589773.52 N 70,33373891 W 149.27172460 5545,16 78.48 357.33 4557.02 2142,33 2206,38 -660,64 4.81 5972263.85 589766.04 N 70,33398644 W 149.27177650 5638,03 82.15 0,62 4572.65 2233,37 2297,89 -662.27 5,27 5972355,32 589763.31 N 70.33423642 W 149.27178973 5735,17 83.01 5,89 4585.20 2329,62 2394,02 -656.79 5.45 5972451.51 589767.63 N 70.33449905 W 149.27174541 5824,60 82,12 9,39 4596.77 2418.18 2481,90 -645.01 4,01 5972539,51 589778.35 N 70.33473912 W 149.27164988 5902,23 81,29 15,14 4607,98 2494,32 2556,93 -628.70 7.41 5972614.73 589793,75 N 70.33494411 W 149.27151765 "~ 5943,83 81.26 16,75 4614.29 2534.68 2596.46 -617.41 3,83 5972654.39 589804,57 N 70,33505212 W 149,27142605 5965,21 81.10 17,58 4617,57 2555.32 2616.65 -611 . 17 3.91 5972674,65 589810,56 N 70,33510726 W 149.27137548 5996,02 81,62 19.46 4622.20 2584.92 2645.53 -601,50 6.26 5972703.64 589819.88 N 70.33518617 W 149.27129702 6027.44 86.65 20.04 4625.41 2615.11 2674,94 -590,94 16.11 5972733,17 589830,09 N 70.33526651 W 149.27121138 6061.08 87,75 20.94 4627,05 2647.47 2706.41 -579.18 4,22 5972764.78 589841.47 N 70.33535249 W 149,27111599 6087,36 88.33 22,16 4627,95 2672.63 2730.84 -569.53 5.14 5972789.32 589850,82 N 70.33541923 W 149.27103775 6121.74 90,01 22,84 4628.45 2705,39 2762.60 -556.37 5,27 5972821.23 589863.59 N 70.33550599 W 149.27093106 6152.77 92,00 23.77 4627,91 2734,82 2791.09 -544.1 ° 7.08 5972849.87 589875.51 N 70.33558383 W 149.27083151 6184.71 93,89 24.36 4626.27 2764,95 2820,21 -531.09 6,20 5972879.15 589888.17 N 70.33566340 W 149.27072602 6213,10 94,89 24,23 4624.09 2791,64 2846,01 -519.45 3.55 5972905.08 589899,50 N 70.33573388 W 149.27063156 6246,69 95,02 23.36 4621.19 2823,30 2876.63 -505.95 2,61 5972935.86 589912.63 N 70.33581754 W 149.27052205 6277.40 95,09 22.42 4618.49 2852.39 2904.81 -494,05 3.06 5972964.18 589924,19 N 70.33589453 W 149.27042554 6306.57 94.06 20.52 4616.16 2880.25 2931,87 -483.41 7.39 5972991,36 589934.50 N 70.33596845 W 149.27033923 6337.63 94,10 20,36 4613,95 2910,09 2960,90 -472.59 0,53 5973020.52 589944.97 N 70.33604776 W 149,27025147 6368.82 94,85 20,59 4611.51 2940,04 2990,03 -461.71 2,51 5973049.77 589955.49 N 70.33612734 W 149.27016325 6399,66 93,99 21.80 4609.14 2969,55 3018,70 -450.59 4.80 5973078.57 589966,26 N 70.33620566 W 149.27007308 - 6430,11 94.23 23,03 4606.96 2998,51 3046,78 -439.01 4.11 5973106.78 589977,50 N 70.33628237 W 149,26997915 6461.90 94,78 23.82 4604.46 3028.55 3075.86 -426.41 3.02 5973136,01 589989.75 N 70.33636181 W 149.26987695 6493.89 95,30 23.57 4601.65 3058.71 3105.04 -413.61 1,80 5973165,34 590002.20 N 70.33644153 W 149.26977308 6525,50 93.58 24.56 4599,20 3088.48 3133.81 -400.76 6,27 5973194.26 590014,70 N 70.33652014 W 149.26966884 6556.34 90.11 24.81 4598,21 3117.47 3161,81 -387,89 11.28 5973222.41 590027.23 N 70.33659664 W 149.26956444 6588.85 86,99 23.90 4599,03 3148,1 ° 3191.42 -374.48 10.00 5973252.18 590040.28 N 70.33667752 W 149.26945573 6619,32 86.92 23,70 4600.65 3176.88 3219,26 -362,21 0.69 5973280.16 590052,22 N 70.33675358 W 149.26935613 6649,30 87.40 24.01 4602,13 3205.20 3246,64 -350.10 1.91 5973307.68 590063.99 N 70.33682839 W 149.26925790 6680,39 88,78 24.52 4603.17 3234.51 3274,97 -337.33 4,73 5973336.16 590076.42 N 70.33690578 W 149,26915432 Schlumberger Private V-202 ASP Final Survey,xls Page 3 of 6 6/4/2003-3:45 PM Grid Coordinates Geographic Coordinates Station 10 MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (") (0) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 6711.71 87.92 25,13 4604.07 3263.93 3303,38 -324,18 3.37 5973364.73 590089,22 N 70.33698340 W 149.26904770 6742.42 86.61 24,65 4605.54 3292.76 3331.21 -311,27 4.54 5973392,70 590101,79 N 70.33705942 W 149.26894297 6775.19 85.31 23,04 4607.85 3323,67 3361,10 -298,06 6.31 5973422,75 590114.64 N 70.33714110 W 149.26883578 6806,53 86.03 23.48 4610.21 3353.32 3389,81 -285,72 2.69 5973451.61 590126,64 N 70,33721953 W 149,26873567 6837.44 87.03 24,52 4612.08 3382.47 3418.00 -273,17 4.66 5973479.94 590138.84 N 70.33729653 W 149,26863387 6869.53 87.16 23,94 4613.71 3412.71 3447.22 -260.02 1.85 5973509.32 590151,64 N 70.33737638 W 149,26852717 6909.37 84.03 22,78 4616.77 3450.37 3483.69 -244.27 8.38 5973545,96 590166,95 N 70.33747599 W 149.26839941 6931,24 84,03 20,19 4619.05 3471.21 3503.92 -236.30 11.78 5973566.30 590174.67 N 70.33753128 W 149.26833479 6962,11 84.45 18,90 4622,14 3500.92 3532.87 -226.03 4.37 5973595.36 590184.59 N 70.33761035 W 149.26825144 6992,65 85,06 18,09 4624,94 3530.48 3561.71 -216.38 3,31 5973624.31 590193,89 N 70.33768914 W 149.26817318 - 7024.06 85,62 18.29 4627.49 3560.94 3591.45 -206,61 1.89 5973654.17 590203.30 N 70.33777039 W 149.26809390 7054.98 86.48 18.13 4629,62 3590.96 3620.75 -196.97 2,83 5973683.58 590212,59 N 70.33785044 W 149.26801570 7085.83 87,75 17,13 4631.17 3621.01 3650.11 -187,64 5,24 5973713,05 590221.56 N 70.33793066 W 149,26794000 7116.15 88,91 16.07 4632.05 3650.68 3679,16 -178.98 5.18 5973742.19 590229.87 N 70.33801000 W 149,26786977 7146.81 90,56 15,71 4632.20 3680.77 3708,64 -170.58 5.51 5973771.77 590237.91 N 70.33809056 W 149,26780167 7177.52 89,70 16,58 4632,13 3710,89 3738,14 -162.04 3,98 5973801,37 590246.09 N 70,33817115 W 149.26773240 7209.90 86,99 16.85 4633.06 3742,56 3769,14 -152.74 8.41 5973832.47 590255.02 N 70.33825582 W 149.26765688 7241.58 85,93 16,39 4635,02 3773,52 3799.44 -143.69 3.65 5973862,88 590263.70 N 70,33833860 W 149,26758351 7271,38 86,27 16,68 4637,04 3802.64 3827,94 -135.23 1.50 5973891.47 590271 .82 N 70.33841646 W 149,26751487 7303,09 86,72 17,23 4638.98 3833.59 3858,21 -126,00 2,24 5973921.86 590280.68 N 70,33849917 W 149,26743999 7334.80 86.99 17.04 4640.72 3864.53 3888.47 -116.67 1.04 5973952.22 590289.64 N 70,33858183 W 149.26736431 7365.17 87.20 16.12 4642,26 3894.23 3917.54 -108,02 3.10 5973981.39 590297,95 N 70.33866124 W 149,26729409 7396.60 88.09 16.85 4643,55 3924.99 3947.65 -99.11 3.66 5974011,60 590306.49 N 70,33874351 W 149.26722180 7427.83 88.98 17.39 4644.35 3955.49 3977.49 -89.92 3.33 5974041,55 590315,32 N 70.33882502 W 149,26714723 7459.38 90,08 15.89 4644.61 3986.38 4007,71 -80,88 5.90 5974071.88 590323.99 N 70.33890759 W 149,26707394 7489,98 90,39 16.75 4644.48 4016.37 4037,08 -72,28 2.99 5974101.34 590332.23 N 70.33898782 W 149,26700418 ~ 7520,95 90.46 16,26 4644.25 4046.70 4066,77 -63.49 1.60 5974131 .14 590340.67 N 70,33906894 W 149.26693280 7553.93 88.64 16.77 4644,51 4079.00 4098.39 -54.11 5.73 5974162.86 590349.66 N 70,33915531 W 149.26685674 7583,61 87,51 17.80 4645.51 4107.97 4126.71 -45.30 5.15 5974191.28 590358,13 N 70.33923269 W 149.26678524 7617,32 86.58 20.06 4647,25 4140.62 4158.55 -34,38 7.24 5974223.25 590368.67 N 70.33931968 W 149.26669663 7646.00 89.80 20,70 4648.15 4168,24 4185.42 -24.40 11 .45 5974250.24 590378.32 N 70,33939308 W 149,26661565 7677.40 92.24 21.80 4647,60 4198.36 4214.68 -13.02 8,52 5974279.63 590389,35 N 70,33947301 W 149,26652334 7710,74 91.55 21.74 4646.49 4230,24 4245.63 -0.66 2,08 5974310.72 590401 .33 N 70,33955755 W 149.26642306 7742.18 91.69 21.49 4645.60 4260,34 4274.84 10.92 0.91 5974340.07 590412,55 N 70,33963737 W 149.26632913 7770.31 92.21 21,39 4644.65 4287,28 4301,01 21.19 1.88 5974366.36 590422.51 N 70.33970886 W 149.26624575 Schlumberger Private V-202 ASP Final Survey. xis Page 4 of 6 6/4/2003-3:45 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nt-S E/-W DL5 Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ("/1000) (ftUS) (ftUS) 7801,37 90,08 21,26 4644.03 4317,06 4329,94 32.49 6,87 5974395.41 590433.45 N 70,33978788 W 149.26615413 7835,28 89.46 21.56 4644.16 4349.57 4361.51 44.86 2.03 5974427,13 590445.45 N 70.33987412 W 149.26605369 7862,61 89,81 21.10 4644.34 4375,78 4386.96 54.80 2.11 5974452,70 590455.08 N 70,33994367 W 149.26597304 7893.86 90,29 21.22 4644,31 4405.77 4416.11 66.09 1.58 5974481.97 590466,01 N 70,34002329 W 149,26588151 7925,75 89,19 21.53 4644.45 4436.35 4445.80 77.71 3.58 5974511,80 590477,27 N 70,34010441 W 149.26578720 7956.70 88,09 21.82 4645.19 4465.97 4474.56 89.14 3,68 5974540,69 590488,35 N 70,34018296 W 149.26569447 7986.22 88.16 21,99 4646,15 4494.18 4501 .93 1 00.14 0,62 5974568,19 590499,03 N 70,34025775 W 149.26560516 8017,53 88.71 21.57 4647,01 4524,12 4530.99 111.76 2,21 5974597,39 590510,29 N 70,34033715 W 149.26551093 8048,03 88,67 21.08 4647,71 4553,37 4559.40 122.84 1,61 5974625,92 590521.03 N 70,34041474 W 149,26542095 8079.93 89.19 20.96 4648,30 4584.00 4589,17 134.28 1,67 5974655,83 590532,11 N 70,34049608 W 149.26532812 ---' 8110.85 88,09 20.95 4649.04 4613.70 4618.04 145,34 3.56 5974684,82 590542.82 N 70.34057494 W 149.26523842 8141.88 87,95 20.73 4650,11 4643.52 4647.02 156,37 0.84 5974713.94 590553.50 N 70.34065411 W 149.26514889 8173,66 90,77 21.84 4650.46 4674.00 4676.63 167,91 9.54 5974743,68 590564.67 N 70.34073500 W 149.26505529 8204.78 92,27 21.53 4649.64 4703.78 4705.53 179.40 4,92 5974772.72 590575.82 N 70.34081397 W 149.26496202 8235.25 92.41 21.72 4648.39 4732.93 4733,83 190,62 0,77 5974801.15 590586.69 N 70.34089128 W 149.26487098 8266,83 93,51 21.69 4646.76 4763.11 4763.14 202.28 3,48 5974830.59 590598.00 N 70.34097133 W 149.26477633 8297.65 94,37 21,79 4644,65 4792.54 4791,70 213,67 2,81 5974859,28 590609.04 N 70.34104935 W 149.26468391 8328.30 94.47 21,31 4642,28 4821.81 4820.12 224.90 1.60 5974887,83 590619,92 N 70,34112700 W 149.26459283 8360.08 91,73 21,51 4640.57 4852.23 4849,66 236.48 8,64 5974917.51 590631,15 N 70.34120770 W 149.26449883 8391 ,32 90,63 22,02 4639.92 4882.11 4878.67 248,06 3.88 5974946,65 590642.38 N 70.34128694 W 149.26440485 8421.83 90.80 22,21 4639.54 4911,25 4906.93 259,55 0,84 5974975,05 590653.52 N 70.34136416 W 149.26431165 8452,81 91,21 22,39 4639.00 4940,80 4935.59 271,30 1.45 5975003,84 590664.93 N 70.34144245 W 149,26421627 8483.81 90,22 22,23 4638,61 4970,37 4964.26 283.07 3.23 5975032.65 590676.35 N 70.34152079 W 149.26412077 8514.07 86,79 19,65 4639.40 4999.43 4992,51 293.88 14.18 5975061.03 590686,81 N 70.34159795 W 149.26403306 8545,64 86,31 19,70 4641 ,30 5029.90 5022.18 304.49 1.53 5975090,82 590697.06 N 70,34167901 W 149.26394695 8577,08 86.48 19.71 4643,28 5060,23 5051.72 315.07 0.54 5975120.48 590707.29 N 70.34175971 W 149.26386109 -. 8608.12 85.51 19,24 4645.44 5090.20 5080.91 325.39 3.47 5975149.80 590717.26 N 70,34183946 W 149,26377731 8635.11 86.13 19.47 4647.41 5116.26 5106.31 334.31 2.45 5975175.30 590725,87 N 70,34190884 W 149,26370491 8670.20 86.65 20,02 4649,62 5150.10 5139.27 346.14 2,15 5975208,39 590737.30 N 70.34199889 W 149.26360889 8701,55 88.67 20,80 4650.90 5180.28 5168.63 357,06 6,91 5975237,88 590747,87 N 70,34207908 W 149.26352025 8732,38 88,95 21,15 4651,54 5209.89 5197.41 368,10 1,45 5975266,79 590758.55 N 70.34215771 W 149.26343070 8763.46 88,95 21,36 4652,11 5239,71 5226,37 379,36 0.68 5975295.88 590769.47 N 70,34223683 W 149.26333927 8795.60 88,36 21.77 4652.87 5270.48 5256.25 391 ,17 2,24 5975325.90 590780.92 N 70,34231846 W 149,26324343 8829.39 86,89 22.68 4654.27 5302.71 5287.50 403.94 5,12 5975357.30 590793.31 N 70,34240383 W 149.26313979 8860,88 85,72 22.54 4656.30 5332.64 5316.51 416.02 3.74 5975386.45 590805,04 N 70.34248308 W 149.26304174 Schlumberger Private V-202 ASP Final Survey,xls Page 5 of 6 6/4/2003-3:45 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVD vSec W-S EI-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8889,55 86.44 22,14 4658.26 5359,92 5342,97 426.90 2,87 5975413,03 590815.59 N 70,34255535 W 149,26295351 8923.26 87,20 21,80 4660.13 5392.09 5374.18 439.49 2.47 5975444.39 590827.80 N 70,34264062 W 149.26285131 8934.67 87.40 22.42 4660.66 5402.97 5384,74 443.78 5,70 5975455.00 590831 .96 N 70,34266947 W 149.26281649 8985,00 87.40 22.42 4662,95 5450.91 5431.22 462.95 0,00 5975501,70 590850.57 N 70,34279644 W 149.26266086 ~ V-202 ASP Final Survey,xls Schlumberger Private Page 6 of 6 6/4/2003-3:45 PM Customer Well No Installation/Rig Data Surveys Received By: ) MWD/LWD Log Product Delivery BP Exploration (Alaska) Inc. Dispatched To: V-202 Date Dispatche Nabors 9ES Dispatched By: )0 j -0 ì 7 Lisa Weepie 2-May-03 Nate Rose No Of Prints No of Floppies 2 ~~-J7)a~ I_~,~ 1/ - /) :; LWD Log Delivery V1.1, Dec ~ I.. . Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 1, ~ ) \~\ IT ß\ì~ re (IT ~ [ß~/ [þ\ ~ ~1 !Æ / Q,!) lJlJ\\ J Lb wJ J Lb ru c~ iN dL /1 A.I,A.~IiA. OIL AND GAS . CONSERVATION COMMISSION / Lowell Crane ,/ Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 FRANK H. MURKOWSKI, GOVERNOR 333 W, TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe bay Unit V -202 BP Exploration (Alaska), Inc. Pennit No: 203-077 Surface Location: 4820' NSL, 1848' WEL, Sec. 11, TI1N, RIlE, UM Bottomhole Location: 4959' NSL, 1393' WEL, Sec. 02, TI1N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit 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 right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, /è-~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this 1. 'Bday of April, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environm~ntal Conservation w/o encl. Exploration, Production and Refineries Section Hole 48" 13-1/2" 9-718" 6-3/4" , STATE OF ALASKA ..... . ALAS~·,.. )OIL AND GAS CONSERVATION COI\".,)SSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 1m Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 82.3' Prudhoe Bay Field / Orion / 6. Property Designation (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / V-202 9. Approximate spud date 05/01/03./ Amount $200,000.00 14. Number of acres in property 15. PrQPosed depth (MD and TVD) 2560 /8952' MD / 4652' TVDrkb 17. Anticipated pressure {sE7 20 AAC 25.035 (e) (2)} 96 0 Maximum surface 1497 psig, At total depth (TVD) 4300' 11927 psig Setting Depth Top Bottom MD TVD MD TVD 29' 29' 109' 109' 29' 29' 2872' 2757' 29' 29' 5816' 4608' 5716' 4590' 8952' 4652' 'vJ6h- 'fr.:~/z-oo~ <:~ \.} ~(~\ 1 a. Type of work 1m Drill 0 Redrill ORe-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 x = 590453, Y = 5970066 4820' NSL, 1848' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval x = 590001, Y = 5973143 2622' NSL, 2260' WEL, SEC. 02, T11 N, R11 E, UM At total depth x = 590838, Y = 5975490 4959' NSL, 1393' WEL, SEC, 02, T11 N, R11 E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well / ADL 028238,320' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 1100' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casing Weiaht Grade CouDlinQ 20" x 34" 215.5# A53 Welded 10-3/4" 45.5# L-80 BTC-M 7-5/8" 29.7# L-80 BTC-M 4-1/2" 12.6# L-80 IBT-M Lenath 80' 2843' 5787' 3236' Quantity of Cement (include staQe data) ,260 sx Arctic Set (Approx.) 585 sx PF 'L', 348 sx Class 'G' 532 sx Class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED APR 2 3 Z003 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments 1m Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 1m Drilling Program 1m Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 1m 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michaej,Triolo, 564-5774 21. I hereby certify that the fore g is true anJ.c~. . ,.co.rrect to th.,e. best '0. f. m. ..y knO.W.I.e. dge Signed Lowell Crane cf'L4 L f-Y ~ Title Senior Drilling Engineer ; Ç()mmissic)n·~seØnly. Permit Number API Number 203 - 07.7 50- O¿7 - .2. 3/S3 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes RI No Required Working Pressure for BOPE 0 2K 0 3K Other:T€~t- 1,;o1>E t-c ~ç<9C J:1~~. Approved By 1\ r/v)/"vtP-¡;l.",- ¿./l-. 0 r" '~~1i~ifn,'{ J Form 10-401 Rev. 12-01-85 :. r\ t U,i t ~ \J r. Prepared By NameINumber: Terrie Hubble, 564-4628 Date 4 - 23-- a3 Ap~~O~1 DJ~ .3 See cover letter 'f ( <-> "'ð ( v for other requirements Mud Log Required 0 Yes t2SJ No Directional Survey Required gJ Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU by order of the commission Date f!2~Ó) Submit In Triplicate Well Plan Summary ) Greater Prudhoe Bay Orion V-202 Permit ') I Well Namê:·.I"·V~202 . I I Type of Well (producer or injector): I SH Horizontal Producer Surface Location: 4,820' FSL, 1,848' FEL, Sec. 11, T11 N, R11 E _____- X = 590,453.17 Y = 5,979,065.80 2,622' FSL, 2,260' FEL, Sec. 2, T11 N, R11 E /" X = 590,000.64 Y = 5,973,143.09 Z = 4,505' TVDss 4,9591 FSL, 1,393' FEL, Sec. 2, T11 N, R11 E /' X = 590,837.76 Y = 5,975,490.33 Z = 4,570' TVDss V-202 Target Start: V-202 Target End: I AFE Number: I ORD5M3525 I Rig: I Nabors 9ES I Estimated Start Date: I May 1 st 2003 I Operating days to complete: 116.95 MD 18,952' I I TVDrkb: TD I 4,652' I I Max Inc. I 96° I I KBE I 82.30' Well Design: SH Grassroots Schrader Horizontal Producer. /' 4-Y2" BTC-M, L-80 Completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: V -202 50-029- ????? Development - Orion Schrader Horizontal Producer New well, 20" X 34" insulated conductor /' 1,927 psi @ 4,300' TVDss (8.6 ppg EMW). Underpressured due to W-203 offtake. 84°F @ 4,505' TVDss Estimated Mechanical Condition V-202: Nabors 9ES: Conductor: Cellar Box above MSL = 53.8' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: 700 mstb 1 ,375 bopd 975 bopd Final 3/25/03 ) Materials Needed Surface Casing: 2,900' 1 each 25 each 1 assembly 1 lot Intermediate Casing: 12,450' 1 each 60 each 1 0 each 2 lots 3 each 2 each Production Liner: 3,250' 160 each 7-%" x 4-¥2" 4-¥2" 1 each L-80 Completion: 5,000' 1 each 1 each 2 each 1 each 1 each 1 each 3 each 1 each Surface and Anti-Collision Issues Greater Prudhoe Bay Orion V-202 Permit ) 10-3,4",45.5#, L-80 BTC Casing 10-3,4", BTC Float Shoe and Float Collar 10-3,4" x 13- ¥2" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 10-3,4" casing pups 5',10',20'. 7-%" 29.7# L-80 BTC-M Casing 7 -%" BTC-M Float Shoe and Float Collar 7 -%" x 9-%" Rigid Straight Blade Centralizers 7 -%" Stop Rings 7-%" casing pups 5',10',20' 7-%" RA Tag 7-%" 29.7# L-80 BTC-M Casing Short Joint 4 Y2", 12.6#, L-80, IBT -Mod Slotted Liner 4 Y2" x 5 3,4" x 8" Straight Blade Centralizers Baker ZXP Liner Top Packer Baker guide shoe Halliburton XN-Nipple (2.75" 10) 4-Y2" 12.6 Ib/ft, L-80, BTC-M tubing Baker PRM Production Packer 7" X 4-¥2" Halliburton XN-Nipple (3.688" 10 with 3.456" no go) Halliburton X-Nipple (3.813" 10) 4-Y2" Baker CMO Sliding Sleeve 11" X 4- ¥2" FMC tubing hanger 4-1/16", 5m Cameron Tree Cameo 4-Y2" X 1" KBMG Gas Lift Mandrels 4-Y2" WLEG Surface Shut-in Wells: V-104i and V-1 01 need to be shut-in for the rig move on and off V-202. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. /' Close Approach Well List: / Well Name Ctr-Ctr Distance V-108 61.95-ft V-101 26.86-ft V-102 90.50-ft V-201 69.91-ft V-104 26.33-ft V-107 50.30-ft Reference MD 249.98-ft 399.88-ft 649.42-ft 846.90-ft 999.83-ft 1,545.38-ft Mud Program 1"'5 -Ill.·· "-' G Ir- ~ Surface Hole Mud Properties: Interval I Density (ppg) Funnel vis 0- 1,700 8.6 - 9.2 250 - 300 1,700 - 2,500 9.0 - 9.5 I 200 - 250 'I 2,500 - 2,865 9.3 - 9.5 I 200 'I. .ïft; ~ntermediate Hole Mud Properties: ~r Interval I Density (ppg) / Funnel vis IntervÎtlf~ 9.0 - 9.2 45 - 55 ~ Production Hole Mud Properties: Interval I Density (ppg) Stability Interval 9.2 /" 650 - 900 YP 50 - 70 30 - 45 30 - 40 YP 26 - 30 YP 18 - 25 Allowable Deviation 57.49-ft 20.38-ft 80.03-ft 57.80-ft 11.82-ft 29.05-ft Precautionary Comment Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) I Spud - Freshwater Mud Tauo PH Plastic Vis FL 10 - 18 8.5 - 9.0 20 - 45 NC - 8 8 -16 8.5 - 9.0 20 - 40 8 9 - 14 8.5 - 9.0 14 - 20 5.5 - 8 I Freshwater Mud (LSNO) PH: 9.0 - 9.5 Tauo PV API Filtrate MBT 3 - 6 12 - 18 4 - 6 < 20 Oil: H20 Ratio PV API Filtrate MBT 80:20 15-20 4-5.5 <6 2 Final Approved Greater Prudhoe Bay Orion V-202 Permit ) ) Formation Markers : Formation Tops "Ft TVDss " ""FtMD Ft TVD Pore psi . EMW (ppg): ." Hydrocarbons SV6 885 968 967 410 8.9 No SV5 1,545 1,631 1,627 710 8,8 No Base Permafrost 1,695 1,785 1,777 No SV4 1,675 1,765 1,757 770 8,8 Poss, Gas Hydr. SV3 2,075 2,188 2,157 950 8.8 Poss, Gas Hydr. SV2 2,255 2,391 2,337 1,030 8.8 Poss, Gas Hydr. SVl 2,540 2,757 2,657 1,175 8.9 Poss. Gas Hydr. UG4 2,840 2,946 2,822 1,245 8.4 Yes - Heavy Oil f. 1..- UG4A 2,875 2,986 2,857 1,260 8.4 Yes - Heavy Oil UG3 3,150 3,380 3,202 1,420 8,7 Yes - Heavy Oil UGl 3,650 1,640 8,6 Yes - Heavy Oil Ma 3,880 1,765 8.7 Yes Mbl 3,940 1,785 8.7 No - Water Mb2 4,010 1,815 8.7 Yes Mc 4,070 1,840 8.7 No - Water Na 4,135 1,880 8.7 No Nb 4,160 1,905 8.8 Yes Nc 4,205 1,910 8.7 Yes OA 4,300 4,971 4,382 1,927 8.6 Yes OBa 4,360 5,137 4,442 1,945 8,6 Yes OBb 4,400 5,261 4,482 1,970 8,6 Yes OBc 4,455 5,460 4,537 1,986 8,6 Yes OBd 4,505 5,696 4,587 2,008 8.6 Yes TD 4,570 8,952 4,652 2,044 8.6 Yes OBe (not reached) 4,570 2,035 8,6 Yes OBf (not reached) 4,610 2,062 8.6 Yes OBf_Base (not reached) 4,655 2,082 8.6 Yes Casingffubing Program 48" 13- Y2" 9-%" 6-%" Tubing Csg I / WtlFt Tbg O.D. 20" X 34" 215.5# 10-%" 45.5# 7-%" 29.7# 4-Y2" 12.6# 4-Y2" 12.6# Grade Conn Length Top MD I TVDrkb 29' / 29' 29' / 29' 29' / 29' 5,716' / 4,590 29' / 29' Bottom . MD I TVDrkb 1 09' / 1 09' 2,872' /2,757' 5,816' / 4,608' 8,952' / 4,652' 4,850' / 4,330' Hole Size A53 . Welded /'" 80' L-80 /' BTC-M 2843 L-80 BTC-M 5,787 L-80 IBT-M 3,236 L-80 IBT-M 4,821 Cement Calculations Casing Size 10-% -in 45.5-lb/ft L-80 BTC surface casing Basis 250% excess in permafrost. 30% excess below permafrost. Top of tail cement 750' MD above shoe Total Cement Vol: Wash 20-bbl Water Spacer Spacer 75-bbl 10.5-lb/gal Alpha spacer Lead 432-bbl, 585-sx 10.7-lb/gal Permafrost L - 4.15 ff'/sx / (cement to surface) Tail 71-bbl, 348-sx 15.8-lb/gal Premium G 2% CaCL- 1.15 ftJ/sx /' (top of tail at 2,122-ft MD) Temp I BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. 3 Final Approved , ) Casing Size 7-% -in 29.7-lb/ft L-8Ö BTC intermediate casing Basis Top of tail cement 700-ft MD above top of Schrader Ma-sand. 30% excess over gauge. Total Cement Vol: Wash 5-bbl Water Spacer 25-bbl 1 0.2-lb/gal Alpha Spacer Tail 116 bbl, 532-sx 1 Premium G + LXT - 1.22 ftJ/sx -- of tail at Ma: MD Temp BHST :::::: 90°F from SOR, BHCT 80°F estimated by Halliburton Greater Prudhoe Bay Orion V-202 Permit ') 10-3,4" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1 ,872' MD (1,000' MD above the shoe). b) This centralizer program is subject to change pending actual hole conditions. 7-%" Casing Space Out a) Space 7-%" casing out with pups and long/short joints as required to place the top of a long full joint - 5- 15' above the top of the OBb, OBa and OA sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. b) Place 1 RA tag above the first window, 1 RA tag above the second window, and 1 RA tag above the third window. RA tags to be spaced out -80' above window depth. c) Emergency 7-%" casing slips can be used instead of the 7-%" mandrel hanger if required for space out. 7-%" String Centralizer Placement a) Centralizer size: 7-%" X 9-%" (this is different then the norm of "IA" under gauge hole) b) Do not run centralizers on the window joints spaced at the top of each sand. c) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints (see illustration at the end of the wellplan). d) With the exception stated above, alternate 1 rigid straight vane cenralizer floating across a full joint and 2 rigid straight vane centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar up to 4,651' MD (320' MD above the top OA sand). Then continue with 1 rigid straight vane centralizer per joint floating to 3,565' MD (700' MD above Ma sand). Zonal isolation with cement is required between base of the OBb to the top of the OA sands. The centralizer program is subject to change pending modeling and hole conditions. See attached drawing. 4- 112" Slotted Liner Centralizer Placement a) Run 2 straight blade rigid centralizers per joint, one floating on the top half and one on the bottom between a stop collar. Tack weld the stop collar in place to prevent movement while tripping in the hole. Bit Recommendations BHA Number Surface Surface Interm. Prod. Hole Size and Section 13- Y2" 13-Y2" 9-%" 6-%" Depths (MD) Bit Type Nozzles K-Revs Hours 0' -1,785' 1 ,785' - 2,872' 2,872' - 5,816' 5,816' - 8,952' Hughes MXC-1 Hughes MXC-1 Smith S-73 Secu rity FM2643 2x20 1x14 1x12 2x20 1x14 1x12 6x14 3x15 4 Fi nal Approved )- Survey and Logging Program Greater Prudhoe Bay Orion V-202 Permit ') 13-%" Hole Section: Open Hole Drilling: Cased hole: 9-¥s" Hole Section: Open Hole Drilling: Open Hole: Cased Hole: 6-3,4" Hole Section: Open Hole Drilling: Cased Hole: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) MWD I GR None Surveys will need to be IFR + MS corrected real time MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) I AIM DPC MDT (20 pressures + 8 Samples) USIT Bond Log (only as contingency if poor cement job) Surveys will need to be IFR + MS corrected real time MWD I GR I Res I Azimuthal Den I Neu (Den/Neu recorded only) I AIM None Motors and Required Doglegs BHA No. 1&2 Motor Size and Motor Required 9-%" Anadrill A962M344SSP Mud Motor, 1.S0 ABH with 12-14" string stabilizer 6-3,4" Anadrill A67SM4S70XP Mud motor, with 1. 1So ABH with 7.0" string stabilizer 4-3,4" Anadrill A47SM4S70XP Mud motor, with 1 .so ABH with S.O" string stabilizer 3 4 Flow Rate RPMs 400 - 6S0 40 - 60 gpm SOO - 600 60 -120 gpm 2S0 - 300 60 -100 gpm 8°/100' build and turn & subsequent geosteer Required Doglegs 1.SO - 2.so/100' initial 3°/100' final build 4°/100' build and turn Well Control Well control equipment consisting of S,OOO psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- Maximum anticipated BHP: 1,927 psi @ 4,300' TVDss ~. Schrader Maximum surface pressure: 1,497 psi @ surface /' (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · · · Planned BOP test pressure: · Planned completion fluid: 3,SOO psi (the 7-%" casing will be tested to 3,SOO psi) Estimated 9.2 ppg Brine /6.8 ppg Diesel Planned BOPE Test Pres. 3,SOO/2S0 psi Rams & Valves 3,SOO/2S0 psi Annular /' Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. S Final Approved ) ,Drillina Hazards and Continaencies Greater Prudhoe Bay Orion V-202 Permit ) POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be underpressured at 8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas hydrates are present below V-pad, but have not been a significant issue thus far during V-Pad drilling. If hydrates are encountered follow the recommended practice and apply good drilling operational practices. III. Lost Circulation/Breathing A. Lost circulation is unlikely within the Schrader interval. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's i.e. Seabee. IV. Kick Tolerance/Integrity Testing A. The 10-%" casing will be cemented to surface. B. The 7-%" casing will be cemented with 15.6:¡b/ Tlail cement to 700' MD above the Ma sand -3,565' MD. C. The Kick Tolerance for the surface casing is 2. bbls with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. If the LOT is less then 11.5 PP . Wæt he kick tolerance will be < 50 bbls. D. The Kick Tolerance for the intermediate casing is' fin' with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. If the FIT is less then 9.6 ppg EMW, n the kick tolerance will be < infinite. E. Integrity Testing ············mllt:'i?øi!nîli·.i. 10-% -in shoe 7 -% -in shoe 20-ft minimum from 10-%--in shoe 20-ft minimum from 7 -%--in shoe .·..m.$t!'t~pê·:H ···;!'...:eI\llW..(IJ¡j~åâì)·····.·.... LOT 11.5 minimum FIT 11.5 minimum V. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen Sulfide ./ A. V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S has been measured at V-Pad from wells tested as recently as January 2003 with hand held H2S meters. There has been no seawater injection at V-Pad to date. VII. Faults A. One fault is planned to be crossed up in the UGNU after the surface casing shoe. This fault has been crossed on numerous wells and is not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 3,060' MD 3,684' TVD 2,840' TVDss Th row: 110' South West CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Fi nal Approved Greater Prudhoe Bay Orion V-202 Permit ) ) Drill and Complete Procedure Summary Pre-Ri2 Work: 1. A 34" x 20" insulated conductor has already been set and surveyed. 2. Weld an FMC landing ring for the FMC Gen S Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and simops production. RiQ Operations: 1. MIRU Nabors 9ES /' 2. Nipple up diverter spool and riser. Function test diverter. PU 4" OP as required and stand back in derrick. ~ 3. MU 13-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2,871' MO 12,7S7' TVD. The actual surface hole TD will be +1)00' TVD below the top of the SV1 sand. 4. Run and cement the 10-3,4", 4S.S# L-80 surface casing back to surface. Will not use TAM Port collar. S. ND drilling spool and riser and NU casing 1 tubing head. NU BOPE and test to 3,SOO psi. /' 6. MU 9-%" directional drilling assembly with MWD/GR/Res/Den/Neu/AIM/PWD and a Weatherford Orill-Mill at±800' from the bit in the HWDP section RIH to float collar. Test the 10-3,4" casing to 3,SOO psi for 30 minutes. /' 7. Drill out shoe track. Circulate and condition mud. Displace well to new LSND drilling fluid. Drill 20' of new formation below rathole and perform an LOT. LJ 8. Directionally drill ahead to TD (~120' MD below the Top OBd) as per directional profile to ~ MO 14,607' TVD. 9. POOH for open hole OPC MOT, standing back 4" OP, LD drilling BHA 10. RU Schlumberger and run a OPC MDT to collect fluid samples and pressure readings in the OBd, OBc, OBb, OBa, and OA sands. Sample depths to be determined based on real time GR/Res data (planned to acquire 20 pressures and 8 fluid samples). 11. MU 9-%" cleanout assembly and RIH to TD. Work tight spots as seen. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. 12. POOH. Standing back 4" drillpipe. Retrieve bowl protector. /' 13. MU and run 7-%" 29.7# L-80 BTC long string casing to TD. Cement in one stage to 700' MD above the Schrader Ma (4,264' MD) sand. Bump plug with MOBM. Land casing on mandrel hanger. 14. Clean pits for displacement. Freeze protect 7-%" x 10-3,4" annulus with dead crude to 2,200' TVO. 1S. PU 6-3,4" directional assembly with MWO/GR/Resl Azimuthal Den INeu/AIM/PWD and RIH to the float collar picking up 4" DP on the way. Test the 7-%" casing to 3,SOO psi for 30 minutes. / 16. Drill out shoe track. Circulate and condition Versapro MOBM 17. Drill 20' of new formation below rathole and perform an FIT to 11.S ppg EMW. /" 18. Directionally drill ahead to TD geosteering through the OBd to TD at 9,160' MD 14,662' TVD (prognosed). 19. Perform wiper trip, circulate and condition mud and POH. Lay down excess drillpipe. 20. MU and run 4-%" 12.6# L-80 BTC-M slotted liner with hanger and liner top packer to TD. /' 21. PU off liner hanger and circulate and condition mud. Clean pits for displacement. 22. Displace over to 9.2 ppg KCL brine above liner top packer. 23. MU 4-Y2" 12.6# BTC-M, L-80 completion assembly and RIH. See completion schematic for details. 24. Land tubing hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. /' 2S. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,SOO psi and annulus to 3,SOO psi. Shear DCK-1 valve. 26. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to S,OOO psi. 27. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7-%" casing annulus valve. 28. Install BPV. Secure the well and rig down 1 move off Nabors-9ES. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod 1 RHC plug. / 2. Pull out DCK-1 shear valve, install DV in the mandrel as per the PE. 3. Test OBd for production as per the strategy. 7 Final Approved ') Greater Prudhoe Bay Orion V-202 Permit :m::llm:,:llaL_II,IUII:,lm_lllc~aIC,all:alll:cml:mmmHII:UIcm~H~MW,II,:mmlll:I:II,:'¡;;¡~¡:;;»IIIII~~I'laac:+:::""J""""-.M.m.m·.....","""·..""<,_m:llllllm: .....·.......·..···',UUI'I·"1··~:.'I~:.':~ _. I:: :11hI·~~:II_ Job 1: MIRU: Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-104i and V-101 will need to be shut in at the surface prior to the V-202 rig move. V-108 and V-107 will not need to be shut in for the rig move. The well houses will need to be removed off of V-104i and V-101. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearby Wens Distance to Target Well Rig N9ES Wellhead Separation V-I04i 29.89 -0.11 V-I01 30.10 0.10 V-I08 60.11 35.11 V-I07 59.88 34.88 /" ~ V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S has been measured at V-Pad from wells tested as recently as January 2003 with hand held H2S meters. There has been no seawater injection at V-Pad to date. Reference RPs .:. l'Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" :l:1,.\~~,;¡w,'~I:I:i!l:I;I,~'I;I,IIo.W,':,o I¡"."\'~"~i;W;Ir' ;\,¡,~,,w:~~~¡m~ ,.,ÿ,~I,·,'I¡ ,I~\:,-I;'I;I,~"'\~~'I;I,~~W,~~·~~I!W,IAA"\\\ÿ;\.....,,,.,I, ,1:O,Ÿ.\"\"I;\""'; ,~~,1'.~~I,'.M'\'I":I:I;\W"\~-w,,..w.·,W;~~~~;"'I,1,ii\1'¡':,\';'~,*,~~~I:I:I:"~~~i'I:'(Ir~~~,I,;'-,~~~Ÿ,I,I¡,, ,,\\:.,~I;t.~~I:I;(I,~,1:I.M1:I;~¡¡¡,;":...w..''''~.,I",,,,¡,;,y,I..,I,IJ.'I,'~''¡;,''''''''''~'~''';'¡' ~',~~_ ".c, .'-';'-~"'.,- "',,; .~, ,,-.',_ ,~-, ,,' "~,,., ,.,.\, ..,-,.,,, ,,!!;,, ,,'" ,.",.". "., 'W,., ,¥" ....,...., 'w, ""'".""'....,.,;,.,.,,.,.,.....;~""T~'\>1Ir<:>"""1'r~~~~I;:M" , Job 2: Drill 13- Y2" Surface Hole: Critical Issues: ~ At V-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. ~ Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. Need to run a gyro to a minimum depth of 500' with a maximum depth of 1,200' MD. Magnetic interference is expected to be nonexistent by 1,250' MD. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Obiective is to keep DLS ~1 0 over planned. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm because of the 1.50 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 -700 GPM to increase hole cleaning. ~ Drill Pipe specs: from Premium classification, not New. Adjusted weight: 17.39 #/ft 4", 15.7#, HT-40, 15-1351 ID Collapse Burst Torsional Tensile 1000/0 3.24 18,593 psi 21,331 psi 33,600lbs 456,9001bs / 800/0 2.688(tool joint) 14,874 psi 17,065 psi 26,880 Ibs 365,520 Ibs ***Max Recommended MU Torque: 20,200 ft-Ibs Fluid Capacity: 0.419 gallft ***Min Recommended MU Torque: 14,100 ft-Ibs Fluid Displacement: 0.266 gallft ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. 8 Final Approved _. Greater Prudhoe Bay Orion V-202 Permit » Critical LWD Tools: It is crJical for the landing of this hole section to I ,,,ìe the GR to pick the top of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates the upper section of the SV1 sands. In order to do this the casing will need to be set -100' TVD below the top of the SV1 sand in the shale. Reference RPs: .:. lIPrudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations ~;m:':II::I!':I:::'~nll'::IICI:I"::--::\iI!mm~I'II '::I:ai!I~'m:'~III'_TI:m':n:II:::I:_:II__:'I!I: ::::::llr-'1:-;::::!'::::I:::I;II:'I:IIII::'::IIIIII:lllomllllll_:11:.;.;;~;.;.m;;,;,:-"",mm~;~:I:I:I:m:'m!:I":'lm:::III::lm::'::I:11m__':_I.":--:::-:I--::::-::'::II::I::I-:-::'::I::I:::I:I::-IW-I::::'-:I':-':::I::II:I::-:m:mmmm,rmllllm::,:mr1"'111'11111:1.1::11111:--:'1::11:'1::-:1:'1:--:11:;111111:'llnll!'::'lm:llIl~IIIII : I::I:'I:::::I:::lllnlla'I:'::'-:1_ Job 3: Run 10-3,4" Surface CasinQ: Critical Issues ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to insure circulation is attained at TD at the desired cementing rates without losses. ~ Casing drift: 10-3,4" special drift casing is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 9-%" bit, i.e. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar will not be utilized. ~ Losses during cement job: At V-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is 12.5-lb/gal EMW. Follow the Halliburton recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" ~W~.v,(··· _"w.v....N._..'.,¡_....m...'.v____m.._.~_~,¡-.'."Vn~n.....·..__m~._---",. ·v",_· .,_.--~ . ,~. ·,vv_····-"n "·~....·.._,,,·'.'.;.{n .o·:.·,....'*"ldl-.·: ;;;~:m:;:-w+x~"o;,..o.'...~~;:~;,~_«w.,MIW'............·,..........,....,-'''-......,.-·n_'....'.'...-_m,¡.--.m-'-._·v,·,.......'-..¡.~....-'WVM.,-,..'.' :;;::11:111:_';11..'_ -;:;wtr.::..··.........._m_~·;,m;~::::_ Job 4: Drill 9-Va" Intermediate Hole: Critical Issues ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the expected Schrader reservoir pressure of 8.8 ppg and a 9.2 ppg mud, an 11.5 ppg leak-off will provide just over 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off-set drilling data on V-Pad, a minimum leak-off of 12.5 ppg is expected at the 10-%" shoe. ~ 7-%" casing landing point: The landing point for the 7-%" casing will be determined by depth based on changes in GR/Res curves associated with the top of the OBd sand. After seeing the top OBd, TD will be picked based on drilling 120' MD past this pick. This footage is critical for future wellwork. If tops are coming in 100' or more out from prognosis, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that high torque values, in the 10,000 to 13,500-ftlb range can be expected by section TD. Do not use lubricants within this hole interval due to the MDT logging requirements. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 BU to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. The landing of this well will depend on picking the base OBf sand which will be picked by Gamma Ray. If we 9 Fi nal Approved ) loose the GR tool, we will need to trip for it. Faults: There is one major fault that will be crossed in this hole section: Greater Prudhoe Bay Orion V-202 Permit ') ~ Fault #1: 3,060' MD 3,684' TVD 2,840' TVDss Throw: 110' South West ~ Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements and junction requirements. It is critical to design a BHA to minimize inclination walking tendencies and thus minimize wellbore tortuousity. DLS should be kept :::;10 over planned. ~ Survey program per JORPS: Dogleg Severity Survey Frequency <1 °/1 00' 90'(Every stand, not exceeding 100') 1 ° - 5°/100' 90'(Every stand, not exceeding 100') >5°/100' 30'(Every joint) Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. ~,wm,:;'!,:;,:,:,:~.~".;;· fu,:.;o:.x.~.;.:.~~Y.»:~~.:v.:)~X(.),»)~~ . ¡~)~¡)):.:.;~)~;.:.m:;:;fflffl,:;,:,:;;· Job 5: LOQ Intermediate Hole (DPC MDT): Critical Issues ~ The base plan consists of one DP conveyed MDT run to obtain pressure readings and fluid samples in the OBd, OBc, OBb, OBa, and OA sands. Sample depths will be determined based on real time GR/Res data. It is planned to acquire 20 pressures and 8 fluid samples from these sands and or the sands above the 0 sands if time allows. ~ The minimum fluid sample requirements would be acquire fluid samples from the OA, OBa, OBb and OBd sands. Pressure requirements would be to obtain pressures in the upper sand intervals that we did not get samples in, Le. the M, N, and Ugnu sand intervals to complete the Schrader / Ugnu pressure profiles. ~ Due to the 9-%" hole size a modified open hole dual packer will be needed to obtain the isolation during the fluid sampling. Ensure Schlumberger has the right hook-up to conduct this logging operation in the 9-%" hole. ~ Run an open hole caliper to redefine hole volume for cement excess. ~ Ensure a back-up tool and packer assembly is available in case a failure is encountered. Reference RPs .:. IDrillpipe Conveyed Logging" .:. Follow Schlumberger logging practices and recommendations \~mUamU1il:nllllllm:ml_ml:nlillmlll!mlllmlmmmll!::lUllllllm:mmml!~;;;;';'¡,;,~,"'WIIII.H..llltl. .I..WIII" : ~llmlm__--ITlm::IWII!:IIU_L .11:l'-::mmml.l.CL ---11111111:11.1.1. .:..m:nlllllmHUT .I Job 5: Run and Cement 7-%" Intermediate CasinÇl Critical Issues >- Cement Job: It is imperative to achieve a good cement job on this well due to the water wet M sands and the junction requirements. Good zonal isolation of these sands is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job between the sands if any problems are encountered during the cement job. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Casing Space out: There are 4 important space out zones for this casing run: o There must be a long full joint of casing just starting above the top of the OA, OBa and OBb sands so that the multi-lateral junction window can be milled out as close to the top of the respective sands in the top/middle of a full joint of casing. Run full casing joints across the OA, OBa and OBb sands. Any casing pup joints required for space out should be placed below the base of the sands. o The shoe must be within 10 feet of the bottom when the casing is cemented in place. 10 Final Approved Greater Prudhoe Bay Orion V-202 Permit o The mandrel hanger ~ust be spaced out correctly at surface if ..1 to be used. Emergency slips may be used if necessary to achieve proper space out. ~ Freeze Protection: Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7-%" x 10-3,4" casing outer annulus with 87 bbls of dead crude (2,200' MO, 2,168'TVD), the hydrostatic pressure will be 7.8 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 100 psi underbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping ~' permits.) ~ Centralization/Differential Sticking: See centralizer strategy under Section 3: Drilling Program Overview. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 4 RA tags placed in the 7-%" casing for depth control. Placement strategy is....80' above each of the respective sands: Pip # 1: Top OA sand, Pip #2: Top OBa sand, Pip #3: Top OBb sand, Pip #4: Top OBd sand. ~ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7-%Ucasing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 7-%" BTC casing is on the rig floor Reference RPs .:. tllntermediate Casing and Cementing Guidelines" .:. 'Freeze Protecting an Outer Annulus" »»~"",IÌ..-M~~« ,:;;;~~_:'¡')(>··"···M/'UJ~'-""'_"·'_~·<·'___I·rJ·~_'·..·n ·N__·mu..."....."mu'm~"·W-........u....__K ..··"'''''''''N.''''''..·..._m...J.-'.. ''''''''''',.....''1 ............ ···.U^_Nn..J""____~··..·:..v..·:·:·:·~~~~:_,<:_,~:....M....,~~N"'''.....J...µJ""",......>J<>~. .........:4t_w.w-~.¡.,.~+I~y)p".,._J -;:1!1:1:1::1:11.;.,.........w;~1'111:>",..:-,.,.,.....¡~ Job 6: 6-%" Lower Lateral (OBd Sand) Critical Issues ~ Geosteering: Geosteering in the lateral intervals is expected to be the most challenging aspect of this well. ....- Anadrill AIM will be used and should help mitigate some of this challenge. A 1.50 bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this interval. There will be a rigsite geologist on location to help with interpretations. The projected formation sand thickness and 'sweet spot' thickness for the OBd sand is listed below for reference: o The OBd sand target is expected to consist of a 20 to 30 foot thick net sand interval, which lies in the upper half of the 65 foot thick OBd parasequence. Within the total 20 to 30 foot thick OBd net sand/net pay target interval, the primary OBd target interval consists of an 8 to 14 foot thick high permeability sand body (300-900 md.) which lies ....15 feet below the OBd sand top. The V-202 OBd high angle well section is targeted to drill within this high permeability interval over approximately 60- 70% of the total length of the V-202 polygon. ~ Surveying: Survey density is critical to achieve vertical positional certainty. It is recommended to survey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This survey density should alleviate the errors associated with vertical section creep. ~ ECD/Hole Cleaning: Utilize PWO to monitor for good hole cleaning and ECO trends. Cuttings will tend to dune up at the window due to hole geometry. Planned ECD hardline 11.5 ppg EMW. ~ FIT: An FIT of 11.5 ppg EMW is required at the 7-%" shoe. The expected frac gradient for the Schrader is 12.5 ppg EMW. ~ Target Constraint: It is imperative that we do not cross the north eastern boundary of the geological target as there is a major fault beyond the geological polygon. Reference RPs: .:. tlprudhoe Bay Directional Guidelines" .:. tlStandard Operating Procedure: Leak-off and Formation Integrity Tests" 11 Final Approved ) Greater Prudhoe Bay Orion V-202 Permit a___. ..L"",,,,,_,,,,,,,,,,,,,","",,,,,,,,,, ~::·,"~m::II:tm:+aII__:'«+I":I~I:I:I,:,:I',:I!.Cml,~a:lll!m~:::::~+~:::.;;¡;;.¡:«~mm:I=:~~:lall:lml,I::11:~.II:~C:lmll:m::::IWlmm~:_mlll::ma:I,I_II_I:_al:m~=::::~;:::''''''~il":.I!.::..I Job 7: Run 4-11211 Slotted Liner (OBd Sand) Critical Issues ~ Liner to bottom: It is imperative that we get this liner to bottom to allow for adequate space-out for the OBc lateral. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reserves possible for this section length. ~ Innerstring: The innerstring should not be needed to help insure the success of getting the liner on bottom. Innerstrings have not been used in Schrader Multilats in Milne for quite some time due to the lack of utilization and the extra weight associated with running them. The use of the innerstring will ultimately be as a contingency only based on actual hole conditions. ~ Centralizer Placement (5-%" OD): o See centralizer strategy on page 6. Do not run any in the liner lap. ~ 4-11211 Rams: Keep VBR's in. Can also utilize annular if necessary. /' ~ Have a Baker completion specialists onsite to engineer and supervise this liner job. 4 112", 12.6#, L-80 IBT-M 1 000/0 800/0 ID (drift) 3.833 Collapse N/A N/A Burst N/A N/A Tensile 288,0001bs 230,4001bs ~ Connection make-up information: o 4-112" IBT - makeup to position Reference RPs: .:. 'Wane Apply" :-;~(:;:;:;;;;;;:«-!¡;;I««««WC>'«<__..........-.-.._,. .m·~"""""w~a««·'I1___"'N....""w'¡'·(·"""~X*«~_~_~(>VJ"'J""""N....,.r",·"""+'W"w~«-MH+:~:~:;~~«o!(«<«""'W.W''''''''''''''''~:1;:·::-;~__~: :·::::·::·M.·~~~I:C:III':_ft~__ Job 12: Run 4-Y2" Completion: Critical Issues ~ Thread Dope: BOL 2000 NM or BOL 2000 is the BP approved thread compound for Carbon API connections. All IBT-M pipe should arrive on location with one of these two thread compounds. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. >- Shear Valve: We will switch from an RP shear valve to a OCR shear valve due to the RP shear valve failure on numerous wells. The OCR shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NU/Release RiCl: Critical Issues » See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. » Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 12 Fi nal Approved POST - COMPLETION a 0 TREE: FMC 4 - 1/16" 5M ( Orig KB elev (N -9ES) = 28.5' V -202 OBd Onl WELLHEAD: FMC Gen 5 System J it[ 11 ", 5M csg.head w/ 7" mandrel hanger & packoff 11" x 11 ", 5M, tbg spool w/ 11" x 4 -1/2" tubing hanger with control line ports 11" X 4 -1/16" Adaptor Flange 20" X 34" 215.5 lb/ft, A53 ERW Insulated I 109' Halliburton X- Nipple (3.813" ID) 2,200' TVD ■ Camco gas lift mandrel 4 -1/2" x 1" KBMG / With DCR Shear Valve in top mandrel 2,500' TVD, 2 & 4 joints above the sliding sleeve I ` 10 -3/4 ", 45.5# L -80 BTC Csg @8 Ali 4 -1/2 ", 12.6 lb/ft, L -80, BTC -M Coupling OD: 5.2" Drift /ID : 3.833 "/3.958" /„. , , RA Tag RA Tag \♦ 4.5" HES XD Durasleeve with 3.813 ID 7 -5/8 ", 29.7 #, L -80, BTC -M Casing Drift: 6.75" . 7" X 4.5" Baker PRM Packer Casing ID: 6.875" \ Halliburton X- Nipple (3.813" ID) RA Tag �,� � 4.5" WLEG — 4,850' 9.2 PPG Versapro MOBM below Completion RA Tag \4PI `, Halliburton XN- Nipple (2.75" ID) Baker ZXP Liner Top Packer & Hanger @ 5,716` MD `� "-'_ __ N iiiiimmiu i 7 -5/8" Casing Shoe @ 5,816' MD 6 -3/4" OBd Lateral 15,816' 8,952' I DATE REV. BY COMMENTS GP terPrxr l day 3/25/2003 MIK TRIOLO OBd Lateral Completion O E LL: V -L02 ML API NO: 50-029-XXXXX-00 Vertical Section Departure at 4.75 deg from (0.0, 0.0). (1 in = 1000 feet) ~ E;,dCrv358Ú.ïb 33a200- - - -:'-"33 §SOME! ~J2TVD- -, - - - - - - -, - - - - - - - - - 29.00" 325.1)0' F 846 departure I ¡ ~~~~-~ ~ ' 8O.oq- 6.90" az 2293 departure ! : ~ 7-5/8" Csg Pt5816 MD 460a TVD Cry 4/100 ~ ! 8000' 690' az 2412 departure 7251 MD 4602 ND End Cry ~ ~crv 81100 5836 MD 4612 ~ 88.94' 19.72' az! 7266 MD 4602 TVD End!Crv 80 00' 690" az 2431 departure 3803 departur¡. 8939' 20 14' az 8190 MD 4614 TVD .. Cry 4/100 6371 MD 4591 TVD ~ -- -- _3BjB-departur1L____8z.œ~21.13· ¡g- ___JD1A,jJ2::.Lnr_______ 95 7ff' 18 15~az 2953 departure . 4709 departure 8952 MD 4652 TVD ¡: j 8708' 2U3'az ~ ~~~ -- -- - - -- -- - - - - - --~":~ - 2L""'CN/ JO~"N 4JOO CN"'''¡' sJoo ~~~~ ~~-~ ~~~~ 95.7ff' 18.15' az 88.94' 19.72" az 89.39" 20.14' az 2670 departure 3038 departure 4649 departure Hold Angle 29.00° I 6000 ! Cry 4/100 5007 MD 4396 TVD ¡ ! 68.23' 340.93" az 1649 departife ~ ~ ~lffi4§tl··.;J1J~T'JD~~i~, 3 ~ ~ :: ~ -~ . . ",t;<~ :tt~. Õ-- -. - - _. /::. : .~I - .......k-""J:'f'L-' ~B! V : ~ End Cry 5003 Mq 4395 TVD I 68.23" 340.93" r 1646 departure o 1000 = ë= ë= -,.;:.- - ¡ 01 --------" ; SV3 2188 MD 2=571'\'0 Crv4/1003~MD 3732TVD _ 29.00" 325.þ<r az 995 departure ____._un - =¡t.ah~'fu~o-~t¥{ìö= Hold Angle 2ß,00° -. ..- ¡ SV1 2757 ~D 21357 TVD -- -. ------- ¡ SV2 2391 MD 2337 -rvo -, - -----.--.---..---- =1 ~ tffl.5 MÐ 'f15? -=FVD=;æs-Pe:m-1 i7ð5 ijb m7TvD= . . .._m.__.__m______m_...ly- -~~cI.~~~~~~rture .----.---- ¡ -------.--...---¡-- m__.____._m._..__m.__.~----------.---m. -.- -" - - - - - - ~ SV5 re31 ~ tê2Y1'"VD- Ndg 1.~100300 MD 300 TVD ____ 0.00" :165.00' az 0 departure Drp 1.51100 533 MD 533 TVD ____ 3.501165.00' az -7 departure End I)rp 767 MD 766 TVD ____ 0.001165.00" az -13 departure KOP jlkl1.5I1001100 MD 1100 TVD 'T~·~·~i~~~~~~~~e_- l B~ 2.51100 1233 MD 1233 TVD ' 2.T 355.00' az -11 departure Er!d Bkl1734 MD 1727 ~ 1151' 355.00" az 60 departure , J B~ 3/!.,00 !¥O ~D .!!I3O _~ J j 14.51' 355.00" az 86 departur~ -----.-.---,-..-..------- - -~_._----~..- ------------- . . ~------~_. ---_._._._.~_.-. ~._-~~~-- Schlumberger Structure: V-Pad Section At: 4.75 deg Date: April 15, 2003 BP Exploration Alaska V-202 OBd (P6) Prudhoe Bay Unit - WOA Client: Well: Field: VERTICAL SECTION VIEW f -1000 40004.... . 3000 -+... - - 20004·· -. -_._-~- 1000 -T...:::.....::.:. I I i 04·..- I i ! õ ... -+- T ........ ...... 0) ........ O)...J ~CI) 8~ o 0) ~ > II .8 .~ ro sg ..c.~ ......C\I Cow 0)- om ro~ o.¡..: .- 0) "äja:: > > O)~ ::JW L... ~ ~ ~ - .-..... - -1000 --. -.-.'00-"'1"- 2000 mooo__. _ 0 - 1000 - 2000 ......................- 3000 I I i I 1 I I I ! i i ······1···...·· ....... - 5000 I i i i i I I I I '1·······...······..'····...·...··- 4000 I ! ... - 6000 2000 I Schlumberger EAST »> .J-.-....--- -1000 «< WEST ·-·-·t--- 1000 --·1'··-··--··-···'·· o -.---...----..-.-,.-." Cry 8/100 ,···I,··,···~~~Ö·~º6:~1-~T.Y.º· .....,..... ··...i··..·...··.. î 2489N 587W I . Cry Al100 I I 3984 MD 3732 TVD AI 29.00' 325.00' az ; 1017N 228W i End CrY \ . I .u............... .... .¿.;.~8?;~~3.2;~~~ ~D .! y............. aSS ij ïï7W·..····..······I· ; I i ___ Cry Al100 i Bid 31100 ,~ . 3223 MD 30~5 TVD 1840MD 1830TVD bi 29.00" 355.qo·az 14.51'.1 355.00'az ~.. ..117 . 6..99N .59W.i 87 N P W \ 1 I 10-3/'" d.g Pt End bid I 2872 MD1 2757 TVD 1734!MD 1727 TVD 29.00' ~55.00· az --....~~r:ï~~~·~:.~-7.oo....-...m.oo.....m.. 00... \.~............._.__._.m_...~~:~o. .'.~.~.:TVD I 29.00' 35S.0Ò;oo;¡z.0.. Ndg UI100 264 N 21 W 300 ~q 300 TVD Bid 2.51100 i ~.~O 0 ~65.oo' az 1233 MD 1233 TVD i 2.00' 355.00' 8Z i Drp 1.51100 115 3 E . ¡ 533 MD 533 TVD End Drp ; OP :: , 3.50" 165 00' 767 MD 166 TVD Bid 1.51100 I 75 2E' 8Z 0.00' 16$.OO'az 11~MD 1100TVD ! 145 4 E i 0.00 355.00" 8Z . ¡ 145 4E ....................................".............. End Cry 6458 MD 4587 TV) 88.94' 19.72' az :¡Ö83..¡;¡....41S\iV....·.. ........ Cry Al100 6371 MD 4591 TVO 95.78' 18.15' az 3000 N 444 W ' 7-518" Csg Pt 5816 MD 4608 TVD 80.00' 6,90' az 2469 N 589 W Cry Al100 7251 MD 4602 TV) 88.94' 19.72' az 3829N 148W End Cry 6078 MD 4620 -VD 95.78' 18.15' az 2723 N 535 W ~ C· CV S ::;¡ ·S ..........~............ ~ :B ~ .....7J..................r¡.... .................... ··i"ïië'iïr·mmm.. 8190 M~ 4614 TVD 87,08' t 1.13' az I 4710 N i176 E i . Cry 4/100 I . 8128 MDi 4612 TVD I~.[~?~~~~~. 1000 r I ·····ií:ïi;¡::1ï:z;~·[¡;r··..··· 8952 MD þ652 TVD 87.08' 21i13' az 5420 N 450 E o I E 25.57° -1000 I 1 in = 1000 ft 15-Apr-2003 Scale: Date: PLAN VIEW Client: BP Exploration Alaska Well: V-202 OBd (P7) Field: Prudhoe Bay Unit - WOA Structure: V-Pad ..................... Cry Al100 5007 MD 4396 TVD 68.23' 340.93' az 1699 N 539 W True North End Cry 5695 MD 4587 TVD 80.00' 6,90' az 2351 N 604 W .____..~~..__..___..m.__ -1000 _. ...... .--_o--oJ..-... -2000 ...... .~......_.~.._......_._...,..._,.~-_..._.- ~ Mag Dee ) 0-'00'" 1000 _m... .........·1..· I I- :::> o CJ) V V V 2000 _............. 3000 _.......... 4000 _............................ ^ ^ ^ I I- 0:: o Z 5000 _. ..... 6000 _.. . -2000 , i I ö KBE Ndg 1.5/100 Drp 1.5/100 End Drp SV6 KOP Bid 1.5/100 Bid 2.5/100 SV5 Report Date: Client: Field: Structure / Slot: Well: Borehole: UWUAPI#: Survey Name / Date: Tort I AHD / DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: V-202 (Obd) Geodetic Report Proposed Well Profile - April 15, 2003 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) V-Pad I Plan V-202 (N-F) b _111I1 ty ~:~~~ Feasl I 50029 V-202(P7)/ApriI11,2003 148.228° /5757.89 ft/6,215/1.23E NAD27 Alaska State Planes, Zone 04, US Feel N 70.32795887, W 149.26641773 N 5970065.800 flUS, E 590453,170 flUS 4{),69077098° 0.99990929 Survey / DLS Computation Method: Vertical Section Azimuth: st. dy Vertical Section Origin: . U TVD Reference Datum: TVD Reference Elevation: Sea Bed / Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Schlumberger Minimum Curvature I Lubinski 4.750° N 0.000 ft, E 0.000 ft KB 82.3 ft relative to MSL 54.000 ft relative to MSL 25.570° 57514.728 nT 80.778° May 10, 2003 BGGM 2002 True North +25.570° Well Head '~ Grid Coordinates Geographic Coordinates MD Incl I Azim TVD TVDss I VSec N/-S I E/-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 165.00 0.00 -82.30 0.00 0.00 0.00 0.00 5970065.80 590453.17 N 70.32795887 W 149.26641773 300.00 0.00 165.00 300.00 217.70 0.00 0.00 0.00 0.00 5970065.80 590453.17 N 70.32795887 W 149.26641773 400.00 1.50 165,00 399.99 317.69 -1.23 -1.26 0.34 1.50 5970064.54 590453.53 N 70.32795543 W 149.26641497 500.00 3.00 165.00 499.91 417.61 -4.93 -5.06 1.35 1.50 5970060.76 590454,58 N 70.32794505 W 149.26640678 533.33 3,50 165.00 533.19 450.89 -6.71 -6.88 1.84 1.50 5970058.94 590455.09 N 70.32794007 W 149.26640281 600.00 2.50 165.00 599.76 517.46 -9.99 -10.25 2.75 1.50 5970055.58 590456.04 N 70.32793087 W 149.26639543 700.00 1.00 165.00 699,71 617.41 -12.86 -13.20 3.54 1.50 5970052.64 590456.87 N 70.32792281 W 149,266389"" 766.67 0.00 165.00 766.38 684.08 -13.41 -13.76 3.69 1.50 5970052.09 590457.03 N 70.32792128 W 149.26638 967.59 0.00 355.00 967.30 885.00 -13.41 -13.76 3.69 0.00 5970052.09 590457.03 N 70.32792128 W 149.2663818tj/ 1100.00 0.00 355.00 1099.71 1017.41 -13.41 -13.76 3.69 0.00 5970052.09 590457,03 N 70.32792128 W 149.26638780 1200.00 1.50 355,00 1199.70 1117.40 -12.12 -12.46 3.57 1.50 5970053.39 590456.89 N 70.32792483 W 149.26638878 1233,33 2.00 355.00 1233,02 1150.72 -11.12 -11.45 3.49 1.50 5970054.39 590456.80 N 70,32792759 W 149,26638943 1300.00 3.67 355.00 1299.60 1217.30 -7.87 -8.16 3.20 2,50 5970057.68 590456.47 N 70.32793658 W 149.26639178 1400.00 6.17 355,00 1399.22 1316.92 0.58 0.37 2.45 2.50 5970066.20 590455,62 N 70.32795988 W 149.26639786 1500.00 8.67 355,00 1498.38 1416.08 13.30 13.23 1.33 2,50 5970079.04 590454.34 N 70.32799501 W 149.26640694 1600.00 11.17 355.00 1596.88 1514.58 30.27 30.39 -0.17 2.50 5970096.18 590452.63 N 70.32804189 W 149.26641911 1631,05 11.94 355.00 1627,30 1545.00 36.40 36.58 -0.72 2.50 5970102.37 590452.01 N 70.32805880 W 149.26642357 1700.00 13,67 355,00 1694.53 1612.23 51.46 51.81 -2.05 2.50 5970117.58 590450.50 N 70,32810041 W 149.26643435 Station ID V-202 (P7) report.xls Schlumberger Private Page 1 of 3 4/15/2003-12:32 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD TVDss I VSec N/-S I E/-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) End Bid 1733.79 14.51 355.00 1727.30 1645.00 59.56 60.00 -2.77 2.50 5970125.76 590449.68 N 70.32812278 W 149.26644019 SV4 1764,78 14,51 355.00 1757.30 1675.00 67,22 67.73 -3.44 0.00 5970133.48 590448.91 N 70.32814390 W 149.26644562 ~ JBâse Perm 1785.43 14.51 355,00 1777.30 1695.00 72.32 72.89 -3.89 0.00 5970138.63 590448.40 N 70.32815800 W 149,26644927 (/ Bid ªl1OÐ 1840.18 14.51 355.00 1830.30 1748.00 85.84 86.56 -5.09 0.00 5970152.28 590447,04 N 70.32819534 W 149.26645900 -- 1900,00 16.31 355.00 1887.97 1805.67 101.50 102.39 -6.47 3,00 5970168.10 590445.47 N 70.32823859 W 149.26647019 2000.00 19.31 355.00 1983.17 1900.87 131.64 132.85 -9.14 3.00 5970198.52 590442.43 N 70.32832180 W 149.26649185 2100.00 22.31 355.00 2076.63 1994.33 166.64 168.23 -12.23 3.00 5970233.85 590438.91 N 70.32841846 W 149.26651690 SV3 2188.05 24.95 355,00 2157.30 2075.00 201.42 203.38 -15.31 3.00 5970268.96 590435.41 N 70.32851449 W 149.266541 2200.00 25.31 355.00 2168.12 2085.82 206.42 208.44 -15.75 3.00 5970274.02 590434.91 N 70.32852831 W 149.266545~ 2300,00 28.31 355.00 2257.36 2175.06 250.86 253.36 -19.68 3.00 5970318.88 590430.44 N 70,32865103 W 149.26657732 End Bid 2323,14 29,00 355.00 2277,66 2195.36 261.79 264.41 -20.65 3.00 5970329.92 590429.34 N 70,32868122 W 149.26658519 SV2 2391.32 29.00 355.00 2337.30 2255.00 294.37 297.34 -23.53 0.00 5970362,81 590426.06 N 70.32877118 W 149.26660854 SV1 2757.20 29.00 355.00 2657.30 2575.00 469.19 474.04 -38.99 0.00 5970539.29 590408.47 N 70.32925391 W 149.26673392 10-3/4" Csg Pt 2871.53 29.00 355.00 2757.30 2675.00 523.82 529.26 -43.82 0.00 5970594.44 590402.98 N 70.32940476 W 149.26677309 UG4 2945.85 29.00 355.00 2822,30 2740.00 559.33 565.16 -46.96 0,00 5970630.30 590399.40 N 70.32950284 W 149.26679856 UG4A 2985.87 29.00 355.00 2857,30 2775.00 578.45 584.48 -48.65 0.00 5970649.60 590397.48 N 70.32955562 W 149.26681226 Crv 4/100 3223.14 29.00 355,00 3064.82 2982.52 691.82 699.08 -58.68 0.00 5970764.06 590386.07 N 70.32986870 W 149.26689361 3300.00 28.44 348.71 3132.24 3049.94 727.78 735.60 -63.89 4.00 5970800.51 590380.42 N 70.32996847 W 149.26693587 UG3 3379.56 28.18 342.02 3202.30 3120.00 763.32 772.05 -73.40 4.00 5970836.84 590370.48 N 70,33006804 W 149.26701299 3400.00 28.17 340.28 3220.32 3138.02 772.17 781.19 -76.52 4.00 5970845.94 590367.25 N 70.33009301 W 149,26703830 3500.00 28.41 331.85 3308.42 3226,12 813.64 824.39 -95.71 4.00 5970888.90 590347.54 N 70.33021103 W 149.26719393 End Crv 3583,55 29.00 325,00 3381.72 3299.42 845.91 858.52 -116.71 4.00 5970922.77 590326.13 N 70.33030427 W 149.26736425 Crv 4/100 3983.55 29.00 325,00 3731.57 3649.27 995.00 1017.37 -227.94 0.00 5971080.25 590213.00 N 70.33073823 W 149.26826636 4000.00 29,61 325.52 3745.91 3663.61 1001.22 1023.99 -232.53 4.00 5971086.82 590208.33 N 70.33075631 W 149.26830" 4100.00 33.33 328.31 3831.19 3748,89 1042.47 1067.75 -260.96 4.00 5971130.23 590179.38 N 70.33087586 W 149,26853"___/ 4200.00 37.11 330.59 3912.87 3830.57 1089.55 1117.43 -290.22 4.00 5971179.55 590149.53 N 70.33101158 W 149.26877149 4300.00 40.93 332.50 3990.56 3908.26 1142.24 1172.78 -320.17 4,00 5971234.53 590118.92 N 70.33116279 W 149.26901442 4400,00 44.77 334,14 4063.86 3981.56 1200.27 1233.55 -350.66 4.00 5971294.92 590087.70 N 70.33132880 W 149.26926172 4500.00 48.63 335.57 4132.43 4050.13 1263.37 1299.43 -381.54 4.00 5971360.42 590056.03 N 70.33150877 W 149.26951220 4600.00 52.51 336.85 4195.94 4113.64 1331.22 1370.09 -412.67 4.00 5971430.69 590024.05 N 70,33170181 W 149.26976471 4700.00 56.40 337.99 4254.07 4171.77 1403.49 1445.21 -443.89 4.00 5971505.42 589991.93 N 70.33190702 W 149.27001796 4800.00 60.30 339.04 4306.53 4224.23 1479.83 1524.41 -475.05 4.00 5971584.23 589959.82 N 70.33212339 W 149.27027073 4900,00 64.21 340.00 4353.08 4270.78 1559.88 1607.30 -506.00 4.00 5971666,73 589927,88 N 70.33234983 W 149.27052180 OA 4970.70 66.97 340.65 4382.30 4300.00 1618.49 1667.91 -527.66 4.00 5971727.07 589905.49 N 70.33251541 W 149.27069751 5000.00 68.12 340.91 4393.49 4311 . 19 1643.24 1693.49 -536.58 4.00 5971752.54 589896.26 N 70.33258529 W 149.27076988 Schlumberger Private V-202 (P7) report. xis Page 2 of3 4/15/2003-12:32 PM Grid Coordinates Geographic Coordinates I Station ID MD I Incl I Azim I TVD TVDss I VSec N/-S I E/·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0/100tt) (ttUS) (ftUS) End Crv 5002.95 68.23 340.93 4394.59 4312.29 1645.74 1696.07 -537.47 4.00 5971755.11 589895.34 N 70.33259234 W 149.27077710 Crv 4/100 5006.60 68.23 340.93 4395.94 4313.64 1648.84 1699.27 -538.58 0.00 5971758.30 589894.19 N 70,33260108 W 149,27078610 5100.00 69.62 344.65 4429.53 4347.23 1729.66 1782,52 -564.35 4.00 5971841.22 589867.43 N 70.33282850 W 149.27099517 OBa 5137.17 70.20 346.11 4442.30 4360.00 1762.60 1816.30 -573.16 4.00 5971874.89 589858.21 N 70.33292079 W 149.27106665 5200.00 71.20 348.55 4463.07 4380.77 1819.17 1874.14 -586.16 4.00 5971932,56 589844.51 N 70.33307880 W 149.27117213 Obb 5261.25 72.20 350.91 4482.30 4400.00 1875.33 1931,36 -596.52 4.00 5971989.65 589833.47 N 70.33323511 W 149.27125620 5300.00 72.85 352.38 4493.94 4411.64 1911.33 1967.93 -601.89 4.00 5972026,15 589827.66 N 70.33333502 W 149.27129978 5400.00 74.58 356,14 4521.98 4439.68 2005.69 2063.41 -611.47 4.00 5972121.50 589816.93 N 70.33359586 W 149.27137ï OBc 5459,58 75,64 358.35 4537.30 4455.00 2062,77 2120.92 -614,23 4.00 5972178.96 589813.47 N 70,33375297 W 149.27139g~ 5500.00 76.36 359,84 4547.08 4464.78 2101,80 2160.13 -614.85 4.00 5972218.16 589812.38 N 70,33386009 W 149.27140503 5600.00 78.21 3.48 4569.09 4486.79 2199,18 2257.62 -612.01 4.00 5972315,67 589814.05 N 70.33412643 W 149.27138205 End Crv 5695.17 80.00 6.90 4587,09 4504.79 2292.62 2350,67 -603.55 4.00 5972408.81 589821.38 N 70.33438063 W 149.27131349 OBd 5696,38 80,00 6.90 4587.30 4505,00 2293.80 2351.85 -603.41 0.00 5972409.99 589821.51 N 70.33438386 W 149,27131236 5725.17 80.00 6.90 4592.30 4510.00 2322.14 2380.00 -600.00 0.00 5972438.17 589824.58 N 70.33446076 W 149.27128471 7-5/8" Csg Pt 5816.00 80.00 6.90 4608,07 4525.77 2411.53 2468.80 -589.25 0.00 5972527.09 589834,26 N 70.33470336 W 149.27119757 Crv 8/100 5836.17 80.00 6.90 4611.57 4529.27 2431.38 2488.52 -586.87 0.00 5972546.83 589836.40 N 70.33475723 W 149.27117828 5900,00 84.15 9.90 4620.38 4538.08 2494.45 2551.04 -577,62 8.00 5972609.46 589844.89 N 70.33492803 W 149.27110328 90° pt 5989.50 89.99 14.05 4624.95 4542.65 2583.06 2638.42 -559.08 8.00 5972697.04 589862.38 N 70.33516675 W 149,27095294 6000.00 90.68 14.53 4624.89 4542.59 2593.42 2648,59 -556.49 8.00 5972707.24 589864,84 N 70,33519453 W 149.27093194 End Crv 6078.10 95.78 18.15 4620.49 4538.19 2669.77 2723.39 -534.56 8.00 5972782.30 589885.87 N 70.33539888 W 149.27075408 Crv 4/100 6370.62 95.78 18,15 4591.04 4508.74 2952.87 2999.93 -443.89 0.00 5973059.88 589973.19 N 70.33615438 W 149.27001870 6400.00 93.49 18.69 4588.66 4506.36 2981.32 3027.71 -434.64 8.00 5973087.77 589982.10 N 70.33623028 W 149.26994367 Target 6444.78 90.00 19.50 4587.30 4505.00 3024.68 3070.00 -420.00 8.00 5973130.23 589996.23 N 70.33634581 W 149,26982493 End Crv 6458,37 88,94 19.72 4587.43 4505.13 3037.82 3082.81 -415.44 8.00 5973143.09 590000.64 N 70.33638081 W 149.26978- Crv 4/100 7250.77 88.94 19.72 4602,15 4519.85 3803.18 3828.60 -148.08 0.00 5973891.98 590258,96 N 70.33841827 W 149.26761~ Target 7259.84 89.20 19.97 4602,30 4520.00 3811.93 3837.12 -145.00 4.00 5973900.54 590261.94 N 70.33844154 W 149.26759413 End Crv 7266.10 89,39 20.14 4602.38 4520.08 3817.98 3843.00 -142.85 4.00 5973906.44 590264.02 N 70.33845761 W 149.26757669 Crv 4/100 8127.65 89,39 20.14 4611 ,62 4529.32 4648.59 4651.83 153,76 0.00 5974718.71 590550.83 N 70.34066726 W 149.26517008 Target 8159.92 88.20 20,65 4612.30 4530.00 4679.66 4682.08 165.00 4.00 5974749.09 590561.70 N 70.34074990 W 149.26507888 End Crv 8190.26 87.08 21.13 4613.55 4531.25 4708.77 4710.39 175.81 4.00 5974777.53 590572.17 N 70.34082724 W 149.26499116 TD 14-1/2" Lnr 8951.98 ---87.08 21.13 4652.30 -4570.00 5438.65 5420.00 450.00 0.00 5975490.33 590837.76 N 70.34276580 W 149.26276598 LeClal Description: NorthinCl (Y) rftUSl Eastin~ eX) rftUSl Surface : 4819 FSL 1848 FEL S11 T11N R11E UM 5970065.80 590453.17 BHL: 4959 FSL 1393 FEL S2 T11 N R11 E UM 5975490.33 590837.76 Schlumberger Private V-202 (P7) report.xls Page 3 of 3 4/15/2003-12:32 PM ') / BP Exploration Alaskh ') Anticollision Report ·:çol~it~ål1y: .... · ..BP~rriþço ..: . .... ~i~Ic.: .. . . prqqpoe Bay RêfërWcëSite:. ····.p~\lPa(l···.; .... ........ ··~ef~rèn~W-Welf:. ..... þlanV;;202(N;'F)· RefeÍ"enèêWellpath: PlànY~202qBd .... NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 50,00 ft Depth Range: 28,50 to 8951.98 ft Maximum Radius: 3000.00 ft .nåte:.4Î15t2003 ... ... ". :..... .. ..... .. .' ....... .... ... . . . .... . ....:.:. .:. ·..ép~~~i~åt~(NF;j~~f~re~f~: ···.V ei-~ical(TY)))Rê~êrence: : time: ... 12:39:18 Reference: Error Model: Scan Method: Error Surface: .... '. .".. ........ ....... . ...... .... ... ... . ... .. . .".. ..... '. ... . ",. .......:. .":; ::: '":::':'.:'.:::': ::.. ,"':... :.. .::. ::::::"::"::..;. ::.;.;;.:/:..' '::.':'..:.:.: : :" .::::":.:::"".:..":., -:: ::.; . "" . .:.... ":":::..:"":::.;":: ... .. ·\lVëll:P1an Y-20g(N-F), Try~NÓrth·· . ··Y':;202Plah82,3 ..... ...... ..... ...... ........ .. . Db: Sybåše Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing rage: 1··.·:·, Survey Program for Definitive Wellpath Date: 8/19/2002 Validated: No Planned From To Survey ft ft 28.50 1300.30 Planned: Plan #7 V2 1300,30 8951,98 Planned: Plan #7 V2 Version: 4 Toolcode Tool Name GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points MD ft 2871,53 5816.00 8951.98 TVD ft 2757,30 4608.07 4652.30 . Diameter in 10.750 7.625 4.500 Hole Size in 13.500 9,875 6.750 10 3/4" 7-5/8" 4 1/2" Summary · Reference Offset Ctr-Ctr No"Go Allowable wárning/" MD MD Distance Area Deviation ft ft ft: ft ft PB V Pad Plan V (2-03HAW) (NPlan V (2-03HAW) VO PI 400.21 400,00 75.55 8.44 67,11 Pass: Major Risk PB V Pad Plan V (2-04HAW) (SPlan V (2-04HAW) VO PI 1244.48 1250.00 228,90 21,58 207.32 Pass: Major Risk PB V Pad Plan V (2-05HAW) (SPlan V (2-05HAW) VO PI 655.47 650.00 290.70 11.66 279.04 Pass: Major Risk PB V Pad Plan V (2-07i) (N-G) Plan V (2-07i) V1 Plan 400.24 400.00 15,52 8.55 6.97 Pass: Major Risk PB V Pad Plan V (2-08i) (N-C) Plan V (2-08i) V1 Plan 450,05 450,00 45.05 9.04 36.01 Pass: Major Risk PB V Pad Plan V (2-11 i) (S-J) Plan V (2-11 i) VO Plan 607.74 600.00 184.63 10.14 174.52 Pass: Major Risk PB V Pad Plan V (2-12i) (S-D) Plan V (2-12i) VO Plan 1148.45 1150.00 168.61 20.19 148.43 Pass: Major Risk PB V Pad Plan V (2-13i) (N-W) Plan V (2-13i) VO Plan 350.34 350.00 295.73 7,74 287,99 Pass: Major Risk PB V Pad Plan V (2-14i) (N-R) Plan V (2-14i) V3 Plan 900.15 900.00 221.11 14.26 206.86 Pass: Major Risk PB V Pad Plan V (2-15i) (S-P) Plan V (2-15i) VO Plan 607.76 600.00 256,89 10.21 246,68 Pass: Major Risk PB V Pad Plan V (2-16i) (N- T) Plan V (2-16i) V1 Plan 400,32 400.00 251.34 8.42 242,92 Pass: Major Risk PB V Pad Plan V (2-17i) (S-Q) Plan V (2-17i) VO Plan 457.84 450.00 273.28 8.37 264.91 Pass: Major Risk PB V Pad Plan V (2-18i) (S-T) Plan V (2-18i) VO Plan 405.34 400,00 308,88 8,13 300,74 Pass: Major Risk PB V Pad Plan V (2a-06i) (N-M Plan V (2a-06i) VO Pia 499.78 500,00 146,11 9.58 136,54 Pass: Major Risk PB V Pad Plan V (2a-09i) (N-I Plan V (2-09i) V1 Plan 450.09 450.00 46.02 9.06 36.97 Pass: Major Risk PB V Pad Plan V (3a-06) (S-U) Plan V (3a-06) V1 Plan 559.42 550.00 320.38 10,10 310.29 Pass: Major Risk PB V Pad Plan V-01 (S-N) Plan V-01 V8 Plan: V-( 676.61 650,00 235.41 11.45 223.97 Pass: Major Risk PB V Pad Plan V-02 (S-K) Plan V-02 V4 Plan: V-O 1148.66 1150.00 182.21 18.13 164.09 Pass: Major Risk PB V Pad Plan V-110 (N-X) Plan V-110 V2 Plan: PI 450,36 450,00 310.56 7,68 302.88 Pass: Major Risk PB V Pad Plan V-111 (S-G) Plan V-111 V6 Plan: PI 1290.58 1300.00 108,27 20.58 87,77 Pass: Major Risk PB V Pad Plan V-112 (S-H) PlanV-112 LatV1 Plan 748.80 750.00 166.85 13,19 153.66 Pass: Major Risk PB V Pad Plan V-112 (S-H) Plan V-112 V6 Plan: PI 748,80 750.00 166.85 13,08 153.77 Pass: Major Risk PB V Pad Plan V-114 (S-R) Plan V-114 V2 Plan: PI 1196,83 1200,00 276,16 19.30 256,86 Pass: Major Risk PB V Pad Plan V-115 (S-A) Plan V-115 V1 Plan: PI 700,00 700.00 182,90 10.74 172,18 Pass: Major Risk PB V Pad Plan V-115 (S-B) Plan V-115 V1 Plan: PI 747.88 750.00 174,71 11.36 163.36 Pass: Major Risk PB V Pad Plan V-116 (S-L) Plan V-116 V3 Plan: PI 702,88 700.00 192.36 9.99 182.39 Pass: Major Risk PB V Pad Plan V-117 (S-X) Plan V-117 V1 Plan: PI 404.83 400,00 358.79 6.93 351.86 Pass: Major Risk PB V Pad Plan V-117 (S-X) Plan V-117PB1 V2 Plan: 404.83 400.00 358.79 7.04 351.75 Pass: Major Risk PB V Pad Plan V-400 (N-U) Plan V-400 V5 Plan: PI 349.82 350,00 266.10 6.42 259.68 Pass: Major Risk PB V Pad Plan V-Pi (S-A) Plan V-Pi V1 Plan: Pia 700.00 700,00 185.46 10.59 174,91 Pass: Major Risk PB V Pad V-03 V-03 V7 1800.09 1800.00 300.36 23.14 277.46 Pass: Major Risk PB V Pad V-100 V-100 V7 1195.71 1200.00 330.10 15.34 314.79 Pass: Major Risk PB V Pad V-101 V-101 V7 399.88 400,00 26.86 6.49 20,38 Pass: Major Risk PB V Pad V-102 V-102 V5 649.42 650.00 90.50 10.47 80.03 Pass: Major Risk PB V Pad V-103 V-103 V6 498.96 500.00 236.70 7.61 229.16 Pass: Major Risk PB V Pad V-104 V-104 V13 999.83 1000.00 26.33 14.53 11.82 Pass: Major Risk PB V Pad V-105 V-105 V13 1099,37 1100.00 161.92 15.22 146,69 Pass: Major Risk PB V Pad V-106 V-106 V10 799.01 800.00 208.93 10.68 198.29 Pass: Major Risk PB V Pad V-107 V-107 V5 1545.38 1550.00 50.30 21.26 29,05 Pass: Major Risk PB V Pad V-108 V-108 V7 249.98 250.00 61.95 4.47 57.49 Pass: Major Risk PB V Pad V-109 V-109 V2 1148.87 1150.00 141.18 15.13 126,11 Pass: Major Risk PB V Pad V -109 V-109PB1 V5 1148.87 1150.00 141.18 15.13 126.11 Pass: Major Risk :C()lJ1pa~y: ... BP Amoco .. Field.: . .. ··Pfµdt:I(:~~ß~Y ... Refei'enceSité . .. ..... ... p~V' P~d' ... .. .... . ·RecerenceWell: . ..... PlåhY~202.(N~F) llef'ei'ençeWellpäth: PlanV.;2020Bd Summary ) BP Exploration Alaskh ) Anticollision Report þff'set WeUpath ~~~- .:. ... ... ___-:->.. . weil· Wellpath . . PB V Pad PB V Pad PB V Pad V-109 V-113 V-201 V-109PB2 V2 V-113 V6 V-201 V8 Date: ·.4/15/2003 ··l'im~~ 12:3ß:1~ .' P~ge:·. ··2···. ," . .. .... .................. ..... .. .. ........... .... . . ........". . '" . . .': :. .:" ...... .........":.' ."... .... ........ ..... ... .. ......- .. . C~~ð~tî~t.å~~(N~jItefêreº¢ë: . 'We!I:PI~nY':~Ó2(N-f),frµ~ NÞHh .. Yerti~'a~{'I'YI»J'{~ferertcë: ' V"202 Plan 82,3 . .... . .. . . .. .. Db:Sybase ,. .. Çtr'-Ctr .·No-G() .DistanceArea ft ·ft 141.18 15.13 148.50 17.68 69.91 12.14 ··Allowable Deviation ft· 126,11 130,85 57.80 Pass: Major Risk Pass: Major Risk Pass: Major Risk _J --/ Travelling Cylinder Azimuth (TFO+AZI) [deg) vs Centre to Centre Separation [35Mn) 90 -103 70 35 Plan V (2-03HA W) (N-A) (Plan V (2-03HA W» V-108 (V-108) ) 27() -0 35 V-IOI (V-IOI) Plan V (2-08i) (N-C) (Plan V (2-08i» 30 Plan V (2-07i) (N-G) (Plan V (2-07i» Field: Prudhoe Bay Site: PB V Pad Well: Plan V-202 (N-F) Well path: Plan V-202 OBd 70 -103 --- -- -------~---~ ~----- ---- ~ c 4(}-- 0 1 ~ u 0 ~ u 3(}-- 7(}-- 6(}-- 5(}-- I(}- 250 I 1750 Measured Depth [25Oft/in] Target: V-202 Poly Site: PB V Pad ) Drilling Target Conf.: J 0 Description: Map Northing: 5972438.17 ft Map Easting : 589824.58 ft Latitude: 70020'04.059N +N/-S ft -59.08 156.71 3085.12 2915.89 ') Well: Plan V-202 (N-F) Based on: Planned Program Vertical Depth: 4510.00 ft below Mean Sea Level Local +N/-S: 2379,99 ft Local +E/-W: -600.00 ft Longitude: 149°16'16.625W Northing ft 5972380.00 5972590.00 5975535.00 5975370.00 Polygon 1 2 3 4 +E/-W ft 74.72 -402.76 1012.78 1361. 79 Easting ft 589900,00 589420,00 590800.00 591151.00 5500 5000 5500 5000 N ^ 4-500 4-000 3500 3000 2500 2000 1500 D D D D D D D D D D D D D D Lfl Lfl D LJ) D I N 11 ) ,-¡-------.l--Ë 5,172---r------.l--ì r I I I I I I I I I I I 1 I I . V-110 I r . V-03 I I . V-10Oi 1 I · V-400 I . V-ST I . V-103 I I . V-106 I I I I 1 1 . V-105i I r . SLOT NM I I I I I g . V-102 I I d = V-201 I I; V-107 01 I . V-104i ~I I . V-111 C»I r V-202 -+ zl I . · V-109 I I V-101. V-113 I 1 . V-108 I 1 I I 1 I I I I r \ : \" : V-PAD ~ I --- I /... /l GRID 15'00'00';( PLANT 1 -.r-Z - 1 NOTES 1. DATE OF SURVEY: APRIL 1, 2003 2. REFERENCE FIELD BOOK: W003-03 PAGES 30-32. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MSL DATUM. 6. 1HE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. ~J.""!'. ., N::.~ ......,~ ,,)~~ \H. / \.~) ,/~1',;~..,,-\ { :¡! "_: " ~ ð . \ 1\ '" \ " I", lie \ . '¡' {,V II " \ ' . \ i (, / ~" Ii( 34~, t,' iò {~\ W. ,.,3~ li!~ ",~ . o."'~ ,;\) ,'~ (J'I~I) ~ '" \ ç" ·u, )~' çJ...;ïfl¡f- <,/~ '\I¡ìì'''';'\ . ,L./'~, "... ~!":,, ') \ \" \ I~ I .",;\'1 . '\" "t;,\ ~, .. r \ ,).~~~I;~r \"...i, ,:¿";ó \'~\~~~<Y'; t~~~~1~; ; í'I''''~ '\ j 4., ,'" \ (,~, \, '~,',\. "\ ~>}! <T~7,1\J. \1 .... /' <. "t¡ ~\ '~,' . '\1', II iI' tI '" ' <-~ - \~. . .-~~i.\. ~~ 1·f"' = ~ ,I/" ~\Ì'\\~ ,S ç¡ · ~. ~~UK ??..' /...., . . ¡, d) I~ :' :'ho" ~,STATE \. ~ \~~:i~.'1' I "ì.:~ " . ... r. " . \: Î~ 03-11-11., ll....t.~,;)'Þ,:,-:.{ 2 \ ;. (::\ <' l' : " '. .' ?fnJ;" I V' -' .:'..,.' 3 Q,~~ (') .. ',,'''';\./) ¡-' PROJEC"f;',\~\~ \ \\ì n '~.':,.' '>,1.1'" \....... ," AREA ~", .i \~ t~,) ··1~\~ 9;.~ l~p t"\) Jr , ["\,,"~~~\ · pi " \ f\Rì~ '\ 1',,:,.., ' ',' woÀ' "'1'" C\ ~ ":." . '··::'.~:¡·"l ~j,. ,;¡' t~.: ') v.pAD~'''Aí\ (ì" ,,'',)... · \ / "0'(.,')' v,l},. }, < r···· ì(: 1"· \.!" '\\~""'\¡ \ ). '>~10 "0 . \ \,;1 ~".?\y ~().\'l" '\.\, II" ,,'....,.. ~.. .\0' . ,>. \. í" ('11 ~ i ¡~ (II ì '.' 1 ~~1) . ·f V!' 1:[' ,\,,<1-·t- 12 'I..".. . ~>,~:~J'I~ \)¡ ''f,~:~~. r "-'1, :~\, l~~~·· ~~-~,: '~. ..",,,~. (/., ",\ \)\ ,\ \'''\ {D ~;,,~~ ,)\1.,." . l ¡V., "'\'1 ",~:I \ \ VICINITY MAP N.T.S. LEGEND + AS-BUILT CONDUCTOR . EXISTlNG CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 1, 2003. WELL NO. V-202 LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 L, UMIAT MERIDIAN, ALASKA A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=5,970,065.80 N=1 0,179.99 70·19' 40.652" 70.3279589' 53 8 4,820' FSL X= 590,453.17 E= 4,704.68 149'15'59.104" 149.2664178' . 1,848' FEL F, RObelt l -- I. 1]__ ..: I ¡ ~~~rnœD DRAWN: COTTON CHECKED: ONEIL DATE: 4/2/03 DRAWING: FRB03 WOV 02-01 JOB NO: SCALE: 1-=150' o 4/2/03 ISSUED FOR INFORMAl1ON NO. DATE REVISION [NQN([!ItS IN) lANO SUt'Æ'r'ORS 1101 wtsT rlR(W((O LAN( ~AC(, ALASKA ":!.OJ JJC MLO BY CHK ObP WOA V-PAD AS-BUILT CONDUCTOR WELL V- 202 SHEET: 1or1 P055052 DATE 4/4/2003 INVOICE / CREDIT MEMO INV# CK0401038 THE ATTACHED CHECK IS IN PAYMENT FÓ'R; !TEMS DESCRIBED ABOVE. . '';';':, ,~~\:- BP EXPLORATIOf\1,~ÅtASKA) INC. PRUDHOE BAY UNIT .;': .~" PO BOX 196612 . .~' .... ANCHORAGE, AK ·99519:6612 PAY: TO THE ORDER OF: (~~) DESCRIPTION DATE 4/412003 CHECK NO. ObbOb2 GROSS VENDOR DISCOUNT NET PERMIT TO DRILL FEE "\/ /)IO~~ iJ"~ ~ TOTAL ~ 56-389 """412 No. P 055052 NATlONALCITV BANK Ashland, Ohio . - -. B P··:· . r;........'".. 'r i"'lh....)·.....~..... ... ¡I'.') .~.'.··..:.I.' f'.::..·..·.·.. 1Ii-,- -----: _:-,.- ':':: -.;--;:-. 1-" - ~_--. d- .".:--:' .> . -~.J ,,>.~tI¡" ·.IÌ. _.".un.. ~n~'r'''':.'' .- -------- .- _.- - .-. ALASKA OIL &GAS CQNSERV,f\TION C0MMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 CONSOLIDATED COMMERCIAL ACCOUNT DATE· ApriJ4, .2ÓQ3 AMOUNT **1I:~'tt*$tO.o .00******* 1110 5 50 5 2111 I: 0 1. ~ 2 0 ~ a ~ 51: 0 ~ 2 ? a ~ b liD H .~ Rev: 07/10/02 C\jody\templates ) \ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) paOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number· (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ðPX WELLNAMEPlJq tJ-:J.c>2- PROGRAM: Exp_ Devk Redrll_ Re-Enter_ Serv_ Wellboreseg_ FIELD & POOL 67<'0/. ~..t:; INIT CLASS /)P./ì/ I-~(/'I GEOL AREA <þ (r) UNIT# I/b.(ð ON/OFF SHORE..QV rt ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . v" 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 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N /J/J~ /.J~ _ ¿j 8. If deviated, is wellbore plat included.. . . . . . . . . . , . . . Y N ~ ~0 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.. . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ Y V /I/r A, (Service Well Only) 14. All wells w/in X mile area of review identified.. . . . . ., J(N ~ ~N 1..-0" v '5 ¥ 't (i) JOt¡ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¡- 16. Surface casing protects all known USDWs. . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . 18. CMT vol adequate to tie-in long string to surf csg. . ~ 19. CMT will cover all known productive horizons. . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N A1cJ.Or~ q ES . 22. If a re-drill, has a 10-403 for abandonment been approved. . . '~N /\Ilk 23. Adequate wellbore separation proposed.. . . . . . . . . . . . Qf.¿ N 24. If diverter required, does it meet regulations. . . . . . . . . . N . 25. Drilling fluid program schematic & equip list adequate. . . . . N rn ~_ fJ1 /Ai q, s P p~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . NN YV1 '" P· l/q 1 f1 (" _' . 27. BOPE press rating appropriate; test to 3500 psig. I f( ~ -r r '>-'\. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N WGI'\- c.¡1t.~/()'~ 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ŒJ 31. Mechanical condition of wells within AOR verified. . . . . . . . --¥---N-1\l1A- øN ){ N'A, APPR DATE ) APPR DATE (Service Well Only) GEOLOGY APPR DATE ~íè 7'h~~ (Exploratory ~~) 32. 33. 34. 35. 36. Permit can be issued w/o hydrogen sulfide measures. . . . . Data presented on potential overpressure zones. . . . . . . . Seismic analysis of shallow gas zones. . . . . . . . . . . . . Seabed condition survey (if off-shore). . . . . .. ...... Contact name/phone for weekly progress reports. ...... GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~ TEM JDH JBR ~ DTS q./7.f!D3 / MJW f( ~ \ ~'" '\:::"') SFD_ WGA Rev: 07/12/02 G:\geology\perm its\checklist.doc
