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Home My WebLink About208-151STATE OF RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed FEB 11 2020 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate EI Other Stimulate ❑ Alter Casing11Chan g/�� ❑ Plug for R drill ❑ Perforate Naw Pool ❑ Repair Well ❑ ,�9g1A+�- Re-enter Susp Well ❑ Other9sim c 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number. 208-151 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6_ API Number: 50-029-21614-03-00 1 7 Property Designation (Lease Number): ADL 028321 8. Well Name and Number: PBU 18-14C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12960 feet Plugs measured None feet true vertical 8767 feet Junk measured 10010,10557 feet Effective Depth: measured 12867 feet Packer measured 9062 feet true vertical 8759 feet Packer true vertical 6069 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 16" 29-109 29-109 1640 670 Surface 3420 10-3/4" 29-3449 29-3449 3580 2090 Intermediate 8673 7-5/8" 27-8700 27-7805 6890 4790 Liner 6025 5-1/2" 3543-9568 3543-8442 7000/7740 4990/6280 Liner 1278 3-1/2" 9432-10710 8351-8744 7000 4990 Liner 2311 2-3/8" 10593 - 12904 8740-8761 11200 11780 Perforation Depth: Measured depth: 9464-12859 feet True vertical depth: 8371 -8758 feet Tubing (size, grace, measured and We vertical depth) 3-1/2" 9.3# 9Cr80 25-9118 25-8132 Packers and SSSV (type, measured and 3-1/2" Baker S-3 Packer 9062 8089 true vertical depth) NO SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure-. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 424 4519 3038 0 505 Subsequent to operation: 228 4374 3622 0 392 14.Attachments :(requaea per 20 nnc 25.070,25.071, a 25,283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development m Service ❑ Stretigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Oestgaard, Finn Contact Name: Oestgaard, Finn Authorized Title: Production Engineer Challenger Contact Email: Finn.Oestgaartl(rObp.com Date: �. �l t �7.� Contact Phone: Authorized Signature: �� +1 907 564 5026 Form 10404 Revised 04/2017 — A — /_/ZVZo OBDMSWFEb 12 2020 Submit Original Only Daily Report of Well Operations PBU 18-14C ACTIVITYnATF SI IMMARV 'WELL S/I ON ARRIVAL*** (Profile Mod) PULL 3 -1/2"X -LOCK FROM 9,041' MD (lower section of dream catcher still in hole) RAN 2.50" LIB TO 9,065' SLM (no definitive marks) RAN 3-1/2" BRUSH TO 9,762' SLM RAN 2-3/8" BRUSH TO DEVIATION AT 10,010' SLM 12/5/2019 ***CONT WSR ON 12/6/19*** ***CONT WSR FROM 12/5/19**' (profile modification) RAN STIFF 1" POCKET POKER/ BRUSH TO 10,020' SLM RAN SBHPS SPARTEK GAUGES PER PROGRAM DRIFT TO 9,790' SLM W/ 12'x 2.70" DMY WHIPSTOCK & 2.74" CENT 12/6/2019 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED ON WELL STATUS*** ***WELL SHUT IN UPON ARRIVAL**'(ELINE PERF AND SET PACKER) T/1/0=1200/1100/0 RUN 1: 2'x 2" SLB POWER JET OMEGA 6 SPF 60 DEG PHASING PERFORATE 9464-9466 ELMD RUN 2: SET BOTTOM OF BLAST JOINT/TOP OF 3-1/2" PACKER AT 9472' ELMD. TOP OF QCLL RECEPTACLE @ 9462'. 12/11/2019 ***JOB COMPLETE*** ****WELL S/I ON ARRIVAL***(profile mod) DRIFT W/ 2.68" CENT, 2.50" LIB TO LOWER SECTION OF STRADDLE AT 9437' SLM (clean pic of straddle) SET 35 KB PKR W/ 2-3/8" NSAK SLIDING SLEEVE W/ HES DPU AT 9451' MD (SLD SLV AT 9457' MD). NOTE: ORIFICE INSERT W/ TWO .188" PORTS WAS PRE-INSTALLED IN OPEN NSAK SLIDING SLEEVE. 1/13/2020 ***WELL TURNED OVER TO DSO*** I TREE = CM/ WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 50' REF ELEV = 46A' BF. ELEV = 19A3' KOP= 4500' Max Angb = 97° 01221& Datum MD = ?? Datum TVD = 8800' SS 10-3/4' CSG, 45.5#, L-80, D = 9.953' 3462' TOP OF 5-12— SCAB LINER 363W Minimum ID =.86" @ 9457- ORIFICE SLV SET IN SLD SLV IN STRADDLE 5-12' SCAB LNR, 15.5#, L-80 BTC, H 8509' .0238 bpf, D = 4.950• 7-518• CSG, 29.7#, L-80, D = 6.875' 8700' MLLOUT WINDOW (18-14A)8700'-8750' MILLOUT WINDOW (18-14B)9568'-9581' .0087 bpf, ID - 2.992' LNR 17#, NT -80 NSCC, bpf, ID =4.767- PERFORATDN SUMMARY REF LOG: MCNL LOG CCLJGR/CNL 10106108 ANGLE AT TOP PERF: 48° @ 9464' Note: Refer b1 PmdLEbon DB for lislDdoal pe ab SIZE SPF INTERVAL OprVSqz SHOT SOZ 2' 6 9464-9466 O 12/11/19 01/08/16 1.56' 6 10860-10890 O 10107/08 M 1.56' 6 10920-10990 O 10107/08 39 1.56' 6 11080-11130 O 10107108 1.56' 6 11280-12080 O 10107108 1.56' 6 12470-12490 O 10/07/08 1.56' 6 12530-12610 O 10107/08 1.56' 6 12700-12859 O 10/07/08 18-14C S'ORIG WELL, 18-144A & AFETYNOTES 11�8-14B NOTSHOWN BELOW WHIPSTOCK•••3-12"CHROME TBG*** 2213' 312' CA MOO TRM-4E TRSSSV, D= 2.812' OLOCKED OPEN (0228/08) GAS LFT MANDRELS -12'WHPSTOCK(09127/08) 10710- ,l RA TAG @ 10715' DT -M, 0087 bpf, D = 2.992' -10710 ST I MD I TVD DE/ I TYPE VLV LTCH PORI DATE 3 3240 9451° - 9476' 1 KBG2-9 DONE M 16 01/08/16 2 5751 1 132411 5606 39 KBG2-9 DONE 1 M 16 01108/16 1 8322 7509 39 KBG2-9 OM1' M 0 03/11/04 3637- —17-5/8'X 5-72' BKR D(P LTP, 0= ig4 7-5/8' X 5-12' FLEXLOCK LNR H( I 8522' I I7-SIW X 5-12' BKR G2 TEBK SLV, D = 5.750' 7-5/8' X 5-12" BKR H PKK D = 4.812' 13-12'HESXNP,D=2.813' I 9062' H5 -11r2- X 312• BKR S-3 PERM PKR —� 8117- ��3-12•WLEG,ID =2.992' 9413' 5-12' BKR LNR TOP TIEBACK, ID=4.24' 9419' 5-12'X312•BKRZXP L7P,ID =3.410' ---® 4-12' BKR POUSHED NIP,ID = 3.250' 9432' 5-12•X3-12-BKRLNRHGR ID=2.920• 9451° - 9476' 35KB STRADDLE W/2-=- NS SLD SLV 8 BUST JOINT (01/1320) 9457- 2-318• SLD SLV IN STRADDLE, D =1.781• (OPEN 111320) 9457- 2-3W ORIFICE SLV SET W/ 2.188" PORTS, ID =.a8— (1/1320) 61' -8472' 2-3/8' CS HYDRL BLAST JT, D =1.88' (12/11/19) 10010' SLM FISH - BTM 44'01' DREAMCATCHER \10577- CTMFISH - BTM SECWN - 35 KB LTP (9/10113) �iLraL� 270• nFpL oY MENr 5'i v In = 1 9n0' I MLLOUf wm)ow (1B -14C) 10710• - 10715' PBTD 12867' 2-3/8' LNR 4.7#, L -BO STL, .0039 bpf, D =1.995' 12904' DATE REV BY COMMENTS DATE REV BY COMMENTS 11108186 INITIAL COMPLETION 11/03/15 CJWJMD SET DREAMCATCHER(102811! 0225195 N2ES SIDETRACK (1844A) 01/12/76 DLFVJMD GLVC/0(01/08116) 0410INS NORDIC 1 CTD (2-718' SLID LNR) 02/0320 CJWJMD PULLED DREAMCATCHER/FISf 03M3M4 N118E SIDETRACK (1844B) 0210320 BTWJMD ADPERFS(12111/19) 10/08108 NORDIC I RIG SIDETRACK 18-14C 0210320 CJWJMD SET STRDL W/ SLD SLV&ORFI 0728110 SMIJMD ORLGDRAFTCORRECTIONS PRUDHOE BAY UNIT WELL: 18-14C PERMITND: `2081510 API No: 50-029-21614-03-00 BP Expbratfon (Alaska) Ima a Pro'ect Well History File Cove~age 9 1 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. _~ Q ~ - ~ ~ L Well History File Identifier Organizing (done) RESC N Color Items: ^ Greyscale Items: o..~,a~ imuiiiiuiium DIGITAL DATA ~iskettes, No. ` ^ Other, No/Type: o R~~a~~,~~ iuumniiiiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: Maria Date: /a /s/ ~Y: ro"ectProofin II(IIIII(IIIII ((III P , g ~1 BY: Maria Date: 3 O /s/ - + =TOTAL PAGES ~ .3 Scanning Preparation _~. x 30 - ~~ ~~~ (Count does not include cover sheet) gy: Maria Date: /s/ IIIIIIIIIIIIII IIIII Production Scanning Stage 1 Page Count from Scanned File: - te=a-- (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES ~/N~O BY: Maria Date: 3/g~/~ /s/ ~ ~/ 1 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ m lete at this Dint unless rescanning is required. II I II I) II I II II IIIII Scanning is co p P ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s! mments about this file: Quality Checked III IIIII III III II Co 10/6!2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2124/2010 Permit to Drill 2081510 Well Name/No. PRUDHOE BAY UNIT 18-14C Operator BP EXPLORATION (ALASKq) INC MD 12960 TVD 8767 Completion Date 10/7/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-21614-03-00 UIC N REQUIRED INFORMATION Mud Log No DATA INFORMATgN . Types Electric or Other Logs Run: MWD, GR, RES, MCNL Well Log Information: Log/ Electr Data Digital Dataset Samples No Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / meairrmt rvumuer ryame D Asc Directional Survey Directional Survey C Lis 17375./~leutron Neutron LIS Verification C Lis 17492 induction/Resistivity Induction/Resistivity Induction/Resistivity Gamma Ray S//ee Notes C Las 19330/lnduction/Resistivity Gamma Ray acme IYICUTA No star[ atop ~.n Keceroea ~.ommenLS 10693 12960 Open 11/10/2008 ~ 10693 12960 Open 11/10/2008 8701 12852 Case 12/31/2008 LIS Veri, GR, CNT ~ 25 Blu 8704 12853 Case 12/31/2008 MCNL, Lee CCL, GR 6-Oct-) 2008 10690 12960 Open 1/26/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 10690 12960 Open 1/26/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 25 Col 10710 12960 Open 1/26/2009 MD MPR, GR 3-Oct-2009 25 Col 10710 12960 Open 1/26/2009 TVD MPR, GR 3-Oct-2009 25 Col 10710 12960 Open 1/26/2009 MD GR 3-Oct-2009 5 Col 10320 12941 Open 1/26/2009 Depth Shift Monitor Plot 10320 12960 Open GR, Induction Res, ROP 5 Coi 10710 ---- 12960 Open 1!26/2009 TVD GR 3-Oct-2009 --- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments •I DATA SUBMITTAL COMPLIANCE REPORT 2/24/2010 Permit to Drill 2081510 Well Name/No. PRUDHOE BAY UNIT 18-14C MD 12960 TVD 8767 ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~f-F~P4. Analysis Y'TIV Received? Completion Date 10/7/2008 Operator BP EXPLORATION (ALASKIy INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? Y N Formation Tops Y N API No. 50-029-21614-03-00 UIC N Comments: Compliance Reviewed By: __ Imo"`-' Date: _~ / L1 '`~~ 'OPERABLE: 18-14C (PTD #2010) Tubing Integrity Restored ~ Page 1 of 2 Regg, James B (DOA) ___ ~.~ __ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ Sent: Sunday, April 26, 2009 10:16 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Sinyangwe, Nathan; Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 18-14G (PTD #2081510) Tubing Integrity Restored All, Well 18-14C (PTD #2081510) passed an MIT-IA on 04/25/09 after dummy gas lift valves were set. The passing test confirms that tubing integrity has been restored. The well has een rec asst le as perable and may be returned to production when slickline operations have been completed. Please use caution when putting the well ,~ on production as the IA is liquid packed and will pressure up due to thermal expansion. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 08, 2009 7:37 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl DS Ops Lead; GPB, FSi OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, EOC Specialists Cc: Sinyangwe, Nathan; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 18-14C (PTD #2081510) TxIA communication All, Well 18-14C (PTD #2081510) has been confirmed to have TxIA communication. The wellhead pressures were equal to tubing/IA/OA 878/2260/40 on 04/04/09 and the failed a TIFL on 04/07/09 due to overnight pressure build- up. The well has been reclassified as Under Evaluation and may remain online while further diagnostics are completed. The plan forward includes: 1. DHD: TIFL -FAILED 2. WIE: Evaluate for GLV change out 3. slickline: Change out GLVs 4. DHD: Re-TIFL post GLV c/o 8/6/2009 OPERABLE: 18-14C (PTD #2010) Tubing Integrity Restored ~ Page 2 of 2 A TIO plot and wellbore schematic have been included for reference. « File: 18-14C TIO Plot.doc » Please let us know if there are any questions. Thank you, Anna Dude, 2'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907 659-5100 x1154 8/6/2009 UNDER EVALUATION: 18-1~(PTD #2081510) TxIA communicati~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~~ ~ / l 41 Sent: Wednesday, April 08, 2009 7:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Sinyangwe, Nathan; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 18-14C (PTD #2081510) TxIA communication Attachments: 18-14C TIO Plot.doc; 18-14C.pdf ~ - C~3t_ All, Well 18-14C (PTD #2081510) has been confirmed to have TxIA communication. The wellhead pressures were equal to tubing/IA/OA 878/2260/40 on 04/04/09 and the failed a TIFL on 04/07 09 due to overnight pressure build- up. The well has been reclassified as Under Evaluation and may remain online while further diagnostics are completed. -- The plan forward includes: 1. DHD: TIFL -FAILED 2. WIE: Evaluate for GLV change out 3. Slickline: Change out GLVs 4. DHD: Re-TIFL post GLV c/o A TIO plot and wellbore schematic have been included for reference. «18-14C TIO Plot.doc» «18-14C.pdf» ~..- Please let us know if there are any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/14/2009 PBU 18-14C PTD #2081510 4/8/2009 TIO Pressures 4,000 3,000 2,000 i 1,onn -#-- T bg -~ IA --~- OA OOA oaoA On • 01110109 0111?!09 01124109 011'31109 0210?109 02114109 02/21109 02128109 0310?!09 03/14/09 03121109 03128:'09 04104109 TREE= 7-1/16" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' _ Max Angle = 97 @ 12218' Datum MD = 9159' Datum TVD = 8800' SS 18-14C DRLG DRAFT 10-3/4" CSG, 45.5#, L-80, ID = 9.953" 3452' TOP OF 5-1/2"" SCAB LNER 3530' Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 5-1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~-1 8700 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" 9118' PERFORA TION SLINA~IA RY REF LOG: MCNL Log CCL/GR/CNL O6-OCT 08 ANGLE AT TOP PERF: 89 ~ 10860' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10860-10890 O 10/07/08 1.56" 6 10920-10990 O 10/07/08 1.56" 6 10080-11 f 30 O 10/07/08 1.56" 6 11280-12080 O 10!07/08 1.56" 6 12470-12490 O 10!07/08 1..56" 6 12530-12fi10 O 10/07/OS ~~~ ' r l ~O -1 :>8 ,Si C) t t1'Ci r (t3F, ~~ '~ I 5-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ~ = 4.767" 10312' O 2213' ~ 3-1 /2" CAMCO TRM-4E TRSSSV, ID = 2.812" LOCKED OPEN (02/28/08) GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LTCH PORT DP. 3 324f? 3240 1 KBG2-9 DOME INT 16 10/x' 2 5751 550x, 39 KBG2-9 SO INT 20 10/ 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/0 3530' - 17' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-518" X 5-1/2" BKR ZXP LTP, ID = 4.910" 3543' 7-5/8" X 5-1/2" FLEX LOCK HGR, ID = 4.820 8509' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-1 /2" BKR H PKR, ID = 4.812" $522' 5-1/2" HMC LNR HGR, ID = 4.938" 9041' 3-112" HES X NIP, ID = 2.813" 9062' -'+5-1/2" X 3-1/2" BKR S-3 PERM PKR, ID = 2.770" 9086' 3-112" HES X NIP. ID= 2.75'" 9106' 3.1 ?" 1 iES X NIP, ID = 2.750" 9118' 3-1/2" VULEG, ID = 2.992" 5-1 /2" BKR LNR TOP TIEBA CK, ID = 4.24" 5-112" X 3-117' BKR ZXP LTP, ID = 3.410" 10010' 1~ 2.74 BKR KB LTP, ID = 10590' -1 LNR TOP PKR DID NOT SET 10593' 2 3/8" TOP OF LNJER Depbyment Sleeve MILLOUT WINDOW (18-14C) 10710' - 10715' 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 12904 TD 12867 PBTD 10710' (STOP 3 112" NMIPSTOCK ~ 3-1/2" LNR, 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" 1 12201' i-I PBTD DATE REV BY COMMENTS DATE REV BY COMMFIJ-fS 11/08/86 ORIGINAL COMPLETION 11/10/08 JGNVSV SET KB PKR (11/02!08) 02/25/95 R!G SIDETRACK (18-14A) 04/01/95 CTD (2-718" SLTD LNR) 03/13/04 DAVIKA RIG SIDETRACK (18-14A) 10/08/08 Nordic 1 CTD Sidetrack (18-14C) 11/10/08 CJN/SV GLV C/O (10/28/08) & CORR PRUDHOEBAY UNfT WELL: 18-i4C PERMfT No: 82081320 API No: 5l)-U29-21614-U3 SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL BP Exploration (Alaska) INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7~h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 18-14C Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ~~ 1 LDWG lister summary 'E ~ 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2218427 Sent by: Terri Tuminello Date: 01/23 Received by:~l Date: ~~~~~~ 2 ~ ~~~~ ~das4~a GiE ~ Gas Cars. Gar~~s?iss9o~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING~'~~'crTURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~Ga~ ~ MI6Nl~i INTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~' CUMYANY WELL NAME . ~ ~ ~s` ~/ ~~ BAKER F~Y6F~ES Barer Atlas PRINT DISTRIBUTION LIST BY EXYLUKA'I'IUN (ALASKA) 1NC C:UUN f Y NUK"1'H SLUYIr BUKUUGH 1 R-14C STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/23/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO # 2218427 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This Distribution List Completed Bv: ~~~~fS~ Page 1 of 1 12/18/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.5011 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wull I..h u I• i• 11-34 12071901 USIT [.~ _ 10/17/08 V VIVI 1 VV 1 V-219 12103700 USIT ~ 11/21/08 1 1 D-12 12113022 INJECTION PROFILE 'fj 12/05/08 1 1 R-11A 12096929 USIT (; 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG (p - ~ '~- ~ a 12/06/08 1 1 F-19 AWJI-00011 MEM LDL v 12/08/08 1 1 18-29B AWJI-00010 MEM LDL (, ~ 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE fO~ --(S 12/04/08 1 1 18-14B 12005233 MCNL ~ - 09/21/08 1 1 18-066 12083417 MCNL ~ 10/28/08 1 1 18-14C 12066551 MCNL 10/06/08 1 1 05-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 1 L ~o - ~~ 3 i s wt -r -r ~ - ~ c DI CACC A/`ICHIl11AII CI'f!!G o~ nonr w c~~~u u~i. . -_._ - _ _._.__.___.-.__.-_. ~.-.....~....~..... .-....., .v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth Received by: "® Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, December 01, 2008 1:50 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU 18-14C / PTD # 208-151 H i Art, Please reference the fallowing well: Wel! Name: PBU 18-14C Permit #: 208-151 API #: 50-029-21614-03-00 Top Perf MD: 10860' Bottom Perf MD: 12859' This well began Production on November 26, 2008 Method of Operations is: Flowing Date of Test: November 26, 2008 Hours Tested: Flowing 24-Hour Rate /Oil-Bbl: 2,280 24-Hour Rate /Gas-Mcf: 9,253 24-Hour Rate /Water-Bbl: 51 Test Rate 1 Oil-Bbl: 1,330 Test Rate 1 Gas-Mcf: 5,39$ Test Rate /Water-Bbl: 30 Choke Size: 61 Gas-Oil Ration: 4,058 Flow Tubing Pressure: 876 Casing Pressure: 1,220 Oil Gravity-API: 33.8 12/1/2008 /~~ BAKER NElGHES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 07, 2008 Please find enclosed directional survey data for the following wells: 06-23C 07-30B 18-14C 18-24B 18-06B Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~.~~.o~ ,State of Alaska AOGCC DATE: 1 t7 IJ c~ ~8 Cc: State of Alaska, AOGCC ~.~~ -IS 1 ., STATE OF ALASKA ~ ALASK~IL AND GAS CONSERVATIOI~~~~N1l&I'~Tl WELL COMPLETION OR RECOMPLETION REPORT ANR LOG ,- //SOS 1 a. Well Status: ®bil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: 20AAC25.105 zoAAC2s.~~o ®Development' ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Strati raphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10 008 208-151 - 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/28/2008 i 50-029-21614-03-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 10/3/2008 - PBU 18-14C 4351 FSL, 4609 FEL, SEC. 19, T11N, R15E, UM Top of Productive Horizon: 8. KB (ft above MSL): 46.4 15. Field /Pool(s): 884' FSL, 3644' FEL, SEC. 19, T11 N, R15E, UM Ground (ft MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 214' FSL, 2503' FEL, SEC. 19, T11 N, R15E, UM 12867' - 8759' - 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692104 y- 5960948 Zone- ASP4 12960' ~ 8767' , ADL 028321 TPI: x- 693171 y_ 5957508 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 694332 y- 5956867 Zone- ASP4 2213' 2213' 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): i ni i f i n r N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed informati per 20 AAC 25 071): MWD, GR, RES, MCNL ~//NDO/JGa /D~~I~ ~~i~ld ~ ~j~~Tl~~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVO HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " H-4 1 S 1 P I / " -/" 4.7 1 ~ ~ ~~ 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of To 8 Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MO PACKER SET MD p 1 56" Gun Diameter 6 spf 3-1/2", 9.3#, 13Cr80 / 9Cr 9118' 9062' . , MD TVD MD TVD 10860' - 10890' 8749' - 8749' CEMENT SQUEEZE ETC. FRACTURE Ac10 25 10920' - 10990' 8749' - 8749' , , , . 11080' - 11130' 8749' - $750' DEPTH INTERVAL MD AMOUNT $t KIND OF MATERIAL USED 11280' -12080' 8755' - 8754' 12470' 12490' 8753' 8754' 2500' Freeze Protect w/ Diesel - - 12530' -12610' 8756' - 8758' 12700' - 12859' 8754' - 8758' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ~ No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~lD--~ . ... k ~ g '...::.. F s.i ... ~~j f,~`i ~ ZQ~~ , r :. ~...,,~.,,~.~.+ Form 10-407 Revised 02/2007 ~ r ~ ~ ~4t` CONTINUED ON REVERSE SIDE ~ 1 4 '~~L~ G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kicked off in Zone 1A None (From 18-14B) Zone 1A /TDF 10448' 8729' Formation at Total Depth (Name): Zone 1A /TDF 10448' 8729' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. Signed Terrie Hubble ~_Title Drilling Technologist Date ' ~~ i~ PBU 18-14C 208-151 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRa.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 28: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: ~Q~~~C ~ Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT ~~ Phase Description of Operations 9/25/2008 22:00 - 22:15 0.25 MOB -- P PRE - -- Prepare to move rig off of well. Jack up and warm up tires. 22:15 - 22:30 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving rig to DS 18-14BL1. 22:30 - 00:00 1.50 MOB P PRE Move rig to DS 18-14BL1. 9/26/2008 00:00 - 05:00 5.00 MOB P PRE Move Nordic 1 ri on Oxbow road to West Dock road to DS18 05:00 - 11:00 6.00 MOB N WAIT PRE While moving rig past Doyon 14 rig. The rear tire went thru the 11:00 - 11:30 0.50 MOB P PRE 11:30 - 11:45 0.25 MOB P PRE 11:45 - 12:00 0.25 MOB P PRE 12:00 - 16:00 4.00 MOB P PRE 16:00 - 18:30 2.50 MOB P PRE 18:30 - 18:45 0.25 MOB P PRE 18:45 - 19:40 0.92 MOB P PRE 19:40 - 00:00 4.33 BOPSU P PRE 9/27/2008 00:00 - 01:00 1.00 BOPSU P PRE 01:00 - 01:30 0.50 MOB P PRE 01:30 - 01:45 0.25 MOB P PRE 01:45 - 02:45 1.00 RIGU P PRE 02:45 - 04:40 1.92 RIGU P PRE 04:40 - 04:50 0.17 RIGU P PRE 04:50 - 05:50 1.00 RIGU P PRE 05:50 - 07:00 I 1.171 RIGU I P I I PRE 07:00 - 08:45 1.75 WHIP P WEXIT 08:45 - 09:00 0.25 WHIP P WEXIT 09:00 - 10:45 1.75 WHIP P WEXIT pad near a wet area with thin [2-aft] gravel on the pad. Jacked rig out using rig mats and plywood. Move rig to DS 18-14BL1 and position rig in front of well. SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over the well. Back rig over well and center over well. Set down rig. ACCEPT RIG AT 12:00 HRS, 09/26/2008 ON DS 18-14BL1 Position trailer and tanks, rig up hardline to Tiger Tank. N/U BOP Stack. Position injector head. M/U and pull test CT internal grapple. Pull CT stub to reel. Prep for BOP test and reel swap. SAFETY MEETING. PJSM for swapping reels. Hazards discussed were overhead loads, communication and falling objects when the reel door is opened. Lower 2" a-free work string down onto trailer and secure. Hook up to 2" a-line reel and lift into reel house. Test BOP. Test is witnessed by AOGCC official Lou Grimaldi. Also test pit level indicators and all gas alarms. Pit level sensor for pit 1 failed. Continue BOP test. Load BPV lubricator and pulling equipment to rig floor. SAFETY MEETING. PJSM for pulling BPV. Pull BPV. Well is on slight vac. Load out BPV equipment. Inspect injector chains, replace failed bearings. Fill well with 6 bbls while waiting. SAFETY MEETING. PJSM for pulling CT across pipe shed roof. Crew positions and procedure was discussed. Install grapple in CT end. Pull test. Pull CT across pipe shed and into injector. Cut off grapple and install cable boot. M/U CT riser, line up to pump backwards to fill reel. Pump 20 bbls fresh water followed by 2# biozan to fill reel. Reverse circ at 3.0 bpm, 4200 psi, 5 times to pump slack into coil. Cut off 105' of coil, found E-Line at 60'. M/U Kendle CTC. Pull test. M/U CoilTrak UOC and test E-Line, OK. SAFETY MEETING. Review procedure, hazards and mitigation for M/U Baker whipstock and CoilTrak BHA. M/U Baker Monobore 3-1/2" Retrievable Whipstock to CoilTrak tools. Install 2 SWS PIP tags into Whipstock tray 5.35' from top of tray. BHA OAL = 66.69'. Printed: 10/30/2008 11:26:49 AM 5-~a, ~ $. BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date ;From - To Hours Task Code NPT Phase Description of Operations 9/27/2008 10:45 - 13:15 2.50 WHIP P WEXIT RIH with BHA #1, BOT 3-1/2" Monobore RWS Whipstock setting BHA. Check CoilTrak tools at surface. Open EDC. Circ at 0.1 bpm, 600 psi. 13:15 - 13:45 0.50 WHIP P WEXIT Log GR tie-in with GEO log. -16' CTD. 13:45 - 14:10 0.42 WHIP P WEXIT RIH and position top of Whipstock at 10710' with a 90 LOHS TF. Close EDC. Press up and set Whipstock with #10J setting tool at 4200 psi. 14:10 - 16:00 1.83 WHIP P WEXIT POH with setting tools while Circ well to 2# Biozan. 16:00 - 16:30 0.50 WHIP P WEXIT La out Whi stock runnin tools. - 17:15 0.75 STWHIP P WEXIT M/U 2.74" window milling BHA #2 with 2.74" HCC diamond window mill and string reamer, motor, 2 jts CSH and CoilTrak. BHA OAL = 99.26'. 17:15 - 19:25 2.17 STWHIP P WEXIT RIH with milling BHA #2. circ at 0.2 bpm, 1200 psi. I/, ~ 19:25 - 21:00 1.58 STWHIP P WEXIT flag whipstock with min pump rate and correct -15 ft to 10,710 "1 Pick up and bring pump up. Up weight is 34 Klbs. Free spin is 3120 psi at 1.50 / 1.48 bpm. Ease down and tag whipstock to start milling. Stall at 10,708.8 ft, then steady progress after that. TOW = 10,708.8 ft. . 21:00 - 00:00 3.00 STWHIP P WEXIT Mill at 10,709.8 ft ~ 1.44 / 1.44 bpm 3040 psi. DWOB = 1.40 Klbs. 22:00 - 10,710.8 ft 1.43 / 1.43 bpm ~ 3130 psi. DWOB = 2.39 Klbs. 23:00 - 10,710.85 ft 1.51 / 1.52 bpm C~3 3,220 psi. DWOB = 1.84 Klbs. 9/28/2008 00:00 - 04:00 4.00 STWHIP P WEXIT Continue milling window. 00:00 - 10,711.62 ft 1.52 / 1.52 bpm ~ 3170 psi. DWOB = 1.83 Klbs. 01:00 - 10,712.50 ft 1.51 / 1.51 bpm ~ 3060 psi. DWOB = 1.61 Klbs. 02:00 - 10,712.90 ft 1.50 / 1.50 bpm C~3 3030 psi. DWOB = 1.76 Klbs. 03:00 - 10,713.70 ft 1.50 / 1.50 bpm ~ 3100 psi. DWOB = 1.90 Klbs. Stall at this depth, then loss of DWOB and motor work. Likely window exit at 10,713.7 ft. 04:00 - 05:40 1.67 STWHIP P WEXIT Continue milling 1 fUhr until string reamer exits. Drill 10 ft of rathole to 10,725 ft at 10 - 15 ft/hr. Trace of formation in 10,714 sample. 05:40 - 06:20 0.67 STWHIP P WEXIT Perform 3 up and down passes through window at slow speed. Dry run through window shows no weight bobbles. 06:20 - 08:45 2.42 STWHIP P WEXIT POOH with window milling BHA. 08:45 - 09:00 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for changing BHA's. 09:00 - 09:45 0.75 STWHIP P WEXIT L/O milling BHA. Mills gauged at 2.73" go/1.72" no-go. 09:45 - 10:15 0.50 STWHIP P WEXIT C/O CT pack-off and repair hyd hose. 10:15 - 11:00 0.75 DRILL P PROD1 M/U CoilTrak Turn/RES BHA #3. HYC BC Bit #1, 1.9 deg Xtreme motor, CoilTrak with RES. BHA OAL = 67.76'. 11:00 - 13:00 2.00 DRILL P PROD1 RIH with CoilTrak Turn/Res BHA #3. Circ at 0.1 bpm. 13:00 - 13:30 0.50 DRILL P PROD1 Log GR tie-in from 10350-10400'. -17' CTD. 13:30 - 14:45 1.25 DRILL P PROD1 Drill Z1A left turn section. 1.6 bpm, 3650-4200 psi, 88 deg Printed: 10/30/2008 17:26:49 AM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To ', Hours Task .Code NPT Phase Description of Operations ---... --_ - --_ 9/28/2008 13:30 - 14:45 1.25 DRILL P PROD1 incl, 90L TF, 50-60 fph, 1-2K WOB, 10.8 ecd, Drilled to 10780'. 14:45 - 17:40 2.92 DRILL P PROD1 Drill Z1A left turn section. 1.6 bpm, 3650-4200 psi, 90 deg incl, 80L TF, 40 fph, 1-2K WOB, 10.8 ecd, Drilled to 10875'. 17:40 - 17:50 0.17 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 17:50 - 20:30 2.67 DRILL P PROD1 Drill Z1A left turn section. 1.7 bpm, 3800-4200 psi, 90 deg incl, 80L TF, 40 fph, 1-2K WOB, 10.8 ecd. After 10,830 ft DLS goes to 20 - 25 deg/100 ft. Drill to 11,000 ft. Not getting more than 24 deg/100 ft, need 31 de /100 ft from this point forward to stay in the polygon. 20:30 - 22:50 2.33 DRILL P PROD1 POOH for AKO change. Pull through window and open EDC, pump max rate OOH. 22:50 - 23:00 0.17 DRILL P PROD1 SAFETY MEETING. Discuss hazards and mitigations for change out motor bend. 23:00 - 00:00 1.00 DRILL P PROD1 Tag stripper. Break off CT riser and change bend on motor from 1.9 deg to 2.1 deg. Bit is in new condition, re-run it. 9/29/2008 00:00 - 02:20 2.33 DRILL P PROD1 RIH with BHA #4 - 3.0 bi-center bit + 2.1 deg AKO motor + 2-3/8" CoilTrak with Res. 02:20 - 02:40 0.33 DRILL P PROD1 Start logging down from 10,740 ft to find RA tag. Correct -19 ft. 02:40 - 05:45 3.08 DRILL P PROD1 RIH to find bottom. Drill Zone 1 A left turn. Maintain 90L toolface. Drill at 1.62 / 1.61 bpm ~ 3600 - 4000 psi. Initial ROP is 70 - 100 ft/hr with 2-3 Klbs DWOB. First 3 surveys showing less turn than anticipated. 05:45 - 06:15 0.50 DRILL P PROD1 Wiper trip from 11,150 ft to window. 06:15 - 08:00 1.75 DRILL P PROD1 POH for 2.6 deg motor. 08:00 - 08:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing CoilTrak BHA. 08:15 - 09:15 1.00 DRILL P PROD1 Adjust motor to 2.6 de AKO M/U Bit # HYC BC, RAPTOR. /U Coiltrak and RES tool. BHA OAL = 67.76'. 09:15 - 11:30 2.25 DRILL P PROD1 RIH with CoilTrak /RES Turn BHA #5. Circ at 0.2 bpm. 11:30 - 11:45 0.25 DRILL P PROD1 Log GR tie-in at RA tag. -7' CTD. 11:45 - 12:00 0.25 DRILL P PROD1 RIH clean to bottom. 12:00 - 13:45 1.75 DRILL P PROD1 Drill Z1A Turn section, 1.5 bpm, 3600-4300 psi, 80L, 89 deg incl, 40 fph, 11.0 ecd, full returns, 38 Deg DLS Drilled to 11225'. 13:45 - 15:45 2.00 DRILL P PROD1 Drill Z1A Turn section, 1.5 bpm, 3600-4300 psi, SOL, 89 deg incl, 40 fph, 11.0 ecd, full returns, 38 Deg DLS, Drilled to 11290'. 15:45 - 16:15 0.50 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 16:15 - 18:00 1.75 DRILL P PROD1 Drill Z1A Turn section, 1.6 bpm, 3700-4300 psi, 90L, 90 deg incl, 40 fph, 11.0 ecd, full returns, 38 Deg DLS, Drilled to 11350'. 18:00 - 20:30 2.50 DRILL P PROD1 POH. Pull through window and open EDC. Make an additional pass up and down through the 5" casing section. 20:30 - 20:45 0.25 DRILL P PROD1 SAFETY MEETING. Discuss hazards and mitigations for L/D BHA and cutting coil. 20:45 - 21:10 0.42 DRILL P PROD1 Tag stripper. UD BHA #5. Bit is in new condition, re-run it for the next Printed: 10/30/2008 11:26:49 AM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date From. - To I Hours Task 'Code. N'PT Phase Description of Operations 9/29/2008 20:45 - 21:10 0.42 DRILL P PROD1 section. 21:10 - 23:30 2.33 DRILL P PROD1 Rig up hydraulic CT cutter. Cut 100' of CT for chrome management. Dress end of CT and install SLB connector and BHI cable head. Pull test CT connector to 35 Klbs, good. PT to 3,500 psi, good. 23:30 - 00:00 0.50 DRILL P PROD1 M/U BHA #6 - 3.0" HYC Raptor bi-center + 2-3/8" CoilTrack with Res. BHA OAL = 67.76' 9/30/2008 00:00 - 03:00 3.00 DRILL P PROD1 RIH with BHA #6. Log from 10,740 ft down to see RA tag, correct -17 ft. Problem with BHI computer, pull back through window and re-boot system. 03:00 - 03:25 0.42 DRILL P PROD1 Pass through window and RIH to bottom. Take weight at 11,280 ft and 11,300 ft. 03:25 - 06:00 2.58 DRILL P PROD1 Drill from 11,350 ft at initial TF 90L, continue left turn. Free spin is 3,700 psi at 1.58 / 1.56 bpm. Drill with 1-3 Klbs DWOB, 3-10 Klbs CT wt, ROP is 20-50 ft/hr with weight stacking. Start mud swap at 11,375 ft. New free spin is 2,800 psi at 1.59 / 1.56 bpm. Drilled to 11430'. 06:00 - 08:00 2.00 DRILL P PROD1 Drill Z1A Lateral, 1.6 bpm, 2850-3800 psi, 80R TF, 94 deg incl, 40 fph, 10.2 ECD Drilled to 11500'. 08:00 - 08:50 0.83 DRILL P PRODi Wiper trip to window. RIH clean to bottom. 08:50 - 11:00 2.17 DRILL P PROD1 Drill Z1A Lateral, 1.6 bpm, 2850-3600 psi, 120R TF, 91 deg incl, 50 fph, 10.3 ECD Drilled to 11,590'. 11:00 - 13:00 2.00 DRILL P PROD1 Drill Z1A Lateral, 1.6 bpm, 2850-3600 psi, 90R TF, 89 deg incl, 50 fph, 10.4 ECD Drilled to 11650. 13:00 - 13:50 0.83 DRILL P PROD1 Wiper to window. 13:50 - 16:45 2.92 DRILL P PROD1 Drill Z1A Lateral, 1.6 bpm, 2850-3600 psi, 270R TF, 86.6 deg incl, 30-50 fph, 10.35 ECD Drill to 11800 16:45 - 19:10 2.42 DRILL P PROD1 Wiper to tail pipe. Log RA tag from 10,740 ft downwards. Correct +10 ft. RIH to bottom, clean pass. 19:10 - 23:40 4.50 DRILL P PROD1 Drill from 11,800 ft. Start turn back to left and hold 88-89 deg inc. Some weight stacking, drill at 6-9 Klbs CT wt with 2-3 Klbs DWOB, ROP is 40 - 80 ft/hr. 1.63 / 1.59 bpm ~ 3200-4000 psi. Drill to 11,950 ft. 23:40 - 00:00 0.33 DRILL P PROD1 Wiper trip to window. 10/1/2008 00:00 - 01:15 1.25 DRILL P PROD1 Continue wiper trip from 11,950 ft to window. Re-log section from 11,795 ft to 11,850 ft. 01:15 - 05:15 4.00 DRILL P PROD1 Drill from 11,950 ft. PVT = 277 bbls, losing 2-4 bbls/hr. 90R toolface maintain 86-87 deg inc as per plan. 1.66 / 1.63 bpm C~? 3200 psi FS and 3500 - 4100 psi while drilling. ECD = 10.74 PPg• Some difficulty sliding past 11,960 ft, CT wt is <0 with DWOB 2-3 Klbs. Drill to 12,056 ft with slow progress. 05:15 - 08:00 2.75 DRILL P PRODi POOH for agitator. Printed: 10/30/2008 11:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 18-14 Page 5 of 12 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date !, From - To Hours Task Code NPT Phase ', Description of Operations 10/1/2008 08:00 - 10:30 2.50 DRILL P PROD1 LD BHA PU agitator new DGS & USR. Bit 1,1 10:30 - 12:30 2.00 DRILL P PROD1 RIH 12:30 - 13:00 0.50 DRILL P PROD1 Log tie-in. Correction -21'. 13:00 - 13:30 0.50 DRILL P PROD1 RIH and tag at 12059. Swapping to new mud. 13:30 - 17:20 3.83 DRILL P PROD1 1.4/1.37 bpm ~ 3760 psi, 3330 psi FS. ROP 75,W0B 1.56K,ECD 10.82. Drill to 12200. 17:20 - 18:55 1.58 DRILL P PROD1 Wiper to window. Clean pass up and down. 18:55 - 22:15 3.33 DRILL P PRODi Drill from 12,200 ft. Free spin is 3,450 psi at 1.48 / 1.45 bpm. PVT = 317 bbls. Near bit inc = 94.3 deg, drill at 140R TF to level out and maintain 8,704 ft TVD. Drill at 3,500-4,000 psi with CT wt of 10-12 Klbs, DWOB = 1-2 Klbs. Initial ROP is 80-100 ft/hr. After 12,240 ft ROP slows to 10-40 ft/hr with weight stacking. Point tool straight down to try and reduce inc to 86 deg, formation is making steering difficult. Likely in Zone 1 B. Drill to 12,350 ft. 22:15 - 23:55 1.67 DRILL P PROD1 Wiper trip to window. Clean pass up and down 23:55 - 00:00 0.08 DRILL P PROD1 Drill from 12,350 ft. Maintain 86 deg inc. 10/2/2008 00:00 - 02:05 2.08 DRILL P PROD1 Continue drilling past 12,350 ft. ROP is 20 - 50 fUhr. 1.53 / 1.46 bpm ~ 3500-4000 psi. CT wt <0 with DWOB 0-2 Klbs. PVT = 296 bbls. Drill to 12,499 ft. 02:05 - 05:20 3.25 DRILL P PROD1 Wiper trip + tie-in. 60 Klbs up weight off bottom. Clean 5" section of casing. Correct +10 ft after tie-in. Continue wiper trip to bottom. 05:20 - 09:00 3.67 DRILL P PROD1 Drill from 12,500 ft. Hold 86 deg inc. Initial ROP is 80-120 ft/hr, 1.43 / 1.37 bpm C~ 3600-4500 psi. PVT=284 bbls, ECD = 10.81 ppg. DWOB = 1-2 Klbs with 0-10 Klbs CT wt. Stacking weight past 12,515 ft. Drill to 12637. Differentially 09:00 - 13:45 4.75 DRILL N STUC PROD1 13:45 - 14:00 0.25 DRILL N STUC PROD1 14:00 - 17:45 3.75 DRILL N STUC PRODi 17:45 - 17:50 0.08 DRILL P PROD1 17:50 - 20:00 2.17 DRILL P PROD1 20:00 - 22:40 2.67 DRILL P PROD1 Order Crude. Pull 60 K hold NO GO. Slackoff and wait NO GO. Circulate bottoms up no shale in returns. Pull 60K 15 min No Go. Slack off. No Go. periodically circulate to warn coil.1.32/.124 bpm. PJSM for pumping crude. Circulate 10 bbl crude to bit. 1.32 BPM ~ 3840 psi. Pump 6 bbl out Let soak.NO Go PULL 60K wait 30 min .NO GO. Pump 1 bbl Slack off wait 30 min . No Go .Pump 1 bbl Pull 60K.Hold 30 min . No Go.Circulate out Crude. We are able to orient Bit No Problem. See DWOB sensor change 1 K. Pump at max rate no evidence thar agitator working based on down hole vibration sensor. Pump 20 bbl to bit and 10 bbl in open hole. Slack neutral wt and wait 30 min.let crude soak. Pull free with 44K. Circulate balance of crude out of CT. RIH tag at 12630. Wiper to window. Circulate crude + light mud out to flowback tank. After crude is out, tie-in log from 10,740 ft down. Correct +7 ft. Up weight is 34 Klbs just off bottom Tag bottom at 12,639 ft and drill ahead. Initial ROP is around 100 ft/hr. Drill at 1.46 / 1.38 bpm ~ 4000-4400 psi. Printed: 10/30/2008 11:26:49 AM • BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: i I Date ! From - To Hours ~ Task Code NPT Phase Description of Operations 10/2/2008 20:00 - 22:40 2.67 DRILL P PROD1 Start new mud down the CT. Drill to 12,662 ft and stack out, up wt is 52 Klbs. Frequent pickups and weight stacking. ECD = 10.41 ppg. Drill at various pump rates 1.35-1.52 bpm to try and improve weight transfer. Reduce inc to 85-86 deg. Drill to 12,755 ft. - 22:40 - 00:00 1.33 DRILL P PROD1 Wiper trip to window. Clean pickup off bottom. 10/3/2008 00:00 - 00:20 0.33 DRILL P PROD1 Continue wiper trip from 12,755 ft. - 00:20 - 01:20 1.00 DRILL P PROD1 Drill from 12,755 ft~ Hold 180E TF initially to try and reduce inc to 85-86 deg. Drill at 1.47 / 1.40 bpm ~ 3300-4000 psi. ROP is 40-90 fUhr with CT wt 0-5 Klbs, DWOB 0-1 Klbs. Frequent pickups and weight stacking. Drill to 12,791'ft at pick up to 60 Klbs, differentially stuck. Work pipe several times with pump on and off, not able to pull free. Able to turn orientor freely and circulate full rate. Relax CT to neutral wt and order crude. 01:20 - 02:20 1.00 DRILL P PROD1 Shut off pump for 10 min and relax hole. Work pipe several times and free it with 58 Klbs ull. Wiper trip ack to 12,000 ft. 02:20 - 04:10 1.83 DRILL P PROD1 Bottoms up sample shows no shale. Drill from 12,791 ft.-1.49 / 1.44 bpm C~ 3500-3900 psi. Maintain 180E TF to reduce inc to 80 deg, near bit inc is now around 87 deg. Drill to 12,850 ft and stack weight, pull 100 ft wiper. At 12,870 ft PVT = 309 bbls. Drill to 12,886 ft- 04:10 - 05:55 1.75 DRILL P PROD1 Wiper to window. Mostly clean pass up and down. 05:55 - 08:00 2.08 DRILL P PROD1 Drill from 12,886 ft. _1.52 / 1.42 bpm ~ 3700-4200 psi. Hold 180E TF. CT wt is 0-2 Klbs with DWOB 1-2 Klbs. TD called at 12958.- 08:00 - 09:30 1.50 DRILL P PROD1 Wiper to window. 09:30 - 09:40 0.17 DRILL P PROD1 Tie-in LOG. +3' correction. 09:40 - 11:30 1.83 DRILL P PROD1 Wiper to TD 11:30 - 15:00 3.50 DRILL P PROD1 Madd pass to window 15:00 - 16:00 1.00 DRILL P PROD1 RIH Tag TD Spot liner pill with beads. 16:00 - 18:00 2.00 DRILL P PROD1 POH spot pill. Pin Hole at 8026. 18:00 - 19:10 1.17 DRILL P PROD1 Flag pinhole and POOH. Circ across kill line while POOH. 19:10 - 19:25 0.25 DRILL P PROD1 SAFETY MEETING. Discuss hazards and crew positions for UD BHA. Minimizing people on rig floor. 19:25 - 20:00 0.58 DRILL P PROD1 UD BHA #7. Bit is 3-1. 20:00 - 20:20 0.33 CASE P RUNPRD Fill well with 1.2 bbls. Shut in swab valve. 20:20 - 20:50 0.50 CASE P RUNPRD Circulate 10 bbls inhibitor + 40 bbls fresh water + 5 bbls McOH. PJSM with N2 crew for N2 pumping. 20:50 - 21:40 0.83 CASE P RUNPRD PT N2 line to 3000 psi. Purge reel with 1,200 scfm for 15 min. Bleed off pressure. 21:40 - 22:40 1.00 CASE P RUNPRD Break off CT riser. Remove nozzle and rest of BHI cable head. Cut off CT connector. Install grapple, prep for pulling CT across pipe shed. Pull CT across and onto reel. Install shipping bar and secure CT end, cut off the rest. Printed: 10/30/2008 11:26:49 AM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task ~ Code NPT .Phase Description of Operations 10/3/2008 22:40 - 22:50 0.17 CASE P RUNPRD SAFETY MEETING. PJSM with CH2 drivers for change out reel. Discuss communications and rigging/lifting. 22:50 - 23:30 0.67 CASE P RUNPRD Lower a-line reel onto trailer. Pick up a-free coil into reel house. 23:30 - 00:00 0.50 CASE P RUNPRD Attach grapple to CT. Remove shipping bar and pull across into injector. 10/4/2008 00:00 - 01:00 1.00 CASE P RUNPRD Pull CT across into injector. Install weld-on CTC. Pull test to 35 Klbs, good. 01:00 - 01:20 0.33 BOPSU P RUNPRD Function test BOPs. 01:20 - 01:50 0.50 CASE P RUNPRD M/U CT riser to well. Pump 3 bbls McOH ahead then Flo-Pro to fill reel. 01:50 - 02:30 0.67 CASE P RUNPRD Fill well with 5 bbls then break off CT riser. Line up test pump to test and chart inner reel valve. Test inner reel valve and CT connector to 450 / 3500 psi, good. 02:30 - 03:15 0.75 CASE C RUNPRD Rig up to pump a volume dart. Insert dart and launch with 500 psi. Dart lands at 41.6 bbls. 03:15 - 03:30 0.25 CASE P RUNPRD Prep to run liner. Set injector on legs, rig up elevators. SAFETY MEETING. Discuss hazards and mitigations for running liner. 03:30 - 07:15 3.75 CASE P RUNPRD Run liner as er ro ram; Guide shoe, float collar, 1 jt 2-3/8", float collar, Spacer, Landing Collar, 75 jts 2-3/8" 4.70# L-80 with cementralizers, Pup jt, Deployment sleeve, LBRT running tool, XO, Swivel, CTC. BHA OAL = 2,314.3 ft. 07:15 - 10:35 3.33 CASE P RUNPRD RIH with liner. Wt CK 32K up at 10590'.negative wt at 11950'. Working liner to bottom stacking out.++Set down stackout 12236, 12870 PU losing ground. to 12830. Circulate 1.9 bpm ~ 3920 psi. with -9K stacked out. Work liner to 12936. Stack -6K and circulate. No Go. Thats it. 10:35 - 11:20 0.75 CASE P RUNPRD Launch ball 5/8 AI. with 1000 psi. Circulate ball to seat 1.93/.7 bpm ~ 3625 psi. Slow pump 1.12/.59 bpm Ball on seat with 34.5 bbls.( Dart vol 41.6) 11:20 - 14:00 2.67 CASE P RUNPRD Swap well to KCL.Loss rate 60% initially. Reduced circ rate to .75/.56bpm, & 1.5 / 1.08 bpm. 14:00 - 15:00 1.00 CASE P RUNPRD Wait on truck. Truck with contaminent pill late due to mechanical break down. 15:00 - 15:35 0.58 CEMT C RUNPRD Flood cementers lines with 2% KCL. Batch Up 11 bbl 15.8 ppg G cement. Pressure test cementers to 6000 psi. 15:35 - 16:48 1.22 CEMT C RUNPRD Mixed 11.8 bbl cement; Installed wiper dart. Purge lines behind dart with BIO. Launch dart with 600 psi.Displace with 25 bbl Bio and KCL. PU liner wiper at 41.5 bbls. bbls Pressure In Rate Out Rate 5. 2490 1.48 .97 10 1850 1.48 .97 13.5 1274 1.45 .95 18 1470 1.44 .97 25.3 1809 1.44 .96 30 2292 1.5 1.02 38.5 1.5 .82 40 2240 1.0 .66 41.5 PU liner wiper plug shear at 4000 psi. Printed: 10/30/2008 11:26:49 AM ~ ~ BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: L , Date From.- To I~, Hours Task 'Code NPT Phase Description of Operations 10/4/2008 15:35 - 16:48 I 1.22 CEMT C 16:48 - 18:50 2.03 CEMT C 18:50 - 19:20 0.50 CEMT C 19:20 - 21:15 1.92 EVAL C 21:15 - 21:50 0.58 EVAL C 21:50 - 23:10 1.33 EVAL C 23:10 - 23:40 0.50 EVAL X 23:40 - 00:00 0.33 EVAL C 10/5/2008 00:00 - 00:40 0.67 EVAL C 00:40 - 01:00 0.33 EVAL C 01:00 - 02:00 1.00 EVAL C 02:00 - 04:15 2.25 EVAL C 04:15 - 04:25 0.17 EVAL C 04:25 - 06:10 1.75 EVAL C 06:10 - 12:45 ~ 6.58 EVAL ~ C 12:45 - 13:40 0.92 EVAL C 13:40 - 14:00 0.33 EVAL C 14:00 - 16:30 2.50 EVAL C RUNPRD Displace to landing collar Out total 42.4 0 44 2680 .96 .79 1.4 48.6 3329 .97 .79 5.2 50.5 BUMP (Calculated 50.27bbls) 6.6 Lost 1.5 bbl to formation Floats held. Up Wt 30K Break circulation with 2 bbls RUNPRD POH filling displacement. RUNPRD Tag stripper, UD liner running tools. PJSM for picking up 1"CSH. LOWERI M/U BHA #9 - CT connector, DBPV, Lockable swivel, 3/4" disconnect, XO, 78 jts 1"CSH, XO, 5/8" disconnect, 1/2" circ sub, 1.69 motor, 1.86" diamond speed mill. Fill 1 "CSH with water prior to M/U CT. LOWERI M/U CT riser. Clean out cement filter on reel manifold and test SPM pump popoffs. LOWERI RIH with BHA #9. CEMT LOWERI Wait at 8,600 ft for cement to get to 500 psi compressive. After 6hr 45min cement is at 19 psi compressive strength. LOWERI Cleanout down to 10,600 ft, just above liner top. Take weight at 10,550 ft, pick up and wash through it to 10,558 ft. LOWERI Continue cleanout to liner top. Hard cmt at 10,558 ft. Mill through it then wash down to 10,600 ft. LOWERI Pick up and circulate cmt to surface. LOWERI Cement sample is at 500 psi compressive, after 8hr 39min. RIH to wash to PBTD. Taq at 12,839 ft, about 60 ft higher than PBTD_ supposed to be. Pick up and tag here again, with motor work. Set 4 Klbs on it. Hard bottom, not drilling off. LOWERI POOH, circ full rate. LOWERI SAFETY MEETING. Discuss hazards and mitigations for standing back CSH and UD BHA. LOWERI Break off CT riser. Stand back injector. Stand back 1" CSH, find out that an extra stand had been run inadvertantly, which puts the PBTD tag where its supposed to be. LOWERI M/U CT riser with swizzle stick. Fill well with 2.5 bbls then shut in swab. Jet stack with swizzle stick. Clean cement from lower double gate and check upper double gate OK. Swab valve leaking . Regrease valves. Body test BOP. Test lower rams. LOWERI Test Liner lap to 2000 psi for 30 min. Lost 600 psi in 5 min. Failed test. LOWERI PJSM for Pu logging tools. LOWERI PU logging tools and 39 stands of 1"CSH. PU injector. and Printed: 10/30/2008 11:26:49 AM BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To ' 8-14 8-14 REENTE Hours R+COM Task ~, PLET Code E NPT Start Rig Rig Phase Spud Date: 10/22/1986 : 9/18/2008 End: 10/9/2008 Release: Number: Description of Operations 10/5/2008 14:00 - 16:30 2.50 EVAL C LOWERI stab onto well. 16:30 - 18:00 1.50 EVAL C LOWERI RIH 18:00 - 19:40 1.67 EVAL C LOWERI Log down at 30 ft/ min from 8700' to PBTD. Set down wt at 10,610 ft. Not able to work past. Pick up hole 100 ft and try again. Try to pass with higher pump rate, then with no pump rate. Pick up 500 ft and try again with pumps on, off, no-go. 19:40 - 21:30 1.83 EVAL X DPRB LOWERI POOH. Flag pipe at 10,500 ft (8057 EOP). Log up from 10,500 ft to 8,800, then POOH. 21:30 - 21:45 0.25 EVAL X DPRB LOWERI SAFETY MEETING. PJSM for standing back injector and 1" CSH. Discussed pinch points and overhead loads. 21:45 - 00:00 2.25 EVAL X DPRB LOWERI Break off CT riser. Stand back injector. Stand back 1 "CSH. 10/6/2008 00:00 - 00:15 0.25 EVAL X DPRB LOWERi Continue standing back CSH. PJSM for handling logging tools. 00:15 - 00:30 0.25 EVAL X DPRB LOWERi Remove logging tools and RA source. Download data. Correct flag depth -18 ft. 00:30 - 00:50 0.33 EVAL X DPRB LOWERI M/U BHA #11 for cleanout to top of Degjgymant SiPa~ - Welded CTC, DBPV, XO, 2 jts 1-1/4" CSH, XO, 3/4" Hydraulic Disconnect, 2-1/8" Navidrill motor, Diamond speed mill 2.74" go 2.73" no-go. 00:50 - 03:00 2.17 EVAL X DPRB LOWERI RIH BHA #11. Stop at flag and correct depth -14 ft to 8,115 ft. Continue RIH. Slight motor work and weight loss seen at 9,820 ft, pick up and go to 1.5 bpm, nothing seen. RIH from 9,800 ft at 1.43 bpm, 30 fUmin. Tag at 10,604 ft. Pick up and mill from here. 03:00 - 03:40 0.67 EVAL X DPRB LOW ERi Mill from 10 604 ft. Stall 5 times her . Appear to be drilling metal, almost no progress. Some metal on ditch magnets. 03:40 - 06:00 2.33 EVAL X DPRB LOW ER1 POOH. 06:00 - 07:10 1.17 EVAL X DPRB LOW ER1 LD Mill #1 (green Condition) and PU Deployment sleeve olishin mill. 2.21 "mill & 2.85" NO Go at 5.81'. 07:10 - 09:50 2.67 EVAL X DPRB LOWERI RIH. +6' correction to EOP flag ~ 8039. Tag 10610 09:50 - 11:45 1.92 EVAL X DPRB LOWERI POH 11:45 - 12:00 0.25 EVAL X DPRB LOWERI PJSM LD BHA & Cut Coil 12:00 - 12:30 0.50 EVAL X DPRB LOWERI LD BHA. Marks on NO GO confirm contact with top deployment sleeve also corrected depths match. 12:30 - 13:30 1.00 EVAL X DPRB LOWERI Cut 110 CT. Install Kendal connector. Pull 35K and PT connector 3800 psi. 13:30 - 14:15 0.75 EVAL X DPRB LOWERI Crew change and PJSM for PU logging tools and memory log. 14:15 - 14:30 0.25 EVAL X DPRB LOWERI PU logging tools. 14:30 - 16:45 2.25 EVAL X DPRB LOWERI RIH with 39 stands form derrick. Pu injector. Stab into well. Changeout counter wheel on injector. 16:45 - 22:00 5.25 EVAL X DPRB LOWERI RIH. Start down pass at 8,700 ft at 30 ft/min. Enter liner sleeve clean) , nothin seen on wei ht. Ta at 12,852 ft 2 times. Paint flag at 12,750 ft (8,315 ft EOP). 22:00 - 22:50 I 0.831 EVAL I C I I LOWERI I POOH. Printed: 70/30/2008 11:26:49 AM i BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Haurs ~ Tank Code NPT Phase Description of Operations 10/6/2008 22:50 - 23:05 0.25 EVAL C LOWERI SAFETY MEETING. PJSM for standing back 1"CSH. Crew positions and hand traps were discussed. 23:05 - 00:00 0.92 EVAL C LOWERI Tag stripper and break off CT riser, stand back injector. Stand back 1 "CSH. 10/7/2008 00:00 - 00:50 0.83 EVAL C LOWERI Continue standing back 1"CSH. PJSM with SLB memory logger prior to pulling source. Pull logging tools and RA source. 00:50 - 01:20 0.50 EVAL C LOW ERi Fill well with 2.2 bbls. Send MCNL tools and running equipment down. Download data. Load perforation gun running equipment to rig floor. M/U safet 'oint and prep to run erf uns. 01:20 - 01:35 0.25 PERFO C LOWERI SAFETY MEETING. PJSM for M/U perf guns. Discussed no-go areas and minimizing rig floor personnel. 01:35 - 03:30 1.92 PERFO C LOWERI Run first perf gun BHA - 429.74 ft Perf gun + firing head, 5/8" Disconnect, 32 stds 1" CSH, 3/4" Disconnect, Locking Swivel, DBPV, Welded CTC. Run all guns, Start running 1"CSH. Find out from memory logs PBTD is at 12,864 ft instead of planned 12,899 ft. Discuss plan forward with Anc Geo Doug Stoner, decide to drop 35 ft of guns from bottom. 03:30 - 03:45 0.25 PERFO X DPRB LOWERI SAFETY MEETING. PJSM for pulling 1"CSH and changing perf gun configuration. Discussed change of scope. 03:45 - 05:15 1.50 PERFO X DPRB LOWERI Pull 4 stds 1"CSH and 14 perf guns. Pull 2 x 21.33 ft guns out add an 11.33 ft. Re-run the rest of the perf guns. 05:15 - 07:00 1.75 PERFO C LOWERI Run 1"CSH. 07:00 - 10:50 3.83 PERFO C LOWERI RIH with first set of guns. Tag at 12861 correct to 12864'. PU to~ 11183 8800 EOP . Paint flag. For second run. RIH Tag . PU to ball drop position. Launch ball with 860 psi and 11 bbl pill. 1.37 bpm C~ 3940 psi. Reduce rate to .5 bpm 1527 psi @ 32 bbl.with bbl displacement. Ball on seat @ 39 bbls. Pressure to 3500 psi bottom 12859. on the fly. 1.56' 6SPF 12470-12490 12530-12610 12700-12859 10:50 - 13:00 2.17 PERFO C LOWERI POH. 13:00 - 13:15 0.25 PERFO C LOWERI PJSM for BHA 13:15 - 14:30 1.25 PERFO C LOWERI Stand back 32 stands of 1"CSH. 14:30 - 16:00 1.50 PERFO C LOWERi LD 20 1.56" perf guns. 16:00 - 16:30 0.50 PERFO C LOWERI Install and calibrate pressure gauge on pump manifold. 16:30 - 16:45 0.25 PERFO C LOWERI PJSM for PU of gun and CSH. 16:45 - 21:00 4.25 PERFO C LOWERI PU second erforatin ass 21:00 - 22:45 1.75 PERFO C LOWERI RIH w/ BHA # 15, 32 stands of CSH + 1240.28' of guns and firing head Tie-in ~ 8800' w/ EOP flag (+1.6' correction), Correct to 12,025' Continue RIH to 12,085' 22:45 - 00:00 1.25 PERFO C LOWERI Launch 1/2" AL ball with 940 psi and 16 bbl pill. 1.1 bpm ~ 2200 psi. Reduce rate to 0.7 bpm 1160 psi @ 30 bbl displacement. Ball on seat ~ 42.5 bbls. Pressure to 4100 psi shoot on the fly. Printed: 10/30/2008 11:26:49 AM ~ ~ BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 18-14 ell Name: 18-14 e: REENTE Name: From - To ,Hours R+COM Task PLET Code E NPT Start Rig Rig ~ Phase Spud Date: 10/22/1986 : 9/18/2008 End: 10/9/2008 Release: Number: Description of Operations 10/7/2008 22:45 - 00:00 1.25 PERFO C LOWERI 1.56' 6SPF 10860-10890 10920-10990 1 1 080-1 1 1 30 ~ 11280-12080 10/8/2008 00:00 - 01:45 1.75 PERFO C LOWERI POOH to lay down BHA 01:45 - 02:00 0.25 PERFO C LOWERI PJSM for standing back CSH, discuss procedures, hazards, and mitigations. 02:00 - 03:15 1.25 PERFO C LOWERi Stand back CSH 03:15 - 03:30 0.25 PERFO C LOWERI PJSM for LD spent pert guns, discuss procedures, hazards, and mitigations. 03:30 - 07:30 4.00 PERFO C LOW ERi LD perf guns 07:30 - 10:30 3.00 CASE C RUNPRD RIH Correct to 8800 flag +4'. Continue to RIH set down in XN nipple. continue to RIH tag at.10594'. PU to ball drop launch ball with 1000psi. 10:30 - 11:25 0.92 CASE C RUNPRD Circulate 5/8 AL ball to seat with 36.7 bbls. Set down at 10599.59 . PU to breakover 23K PU 2' to 10588.6. Pressure to 2000. Slackoff wt. 11:25 - 12:25 1.00 CASE C RUNPRD Test KB acker to 2000 si for 30 min. No Test Lost 700 i 2 min. Possible leak in lap above sidetrack. Discuss with Anchorage. Decided to 12:25 - 12:55 0.50 CASE C RUNPRD POH pull 4K over to shear packer. BEWARE Over pull 8K ~ 9900 went down and pull thru no problem. Continnue to POH 9735 over pull 16 K .RIH. PU Over pull at 9747. Call Anchorage suggest placing packer back on liner and releasing from it. 12:55 - 13:25 0.50 CASE X WAIT RUNPRD Wait on orders. 13:25 - 13:45 0.33 CASE C RUNPRD RIH Sting in at 10598.99. Pressure to 4000 psi to release NOTE: KB LINER TOP PACKER IS NOT SET. 13:45 - 16:00 2.25 CASE C RUNPRD POH Recovered the KB packer element from the CTC. 16:00 - 16:30 0.50 CASE X WAIT RUNPRD Wait on custom drift. 16:30 - 17:00 0.50 CASE C RUNPRD MU BHA 17:00 - 17:20 0.33 CASE C RUNPRD RIH to 2000'. 17:20 - 18:45 1.42 CASE X WAIT RUNPRD Wait on freeze protection. Change in scope of work by Asset to drop drift run advanced the freeze protection operation. 18:45 - 19:30 0.75 CASE C RUNPRD RU diesel, pump diesel FP and POH 19:30 - 19:45 0.25 CASE C RUNPRD PJSM for LD FP BHA, discuss procedure, and hazards 19:45 - 20:00 0.25 CASE C RUNPRD Stand back injector, LD FP BHA 20:00 - 20:50 0.83 DEMOB C POST Pump 40 bbl fresh H2O 15 bbls inhibitor 5 bbls methanol Install BPV 20:50 - 21:00 0.17 DEMOB C POST PJSM for N2 blowdown. Discuss procedure, hazards and mitigations 21:00 - 21:45 0.75 DEMOB C POST PT to 3000 psi Blowdown reel with N2, rig down N2 and prep for reel swap 21:45 - 22:45 1.00 DEMOB C POST Install grapple and pull test, pull coil across 22:45 - 23:00 0.25 DEMOB C POST PJSM for dropping reel. Discuss procedure, hazards and mitigations 23:00 - 00:00 1.00 DEMOB C POST Drop a-free coil onto trailer, and PU a-coil, install grapple 10/9/2008 00:00 - 01:15 1.25 DEMOB P POST Pull coil across to injector Printed: 10/30/2008 11:26:49 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Event Name: REENTER+COMPLETE Contractor Name: Rig Name: Date From - To Hours Task 'Code 10/9/2008 01:15 - 01:30 0.25 DEMOB P 01:30 - 06:00 4.50 BOPSU P 06:00 - 09:15 3.25 BOPSU P 09:15 - 10:00 0.75 BOPSU P Start: 9/18/2008 Rig Release: Rig Number: Page 12 of 12 Spud Date: 10/22/1986 End: 10/9/2008 NPT Phase Description of Operations POST PJSM for removing the bag and changing out the top TOT on BOPE, discuss procedure, hazards and mitigations POST Remove the bag and c/o top TOT on BOPE Install hardline POST Continue installation of TOT double gate POST ND BOP. NP tree cap and test to 4000 psi. Release rig. Printed: 10/30/2008 11:26:49 AM • • BP Alaska BNB °~ Baker Hu hes INTE Serve Re ort -- g Q Y P I_N~r~;~ 1 nnipanp: BP ! morn _ Uatc: 11t4/200~ Timc U525G' P>~¢c: I'iclJ:. Prudhoe Bay (.u-o rdiuate(Nt:) Rcicrcu i'c: A~Jell. iv-14. True f~dorth tiit.~: PB DS 13 ~crlical ITVD~ Ilcla-curc : 1~-148. 4~i.d ~1cll: 18-14 ticction(VS)Rcti~rcn~~c ~'v`elll;O.OON.O.GOE,152-80A~i) V~cll~uith: 1B-14C 5nrcc~ (.aleulutiun ATrlh oJ: C~~1inimUm Curvature Dli: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 1 48 26 55.555 W '. Position Uncertainty: 0.00 ft I~ Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.46 deg Well: 18-14 Slot Name: 14 18-14 Well Position: +N/-S 1720.96 ft Northing: 5960947.74 ft Latitude: 70 17 52.178 N +E/-W 560.77 ft Easting : 692100.14 ft Longitude: 1 48 26 39.208 W Position Uncertainty: 0.00 ft Wellpath: 18-14C Drilled From: 18-14B 500292161403 Current Datum: 18-146: Height 46.40 ft Tie-on Depth: 10693.19 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 8/4/2008 Declination: 23.23 deg Field Strength: 57687 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg j 28.50 0.00 0.00 152.80 Survey Program far Definitive Wellpath Date: 8/4/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 96.40 8698.70 Schlumberger GCT Multishot (96 GCT-MS Schlumberger GCT multishot 8703.70 9546.70 MWD -Standard (8703.70-10848. MWD MWD -Standard 9568.00 10693.19 18-14B IIFR (9568.00-12234.51) MWD+IFR+MS MWD +IFR + Multi Station 10710.00 12960.00 MWD (10710.00-12960.00) MWD MWD -Standard Annotation VID l~l) ft ft 10693.19 8743.77 TIP 10710.00 8744.44 KOP 12960.00 8766.61 TD Survey: MWD Start Date: 9/29/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~U ~~ S~ • _,. ~ BP Alaska Baker Hughes INTEQ Survey Report 1 ~. BAKER ' HUGHES __- - 1~`z1/(~ C uul any: BP r`~rnoco Picl~l: Pr~idhoe BaV ti'itr: PB DS 18 `.\ cll: 18-14 1Acllhuili: 1~, 14C tiln~ r~ VIII lucl ft deg 10693.19 87.72 10710.00 87.69 10741.11 87.42 10771.65 87.64 10799.67 88.74 10830.59 88.93 10860.89 89.05 10891.43 89.91 10921.39 89.85 10954.53 89.97 10983.50 90.83 11013.06 90.52 11043.64 90.25 11074.44 89.32 11104.84 89.08 11135.23 87.60 11166.22 85.23 11196.39 87.97 11228.43 89.45 11259.05 89.23 11291.88 89.57 11322.00 90.86 11351.82 89.51 11381.94 89.66 11412.80 93.07 11447.32 94.36 11479.00 96.11 11512.64 92.58 11540.24 90.49 11572.60 90.21 11603.12 88.92 11631.66 89.32 11666.12 89.60 11695.38 87.45 ~ 11726.04 87.29 i 11756.92 87.23 ~ 11789.20 88.56 11817.18 89.48 11849.30 88.83 11878.92 87.73 i 11910.26 87.45 i 11940.10 86.99 ~ 11971.46 88.62 12001.10 90.89 12031.35 93.44 12062.55 92.88 12091.89 95.07 12121.43 90.89 12150.20 90.52 12180.36 96.21 12218.35 97.42 12248.30 95.96 12277.92 92.52 Uatc. 11'4;2008 I~inn 025-U2 Yacc: (n-nrdiusiiefYE) Rclcrauc: Well- 1 r-14_ True North \crtir.il i'f~~U) Relcrairr. 18-148 46.4 ticcliun f`v~~~l Ifefereucr: Well i0.00N 0.00E~?2~`~Orc:il Suru~~ (_alculaliru~ Atrlhud: Gainmum Curvature I)b: Or3cl~a \ium l ~'U ti~,'I ~U A'.ti E/~V Alal~A \lal~l rieg ft it ft ft ft ft 281.61 8743. 77 8697. 37 -3437 .14 740. 02 5957530. 84 692927. 73 278.20 8744. 44 8698. 04 -3434 .25 723. 48 5957533. 30 692911. 12 271.89 8745. 77 8699. 37 -3431 .52 692. 53 5957535. 24 692880. 12 265.70 8747. 09 8700. 69 -3432 .16 662. 04 5957533. 82 692849. 66 259.35 8747. 97 8701. 57 -3435 .81 634. 29 5957529. 47 692822. 01 250.61 8748. 60 8702. 20 -3443 .81 604. 46 5957520. 71 692792. 40 243.25 8749. 14 8702. 74 -3455 .67 576. 61 5957508. 14 692764. 86 235.94 8749. 42 8703. 02 -3471 .12 550. 29 5957492. 02 692738. 94 228.68 8749. 48 8703. 08 -3489 .42 526. 60 5957473. 12 692715. 72 221.25 8749. 53 8703. 13 -3512 .85 503. 19 5957449. 10 692692. 93 214.47 8749. 33 8702. 93 -3535 .71 485. 42 5957425. 80 692675. 75 206.50 8748. 98 8702. 58 -3561 .16 470. 44 5957399. 97 692661. 43 199.00 8748. 77 8702. 37 -3589 .34 458. 62 5957371. 50 692650. 33 190.83 8748. 89 8702. 49 -3619 .08 450. 70 5957341. 57 692643. 18 183.53 8749. 32 8702. 92 -3649 .22 446. 91 5957311. 35 692640. 15 175.56 8750. 20 8703. 80 -3679 .57 447. 15 5957281. 02 692641. 17 164.25 8752. 14 8705. 74 -3709 .97 452. 56 5957250. 77 692647. 35 153.02 8753. 94 8707. 54 -3737 .97 463. 51 5957223. 06 692659. 02 140.68 8754. 66 8708. 26 -3764 .73 481. 00 5957196. 75 692677. 18 127.85 8755. 01 8708. 61 -3786 .06 502. 88 5957175. 99 692699. 60 115.03 8755. 36 8708. 96 -3803 .15 530. 83 5957159. 63 692727. 97 105.98 8755. 25 8708. 85 -3813 .68 559. 01 5957149. 81 692756. 41 95.23 8755. 15 8708. 75 -3819 .16 588. 27 5957145. 08 692785. 81 90.08 8755. 37 8708. 97 -3820 .56 618. 35 5957144. 46 692815. 91 85.05 8754. 63 8708. 23 -3819 .25 649. 16 5957146. 55 692846. 67 84.17 8752. 40 8706. 00 -3816 .01 683. 45 5957150. 66 692880. 87 90.13 8749. 50 8703. 10 -3814 .44 714. 95 5957153. 04 692912. 31 96.16 8746. 95 8700. 55 -3816 .29 748. 42 5957152. 05 692945. 82 98.92 8746. 21 8699. 81 -3819 .91 775. 77 5957149. 13 692973. 25 104.10 8746. 02 8699. 62 -3826 .36 807. 46 5957143. 49 693005. 10 109.71 8746. 25 8699. 85 -3835 .23 836. 65 5957135. 37 693034. 50 115.48 8746. 69 8700. 29 -3846 .19 862. 99 5957125. 09 693061. 11 120.21 8747. 01 8700. 61 -3862 .28 893. 45 5957109. 78 693091. 96 121.69 8747. 76 8701. 36 -3877 .32 918 .53 5957095. 39 693117. 42 117.03 8749. 17 8702. 77 -3892 .34 945 .22 5957081. 06 693144. 48 111.83 8750. 65 8704. 25 -3905 .09 973 .29 5957069. 03 693172. 87 107.25 8751. 83 8705. 43 -3915 .88 1003 .68 5957059. 03 693203. 53 102.56 8752. 31 8705. 91 -3923 .07 1030 .71 5957052. 53 693230. 73 95.71 8752. 79 8706. 39 -3928 .16 1062 .40 5957048. 24 693262. 54 92.25 8753. 68 8707. 28 -3930 .22 1091 .93 5957046. 94 693292. 11 87.03 8755. 00 8708. 60 -3930 .02 1123 .23 5957047. 94 693323. 39 81.11 8756. 44 8710. 04 -3926 .95 1152 .86 5957051. 77 693352. 93 85.60 8757. 65 8711. 25 -3923 .32 1183 .98 5957056. 19 693383. 95 91.37 8757. 77 8711. 37 -3922 .54 1213 .59 5957057. 73 693413. 53 90.83 8756. 63 8710. 23 -3923 .12 1243 .81 5957057. 92 693443. 75 95.68 8754. 91 8708. 51 -3924 .89 1274 .91 5957056. 95 693474. 88 98.05 8752. 88 8706. 48 -3928 .38 1303 .96 5957054. 20 693504. 01 98.16 8751. 34 8704. 94 -3932 .54 1333 .16 5957050. 79 693533. 31 94.72 8750. 99 8704. 59 -3935 .77 1361 .74 5957048 .29 693561. 96 97.99 8749. 22 8702. 82 -3939 .10 1391 .65 5957045 .73 693591. 94 105.28 8744. 70 8698. 30 -3946 .70 1428 .57 5957039 .08 693629. 04 109.85 8741. 21 8694. 81 -3955 .67 1456 .92 5957030 .83 693657. 61 113.89 8739. 02 8692. 62 -3966 .67 1484 .32 5957020 .53 693685. 28 V_ti UI.N Iiml ft d~~~;'1iJOft 3395.31 0.00 MWD 3385.18 20.27 MWD 3368.60 20.28 MWD 3355.24 20.26 MWD 3345.79 22.99 MWD 3339.28 28.27 MWD 3337.09 24.29 MWD 3338.80 24.10 MWD 3344.25 24.23 MWD 3354.39 22.42 MWD 3366.60 23.59 MWD 3382.39 26.98 MWD 3402.05 24.54 MWD 3424.88 26.70 MWD 3449.95 24.02 MWD 3477.06 26.66 MWD 3506.56 37.22 MWD 3536.47 38.25 MWD 3568.27 38.78 MWD 3597.24 41.90 MWD 3625.21 39.06 MWD 3647.47 30.35 MWD 3665.72 36.33 MWD 3680.71 17.11 MWD 3693.63 19.69 MWD 3706.43 4.52 MWD 3719.43 19.53 MWD 3736.37 20.72 MWD 3752.09 12.54 MWD 3772.32 16.03 MWD 3793.55 18.86 MWD 3815.33 20.26 MWD 3843.57 13.75 MWD 3868.41 8.92 MWD 3893.96 15.19 MWD 3918.14 16.82 MWD 3941.62 14.76 MWD 3960.37 17.08 MWD 3979.39 21.42 MWD 3994.72 12.25 MWD 4008.85 16.67 MWD 4019.66 19.88 MWD 4030.66 15.22 MWD 4043.50 20.92 MWD 4057.83 8.62 MWD 4073.61 15.62 MWD 4090.01 10.98 MWD 4107.05 14.16 MWD 4122.99 12.02 MWD 4139.62 21.75 MWD 4163.25 19.32 MWD 4184.19 15.92 MWD 4206.50 17.88 MWD r~ ~ • BP Alasl~a gHUGH _ ' Baker Hughes INTEQ Survey Report I;~-rFQ C`uwpan~: EP Amoco U,i[c: 11;4;`'ODo Iinu ~ Oo.2502 Pa__c: Field: Pru dhoe Bay C u-urdiu,itc(\f :~ Itcfercncc: Well 1v-14 T rue North Site: PB DS 18 ~ ~rrtical ("f~l)i Rcfrrcncc: 1 ;-14E: 4G.4 Nell; 18- 14 ~ti cction ~~ti) Itc tirruce: 'Jell ~O.OUfJ ',1 00E 1 ~ _~ OF, i) ~Rcllpalli: 1~- 14C ~ urccc (alcula tiun Vclhud: LdinimUnt Cur ~alUre [)b. Oracle tiur~r~ tilU lurl - \iiu~ 1~ll ~~~ l ~I) -- A S - Li1~' \Is~~A Va~il~. ~~~ I?LS foul ft Jc~~ dag ft ft ft ft ft ft it deg/100ft 12311.05 87.94 117.32 8738.89 8692.49 -3980.99 1514.19 5957006.99 693715.50 4232.88 17.27 MWD 12341.94 84.47 113.83 8740.93 8694.53 -3994.29 1541.98 5956994.40 693743.62 4257.42 15.91 MWD 12372.10 84.59 109.32 8743.81 8697.41 -4005.33 1569.89 5956984.08 693771.81 4280.00 14.89 MWD 12401.48 83.02 105.86 8746.98 8700.58 -4014.15 1597.73 5956975.97 693799.86 4300.57 12.87 MWD 12432.06 85.18 103.06 8750.12 8703.72 -4021.74 1627.18 5956969.13 693829.49 4320.79 11.53 MWD 12462.42 85.66 99.13 8752.55 8706.15 -4027.57 1656.87 5956964.07 693859.32 4339.54 13.00 MWD 12492.66 86.38 93.93 8754.65 8708.25 -4031.00 1686.83 5956961.41 693889.36 4356.28 17.32 MWD 12521.90 89.23 92.27 8755.77 8709.37 -4032.58 1716.00 5956960.58 693918.56 4371.02 11.28 MWD 12550.42 90.31 87.82 8755.88 8709.48 -4032.60 1744.52 5956961.29 693947.06 4384.07 16.06 MWD 12580.24 86.89 85.25 8756.61 8710.21 -4030.80 1774.27 5956963.85 693976.75 4396.07 14.34 MWD 12611.30 86.99 83.66 8758.27 8711.87 -4027.80 1805.14 5956967.63 694007.53 4407.51 5.12 MWD 12642.74 91.90 87.64 8758.58 8712.18 -4025.42 1836.47 5956970.81 694038.79 4419.72 20.10 MWD 12674.62 95.65 94.04 8756.47 8710.07 -4025.88 1868.25 5956971.16 694070.58 4434.66 23.23 MWD 12704.92 92.94 98.23 8754.20 8707.80 -4029.11 1898.28 5956968.70 694100.68 4451.26 16.43 MWD 12730.94 90.71 104.60 8753.38 8706.98 -4034.25 1923.76 5956964.21 694126.28 4467.48 25.92 MWD 12761.32 90.98 106.99 8752.93 8706.53 -4042.52 1952.99 5956956.69 694155.71 4488.19 7.92 MWD 12792.02 88.93 111.46 8752.95 8706.55 -4052.63 1981.97 5956947.33 694184.93 4510.43 16.02 MWD 12822.47 85.42 114.11 8754.45 8708.05 -4064.40 2010.00 5956936.28 694213.26 4533.71 14.44 MWD 12852.15 82.78 117.69 8757.50 8711.10 -4077.29 2036.55 5956924.07 694240.13 4557.32 14.93 MWD 12887.01 87.79 121.99 8760.37 8713.97 -4094.57 2066.67 5956907.57 694270.67 4586.45 18.91 MWD 12914.83 84.46 126.15 8762.25 8715.85 -4110.12 2089.66 5956892.62 694294.05 4610.78 19.13 MWD 12960.00 84.46 126.15 8766.61 8720.21 -4136.64 2125.96 5956867.04 694331.02 4650.96 0.00 MWD ~C~U.ATOR= BAKER :B. ELEV = 47, 3F. ELEV = SOP = 45C Aax Angle = 97 @ 1221 )alum MD = 91 )alum TVD = 8800' ~ • DRLG DRAFT 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~~ 3452' TOP OF 5-112"" SCAB LNER I~ 3530' Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 1 8 - 14 C 3A1 /12N" CHROME TBG ~^uVV H ONTDIAGRAM . . 2~ 213' ~~ 3-1/2" CAMCO TRM-4E TRSSSV, ID = 2.812" O LOCKED OPEN (02/28/08) GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/0 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/G 1 8322 7510 39 KBG2-9 DMY INT 0 03/11 /0 353~~ 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1 /2" BKR ZXP LTP, ID = 4.910" 3543' 7-5/8" X 5-1/2" FLEX LOCK HGR, ID = 4.820 8509' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-112" BKR H PKR, ID = 4.812" $522' 5-1/2" HMC LNR HGR, ID = 4.938" 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: MCNL Log CCL/GR/CNL O6-OCT-08 A NGLE A T TOP PERF: 89 ~ 10860' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 1.56" 6 10860-10890 O 10/07/08 1.56" 6 10920-10990 O 10/07/08 1.56" 6 10080-11130 O 10/07/08 1.56" 6 11280-12080 O 10/07/08 1.56" 6 12470-12490 O 10!07/08 1.56" 6 12530-12610 O 10/07/08 1.56" 6 12700-12859 O 10/07/08 3-1 /2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" TOP OF FZSV 959(i' 10590' Liner Top Packer /~~ Note: LTP did NOT set , ' i-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, 0=4.767" 10312' ~ 3-1/2" LNR 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" ( 9106' --~3-1/2" HES XN N(P, ID = 2.750" 9118' -j3-112" WLEG, ID = 2.992" 9413' S-1/2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' S-1 /2" X 3-1/2" BKR ZXP LTP, ID = 3.410" MLLOUT WINDOW (18-14B~ 9568' - 9581' 10593' 2 3/S" TOP OF LINER De~bvment Sleeve 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 12904 TD 12867 PBTD 10710' TOP 3 112" WHIPSTOCK 12201' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 11/08/86 ORIGINAL COMPLETION 09/24/04 KDCIRH TRSSSV CORRECTION 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSBlPJC GLV CIO 04/01/95 CTD (2-7/8" SLTD LNR) 06/25/07 ?/ PJC l BG /LNR C(7RRECTIONS 03/13/04 DAVIKA RIG SIDETRACK (18-14A) 03/08/08 SWC/PJC TRSSSV LOCKED OPEN (02/28/C 03/16!04 JBM/KAK GLV C/O 05/30!08 DAV/PJC TRSSV CORRECTION (02/21/08 09/18/04 G.1B/TLP GLV C/O 1DI08/08 Nordic 1 CTDSidetrark 118-14C1 )3-1/2" HES XNIP, O = 2.813" ( 5-112" X3-1/2" BKR S-3 PERM PKR ID = 2.770" 9086' (~3-1/2" HES X NIP, ~ = 2.813" PRUDHOE BAY UNfT WELL: 18-14C PERMfT No: `2081320 API No: 50-U29-21614-U3 B) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL BP Exnloratinn (Alaska/ r~ ~, ~ ~ ~I;~ ~ ~~ n ;, ~ ~ ~ ~~~ SARAH PALIN, GOVERNOR OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5~RQA~'IO1~T CO~gIIS5IOr1T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-14C BP Exploration Alaska Inc. Permit No: 208-151 Surface Location: 4351' FSL, 4609' FEL, SEC. 19, T11N, R15E, UM Bottomhole Location: 250' FSL, 2529' FEL, SEC. 19, T11N, RI5E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA /~~ ALASK~ AND GAS CONSERVATION COMMISSI~ ~ PERMIT TO DRILL L C 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class Exploratory ^ Service ^ Stratigraphic Test ~ DevelopmeM Oil ~ Development Gas MuRiple Zone Single Zone 1 c. S ecify if well is proposed for. ~Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 18-140 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 12800' TVD 8720'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4351' FSL 4609' FEL SEC 1 T11 N R1 M 7. Property Designation: ADL 028321 Pool , , , . 9, 5E, U Top of Productive Horizon: 884' FSL, 3644' FEL, SEC. 19, T11N, R15E, UM 8. Land Use Permit: 13.~proximate Spud Date: //O~' Currently In Progress Total Depth: 250' FSL, 2529' FEL, SEC. 19, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-692104 y-5960948 Zone-ASP4 10. KB Elevation (Hei ht above GL): 46.4 feet 15. Distance to Nearest Well Within Pool: 400' 16. Deviated Wells: Kickoff Depth: 10700 feet Maximum Hole A le: 90 d noes 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3324. Surface: 2444 r Hole asin Wei ht Grade Cou lin Len h MD TVD MD TVD includin sta a data ~~ 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12270 Total Depth TVD (ft): 74 Plugs (measured): None Effective Depth MD (ft): 12201 Effective Depth TVD (ft): 8748 Junk (measured): None Casin Len Size ment Volume MD TVD Conductor /Structural " Surface 4 Intermediate " Liner -1 Perforation Depth MD (ft): 10880' -12190' Perforation Depth TVD (ft): 8750' - 8748' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ~ Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal A roval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Joh c ull Si nature Contact Sean McLaughlin, 564-4387 Title Engineering Team Leader ~ ~ N~ Phone 564-4711 Date ~ Z ~~ Terrie Hubble, 564628 C I Permit To D ~~kS/ API Number: JO-029-21614-03-00 Permit Ap royal. ~ l.p See cover letter for Corxiitions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~11~ ~~~~~~~`~ ~C,~-~1~~~~~,~~~(v"~\SamplesReq'd: ~es ~o Mud LogReq'd: ^Yes QNo ~~..JJ~~ 2- ~ ` J HZS Measures: Yes ^ No Directional Survey Req'd: ®Yes ^ No Other: '~j 5~~ ~`~~ 1 ~7V~ ~5 ~ Date APPROVED BY THE COMMISSION COMMISSIONER Forth 10-461 RevisLd 12/2005 Submit In Duplicate f ~~ ~ r jj~~ fF`%~it f~' • by BPXA Prudhoe Bay DS 18-14C CTD Sidetrack October 02, 2008 CTD Sidetrack Summary Pre-Rig Work Summary: 1. F MIT-IA 2. S Run Caliper deep as possible 3. C Drift with dummy 2.7" x 15' whipstock to 10900' (90deg incl) 4. C MGR/CCUCNL log from 9000' to 10900'. 5. W Set BPV 6. W PT MV, SV, WV 7. O Blind and bleed lines, remove well house, level pad Rig Sidetrack Operations: 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. Pull BPV. 3. Set 3-1/2" retrievable whipstock 90 LOHS with top at 10,710'. 4. Mill 2.74" window through 3'h" liner. 5. Drill turn section with 2.70" x 3.0" bicenter bit to 11350'. 6. Drill lateral section to 12,800'. 7. Run and cement a 2-3/8" L-80 liner string, abandoning perfs in 8. Make a cleanout run with mill and motor. 9. Make a logging run with a MGR/CCUCNL logging tool. 10. Perforate well. Passed 8/22/08 Done 8/31/08 Done Done Done Done Done Done Done Done Done Done In Progress parent wellbore- (8 bbls) 11. Circulate well to brine. FP well to 2000' with diesel. 12.Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 13. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will. to Pad 3 for disposal. Hole size: 3.0" (bi-center bits used) Casing Program: fully cemented liner • 2-3/8", solid L-80 4.70# STL 10,600' - 12,800' • A minimum of 8 bbls of 15.8 ppg cement will be used for the liner cementing. • TOC planned at the top of liner (10600') Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan (same as 18-14BL1). Maximum planned hole angle is 97 deg at 12,218'. • Magnetic and inclination surreys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 25,000 ft. • Distance to nearest well within pool - 400 ft. (18-24AL2) Anti-Collision • 18-03A ctr-ctr distance 119'; The well is P&A'd Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. • Cased hole MCNL will be run. Hazards • The maximum recorded H2S level on DS 18 was 20 ppm on well 18-14B. • Lost circulation risk is low Reservoir Pressure • The reservoir pressure on 18-14 is expected to be 3,324 psi at 8,800' TVDSS. (7.3 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,444 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREI== 7-1/16" FMC WELLHEAD = FMC ACTUATOR BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = 94 @ 11865' Datum MD = 9159' Datum TVD = 8800' SS 10-3l4" CSG, 45.5#, L-80, ID = 9.953" TOP OF 5-1/2"" SCAB LNER H 3530 ~ Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 5-1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD / GR ON 03/01/04 A NGLE AT TOP PERF: 88 @ 10880' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz .DATE 2" 6 10880 - 11610 O 03/04/04 2" 6 11860 - 12190 O 03/04/04 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" TOP OF EZSV ~ ~ 5-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ID = 4.767" I 18 -14 B N DIAGRAM. n3 1 /2" CHROME TBG. 2213 3-1/2"CAMCOTRM-4ETRSSSV,ID=2.812" LOCKED OPBd (02/28/08) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY IIVT 0 06/24/07 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/04 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/04 $530' 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-518" X 5-1/2" BKR ZXP LTP, ID = 4.910" 3543' 7-5/8" X 5-1 /2" FLEX LOCK HGR, ID = 4.820 $509' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-1/2" BKR H PKR, ID = 4.812" $522' S-1/2" HMC LNR HGR ID = 4.938" 9041' ~ 3-1/2" HES X NIP, ID = 2.813" 9062' 5-1/2" X 3-1/2" BKR S-3 PERM PKR, ID = 2.770" 9086' H 3-1 /2" HF~ X NIP, ID = 2.813" I 9106 3-1/2" HES XN NIP, ID = 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413' S-1 /2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' ~--~ 5-1/2" X 3-1/2" BKR ZXP LTP, ID = 3.410" MILLOUT WINDOW (18-146) 9568' - 9581' ~ ~ ~ ~ L 3-1/2" LNR 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" 12269 PBTD I I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/08/86 ORIGINAL COMPLETION 09/24/04 KDGTLH TRSSSV CORRECTION WELL: 18-146 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSB/PJC GLV GO PERMIT No: 2030630 04/01/95 CTD (2-718" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS API No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02/28/08) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL 03/16/04 JBMlKAK GLV GO 05/30/08 DAV/PJC TRSSV CORRECTION(02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) TREE = 7-1116" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = 94 @ 11865' Datum MD = 9159' Datum TV D = 8800' SS 18 -14 C S NOTES: ORIGINAL W ELLBORE NOT Proposed CTD Sidetrack !"NON DIAGRAM. 3-1 /2" CHROME TBG. 2213' ~ 3-1/2" CAMCO TRM-4E TRSSSV, ID = 2.812" LOCKED OPEN (02/28/08) GAS LIFT MANDRELS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~-~ 3452' TOP OFS-1/2"" SCAB LNER Minimum ID = 2.750" @ 9086' 3-1 /2" HES ~ TIPPLE ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/07 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/04 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/04 7' BKR LNR TIEBACK SLV, ID = 5.750" 7-5/8" X 5-1/2" BKR ZXP LTP, ID = 4.910" 7-5/8" X 5-1/2" FLEX LOCK HGR, ID = 4.820 8509' BKR G2 TIEBACK SLV, ID =? LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509' 8517' 7-5/8" X 5-1/2" BKR H PKR, ID = 4.812" $522' S-1/2" HMC LNR HGR, ID = 4.938" 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD / GR ON 03/01/04 ANGLE AT TOP PERF: 88 @ 10880' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10880 - 11610 O 03/04/04 2" 6 11860 - 12190 O 03/04/04 ~ 3-1 /2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" ~ MILLOUT WMIDOW (18-148) 9568' - 9581' ~ ~/~ ,~ ~ 5-1 /2" LNR 17#, NT-80 NSCC, .0232 bpf, ID = 4.767" H 10312' ~ 3-1 /2" LNR, 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" ~ 9041 3-1/2" HES X NIP, ID = 2.813" 9062' 5-1/2" X 3-1/2" BKR S-3 PERM PKR, ID = 2.770" 90~ 3-1/2" HES X NIP, ID = 2.813" 9106' ~3-1l2" HES XN NIP, ID= 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413' 5-1l2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' S-1/2" X 3-1 /2" BKR ZXP LTP, ID = 3.410" j 2 3/8" TOP OF LINER, TOC TOP3 1/2" WHIPSTOCK 2-3/8" LNR 4.7#, L-80 STL, 0.003876PF, ID=1.995" (~ 12800' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/08/86 ORIGINAL COMPLETION 09/24/04 KDGTLH TRSSSV CORRECTION WELL: 18-14C 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSB/PJC GLV GO PERMIT No: 82030630 04/01/95 CTD (2-718" SLID LNF~ 06/25107 ?/ PJC TBG /LNR CORRECTIONS AR No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02/2810 8) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL 03/16/04 JBM/KAK GLV GO 05/30/08 DAV/PJC TRSSV CORRECTION (02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) by i BP Alaska Baker Hu hes INTEQ Planning Report g ~e~ INTEQ Company: BP Amoco -- -- --- - Date: 8/4/2008 Time: 15:21:55 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-14, True North 'i Site: PB DS 18 Verlacal (TVD) Reference: 18-14B: 46.4 Well: 18-14 L Section (VS) Reference: Well (O.OON,O.OOE,140.OOAzi) Wellpath: Plan 3; 18-14~L'I Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True '~ Ground Level: 0.00 ft Grid Convergence: 1.46 deg ', Well: 18-14 Slot Name: 14 18-14 ' Well Position: +N/-S 1720.96 ft Northing: 5960947.74 ft Latitude: 70 17 52.178 N ~, +E/-W 560.77 ft Easting : 692100.14 ft Longitude: 148 26 39.208 W ', Position Uncertainty: 0.00 ft Wellpath: Plan 3, 18-14BL1 Drilled From: 18-14B 500292161460 Tie-on Depth: 10693.19 ft Current Datum: 18-14B: Height 46.40 ft Above System Datum: Mean Sea Level Magnetic Data: 8/4/2008 Declination: 23.23 deg Field Strength: 57687 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 140.00 Plan: Plan 3 Date Composed: 8/4/2008 copy Sean's Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Map Northing ft Map Easting ft <---- Deg Latitude ----> Nlin . Sec <--- Longitude ---> Deg Min Sec 18-146L1 Polygon 46.40 -3750.48 207.08 5957204.00 692403.00 70 17 15.292 N 148 26 33.175 W -Polygon 1 46.40 -3750.48 207.08 5957204.00 692403.00 70 17 15.292 N 148 26 33.175 W -Polygon 2 46.40 -3873.59 640.10 5957092.00 692839.00 70 17 14.081 N 148 26 20.559 W -Polygon 3 46.40 -4045.38 1137.90 5956933.00 693341.00 70 17 12.391 N 148 26 6.056 W -Polygon 4 46.40 -4365.12 2531.26 5956649.00 694742.00 70 17 9.243 N 148 25 25.465 W -Polygon 5 46.40 -4024.23 2619.01 5956992.00 694821.00 70 17 12.595 N 148 25 22.905 W -Polygon 6 46.40 -3630.78 1472.62 5957356.00 693665.00 70 17 16.468 N 148 25 56.302 W -Polygon 7 46.40 -3207.02 393.04 5957752.00 692575.00 70 17 20.637 N 148 26 27.756 W 18-146L1 Target 1 8753.40 -3794.07 699.15 5957173.00 692896.00 70 17 14.863 N 148 26 18.838 W 18-146L1 Target 2 8763.40 -4015.04 1789.92 5956980.00 693992.00 70 17 12.688 N 148 25 47.060 W 18-146L1 Target 3 8769.40 -4147.55 2394.77 5956863.00 694600.00 70 17 11.383 N 148 25 29.439 W Annotation MD TVD ft ft 10693.19 8743.77 10700.00 8744.04 10720.00 8744.81 11020.00 8751.80 11330.00 8753.41 11630.00 8756.75 11980.00 8760.20 12240.00 8762.18 TIP KOP End of 9 deg / 100 ft DLS 4 End of 31.5 deg / 100 ft DLS 6 7 8 by ~ BP Alaska Baker Hughes INTEQ Planning Report /liter yes INTEQ Company: BP Amoco pate: 8/4/2008 Time: 15 :21:55 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: 18-14, T rue North Site: PB DS 18 Vertical (TVD) Reference: 18-14 B: 46.4 Well: 1 8-14 ` Section(VS)Reference: Well (O.OON,O .OOE,140.OOAzi) Wellpath: Plan $, 18-1 ~ Survey Calculation Method: Minimum Curvature Db: Oracle Mnotation ~,MD TVD __ .. ____ ft ft - -- _. 12470.00 8763.69 9 __ -- - 12770.00 8766.19 10 13100.00 8769.25 TD Plan Section Information MD Incl Azim TVD +N!-S +FJ W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft ,deg/100ft deg/100ft deg 10693.19 87.72 281.61 8743.77 -3437.14 740.02 0.00 0.00 0.00 0.00 10700.00 87.79 281.68 8744.04 -3435.77 733.36 1.45 1.03 1.03 44.98 10720.00 87.79 279.88 8744.81 -3432.03 713.73 9.00 0.01 -9.01 270.00 11020.00 90.17 185.38 8751.80 -3594.20 501.56 31.50 0.79 -31.50 270.00 11330.00 89.38 87.73 8753.41 -3793.01 689.84 31.50 -0.26 -31.50 269.40 11630.00 89.38 123.74 8756.75 -3873.03 973.85 12.00 0.00 12.00 90.20 11980.00 89.54 81.73 8760.20 -3948.46 1307.63 12.00 0.05 -12.00 270.00 12240.00 89.61 112.93 8762.18 -3981.24 1562.33 12.00 0.03 12.00 90.00 12470.00 89.65 85.33 8763.69 -4017.40 1787.21 12.00 0.02 -12.00 270.00 12770.00 89.42 121.33 8766.19 -4085.46 2074.34 12.00 -0.08 12.00 90.50 13100.00 89.56 81.73 8769.25 -4150.13 2391.26 12.00 0.04 -12.00 270.00 Survey MD Inch Aam SS TVD N/S E/W MapN MapE DLS VS 'CFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10693.19 87.72 281.61 8697.37 -3437.14 740.02 5957530.84 692927.73 0.00 3108.68 0.00 MW D 10700.00 87.79 281.68 8697.64 -3435.77 733.36 5957532.04 692921.04 1.45 3103.35 44.98 MW D 10720.00 87.79 279.88 8698.41 -3432.03 713.73 5957535.27 692901.32 9.00 3087.86 270.00 MW D 10730.00 87.79 276.73 8698.79 -3430.59 703.84 5957536.46 692891.40 31.50 3080.40 270.00 MW D 10740.00 87.80 273.57 8699.18 -3429.69 693.89 5957537.10 692881.43 31.50 3073.32 270.12 MW D 10750.00 87.82 270.42 8699.56 -3429.34 683.90 5957537.20 692871.44 31.50 3066.63 270.24 MW D 10760.00 87.84 267.27 8699.94 -3429.54 673.91 5957536.74 692861.46 31.50 3060.37 270.36 MW D 10770.00 87.87 264.12 8700.31 -3430.30 663.95 5957535.74 692851.52 31.50 3054.54 270.48 MW D 10780.00 87.91 260.97 8700.68 -3431.59 654.04 5957534.19 692841.64 31.50 3049.16 270.60 MW D 10790.00 87.95 257.81 8701.04 -3433.43 644.22 5957532.10 692831.87 31.50 3044.26 270.72 MW D 10800.00 88.00 254.66 8701.39 -3435.81 634.52 5957529.47 692822.23 31.50 3039.84 270.83 MW D 10810.00 88.06 251.51 8701.74 -3438.72 624.96 5957526.32 692812.75 31.50 3035.92 270.94 MW D 10820.00 88.12 248.36 8702.07 -3442.14 615.57 5957522.65 692803.46 31.50 3032.52 271.05 MW D 10830.00 88.18 245.21 8702.39 -3446.08 606.38 5957518.48 692794.37 31.50 3029.63 271.15 MW D 10840.00 88.25 242.06 8702.70 -3450.52 597.43 5957513.82 692785.54 31.50 3027.27 271.26 MW D 10850.00 88.33 238.91 8703.00 -3455.45 588.73 5957508.67 692776.97 31.50 3025.46 271.35 MW D 10860.00 88.41 235.76 8703.29 -3460.84 580.32 5957503.06 692768.70 31.50 3024.18 271.45 MW D 10870.00 88.50 232.61 8703.56 -3466.69 572.21 5957497.01 692760.74 31.50 3023.45 271.54 MW D 10880.00 88.59 229.46 8703.81 -3472.98 564.44 5957490.53 692753.14 31.50 3023.27 271.62 MW D 10890.00 88.69 226.31 8704.05 -3479.68 557.03 5957483.64 692745.90 31.50 3023.64 271.70 MW D 10900.00 88.79 223.16 8704.27 -3486.78 549.99 5957476.36 692739.05 31.50 3024.56 271.78 MW D 10910.00 88.89 220.01 8704.47 -3494.26 543.36 5957468.71 692732.60 31.50 3026.02 271.85 MW D 10920.00 89.00 216.86 8704.65 -3502.09 537.14 5957460.73 692726.59 31.50 3028.03 271.91 MW D 10930.00 89.11 213.71 8704.82 -3510.25 531.37 5957452.42 692721.03 31.50 3030.56 271.97 MW D 10940.00 89.22 210.56 8704.97 -3518.72 526.05 5957443.82 692715.93 31.50 3033.63 272.02 MW D 10950.00 89.33 207.42 8705.09 -3527.46 521.20 5957434.96 692711.31 31.50 3037.22 272.07 MW D 10960.00 89.45 204.27 8705.20 -3536.46 516.85 5957425.85 692707.18 31.50 3041.31 272.11 MW D 10970.00 89.57 201.12 8705.28 -3545.68 512.99 5957416.53 692703.56 31.50 3045.89 272.14 MW D 10980.00 89.69 197.97 8705.35 -3555.11 509.64 5957407.03 692700.46 31.50 3050.96 272.17 MW D 10990.00 89.81 194.83 8705.39 -3564.70 506.82 5957397.37 692697.88 31.50 3056.49 272.19 MW D 11000.00 89.93 191.68 8705.41 -3574.43 504.53 5957387.58 692695.84 31.50 3062.48 272.20 MW D 11010.00 90.05 188.53 8705.42 -3584.27 502.77 5957377.70 692694.34 31.50 3068.89 272.21 MW D 11020.00 90.17 185.38 8705.40 -3594.20 501.56 5957367.74 692693.38 31.50 3075.71 272.21 MW D 11030.00 90.14 182.23 8705.37 -3604.18 500.90 5957357.75 692692.97 31.50 3082.93 269.40 MW D by ~ BP Alaska Baker Hughes INTEQ Planning Report ~~~ INTEQ C' C p ny: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-14 L Wellpath: Plan 3, 18-14$L~1 Survey ~ - MD' Incl Azim ' ft deg deg __ SSTVD ft S ft Date: 8/4/2008 Time: 15:21:55 Page: 3 Go-ordiuate(NE) Reference: Well: 18-14, True North ~I Vertical (TVD) Reference: 18-146: 46.4 SeMion(VS)Reference: Well (O.OON,O.OOE,140.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle E/W MapN MapE DLS VS TFO Tool ft ft ft deg/100ft ft deg -- - 11040.00 90.11 179.08 8705.35 -3614.17 500.78 _ 5957347.76 _ 692693.11 31.50 3090.52 269.39 MW D 11050.00 90.07 175.93 8705.33 -3624.16 501.22 5957337.78 692693.80 31.50 3098.45 269.38 MW D 11060.00 90.04 172.78 8705.32 -3634.11 502.20 5957327.86 692695.04 31.50 3106.70 269.38 MW D 11070.00 90.00 169.63 8705.32 -3643.99 503.73 5957318.02 692696.82 31.50 3115.25 269.38 MWD 11080.00 89.97 166.48 8705.32 -3653.78 505.80 5957308.30 692699.14 31.50 3124.08 269.38 MW D 11090.00 89.94 163.33 8705.33 -3663.43 508.40 5957298.71 692701.99 31.50 3133.15 269.38 MW D 11100.00 89.90 160.18 8705.34 -3672.93 511.53 5957289.30 692705.36 31.50 3142.43 269.38 MW D 11110.00 89.87 157.03 8705.36 -3682.24 515.18 5957280.09 692709.24 31.50 3151.91 269.38 MWD 11120.00 89.83 153.88 8705.39 -3691.33 519.33 5957271.10 692713.63 31.50 3161.55 269.39 MW D 11130.00 89.80 150.73 8705.42 -3700.19 523.98 5957262.37 692718.50 31.50 3171.31 269.40 MW D 11140.00 89.77 147.58 8705.46 -3708.77 529.11 5957253.92 692723.84 31.50 3181.19 269.41 MW D 11150.00 89.74 144.43 8705.50 -3717.06 534.70 5957245.78 692729.64 31.50 3191.13 269.42 MW D 11160.00 89.71 141.28 8705.55 -3725.03 540.73 5957237.96 692735.88 31.50 3201.12 269.43 MW D 11170.00 89.68 138.13 8705.60 -3732.66 547.20 5957230.51 692742.54 31.50 3211.11 269.45 MWD 11180.00 89.65 134.98 8705.66 -3739.92 554.07 5957223.42 692749.59 31.50 3221.09 269.47 MW D 11190.00 89.62 131.83 8705.73 -3746.79 561.34 5957216.74 692757.03 31.50 3231.03 269.48 MW D 11200.00 89.59 128.68 8705.80 -3753.25 568.97 5957210.48 692764.82 31.50 3240.88 269.50 MW D 11210.00 89.57 125.53 8705.87 -3759.28 576.94 5957204.65 692772.95 31.50 3250.63 269.53 MW D 11220.00 89.54 122.38 8705.95 -3764.87 585.23 5957199.28 692781.38 31.50 3260.24 269.55 MW D 11230.00 89.52 119.23 8706.03 -3769.99 593.82 5957194.38 692790.09 31.50 3269.68 269.57 MW D 11240.00 89.50 116.08 8706.11 -3774.63 602.68 5957189.97 692799.07 31.50 3278.93 269.60 MW D 11250.00 89.48 112.93 8706.20 -3778.78 611.77 5957186.05 692808.27 31.50 3287.95 269.63 MW D 11260.00 89.46 109.78 8706.29 -3782.42 621.09 5957182.65 692817.67 31.50 3296.73 269.65 MW D 11270.00 89.45 106.63 8706.39 -3785.54 630.58 5957179.77 692827.24 31.50 3305.23 269.68 MW D 11280.00 89.43 103.48 8706.49 -3788.14 640.24 5957177.42 692836.96 31.50 3313.42 269.71 MW D 11290.00 89.42 100.33 8706.59 -3790.21 650.02 5957175.61 692846.79 31.50 3321.29 269.74 MW D 11300.00 89.41 97.18 8706.69 -3791.73 659.90 5957174.34 692856.71 31.50 3328.81 269.78 MWD 11310.00 89.40 94.03 8706.80 -3792.70 669.85 5957173.62 692866.68 31.50 3335.95 269.81 MW D 11320.00 89.39 90.88 8706.90 -3793.13 679.84 5957173.44 692876.67 31.50 3342.70 269.84 MW D 11330.00 89.38 87.73 8707.01 -3793.01 689.84 5957173.82 692886.67 31.50 3349.04 269.87 MW D 11350.00 89.37 90.13 8707.23 -3792.64 709.83 5957174.70 692906.64 12.00 3361.60 90.20 MW D 11375.00 89.37 93.13 8707.50 -3793.35 734.82 5957174.63 692931.64 12.00 3378.21 90.17 MWD 11400.00 89.36 96.13 8707.78 -3795.37 759.73 5957173.25 692956.59 12.00 3395.77 90.14 MWD 11425.00 89.35 99.13 8708.06 -3798.69 784.51 5957170.56 692981.44 12.00 3414.24 90.11 MWD 11450.00 89.35 102.13 8708.34 -3803.31 809.07 5957166.58 693006.12 12.00 3433.56 90.07 MW D 11475.00 89.35 105.13 8708.63 -3809.20 833.36 5957161.31 693030.55 12.00 3453.69 90.04 MW D 11500.00 89.35 108.13 8708.91 -3816.35 857.31 5957154.77 693054.67 12.00 3474.57 90.01 MW D 11525.00 89.35 111.13 8709.19 -3824.75 880.86 5957146.98 693078.42 12.00 3496.13 89.97 MWD 11550.00 89.36 114.14 8709.47 -3834.37 903.93 5957137.95 693101.73 12.00 3518.33 89.94 MW D 11575.00 89.36 117.14 8709.75 -3845.19 926.46 5957127.71 693124.53 12.00 3541.10 89.90 MW D 11600.00 89.37 120.14 8710.03 -3857.16 948.40 5957116.30 693146.77 12.00 3564.38 89.87 MWD 11625.00 89.38 123.14 8710.30 -3870.28 969.68 5957103.74 693168.37 12.00 3588.10 89.84 MW D 11630.00 89.38 123.74 8710.35 -3873.03 973.85 5957101.09 693172.61 12.00 3592.89 89.81 MWD 11650.00 89.38 121.34 8710.57 -3883.79 990.71 5957090.77 693189.74 12.00 3611.97 270.00 MW D 11675.00 89.39 118.34 8710.84 -3896.22 1012.39 5957078.90 693211.73 12.00 3635.43 270.03 MW D 11700.00 89.39 115.34 8711.10 -3907.50 1034.70 5957068.19 693234.32 12.00 3658.41 270.06 MW D 11725.00 89.39 112.33 8711.37 -3917.61 1057.56 5957058.67 693257.43 12.00 3680.85 270.09 MW D 11750.00 89.40 109.33 8711.63 -3926.50 1080.92 5957050.38 693281.01 12.00 3702.67 270.12 MW D 11775.00 89.41 106.33 8711.89 -3934.15 1104.72 5957043.34 693304.99 12.00 3723.83 270.15 MW D 11800.00 89.42 103.33 8712.15 -3940.55 1128.88 5957037.56 693329.31 12.00 3744.27 270.18 MW D 11825.00 89.43 100.33 8712.40 -3945.68 1153.35 5957033.06 693353.90 12.00 3763.92 270.22 MW D 11850.00 89.45 97.33 8712.64 -3949.52 1178.05 5957029.86 693378.68 12.00 3782.74 270.25 MW D ~ Q~~ by ~ Bake BP Alaska r Hu hes INTEQ Plannin Report g g INTEQ Company: BP AmoCO Date: 8l4J2008 Time: 15 :21:55 Page: 4 Field: Prudhoe Bay Go-ordiuate(NE) Reference: Well: 18-14, True North Site: PB DS 18 Vertical (TVD) Reference: 18-14 6: 46.4 ', i Well: 18- 14 Section (VS) Reference: Well ( O.OON,O.OOE,140.OOA zi) Wellpath: Plan 3, 18-14 6L1 Survey Calculation Method: Minimum Curvatu re Db: Oracle Survey MD Iacl Azim - SS TVD N/S FJW -- - MapN MapE DLS - VS TEO TooF ft deg `deg ft ft ft ft ft deg/100ft ft deg ---- ------- - -- -- 11875. 00 89.46 94.33 8712.88 -3952.06 1202.91 5957027.95 693403.61 12.00 3800.67 270.27 MW D 11900. 00 89.48 91.33 8713.11 -3953.29 1227.88 5957027.35 693428.59 12.00 3817.66 270.30 MW D 11925. 00 89.50 88.33 8713.33 -3953.22 1252.87 5957028.07 693453.58 12.00 3833.67 270.33 MW D 11950. 00 89.52 85.33 8713.55 -3951.84 1277.83 5957030.08 693478.49 12.00 3848.66 270.36 MW D 11975. 00 89.54 82.33 8713.76 -3949.15 1302.68 5957033.40 693503.26 12.00 3862.58 270.38 MW D 11980. 00 89.54 81.73 8713.80 -3948.46 1307.63 5957034.22 693508.20 12.00 3865.23 270.41 MW D 12000. 00 89.54 84.13 8713.96 -3946.00 1327.48 5957037.19 693527.97 12.00 3876.10 90.00 MW D 12025. 00 89.54 87.13 8714.16 -3944.10 1352.40 5957039.73 693552.84 12.00 3890.66 89.98 MW D 12050. 00 89.55 90.13 8714.35 -3943.50 1377.39 5957040.96 693577.80 12.00 3906.27 89.96 MW D 12075. 00 89.55 93.13 8714.55 -3944.22 1402.38 5957040.89 693602.80 12.00 3922.88 89.93 MW D 12100. 00 89.56 96.13 8714.75 -3946.24 1427.29 5957039.51 693627.75 12.00 3940.44 89.91 MW D 12125. 00 89.56 99.13 8714.94 -3949.56 1452.07 5957036.82 693652.60 12.00 3958.91 89.89 MW D 12150. 00 89.57 102.13 8715.13 -3954.17 1476.64 5957032.84 693677.28 12.00 3978.23 89.86 MW D 12175. 00 89.58 105.13 8715.31 -3960.06 1500.93 5957027.57 693701.71 12.00 3998.36 89.84 MW D 12200. 00 89.59 108.13 8715.50 -3967.22 1524.88 5957021.03 693725.84 12.00 4019.24 89.82 MW D 12225. 00 89.60 111.13 8715.67 -3975.62 1548.42 5957013.23 693749.58 12.00 4040.81 89.80 MW D 12240. 00 89.61 112.93 8715.78 -3981.24 1562.33 5957007.96 693763.63 12.00 4054.05 89.77 MW D 12250. 00 89.61 111.73 8715.84 -3985.04 1571.57 5957004.40 693772.97 12.00 4062.91 270.00 MW D 12275. 00 89.61 108.73 8716.02 -3993.69 1595.03 5956996.36 693796.64 12.00 4084.61 270.01 MW D 12300. 00 89.61 105.73 8716.19 -4001.10 1618.90 5956989.56 693820.69 12.00 4105.63 270.03 MW D 12325. 00 89.61 102.73 8716.35 -4007.24 1643.13 5956984.04 693845.07 12.00 4125.91 270.05 MW D 12350. 00 89.62 99.73 8716.52 -4012.11 1667.65 5956979.80 693869.70 12.00 4145.40 270.07 MW D 12375. 00 89.62 96.73 8716.69 -4015.69 1692.39 5956976.85 693894.52 12.00 4164.04 270.09 MW D 12400. 00 89.63 93.73 8716.85 -4017.97 1717.28 5956975.21 693919.46 12.00 4181.79 270.11 MW D 12425. 00. 89.64 90.73 8717.01 -4018.95 1742.26 5956974.87 693944.45 12.00 4198.59 270.13 MW D 12450. 00 89.64 87.73 8717.17 -4018.61 1767.25 5956975.85 693969.43 12.00 4214.40 270.15 MW D 12470. 00 89.65 85.33 8717.29 -4017.40 1787.21 5956977.56 693989.35 12.00 4226.31 270.17 MW D 12475. 00 89.65 85.93 8717.32 -4017.02 1792.20 5956978.07 693994.33 12.00 4229.22 90.50 MW D 12500. 00 89.62 88.93 8717.48 -4015.90 1817.17 5956979.83 694019.26 12.00 4244.42 90.50 MW D 12525. 00 89.60 91.93 8717.65 -4016.09 1842.17 5956980.28 694044.25 12.00 4260.63 90.48 MW D 12550. 00 89.57 94.93 8717.83 -4017.59 1867.12 5956979.42 694069.23 12.00 4277.81 90.46 MW D 12575. 00 89.55 97.93 8718.02 -4020.39 1891.96 5956977.26 694094.13 12.00 4295.93 90.44 MW D 12600. 00 89.53 100.93 8718.22 -4024.49 1916.62 5956973.79 694118.89 12.00 4314.91 90.41 MW D 12625. 00 89.51 103.93 8718.43 -4029.87 1941.03 5956969.03 694143.42 12.00 4334.73 90.39 MWD 12650. 00 89.49 106.93 8718.65 -4036.52 1965.12 5956963.00 694167.68 12.00 4355.31 90.36 MW D 12675. 00 89.48 109.93 8718.88 -4044.43 1988.83 5956955.70 694191.59 12.00 4376.61 90.34 MW D 12700. 00 89.46 112.93 8719.11 -4053.56 2012.10 5956947.17 694215.08 12.00 4398.56 90.31 MW D 12725. 00 89.45 115.93 8719.35 -4063.90 2034.86 5956937.41 694238.09 12.00 4421.11 90.28 MW D 12750. 00 89.43 118.93 8719.59 -4075.42 2057.04 5956926.47 694260.56 12.00 4444.19 90.25 MW D 12770. 00 89.42 121.33 8719.79 -4085.46 2074.34 5956916.88 694278.11 12.00 4463.00 90.22 MW D 12775. 00 89.42 120.73 8719.84 -4088.04 2078.62 5956914.41 694282.46 12.00 4467.73 270.00 MW D 00. 00 89.43 117.73 8720.09 -4100.24 2100.43 5956902.76 694304.57 12.00 4491.10 270.01 MW D 2825. 00 89.43 114.73 8720.34 -4111.29 2122.86 5956892.29 694327.27 12.00 4513.98 270.04 MW D 1 850. 0 89.43 111.73 8720.59 -4121.15 2145.82 5956883.02 694350.48 12.00 4536.30 270.07 MW D 12 75 0 89.44 108.73 8720.84 -4129.80 2169.28 5956874.98 694374.14 12.00 4557.99 270.10 MW D 129 00 89.45 105.73 8721.08 -4137.20 2193.15 5956868.19 694398.20 12.00 4579.01 270.13 MWD 129 . 00 89.45 102.73 8721.32 -4143.35 2217.38 5956862.66 694422.57 12.00 4599.29 270.15 MWD 129 . 00 89.47 99.73 8721.55 -4148.22 2241.90 5956858.42 694447.21 12.00 4618.78 270.18 MW D 129 5 0 89.48 96.73 8721.79 -4151.80 2266.64 5956855.48 694472.03 12.00 4637.43 270.21 MW D 13 00. 0 89.49 93.73 8722.01 -4154.08 2291.53 5956853.83 694496.97 12.00 4655.17 270.24 MW D 1 25. 89.50 90.73 8722.23 -4155.05 2316.51 5956853.50 694521.96 12.00 4671.98 270.27 MW D 1 050. 0 89.52 87.73 8722.44 -4154.72 2341.50 5956854.47 694546.93 12.00 4687.79 270.29 MW D 13075. 0 89.54 84.73 8722.65 -4153.08 2366.44 5956856.75 694571.83 12.00 4702.56 270.32 MW D BP Alaska w6u6~>•x o6ruu 030009316t~601 •~ M m MO. 10693. ~O6 LEGEND 10-14 (18-14) - - 18-14118-16A) ___ 18-14(,8-14A B1) 18-14(18-14B) Pian 3,18-14BL1 Plan 3 Gmbc1 MMnwhan-. ~1~~1~11 ~oi.nna E riuil. dll.micnaMw~®~nWC.wm • • rements are r 1 i ~_ ~ 18-14C of bag bttm of bag middle of pipes/slip 2~~ combi ram/slips BAG TOTs ~ -~ Mud Cross I I Mud Cross of flow cross fiddle of pipe/slip 2 3/$~~ pipe/slip TOTs iddleofpipe/slips 2~~ pipe/slips ve Blind/Shears Flow Tee 18-14BL1 -change of completic2n plan ~ Page 1 of 1 Maunder, Thomas E DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 02, 2008 11:34 AM To: 'McLaughlin, Sean M' Cc: McMullen, Jahn C; NSU, ADW Drlg Nardic 1 Supervisor; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-146L1 -change of completion plan Sean Thanks for the information. You are correct that this newly drilled well segment will become 18-14C. I have spoken to my colleagues and unfortunately it will be necessary to submit a new permit application. This is necessary due to the data system we employ. It is not possible to just "over write" information. It will also be necessary to submit a 407 abandoning the lost portion of 18-146. It is not necessary to halt operations. The new application should be submitted as soon as possible. Please include a discussion of what has happened to require the new permit. There should also be a discussion regarding the reserves that will no longer be accessible due to the plugging of 18-146. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Thursday, October 02, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; NSU, ADW Dr(g Nordic 1 Supervisor Subject: 18-146L1 -change of completion plan Tom, Nordic 1 is currently drilling 18-14BL1. This lateral was planned to be completed with a slotted finer. Unfortunately last night the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent well bore. Our planned 18-14BL1 wauld then become 18-14C. Would this require a change to the current permit (208-132) or a new permit? Regards, Sean «18-146L1.jpg» «18-14C.jpg» Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 10/3/2008 Alaska Department of Natural sources Land Administration System Page 1 of~ ~ See Township, Range, Section and Acreage? ~` Yes C~ No New Search 1..45 Meng ~ Case Abstract ~ Case Detail ~ t_arrrl Abstract .-. I~Ie: ~1)I, 28321 Search for Status alai L~i~~~.~7~f~s ~~ ~,f IOiO-~,"2005 Custon~ei°: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: ';'~ OlL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Locution: DOG DIV OIL AND GAS Cure Status: 35 ISSUED Statr~s Date: 09/14/1965 Total Acres: ?480.000 Date Irritiuted: OS/?8/I965 Office ~fPrinuu~~ Responsibility: DOG DIV OIL AND GAS Lust Trunsactiorz Date: 12/04/2006 Ca.S~e Subtype: ~=•~ NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED 11'Ieridi~r~i.~ l_! l nrr~nshr~~ ll I 1 N P~r/r~t_': 0 I ~ E : ~~~~~~~inu: 17 .Section Ac~r~~s: (40 I''lats l~el"hihUl.~ i_~ I~ON~nShli': Q~ ~ N ~~i771,~C'.~ 01JE Section. ~ ~ ,~~~'i'/lU/1 .~~'/'C,~.' 599 ~~~'}~lcil~!/1.' I_~ TObV77S{]l)l: U~ ~'~ 2an~C.~ 015E SeCtI0T1: ~~) .~~~'~'lIUII.~~c'i'C,~: OOI ~1leridiuji: L! l~„vnshr/> 011N Range: Ol~E Section: ~U S'c~c~iioil,lcr~~s. (,-l(1 Legal Description 0>-2~S'-196 *** ~S:-ILF.:VOTIC'L' I,ECTAL DL'SCRIPTION *** C'I~-1~1 TIIN, Rl~l, CIL71?, IS, 19, 202=1<40.00 e~ SE' ~U t'°t1 tit Last updated on 10/03/2008. Search http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28321 &... 10/3/2008 • TRANSMITTAL LETTER CIiECKLIST WELL NAME ,~~~ J~ /~G' P•rD# ao~~~s/ Developments ,_ Service _____ Exploratory Strati _____ Non-Conventional Welt graphic Test FIELD: ~~`~~ POOL: ~t~XN`E'k ~r - ~~-F r Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~. FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in well ApI number, are Permit No. . AP[ No. SO- between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PIS and AP[ number ~s~ = 1) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect is contingept upon issuance of a conservation order approving a spacing exception. 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 SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for jname of welp unfit after (Coinoanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity.lComnanv Nanee) must contact the Commission to obtain advance approval of such water well testing DroQram R~~: ~n inaos WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 64015D Well Name: PRUDHOE BAY UNIT 18-14C Program DEV Weli bore seg ^ PTD#:2081510 Company 6P EXPLORATION (ALASKA) INC Initial ClasslType DEV! P END GeoArea 890 Unit 11650 OnlOff Shore ~n Annular Disposal ^ Administration 1 Permit-fee attached---- -- -- - ---- - - - -- KA --- - - -- ---- ---- - ---- --- - - - - - ---- 2 Leasenumb@rapproprlate- ------ -- - - - --- ---Yes -- -- - -- - ---- --- ----- ---- --- - ---- 3 Uniqueweli_nameandnumbe[- ----- -- - --- --- ------ Yes------ --- ------ --- -------- ------ -- - ------ 4 Welllocatedlna_deflnedpool_____-.-_-__-----_-----_-- --_ --_--Yes__--- -Prudhoe BayFieldlP[udhoeBayOllPOOI________________________------------_----- 5 WBII14catedProperdlstancef[omdrillingunitboundary-------------- ---------Yes------ -------------------------------------------------- - -- - 6 Weil located P[oper dlstanoe f[om other v~ells- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage_ayailablein_drillingunit_____----___---__--- ----------Yes------ -2560 acres•_---__-------_---_---_----------------------------------- 8 If_deviated,is_wellboreplatinc)uded---- -- -- - -- -- - ---- Yes---- - ---- - - - - ------ ------- ----- - --- --- 9 Ope[alotDnlyafleoiedpa~b'----- --- - -- ----- - ~-- --- Yss------ --- - ---- - ----- -------- - --- - - - ----- 10 Operaiorbas_appropriaiebondinforce----------------------- ----------Yes--.-.- -Blanket Bond#61Q4193.---_-__--_.---_-_-.------------------------------ 11 Pe[mitcanbelssuedwithoulCOns@rvationord@r------------------ ----------Yes------ .--.---.---------------------------------------... ------ ------- Appr Date 12 Pe[mitcanbelssuedwithoutadmioistrative_approval-------------- ----------Yes------ ----.------.-------,--------------------------------- --- --- - 13 Can permit be approved before 15-daywait --- - ----- -- ------- -Yes------ ---- - - -- - - ----- - ---- -- -- - -- - -- --- ACS 101312008 14 _1Nelllocatedvrithirlargaand-sirataAUthorizedbylDJeotiDn9[de[#(put1O#in_comments)(For_ NA------ ------------------------------------------------------------------ 15 Ahwells_within114_mileatea_ofreyi~videnifiQd(Fo[servicewellpnly)----- ---------- NA-_---_- .-_---.---_---__------_--------------------.----------------------- 16 Pte-produced injector. duration of preproducti9nlessthan3months-(ForservlcewellonJy)___NA------ -------_-_---_-.-.---_--._-------.----------------.----------------- 17 Nonoonven,pas-c~nformsioA&31.05,030(j.1.A),G,2.A-D}-- -- ---- - ------- NA-- -- --- -- ------ -- ------ -- --- - - -- --- -------- Engineering 18 Condu-cto[st[ing.p_r@vlded----------------------------- --------- NA------- -ConductorsetinD$1$-14(186.119.-------------------------.------------------- 19 Su[facecasingprotectsall_knownUSD1Ns-------------------- ---------- NA------- -NO aquifers,A1O48,_ConClusion_5.------------.--------.---------------------.-- 20 CMTvoladequateioeirculateonc9nductor&surf-csg-------------- ------_-- NA__--___ _$urfaceoasingsefinQ$18-14._.------_---------_-_--.-_----.--_-----------_- 21 CMTvoladequatet9lie-lnJongstringtosurfcsg----------------- ----__--- NA__-__-- -Production-casing setlnD$1&t4,_____-___-__-___-------_---_-----------_-_.--_ 22 CMT-will cover all known-productivehorizons---_----_---------- ----------Yes------ ---------.-------------------------------...------------- --- ---- 23 Casingd@synsadeAu@te(o[C~LB&-pe[maf[osf. ----- -- - -- -- Yes-- - -- - --- ~ -- ------ --- --- - -- - -- -- -------- 24 Adequate fankage_ or Ceseryepit - - - - - - - - -- - - - - - - _ - . - - - - _ - - - - - -Yes - _ _ - - - -Rig equipped with steel pits, No reserve p!t planned._ AI! wasle_to approved disposalwell(s), - - - - - - - - _ - .. - 25 If a- re-dill, has_a 10~t03 for abandonment been approved - - - - - - - - - - - - - - - - - - - - - - Jyo_ _ _ _ _ _ - Complioations- with originally planned 1$-14Bt 1_(20$-132), See file for email. _ _ - _ _ _ - - - - - - - - _ - _ - - _ _ - 26 Adequate we11bo1e separationprop9sed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - . _ - Proximity analysis perfomled, Nearesi segment is P&A podion of 1$-148 and_paths diyerg@.. _ _ _ _ _ _ _ _ _ - _ . 27 If-divert@r-requited,doesiimeetregulati9na_.-----__---_-__-- --.__--.-_NA__--__ BQPstaCkalreadyinplace---------------__---_--_---------------------- Appr Date 26 Drilling f)uid program schematic-& equip list adequate- - - - - - - - - - - - - - - - - - - - - - -Yes _ - . _ - -Maximum expected fo[mation pressure 7,3_EMW.- Planned MW $:6_ppg.- _ _ _ - - - - - - - - - - . - . _ - - - _ - - TEM 10!3(2008 29 BOPEs,dotheymeetreguJation---- --- - -- ---- - --- Yes----- -- - --- -- -------- --- -- - --- - -- -- - 30 BOPE_press rating appropriate; test ta.(put psig in cpmmerlts)- - - - - - - - - - - - - - - - - - -Yes - - _ - - - MASP caicu)ated at 2444psi, 3500_psi_BQP test planned, _ - _ , - - _ _ - - - - - - _ - - - - - - - _ - - - _ - - - _ - - 31 Choke-roanifoidCOmplieswlAPl_RP-53(May$4)---- - -- -- -- - Yes--- - --- --- - -- - -- -- -- ------- ------ - - -- ---- vvv 32 Workwih9ccu[withoufoperationsbutdown-------------------- ----------Yes----- ------.------------------------------------ ------------------ 33 Js presence of N2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ - _ _ Mln4r_H2S_repolted at DS_ 16, Mud should_pteciude H2S on rig. Rig has sensors and ala[ms, - - _ _ _ _ _ 34 Mechanical-cgnditlonof wellswtthirtAQRyer'lfied(F9rservlcewellonly~---- -----------NA------- -.--------------------------------------------------- -- --- -- Geology 35 Pemtit can be Issued wlo hyd[ogert sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - _No_ _ _ - - - Max level H2$ on_ D$18=29ppm_ on weh 1$-14B. _ _ _ _ _ _ - _ - _ _ _ - _ . - - - - - _ - - - - - - - _ - _ _ 36 Daia_ptesented on potential overpressure zones- - - - - - - - - - - - - - - - - - - - - NA _ - ""`""&es smalls in file.-dell segment originalry permited_as 1$-14141,1, Adequate standoff-togas-noi [ealized - _ - Appr Date 37 Seismic anaysis-of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - _ ~""'plans cflanged to c@ment line[. This resultfld_in abandoning the_existing_perforaflons in 1$-14B (203-063a _ _ - ACS 101312008 38 Seabed conditionsurvey_(ifoff-sho[e)_______---------------- ---------- NA__-__- ----.---- ------------------------------------------------------------ 39 Contactnamelphoneforweeky_prop-ressreports[exploratory oniyj____--_ _-_-_---_Yes______ _SeanMcLaughlin_-564.4387----------------------------------------_---_-.-_- Geologic Commissioner: Date: Engineering Date Public Commissioner: Commission Date /~•6•a~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efi(or1 has been made to chronologically organize this category of information. C tapescan.txt **** REEL HEADER **** MWD 09/01/19 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/10/03 2218427 O1 2.375"- CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 10690.0000: Starting De th sTOP.FT 12960.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 18-14C FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 52.178"N 148 deg 26' 39.208"w CNN. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 03 OCt 2008 API API NUMBER: 500292161403 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R15E PDAT. MSL . EPD .F 0 LMF DF FAPD.F 46.4 DMF DF EKB .F 0 EDF .F 46.4 EGL .F 0 Page 1 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level tapescan.txt CASE.F N/A Casing Depth OSl DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 06 Oct 2008 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 18-148 through a milled window in a 3 1/2 inch liner. Top of window Bottom of window (9) Tied to 18-146 at (10) The interval from feet TVDSS) was not logged due to sensor to 10710 ft.MD (8698.0 ft.TVD55) 10715 ft.MD (8698.3 ft.TVDSS) 10693 feet MD (8697.4 feet TVDSS). 12920 feet to 12960 feet MD (8716.4 feet to 8720.3 pit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJ~vG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (oHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, 10322.4, 10323, 10329.9, 10329, 10334.4, 10334, 10339.4, 10338.4, 10342.1, 10342.1, 10343.5, 10344, 10345, 10345.4, 10347.1, 10347.7, 10349.3, 10349.1, 10351.4, 10350.6, 10355.1, 10355.4, 10359.3, 10358.9, 10362.6, 10361.8, 10366.5, 10365.9, 10370.9, 10370.3, 10374.4, 10373.6, 10378.2, 10377.1, 10694.2, 10689.8, 10703.9, 10700.2, 10712.9, 10708.5, 10714.9, 10711, 10716.4, 10713.3, 10720.7, 10718.7, 10728.4, 10725.7, 10731.7, 10727.6, 10744.9, 10738.7, DISPLACEMENT 0.62207 -0.829102 -0.415039 -1.03613 0 0.414062 0.414062 0.62207 -0.207031 -0.829102 0.207031 -0.414062 -0.829102 -0.62207 -0.62207 -0.829102 -1.03613 -4.35352 -3.73145 -4.35352 -3.93945 -3.11035 -2.07227 -2.69434 -4.14648 -6.21875 Page 2 10748, 10743.2, 10750.3, 10745.7, 10757.9, 10751.7, 10772.1, 10771.3, 10775.6, 10774.6, 10783.9, 10781.4, 10787, 10784.6, 10829.2, 10819.7, 10831.5, 10822.6, 10833.5, 10827.7, 10844.3, 10838.3, 10851.4, 10846, 10861.1, 10855.1, 10878.1, 10874.3, 10882.8, 10878.9, 10892.8, 10888.4, 10894.7, 10890.7, 10896.7, 10893, 10901.5, 10897.6, 10904.4, 10900.7, 10907.6, 10902.8, 10910.1, 10905.3, 10915.7, 10910.7, 10920, 10914, 10922.3, 10917.8, 10926.5, 10922.3, 10945.4, 10940.6, 10953.7, 10946.8, 10985.4, 10978.3, 10987.3, 10980.7, 10996.3, 10989, 11003.3, 10996.5, 11011, 11004.3, 11026.3, 11020.2, 11104.1, 11098.9, 11129.9, 11124.6, 11134.9, 11129.7, 11146.1, 11142, 11159.9, 11156.8, 11165.9, 11159.7, 11177.3, 11169.4, 11182.7, 11176.7, 11202.4, 11194.5, 11207.5, 11200.5, 11213.7, 11207.3, 11222.8, 11216.8, 11228.8, 11221.7, 11243.3, 11236.1, 11258, 11253, 11263.6, 11259.3, 11269.8, 11263.4, 11273.5, 11268.5, 11275.4, 11272.3, 11280.1, 11276.4, 11282.8, 11278.9, 11285.3, 11280.8, 11312.5, 11307.1, 11367.8, 11360.7, 11444.2, 11432.4, 11473.4, 11461.8, 11908.5, 11896.3, 11941.5, 11927.9, 11955, 11942.2, tapescan.txt ! -4.76855 ! -4.56055 ! -6.21875 ! -0.829102 ! -1.03613 ! -2.4873 ! -2.4873 ! -9.53613 ! -8.91406 ! -5.80371 ! -6.01074 ! -5.38965 ! -6.01074 ! -3.73145 ! -3.93945 ! -4.35352 ! -3.93848 ! -3.73145 ! -3.93848 ! -3.73145 ! -4.76758 ! -4.76758 ! -4.97461 -6.01172 ! -4.56055 ! -4.14551 ! -4.76758 ! -6.84082 ! -7.04785 ! -6.63379 ! -7.25586 ! -6.84082 ! -6.63379 ! -6.01172 ! -5.18262 ! -5.38965 ! -5.18262 ! -4.14648 ! -3.10938 ! -6.21973 ! -7.87695 ! -6.01172 ! -7.87695 ! -7.04785 ! -6.42676 ! -6.01172 ! -7.04785 ! -7.25488 -4.97461 ! -4.35352 ! -6.42676 ! -4.97461 ! -3.10938 ! -3.73145 ! -3.93945 ! -4.56055 ! -5.38965 ! -7.04785 ! -11.8154 ! -11.6084 ! -12.2305 ! -13.6816 ! -12.8525 Page 3 • tapescan.txt 11965.7, 11953.9, ! -11.8154 11975.4, 11964.7, ! -10.7793 12015.4, 12004.9, ! -10.5723 12057.4, 12053.2, ! -4.14551 12060.3, 12054.3, ! -6.01172 12098.4, 12092.8, ! -5.59668 12116.6, 12101.9, ! -14.7178 12130.5, 12119.5, ! -10.9873 12133.6, 12123, ! -10.5723 12137.7, 12126.5, ! -11.1943 12147.1, 12133.5, ! -13.6816 12159.6, 12142.2, ! -17.4131 12186.9, 12179.4, ! -7.46289 12199.5, 12187.9, ! -11.6084 12206.4, 12195.2, ! -11.1943 12218.2, 12206.2, ! -12.0234 12221.1, 12209.5, ! -11.6084 12229.4, 12216.9, ! -12.4375 12235.8, 12225, ! -10.7793 12249.7, 12241.6, ! -8.08398 12260.5, 12250.7, ! -9.74316 12297.6, 12286.6, ! -10.9873 12300.3, 12289.7, ! -10.5723 12305.2, 12295.5, ! -9.74316 12315.4, 12309.4, ! -6.01172 12319.7, 12312.1, ! -7.66992 12333, 12325.5, ! -7.46289 12374.8, 12368.5, ! -6.21875 12378.7, 12372.9, ! -5.80371 12399.6, 12390.1, ! -9.53516 12402.7, 12393.4, ! -9.3291 12404.4, 12394.5, ! -9.9502 12407.1, 12396.9, ! -10.1572 12409.2, 12399.2, ! -9.9502 12413.1, 12403.1, ! -9.9502 12415, 12405, ! -9.9502 12416.8, 12407.5, ! -9.3291 12420.8, 12410.6, ! -10.1572 12422.8, 12412.7, ! -10.1582 12424.9, 12414.8, ! -10.1572 12426.2, 12416.4, ! -9.74316 12433.8, 12424.1, ! -9.74316 12439.4, 12429.9, ! -9.53516 12444.2, 12434.2, ! -9.9502 12445.4, 12435.7, ! -9.74316 12455.2, 12446.5, ! -8.70703 12457.9, 12447.9, ! -9.9502 12481, 12465, ! -15.9619 12483.5, 12467.3, ! -16.1689 12487.8, 12472.9, ! -14.9248 12491.5, 12478.5, ! -13.0596 12508.1, 12494.2, ! -13.8896 12529.5, 12515.6, ! -13.8887 12532, 12519, ! -13.0596 12545.1, 12532, ! -13.0605 12550.3, 12536.8, ! -13.4736 12553.4, 12540.7, ! -12.6445 12560.6, 12547.8, ! -12.8525 12564.3, 12552.5, ! -11.8154 12571.2, 12558.5, ! -12.6445 12575.7, 12564.8, ! -10.9863 12579.5, 12566.8, ! -12.6445 12581.1, 12569.1, ! -12.0225 Page 4 tapescan.txt 12583.4, 12571, ! -12.4375 12586.7, 12574.7, ! -12.0234 12589.2, 12577, ! -12.2305 12592.3, 12579.3, ! -13.0596 12593.8, 12581.8, ! -12.0234 12605.5, 12589, ! -16.584 12607.8, 12591.2, ! -16.584 12612.4, 12596, ! -16.376 12642.2, 12626.1, ! -16.1689 12654.9, 12638.3, ! -16.583 12667.9, 12651.3, ! -16.583 12677.9, 12660.3, ! -17.6201 12685.6, 12667.6, ! -18.0352 12692.6, 12675.6, ! -16.998 12698.2, 12680.8, ! -17.4131 12703.1, 12687, ! -16.1689 12705.4, 12688.2, ! -17.2061 12708.1, 12691.3, ! -16.791 12713.6, 12696.4, ! -17.2051 12744.4, 12731.6, ! -12.8516 12753.6, 12739.5, ! -14.0957 12757.9, 12743, ! -14.9258 12763.9, 12748.4, ! -15.5469 12770, 12753.4, ! -16.584 12776.4, 12760, ! -16.376 12792.6, 12776, ! -16.583 12821.5, 12803.1, ! -18.4492 12828.2, 12812, ! -16.1699 12832.7, 12817, ! -15.7549 12837.1, 12820.5, ! -16.583 12840.5, 12824.8, ! -15.7549 12846.9, 12833, ! -13.8887 12849.6, 12835.7, ! -13.8887 12854.6, 12838.9, ! -15.7549 12857.1, 12839.9, ! -17.2051 12861.7, 12842.4, ! -19.2783 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 263 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from schlumberger GR CNL dated 06 oct 2008 per Doug stoner with Page 5 tapescan.txt BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 146 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De th = 10320.000000 Tape File End Depth = 12940.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 159 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 L..~ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 Page 6 tapescan.txt The data presented here is final and has been depth shifted to a PDCL from MWD 18-14C dated 03 oct 2008 per Doug Stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Lod Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 42 one depth per frame (value= 0) Datum specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool code samples units 1 GR MWD 68 1 AAPI 2 RAD MWD 68 1 OHMM 3 RAS MWD 68 1 OHMM 4 RPD MWD 68 1 OHMM 5 RPS MWD 68 1 OHMM 1 size Length 4 4 4 4 4 4 4 4 4 4 20 Total Data Records: 107 Tape File Start Depth = 10694.000000 Tape File End Depth = 12926.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 119 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 Page 7 tapescan.txt *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MADPass data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) optical Lod Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 RAD MWD 68 1 OHMM 3 RAS MWD 68 1 OHMM 4 RPD MWD 68 1 OHMM 5 RPS MWD 68 1 OHMM Total Data Records: 213 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Tape File Start Depth = 10694.000000 Tape File End Depth = 12926.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 4 225 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** Page 8 ~ ~ tapescan.txt !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Opticall Lod Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total rata Records: 294 Tape File Start De th = 10320.000000 Tape File End Depth = 12959.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape subfile: 5 307 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/10/03 2218427 O1 Page 9 tapescan.txt **** REEL TRAILER **** MWD 09/01/19 BHI O1 Tape subfile: 6 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes • Tape Subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10320.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10320.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 43.7692 -999.2500 2000.0000 -999.2500 0.0956 15.3789 10800.0000 77.3816 23.8969 37.6830 234.7095 165.4337 305.4163 10900.0000 90.7693 32.6454 38.5433 198.2730 76.7246 81.1376 11000.0000 170.6286 83.8123 36.8330 204.6040 174.4481 353.4377 11100.0000 64.6336 74.4000 43.5098 219.5243 156.9324 269.9186 11200.0000 107.1997 48.8899 48.8022 2000.0000 126.5772 189.5478 11300.0000 70.7845 84.3336 33.5599 199.2740 111.8580 167.5615 11400.0000 78.0047 55.4229 28.0048 119.9445 Page 10 • tapescan.txt 112.1570 181.7068 11500.0000 84.7934 44.0557 182.1686 319.0700 11600.0000 77.0618 59.4817 165.6480 296.3854 11700.0000 74.5293 103.0848 138.5349 228.9996 11800.0000 80.0385 78.1769 137.8490 211.3499 11900.0000 75.3991 84.2613 102.4528 155.0584 12000.0000 73.8587 93.2149 103.6678 150.8834 12100.0000 91.4463 93.9977 201.5016 325.7930 12200.0000 43.4475 108.7803 174.1419 589.5724 12300.0000 43.0116 66.3288 315.1090 1397.8950 12400.0000 68.1000 101.1000 245.7970 652.4099 12500.0000 91.4987 84.0544 141.5550 178.6940 12600.0000 67.4075 48.8279 107.1517 124.0739 12700.0000 35.4002 115.4208 278.2864 1682.3384 12800.0000 73.9717 92.7592 192.5403 456.9705 12900.0000 -999.2500 193.9355 71.4429 73.8869 12940.5000 -999.2500 21.9014 -999.2500 -999.2500 Tape File Start De th = 10320.000000 Tape File End Dept h = 12940.500000 Tape File revel Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR RAD RPS 10694.0000 49.6391 2000.0000 2000.0000 Page 11 39.5052 32.9085 32.6488 35.3707 31.7971 38.1535 2000.0000 72.8066 304.1789 171.8990 2000.0000 2000.0000 197.8930 144.4881 138.1493 -999.2500 RAS 2000.0000 532.2695 205.1494 181.4407 250.7277 135.4225 2000.0000 255.7582 64.7968 194.0570 142.9320 1342.1599 175.-4593 87.3227 91.6184 2000.0000 -999.2500 RPD 2000.0000 tapescan.txt 10694.5000 47.6795 2000.0000 2000.0000 2.2522 2000.0000 10700.0000 44.5598 2000.0000 2000.0000 2000.0000 2000.0000 10800.0000 65.7016 118.3207 2000.0000 108.8270 123.5140 10900.0000 92.0000 183.6160 2000.0000 58.7725 54.5391 11000.0000 163.4000 148.0676 347.4114 214.3926 377.6900 11100.0000 66.5000 316.6700 2000.0000 93.5450 95.9881 11200.0000 109.9473 108.2376 2000.0000 123.8195 164.5358 11300.0000 74.7104 84.4078 233.3162 95.2690 115.7347 11400.0000 78.9011 63.0055 277.6885 107.1059 147.6850 11500.0000 85.8000 184.5698 2000.0000 133.6491 170.3096 11600.0000 71.0439 370.7911 2000.0000 205.1243 298.4614 11700.0000 74.4195 136.1940 363.3768 123.0936 159.0740 11800.0000 83.9870 505.8688 264.7922 129.6971 163.2271 11900.0000 77.0000 78.2786 179.7533 88.1928 112.3915 12000.0000 80.1679 101.3233 209.7906 99.1400 118.1330 12100.0000 86.6571 1772.6929 2000.0000 159.8980 190.8162 12200.0000 39.8402 58.3613 68.4593 138.6293 300.0795 12300.0000 46.3000 207.5019 189.8390 262.1479 560.9280 12400.0000 60.6444 70.2000 257.1702 174.4197 499.8701 12500.0000 80.3000 282.5940 2000.0000 133.6940 168.4610 12600.0000 73.4107 114.1464 2000.0000 104.5103 133.7040 Page 12 • tapescan.txt 12700.0000 36.5000 75.9742 85.3645 205.8943 451.2149 12800.0000 73.4055 69.6150 83.1508 177.2204 447.0428 12900.0000 157.6039 218.7039 2000.0000 54.4026 62.4032 12926.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start De th = 10694.000000 Tape File End Depth = 12926.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS DEPTH GR RAD RAS RPD RPS 10694.0000 54.6000 -999.2500 -999.2500 -999.2500 -999.2500 10694.2500 53.0000 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 46.9000 2162.8501 6933.3096 1.6430 98641.8906 10800.0000 67.4000 123.5000 6933.3096 108.8270 129.3810 10900.0000 126.9000 109.4470 160.8170 61.2600 65.5900 11000.0000 190.6000 123.5000 376.7420 200.5030 338.0610 11100.0000 66.1000 387.1300 6933.3096 108.8270 124.9470 11200.0000 80.3000 179.2760 6933.3096 133.6940 160.3780 11300.0000 66.5000 87.8830 203.1420 84.5240 97.2710 11400.0000 80.0000 58.9240 124.8470 102.6400 150.5860 11500.0000 84.3000 149.6380 1840.5300 126.5260 159.0740 11600.0000 74.7000 2162.8501 6933.3096 218.2380 305.5420 11700.0000 72.1000 87.0000 306.6230 150.6220 203.7010 Page 13 • • tapescan.txt 11800.0000 86.2000 222.4330 5602.4121 161.3090 11900.0000 64.7000 78.4260 132.9500 113.1820 12000.0000 68.4000 66.5170 108.6140 12100.0000 83.1000 213.0460 150.5860 12200.0000 38.5000 61.2360 305.5420 12300.0000 107.6000 80.7500 573.7560 12400.0000 41.0000 88.9970 367.5480 12500.0000 89.2000 106.0620 144.0440 12600.0000 79.5000 173.3900 100.4790 12700.0000 58.0000 704.6909 1037.7271 12800.0000 36.5000 71.7760 645.2710 12900.0000 157.0000 40.0310 93.4060 12926.0000 -999.2500 70.6590 109.9020 Tape File Start De th = 10694.000000 Tape File End Dept h = 12926.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 5 is type: LIS DEPTH GR ROP RPD RPS 10320.0000 -999.2500 -999.2500 -999.2500 -999.2500 10320.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 -999.2500 98.7850 269.3460 108.2770 5305.6758 157.3920 151.2480 743.1389 131.4380 75.8150 109.4530 2736.3140 RAD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 131.9880 91.4210 91.4210 120.0530 133.6940 245.3620 175.5440 127.6100 96.1950 285.4980 200.5030 64.4610 97.9470 RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Page 14 • • tapescan.txt -999.2500 -999.2500 10700.0000 46.2000 -999.2500 2162.8501 -999.2500 0.1760 14.5010 10800.0000 72.8000 29.5000 37.6650 239.0560 168.4650 309.9200 10900.0000 135.3000 51.1000 36.5590 211.5200 67.2290 73.7560 11000.0000 203.7000 92.1000 39.4880 201.5260 136.7980 223.9430 11100.0000 76.0000 73.0000 41.7060 260.2890 153.3670 260.7410 11200.0000 78.7000 55.1000 48.2460 6933.3096 142.0310 217.2040 11300.0000 56.4000 62.0000 34.7020 138.0230 102.2560 153.7670 11400.0000 78.7000 48.0000 26.8820 96.8640 101.1530 162.5730 11500.0000 82.0000 60.7000 39.8170 330.6790 178.0900 300.0090 11600.0000 74.2000 38.9000 58.4490 3740.6899 152.3010 51244.1719 11700.0000 81.9000 49.5000 30.4110 183.4830 138.8210 234.8180 11800.0000 78.5000 29.4000 33.8310 186.7580 130.3130 211.9620 11900.0000 65.2000 69.6000 30.3770 114.2870 101.7170 153.0130 12000.0000 75.3000 36.6000 34.1310 254.7660 103.5800 146.6110 12100.0000 78.2000 106.5000 1669.8899 138.4790 133.0970 171.8570 12200.0000 48.7000 104.3000 95.5010 66.0220 157.3940 448.2050 12300.0000 126.6000 27.9000 2162.8501 83.0240 307.3400 39346.5391 12400.0000 41.0000 105.3000 153.6700 136.3910 279.1390 766.9440 12500.0000 91.4000 291.4000 805.4459 280.5890 133.5870 168.2950 12600.0000 46.2000 39.7000 2162.8501 6933.3096 141.5550 158.9240 12700.0000 95.8000 108.7000 1821.8149 118.6340 Page 15 tapescan.txt 394.1720 75254.8125 12800.0000 36.0000 102.9000 167.1750 244.3870 845.5300 12900.0000 104.2000 90.5000 77.2540 88.1250 125.4670 12959.7500 -999.2500 99.9000 -999.2500 -999.2500 -999.2500 Tape File Start Deppth = 10320.000000 Tape File End Depth = 12959.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 6 is type: LIS 97.1240 54.9340 -999.2500 Page 16