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Home My WebLink About204-166 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dO If. - 1- (Pro- Well History File Identifier Organizing (done) D Two-sided 11111111111 ""111I D Rescan Needed 1111111111111111111 RE,CAN 'Ø" Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. ~ D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: o Other:: BY: ~ Date: 1 d.-II/ lo(p I I 151 \11P Project Proofing 111111111111111111I BY: ~ Date: 1:1./11/06 I ,¡ á X 30 = (PO 151 rtlfJ BY: Date: + ~ = TOTAL PAGES to I (Count does not include cover sheet) 151 p Scanning Preparation Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: b ~ (Count does include cover sheet) LYES BY: ~ Page Count Matches Number in Scanning Preparation: Date: I ð.!11 /0 b If NO in stage 1, page(s) discrepancies were found: 151 NO ý\¡rP Stage 1 YES NO BY: Maria Date: 151 11111111111I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I1111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11/1/1111111 111/111 10/6/2005 Well History File Cover Page.doc A RECEIVEW STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSICO 1 N, j' ; ' , :'. U11 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well Ej Plug Perforations 0 Stimulate 0 All9tterlrN FAV t.;com tQ6Alfe11n fl Performed: Alter Casing Pull Tubing Perforate New Pool E Waiver0 Time Extension 0 . .. . . Change Approved Program ❑ Operat. Shutdown ❑ Perforate In Re -enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ ^. 204 -1660 3. Address: P.O. Box 196612 Stratigraphic Service el 6. API Number: Anchorage, AK 99519 - 6612 ,- 50- 029 - 20863 -01 -00 8. Property Designation (Lease Number) : Y 9. Well Name and Number: ADLO- 028330 • PBU 12 -20A 10. Field /Pool(s): r- PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10635 feet Plugs (measured) None feet true vertical 9004.59 feet Junk (measured) None feet Effective Depth measured 10589 feet Packer (measured) 2484, 8777 10132 10185 feet true vertical 8961 feet (true vertical) 2484. 7288 8525 8575 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 91.5# H -40 25 - 106 25 - 106 1490 470 Surface 2351' 13- 3/8 "72# L -80 24 - 2375 24 - 2375 4930 2670 Production 8898' 9 -5/8" 47# L -80 22 - 8920 22 - 7410 6870 4760 Scab Liner 6293' 7" 26# L -80 2484 - 8777 2484 - 7288 7240 5410 Liner 1546' 7" 26# L -80 8777 - 10323 7288 - 8707 7240 5410 Liner 450' 4 -1/2" 12.6# L -80 10185 - 10635 8575 - 9005 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 10189 23 - 8579 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP To Packer 2484 2484 7" Baker ZXP Top Packer 8777 7288 4 -1/2" BakerS -3 Perm Packer 1013 8525 4 -1/2" Baker ZXP Mech Set LT Packer 10185 8575 12. Stimulation or cement squeeze summary: MAY r� y Intervals treated (measured): t•'*'bs 2 4 2011 11 Treatment descriptions including volumes used and final pressure: I 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 9816 140 Subsequent to operation: 9574 112 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service` 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: .... Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na • - Lastu ilk Title Petrotechnical Data Technologist Signatur_ My` ■ Phone 564 -4091 Date 5/12/2011 W IlltBDMS MAY 1.31 s Z J' < < Form 10-404 Revised 10/2010 Submit Original Only 12 -20A 204 -166 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12 -20A 11/5/04 PER 10,488. 10,528. 8,864.95 8,903.07 12 -20A 11/6/04 PER 10,427. 10,444. 8,806.7 8,822.94 12 -20A 11/6/04 PER 10,463. 10,488. 8,841.09 8,864.95 12 -20A 3/27/11 CKS 10,177. 10,528. 8,567.58 8,903.07 12 -20A 5/9/11 APF V 10,341. 10,361. 8,724.55 8,743.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 411 • • 12 -20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/9/2011 ** *WELL SHUTIN ON ARRIVAL * ** (ELINE PERF) f INITIAL T /I /O= 0/100/0 1 ;RIH WITH MH22 /ERS /UPCT /20' 2 -7/8" HSD GUN 6 SPF PJO OAL =29', OAW= ''270 #, FISHING NECK SIZE= 1.38" PFRFORATE INTERVAL 10341'- 10361'. CORRELATED TO SLB 5 -NOV -2004 GR/CCL. ENTRY HOLE = 0.34 ", PENETRATION =36 ", SWELL= 2.3.16" WELL LEFT SHUT IN WING, SWAB, SSV= OPEN OTG FINIAL T /I /O= 0/0/0 ** *JOB COMPLETE * ** 1 FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 TOTAL 4 TREE = FMC GEN 3 I 0 ETY NOTES I WELLHEAD = FMC 12-20A ACTUATOR = AXELSON KB. ELEV = 77' BF.ELEV= - KOP = 2700' Max Angle = 47 @ 6424' Datum MD = 10556' Datum TV D = 8800' SS 1 1 I 2208' H4-1/2'' 4 -112" HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2383' HA I 2484' I — 9 -5/8" X 7" BKR SLZKP LNR TOP PKR w /TIEBACK SLV & FLEX LOCK LNR HGNR, ID = 6.726" Minimum ID = 3.725" @ 10177' % 4 -1/2 HES XN NIPPLE ∎ i 1 1� 1 1 1 1I ►/ 7" SCAB LNR (CMT'D), 26 #, — 8777' ►: I 8777' H 7" BKR TIEBACK SEAL ASSY, ID = 6.160" I L -80 BTC-M, ID = 6.276" I 8777' I — 9 -5/8" X 7" BKR ZKP LNR TOP PKR & HMC LNR HGNR, ID = 6.280" MILLOUT WINDOW (12 -20A) 8920' - 8936' I9 -5/8" WHIPSTOCK (09/26/04) H 8925' 10069' I-14 -1/2" HES X NIP, ID = 3.813" 1 I ESZV (09/24/04) I - 1 8946' 101321-- I-17" X 4 -1/2" BKR S3 PKR, ID = 3.875" I 1TOP OF CEMENT (09/24/04) I 9275' ��Vs��V�� ►111111111111111111111 ,� 10156' H4-1/2" HES X NIP, ID = 3.813" 1 ►11111111f ►1.: 111 E 1111� = �� 10177' 1-14-1/2" HES XN NIP, ID = 3.725" I 5 -1/2" TBG -PC, 17 #, L -80, ID = 4.892" I 10044' 141 1 1 1 1 1 1 I TOP OF 7" LNR 10061' 11111∎ „ � � 11 I 10185' 1— X 5" BKR ZKP LNR TOP PKR 14 - 1 /2" TBG - PC, 12.6 #, L - 80, ID = 3.958" 1 10117' 1 # ■ w /TIEBACK SLV, ID 4.420" ►• +1 1111'' 1. 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I- j 10382' ► 10189' H4-1/2" WLEG, ID = 3.958" I ►1111111 .1.1.1.1. ! 10199' I — 7" X 5" BKR HMC LNR HNGR, ID = 4.440" gall i 10206' I — 5" X 4 -12" XO, ttt'ttt't't ID = 3.990" 17" LNR, 29 #, L -80, ID = 6.184" I—I 10940' 0.1.1.1.1.1.1: I TD H 10950' I ►•1.1.1.1.1.1.1 / b 3K 3G r 4 -1/2" TBG, 12.6 #, L -80 TCII, — 10189' I .0152 bpf, ID = 3.958" ` PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 10/04/04 I7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" I 10323' ` ANGLE AT TOP PERF: 17 @ 10424' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10427 - 10444 0 11/05/04 IPBTD LJ 10589' I 1 \ 2 -7/8" 6 10463 - 10528 0 11/05/04 4 %0' I4 -112" LNR 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" H 10635' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/30/82 ORIGINAL COMPLETION WELL: 12 -20A 10/06/04 N7ES SIDETRACK (12 -20A) PERMIT No: 2041660 11/06/04 MDC/PJC PERFS API No: 50- 029 - 20863 -01 12/08/05 MJA/TLH DRLG DRAFT CORRECTIONS SEC 18, T1 ON, R15E, 2426.03' FEL & 5272.94' FNL 11/17/10 CSR/PJC PERF CORRECTIONS BP Exploration (Alaska) ~ STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMMISS ON ' ~" REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair WeU ~ Plug Perforations ~ Stimulate~ Other Q? g~IGH1' WATER Performed: Alter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver[] Time Extension~ TREATMENT Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ 204-1660 ~ 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage,AK 99519-6612 50-029-20863-01-00 ,j 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028330 ~ PBU 12-20A ~j 10. Field/Pool(s): Prudhoe Bay FIELD / Prudhoe Bay POOL l 11. Present Well Condition Summary: Total Depth measured 10635 ~ feet Plugs (measured) None feet true vertical 9004.59 ~ feet Junk (measured) None feet Effective Depth measured 10589 , feet Packer (measured) 2484 8777 10132 10185 true vertical 8961 ; feet (true vertical) 2484 7288 8525 8575 Casing ~ength Size MD ND Burst Collapse Structural Conductor 79 20" 91.5# H-40 Surface - 79 Surtace - 79 1490 470 Surtace 2382 13-3/8"72# L-80 Surface - 2382 Surface - 2382 4930 2670 Intermediate 8920 9-5/8" 47# L-80 SurFace - 8920 Surface - 7410 6870 4760 Production Liner 7839 7"26# L-80 2484 - 10323 2484 - 8707 7240 5410 Liner 450 4-1/2" 12.6# L-80 10185 - 10635 8575 - 9005 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 23 - 10189 23 - 8579 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer " 2484 ~ "~ 2484 7 Baker ZXP Too Packer 8777 ~ 7288 " ~~~~ 4-1/2 Baker S-3 Perm Packer 10132 8525 4-1/2" Baker ZXP Mech Set LT Packer 10185 8575 12. Stimulation or cement squeeze summary: Intervals treated (measured): . i, , ~:.: r€ t,~~'r~F 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: 10030 531 Subsequent to operation: 9974 559 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service Q Daily Report of Well Operations X 16. Well Status after work: Oil Gas WOSPL GSTOR ~ WAG Q GINJ ^ W1NJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowiedge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 9/16/2009 " e*'~~ ' ' .. j ,~, ~~I`'; 1P . .~uunn~ vnyuiai viny . _. ~ . ~ .. ~~ ~~~ 12-20A 204-166 PFRF OTTOCHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-20A 11/5/04 PER 10,488. 10,528. 8,864.95 8,903.07 12-20A 11/6/04 PER 10,427. 10,444. 8,806.7 8,822.94 12-20A 11/6/04 PER 10,463. 10,488. 8,841.09 8,864.95 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ ~ 12-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY MElVIORANDUM Tai Jim Regg P.I. Supervisor ~~~~ f ~'~ ~~ ~Zti~~ ~' FROM: John Cnsp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-20A PRUDHOE BAY L'NIT 12-20A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ ).~ Comm Well Name: PRUDHOE BAY UNIT 12-20A API Well Number: 50-029-20863-01-00 Inspector Name: John Crisp Insp Num: mitJCr08121 1055518 Permit Number: 204-166-0 Inspection Date• 12/6/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ Iz-2oA ~~TypeInj. ~ w ~ TVD ~ sszs ~~ IA ~ I6o ~ z3oo ~I zzao ~ zzzo ~~ i p T I zoa166o ,TypeTest ~ SPT ~ Test psi ~ zlsl.zs ~ OA I o ~, o o o Interval aYRTST plF, P ~ Tubing ~ soo so 00 ! soo ~ j NOteS' 4 bbl's pumped for test. IA has ANSI I s00 flange installed with no guage just a plug in the flange. The integrity of the annulus valve could not • be verified. BPX Supervisor Joe Anders ordered DHD & Little Red to exceed working pressure of ANSI flange. There was no reason to risk ~ exceeding working pressure so I would not test with 4,000 psi. MIT was performed with State required test pressure. i~~Ionday, hecember 15, 2008 Page 1 of 1 OPERABLE: 12-20A (PTD #2041660) AOGCC UIC MITIA Passed Page 1 ~~ • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, December 07, 2008 1:22 PM ~~~~ (~I I~~ To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, FS1 DS12 Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FS1 DS12 Operator; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Cooper, Katrina N; Winslow, Jack L.; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 12-20A (PTD #2041660) AOGCC UIC MITIA Passed All, Well 12-20A {PTD #2041664) has been brought online and is currently under injection. The well was able to be pressure tested and passed an AOGCC witnessed test to 4000 psi on 12/06/08. The well has been returns to npPra_ b~tatus and may continue injection as Operations sees fit. I would like to recognize the Operations team for their hard work in getting 12-19, 12-20A, and 12-34 {tripled injectors} online to be able to test the webs. It was a great effort and it is appreciated, Please canfact me if there are any questions ar comments. Thank yau, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 ^~~~'~~'~:~~~~ "~~~ ~:_ ~~~ Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, November 23, 2008 11:29 AM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, FSl DS12 O tor; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FSl DS12 Operator; 'Re , James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-20A (PTD #2041660) To place on injection for AO C UIC MITIA All, Well 12-20A {PTD #2041660} has been reclassified~a~XJnder Evaluation. The well may be placed on injection now that the produced water line has been replaced. Once t well is stable, an AOGCC witnessed MITIA will be conducted. Please let us know if yau have any questi Thank yau, . Anna ~D•u6e, <1'. E. Well Integrity Coordinator GIB Wells Group ~'hor€e: {907) 659- r1 t~2 Pager: (907) fi59-5100 x1154 12/19/2008 ~_ UNDER EVALUATION: 12-ZOA (PTD #2041660) To place on injection for AOGCC UIC MITIA Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] *~ 1l~ZA'~Zc.~~ Sent: Sunday, November 23, 2008 11:29 AM ~~ l To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, FS1 DS12 Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FS1 DS12 Operator; Regg, James B (DOA}; Maunder, Thomas E (DOA) Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-20A (PTD #2041660) To place on injection for AOGCC UIC MITIA AI 1, ./ Well 12-20A {PTD #2041660) has been reclassified as Under Evaluation. The Weil may be piac on inipction now that the produced water line has been replaced. Once the well is stable, an AOGCC witnessed MIT1A will be conducted. Please let us know if you have any questions. Thank you, Anna rDui6e, 2'.2. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907) 659-5100 x1154 ~~ From: NSU, ADW Well Integrity Engineer Sent: Monday, November 17, 2008 1:59 PM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, FSl DS12 Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: NOT OPERABLE: 12-20A (PTD #2041660) Expired MIT-IA for AOGCC Compliance All, Well 12-20A (PTD #2041660) is due for an AOGCC required 4-year MIT-IA on 11/21/08. However, to perform the AOGCC witnessed test, the well needs to be on injection. The well will not have water injection available for -1-2 weeks. Therefore, the well has been reclassified as Not Operable until injection is available to perform the test. The well will have an MIT-IA before it is put back on injection and the AOGCC test will then be completed after. Please call with any questions or concerns. Thank you, Andrea Hughes Wel{ Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /24/2008 ~'~`~ ,. s. MICROFILMED 03/01 /2008 r.; ~:- .~. ` Y ~- DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\C~c~Pgs_Inserts\Microfilm_Marker.doc -.-/ S 6~c:- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041660 Operator BP EXPLORATION (ALASKA) INC API No. :O~3~1~ ~'i Well Name/No. PRUDHOE BAY UNIT 12-20A MD 10635 r' TVD 9005 --- Completion Date 11/5/2004 ---"'----------.'"--....~. // UIC Y __) '- =--- Completion Status WAG IN Current Status WAGIN ------~- ._~.~~~- -~- ~~-~----_._..__._~--~----~---~---"-~--_._,.,. REQUIRED INFORMATION Mud Log No Directional surve.y~~= Samples No --,~---,._-~- ~~._~_._-,~~-~-,--- ---,~- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR 1 GR I RES I PWD, MWD DIR I GR I RES 1 DEN I NEU, US Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments I ED D {)fsC Directional Survey 8823 10635 11/9/2004 IIFR -----1 Rpt c.6irectional Survey 8823 10635 11/9/2004 ED D~C ~CtiOnal Survey 8823 10635 11/9/2004 MWD I Rpt irectional Survey 8823 10635 11/9/2004 MWD i I ED D TIF ~079 LIS Verification 8908 10619 3/16/2005 MWD/GRlEWR4/CNP/SLDI j ROP I Rpt 13079 LIS Verification 8908 10619 3/16/2005 MWD/GRlEWR4/CNP/SLDI ROP , ED C Lis ~3565 I nd u ction/Resistivity 8920 10635 Open 2/22/2006 ROP DGR EWR SLD CTN I plus Graphics I Log Vemperature 5 Blu 8700 10583 Case 3/26/2006 GRlCCLlPRESrrEMP 5- I Nov-2004 Log Aonic 5 Col 8675 10323 Case 3/26/2006 US IT Ultrasonic Imaging L Tool GRlCCL 3-0ct-2004 j ----.- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y IIQ Chips Received? ~ Analysis ~ Received? Daily History Received? ~/N ~/N Formation Tops . . Permit to Drill 2041660 MD 10635 TVD 9005 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Well Name/No. PRUDHOE BAY UNIT 12-2OA Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20863-01-00 Completion Date 11/5/2004 Completion Status WAGIN Current Status WAGIN UIC Y ih Date: ~~~_n . . . . WELL LOG TRANSMITTAL ~64--1(P~, 135lÐc;5 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 RE: MWD Fonnation Evaluation Logs 12-20A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 12-20A: LAS Data & Digital Log Images: 50-029-20863-01 1 CD Rom (!!:.t{iòu0 ðlgg/Oll! . . õtJf:-v 1& ýP WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 7, 2005 RE: MWD Formation Evaluation Logs: 12-20A, AK-MW-3286719 1 LDWG formatted Disc with verification listing. API#: 50-029-20863-01 \;\:)1<1 * PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITI AL LETTER TO THE ATTENTION OF: Sperry Drillíng Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 /]L I'h/ Date:~ Sign . STATE OF ALASKA . ALASKA: AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended a WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 o Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic a Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 11/5/2004 204-166 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/27/2004 50- 029-20863-01-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Name and Number: Surface: 10/2/2004 PBU 12-20A 691' NSL, 942' WEL, SEC. 18, nON, R15E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 4688' NSL, 2680' WEL, SEC. 18, nON, R15E, UM 68.96' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 4699' NSL, 2743' WEL, SEC. 18, nON, R15E, UM 10589 + 8961 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 696661 y- 5930998 Zone- ASP4 10635 + 9005 Ft ADL 028330 TPI: x- 694806 y- 5934948 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 694742 y- 5934958 Zone- ASP4 (Nipple) 2208' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aYes DNo NIA MSL 1900' (Approx.) 21. Logs Run: MWD DIR I GR 1 RES I PWD, MWD DIR I GR I RES I DEN I NEU, US IT 22. CASING, liNER AND CEMENTING RECORD CASING :SETTIN,>· £:PTH MD . :SETTING ¡ £:PTH"TVD H<.KE 'po'tIé6 SIZE WT.PERFT; GRADE Top BottOM Top ¡ BOTTOM SIZE ........... 20" 91.5# H-40 Surface 79' Surface 79' 30" 415 sx Permafrost 'C' 13-3/8" 72# L-80 Surface 2382' Surface 2382' 17-1/2" 2100 sx Fondu, 400 sx Permafrost 'C' 9-5/8" 47# L-80 Surface 8920' Surface 7410' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 7" 26# L-80 2484' 10323' 2484' 8701' 8-112" 305 sx 'G', 440 sx 'G', 136 sx 'G' 4-112" 12.6# L-80 10185' 10635' 8575' 9005' 6-1/8" 77 sx Class 'G' 23. Perforations 0Ren to Production (MD + TVD of Top and 24. IRING ). .... i. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2.88 Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10189' 10132' MD TVD MD TVD 10427' - 10444' 8807' - 8823' 25. AClö;.. .~I:I\III:;,N 10463' - 10488' 8841' - 8865' ......... 10488' - 10528' 8865' - 8903' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect w/151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 15, 2004 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-BSl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUb'Pj~ê~~rf(;l1ìPê\ if none, state "none". RBDMS 8Ft ¡ ." .-.- ., OR\G\NAL DEC 0 7nn~ None¡ ~! ~¡ ~I " ,¡;U Gf >N··_~·_'_, ~ ,......--..--..,........,- Form 10-407 Revised 1212003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD CM1 9494' Top HRZ 9788' Base HRZ 9979' LCU I Kingak 10072' Sag River 10335' Shublik A 10363' Shublik B 10385' Shublik C 10392' Sadlerochit 10427' 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, rvD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 7924' None 8199' 8379' 8467' 8719' 8746' 8767' 8773' 8807' 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date l~/O PBU 12-20A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 204-166 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump. Submersible. Water Injection, Gas Injection. Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 4,525 (pSi) 0.00 (ppg) - Printed: 10/11/2004 9:30:39 AM 725 (pSi) 8.40 (ppg) 8,709.0 (ft) 0,323.0 (ft) FIT 10/2/2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 9/19/2004 10/5/2004 Spud Date: 11/11/1982 End: 10/5/2004 9/19/2004 20:00 - 21 :30 1.50 MOB P PRE Prep Rig floor to lay down derrick, disconect topdrive, bridle up, held PJSM wI Toolpusher, lay down derrick. 21 :30 - 23:00 1.50 MOB P PRE Blow down pits & disconect service lines. 23:00 - 00:00 1.00 MOB P PRE Held PJSM wrroolpusher, Peak. prep pits and rig for move. 9/20/2004 00:00 - 07:00 7.00 MOB P PRE Move pits away from rig, Pull rig off U-12A & position to allow pits, camp and shop to pass. Move Pits, camp and shop from U-pad to DS-12. 07:00 - 09:00 2.00 MOB P PRE Spot camp and shop, position pits to spot on 12-20A. 09:00 - 00:00 15.00 MOB P PRE Move sub from U-pad, 9 miles into move at pipeline crossing at the intersection of Spine road and A-pad turn off, the sub broke through the road, 100' before pipe line crossing, were able to back the rig up, filled holes with timbers and matted this section up to the existing matts laid for pipe line crossing, 3 hr delay. Continued moving @ midnight rig was 1 mile from WOA check point. 9/21/2004 00:00 - 14:30 14.50 MOB P PRE Continue Moving rig from WOA checkpoint. Approximately 1/4 mile past WOA check point rig fell through the road, began cutting timbers and blocking up under tires, lay plywood from in front of rear tires to front tires, lay mats in front of rig. 14:30 - 00:00 9.50 MOB P PRE Held PJSM with Peak drivers, utilized Peak truck to assist rig out of hole & up on mats. Shuttle mats around Colleen Lake with three Veco contract trucks, two loaders from heavy equipment, two rig loaders, and support from field engineers Scott Grieve, Mike Calloway and roustabout crew from tool service. Mats will be required for this entire section of road to the turn at 100% pad and on to the pipeline crossing at Baker Fishing shop. At midnight the rig had progressed 1 mile from the point of falling through the road and are currently sitting in front of the water hole at Colleen Lake. 9/22/2004 00:00 - 04:00 4.00 MOB P PRE Lay mats from the water hole at Colleen Lake to corner at 100% pad, move rig to intersection. 04:00 - 09:00 5.00 MOB P PRE Pickup mats and shuttle around rig, lay mats from intersection to turn off to Shlumberger camp. 09:00 - 11 :30 2.50 MOB P PRE Move rig to Shlumberger camp, continue moving rig to DS-12, utilizing plywood on shoulders as needed. rig on location at 11 :30. 11 :30 - 12:00 0.50 MOB P PRE Position Sub to to move over well. 12:00 - 13:00 1.00 MOB P PRE Remove wing valve on tree. (valve woud hit BOP stack) 13:00 - 15:00 2.00 MOB P PRE Lay herculite around cellar, spot and level rig over hole. Lay mats for pits, spot pits. 15:00 - 18:00 3.00 RIGU P PRE Held PJSM wi Toolpusher, raise derrick, pipe shed chute, unbridle blocks and hang bridle line in derrick, R/U topdrive, mud lines and cement line. Take on seawater. Accept rig @ 17:00 hrs 9/22/2004 18:00 - 19:00 1.00 WHSUR P DECOMP R/U DSM lubricator and pull back pressure valve, well on vacuum. 19:00 - 20:00 1.00 KILL P DECOMP RIU and test mud line and secondary kill lines. 20:00 - 00:00 4.00 KILL P DECOMP Held PJSM, R/U to reverse circulate taking returns through choke manifold to cuttings tank. Reverse diesel from tubing, took 64 bbls to fill hole, pumped an additional 60bbls, to displace diesel at 3 bpm, 275 psi. R/U and pump down tubing initial rate 5 bpm @ 90 psi, slowed rate to 1 bpm, while getting Printed: 10/11/2004 9:30:48 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 9/19/2004 10/5/2004 Spud Date: 11/11/1982 End: 10/5/2004 9/22/2004 20:00 - 00:00 4.00 KILL P DECOMP air and diesel back and keep returns from splashing out of cuttings tank. Hole taking 45 bph. 9/23/2004 00:00 - 03:30 3.50 KILL P DECOMP Held PTSM, Continue circulating down tubing, taking returns through choke, until clean seawater at surface, 4 bpm ,130 psi, pumped a total of 655 bbls. Zero pressure on tubing and annulus. Blow down circulating lines and choke manifold. Lost a total of 318 bbls during displacment. 03:30 - 04:00 0.50 WHSUR P DECOMP R/U and install BPV. 04:00 - 06:00 2.00 WHSUR P DECOMP Nipple down tree, inspect lifting threads on tubing hanger, Keep hole full by pumping down 5.5" X 9 5/8" annulus with charge pump. 06:00 - 09:00 3.00 WHSUR N SFAL DECOMP BPV set too high blanking plug will not seat properly, attempt to re set BPV, no go. 09:00 - 10:30 1.50 WHSUR N SFAL DECOMP Nipple tree back up. 10:30 - 11 :30 1.00 WHSUR N SFAL DECOMP Rig up DSM lubricator, and pull BPV, 11:30 -12:00 0.50 WHSUR N SFAL DECOMP Flush profile in tubing hanger with water hose, berfore re installing new BPV. Losses for past 12 hrs = 451 bbls. 12:00 - 12:30 0.50 WHSUR N SFAL DECOMP Install BPV. 12:30 - 13:30 1.00 WHSUR N SFAL DECOMP Nipple down tree and install blanking plug. 13:30 - 16:00 2.50 BOPSU P DECOMP Nipple up BOP and riser. 16:00 - 16:30 0.50 BOPSU P DECOMP R/U BOP test equipment 16:30 - 00:00 7.50 BOPSU P DECOMP Test BOP's per testing procedure to 250 psi low, 3,500 psi high, Jeff Jones with AOGCC witnessed BOP test Losses for last 12 hrs = 382 bbls 9/24/2004 00:00 - 00:30 0.50 BOPSU P DECOMP RID BOP test equipment. 00:30 - 01 :30 1.00 BOPSU P DECOMP R/U DSM lubricator, pull BPV, RID Lubricator 01 :30 - 02:30 1.00 PULL P DECOMP MIU landing joint, screw into hanger, Back out lock down screws. Pull tubing hanger to floor, broke loss @ 225k up weight = 185K, 02:30 - 04:00 1.50 PULL P DECOMP Circulate Bottoms up @ 500 gpm, 700 psi, lost 58 bbls while circulating. Rig up contro/line spooler and casing tools while circulating. 04:00 - 04:30 0.50 PULL P DECOMP Lay down tubing hanger, landing joint, break and lay down circulating head. 04:30 - 12:00 7.50 PULL P DECOMP Lay down 5.5" 17# L-80 tubing. Laid down 155 jts, SSSV, recovered 27 control line clamps and 3 SS bands. Losses in past 12 hrs = 636 bbls. 12:00 - 16:30 4.50 PULL P DECOMP Continue POH laying down 5.5" 17# L-80 tubing, laid down a total of 239 jts. plus 19.50' cut off jt. Rig down casing tools 16:30 - 17:00 0.50 CLEAN P DECOMP Clean floor, change elevators and bails. 17:00 - 17:30 0.50 CLEAN P DECOMP Install wear ring. 17:30 - 00:00 6.50 CLEAN P DECOMP PJSM wI Sch/umberger, rig up E-line tools, RIH with 8.5" gauge ring junk basket, tag stump @ 9,325', POH with gauge ring and lay down. Make up Halliburton 9 5/8" EZSV and RIH. Losses for past 12 hrs = 519 bbls. 9/25/2004 00:00 - 02:00 2.00 DHB P DECOMP RIH with EZSV on E-line, correlate GRlCCL with previous run, locate collar and set EZSV @ 8,946', POH with E-line, Rig down Schlumberger. 02:00 - 10:00 8.00 PXA P DECOMP MIU Halliburton cement stinger and RIH picking up 4" DP to Printed: 10/11/2004 9:30:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 9/25/2004 02:00 - 10:00 8.00 PXA P DECOMP 8,925' 10:00 - 11 :00 1.00 PXA P DECOMP R/U and test 9 5/8" casing to 3,500 psi for 15 min. Circulate DP volume, 5 bpm @ 640psi. 11 :00 - 12:00 1.00 PXA P DECOMP MIU Circulating head, change out bails. Losses for past 12 hrs = 78 bbls. 12:00 - 12:30 0.50 PXA P DECOMP Sting into EZSV & establish injection rate, 2 bpm @ 240 psi, 3 bpm @ 520 psi. Pumped 10 bbls seawater. 12:30 - 14:30 2.00 PXA P DECOMP PJSM wi Co Rep, Toolpusher, Schlumberger. Pump 5 bbls water and test lines to 3,500 psi. Pumped 82 bbls 15.8 ppg class G cement, average rate 4.5 bpm @ 900 psi, final rate 4 bpm @ 595 psi. Pumped 10 bbls Fresh water and displace with seawater, Intial rate 4 bpm @ 210 psi, Slow rate to 3 bpm 53 bbls into displacement, pressure 100 psi. Slow rate to 2 bpm when cement at perfs, 77 bbls into displacement, pressure 691 psi. Slowed rate to 1 bpm 91 bbls into displacement, pressure 980 psi. Final rate 1 bpm, 1,400 psi. Squeezed 35 bbls cement through perfs. Top of cement @ 9,275' 14:30 - 15:30 1.00 PXA P DECOMP Unsting from EZSV, circulate bottoms up 11 bpm @ 1,420 psi. no cement to surface. 15:30 - 16:30 1.00 PXA P DECOMP R/U and test lower pipe rams and casing to 3,500 psi for 30 min. record on chart. 16:30 - 17:30 1.00 PXA P DECOMP Pump dry job and change bails. 17:30 - 20:30 3.00 PXA P DECOMP POH UD cement stinger. 20:30 - 21 :00 0.50 WHSUR P DECOMP Pull wear ring 21 :00 - 22:30 1.50 BOPSU P DECOMP Nipple down riser and BOP. Bleed 133/8' X 9 5/8" annulus to zero. 22:30 - 00:00 1.50 BOPSU P DECOMP Nipple down tubing spool, back out lock down screws, while backing out the last screw, casing pushed pack- off out, cutting a groove in the Pack-off, pipe grew 3 1/2". 9/26/2004 00:00 - 03:30 3.50 BOPSU P DECOMP Position pack-off over mandrel on casing hanger with running tool, Make up top drive, set weight of topdrive on pack-off, lacked 1" of being seated. UD running tool, PIU BOP's and set weight of BOP on pack-off, ran joint of 5" HWDP through stack and applied weight of top drive, pack off seated RILDS. Pull joint out & set BOP back. Make up new tubing spool and test pack-off to 5,000 psi. 03:30 - 05:30 2.00 BOPSU P DECOMP Nipple up BOP and riser, Install secondary valve on IA valve. 05:30 - 06:00 0.50 BOPSU P DECOMP R/U and test Flanges to 250 psi low and 3,500 psi high. 06:00 - 06:30 0.50 BOPSU P DECOMP Install wear ring. 06:30 - 10:30 4.00 STWHIP P WEXIT Held PJSM, PIU whipstock, milling assembly orient MWD & whipstock, PIU 9 61/4" DC's, surface test MWD, PIU 18 joints of 4" HWDP. 10:30 - 12:00 1.50 STWHIP P WEXIT RIH with whipstock milling assembly to 3,814' 12:00 - 15:00 3.00 STWHIP P WEXIT RIH to 8,879' filling pipe @ 3,814' - 6,680' 15:00 - 16:00 1.00 STWHIP P WEXIT Service rig and top-drive. 16:00 - 16:30 0.50 STWHIP P WEXIT Break circulation & orient whipstock 70L of high side & set trip anchor, top of whipstock @ 8,925', bottom of whipstock @ 8,941. 16:30 - 18:00 1.50 STWHIP P WEXIT Displace seawater with 10.1 ppg milling fluid 18:00 - 00:00 6.00 STWHIP P WEXIT Mill window from 8,920' to 8,936' 2-10k wob, 500 gpm @ 2,480 psi, 100 - 120 rpm, 6,500 ftllbs torque, up wt = 180k, dn wt. = 150k, rt wt = 165k. Pumped 30 bbl high vis sweep (duo vis, and super-sweep.) Sweep brought back a significant amount of Printed: 10/11/2004 9:30:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 9/26/2004 18:00 - 00:00 6.00 STWHIP P WEXIT metal. Mill formation from 8,936' to 8,950'. Work milling assembly through window, began packing off when starting mill at the bottom of the slide, working string back to bottom, had 2' of fill. Pump 30 bbl high vis sweep. 9/27/2004 00:00 . 01 :00 1.00 STWHIP P WEXIT Continue working Mills from 8,91S' to 8,9S0' rotating string 120 rpm, pumping SOO gpm, 2,410 psi seeing slight drag when working string above window 5K. Did not see an increase in cuttings when sweep came back, circulated an additional bottoms up. 200 Ibs. metal recovered. 01 :00 . 02:00 1.00 STWHIP P WEXIT POH to 8,890', RlU test equipment & perform FIT. Mud weight 10.1 ppg in and out. 8,920 md, 7,409' tvd. pressure achieved 643 psi, EMW 11.77 ppg. 02:00 - 06:00 4.00 STWHIP P WEXIT RID test equipment, pump dry job, monitor well, POH, @ 8,784' to 8,S83' started seeing excess drag 2Sk worked string down, no further hole problems. Continue POH. 06:00 - 08:30 2.S0 STWHIP P WEXIT Stand back DC's, Lay down milling assembly, (mills were packed off) clear floor of all milling equipment, clean floor. 08:30 - 09:00 O.SO STWHIP P WEXIT Flush BOP stack, blow down choke and kill lines. 09:00 - 11 :30 2.50 STWHIP P WEXIT P/U BHA, orient and suface test MWD. 11 :30 - 13:00 1.S0 STWHIP P WEXIT P/U 57 jts 4" DP from pipe shed. 13:00 - 16:00 3.00 STWHIP P WEXIT RIH, to 8,890' fill DP every 30 stds. 16:00 - 17:00 1.00 STWHIP P WEXIT MIU top drive break circulation, orient motor 70L, work assembly through window, (no problem) wash from 8,940' to 8,950' Up wt = 18Sk dn wt = 145k 17:00 - 00:00 7.00 DRILL P INT1 Directional drill 8.S" hole from 8,950' to 9,061" by sliding. drill string hanging up & stalling motor. DD spending alot of time re-orienting. Pulled off bottom to orient, with stabalizer at the bottom of the window, saw 2Sk overpull attempt to work back down, set down 40K, work free by rotating string 5 rpm and setting 30k down, saw no packing off. Continued drilling ahead by sliding, 500 gpm, 2,950 psi on bottom, 2,800 psi off bottom, up wt = 185k, dn wt = 14Sk, rt wt = 150k. Drilled to 9,061', pulled stabalizer through window with no problem. AST = 1.92 ART = .52 9/28/2004 00:00 . 00:00 24.00 DRILL P INT1 Direcional drill 8.5" Intermediate hole from 9061' to 10,230'. Sliding, 10-15K WOB, SOO gpm @ 3,700 psi on bottom, 3,480 psi off bottom. Up wt = 195k,dn wt = 155k, rt wt = 155k. Once the MWD tools past through the window, drill string stopped hanging up reducing the amount of time spent orienting. Torque off bottom = 5K, on bottom = 7.5K. AST = 9.27 Hrs. ART = 6.43 Hrs. Calculated ECD = 10.6 ppg. Actual ECD averaging 10.85 ppg. Pumping Hi-Vis weighted sweep every 300'. 9/29/2004 00:00 - 01 :30 1.S0 DRILL P INT1 Direcional drill 8.5" Intermediate hole from 10,230' to 10,325'. All Rotating w/10-1SK WOB, SOO gpm @ 3,700 psi on bottom, 3,480 psi off bottom. Up wt = 200k,dn wt = 160k, rt wt = 155k. Torque off bottom = 5K, on bottom = 7.5K. ART = 1.16 Hrs. Calculated ECD = 10.6 ppg. Actual ECD averaging 10.80 ppg. Pumping Hi-Vis weighted sweep every 300'. 01 :30 - 02:30 1.00 DRILL P INT1 Circulate up samples per Geologist request. Confirmed sandstone cap atop Sag. Printed: 10/11/2004 9:30:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 9/29/2004 02:30 - 04:00 1.50 DRILL P INT1 Circulate around a Hi-Vis weighted sweep @ 520 GPM & 100 RPM.. Double the cuttings with sweep at surface then cleaned up immediately. ECD below 0.2 ppg over calculated. 04:00 - 05:30 1.50 DRILL P INT1 Monitor well - static. Wipe to 9 5/8" casing window. Hole in excellent shape. No excess drag. 05:30 - 06:30 1.00 DRILL P INT1 Service Top Drive. Slip & Cut Drilling line. 06:30 - 07:30 1.00 DRILL P INT1 RIH to 10,260'. No Problems. Precautionary wash last stand to bottom - no fill. 07:30 - 09:30 2.00 DRILL P INT1 Circulate weighted Hi- Vis sweep @ 520 GPM, 3375 psi & 110 RPM. Well bore clean. Pump dry job. 09:30 - 14:00 4.50 DRILL P INT1 POH to BHA. 14:00 - 16:30 2.50 DRILL P INT1 Down load MWD & Lay down BHA. 16:30 - 17:30 1.00 CASE P LNR1 Clear & clean floor, RlU to run 7" Int. Liner. PJSM with all hands. 17:30 - 20:30 3.00 CASE P LNR1 Run 39 Jts, 7', 26#, L-80, BTC-M Liner. P/U & MIU ZXP Packer, HMC Hanger & C2 running tool. Make up one stand of 4" DP. 20:30 - 21 :00 0.50 CASE P LNR1 Circulate one liner volume @ 3 BPM & 140 psi. 21 :00 - 00:00 3.00 CASE P LNR1 Run 7" Liner in hole on 4" DP, filling pipe every 10 stands. 9/30/2004 00:00 - 01 :30 1.50 CASE P LNR1 RIH with 7" Drilling Liner on 4" DP to 8,820'. 01 :30 - 02:30 1.00 CASE P LNR1 M/U Cement head on DP single, Srew into drill pipe with top drive, circulate bottoms up. Hold PJSM with Rig Crew, Schlumberger and Baker whle circulating. 02:30 - 04:00 1.50 CASE P LNR1 Run in open hole with Liner. Make up single & Cement Head. Tag bottom @ 10,325'. Pick up 2 ft. to 10,323'. Rig up circulating manifold & hoses to cement head. 04:00 - 05:00 1.00 CEMT P LNR1 Break circulation. Circulate 1.5 X Liner Annulus - Staging pumps up to 7 BPM 11020 psi. 05:00 - 06:30 1.50 CEMT P LNR1 Cement as per program: Test lines to 4000 psi. Mix & Pump 35 bbls, 11.1 ppg, MudPush II followed by 63 BBls, 15.8 ppg, Class "G" slurry w/1.16 cU.ft.lsk yield. Drop Dart and chase wI 5 bbls water from dowel! to clear lines, then switch to rig pumps and displace @ 7 BPM with 140.5 Bbls 10.2 ppg mud. Slow down to 2 BPM to latch plug and again prior to bump. Bump plug with 3000 psi. 06:30 - 08:30 2.00 CASE P LNR1 Pressure up to 3500 psi to set HMC Hanger, Slack off 50 K to check slips. Pick up and rotate 15 turns to the right to release running tool. Pressure up to 1000 psi and pick up 10', when pressure bleeds down, circulate 30 bbl at 6 BPM to move cement up hole. Slow pumps down to 3 BPM, set 55 K down to set ZXP packer. Check set while rotating. Pick up and circulate cement out @ 350 GPM - 5 BBls cement to surface. 08:30 - 13:00 4.50 CASE P LNR1 RID Cement Head & single. POH wI 4" DP. Check and lay down running tool. 13:00 - 14:00 1.00 CASE P TIEB1 R/U to run 7" Tie-Back Liner. Hold PJSM with all involved. 14:00 - 20:30 6.50 CASE P TIEB1 Run 153 Jts of 7", 26#, L-80, BTC-M Tie-Back Liner. Fill every 5 Jts. Make up FlexLock Hanger, ZXP liner top packer with hydraulic setting tool and running tool 20:30 - 22:00 1.50 CASE P TIEB1 RID Casing equipment. RIH w/3 stands 6 1/2". DC"s. Install safety valve in each stand to prevent mud from running over. 22:00 - 23:30 1.50 CASE P TIEB1 M/U Top Drive on stand of HWDP & circulate @ 7 BPM 11000 psi. 23:30 - 00:00 0.50 CASE P TIEB1 RIH wI 4" HWDP screwing top drive into each stand. Printed: 10/11/2004 9:30:48 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 9/19/2004 10/5/2004 Spud Date: 11/11/1982 End: 10/5/2004 10/1/2004 00:00 - 03:00 3.00 CASE P TIEB1 RIH with HWDP and 4" drill pipe to 8750'. Screwed into each stand with top drive. Circulated last 8 stands down. Mud very viscous and running over the top of the pipe. 03:00 - 03:15 0.25 CASE P TIEB1 MIU Cement head & single. 03:15 - 04:30 1.25 CASE P TIEB1 Circulate & condition mud for cement job. 04:30 - 07:00 2.50 CEMT P TlEB1 Stab seal assy into PBR, space out. Pressure up to 500 psi to confirm sting in. Bleed off pressure. Pick string up to expose ports with bottom seals stung into PBR. Cement as follows: Schlumberger pump 5 Bbls water. test lines to 4000 psi. Pump 20 Bbls, 11.1 ppg. MudPush II followed by 141 bbls, (440 sx) 13.5 ppg., class "G" lead Slurry w/1.8 cu. ft. I sk yield followed by 28 bbls, (136 sX), 15.8 ppg., class "G" Tail slurry wI 1.16 cu ft Isk yield. Release dart and pump 5 bbl water to clear lines. Switch to rig pumps and displace with 258.5 bbls 10.2 ppg mud at 7 BPM max and 3 BPM min. Did not bump plug. 07:00 - 08:30 1.50 CASE P TIEB1 Lower seal assy into PBR to no-go. Pick up to string wt of 265K. pressure up to 2600 psi to set Flex Lock II Hanger. Slack off 60K to confirm hanger set. Pressure up to 4000 psi to set ZXP Packer. P/U 30K and rotate 15 turns to the right to release setting tool. Pressure up to 500 psi and P/U to removes seals from hanger, when pressure bleeds off pump 30 bbl mud at 7 BPM to move cement up hole. Slow pumps to 3 BPM. Rotate at 10 RPM & set down 50K to confirm packer set. Continue circlating at 8 BPM 1700 psi. until cement back to surface. Approximately 5 Bbls cement to surface. 08:30 - 10:00 1.50 CASE P TIEB1 RID Circ Lines, UD cement head & single. POH standing back 4" DP & HWDP. 10:00 - 11 :00 1.00 CASE P TIEB1 UD all drill collars and Baker C-2 liner running tool. 11 :00 - 13:00 2.00 CASE P TlEB1 Service and change oil and filter on Top drive. Service Epoch system on driller's console. 13:00 - 15:00 2.00 DRILL P PROD1 PJSM with Sperry MWD on loading nukes. P/U & M/U 6 1/8" BHA #3. 15:00 - 18:45 3.75 DRILL P PROD1 RIH. Tag up @ 8,524'. 18:45 - 19:30 0.75 DRILL P PROD1 Break circulation & circulate @ 240 GPM 11510 psi. Test 7" Tie Back & Lap to 3500 psi for 15 minutes. Good test. 19:30 - 22:30 3.00 DRILL P PROD1 Drill cement from 8,524' to landing collar @ 8,721', Drill landing collar & Float collar @ 8,762' Drilling @ 240 GPM I 1300 psi. wI 120 RPM. 22:30 - 00:00 1.50 DRILL P PROD1 RIH. Tag Cement @ 10,180'. 10/2/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Drill extemely hard cement from 10,180' to 10,200'. 01 :00 - 02:00 1.00 CASE P TIEB1 RlU & test 7" Liner to 3500 psi. Hold & chart for 30 minutes. 02:00 - 02:30 0.50 CASE P TIEB1 RID all test equipment. 02:30 - 07:00 4.50 DRILL P PROD1 Drill HARD Cement, landing collar to 10,320'. 07:00 - 09:30 2.50 DRILL P PROD1 Pump 50 Bbls. water, 50 Bbl Hi-Vis sweep treated with EP MudLube then displace with 8.5 ppg. FloPro mud. Clean under shakers & possum belly. 09:30 - 10:00 0.50 DRILL P PROD1 Drill out shoe. Clean out to 10,325' and drill to 10,3.45'. 10:00 - 10:30 0.50 DRILL P PROD1 Circulate bottoms up, mud balanced @ 8.4 ppg. 10:30 - 11 :30 1.00 DRILL P PROD1 Rig up and perform FIT. 8.4 ppg mud, TVD = 8,709', surface pressure of 725 psi. EMW 10.0 ppg. Rig down lines and blow down. 11 :30 - 17:45 6.25 DRILL P PROD1 Drill 6118" hole from 10,345' to 10,635'. 290 GPM @ 1600 psi. WOB = 15 to 20K, Rotating @ 125 RPM with 6K torque on Printed: 10/11/2004 9:30:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 9/1 9/2004 1 0/5/2004 Spud Date: 11/11/1982 End: 10/5/2004 1 0/2/2004 11 :30 - 17:45 6.25 DRILL P PROD1 bottom and 3K off. P/U Wt. = 190K, Dn Wt. = 165K, ROT Wt. = 177K. ADT = 5.6 Hrs. 17:45 - 18:45 1.00 DRILL P PROD1 Circulate 1.5 X bottoms up @ 290 GPM & 1600 psi. wI 125 RPM. 18:45 - 19:15 0.50 DRILL P PROD1 Wiper trip to 10,300'. No drag - no swab. RIH - no problems. 19:15 - 20:45 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep no discernable increase in cuttings. 20:45 - 21:15 0.50 DRILL P PROD1 POH to 10,300. Hole Slick. Drop Circ sub dart & open circ sub. Pump small calcium carbonate dry job. 21:15 - 00:00 2.75 DRILL P PROD1 POH wi 4" DP to 2,648. P/U single to position circ sub just below TOL @ 2,484'. 10/3/2004 00:00 - 00:45 0.75 DRILL P PROD1 Circulate 7" Liner top clean wI 550 GPM & 620 psi. Good amount of fine solids over shaker. 00:45 - 01 :45 1.00 DRILL P PROD1 Blow down TD, UD single & POH to HWDP 01 :45 - 03:00 1.25 DRILL P PROD1 LID HWDP, Jars & Flex Collars. 03:00 - 04:00 1.00 DRILL P PROD1 PJSM. Remove Nuclear source, LID Flex collar, NB Stab & Bit. 04:00 - 05:30 1.50 DRILL P PROD1 Down load LWD tools, break & LID same. 05:30 - 09:30 4.00 EVAL P PROD1 PJSM. Rig up Schlumberger E-Line. Run USIT in 7" Drilling Liner from 10,323' up to 8,777'. Good Cement. RID SWS. 09:30 - 10:00 0.50 CASE P PROD1 RlU to run 4.5" Liner. 10:00 - 11 :00 1.00 CASE P PROD1 Run 10 Jts, 4.5", 12.6#, L-80, IBT-M Liner as per program. Centralize each Jt. 11 :00 - 11 :30 0.50 CASE P PROD1 MIU Liner I Packer Assy & one stand 4" DP. Circulate 1.5 X Liner volume. 11 :30 - 16:45 5.25 CASE P PROD1 Run Liner in well on 4" DP, filling every 10 stands, to 10,204'. Displacement correct. 16:45 - 18:00 1.25 CASE P PROD1 Circulate and condition mud. Stage up to 6 BPM @ 835 psi. 18:00 - 18:15 0.25 CASE P PROD1 PIU 2 singles, M/U Cement Head & LID Cmt Hd + 1 sngl on skate. 18:15 - 18:45 0.50 CASE P PROD1 Run in open hole with liner to 10,620' 18:45 - 20:00 1.25 CEMT P PROD1 PIU Cement head & R/U Circulating manifold & hoses. Break circulation & stage pump up to 6 BPM & 980 psi. Hold PJSM with D/S cementers, Baker & rig crew. 20:00 - 20:45 0.75 CEMT P PROD1 DIS pump 5 Bbls water& test lines to 4000 psi. Pump 10 Bbls, 8.32 ppg. CW-100, followed by 10 Bbls, 9.4 ppg. MudPush, followed by 16 Bbls (77 sx), 15.8 ppg. Class "G" Tail slurry. wI yield of 1.17 cU.ft. I sk. Wash out cement lines to trough. Turn back over to rig and pump out dart and diasplace with 107.6 Bbls 8.4 ppg FloPro mud @ 6 BPM. Recirocated throughout job. Slowed down to latch plug and bumped plug with 2200 psi. CIP @ 21 :45 Hrs. 20:45 - 21 :00 0.25 CASE P PROD1 Continue pressuring up to 3500 psi to set HMC Hanger. Slack off 40 K to insure set. Rotate 20 turns right to release tool. Pressure up to 1000 psi and P/U 3 ft. to remove seals. When pressure droped: circulate 15 Bbls @ 6 BPM to move cement up hole. Slow rate to 2 BPM and set 55 K down to set ZXP Packer - definite indication of set. Rotate again to insure good set. 21 :00 - 22:30 1.50 CASE P PROD1 Pump 50 Bbls 8.4 ppg. Mud followed by 100 bbls fresh water, then displace well bore with clean seawater - all pumped @ 6 BPM. Approximately 4 bbls cement to surface. 22:30 - 23:00 0.50 CASE P PROD1 Break out & UD Cement head & single. Pump dry job. 23:00 - 00:00 1.00 CASE P PROD1 POH laying down 4" DP. Printed: 10/11/2004 9:30:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 9/1 9/2004 1 0/5/2004 Spud Date: 11/11/1982 End: 10/5/2004 POH Laying down all 4" Drill Pipe. Pull Wear Bushing & make dummy run with Hanger & landing joint. 08:30 - 09:30 1.00 CASE PROD1 Pressure test casing & Liners to 4000 psi. - Chart for 30 minutes. 09:30 - 10:45 1.25 RUNCO RUNCMP R/U to run 4.5" Completion. 10:45 - 12:00 1 .25 RUNCO RUNCMP Run 4.5", 12.6#, L-80, TC-II Completion as per program. 12:00 - 12:30 0.50 RUNCO RREP RUNCMP Repair air line to drum clutch. 12:30 - 22:30 10.00 RUNCO RUNCMP Continue to run 4.5", 12.6#, L-80, TC-II Completion as per program. Tag WLEG in bottom of tie-back sleeve @ 10,192'. Lay down one Jt. No pups needed for space out. Total 241 Jts ran. 22:30 - 23:00 TUBHGR MIU Hanger with TWC installed & landing Jt. Land Hanger & R.I.L.D.S. 23:00 - 23:30 0.50 WHSUR P OTHCMP UD landing jt. Test TWC from below to 1000 psi. 23:30 - 00:00 0.50 BOPSU P OTHCMP NID BOPE. 10/5/2004 00:00 - 01 :30 1.50 BOPSU P OTHCMP Complete N/D BOPE 01 :30 - 03:00 1.50 WHSUR P OTHCMP NIU Adapter Flange & Tree. Test to 5000 psi. 03:00 - 04: 15 1.25 WHSUR P OTHCMP Pull TWC. RIU Circulating I U-tube manifold & test to 3500 psi. 04:15 - 05:15 1.00 RUNCO RUNCMP Reverse circulate 171 bbls. of corrosion inhibited seawater @ 3 BPM - 244 psi. 05:15 - 08:00 2.75 RUNCMP PJSM with Little Red. RIU Little Red and test lines to 4500 psi. Reverse circulate 151 Bbls Diesel down Annulus. Pump @ 2.5 BPM - 450 psi. Shut in and allow diesel to U-tube to freeze protect Tbg & Ann. to 2,200' 08:00 - 12:00 RUNCMP Drop Ball 1 Rod Assy. With Little Red: Pressure down tubing to 4000 psi to set S-3 Packer. Hold & chart for 30 minute test. Bleed tubing to 1000 psi. Pressure down Annulus to 4000 psi to test packer, chart & hold for 30 minute test. Bleed pressure. RID & blow down circulating lines. 12:00 - 13:00 1.00 WHSUR P WHDTRE Set BPV. RID Little Red. 13:00 - 14:00 1.00 WHSUR P WHDTRE RID secondary annulus valve, Secure Well. RIG RELEASED @ 14:00 Hrs. 10/5/2004 Printed: 10/11/2004 9:30:48 AM . . 12-20A Prudhoe Bay Unit 50-029-20863-01-00 204-166 Accept Spud: Release: Ri: 09/22/04 09/27/04 10105/04 Nabors 7ES POST RIG WORK 1 0/1 0/04 PULL BALL & ROD FROM 10160' SLM PULL RHC-M PLUG BODY FROM XN NIPPLE @ 10165' SLM DRIFT WI 27/8 DUMMY GUN - SB I SD @ 10570' SLM I GRAVEL - SAMPLE OF SCALE IN SB. RDMO. LEFT WELL SHUT IN. 11/05/04 BASE TEMPERATURE LOG FROM 8700' - 10584' TD, JEWELRY LOG 10584' - 10000', PERFORATED 10488'- 10528' WITH 2.88" 2906 PJ 6 SPF. WELL SHUT IN. 11/06/04 PERFORATED 10463' - 10488' AND 10427' - 10444' WITH 2.88" PJ 6 SPF, PENE 27.7", EH 0.36", GMS 15. WELL SHUT IN. JOB COMPLETE. . . 15-0ct-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 12-20A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,823.49' MD 8,920.00' MD 10,635.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ / A fill / Date q AJCIÍ~ Signed ~J- U1dvvJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 2~ v(_1 fa (¡; DEFINITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 12 12-20A . Job No. AKZZ3286719, Surveyed: 2 October, 2004 Survey Report 7 October, 2004 Your Ref: API 500292086301 Surface Coordinates: 5930998.26 N, 696661.20 E (70012' 56. 5484 H N, 148024'49.0415" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 930998.26 N, 196661.20 E (Grid) Surface Coordinates relative to Structure: 485.89 S, 879.64 W (True) Ke/ly Bushing Elevation: 68.96ft above Mean Sea Level Ke/ly Bushing Elevation: 68. 96ft above Project V Reference Kel1y Bushing Elevation: 68.96ft above Structure SP:l!f""If""IY-'SUf1 ÔÃll....l.....:NG· se~vc::es A Halliburton Company Survey Ref: svy4404 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 12 - 12-2OA Your Ref: API 500292086301 Job No. AKZZ3286719, Surveyed: 2 October, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ø/100ft) 8823.49 31.960 340.000 7258.35 7327.31 3710.86 N 1277.91 W 5934674.57 N 695287.05 E 3903.25 Tie On Point MWD+IIFR+MS 8920.00 31.560 337.500 7340.41 7409.37 3758.20 N 1296.31 W 5934721.41 N 695267.42 E 1.425 3953.93 Window Point 9054.71 31.110 330.500 7455.51 7524.47 3821.08 N 1326.95 W 5934783.47 N 695235.16 E 2.722 4023.86 9124.32 28.090 326.500 7516.04 7585.00 3850.40 N 1344.86 W 5934812.32 N 695216.49 E 5.182 4058.01 . 9181.02 25.860 322.120 7566.57 7635.53 3871.30 N 1359.82 W 5934832.82 N 695200.99 E 5.265 4083.27 9232.63 24.860 314.230 7613.22 7682.18 3887.76 N 1374.51 W 5934848.89 N 695185.88 E 6.823 4104.40 9278.23 23.590 307.750 7654.81 7723.77 3900.03 N 1388.59 W 5934860.79 N 695171.48 E 6.458 4121.47 9311.67 22.760 303.820 7685.55 7754.51 3907.73 N 1399.26 W 5934868.21 N 695160.61 E 5.248 4132.96 9373.93 21.630 299.830 7743.20 7812.16 3920.14 N 1419.22 W 5934880.10 N 695140.34 E 3.025 4152.64 9469.10 21.010 292.390 7831.87 7900.83 3935.37 N 1450.22 W 5934894.51 N 695108.95 E 2.914 4179.54 9565.71 20.960 290.510 7922.08 7991.04 3948.02 N 1482.42 W 5934906.32 N 695076.44 E 0.699 4204.62 9661.53 21.550 287.200 8011.38 8080.34 3959.23 N 1515.28 W 5934916.67 N 695043.29 E 1.395 4228.66 9755.86 20.530 283.470 8099.43 8168.39 3968.20 N 1547.92 W 5934924.79 N 695010.43 E 1.784 4250.59 9850.84 19.730 275.020 8188.62 8257.58 3973.49 N 1580.09 W 5934929.24 N 694978.13 E 3.173 4268.98 9946.46 18.590 277.220 8278.95 8347.91 3976.81 N 1611.29 W 5934931.75 N 694946.85 E 1.411 4285.18 10042.72 18.030 279.030 8370.33 8439.29 3981.08 N 1641.23 W 5934935.23 N 694916.82 E 0.829 4301.70 10137.75 17.020 277.880 8460.95 8529.91 3985.30 N 1669.53 W 5934938.71 N 694888.42 E 1.124 4317.48 10232.98 16.860 276.600 8552.05 8621.01 3988.79 N 1697.05 W 5934941 .49 N 694860.81 E 0.426 4332.28 10253.86 16.530 277.390 8572.05 8641.01 3989.52 N 1703.01 W 5934942.07 N 694854.84 E 1.918 4335.46 10356.88 17.220 279.870 8670.63 8739.59 3994.02 N 1732.56 W 5934945.79 N 694825.17 E 0.968 4352.03 10390.71 17.330 279.660 8702.94 8771.90 3995.73 N 1742.47 W 5934947.24 N 694815.23 E 0.374 4357.76 . 10422.56 17.050 279.450 8733.36 8802.32 3997.29 N 1751.75 W 5934948.56 N 694805.91 E 0.900 4363.10 10453.90 17.250 280.240 8763.31 8832.27 3998.87 N 1760.85 W 5934949.90 N 694796.77 E 0.980 4368.38 10486.19 17.390 280.390 8794.14 8863.10 4000.59 N 1770.31 W 5934951.38 N 694787.27 E 0.455 4373.93 10517.85 17.800 280.560 8824.32 8893.28 4002.33 N 1779.72 W 5934952.87 N 694777.82 E 1.305 4379.49 10550.05 18.150 280.830 8854.94 8923.90 4004.18 N 1789.49 W 5934954.46 N 694768.01 E 1.117 4385.29 10596.69 18.640 280.210 8899.20 8968.16 4006.86 N 1803.96 W 5934956.77 N 694753.47 E 1.131 4393.84 10635.00 18.640 280.210 8935.50 9004.46 4009.03 N 1816.01 W 5934958.62 N 694741.37 E 0.000 4400.90 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 335.000° (True). 7 October, 2004 - 7:27 Page 2 of 3 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU _EOA DS 12 - 12-20A Your Ref: API 500292086301 Job No. AKZZ3286719, Surveyed: 2 October, 2004 BPXA North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 10635.00ft., The Bottom Hole Displacement is 4401.16ft., in the Direction of 335.630° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastíngs (ft) (ft) (ft) Comment . 8823.49 8920.00 10635.00 7327.31 7409.37 9004.46 3710.86 N 3758.20 N 4009.03 N 1277.91 W 1296.31 W 1816.01 W Tie On Point Window Point Projected Survey Survey tool proqram for 12-20A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8823.49 0.00 8823.49 7327.31 10635.00 7327.31 AK-1 BP _HG - GYD-CT-CMS (12-20) 9004.46 MWD+IIFR+MS (12-20A) . 7 October, 2004 - 7:27 Page 3 of 3 Dril/Quest 3.03.06.006 . . 15-0ct -04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 12-20A MWD Deaf Deaf Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,823.49' MD 8,920.00 I MD 10,635.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 9 jJ ð if ~ ~_ Signed LJ ø/L; Please call me at 273-3545 if you have any questions Of concerns. Regards, William T. Allen Survey Manager Attachment(s) Að~~/G q Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 12 12-20A (mwd) . Job No. AKMW3286719, Surveyed: 2 October, 2004 Survey Report 6 October, 2004 Your Ref: API 500292086301 Surface Coordinates: 5930998.26 N, 696661.20 E (70012' 56.5484" N, 148024' 49.0415" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 930998.26 N, 196661.20 E (Grid) Surface Coordinates relative to Structure: 485.89 S, 879.64 W (True) Kelly Bushing Elevation: 68.96ft above Mean Sea Level Kelly Bushing Elevation: 68.96ft above Project V Reference Kelly Bushing Elevation: 68.96ft above Structure SI=I:E!ï'ï':\I-SU'í'! DFttLL.tN G50 EFt'\lt c::e $ A Halliburton Company Survey Ref: svy4405 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 12 - 12-2OA (mwd) Your Ref: API 500292086301 Job No. AKMW3286719, Surveyed: 2 October, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8823.49 31.960 340.000 7258.35 7327.31 3710.86 N 1277.91 W 5934674.57 N 695287.05 E 3903.25 Tie On Point MWD Magnetic 8920.00 31.560 337.500 7340.41 7409.37 3758.20 N 1296.31 W 5934721.41 N 695267.42 E 1 .425 3953.93 Window Point 9054.71 31.110 330.500 7455.51 7524.47 3821.08 N 1326.95 W 5934783.47 N 695235.16 E 2.722 4023.86 9124.32 28.090 326.500 7516.04 7585.00 3850.40 N 1344.86 W 5934812.32 N 695216.49 E 5.182 4058.01 . 9181.02 25.860 323.120 7566.57 7635.53 3871.43 N 1359.65 W 5934832.96 N 695201.16 E 4.771 4083.32 9232.63 24.860 314.690 7613.22 7682.18 3888.07 N 1374.12 W 5934849.21 N 695186.26 E 7.253 4104.51 9278.23 23.590 308.200 7654.81 7723.77 3900.45 N 1388.11 W 5934861.23 N 695171.95 E 6.466 4121.65 9311.67 22.760 304.200 7685.55 7754.51 3908.23 N 1398.72 W 5934868.72 N 695161.14 E 5.320 4133.18 9373.93 21.630 300.230 7743.20 7812.16 3920.78 N 1418.59 W 5934880.75 N 695140.95 E 3.015 4152.95 9469.10 21.010 292.600 7831.88 7900.84 3936.17 N 1449.51 W 5934895.33 N 695109.64 E 2.985 4179.97 9565.71 20.960 290.960 7922.08 7991.04 3949.00 N 1481.63 W 5934907.33 N 695077.20 E 0.610 4205.18 9661.53 21.550 287.800 8011.38 8080.34 3960.51 N 1514.39 W 5934917.98 N 695044.15 E 1.345 4229.45 9755.86 20.530 283.910 8099.43 8168.39 3969.79 N 1546.95 W 5934926.40 N 695011.36 E 1.833 4251.62 9850.84 19.730 275.540 8188.62 8257.58 3975.34 N 1579.08 W 5934931.11 N 694979.10 E 3.145 4270.23 9946.46 18.590 277.720 8278.95 8347.91 3978.95 N 1610.25 W 5934933.91 N 694947.85 E 1 .407 4286.67 1 0042.72 18.030 279.450 8370.33 8439.29 3983.45 N 1640.15 W 5934937.63 N 694917.84 E 0.811 4303.39 10137.75 17.020 278.260 8460.95 8529.91 3987.87 N 1668.42 W 5934941.31 N 694889.46 E 1.128 4319.34 10232.98 16.860 277.500 8552.05 8621.01 3991.67 N 1695.90 W 5934944.40 N 694861.89 E 0.287 4334.40 10253.86 16.530 278.000 8572.05 8641.01 3992.48 N 1701.84 W 5934945.05 N 694855.92 E 1.724 4337.65 10356.88 17.220 280.550 8670.63 8739.59 3997.31 N 1731.35W 5934949.11 N 694826.30 E 0.982 4354.49 10390.71 17.330 280.350 8702.94 8771.90 3999.13 N 1741.23 W 5934950.68 N 694816.38 E 0.370 4360.32 . 10422.56 17.050 280.170 8733.36 8802.32 4000.81 N 1750.49 W 5934952.11 N 694807.08 E 0.895 4365.75 10453.90 17.250 280.930 8763.31 8832.27 4002.50 N 1759.58 W 5934953.57 N 694797.95 E 0.958 4371.13 10486.19 17.390 281.090 8794.14 8863.10 4004.34 N 1769.01 W 5934955.15 N 694788.47 E 0.458 4376.78 10517.85 17.800 281.280 8824.32 8893.28 4006.19 N 1778.40 W 5934956.77 N 694779.04 E 1.308 4382.43 10550.05 18.150 281.540 8854.94 8923.90 4008.16 N 1788.14 W 5934958.48 N 694769.25 E 1.115 4388.33 10596.69 18.640 280.950 8899.20 8968.16 4011.03 N 1802.58 W 5934960.97 N 694754.74 E 1.124 4397.03 10635.00 18.640 280.950 8935.50 9004.46 4013.36 N 1814.60 W 5934962.98 N 694742.67 E 0.000 4404.22 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 335.000° (True). 6 October, 2004 - 17:11 Page 2 of 3 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 12 - 12-2OA (mwd) Your Ref: AP/500292086301 Job No. AKMW3286719, Surveyed: 2 October, 2004 BPXA North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 10635.00ft., The Bottom Hole Displacement is 4404. 52ft. , in the Direction of 335.6700 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 8823.49 8920.00 10635.00 7327.31 7409.37 9004.46 3710.86 N 3758.20 N 4013.36 N 1277.91 W 1296.31 W 1814.60 W Tie On Point Window Point Projected Survey Survey tool program for 12-20A (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8823.49 0.00 8823.49 7327.31 10635.00 7327.31 AK-1 BP _HG - GYD-CT-CMS (12-20) 9004.46 MWD Magnetic (12-20A (mwd» . 6 October, 2004 - 17:11 Page 3 of 3 DrillQuest 3.03.06.006 133/8",72#, L-SO, ID::: 12.347" 7", 26#, L-80, BTC-M scab liner 12 o 518" X 1" Baker Flex-Lock liner top packer with 9 5/S" X 7" Baker HMC liner hanger, ZXP liner top packer with Tie Back XP MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Wednesday, November 24, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC 12-2OA PRUDHOE BAY UNIT 12-2OA FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv;í"&e "IU/04 Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 12-20A API Well Number: 50-029-20863-01-00 Inspector Name: John Crisp Insp Num: mitJCr041I 23130904 Permit Number: 204-166-0 Inspection Date: 11121/2004 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 12-2OA Type Inj. s TVD 8525 IA 0 2300 2230 2210 P.T. 2041660 TypeTest SPT Test psi 2131.25 OA 25 25 30 30 Interval INITAL P/F P Tubing 950 950 950 950 Notes: Wednesday, November 24, 2004 Page 1 of 1 " . ~ FRANK H. MURKOWSKI, GOVERNOR A I4.\SIiA. OIL AND GAS CONSERVATION COltDlISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 12-20A BP Exploration (Alaska) Inc. Permit No: 204-166 Surface Location: 691' NSL, 942' WEL, SEC. 18, TlON, RI5E, UM Bottomhole Location: 4712' NSL, 2779' WEL, SEC. 18, TI0N, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's petroleum field inspector at (907) 65 36 7 (pager). Si ely BY ORDER OF THE COMMISSION DATED this~ day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o enc1. Department of Environmental Conservation w/o encl. ~6,\- <t/z../Z-Ci04 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED PERMIT TO DRILL 20 MC 25.005 AUG 3 1 2004 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 691' NSL, 942' WEL, SEC. 18, T10N, R15E, UM Top of Productive Horizon: 4690' NSL, 2701' WEL, SEC. 18, nON, R15E, UM Total Depth: 4712' NSL, 2779' WEL, SEC. 18, nON, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 696661 y- 5930998 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8900 feet Maximum Hole Angle: 47 deQrees '1b. Current Well Class 0 Exploratory~ 0 Deve. lopment Oil QMultipl,e Zone. . or o Stratigraphic Test II Service }/ 0 DAtaSkl"fi Naa;øne~ISSIOI 5. Bond: aiD Blanket 0 Single Well 11. Well Name~t1Hrg"er: / Bond No. 2S100302630-277 PBU 12·20A 6. Proposed Depth: 12. Field / Pool(s): MD 10631 TVD 9008 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028330 9. Acres in Property: 2560 13. Approximate Spud Date: / September 20, 2004 14. Distance to Nearest Property: 17,500' 8. Land Use Permit; 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 69.81 feet 12-20 is 525' away at 10420' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.0~ Downhole: 3200 Surface: 2326 11S;cas1ng program: ... 1:>:"'",_ .1"\:.......... Tc,p .,. lC;f.. JI¡:¡a\,;"::H .. Size ..t:){., urn Hole CasinQ WeiQht Grade CouDlina Lenath MD TVD MD TVD (includin) staQe data) 8-1/2" 7" 26# L-BO BTC-M 1563' 8750' 7280' 10313' 8710' 309 sx Class 'G' 8.681" 7" (Tieback) 26# L-80 BTC-M 6250' 2500' 2500' 8750' 7280' 376 sx Class 'G', 131 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 468' 10163' 8568' 10631' 9001' 73 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for. Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): 10950 9243 ~."."inl'l . Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 10600 I 10600 8918 I None ~i7A . MU '. TVD Conductor 79' 20" 15 sx Permafrost 'C' 79' 79' ~ r 2382' 13-3/8" 2100 sx Fondu, 400 sx Permafrost 'C' 2382' 2382' 10382' 9-5/8" 500 sx Class 'G', 300 sx Permafrost 'C' 10382' 8711' Production LinAr 879' 7" 300 sx Class 'G' 10061' - 10940' 8423' - 9233' Perforation Depth MD (ft): 10484' - 10598' 20. Attachments aiD Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8811' - 8916' aiD Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report III Drilling Fluid Program III 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name BiIIlsaacson Title Senior Drilling Engineer 'i - Prepared By Name/Number: SiQnature J,-.... - J,l, ^. L- Phone 5644089 Date fJ/ ~ð/O') Terrie Hubble, 564-4628 ..;:.: "i '..i'" ..................;:......; if ...;.;..:.:.;>././.......,..:.: ......:..:.::.:. ...'.....;.).......)...:.:....;. Permit To Drill API Number: Permit Approval I See cover letter for Number: :2 0 ~ - / C is 50- 029-20863-01-00 Date: I other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes KI No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~ Yes 0 No Other.:T-est ßOPE +o~o pS;¿j eeí C,O. 5.lt.,.OOO ck1.YfVLJ o-f>e:-vc\.-fi'V"vtÇ. ({.fPfCVt'd /,(t-{Jey 15t:~¿oI~.~I. ~~)~t::doJR~I~Gtrtk~~¥~t.fprcfPd ~ -(/ß J/a II\JI-\ L APPROVED BY ð.'~ I·.r/. AODroved Bv: ., .) I /' V \ ./ i THE COMMISSION Date 71.:i / ()..,... Form 10-401 R~ ~ - ßubrl1it In buplicate we~1 12-20A I AFE Number: I P8D 4P2284 I . Surface Location Target Location . I Well Name: I 12-20A / I L -I L I" .02-15 !')-01- ~ A9rL ...) ¡-ð¡-vf,) Planned Well SUmmary ¡Cn· 2S t., \ -1~ - oik·¡ Well Type Conventional Sidetrack WAG Injector Target Objective Zone 48 I API Number: I 50-029-20863-01 Offsets 691' FSL /942' FEL TRS 10N,15E,18 /' Offsets 589' FNL / 2,355' FWL TRS 10N,15E,18 Bottom Location Offsets 567' FNL / 2,283' FWL TRS 10 N, 15 E, 18 / I Planned KOP: I 8,900' md I Planned TD: 110,631' md I Rig: I Nabors 7ES I Maximum Hole Inclination: Proximity Issues: / I RTE: 169.81' I BFE: 141.31' Directional ProQram W 08 Exit oint: 8,900' md /7,406' sstvd -47.0° at 6,400' in the original well bore, -32.0° in the planned 8 1/2" intermediate section at -8,950' md. There are no close approach issues in drilling 12-20A. All surrounding wells ass ma'or risk criteria. Standard MWD with IIFR 1 Cassandra. Well 12-20, with center-to-center distance of -525' at 10,420' md. / 17,500' to the nearest PBU ro ert line. LOQQinQ PrOQram Hole Section: Required Sensors I Service 8 W' intermediate: Real time MWD Dir/GR/Res/PWD throuahout the interval 6 1/8" production: Real time MWD Dir/GR/Res throuQhout the interval. Recorded Densitv/Neutron. Cased Hole: E-line USIT Open Hole: None planned 12-20Ai Permit to Drill / Page 1 . . Mud ProQram Set Whi stock I mill window in 9 5/8" casin PV YP MBT API FL 10 - 15 40+ <3 5 - 7 Drillin 8 W' interval from window to section TD PV YP Tau 0 API FL H 12 - 15 25 - 33 3 - 7 4 - 5 9.0 PV 8 -12 Casinq I Tubinq ProQram Hole Casingrrubing Wt. Grade Connection Length Top Bottom Size Size md I tvd md I tvd 8%" 7" 26.0# L-80 BTC-M 1,563' 8,750'17,280' 10,313/8,710' 8.681" 7" scab 26.0# L-80 BTC-M 6,250 2,500' 12,500' 8,750' 17,280' 61/8" 4 Y2" 12.6# L-80 IBT-M 468' 10,1631 8,568' 10,6311 9,007' Tubinq 4 Y2" 12.6# L-80 TC-II 10,163' Surface 10,163 I 8,370' Slurry Design Basis: Fluids Sequence I Volume: Slurry Design Basis: Fluids Sequence I Volume: 12-20Ai Permit to Drill CementinQ PrOQram 7", 26#, L-80, BTC-M drill in liner Lead slurry: None planned Tail slurry: 85' of 7" shoe track, plus 1,413' of 7" X 8 W' annulus with 40% excess, plus 150' of 95/8" X 7" liner lap, plus 200' of 9 5/8" X 4" drill pipe annulus. Pre-Flush S acer Lead Slurr Tail Slur ; 1.16 disk. ; 2.09 disk. ; 1.16 disk. Page 2 . Slurry Design Basis: Fluids Sequence I Volume: Test 9 5/8" casin Intermediate casin window 9 5/8" casin / 7" liner 7" liner shoe 4 W' roduction liner . 41/2", 12.6#, L-80, IBT-M solid roduction liner Lead slurry: none planned Tail slurry: 42' of 4 W', 12.6# shoe track, plus 318' of 41/2" X 61/8" annulus with 40% excess, plus 150' of 7" X 4 W' liner lap, plus 200' of 7" X 4" drill pipe annulus. Pre-Flush 5 acer Lead Slur Tail Slur ; 1.20 dIsk. Casinql Formation InteQritv Testinq Test Point Test Type 30 min recorded FIT 30 min recorded FIT 30 min recorded Test pressure 3,500 si surface 12.5 EMW 4,000 si surface 10.0 EMW 4,000 si surface Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum antici ated BHP: Maximum surface ressure: Calculated kick tolerance: Planned BOPE test ressure: BOPE configuration for 7" drilling liner" * Disposal Annular In"ection: Cuttings Handling: Fluid Handling: No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at 05-04. An metal cuttin s should be sent to the North 510 e Borou h. All drilling and completion fluids and other Class" wastes are to be hauled to 05-04 for in·ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 12-20Ai Permit to Drill Page 3 . . GeoloQic ProQnosis Formation MD TVDbkb TVDss Comments SV1 Above Kick off point UG4 4,576 Above Kick off point UG4A Above Kick off point UG3 4,766 Above Kick off point UG1 5,459 Above Kick off point WS2 5,977 Above Kick off point WS1 6,246 Above Kick off point CM3 6,512 Above Kick off point CM2 7,020 Above Kick off point CM1 7,917 THRZ 8,170 BHRZ 8,324 LCU TKNG TJG TJF TJE TJD TJC TJB 8,444 TJA TSGR 8,640 TSHU 8,667 TSHB 8,686 TSHC 8,704 46P / TSAD 8,740 -3,200psi (7.0+ppq EMW) 45N 8,775 45P 8,776 44N 8,818 44P 8,818 43N 8,847 43P 8,848 42N 8,884 42P 8,887 41N 8,908 41P 8,911 31N 8,954 31P 8,956 TD Criteria TD Criteria: Well bore needs to be accessible for logging/perforating into the middle of the 43P at 8,870' sstvd. Shoe joint will be minimized to facilitate this. Do not drill any closer to the to of Z3 than 15'. Final TD will be rovided after TSAD is 10 ed. Fault ProQnosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw N/A N/A N/A N/A N/A N/A N/A 12-20Ai Permit to Drill Page 4 . . Qperations Summary Pre-Ria Operations: 1. The latest recorded MITOA to 3,OOOpsi passed on 10/18/2002. 2. Conduct an MITOA to 2,000psi. 3. The latest CMIT T X IA to 3,OOOpsi passed on 5/19/2003. 4. An MITIA attempted to 4,OOOpsi failed on 9/11/2003. Pressure reached -3,600psi, then broke over. An LDL run on 10/21/2003 indicates the tubing is collapsed at 9,424'. 5. R/U and RIH with coil tubing to plug and abandon the well bore above the sand plugllnflatable Bridge plug set at 10,606'md. Confirm tag at top of sand plug at -10,600' md. Plug and abandon, with 15.8ppg class 'G' cement. The estimated cement volume required is 30.0bbls. This is based upon 483' of 7" liner, 73' of 4 W' tubing tail, 44' of 5 W' tubing tail, and -10.0bbls of slurry to squeeze the open perforations. The cement top should be approximately 10,OOO'md. 6. R/U slick-line and. RIH and retrieve the Eclipse 5 W' tubing patch. 7. Drift the 5 W' tubing to the point of collapse at -9,424'md to confirm clear for upcoming chemical cut. 8. Fluid-pack the 5 W' tubing and 95/8" x 5 W' annulus to surface. Test to 3,000 psi. 9. R/U E-line. RIH with the appropriate chemical cutter and cut the 5 W' tubing at -9,200'md. 10. Displace the well to seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 11. Test the 9 5/8" pack-off to 5,000psi for 30 minutes. Function all 9 5/8" casing and tubing Lock Down Screws; repair or replace as needed. 12. Bleed casing and annulus pressures to zero. 13. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. MI I RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down the tree. Nipple up the BOPE and test to 3,500psi. Pull TWC. 4. R/U. Pull the 5W' tubing from the cut at -9,200' MD and above. 5. M/U an 8 1/2" casing mill assembly. RIH, picking up 4" drill pipe, to the 5 W' tubing stump. POOH. 6. R/U E-line. M/U a HES 9 5/8" EZSV. RIH on E-line and set bridge plug at -8,975'md. Set as required to avoid cutting a casing collar. POOH. RID E-line. ·TU _ . I 7. Pressure-testthe95/8"casin to 3500 si for 30 minutes. Record the test. ~ to 40{ ~pYl?"Ci\.-. 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to beginning / milling operations. 10. Mill window in 95/8" casing at ± 8,950'md, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 12. M/U 8 }/2" Dir/GR/Res/PWD éjiSSE!mbly. RIH, kick off and drill the 8 1/2" intermediate section to the top / of the Sag River, per directional proposaI.Circulat€Lw,ªH clean, short trip to window. POOH. . 13. Run and cement a 7", 26.0#, L~--eO, BTC-M intermediate drilliñgiiner. POOH with liner running tool. / 14. R/U, run and cement -6,250' of7.~', 26.0#. L-80, BTC-M scab liner, sufficient to extend from the top of /" the 7" drilling liner, at -8,750'md tò'",2,500'md. POOH and UD the liner running tool. 15. R/U E-line. M/U and RIH with SWS l.JSIT. Log the 7" drilling liner from the float equipment to the top of / the drilling liner at -8,750'md. POOH àhd RID E-line. 16. M/U a 6 1/8" Dir/GR/Res/Den/Neu asseh1bly. RIH to the scab liner float equipment. Test the 9 5/8" X 7" scab liner to 3,500psi for 30 minutes. Rêcordthé test. 17. Drill out the scab liner float equipment and cðntlnue in hole to the drilling liner float equipment. / 18. Pressure-test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 19. Drill out the float equipment and cement down to the 7" shoe. 20. Displace the well to 8.5ppg Flo-Pro drilling fluid. 21. Drill out the shoe plus approximately 20 feet of new formation. Circulate the well clean. 12-20Ai Permit to Drill Page 5 . . 22. Pull up into the 7" shoe and conduct and FIT to 10.0ppg EMW. 23. Directionally drill the 6 1/8" section per directional proposal. Circulate well bore clean, short trip to the 7" shoe. Circulate. POOH. 24. Run and cement a 4 %,', 12.6#, L-80, IBT-M solid production liner, extending the liner lap -150' into the 7" drilling liner. POOH laying down drill pipe. UD the liner-running tool. 25. RIU and run a 41/2", 12.6#, L-80, TC-II completion, stinging into the 41/2" liner tie back sleeve. 26. Circulate the well to clean seawater and corrosion inhibitor. Freeze protect the well to -2,200'. 27. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 28. Install a TWC. 29. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 30. Install BPV. Secure the well. 31. Rig down and move off. / Post-Ria Operations: 1. Mil RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 09101/04 Estimated Spud Date: 09/20/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 12-20Ai Permit to Drill Page 6 . . Phase 1: Move In I Riq Up I Test BOPE Planned Phase Time 24 hours Planned Phase Cost $62,641 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 12-20. However, 12-34 is 60.0' to the South. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ During MI/RU operations, the 12-20 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, seawater, and a BPV. o IA: the P&A cement plug, seawater, and Annulus valves. o OA: Annulus valve. OA tested to 3,OOOpsi on 10/18/2002. ~ Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ During ND/NU BOPE operations, the 12-20 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, seawater, and a BPV. o IA: the P&A cement plug, seawater, and Annulus valves. o OA: Annulus valve. OA tested to 3,000psi on 10/18/2002. ~ DS12 is designated as an H2S site. Standard Operating Procedures for H2S precautions should be fõ1TõWe'd at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 12-19 Injector 01-13 10 12-34 Injector 12-12 / The maximum level recorded of H2S on the pad was 300ppm, in 10/2003. / );> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 12-20Ai Permit to Drill Page 7 . . Phase 2: De-complete Well Planned Phase Time 62 hours Planned Phase Cost $201,483 Reference RP .:. "De-completions" RP Issues and Potential Hazards y Monitor the well to ensure the fluid column remains static, prior to pulling the completion. y Have all wellhead and completion equipment NORM-tested, following retrieval. y Note that this wellhead is a FMC Generation III. The tubing hanger is a 12" X 5 %" OCT with 5 3/4" RH Acme lifting thread. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. y There is a 5W' Camco Bal-O SSSV landing nipple with dual control lines. No records were found regarding the type and quantity of securing bands used in running the control lines. y It will not be necessary to nipple down the stack to change out the 9 5/8" pack-off. Phase 3: Run Whip Stock Planned Phase Time 36 hours Planned Phase Cost $254,966 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards y According to the initial cementing report, it is doubtful there will be cement behind the 9 5/8" casing at the sidetrack point. y Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 5: Drill 8%" Intermediate Hole Interval Planned Phase Time 76 hours Planned Phase Cost $373,935 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 12-20Ai Permit to Drill Page 8 . . Issues and Potential Hazards ~ This well bore will exit the original well into the lower CM2, and drill the remainder of the Colville and the Kingak, to the top of the Sag River formation. Previous DS12 wells drilled the Kingak with 9.8 to 10.4ppg mud weights. For this well, the HRZ and the Kingak will require a mud weight of 10.1 ppg. Maintain mud weight at 10.1 ppg, minimally, from above the Kingak to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a tracture ~~.. Ie t of 11.0ppg at the 9 5/8" casing window, and 10.1 ppg mud in the hole, the kick tolerance r7blS. Phase 6: Run and Cement 7" Intermediate liner Planned Phase Time 57 hours Planned Phase Cost $488,503 Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ After running the intermediate drilling liner, a 7" scab liner will be run and cemented from /" the existing 7" liner top at 8,750'md to -2,500'md. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 45 hours Planned Phase Cost $356,705 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ The trajectory of the 12-20A will not penetrate any faults, but will be bound by a fault to the North, a fault to the South, and possibly a faulted zone to the East. Though the planned well trajectory will not cross any faults, be prepared with adequate Lost Circulation Material. }> The parent well, 12-20, experienced no lost circulation events during drilling operations. 12-20Ai Permit to Drill Page 9 . . Phase 9: Run 41h" Production Liner Planned Phase Time 30 hours Planned Phase Cost $178,571 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a 4 W', 12.6#, L-80 solid liner throughout the production interval. ~ Differential sticking is possible. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner. ~ Ensure the 4 Y2" liner top packer is set prior to POOH. Phase 12: Run 4 1h". L-80. TC-II Completion Planned Phase Time 26 hou rs Planned Phase Cost $379,6562 Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ The completion, as designed, will be to run a 4W', 12.6#, L-80, TC-IJ production tubing string, stinging into the 4 W' liner tieback sleeve. Phase 13: ND/NU/Release RiQ Planned Phase Time 17 hours Planned Phase Cost $55,871 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 12-20. However, 12-34 is 60.0' to the South. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. 12-20Ai Permit to Drill Page 10 133/8",72#, L-80, [) = 12.347" 1 2383' Potential tubing 1 9424' collapse. 51/2",17#, L-80, 10044' PC-tbg, ID = 4.892" TOPOF 7" LNR 10061' 41/2", 12.6#, L-80, 1011T PC-tbg, D = 3.958" 9-5/8" CSG, 47#, L- 10382' 80, [) = 8.681" Sand top H 10600' Baker bridge plug H 10606' /7",29#, L-80, Liner H 10940' D=6.184" ~1 10950' DATE REV BY COMMENTS 11/30/82 ORIGINAL COMPLETION 09/03/01 RN/TP CORRECTkJNS 9/4-9mO BJMlKK SET ECLIPSE PA TCH -20 - TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP- Max Angle = Datum MD = Datum 1VD = FMC GEN 3 FMC AXELSON 77' 2700' 47 @ 6600' 10556' 8800' SS 2213' H5-1/2" CAM BAL-O SSSV NIP, [) = 4.562" PERFORA TkJN SUMMARY REF LOG: BHCS ON 11/24/82 ANGLE AT TOP PERF: 23 @ 10484' Note: Refer to A"oduction DB for hístorical perf data SIZE SPF MERV AL Opn/Sqz DA TE 3-1/8" 4 10519-10599 S 10/17/88 3-118" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17/88 3-1/8" 4 10630-10640 S 10/17/88 3-1/8" 4 10600-10620 S 10/17/88 3-3/8" 6 10773-10777 S 10/17/88 3-3/8" 4 10660-10680 0 11/21/88 3-318" 4 10650-10660 0 11/21/88 3-318" 2 10630-10640 0 11/21/88 3-318" 2 10600-10620 0 11/21/88 3-318" 2 10518-10598 0 11/21/88 3-3/8" 1 10484-10505 0 11/21/88 /8689' - 8712' HS1/2" ECLIPSEpatch,ID=2.441" Minimum ID = 2.441" @ 8689' 5-112" ECLIPSE PATCH, 24' LONG 10017' 1151/2" Baker PBRassy. 10032' 1'19 S/8" X 5 1/2" Baker SAB packer 10044' HS-1/2" X 4-1/2" XO I 10105' Ij4-1/2" CAM NO-GO LANDING NIP, HJ = 3.812" 10116' H4-1f2" BAKER SHEA ROUT SUB I I 10899' HPBTD DA TE REV BY COMMENTS PRUDHOE BAY UNrr WELL: 12-20 PERMrrNo: 1821910 API No: 50-029-20863-00 SEC 18, nON, R1SE, 2426.03' FEL & 5272.94' FNL BP Exploration (Alaska) - BP ~ Iii I Plan: 12-20A wp08 (l2~20!P1an !2-20A) Depth To Survey/Phil'! fool 1i'900.00 10630,68 Phint'lt4: MWD Cheáed; Date: Revíewed: - - WF..LL DETAILS Name 0 .J} ........ -- Name TVD Northing Basting Shape 1NFORMA TION REFERENCE Size BPAll:\OC() - DETÞ No. TVD MD Name 7'\ 4 II2" FORMi\TION TOP DETAILS TVDp.th MDPath Formation SECTION DETAILS Sec MD [ue Azi TVD +EI-W DLeg TFace vSec Target 1 2 3 4 5 6 I 2 3 4 5 6 7 8 9 ¡¡¡ II 12 13 14 15 16 17 18 19 20 21 \ - - \ - \ / \ - \ / / - - '\ 9()(; - \e . \\ - \' // \ - - \ -- \ - III ~ - \ fR \ T [51 - - I \ p :¡¡ "" "" ::!. .c 15. ¿¡ '" " ·f " > " " ~ COMPANY DETAILS REFERhl\!CE JNFORMATI0N I Plan: 12~20A wpû8 (12-20/Pbu; J2-20Aj BP Amoco I T... '" I\Jrmh Survey/pJa¡¡ Too! , '>+28.569S0 8:9fJO.oo 10630-68 Pllirmed: MWD C"-k d. D ,0' ~[{~~~ IseWSA , 41+28$ 69 SO ,= e . a.. ; RuICsBast.->d Nan~ Slot 12-2" ·">7.92 ·1343.56 5930998.25 6%66121 70''''5654ßN 14ß'24·49,114IW 20 ~i¡~ j/¡ TARGET DETAILS , '\ Name TVD +E/-W Naming Easting Shape , .. ^. ~. ~ . f '¿-¿VA' 1L Pmnt , \ . 1¿-¿VA 'LV I ,\ I ' 420v ¡. . I ¡ SECTION DETAILS I See MD Azi TVD DLeg TFaœ VSec Target \ i ~::i ;j ;4:; I~ -8~ ::~ III I I ,I ! : ' ¡ I 2 i:: Ý.! :i' ~ -B~ j ::¡ !?1M 1',(' ~ 41 . . .' I . , \ ¡I 1.4 A!: ~ ~ 44.~ 12-20J\TZD , . II' i : i il! I, , -, u U ,.I ,,,' ¡ !/ ....L: , Ii! I' +¡, : II 14 / ' ¡i \, \::]:::::. /i !:"}If I IT if·· ... .... ¡ . iT t I . '. .... I~I 'H " 8C~ ¡ ...., + I'm, ¡ ... im ..,.... I!..'........ 400 i..i, ~ ,¡ ..., / :irr, i\ I",. FORMATION TOP DETAILS =. + /'~, I' f ,. TVDPath Formation ~ '!, ," "' j, :: .', I 'ð '" ~.~ >7 15 """ : ; ~ /9 J.t Rz ~ 'Ý" 4 !., rR ~ I 5 J.i E 39 I ' 6 :R J5 ,,/ ! 7 rsGR ¡ 8 ~!!y 9 I' , I:::::: i? I 12 I ".!3 , 14 , , I j""", 15 i ¡ ! 16 1 380 11 ¡ : I 18 ¡ 19 1 , ' 20 ¡ ! 21 I 50 i I ¡, ¡ '1 31' CASING DETAILS TVD MD Name Size I 1" 2 1/2" ! 36,,,, -1900 -I8ffO -1700 ·1600 ·1500 ·1400 .1300 .1200 West¡-)/East(+) ¡100M!!] . . BP-GDB BP Planning Report Company: BP Amoco Date: 7/2912004 Time: 09:27:00 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 12-20, TruE! North Site: PB DS 12 Vertical (TVI) Reference: 41+28.569:5 Well: 12-20 Section (VS) Reference: Well (0.00N,O.ooE.335.29Azi) Wellpath: Plan 12-20A Survey Calculatiou Method: Minimum Curvature Db: Oracle Plan: 12-20A wp08 Date Composed: 5/26/2004 Version: 77 Principal: Yes Tied-to: From: Definitive Path 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: bggm2004 Site: PB DS 12 TR-10-15 UNITED STATES: North Slope Site Position: Northing: 5932650.90 ft Latitude: 70 13 12.462 N From: Map Easting: 697966.79 ft Longitude: 148 24 9.888 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 12-20 Slot Name: 20 12-20 Well Position: +N/-S -1617.92 ft Northing: 5930998.25 ft Latitude: 70 12 56.548 N +E/-W -1348.56 ft Easting : 696661.21 ft Longitude: 148 24 49.041 W Position Uncertainty: 0.00 ft Casing Points MD TVD DIameter Hole Size Name ft ft in in 10312.62 8709.50 7.000 8.500 7" 10630.00 9006.87 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direetion ft ft deg <leg 0.00 UG4 0.00 0.00 0.00 UG3 0.00 0.00 0.00 UG1 0.00 0.00 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 9540.96 7986.50 CM1 0.00 0.00 9810.99 8239.50 THRZ 0.00 0.00 9975.35 8393.50 BHRZ 0.00 0.00 10103.43 8513.50 BPTR 0.00 0.00 10103.43 8513.50 TJB 0.00 0.00 10103.43 8513.50 TPTR 0.00 0.00 10312.62 8709.50 TSGR 0.00 0.00 10341.44 8736.50 TSHU 0.00 0.00 10361.72 8755.50 TSHB 0.00 0.00 10380.93 8773.50 TSHC 0.00 0.00 10419.35 8809.50 46P 0.00 0.00 10456.71 8844.50 45N 0.00 0.00 10457.77 8845.50 45P 0.00 0.00 10502.60 8887.50 44N 0.00 0.00 10502.60 8887.50 44P 0.00 0.00 10533.55 8916.50 43N 0.00 0.00 10534.62 8917.50 43P 0.00 0.00 10573.04 8953.50 42N 0.00 0.00 10576.25 8956.50 42P 0.00 0.00 10598.66 8977.50 41N 0.00 0.00 10601.86 8980.50 41P 0.00 0.00 0.00 31N 0.00 0.00 0.00 31P 0.00 0.00 Company: Field: Site: Well: Wellpath: Targets BP Amoco Prudhoe Bay PB DS 12 12-20 Plan 12"20A . Name Description Dip. Dir. 12-20A T1C -Plan hit target 12-20A T2D -Plan hit target Plan Section Information MD ft 8900.00 8920.00 9519.68 10418.28 10525.01 10630.68 Survey MD ft 8900.00 8920.00 8925.00 8950.00 8975.00 9000.00 9025.00 9050.00 9075.00 9100.00 9125.00 9150.00 9175.00 9200.00 9225.00 9250.00 9275.00 9300.00 9325.00 9350.00 9375.00 9400.00 9425.00 9450.00 9475.00 9500.00 9519.68 9525.00 9540.96 9550.00 9575.00 9600.00 9625.00 9650.00 9675.00 Incl deg 31.46 31.75 20.46 20.46 20.46 20.46 Incl deg 31.46 31.75 31.60 30.86 30.14 29.43 28.73 28.05 27.39 26.75 26.13 25.53 24.96 24.41 23.89 23.40 22.94 22.51 22.12 21.76 21.45 21.17 20.94 20.75 20.60 20.50 20.46 20.46 20.46 20.46 20.46 20.46 20.46 20.46 20.46 Azim deg 342.00 337.45 286.93 286.93 286.93 286.93 Azim deg 342.00 337.45 337.20 335.90 334.55 333.13 331.65 330.11 328.49 326.81 325.04 323.20 321.28 319.28 317.20 315.02 312.77 310.43 308.00 305.50 302.92 300.28 297.57 294.81 292.01 289.18 286.93 286.93 286.93 286.93 286.93 286.93 286.93 286.93 286.93 TVD ft 7405.66 7422.70 7966.56 8808.50 8908.50 9007.50 TVD ft 7405.66 7422.70 7426.95 7448.33 7469.87 7491.57 7513.42 7535.41 7557.54 7579.80 7602.18 7624.69 7647.30 7670.02 7692.83 7715.73 7738.71 7761.77 7784.90 7808.09 7831.33 7854.63 7877.96 7901.32 7924.71 7948.12 7966.56 7971.54 7986.50 7994.97 8018.39 8041.81 8065.24 8088.66 8112.08 BP-GDB BP Planning Report TVD ft 8808.50 8908.50 +N/-S ft 3719.54 3729.37 3908.23 3999.69 4010.55 4021.30 Sys TVD ft 7336.16 7353.20 7357.45 7378.83 7400.37 7422.07 7443.92 7465.91 7488.04 7510.30 7532.68 7555.19 7577.80 7600.52 7623.33 7646.23 7669.21 7692.27 7715.40 7738.59 7761.83 7785.13 7808.46 7831.82 7855.21 7878.62 7897.06 7902.04 7917.00 7925.47 7948.89 7972.31 7995.74 8019.16 8042.58 . Date: 7/29/2004 Time: 09:27:00 Page: 2 Co-ordinate(NE) Reference: Well: 12-20. True North Vertical (TVD) Reference: 41+28.569.5 Seetion (VS) Reference: Well (O.ooN,O.00E.335.29Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/-S +E/-W ft ft 3999.69 -1779.72 4010.50 -1815.40 +EI-W ft -1312.51 -1316.14 -1479.28 -1779.72 -1815.40 -1850.73 N/S ft 3719.54 3729.37 3731.79 3743.68 3755.20 3766.35 3777.12 3787.50 3797.50 3807.11 3816.33 3825.16 3833.59 3841.62 3849.25 3856.48 3863.30 3869.71 3875.71 3881.30 3886.48 3891.24 3895.58 3899.51 3903.01 3906.10 3908.23 3908.78 3910.40 3911.32 3913.86 3916.41 3918.95 3921.50 3924.04 Map Map Northing Easting ft ft 5934950.00 694778.00 <-- Latitude Deg Min See 5934959.87 694742.05 DLS Build Turn deg/10Oft deg/100ftdeg/10Oft 0.00 0.00 0.00 12.00 1.45 -22.73 4.00 -1.88 -8.43 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EIW ft -1312.51 -1316.14 -1317.15 -1322.31 -1327.63 -1333.10 -1338.73 -1344.51 -1350.45 -1356.53 -1362.77 -1369.15 -1375.68 -1382.34 -1389.15 -1396.10 -1403.19 -1410.41 -1417.76 -1425.24 -1432.85 -1440.59 -1448.45 -1456.43 -1464.52 -1472.74 -1479.28 -1481.06 -1486.40 -1489.42 -1497.78 -1506.13 -1514.49 -1522.85 -1531.21 DLS deg/100ft 0.00 12.00 4.00 4.00 4.00 MapN ft 5934682.14 5934691.86 5934694.26 5934706.01 5934717.39 4.00 4.00 4.00 4.00 4.00 5934728.39 5934739.00 5934749.23 5934759.08 5934768.52 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 5934777.58 5934786.24 5934794.49 5934802.35 5934809.80 5934816.84 5934823.47 5934829.69 5934835.50 5934840.89 5934845.87 5934850.43 5934854.56 5934858.28 5934861.57 5934864.45 5934866.41 5934866.90 5934868.39 5934869.23 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5934871.55 5934873.88 5934876.20 5934878.53 5934880.86 70 13 35.883 N 70 13 35.990 N TFO deg 0.00 -85.00 -138.43 0.00 0.00 0.00 12-2OA T1C 12-2OA T2D 695252.32 695248.44 695247.36 695241.90 695236.28 695230.52 695224.61 695218.56 695212.37 695206.03 695199.56 695192.95 695186.21 695179.33 695172.33 695165.19 695157.93 695150.55 695143.04 695135.42 695127.68 695119.82 695111.85 695103.77 695095.59 695087.30 695080.70 695078.91 695073.53 695070.49 695062.07 695053.64 695045.22 695036.80 695028.38 148 25 40.741 W 148 2541.777 W TooVComment Start Dir 12/10 Start Dir 4/100 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD End Dir : 9519 MWD CM1 MWD MWD MWD MWD MWD MWD . . BP-GDB BP Planning Report Company: BP Amoco Date: 7/2912004 Time: 09:27:00 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 12-20, True North Site: PB DS 12 Vertical (TVD) R..,ference: 41+28.569:5 Well: 12-20 Section (VS) Refetenee: Well (O.00N.0.00E,~35;;29Azî) Wellpath: Plan 12-20A Survey Calculation Method: Minimum Curvature Db: OraCle Survey MD IncI Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft degl100ft ft ft 9700.00 20.46 286.93 8135.51 8066.01 3926.59 -1539.57 0.00 5934883.18 695019.96 MWD 9725.00 20.46 286.93 8158.93 8089.43 3929.13 -1547.93 0.00 5934885.51 695011.54 MWD 9750.00 20.46 286.93 8182.36 8112.86 3931.67 -1556.28 0.00 5934887.83 695003.12 MWD 9775.00 20.46 286.93 8205.78 8136.28 3934.22 -1564.64 0.00 5934890.16 694994.69 MWD 9800.00 20.46 286.93 8229.20 8159.70 3936.76 -1573.00 0.00 5934892.48 694986.27 MWD 9810.99 20.46 286.93 8239.50 8170.00 3937.88 -1576.68 0.00 5934893.51 694982.57 THRZ 9825.00 20.46 286.93 8252.63 8183.13 3939.31 -1581.36 0.00 5934894.81 694977.85 MWD 9850.00 20.46 286.93 8276.05 8206.55 3941.85 -1589.72 0.00 5934897.13 694969.43 MWD 9875.00 20.46 286.93 8299.47 8229.97 3944.40 -1598.08 0.00 5934899.46 694961.01 MWD 9900.00 20.46 286.93 8322.90 8253.40 3946.94 -1606.44 0.00 5934901.79 694952.59 MWD 9925.00 20.46 286.93 8346.32 8276.82 3949.48 -1614.79 0.00 5934904.11 694944.17 MWD 9950.00 20.46 286.93 8369.74 8300.24 3952.03 -1623.15 0.00 5934906.44 694935.74 MWD 9975.00 20.46 286.93 8393.17 8323.67 3954.57 -1631.51 0.00 5934908.76 694927.32 MWD 9975.35 20.46 286.93 8393.50 8324.00 3954.61 -1631.63 0.00 5934908.80 694927.20 BHRZ 10000.00 20.46 286.93 8416.59 8347.09 3957.12 -1639.87 0.00 5934911.08 694918.90 MWD 10025.00 20.46 286.93 8440.01 8370.51 3959.66 -1648.23 0.00 5934913.41 694910.48 MWD 10050.00 20.46 286.93 8463.44 8393.94 3962.21 -1656.59 0.00 5934915.74 694902.06 MWD 10075.00 20.46 286.93 8486.86 8417.36 3964.75 -1664.94 0.00 5934918.06 694893.64 MWD 10100.00 20.46 286.93 8510.29 8440.79 3967.29 -1673.30 0.00 5934920.39 694885.22 MWD 10103.43 20.46 286.93 8513.50 8444.00 3967.64 -1674.45 0.00 5934920.71 694884.06 TPTR 10125.00 20.46 286.93 8533.71 8464.21 3969.84 -1681.66 0.00 5934922.72 694876.79 MWD 10150.00 20.46 286.93 8557.13 8487.63 3972.38 -1690.02 0.00 5934925.04 694868.37 MWD 10175.00 20.46 286.93 8580.56 8511.06 3974.93 -1698.38 0.00 5934927.37 694859.95 MWD 10200.00 20.46 286.93 8603.98 8534.48 3977.47 -1706.74 0.00 5934929.69 694851.53 MWD 10225.00 20.46 286.93 8627.40 8557.90 3980.02 -1715.09 0.00 5934932.02 694843.11 MWD 10250.00 20.46 286.93 8650.83 8581.33 3982.56 -1723.45 0.00 5934934.34 694834.69 MWD 10275.00 20.46 286.93 8674.25 8604.75 3985.10 -1731.81 0.00 5934936.67 694826.27 MWD 10300.00 20.46 286.93 8697.67 8628.17 3987.65 -1740.17 0.00 5934938.99 694817.85 MWD 10312.62 20.46 286.93 8709.50 8640.00 3988.93 -1744.39 0.00 5934940.17 694813.59 7" 10325.00 20.46 286.93 8721.10 8651.60 3990.19 -1748.53 0.00 5934941.32 694809.42 MWD 10341.44 20.46 286.93 8736.50 8667.00 3991.87 -1754.02 0.00 5934942.85 694803.89 TSHU 10350.00 20.46 286.93 8744.52 8675.02 3992.74 -1756.89 0.00 5934943.65 694801.00 MWD 10361.72 20.46 286.93 8755.50 8686.00 3993.93 -1760.80 0.00 5934944.74 694797.06 TSHB 10375.00 20.46 286.93 8767.94 8698.44 3995.28 -1765.25 0.00 5934945.97 694792.58 MWD 10380.93 20.46 286.93 8773.50 8704.00 3995.88 -1767.23 0.00 5934946.52 694790.58 TSHC 10400.00 20.46 286.93 8791.37 8721.87 3997.83 -1773.60 0.00 5934948.30 694784.16 MWD 10418.28 20.46 286.93 8808.50 8739.00 3999.69 -1779.72 0.00 5934950.00 694778.00 12-20A T1C 10419.35 20.46 286.93 8809.50 8740.00 3999.80 -1780.07 0.00 5934950.10 694777.64 46P 10425.00 20.46 286.93 8814.79 8745.29 4000.37 -1781.96 0.00 5934950.62 694775.74 MWD 10450.00 20.46 286.93 8838.22 8768.72 4002.91 -1790.32 0.00 5934952.95 694767.32 MWD 10456.71 20.46 286.93 8844.50 8775.00 4003.60 -1792.56 0.00 5934953.57 694765.06 45N 10457.77 20.46 286.93 8845.50 8776.00 4003.71 -1792.92 0.00 5934953.67 694764.70 45P 10475.00 20.46 286.93 8861.64 8792.14 4005.46 -1798.68 0.00 5934955.27 694758.90 MWD 10500.00 20.46 286.93 8885.06 8815.56 4008.00 -1807.04 0.00 5934957.60 694750.47 MWD 10502.60 20.46 286.93 8887.50 8818.00 4008.27 -1807.91 0.00 5934957.84 694749.60 44P 10525.00 20.46 286.93 8908.49 8838.99 4010.55 -1815.40 0.00 5934959.92 694742.05 MWD 10533.55 20.46 286.93 8916.50 8847.00 4011.42 -1818.26 0.00 5934960.72 694739.17 43N 10534.62 20.46 286.93 8917.50 8848.00 4011.53 -1818.61 0.00 5934960.82 694738.81 43P 10550.00 20.46 286.93 8931.91 8862.41 4013.09 -1823.75 0.00 5934962.25 694733.63 MWD 10573.04 20.46 286.93 8953.50 8884.00 4015.44 -1831.46 0.00 5934964.39 694725.87 42N 10575.00 20.46 286.93 8955.33 8885.83 4015.64 -1832.11 0.00 5934964.58 694725.21 MWD 10576.25 20.46 286.93 8956.50 8887.00 4015.76 -1832.53 0.00 5934964.69 694724.79 42P 10598.66 20.46 286.93 8977.50 8908.00 4018.04 -1840.02 0.00 5934966.78 694717.24 41N . . BP-GDB BP Planning Report Company: BPAmoco Date: 7/2912004 Time: 09:27:00 Page: 4 Field: Prudhoe Bay Co-ordinate(N.t)·Reference: WeIlZ12-20.TWIiI North Site: PB DS 12 Vertical (TVD) Reference: 41+28.569.5 Well: 12-20 Sèetion (VS) Refere~ee: Well (O.00N,O.OOE.335.29Azj) Wellpath: Plan 12-20A Survey CalculationM~thod: Minimum Curvature Dh: Orao/e Survey MD Incl Azim TVD Sys TVD N/S E/W DLS MapN M~PE ft deg deg ft ft ft ft degl1000 ft 10600.00 20.46 286.93 8978.76 8909.26 4018.18 -1840.47 0.00 5934966.90 694716.79 MWD 10601.86 20.46 286.93 8980.50 8911.00 4018.37 -1841.09 0.00 5934967.07 694716.16 41P 10625.00 20.46 286.93 9002.18 8932.68 4020.72 -1848.83 0.00 5934969.23 694708.37 MWD 10630.00 20.46 286.93 9006.87 8937.37 4021.23 -1850.50 0.00 5934969.69 694706.68 41/2" 10630.68 20.46 286.93 9007.50 8938.00 4021.30 -1850.73 0.00 5934969.75 694706.45 MWD . . TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 141 DATE 08 -3/-ò<.¡ ~~6lR0o'i'E ~,~~EC~ ~$ IOJ). DO ~_~ __ -= DOttÄRŠ First National Bank Alaska ~W~ "Mastercard Check" Anchorage, AK 99501 MEMO~~ ':;¿Ot9- .: ~ 2 5 2000 b 0': q q ~... III b 2 2 7 It, ~ 5 5 b II- 0 ~... ~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) M1JLTI LATERAL (If API number last two (2) digits are between 6.0-69) Exploration Stratigraphic ~'CL DE n. The permit is for a new wellbore segment of existing wen . Permit No, API No. . Production. sbould continue to be reponed as a function ·of tbe original API Dumber. stated above. HOLE In accordance with 2.0 AAC 25..o.o5(t), all records, data and logs acquired for the pilot bole must be clearly differeDtiated ID botb name (name on permit plus PH) .. aDd API Dum ber (5.0 - 7.0/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to full compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing excep1ion. (Company Name) assumes tbe liability of any protest to tbe spacing .eJcep1ion that may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater 1han 3D' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals througb target zones. o o Well bore seg Annular Disposal . . 640150 Well Name: PRUDHOE BAY UNIT 12-20A _Program SER ~ Initial ClasslType SER/1-ill!.-GeoArea 890 Unit 11650_ On/Off Shore ~n - Administration PemJit fee attache.d Yes. - - - - - - - - - - - 2 .Lease .number .appropriate ... Yes. - - - - - 3 .U.nique welL n.a!11e .a[1d lJu.mb.er - - - - . . . . . . . . . .Y.es _. - - - - - - - - - - - - - - - - - - - - - - -- 4 WeJI Jocated in.a. d.efineJ:!.POQI. Yes. 5 WelUocated pr.operdistance. from driJling unitbound.ary. Yes. - - - -- 6 Well Jocated pr.oper .distance. from other welJs ... Yes 7 S.utficient acreage.ayai1able [ndrilliog lInjt . Yes. - - - - - - - - - 8 Jtdeviated. js. wellbore plç¡tincJuded . . - - - - - - - - - - - Yes. . - - - - - 9 OJ)ecator onl)' affected party. . - - - - - - - - - - - Yes. . - - - - - 10 .OJ)ecator has.apprppriateJ).ond inJQrce . . . . . . . . . _ - - - -- ........ Yes._ - - - - - - - - - - - - - - - - - - - - . - -- 11 Permit can be issu.ed without conservation order. . - - - - - - Yes. . - - - - Appr Date 12 Permit Çén be issu.eJ:! without ad.ministratÏ\leaJ)prpvaJ . . Yes. . - - - - RPC 9/1/2004 13 Can permit be approved before 15-day wait Yes 14 Well Jocatßd within area and.strç¡ta .authorized byJojecìipo Order # (puUOtJ incom!11eotsUFor. Yes. . .A.I04C.. . - - - - 15 .AJI welJs. withtn Jl4.ruile.area.of reyieW jdeotified (Fpr servjce .well onl)'>- . . . . . . . . . . . . . . Yes. . pal) 12-12. PßUJ3-j)Za. . . . . . . . . 16 Pre-produ.ced i[1jecìor; J:!uration.of pre-J)roJ:!ucìion less than 3 months. (For service well onlY) . . NA . - - - -- 17 .ACMPJ:indjngof CQnsiste[1cy.has beenJssuedJorJhis project . . . . - - - - - - - - - NA. - - - - - - - - - Engineering 18 .C.ondu.ct.or string.provided . . . - - - - -- - - - - - - NA - - - - 19 .Surfacecç¡sing.pJotec.ts all.known USDWs . - - - -- - - - - - - - - - - NA. - - - - - 20 .CMT v.ol adeq u.ate. to circulate. on .conductor & SUJt csg . . NA. - - - - - - - - - - 21 CMT v.ol adequ.ateJo tie-in Jong .string to surf csg. . . . .. NA 22 .CMTwill coyeralll<oow.npro.ductiye hori¡Qn.s. - - - - Yes. - - - - - - 23 .Casiog desigos ad.etlllate tor C.T. B&. Rerruafr.ost . . . . - - - - -- Yes. - - -- 24 .AJ:!equateJankç¡geoJ re.seIYe pit. - - - - -- - - - - - - - - - - Yes t>labors.7ES, . . 25 JfaJe-J:!rilt has.a. 1.0-403 for abandQnme.nt beeo apPJoved . . . - - - - -- Yes. 8127:12004.. . . - - - - -- 26 .AJ:!equate.VIlellboreseparation.proJ)oseJ:!. . . . _ _ _ _ . . _ . . . _ . . . _ . . . _ _ . . . . . _ . . . Yes. . - - - - - - - - - - - - - - - - - - - - - - -- 27 Jf.dlverter req.uired, does jt.meet reguJatioos. . . . . - - - - -- - - - - - - NA. Sidetrack. - - - - - - - - - - Appr Date 28 .Drilliog fJuJdRrogram schematic & eq.uipJistaJ:!equate. . . - - - - - - - - - - - - .Yes. Mç¡x MW 10..1ppg.. . - - - - - WGA 9/2/2004 29 .BOPEs,dp.they meet regulation . - - - - -- - - - - -- Yes. 30 B.OPEpress ratiog apJ)ropri¡¡te; .test to.(pu.t psig i.n .comments). . - - - - - - - - . . . .Yes Test tp .3500. psi. .MSF' 23.26 psi. . . . . 31 C.hoke.ruanjfold complies w/APIRF'-53 (May 84). . - - - - - - - - - - - - - - .Yes. - - -- 32 Work will occur witho\Jt.operç¡tionshlltdow.n. . . . . . . - - - - - - - - Yes. - - - -- - - - - 33 Is prese[1ce of H2S gas. Rrob.able. . . . . . . . - - - - - - Yes. 1:125 paJ:!- ~o ppru.. 34 MeclJa.nical.cpodJUo[1 p{wells wi.thin AOß yerified (For. service welJ QnJy). . . . . .Yes. Cmt records. oJ all.A.OR wells JndjcateMI Geology 35 Permit ~o be issu.ed w!o hydrogen sulfide me¡¡SUres. - - - - - No. . 36 .D.ata.preseoted on. pote.nti¡¡1 oveJRres.sure .zones. . . . - - - - -- . .NA Appr Date 37 .Sei.s!11ic.anç¡lysjs of shallQW gaszooes NA. - - - - - - - - RPC 9/1/2004 38 Se<lbeJ:!condjtioo sllrvey(if Qff-shore) . . . .NA - - - - -- 39 . CQnta.ct na.rn.elphonefQr.weekly progress reports [expIQrç¡tpryoOIYl . NA. - Geologic Engineering ffI Commissioner: Date: Commissioner Date is ioner Date QJ-s 1/3/<¡- ~9d~ e e 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 effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . c::lo1' - / 'h $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 04 08:10:35 2005 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/04 Origin.................. .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/04 Origin.................. .STS Tape Name........... .... . UNKNOWN Continuation Number.... ..01 Previous Tape Name...... . UNKNOWN Comments.......... ...... .STS LIS writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 12-20A 500292086301 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 04-MAR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003286719 P. SMITH D. FERGUSON MWD RUN 2 MW0003286719 P. SMITH D. FERGUSON MWD RUN 3 MW0003286719 P. SMITH D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 10N 15E 691 942 68.96 41.31 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 8920.0 10323.0 # . . REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK; MILL THE WINDOW; AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS AT 8920'MD/7410'TVD. ONLY SROP DATA ARE PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). THERE WAS NO SLIDING DURING RUN 3, ERGO, THERE ARE NO SLD SLIDE DATA. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DOUGLAS (SIS/BP), DATED 2/17/05, QUOTING AUTHORIZATION FROM STEVE JONES, BP GEOLOGIST. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 3 REPRESENT WELL 12-20A WITH API#: 50-029-20863-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10635'MD/9005'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 2800 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 . . Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.... ...05/03/04 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET GR ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8901.0 8901.0 8901.0 8901.0 8901.0 8908.5 8920.5 10251. 0 10251. 5 10251. 5 10265.0 10318.0 10318.0 STOP DEPTH 10612.0 10612.0 10612.0 10612.0 10612.0 10619.0 10635.0 10577.0 10577.0 10577.0 10590.5 10590.5 10590.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 8920.5 8950.0 10325.0 MERGE BASE 8950.0 10325.0 10635.0 # Data Format Specification Record Data Record Type........ ....... ...0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point....... ...... . Undefined Frame Spacing.. ....... ........ ....60 olIN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 . . NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8901 10635 9768 3469 8901 10635 ROP MWD FT/H 0.17 2007.43 86.1277 3430 8920.5 10635 GR MWD API 16.51 513.14 129.442 3422 8908.5 10619 RPX MWD OHMM 0.32 1774.26 6.90989 3423 8901 10612 RPS MWD OHMM 0.45 1666.54 6.62216 3423 8901 10612 RPM MWD OHMM 0.45 2000 31.644 3423 8901 10612 RPD MWD OHMM 0.28 2000 49.1707 3423 8901 10612 FET MWD HOUR 0.16 81.83 3.91834 3423 8901 10612 NPHI MWD PU-S 5.69 74.18 29.4692 652 10251.5 10577 FCNT MWD CNTS 94.6 2704.25 638.74 652 10251.5 10577 NCNT MWD CNTS 12352 49944.8 27191. 6 653 10251 10577 RHOB MWD G/CM 1. 857 3.077 2.4048 546 10318 10590.5 DRHO MWD G/CM -0.223 0.639 0.0569579 546 10318 10590.5 PEF MWD BARN 1. 03 15.12 4.39603 652 10265 10590.5 First Reading For Entire File......... .8901 Last Reading For Entire File.......... .10635 File Trailer Service name..... .... ....STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/03/04 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name... ....... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .05/03/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8920.5 STOP DEPTH 8950.0 # LOG HEADER DATA DATE LOGGED: 26-SEP-04 . SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...... .....Feet Data Reference Point............. . Undefined Frame Spacing. .......... .... .... ..60 .1IN Max frames per record............ . Undefined Absent value.. .......... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Insite 66.37 Memory 8950.0 8920.0 8950.0 .0 .0 TOOL NUMBER 8.500 8920.0 Milling fluid 10.15 75.0 8.0 1400 3.6 .000 .0 .000 .0 .000 .0 .000 .0 Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 8920.5 0.6 Max 8950 117.74 Mean 8935.25 9.87067 Nsam 60 60 First Reading 8920.5 8920.5 Last Reading 8950 8950 . First Reading For Entire File..... .....8920.5 Last Reading For Entire File...... .....8950 . File Trailer Service name...... .... ...STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation.......05/03/04 Maximum Physical Record..65535 File Type............. ...LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .05/03/04 Maximum Physical Record. .65535 File Type........ . . . . . . . . LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 8901.0 8901. 0 8901.0 8901. 0 8901.0 8908.5 8950.5 STOP DEPTH 10280.5 10280.5 10280.5 10280.5 10280.5 10287.0 10325.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 29-SEP-04 Insite 66.37 Memory 10325.0 8950.0 10325.0 16.5 31.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 53516 56933 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 8920.0 . # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ......... ... ....Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 olIN Max frames per record........ .....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . LSND 10.20 52.0 9.1 1100 4.5 1.100 .520 1. 000 1. 500 70.0 156.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8901 10325 9613 2849 8901 10325 ROP MWD020 FT/H 0.17 2007.43 87.1405 2750 8950.5 10325 GR MWD020 API 21.13 397.83 143.163 2758 8908.5 10287 RPX MWD020 OHMM 0.44 1774.26 3.50447 2760 8901 10280.5 RPS MWD020 OHMM 0.45 1666.54 3.20876 2760 8901 10280.5 RPM MWD020 OHMM 0.45 1667.11 3.51201 2760 8901 10280.5 RPD MWD020 OHMM 0.28 2000 20.8405 2760 8901 10280.5 FET MWD020 HOUR 0.37 29.41 2.10985 2760 8901 10280.5 First Reading For Entire File..... .... .8901 Last Reading For Entire File.. ...... ...10325 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... . Version Number.......... .1.0.0 Date of Generation...... .05/03/04 Maximum Physical Record. .65535 File Type..... .......... .LO Next File Name.. ..... ....STSLIB.004 Physical EOF File Header Service name. ........... .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .05/03/04 Maximum Physical Record..65535 File Type......... ...... .LO Previous File Name. ..... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10251. 0 10251. 5 10251. 5 10265.0 10281. 0 10281.0 10281. 0 10281. 0 10281. 0 10287.5 10318.0 10318.0 10325.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 10577.0 10577.0 10577.0 10590.5 10612.0 10612.0 10612.0 10612.0 10612.0 10619.0 10590.5 10590.5 10635.0 02-0CT-04 Insite 66.37 Memory 10635.0 10325.0 10635.0 17.1 18.6 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER 135134 185639 113413 148579 6.125 . DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.......... ......... ..60 olIN Max frames per record. ......... ...Undefined Absent value..... ........ ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 10323.0 . Flo-Pro 8.40 49.0 10.3 2800 9.0 1.150 .610 1.100 1. 050 70.0 138.1 70.0 70.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10251 10635 10443 769 10251 10635 ROP MWD030 FT/H 4.5 322.58 89.0149 620 10325.5 10635 GR MWD030 API 16.51 513 .14 72.4513 664 10287.5 10619 RPX MWD030 OHMM 0.32 1073.54 21.0863 663 10281 10612 RPS MWD030 OHMM 0.56 1391. 79 20.8318 663 10281 10612 RPM MWD030 OHMM 0.61 2000 148.754 663 10281 10612 RPD MWD030 OHMM 0.39 2000 167.106 663 10281 10612 FET MWD030 HOUR 0.16 81.83 11.4469 663 10281 10612 NPHI MWD030 PU-S 5.69 74.18 29.4692 652 10251.5 10577 FCNT MWD030 CNTS 94.6 2704.25 638.74 652 10251.5 10577 · .10251 NCNT MWD030 CNTS 12352 49944.8 27191.6 653 10577 RHOB MWD030 G/CM 1. 857 3.077 2.4048 546 10318 10590.5 DRHO MWD030 G/CM -0.223 0.639 0.0569579 546 10318 10590.5 PEF MWD030 BARN 1. 03 15.12 4.39603 652 10265 10590.5 First Reading For Entire File......... .10251 Last Reading For Entire File....... .., .10635 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.... ...05/03/04 Maximum Physical Record..65535 File Type........... .... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name....... ..... .LISTPE Date.................... .05/03/04 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. ............... .STS LIS writing Library. Scientific Technical Services Reel Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........ ..... ...UNKNOWN Continuation Number. .... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File