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HomeMy WebLinkAbout204-203 • - l3 1071 Z64-2 30 Regg, James B (DOA) From: Cook, Guy D (DOA) Sent: Tuesday, August 09, 2016 1:03 PM To: AKOPSGC2FieldMTL@bp.com;Akopsgc2wellpadlead@bp.com;AKOPSGC2FieIdOMTL1 @bp.com ( eAttl(K) Cc: Regg, James B (DOA) l Subject: PBU Z-pad Deficiency Reports Attachments: Deficiency_Report_PBUZ-04 .xlsx; Deficiency_Report_PBUZ-11.xlsx; Deficiency_Report_PBUZ-13.xlsx; Deficiency_Report_PBUZ-15.xlsx; Deficiency_Report_PBUZ-26.xlsx Christy Lawler/Dave Spall, Attached are the deficiency reports for the PBU Z-Pad wells with incorrect permit to drill numbers on their well signs. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report(date corrected). If you have any questions, please feel free to call or email. Thank you, Guy Cook +� Petroleum Inspector JAR AOGCC (� R 17 907-227-2614 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Cook at 907-659-2714 or guy.cook@alaska.gov. 1 • • State of Alaska 70- '6\tztito Oil and Gas Conservation Commission Deficiency Report Location: PBU Z-13A Date: 8/8/2016 PTD: 2042030 Operator: BP Exploration Alaska Type Inspection: SVS Operator Rep: Joseph Perkowitz Inspector: Guy Cook Position: GC2 Wellpad Lead Operator Op. Phone: 907-659-4128 Correct by(date): 9/8/2016 Op. Email: Akopsgc2wellpadlead@bp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Wellhouse sign needs to be updated with correct permit to drill number. Operator Rep Signatures: AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 2D14-2.03 2Co42.sg WELL LOG REC FINED TRANSMITTAL NOV o 3 2015 PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED AOGCC ,\ /4/2015 M. K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 uancpdcabp.com SCANNED and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 15-Oct-15 Z-13A BL/CD 50-029-22069-01 2) Signed : i `� � / ' '/ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • STATE OF ALASKA RECEIVED Alt OIL AND GAS CONSERVATION COMA/SION AUG 0 9 2012 REPORT OF SUNDRY WELL OPERATIONS J/'�9 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U cAR9 C Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program 0 Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IS Exploratory ❑ ^ 204 -203 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 —, 50- 029 - 22069 -01 -00 7. Property Designation (Lease Number): a 8. Well Name and Number: ADL0047450 .f PBU Z -13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15443 feet Plugs measured 15034 feet true vertical 9074.24 feet Junk measured 15120 feet Effective Depth measured 15034 feet Packer measured See Attachment feet true vertical 9028.24 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 Surface 2643 10 -3/4" 45.5# L -80 29 - 2672 29 - 2671.98 5210 2480 Intermediate None None None None None None Production 10842 7 -5/8" 29.7# L -80 28 - 10870 28 - 7918.12 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet StANNED AUG 2 ` P M Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# 13Cr80 26 - 12074 26 - 8652.61 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 197 411 1279 287 Subsequent to operation: 184 369 1057 299 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPE 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: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Sum erha Title Petrotechnical Data Technician Signatu ',,,,' - Phone 564 -4035 Date 8/9/2012 Viv '� ` Submit Original Only Form 10-404 Revised 10/2010 Re ©nns AUG 0 2012 ez°1 I Daily Report of Well Operations ADL0047450 AG ITYIAATE • : • w . c . o• • •Iec ive: memory ogging - spinner, ' :orax, a• • pe s RIH with 2.5 Drift and tagged at 15024.2ft. PU to confirm depth with stretch - 15012ft. PU 20 and painted flag at 14992ft eCTM. Pumped KCI with safelube and POOH. On surface and pulley in generator broken. Mechanic called to location. 7/6/2012 « <Job in progress »> Cl U #9 w/1.75" ct. Job Objective: S I P /Contingent CIBP /Contingent MCNL Borax/Perf « <Continued from 7/6/12 WSR »> Weekly BOP test completed. MU STP logging string and RIH.. Log down from 11900' to 15000' at 60 fpm perform stop counts on the way out of hole. At surface confirmed good DATA. It appears that the plug is not leaking. M/U MCNL logging tools. Load and kill well with KCI and begin logging MCNL Baseline Pass #1. 7/7/2012 « <Job in progress »> CTU #9 w/1.75" ct. Job Objective: Drift/STP /MCNL Borax/Adperf « <Continued from 7/7/12 WSR »> Log MCNL Baseline Passes 1 &2 up at 60fpm from 14967'- 12000' cmtd. Log Borax Passes 1 &2 up at 60fpm from 14960' cmtd (directly above CIBP) to 12000' cmtd. RIH w / 2.00" guns 6 spf - 60 deg - PJO 2006 HMX - 7.3gm. Tag CIBP deep and uncomfortable with depth discrepancy. POOH to log GR /CCL tie -in. MU GR /CCL BHA and RIH. 7/8/2012 « <Job in progress »> CTU #9 w/1.75" ct. Job Objective: S I I' /MCNL Borax/Adperf « <Job continued from 7/8/12 WSR »> Log GR /CCL tie -in from 15032'- 12000' cmtd. POOH to verify data. Data verified good. MU Gun #1. RIH w / 2.00" x 20' guns 6 spf - 60 deg - PJO 2006 HMX - 7.3gm. Perforate Top shot 13264' bottom shot 13284'. Gun #2 RIH w / 2.00" x 30' guns 6 spf - 60 deg - PJO 2006 HMX - 7.3gm. Perforate Top Shot 13239', bottom shot 13264' ctmd. MU Gun #3. 7/9/2012 « <Job in progress »> CTU #9 w/1.75" ct. Job Objective: S I P /MCNL Borax/GR -CCL Tie- in /Adpert « <Job continued from 7/9/12 WSR »> RIH w/ Gun #3 - 2.00 "x25' guns, 6 spff, 60 deg phasing, PJO 2006 MHX - 7.3gm. Perforate top shot 13214' bottom shot 13239' / RIH w/ Gun #4 - 2.00 "x 31.84' guns, 6 spff, 60 deg phasing, PJO 2006 MHX - 7.3gm. Perforate top shot 13161' bottom shot 13191' POOH / RIH w/ Gun #5 - 2.00 "x 31.84' guns, 6 spff, 60 deg phasing, PJO 2006 MHX - 7.3gm. Perforate top shot 13131' bottom shot 13161' POOH. 7/10/2012 « <Job in progress »> Cl U #9 w/1.75" ct. Job Objective: S I P /MCNL Borax/GR -CCL Tie- in /Adperf « <Job continued from 7/10/12 WSR »> Continue RIH w/ Gun #6. On depth and fire guns. 2" PJ Omega 2006HMX 7.3gm, 6spf, 60 deg phasing. Top shot= 13101', bottom shot = 13131' cmtd. RIH w/ Gun #7. Tag plug for depth correlation. PUN to 13101 bottom shot depth. 2" PJ Omega 2006HMX 7.3gm, 6 spf, 60 deg phasing. Top shot = 13071, Bottom shot = 13101' . POOH. 7/11/2012 « <Job continued on 7/12/12 »> CTU #9 1.75" Job Scope= Add Pell <Job continued from 7/11/2012 »> MU abd RIH , 2" x 30' 6 spf w/ 60 degree PJO2006 HMX gun #8. Depth at flag was 13090' ctm, corrected to 13101' bottom shot. PUH to 13071 and shoot gun. POOH. Pump 18 bbls of 50/50 methanol for a freeze protect on well. 7/12/2012 « <Job in Progress »> FLUIDS PUMPED BBLS 1703 1% SL KCI WITH SAFELUBE 257 BORAX 30 50/50 METH 1990 TOTAL S • Perforation Attachment ADL0047450 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base Z -13A 7/11/12 APF 13044 13071 8969.08 8966.64 Z -13A 7/12/12 APF 13044 13071 8886.32 8883.88 Z -13A 7/11/12 APF 13071 13131 8883.88 8879.73 Z -13A 7/10/12 APF 13131 13161 8879.73 8878.17 Z -13A 7/10/12 APF 13161 13191 8878.17 8876.7 Z -13A 7/10/12 APF 13214 13239 8875.53 8874.12 . Z -13A 7/9/12 APF 13239 13284 8874.12 8871.42 Z -13A 1/24/10 APF 13320 13340 8869.28 8868.06 Z -13A 1/24/10 APF 13365 13385 8866.44 8865.17 Z -13A 1/23/10 APF 13400 13420 8864.24 8862.96 Z -13A 1/22/10 APF 13440 13500 8861.85 8860.52 Z -13A 1/21/10 APF 13500 13520 8860.52 8860.01 Z -13A 1/20/10 APF 13540 13560 8859.42 8858.83 Z -13A 1/18/10 APF 13580 13600 8858.18 8857.34 Z -13A 12/9/04 PER 13850 13980 8857.81 8864.65 Z -13A 12/9/04 PER 14060 14180 8870.78 8875.44 Z -13A 12/9/04 PER 14220 14630 8877.47 8907.11 Z -13A 12/9/04 PER 14690 14735 8914.16 8920.11 Z -13A 10/25/10 BPS 15010 15011 8944.26 8944.32 Z -13A 12/9/04 PER 15140 15230 8951.27 8960.08 Z -13A 12/9/04 PER 15300 15340 8970.36 8975.82 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 0 • Packers and SSV's Attachment ADL0047450 SW Name Type MD TVD Depscription Z -13A PACKER 10688 7727.16 5 -1/2" ZXP Packer Z -13A PACKER 12022 8538.19 3 -1/2" Baker S -3 Packer Z -13A PACKER 12074 8569.85 3 -1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0047450 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 LINER 1548 5 -1/2" 15.5# L -80 10688 - 12236 7809.92 - 8751.78 7000 4990 LINER 3367 3 -1/2" 9.2# 13Cr80 12074 - 15441 8652.61 - 9073.92 10160 10530 PRODUCTION 10842 7 -5/8" 29.7# L -80 28 - 10870 28 - 7918.12 6890 4790 SURFACE 2643 10 -3/4" 45.5# L -80 29 - 2672 29 - 2671.98 5210 2480 TUBING 12048 3 -1/2" 9.2# 13Cr80 26 - 12074 26 - 8652.61 10160 10530 • • 1 1 1 • Z-1 3A TREE= Y S WELN > –70° @ 12592'. WELLHEAD= FMC _ - "`*31I2 " CH NOTES: TBG8 A � LNR """ ACTUATOR = BAKER KB. ELEV = 91.74' BF ELEV = 55.42' KOP = 3000' ' ' I 2213' H3-1/2" HES X NIP, ID = 2.813" Max Angle = 97 @ 12974' Datum NO = 12447 GAS LIFT MANDRELS Datum 'ND = 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2706 2706 1 (MG DMY RK 0 01/05/05 110 -3/4" CSG, 45.5#, L -80, ID = 9.953 H 2672' 7 3205 3201 14 MMG DOME RK 12 03/05/10 6 4305 4205 34 MVO DOME RK 16 03/05/10 I "I 5 5497 5000 55 MIAG DOME RK 16 03/75/10 4 7727 6206 59 MVIG SO RK 20 03/05/10 3 9233 7001 56 Mu1G DMY RK 0 03/05/10 2 10653 7789 53 !WAG DMY RK 0 03/05/10 1 11941 8572 53 KBG DMY INTG 0 03/05!10 Minimum ID = 2.750" @ 12044' 3 -1/2" HES X NIPPLE 1 11'4 10581' H3- 112 " HES X NIP, ID = 2.813" I I I 10602' —13-1/2" HES RPM GAUGE CARRIER, ID = 2992" I 7 -5/8" X 5 -1/2" ZXP LIP TIEBACK — 10688' -,A L w/ FLEX LOCK HGR MILLOUT WINDOW (Z -13A) 10865' - 10870' I7 -5/8" CSG, 29.7 #, L -80, ID = 6.875" H 10865' IN IWHiPSTOCK (11/23104) H 10865' 11998' H3 -1/2" HES X NIP, ID = 2.813" I IQSV (11/22/04) H 10885' 12021' H5 -1/2" X 3-1/2" BKR S -3 PKR, ID = 2.800" PERFORATION SUMMARY i• REF LOG: GRAM - MAD & EWR - NAND (12/13/04) �, 12044' H3-1/2" HES X NIP, ID = 2.750" I ANGLE AT TOP PERF: 96° @ 13044' yr Note: Refer to Production DB for historical perf data 12065' 312 I ES X NIP, ID = 2.750" SIZE SPF INTERVAL Opn/Sgz DATE 12056' ELM D LOGGED ON 1012V10) 2" 6 13044 - 13071 0 07/12/12 4.4 2" 6 13071 - 13131 0 07/11/12 •OP. . AV .,49 %' 12075' H5 -1/2" X 3 -1/2" ZXPMECH • 2" 6 13131 - 13161 0 07/10/12 ///�j LTP w / HMC LNR HGR 7' 6 13161 - 13191 0 07/10/12 �� 2" 6 13214 - 13239 0 07/10/12 - = : = - 12082' 13 -1/2" TIEBACK 2" 6 13239 - 13284 0 07/09/12 . �� SEAL ASSEMBLY 2" 6 13320- 13340 0 01/24/10 2" 6 13365 - 13385 0 01/24/10 • 2" 6 13400 - 13420 0 01/24/10 7' 6 13440 - 13520 0 01!24110 N 15034' 2.28" HES WIDE RANGE 2" 6 13540- 13560 0 01/24/10 5-1/2" LNR, 15.5#, 12236' GBP(1025/10) 2" 6 13580 - 13600 0 01/24/10 L -80 BTC-M, ID = 4.950" 15120' — FISH - 2.72' CIBP ? 4 13850 - 13980 0 12/09/04 1 ` MILLED (10/25/10) ? 4 14060 - 14180 0 12/09/04 ? 4 14220 - 14630 0 12/09/04 .. ? 4 14690 - 14735 0 12/09/04 PBTD 15374' ? 4 15140 - 15230 C 12/09/04 S ? 4 15300 - 15340 C 12!09/04 3-1/2' SOLID LNR, 9.2 #, 13CR -80 15441' VAM TOP, .0087 bpf, ID = 2.992 DATE REV BY COMVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08125/90 REB ORIGINAL COMPLETION 03/20/10 GJF /SV GLV C/O (03/05 /10) WELL: Z -13A 12/14/04 NIES SIDETRACK "A" 1028/10 MRWPJC MILL! SET CIBP(10/25/10) PERMIT No: "2042030 05/17/05 DTR/PJC GLV GO 04/03/12 KU PJC X NIP ELM) LOGGED 1022/10 AR No: 50- 029 - 22069 -01 11/17/06 DBR / PJC DRLG DRAFT CORRECTION 07/16/12 TTW/JMD ADPERFS/CIBP DEPTH CORR (07/12/12) SEC 19, T11 N, R12E , 981' FNL & 1821' FWL 04/24/07 GLMPJC MN ID CORRECTION 02/04/10 LLI/PJC PEWS (01/24/10) BP Exploration (Alas ka) 11/30/10 Schlonberger NO. 5652 Alaska Data & Consulting Services /ti 3 Company: State of Alaska 2525 Gambell street, Suite 400 l.! Alaska Oil & Gas Cons Comm .1 Anchorage, AK 99503 -2838 Mtn: Christine Shadier ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job it Log Description Date BL Color CD Z -01 B BD88 -00070 MEM PROD PROFILE 00 '5/ - 6n ii 10/31/10 1 A 1 ') (, 04 -25 BJOH -00005 INJECTION PROFILE (T . / &( 0E19 11/08/10 1 ' I ._ - 1 04-25 BJOH -00005 INJECTION PROFILE (5 ") ( L - - (RLl, 11/08/10 1 • . '+• - 1 V -07 BAUJ -00052 MEM PROD PROFILE 11/12/10 1 C. 1 06 -24A BCRD -00068 PRODUCTION PROFILE 11/11/10 1 6 1 1 F -19A AWJI -00121 MEM PROD PROFILE l 11/09/10 1 ' C$, 1 X -25 BD88 -00088 MEMORY GLS � , Zt --ni 10/30/10 1 t . 1 P -08A _ BCUE -00090 MEMORY GLS - 11 10/22/10 1 04 -30 BD88 -00063 MEM PROD PROFILE '_ — - it S -l' 10/26/10 1 aA e 1 01 -06A BCRD -00063 PRODUCTION PROFILE [ r (3 t 10/23/10 1 t . 1 • 9 j D -33 BD88 -00061 MEM PROD PROFILE ,,,,t 10/20/10 10/20/10 1 ; LJ 1 I_ Z -26A 13D88-00067 MEM PROD PROFILE 10 /28/10 1 3 i /'( Z -13A BD88 -00062 MEM PROD PROFILE — S 10/22/10 1 1 I / 01 -02 BCRD -00066 INJ PROFILEIWEL / �g j'(g 10125110 1 1 V -219 AZ2F -00069 MEM INJECTION PROFILE ;",l (2 -/ 4.3 ,7. 10/31/10 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 -r. , fi g 4 ' } �. wr III 1111P f rf1 M1 r: :41 v : STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS N REPORT OF SUNDRY WELL OPERATIONS RECEIVED ~-~:~ ~ q ~~~n 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 Other n Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time E~Bki tY~Ja, ~ ~~ -" Corrrraaa' I Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ ~~rh~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory 204-2030 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Numbers Anchorage, AK 99519-6612 50-029-22069-01-00 8. Property Designation (Lease Number) : Well Name and Number: ADLO-047450 PBU Z-13A 10. Field/Pool(s): \ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured ~ 15443 feet Plugs (measured) None feet true vertical 9074.24 feet Junk (measured) None feet Effective Depth measured 15374 feet Packer (measured) 12021 10688 true vertical 9063.37 feet (true verticaq 8620 7810 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2673 10-314" 45.5# L-80 SURFACE - 2673 SURFACE - 2673 5210 4480 Intermediate 10840 7-5/8" 29.7# L-80 SURFACE - 10840 SURFACE - 7901 6890 4790 Production Liner 1548 5-1/2" 15.5# L-80 10688 - 12236 7810 - 8752 7000 4990 Liner 3366 3-1/2" 9.2# 13CR80 12075 - 15441 8653 - 9074 10160 10530 Perforation depth: Measured depth: SEE ATTACHED - '~_ _ ;~ k= True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1 /2" 9.2# 13Cr80 26 - 12083 26 - 8658 Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker SABL-3 Packer 12021 8620 5-1/2" ZXP LTP TIEBACK 10688 7810 12. Stimulation or cement squeeze summary: Intervals treated (measured): yy~~,~~ X; ry 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: 65 49 329 322 Subsequent to operation: 179 133 910 322 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/8/2010 r VII11 IV-YVY RCVIJC61 //LVV.7 ~ ~i~~~,v /~1 Y! n q ~+~ y~ ~u~ v~~~~p .i~ Z-13A 204-203 PERF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-13A 12/9/04 PER 13,850. 13,980. 8,940.57 8,947.41 Z-13A 12/9/04 PER 14,060. 14,180. 8,953.54 8,958.2 Z-13A 12/9/04 PER 14,220. 14,630. 8,960.23 8,989.87 Z-13A 12/9/04 PER 14,690. 14,735. 8,996.92 9,002.87 Z-13A 12/9/04 PER 15,140. 15,230. 9,034.03 9,042.84 Z-13A 12/9/04 PER 15,300. 15,340. 9,053.12 9,058.58 Z-13A 1/18/10 APF 13,580. 13,600. 8,940.94 8,940.1 Z-13A 1/20/10 APF ~/ 13,540. 13,560. 8,942.18 8,941.59 Z-13A 1/21/10 APF 13,500. 13,520. 8,943.28 8,942.77 Z-13A 1/22/10 APF 13,440. 13,470. 8,944.61 8,943.65 Z-13A 1/22/10 APF 13,470. 13,500. 8,943.65 8,943.28 Z-13A 1/24/10 APF 13,320. 13,340. 8,952.04 8,950.82 Z-13A 1/24/10 APF o/ 13,365. 13,385. 8,949.2 8,947.93 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 • • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/17/2010, CTU #9 w/ 1.75" CT: Perforate /Mud Acid Stim: «Interact Publishing» f MIRU CT unit. Perform weekly BOP tests. Shut in GL and FP flowline with 10 bbls of 60/40 meth. MU Logging BHA and and RIH to 13,800' and log up to 13,100' and POOH. At surface, confirm good logging data. "**Job Continued on 18 Jan 2010""" 1/18/2010~CTU #9 w/ 1 75" CT Perforate /Mud Acid Stim: «Interact Publishing» MU and RIH with Gun Run #1. At flag, confirm with APE that scanned log is correct ..log to shoot from and it is. Correct depth at flag to top shot and PUH to._ ~5~0`° ;top shot depth, drop 1/2" ball to fire 20' of HSD 2006 PJ 6spf gun. At surface with holes, LD spent gun, PT MHA and MU gun run #2. Suspend OPS due to weather, <-40 deg F. ***Job in Progress*** 1/20/2010~ASRC Test Unit #2 S/B for ok to move to well. ***Job in progress*** 1/20/2010 CTU #9 w/ 1.75" CT: Perf/Acid Stim: «Interact Publishing» Return to work ffrom weather standby. PU injector and PT MHA. RIH w / CBF firing head & E20' HSD 2006PJ HMX 6 SPF guns. Perforate from 13.540' - 13.560'. POOH. F....Cont on WSR 01/21/2010. 1/21/2010ASRC Test Unit #2 Cont. S/B for okay to move out to well. "'**Job in progress*"" 1/21/20101CTU #8 w/1.75" OD CT. Perf/Acid stim «< InterACT publishing »> 'Continued from WSR 01/20/2010. POOH. OOH confirmed guns fired. RIH w / CBF firing head & 2" x 20' HDS 2006PJ 6spf gun. Perf top shot 13500' bottom shot 13520'. Confirmed holes. Ball has been recovered. Cut 150' of coil for ;pipe management. Change pack off's and chain inspection. RIH w /SLB GR / CCL memory logging tool. Flag coil @ 13500'. Log up @ 40 fpm from 13,700' ~to 13,200'. POOH. OOH. Bad data from MEM logging tools. MU 2nd Sch iMEM tool string. RIH. Continued on WSR 01/22/2010. 1/22/2010CTU #9 w/1.75" OD CT. MEM log/Perforate. «< InterACT publishing »> !Continued from WSR 01/21/2010. RIH w/SLB MEM tools. Log from 13,700'to j 13,200'. Painted Yellow flag at 13,500'. POOH. OOH. Good data. RIH w /run #4 CBF firing head & 30' HSD 2006 6spf guns top shot t~ 13470' bottom shot j @13500' OOH confirmrd holes. RIH w /run #5 CBF firing head & 30' HSD 12006 6spf guns, top shot @~ 13440', bottom shot ~ 13470' . Fire g .POOH. (Confirmed holes, recovered ball. Continued on WSR 01/23/2009 1 1/22/2010ASRC Test Unit #2 Cont. S/B for ok to move out to well. ***Job in progress*** l3 ~~`' • 1/23/2010ASRC Test Unit #2 Cont. S/B to move out to well. MIRU. ***Job in progress*** 1/23/2010iT/I/O=0/450/400 temp=si Assist Coil tubing- Load IA, Heat Upright tank [Add Perf.] Rigged up to choke skid and pumped 3 bbls 60/40, 420 bbls of 100* 'crude down IA to load. Heat UR tank (072) Safe tube up to 120* Final Whp's=1100/500/400 CTU on well on depart. casing valves open to gauges 1/24/2010 ASRC Test Unit #2 Cont. R/U. S/B for CTU. Outlet well Z-17. ***Job in progress*** 1/24/2010jCTU #9 w/1.75" OD CT. Perf/Acid «< Inter ACT publishing »> Continued from WSR 01/23/2010. RIH w /CBF firing head & 2" x 20' 2006PJ HMX 6spf ;guns. Top shot ~ 13365' & bottom shot ~ 13385. Fire guns, POOH. 3 Confirmed holes. Recovered ball. RIH w /CBF firing head & 2" x 20' 2006PJ HMX 6spf guns. Top shot ~ 13320' & bottom shot 13340'. POOH, all shots fired. Recovered ball. Cut 150' of coil for pipe management. RIH w/ 2" JSN assy. Acid stim perfs. Cont on WSR 01/25/2010 1/25/2010;CTU #9 w/1.75' OD CT. Pipe change out.at stand by rate 1/25/2010ASRC Test Unit #2 Cont. S/B for CTU. POP well. Outlet Z 17. ***Job in =progress*** 1/25/2010-CTU #9 w/1.75" OD CT. Acid trearment. «< InterACT publishing »> Continued from WSR 01/24/2010. Pump acid stimulation as per program. l Found bad pipe starting @ 6300' go to yard and spool on new pipe..Blow reel jdown with N2 and move to yard. -~--Job is complete ----- 1/26/2010~CTU #9 w/1.75" OD CT. Continued from WSR 01/25/2009. Pipe change out at stand by rate.. Off maintenance at 06:00 hrs. 1/26/2010ASRC Test Unit #2 Cont. Acid F/B. S/I and S/B for G/L. POP well. Outlet well Z-17. ***Job in progress*** 1/27/20101ASRC Test Unit #2 Cont. flowing well. Outlet well Z-17. ***Job in progress*** 1/28/2010 ASRC Test Unit #2 Cont. Flow and test well. Begin R/D. 1/30/2010 ASRC Test Unit #2, back on location -snow removal/continue rig down - **job in progress** 1/31/2010 ASRC Test Unit #2, RDMO **job complete** FLUIDS PUMPED BBLS 345.25 60/40 METH 282 1 %KCL W/0.6% SAFE LUBE 100 12% HCL ACID 100 9.1 % MUD ACID 170 3% KCL W/F103 45 3% KCL W/F103 + UO67 44 DIESEL 1126.25 Total TREE= MCEVOY WEL-LHEAD=, _ -- FMC ACTUATOR= BAKER KB. ELEV = 91.74' BF. ELEV = 55.42' KOP = 3000' Max Angle = 97 @ 12974' Datum MD = 12447 Datum TVD = 8800' SS 10-314" CSG, 45.5#, L-80, ID = 9.953 ~-{ 2672' ~ Z-13A Minimum ID = 2.750" @ 12044' 3-1 /2" HES X NIPPLE 7-5I8" X 5-112" ZXPLTPTIEBACK I--) 10688` w /FLEX LOCK HGR WHIPSTOCK (11123/04) ~-{ 10865' EZSV (11122104} S TES: ***3-1 /2" CHROMETBG&LNR*** 2213` -~3-112" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 8 2706 2706 1 MMG DMY RK 0 01!05/05 7 3205 3201 14 MMG DOME RK 16 05/17/05 6 4305 4205 34 MMG DMY RK 0 12(11104 5 5497 5000 55 MMG DOME RK 16 05117!05 4 7727 6206 59 MMG DOME RK 16 05117/05 3 9233 7001 56 MMG DOME RK 16 05117/05 2 10653 7789 53 MMG DOME RK 16 05117!05 1 11941 8572 53 KBG SO INTG 22 05117!05 10581' 3-112" HES X NIP, ID = 2.813" 10602' 3-1/2" HES RPM GAUGE CARRIER, 1D = 2.992" MILLOIlT WINDOW (Z-13A) 10865' - 10870' 11998' 3-1/2" HES X NIP, ID = 2.813" 12021' 5-1/2" X 3-112" BKR S-3 PKR, ID = 2.800" 12044' --~3-1/2" HES X NIP, ID = 2.750" 12065' 3-1/2" HES X NIP, ID = 2.750" 12075' 5-1/2" X 3-112" ZXP MECH LTP w / HMC LNR HGR 12082' 3-1/2" TIEBACK ~ SEAL ASSEMBLY PBTD ~-~ 15374' PERFORATION SUMMARY REF LOG: GRMM - MWD & EWR - MWD (12113/04) ANGLE AT TOP PERF: 89 @ 13850' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE ? 4 13850 - 13980 O 12!09!04 ? 4 14060 - 14180 O 12/09/04 ? 4 14220 - 14630 O 12/09/04 ? 4 14690 - 14735 O 12/09/04 ? 4 15140 - 15230 O 12/09/04 ? 4 15300 - 15340 O 12/09/04 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 5-1/2" LNR, 15.5#, - j 12236' ~ ~, L-&0 BTC-M, ID = 4.950" 3-112" SOLID LNR, 9.2#, 13-GR80 ~ 1544 VAM TOP, .0087 bpf, ID = 2.992 f 11800' (-~ TOP OF CEMENT {11118/04) FISH (4-112" STAB, FS, 3-518" MTR & 4.75" BfT (11118!04) ~4-314"OPEN HOLE{PB1-TD) ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08!25/90 REB ORIGINAL COMPLETION 12/14/04 N7ES SIDETRACK "A" 01!01/06 GLV C/O 05/17/05 DTR/PJC GLV C/O 11/17/06 DBR / PJ DRLG DRAFT CORRECTION 04/24/07 GLNUPJC MIN ID CORRECTION PRUDHOE BAY UNIT WELL: Z-13A PERMfT No: 2042030 API No: 50-029-22069-01 SEC 19, 711 N, R12E, 981' FNL & 1821' FWL BP Exploration (Alaska) ~1 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 August 14, 2009 i~ ~ ',1 ~. ~ ~~~~ ~~f~.~~~5~ -t° Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, • bp ~~~~~~~~ OCT 0 5 20Q9 plask~ Oil 8~ Gas Cons. Corr~iRRiQn Anchorape ~ ~ ~~43 2- ~' 1 ~ /~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ! BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2Q50310 5002922Q530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-146 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-t5 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 500292225t0100 (VA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-236 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219t70000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 02 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA t.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-328L1 1970350 50029219246000 NA 02 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350Q00 NA 1.5 NA 1020 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-i~2 2071720 5002s23380000o NA surface NA MICRQFILMED 03/01/2008 DO NOT PLACE v ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFichelCWrPgs_InsertsllVi~icrofilxn R~arker.cbc Scblumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth J RECEIVED JUL 0 3 Z007 l1Jæka Oil & Gas Coos. CommIssion Anchorage 06/29/07 NO. 4324 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well ob# loa Description Date Bl Color CD H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 lDl 06/19/07 1 A-30A 11661159 MEM PROD PROFilE 06/23/07 1 W-21 A 11661140 MEM PROD PROFilE 04/21/07 1 E-21 B 11661157 MEM PROD PROFilE 06/19/07 1 M-23 11626107 PRODUCTION PROFilE 06/23/07 1 01-21 11824330 PRODUCTION PROFilE 06/22107 1 J-25A 11767130 MEM PROD PROFilE 06/18/07 1 Z-08A 11630483 GlS/PROD lOG 06122/07 1 M-34 11824330 PRODUCTION PROFilE 06/22/07 1 02-30B 11594512 lDl 06/23/07 1 Z-29 11686758 PRODUCTION PROFilE 06/15/07 1 S-38 11801078 lDl 06/20/07 1 H-37A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFilE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 US IT (CEMENT) 06/24/07 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 USIT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. sCANNED JUL 0 5 2007 Petrotechnical Data Center LR2-1 . . 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 8cf{ - Q(t""3 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: )3,~~~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042030 MD 15443 / REQUIRED INFORMATION Mud Log No Samples No ---_.~.._._-----~. Well Name/No. PRUDHOE BAY UNIT Z-13A TVD 9074 ~ Completion Date 12/13/2004 /' Completion Status DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES / PWD, MWD DIR / GR / RES Well Log Information: Log/ Data Digital Type Med/Frmt ED D /Ásc ED D "Äsc ED D .rAse ED/D~C t=6 D Lis ~t ¿ D Lis i~ ¥ i~t ~ ~t ~ Lis D TIF D TIF C Lis Electr Dataset Number Log Log Scale Media Name Directional Survey Directional Survey Directional Survey Directional Survey 13084 Induction/Resistivity 13084 LIS Verification 13085 Induction/Resistivity 13085 LIS Verification 13168 Induction/Resistivity 13168 LIS Verification 13169 Induction/Resistivity 13169 LIS Verification 13725 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Operator BP EXPLORATION (ALASKA) INC 1-01L Current Status 1-01L 5pu.d. ~ lJ~ ~ r API No. 50-029-22069-01-00 UIC N -.-- Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Run No Interval Start Stop 10835 15443 OH/ CH Received 1/27/2005 10835 11339 11339 11354 15443 14340 14340 14272 1/27/2005 1/27/2005 1/27/2005 Open 3/16/2005 11354 14272 Open 3/16/2005 10811 15378 Open 3/16/2005 10811 15378 Open 3/16/2005 11354 14272 Open 6/10/2005 11354 14272 Open 6/10/2005 10811 15378 Open 6/14/2005 10811 15378 Open 6/14/2005 1 0840 15443 Received Sample Set Number Comments Comments IIFR . MWD IIFR PB 1 MWD PB 1 GRlEWR4/ROP/PWD/MW D-PB 1 GRlEWR4/ROP/PWD/MW D GRlEWR4/ROP/PWD/MW D GR/EWR4/ROP/PWD/MW D MWD: GR/EWR4/ROP/PWD-PB 1 MWD: GR/EWR4/ROP/PWD-PB 1 MWD: GR/EWR4/ROP/PWD MWD: GR/EWR4/ROP/PWD ROP DGR EWR plus Graphics / PB 1 11385- 14340 ROP DGR EWR plus Graphics . Permit to Drill 2042030 MD 15443 TVD 9074 ADDITIONAL INFORMATION Well Cored? Y (f8, Chips Received? ~ Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. PRUDHOE BAY UNIT Z-13A Operator BP EXPLORATION (ALASKA) INC Completion Date 12/13/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? ~/N (j1N Formation Tops Jk Date: API No. 50-029-22069-01-00 UIC N / 0 ~)~ ,U)--o -- . e - WELL LOG TRANSMITTAL 2D<I- 203 A ~~ ~.~.o~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 ..- ISld~ RE: MWD Formation Evaluation Logs Z-13A + PB1, 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 Z-13A + PBl: LAS Data & Digital Log hnages: SO-029-21559-01,70 S-o _ o,,'\-lÁ.~ (a "I-o\) c CD Rom Mo~ ¡9-{ t1'òl (Jo . . ;;2{) '-f -- Zo ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 25, 2005 RE: MWD Formation Evaluation Logs: Z-13A PB1, AK-MW-3369825 1 LDWG formatted Disc with verification listing. API#: 50-029-20069-70 PLEASE ACKNOWLEDGE RECEWf BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETfER TO THE AITENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date icf ~ . v~UI ~ 203 . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 25, 2005 RE: MWD Formation Evaluation Logs: Z-13A, AK-MW-3369825 1 LDWG formatted Disc with verification listing. API#: 50-029-20069-01 PLEASE ACKNOWLEDGE RECEIYf BY SIGNING AND RETURNING A COpy OF THE TRANSMIIT AL LEITER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Jfvþ( I _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 'j" h I' J:nh ",... .,' !:i"" Revi~,G2M4Itis;:SPðnmÞ~ Önli¡! 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD DIR I GR I RES I PWD, MWD DIR I GR I RES CASING, LINER AND CEMENTING RECORD SETTING DEPTHMD SETTING DEPTH TVO HOL.E lOP BoTTOM TOp BoTTOM SIZE Surface 110' Surface 110' Surface 2673' Surface 2673' Surface 10840' Surface 7901' 10688' 12236' 7810' 8752' 12075' 15441' 8653' 9074' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 981' SNL, 3132' WEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 353' NSL, 999' WEL, SEC. 07, T11 N, R12E, UM Total Depth: 125' NSL, 1773' EWL, SEC. 08, T11 N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599545 y- 5959100, Zone- ASP4 TPI: x- 601564 y- 5965740 Zone- ASP4 Total Depth: x- 604340 y- 5965551 Zone- ASP4 ----------- 18. Directional Survey IBI Yes 0 No 22. CASING SIZE WT. PER FT. GRADE 20" 10-3/4" 7-518" 5-1/2" 3-1/2" 45.5# 29.7# 15.5# 9.2# L-80 L-80 L-80 13Cr80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 13850' - 13980' 8941' - 8947' 14060' -14180' 8954' - 8958' 14220' - 14630' 8960' - 8990' 14690' - 14735' 8997' - 9003' 15140' - 15230' 9034' - 9043' 15300' - 15340' 9053' - 9059' 26. Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR 2/5/2005 4 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 300 1,500 24-HoUR RATE One Other 5. Date Comp., Susp., or Aband. 12/13/2004 6. Date Spudded 11/5/2004 7. Date T.D. Reached 12/512004 8. KB Elevation (ft): 82.76' 9. Plug Back Depth (MD+ TVD) 15374 + 9063 10. Total Depth (MD+TVD) 15443 + 9074 11. Depth where SSSV set (Nipple) 2214' MD 19. Water depth, if offshore NIA MSL 13-1/2" 9-718" 6-3/4" 4-3/4" 24. SIZE 3-1/2",9.2#, 13Cr80 1 b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-203 13. API Number 50- 029-22069-01-00 14. Well Name and Number: PBU Z-13A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 047450 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD AMOUNT PUL.lED 1999 cu ft Permafrost 1931 cu ft Class 'G' 225 cu ft Class 'G' 191 cu ft Class 'G' DEPTH SET (MD) 12083' PACKER SET (MD) 12022' 25. ACID,FRACTUR¡:, (:;EMENTSQ!J¡:¡:ZE,ETO. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 93 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-Bsl GAs-McF WATER-Bsl 306 267 84 OIL-Bsl 1,835 GAs-McF 1,603 WATER-Bsl 504 CHOKE SIZE I GAS-OIL RATIO 1760 874 all GRAVITY-API (CORR) 26.5 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 1 0-407 Revised 12/2003 RBDMS BFl FEB 1 7 2005 CONTINUED ON REVERSE SIDE (yF ~ GEOLOGIC MARKER. 28.}- 1" NAME MD TVD Sag River 12235' 8751' Shublik A 12286' 8783' Shublik B 12380' 8842' Shublik C 12415' 8864' Shublik D 12447' 8883' Eileen 12455' 8887' Sadlerochit 12497' 8910' 29. .RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.!V\Ì...L ~ Title Technical Assistant Date O'J..-/lL[{ QCÇ' PBU Z -13A 204-203 Prepared By NameINumber: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Ken Allen, 564-4366 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~. . STATE OF ALASKA . ALAS IL AND GAS CONSERVATION CO . SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 12/13/2004 6. Date Spudded 11/5/2004 7. Date T.D. Reached 12/512004 8. KB Elevation (ft): 82.76' 21. Logs Run: MWD DIR I GR I RES I PWD, MWD DIR I GR I RES CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLl: ·IOP BoTTOM ·IOP BoTTOM SIZE Surface 110' Surface 110' Surface 2673' Surface 2673' Surface 10840' Surface 7901' 10688' '12236' 7810' 8752' 12075' 15441' 8653' 9074' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 981' SNL, 3132' WEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 353' NSL, 999' WEL, SEC. 07, T11 N, R12E, UM Total Depth: 125' NSL, 1773' EWL, SEC. 08, T11 N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599545 y- 5959100 Zone- ASP4 TPI: x- 601564 y- 5965740 Zone- ASP4 Total Depth: x- 604340 y- 5965551 Zone- ASP4 -----------~-+~- ._--------------~ ------------- 18. Directional Survey 1m Yes 0 No No. of Completions 22. CASING SIZE 20" 10-314" 7-5/8" 5-1/2" 3-1/2" WT. PER FT. GIW>E 45.5# 29.7# 15.5# 9.2# L-80 L-80 L-80 13Cr80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4spf MD TVD MD TVD 13850' - 13980' 8941' - 8947' 14060' - 14180' 8954' - 8958' 14220' - 14630' 8960' - 8990' 14690' - 14735' 8997' - 9003' 15140' - 15230' 9034' - 9043' 15300' - 15340' 9053' - 9059' 9. Plug Back Depth (MD+ TVD) 15374 + 9063 10. Total Depth (MD+ TVD) 15443 + 9074 11. Depth where SSSV set (Nipple) 2214' MD 19. Water depth, if offshore NI A MSL 13-1/2" 9-718" 6-3/4" 4-3/4" 24. SIZE 3-1/2",9.2#,13Cr80 1b. Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-203 13. API Number 50- 029-22069-01-00 14. Well Name and Number: PBU Z-13A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. P~~s~ation: t~" \JtL:P'~ 17. Lan~ !,Js~perrrt1t:1P ;',.,: D ""L!¡/IJ 1 8 '." "', ... ¿U.(}1 " ~·¡7~~. :I,SS of Permati'ost t~~(~prox.) ;;.j . ~ ~r:}"n"" " ~;iÙSl{}lJ CEMENTING RECORD AMOUNT PULLED 1999 cu ft Permafrost 1931 cu ft Class 'G' 225 cu ft Class 'G' 191 cu ft Class 'G' TUBING RECORD DEPTH SET (MD) 12083' PACKER SET (MD) 12022' 25. ACID, FRACTURE:, CEME.NTSaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 93 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-BBl GAs-McF WATER-BBl GAs-McF WATER-BBl 26. Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + 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). Submit core chips; if none, state "none". Oil -BBl None ,J .'_ (·'i';..,;.-., 1~1k~ I, ~ ! Form 10-4~~'¡2/2003 CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) RBDMS BFL .JAN 2 4 2005 CONTINUED ON REVERSE SIDE '.f :.... 2B. GEOLOGIC MARK. NAME MD TVD Sag River 12235' 8751' Shublik A 12286' 8783' Shublik B 12380' 8842' Shublik C 12415' 8864' Shublik D 12447' 8883' Eileen 12455' 8887' Sadlerochit 12497' 8910' 29. .FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~o ^'\ : if L.J (J 1 # ~ Terrie Hubble ~ I {lJ \I ""f', ~ PBU Z-13A 204-203 Well Number Title Technical Assistant Date 0 l · l7.. OS Permit No. I Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Ken Allen, 564-4366 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 18: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only . . :;;; "- õ; õ; Õ) Õ) "' C> 0.. 0.. 0.. 0.. 0 .s, 0.. .s, .s, ~ 0 0 " C') " If) 0 If) 0 0 C\À C\À ó 0 0 ¡¡; '" ij ( ) ë æ '¡¡¡ '¡¡¡ .¡¡¡ .¡¡¡ .s, .s, .s, .s, <D 0> " (õ C') C') If) C') lC! If) u) "'" u) -<i .¡¡¡ '¡¡¡ .¡¡¡ '¡¡¡ .s, .s, .s, .s, If) <X) 0 C\J If) C\J C\J "'" LJ') " LJ') " Õ) Õ) Õ) Õ) 0.. 0.. 0.. 0.. .s, .s, .s, .s, 0 0 0 0 "! "'" ~ "'" ~ ex) ~ ex) ~ ~ g - g g 0 0 0 0 ex) ("j ó ("j ~ C') 0 If) C\J " 0> ". as as r...:- OO g g g g 0 0 0 0 Lri Lri Ó ex) 0> "'" "'" If) C'). C\J <X) C\J ~ C\Î å C\Î ~ ~ ('I) ('I) T- T- I I N N å> l- I- E l- I- å> ('¡ ¡¡: ¡¡: ¡¡: ¡¡: E z ('¡ c: Z 0 g "'" "'" "'" E 0 0 0 ëij 0 0 E 0 ~ ~ 0 C> ~ C\J Q) 0 ~ ~ "'" C\¡ ~ ~ C\¡ -I Ü ~ -- ~ ~ ~ ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 10/31/2004 18:00 - 20:00 2.00 MOB P PRE Rig down on 2-210i. Disconnect all lines to pits. 20:00 - 00:00 4.00 MOB P PRE PJSM wI Peak Pusher & driver. Pull out pit module. Pull sub off 2-210i. Spread herculite on 2-13. Spot Sub over 2-13. 11/1/2004 00:00 - 03:00 3.00 MOB P PRE Spot Pit Complex, Hook up inter-connect - all hoses & lines. Begin taking on warm seawater. ACCEPT RIG @ 03:00 HRS, 11/01/2004. 03:00 - 06:00 3.00 RIGU P PRE Continue rigging up and taking on seawater and fresh water. Spot Camp, Shop & Cuttings tank. Check Tree - 80 psi on IA. Notify Pad Operator, secure bleed trailer & bleed pressure. Hook up circulating lines to tree and cuttings tank in preparation for circulating out diesel freeze protect. 06:00 - 07:00 1.00 WHSUR P DECOMP R/U DSM Lubricator & pull BPV - '0' psi. RID DSM Lubricator. 07:00 - 09:30 2.50 CLEAN P DECOMP Pump seawater down annulus and displace 20 bbls diesel from tubing, Switch hoses and pump warm seawater, treated with one drum of surfactant, down tubing and displace 75 bbls I diesel from annulus, Circulate surfactant to surface with clean seawater. 09:30 - 10:00 0.50 WHSUR P DECOMP Set TW C and test from below to 1000 psi. 10:00 - 10:30 0.50 WHSUR P DECOMP Pre Spud Meeting with Crew & Service Personell. 10:30 - 11 :30 1.00 WHSUR P DECOMP N/D Tree & Adapter Flange. Check Hanger threads - excellent shape. 11 :30 - 13:30 2.00 BOPSUP P DECOMP N/U BOPE - Pre Spud Meeting with 2nd Crew. 13:30 - 18:30 5.00 BOPSUR P DECOMP Test BOPE to 250 psi Low & 3500 psi High as per AOGCC Permit to Drill. Witness of test waived by John Crisp, AOGCC. 18:30 - 19:30 1.00 WHSUR P DECOMP RlU DSM Lubricator & pull TWC. RID DSM. 19:30 - 20:45 1.25 FISH P DECOMP R/U to pull 3.5" tubing. Install 4" elevators. M/U XO to Jt of 4" DP. Screw into Hanger & screw in Top Drive. B.O.L.D.S. 20:45 - 21 :30 0.75 FISH P DECOMP Pull Hanger to Floor with 120 K up weight. Break circulation & pump 20 bbls seawater to insure annulus clean. Pump slug. 21 :30 - 21 :45 0.25 FISH P DECOMP R/U Cameo control line spooler. UD Hanger. RlU 3.5" YC elevators. 21 :45 - 22:00 0.25 FISH P DECOMP PJSM with Co Rep, Rig Crew, TP and Camco. 22:00 - 00:00 2.00 FISH P DECOMP POH with 3.5" Completion String; laying down same. 11/2/2004 00:00 - 11 :00 11.00 FISH P DECOMP Continue POH, Laying Down 3.5" Completion String. Total 361 Jts, 15.29' stub, Dual control line with 33 rubber clamps & 2 steel bands. 11 :00 - 11 :30 0.50 FISH P DECOMP Rig down tubing handling equipment. 11 :30 - 15:00 3.50 CLEAN P DECOMP RlU Schlumberger E-Line. RIH with 6.75 Gauge Ring & Junk Basket. Stopped @ 9,970'. Attempt to work down - no success. POH with tools and RID E-Line. 15:00 - 16:30 1.50 CLEAN P DECOMP P/U & M/U Cleanout BHA with 7 5/8" Casing Scraper and 6 3/4" Upper string mill. 16:30 - 23:15 6.75 CLEAN P DECOMP RIH picking up 246 Jts of 4" drill pipe from shed. 23:15 - 00:00 0.75 CLEAN P DECOMP Continue RIH running stands from derrick 11/3/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP RIH with stands from derrick & tag stub @ 11,533 (Drillers Depth). Saw nothing at 9,970'. 01 :00 - 02:00 1.00 CLEAN P DECOMP Circulate 50 Bbl Hi-Vis sweep with one drum of EMI 920 Lubricant added. Torque @ 4000 rotating @ 100 RPM. Circulating @ 550 GPM / 2900 psi. No discernible solids came back with sweep. 02:00 - 06:15 4.25 CLEAN P DECOMP POH with Cleanout string to BHA. Stand back HWDP, Jars & DC's. Lay down scraper mill & bit. 06:15 - 07:45 1.50 CLEAN P DECOMP POH w/ BHA. Stand back HWDP & DC's. Lay down Jars, Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 120/2004 11/3/2004 06:15 - 07:45 1.50 CLEAN P DECOMP scraper, mill & bit. Clear Floor. 107:45 - 09:00 1 .25 CLEAN P DECOMP Service and change oil & filter in Top Drive. 109:00 - 14:00 5,00 DHB P DECOMP R/U SWS E-Line RIH with Halliburton 7 5/8" EZSV. Correlate to Collar & set EZSV 5' above @ 11,412'. POH w/ e-line & R/D 114:00 - 15:00 SWS. 1.00 DHB P DECOMP R/U Chart recorder. Pressure test Casing & BP to 3500 psi. Hold & chart for 30 minutes. RID test equipment. 15:00 - 18:45 3.75 STWHIP P WEXIT M/U 6 3/4" Whipstock / Milling Assembly. Orient to MWD & up-load same. M/U & RIH w/ DC's & HWDP. Shallow test MWD - OK, 18:45 - 00:00 5.25 STWHIP P WEXIT RIH w/ Whipstock I Milling Assembly @ 2 minutes per stand, filling every 30 stands. 11/4/2004 00:00 - 02:15 2.25 STWHIP P WEXIT Continue RIH w/ Whipstock to 11,355'. 02: 15 - 03:00 0.75 STWHIP P WEXIT Orient Whipstock to 83 Degrees Right. Tag EZSV @ 11,404' (Driller's Depth) , Set Anchor with 14K down weight. Shear Whipstock with 33K down weight. Insure free rotation: 40 RPM @ 4K Torque, TOW will be 11,385' 03:00 - 04:00 1.00 STWHIP P WEXIT Pump Spacer & Displace Well to 11.2 ppg. LSND Mud. Perform SPR's with both pumps. 104:00-10:00 6.00 STWHIP P WEXIT Mill window from 11,385' to 11,397'. Continue milling open I hole for FIT requirment to 11,411'. 320 to 340 GPM, 75 to 120 I RPM Torque = 4K to 8K, Total of 227 Lbs steel cuttings I recovered. 110:00 - 11 :00 1.00 STWHIP P WEXIT Circulate 50 Bbl. weighted "Super Sweep" Work mills through I window several times, 111 :00 - 11 :30 0.50 STWHIP P WEXIT Perform Formation Integrity Test. TVD of 8,218' + 11.2 ppg ! Mud + 555 psi Surface Pressure = FIT of 12.5 ppg EMW. 11 :30 - 16:00 4.50 STWHIP P WEXIT POH standing back 4" DP, 16:00 - 18:15 2.25 STWHIP P WEXIT UD DC's, Down load MWD, UD Mills. Upper string mill - in gauge. 18:15 - 19:00 0.75 STWHIP P WEXIT P/U BOP Jetting Tool on Jt. of DP. Function and wash out BOP stack. UD Jetting Tool. 19:00 - 19:45 0.75 STWHIP P WEXIT Service Top Drive - Change out Gripper Dies. 19:45-22:15 2.50 STWHIP P WEXIT P/U 7,5" Directional Drilling BHA. Up-Load MWD & Shallow test-OK, M/U 6.5" X 7,5" Bi-Center Bit. 22: 15 - 00:00 1.75 STWHIP P WEXIT RIH on 4" DP out of Derrick filling pipe with fill line on floor to avoid bit rotation. 11/5/2004 00:00 - 03: 15 3.25 STWHIP P WEXIT RIH to 11,355' 03:15 - 03:45 0.50 STWHIP P WEXIT R/U Blower Hose. Fill Pipe. 03:45 - 05:30 1.75 STWHIP P WEXIT Slide through window, without pumps, to 11,405'. Break circulation & bring pumps up to 340 GPM 13050 psi. Orient & ream old hole to 11,411'. Bit grabbing often and stalling motor. 05:30 - 14:00 8.50 DRILL P LNR1 Directional Drill 7 1/2" Hole from 11,411' to 11,643'. 362 GPM @ 3575 psi., Torque = 6.5K - On & 5K Off Bottom. RPM = 60, P/U Wt. = 170K, Dn. Wt. = 138K, ROT Wt. = 150K Calculated ECD = 12.3 ppg. Actual ECD = 12.4 ppg. AST = 2.76 Hrs., ART = 1,5 Hrs. Unable to slide in Kingak with Bi-Center Bit. 14:00 - 14:45 0.75 DRILL P LNR1 Circulate Bottoms Up. 365 GPM @ 3280 psi. Rotate @ 40 RPM to insure no MWD nor Motor damage from spikes.. 14:45 - 20:00 5.25 DRILL P LNR1 POH to BHA. 20:00 - 21 :30 1.50 DRILL P LNR1 POH wI BHA. B/O 6,5" X 7.5" Bi-Center PDC Bit. The Bi-center bit showed no damage or wear whatsoever. M/U Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/1 3/2004 Spud Date: 7/27/1990 End: 12/7/2004 11/5/2004 20:00 - 21 :30 1,50 DRILL P LNR1 6.75" used Hycalog DSX 146, PDC Bit. 21 :30 - 00:00 2.50 DRILL P LNR1 RIH to 6,470'. 11/6/2004 00:00 - 02:00 2.00 DRILL P LNR1 RIH to 11,164', 02:00 - 03:30 1.50 DRILL P LNR1 Service Top Drive & Crown, Change oil in Top Drive. Cut & Slip Drilling Line. 03:30 - 04:00 0.50 DRILL P LNR1 RIH to 11,546'. Precautionary wash last stand to bottom @ 11,643. No problems on trip, 04:00 - 12:15 8.25 DRILL P LNR1 Directional Drill 6 3/4" Hole from 11,643' to 12,236'. 352 GPM @ 3310 psi., Torque = 6,5K Off Btm & 7.5K On Btm P/U Wt. = 180K, Dn. Wt. = 140K, ROT Wt. = 140K, RPM = 70 to 80, Calculated ECD = 12,3 ppg, Actual ECD = 12.43 ppg. 12:15-13:15 1,00 DRILL P LNR1 Circulate Bottoms Up for samples at Geologist request 13:15 - 13:30 0.25 DRILL P LNR1 Directional Drill 63/4" Hole from 12,236' to 12,245' - TD per Geologist. 352 GPM @ 3310 psi., Torque = 6.5K Off Btm & 7.5K On Btm P/U Wt. = 180K, Dn. WI. = 140K, ROT Wt. = 140K, RPM = 70 to 80, Calculated ECD = 12.3 ppg. Actual ECD = 12.43 ppg. Daily: AST = 2,81 Hrs. ART = 3.12 Hrs. 13:30 - 14:30 1.00 DRILL P LNR1 Circulate Hi-Vis Sweep to surface, 360 GPM / 3225 psi, 80 RPM. 14:30-15:15 0.75 DRILL P LNR1 Wipe hole to Window, No drag. 15:15 - 16:00 0.75 DRILL P LNR1 Service top Drive & Crown. 16:00 - 16:30 0.50 DRILL P LNR1 RIH to 12,216'. No Problems. Precautionary wash to 12,245'- No Fill. 16:30 - 18:00 1.50 DRILL P LNR1 Circulate Hi-Vis Sweep. Spot Lube Pill across open hole. 18:00 - 23:00 5.00 DRILL P LNR1 Drop Rabbit with tail. POH to Window. Hole Slick. Pump slug. POH to BHA. 23:00 - 00:00 1,00 DRILL P LNR1 POH w/ HWDP 11/7/2004 00:00 - 01 :15 1.25 DRILL P LNR1 Flush BHA with water. UD Flex DC's & XO. 01:15 - 01:45 0.50 DRILL P LNR1 Down Load MWD. 01 :45 - 02:30 0.75 DRILL P LNR1 UD MWD, Motor & Bit. 02:30 - 03:00 0.50 CASE P LNR1 R/U to run 5.5" Liner. 03:00 - 03: 15 0.25 CASE P LNR1 PJSM w/ Co Rep. TP, Crew. Casing Hand & Baker Rep. 03:15 - 05:00 I 1.75 CASE P LNR1 Run 24 Jts, 5.5", 15.5#, L-80, BTC-M Liner. Check Floats after 3rd Jt. - OK. Fill every Jt. on the run. 05:00 - 06: 15 1,25 CASE P LNR1 MIU Baker FlexLock Hanger & ZXP Packer Assemby, XO, 10' Pup Jt. and RIH on one stand of 4" DP. Circulate Liner volume. 06:15 - 13:00 6.75 CASE P LNR1 RIH with Liner on stands of 4" DP from derrick 0 11,276'. P/U I single, M/U Cmt Hd. & UD on skate. 13:00 - 14:00 I 1.00 CASE P LNR1 Circulate Bottoms Up @ 6 BPM & 1175 psi. 14:00 - 15:00 1,00 CASE P LNR1 RIH. Takig weight (20K) @ 11,955', Attempt to work down without pumps then with pumps - no success. 15:00 - 18:00 3.00 CASE N DPRB LNR1 Working pipe with pumps, attempting to go down, started to pack-off. Worked pipe and pumped out of yhe hole to 11,745'. Established good circulation - 3 BPM @ 650 psi. Attept to wash down - took weight at same spot - 11,955'. Pumped out of hole to window @ 4 BPM 1150 psi. 18:00 - 20:30 2.50 CASE N DPRB LNR1 Circulate @ 7.5 BPM - 1630 psi. Got Lube Pill back, but NO shale cuttings to surface with 2+ Bottoms up. 20:30 - 00:00 3.50 CASE N DPRB LNR1 POH w/5.5" Liner, standing back 4" DP. 11/8/2004 00:00 - 02:00 2.00 CASE N DPRB LNR1 POH w/5.5" Liner, standing back 4" DP. 02:00 - 02:30 0.50 CASE N DPRB LNR1 C/o elevators to 3.5", Pull Hgr I Pkr Assy to floor. Inspect, break-out and UD. Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 Start: Rig Release: Rig Number: 11/8/2004 RlU to LID Liner. POH & LID 24 Jts 5.5" Liner. Use rosebud to heat Shoe Track, Break out same & LID, Threads in good shape. Will re-run. 04:15 - 05:00 0.75 CASE N DPRB LNR1 RID Liner equipment. Bring stabilizers to floor. R/U to M/U 6 3/4" Clean-Out ASSY. 05:00 - 07:00 2.00 CASE N DPRB LNR1 P/U & M/U 6 3/4" Clean-Out BHA consisting of 6 3/4" Milltooth Bit, N/B Stab, DC, Stab, 5 X DC, Stab, XO, 6 X HWDP, Jars, 18X HWDP. 07:00 - 12:30 5.50 CASE N DPRB LNR1 RIH to 11,850' - No Problems. 12:30 - 14:15 I 1.75 CASE N DPRB LNR1 Ream from 11,850' to TD @ 11.245', Saw 1 attempted for hole I to pack-off @ 12,020, Backed pump back from 350 to 325 and continued reaming' to 12,075'. Pumps back to normal - 325 GPM @ 2150 psi. Rotate @ 120 RPM w/9K Torque. 14:15 - 16:00 1.75 CASE N DPRB LNR1 Circulate Hi-Vis Sweep, 350 GPM @ 2390 psi & 80 RPM. Some shale cuttings over shaker - Hole not sloughing. 16:00-17:15 1.25 CASE N DPRB LNR1 POH to 11,550' - Top Stabilizer tight through Window. Broke circulation cleaned up stab and went through with no problem. 17:15-17:45 0.50 CASE P LNR1 Service Top Drive, 17:45 - 18:00 0,25 CASE N DPRB LNR1 RIH to 12,233'. Precautionary wash to 12,245'. No Fill nor problems. 18:00 - 20:00 2,00 CASE N DPRB LNR1 Circulate Hi-Vis sweep, Very few cuttings over shaker. Hole clean. Spot Lube Pill across open Hole. 20:00 - 00:00 4.00 CASE N DPRB LNR1 POH to window, No Problems. Pump Slug. POH to 1,912' 11/9/2004 00:00 - 00:30 0.50 CASE N DPRB LNR1 POH to BHA. 00:30 - 02:00 1,50 CASE N DPRB LNR1 Stand back HWDP, LID Jars, XO & Stab, C/O elevators & 02:00 - 02:30 I Stand back DC's & LID Stabs & Bit. 0,50 CASE N DPRB LNR1 RlU to Re-run 5.5" Liner. 02:30 - 03:45 1.25 CASE N DPRB LNR1 Run 24 Jts of 5.5",15,5#, L-80, BTC-M Liner. Bakerloc 1st 3 Jts. 03:45 - 04:30 0,75 CASE N DPRB LNR1 P/U & M/U Baker 5.5" X 7,625" FlexLock Hanger + ZXP Packer Assembly. C/O Elevators, P/U & M/U Pup Jts & Single. Circulate Liner volume. 04:30 - 10:45 6.25 CASE N DPRB LNR1 RIH with Liner on HWDP & DP to 11,263', fill every 5 stds. 10:45 - 11 :00 0.25 CASE N DPRB LNR1 Make up Baker cement head on single of DP. 11 :00 - 12:00 1.00 CASE N DPRB LNR1 Circulate bottoms up stage pumps up to 6 bpm, 1215 psi. 12:00 - 13:00 1.00 CASE N DPRB LNR1 RIH with Liner on HWDP & DP to 12,245', pickup cement head 13:00 - 14:00 1.00 CEMT P LNR1 Circulate bottoms up @ 5 bpm, 1270 psi, held PJSM with Co Rep, Toolpusher, Cementers, 14:00 - 15:30 1,50 CEMT P LNR1 Pumped 5 bbls Mudpush and tested lines to 4,000 psi, pump 15 bbls 12.2 ppg mud push @ 4.5 bpm 850 psi, pumped 32 bbls 15.8 ppg Class G cement, @ 5 bpm @ 650 psi, drop plug and displace with 11.2 ppg with rig pumps, Bumped plug with calculated strokes, pressure up to 3,500 psi and held for 5 min, to set liner hanger bled off pressure and checked floats, rotated string 15 turns to the right, applied 1,000 psi picked up to expose rotating dog sub, circulate 30 bbls to clear cement, set down 50k to set ZXP packer repeat twice, continue circulating at 1 bpm.while setting packer, rotate string at 20 rpm while applying 50k on packer to confirm set. CIP @ 15:15 15:30 - 16:15 0.75 CEMT P LNR1 Circulate bottoms up at 320 gpm, 1890 psi, 3 bbls cement to surface. 16:15 - 18:30 2.25 CEMT P LNR1 Lay down cement head and displace with seawater, monitor well, pump dry job. Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 11/9/2004 18:30 - 22:30 4.00 CEMT P LNR1 POH with running tool 22:30 - 00:00 1.50 CEMT P LNR1 Lay down 4" HWDP, and liner running tool, break down cement head. 11/1 0/2004 00:00 - 00:30 0.50 CEMT P LNR1 Lay down 4 3/4" DC from derrick 00:30 - 03:00 2.50 BOPSUF P LNR1 Pull wear ring, install test plug, change top rams to 2 7/8" and test door seals to 3,500 psi, pull test plug and install wear ring. 03:00 - 07:30 4,50 DRILL P PROD1 PJSM, P/U 4 3/4" drilling BHA, per Sperry-Sun Directional driller, orient motor and MWD, pulse test MWD 07:30 - 14:30 7.00 DRILL P PROD1 RIH, picking up 115 joints 2 7/8" DP and 33 joints 2 7/8" spiral HWDP from pipe shed, fill pipe as needed. 14:30 - 15:00 I 0,50 DRILL P PROD1 Fill DP and test MWD, blow down topdrive. 15:00 - 18:00 I 3,00 DRILL P PROD1 RIH with 4" DP to 11,163', fill pipe every 20 stds. 18:00 - 19:00 . 1.00 DRILL P PROD1 Slip and cut drilling line, 19:00 - 19:30 0.50 DRILL P PROD1 Service Rig and topdrive. 19:30 -19:45 0.25 DRILL P PROD1 RIH from 11,163' tag cement at 12,115' 19:45 - 20:15 0,50 DRILL P PROD1 Make up topdrive, clean out cement from 12,115' to 12,120', up wt = 160k, dn wt = 135k, st wt = 145k, 145 gpm, 2510 psi., 30 rpm, torque 3.5k. 20:15 - 21:30 1.25 DRILL P PROD1 Rig up test equipment, and test casing to 3,500 psi for 30 min. record on chart. 21 :30 - 23:00 1.50 DRILL P PROD1 Drill cement and float equipment from 12,120' to 12,230' up wt = 165k, dn wt = 140k, st wt = 150k, 145 gpm, 2510 psi., 30 rpm, torque 3.5k. 23:00 - 00:00 1,00 DRILL P PROD1 Pump EP mud lube pill and displace well to 8.4 ppg Flo-Pro mud @ 149 gpm, 1790 psi, rotating string at 30 rpm. 11/11/2004 00:00 - 01 :30 1,50 DRILL P PROD1 Displace well to 8.4 ppg Flo-Pro mud @ 149 gpm, 1830 psi, rotating string at 30 rpm, reciprocating pipe 60' 01 :30 - 02:00 0,50 DRILL P PROD1 Drill shoe and 20' of new hole to 12,265' 02:00 - 03:00 1.00 DRILL P PROD1 Pull back to 12,216', rig up and perform FIT, 12,245' md ,8733' tvd, mud wt. 8.4 ppg, pressure achieved 727 psi, EMW 10.0 ppg. Blow down lines, rig down test equipment. 03:00 - 05:00 2.00 DRILL P PROD1 Directional drill 4.75' hole from 12,265' to 12,270, by sliding wob 2-5k 148 gpm 1565 psi, having detection problems with MWD, no toolface, switched pumps, cleaned suction screens, isolated pumps, reduced pressure on pulsation dampners, after reducing pressure on dampners, signal improved. 05:00 - 12:00 7.00 DRILL P PROD1 Directional drill 4,75' hole from 12,270' to 12,455, with fractional sliding to achieve required build rates, wob 2-7k 148 gpm, 2070 psi on bottom, 1800 psi off bottom, 40 rpm, torque on bottom 4k, torque off bottom 3.5k, up wt = 165k, dn wt = 145k, rt wt = 155k, AST = 2.42 ART = 2.82 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill 4.75' hole from 12,455' to 12,820', wob 2-7k 148 gpm, 2210 psi on bottom, 2000 psi off bottom, 40 rpm, torque on bottom 4.5k, torque off bottom 4k, up wt = 175k, dn wt = 143k, rt wt = 158k, AST = 4.53 ART = 2.52 11/12/2004 00:00 - 12:00 12,00 DRILL P PROD1 Directional drill 4.75' hole from 12,820' to 13,124', wob 2-10k 148 gpm, 2260 psi on bottom, 2060 psi off bottom, 40 rpm, torque on bottom 5k, torque off bottom 4.5k, up wt = 175k, dn wt = 140k, rt wt = 158k, Pumped 20 bbl high vis sweep, 2.5 ppb beads, 1.5 ppb nut plug at 12,970' ART = 4.53 AST = 3.75 Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 11112/2004 00:00 - 12:00 12,00 DRILL P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill 4.75' hole from 13,124' to 13,465', wob 4-12k 148 gpm, 2340 psi on bottom, 2160 psi off bottom, 40 rpm, torque on bottom 5k, torque off bottom 4k, up wt = 180k, dn wt = 140k, rt wt = 160k, ART = 3.46 AST = 2.7 11/13/2004 00:00 - 06:00 6.00 I DRILL P PROD1 Directional drill 4.75' hole from 13,465' to 13,794', wob 10-12k I 150 gpm, 2420 psi on bottom, 2200 psi off bottom, 40 rpm, torque on bottom 5k, torque off bottom 4k, up wt = 183k, dn wt = 145k, rt wt = 160k, ART = 4.69 AST = 2.5 06:00 - 00:00 18.00 DRILL P PROD1 Directional drill 4.75' hole from 13,794' to 14,034', wob 10-12k 150 gpm, 2420 psi on bottom, 2150 psi off bottom, 40 rpm, torque on bottom 5k, torque off bottom 4k, up wt = 185k, dn wt = 145k, rt wt = 160k, Pumped two 20 bbl high vis, lube sweeps at 13,840' - 14,034' to enhance sliding and hole cleaning, no visible increase in cuttings when sweeps came back, ART = 2.88 AST = 3.47 11/14/2004 00:00 - 12:15 12,25 DRILL P PROD1 Directional drill 4.75' hole from 14,034' to 14,340', wob 10-12k 150 gpm, 2550 psi on bottom, 2250 psi off bottom, 40 rpm, torque on bottom 5.5k, torque off bottom 4,5k, up wt = 185k, dn wt = 145k, rt wt = 160k, Pumped 20 bbl high vis, lube and bead sweep at 14,147' to enhance sliding. Sliding becoming more difficult, no weight transfer, having to ream back to bottom after slides, torque increasing and stalling topdrive when reaming back to bottom. ART = 1.99 AST = 2.81 12:15 - 13:30 1.25 DRILL P PROD1 Pump 20 bbl high vis sweep, circulate hole clean. pumping 150 gpm at 2230 psi, no increase in cuttings when sweep came back. 13:30 - 16:00 2.50 DRILL P PROD1 Monitor well, pump out to 12,216', no hole problems encountered while pulling out. 16:00 - 16:30 0,50 DRILL P PROD1 Drop ball, to open circ sub. 16:30 - 18:15 1.75 DRILL P PROD1 Slip and cut 934' of drilling line, 18:15 - 19:00 0.75 DRILL P PROD1 Pump out to 5.5" liner top at drilling rate, keeping cuttings moving up hole, position circ sub at liner top. 19:00 - 21 :00 2,00 DRILL P PROD1 Pump 20 bbl high vis sweep at 300 gpm, 2200 psi rotating string at 40 rpm, reciprocating string 90', saw no increase in cuttings at bottoms up. Monitor well, pump dry job, 21 :00 - 00:00 3.00 DRILL P PROD1 POH to BHA, monitor well. 11/15/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Rig up 2 7/8' power tongs and handling equipment. 01 :00 - 04:00 3.00 DRILL P PROD1 Rack back 11 stands 2 7/8" spiral HWDP, 38 stands 2 7/8" DP 04:00 - 07:00 3.00 DRILL P PROD1 Lay down jars, bumper sub and flex collars, connection between DM HOC and stabalizer twisted off, left bit, motor,float sub and stabalizer in the hole. Down load MWD, lay down MWD. 07:00 - 07:30 0.50 BOPSUF P PROD1 Pull wear ring and install test plug, rig up BOP test equipment. 07:30 - 15:30 8.00 BOPSUF P PROD1 Test BOP to 250 psi low, 3,500 psi high as per rig testing procedure, Chuck Scheve waived witness of BOP test. 15:30 - 22:00 6.50 BOPSUF N RREP PROD1 Change out Hydrill packing element, test Hydrill to 250psi low, 3,500 psi high. rig down testing equipment, pull test plug and install wear ring. 22:00 - 00:00 2.00 DRILL N RREP PROD1 Nabors waiting on weather, unable to change out electric brake Printed: 12/16/2004 4:01:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 11/15/2004 22:00 - 00:00 2,00 DRILL N RREP PROD1 on draw works due to high winds, current wind speed 27-32 IRREP IpROD1 mph. Peak requires winds of less than 20 mph prior to making IN any crane picks. Clean rig, Service topdrive. 11/16/2004 00:00 - 10:00 10.00 DRILL Nabors waiting on crane to change out electric brake on draw works. Clean rig, inspect derrick, PM inspection in mud pits, service pipe skate. 10:00 - 22:30 12.50 DRILL N RREP PROD1 Spot crane, PJSM with Peak crane operator and rig crew, I remove wind wall, remove electric brake from draw works, change out hub on brake, install new brake and test. 22:30 . 00:00 1.50 DRILL N DFAL PROD1 Bring fishing tools to rig floor, held PJSM with Baker Rep and rig crew, pickup fishing assembly as per Baker Rep and dierectional driller. 11/17/2004 00:00 - 08:30 8.50 FISH N DFAL PROD1 Make up 4.625" overshot, bumper sub, oil jar, 3 flex collars, cir sub, 115 jts 2 7/8" DP, 33 jts 2 7/8" spiral HWDP and RIH with fishing assembly on 4" DP to 12,092' 08:30 - 09:00 0.50 FISH N DFAL PROD1 Make up top drive and establish parameters, up WI = 150k, do WI = 130k, torque @ 30 rpm = 3500 ftIlbs, torque @ 40 rpm = 3500 ftIlbs. Pump rates 30 gpm = 378 psi, 50 gpm = 439 psi, 75 gpm = 510 psi, 100 gpm = 588 psi, 150 gpm = 855 psi. 09:00 - 10:00 1,00 FISH N DFAL PROD1 Wash from 12,092', 100 gpm @ 588 psi, tag fish at 12,236' reduce flow rate to 30 gpm, 380 psi, set down 10k had 40 psi pressure increase, pulled up 10' and increased pump rate to 50 I gpm, pressure increased to 480 psi. washed back to 12,236' set down 10k, began to wash away. 10:00 - 11:00 1,00 FISH N IDFAL PROD1 POH pumping out, @ 50 gpm, hole swabbing, swabbed all the way to 5.5" liner top @ 11,231' drag 10 to 20k, 11 :00 - 12:30 1.50 FISH N DFAL PROD1 With fishing assembly above 5.5" liner top, circulating pressure remained 40 psi higher, drop ball to open circ sub. Monitor well, shear open circ sub, and pump dry job, blow down top drive, 140 gpm @ 660 psi with circ sub open. 12:30 - 18:00 5.50 FISH N DFAL PROD1 POH with fish to 4,760' monitor well. Rig up 2 7/8" power tongs and handling equipment. 18:00 - 21 :00 3.00 FISH N DFAL PROD1 POH stand back 2 7/8 spiral HWDP and 2 7/8" DP, lay down flex collars and jars, no fish 21 :00 - 21 :30 0.50 FISH N DFAL PROD1 Inspect Baker overshot, no visible evidence of having engaged fish, guide shoe on overshot had a small amount of cuttings inside, (sticky clay and shale with small amount of sand), clean floor. 21 :30 - 00:00 2.50 FISH N DFAL PROD1 RIH with the same fishing assembly to 4,105' 11/18/2004 00:00 - 04:00 4.00 FISH N DFAL PROD1 Continue RIH with fishing assembly from 4,105' to 12,131' 04:00 - 04:30 0.50 FISH N DFAL PROD1 Make up topdrive and esatblish parameters, 50 gpm = 465 psi, 70 gpm = 550 psi, 120 gpm = 745 psi, 150 gpm = 865 psi, rotary torque @ 30 rpm = 3500 ftIlbs, up WI = 165k dn wt = 140k, rt wt = 150k 04:30 - 11 :30 7.00 FISH N DFAL PROD1 Wash from from 12,131' with 150 gpm 865 psi, at started taking weight,12,234' and packing off, reduced pump rate to 95 gpm @ 640 psi, rotate string 30 rpm 3500 ftIlbs, Continued washing and reaming, adjusting pump rate and rpm, hole conditions getting worse, packing off and torque increasing, washed to 12,545' 11:30-14:30 3.00 FISH N DFAL PROD1 POH, pump out from 12,545' to 11,220', pumping 40 gpm @ 460 psi, hole packing off and swabbing, had 10-20k excess drag all the way to the 5.5" liner top. Printed: 12/16/2004 4:01:12 PM Legal Well Name: Z-13 Common Well Name: Z-13 Spud Date: 7/27/1990 Event Name: REENTER+COMPLETE Start: 10/27/2004 End: 12/7/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/13/2004 Rig Name: NABORS 7ES Rig Number: Phase 11/18/2004 14:30 - 15:00 0.50 FISH N DFAL PROD1 Monitor well, pump dry job, blow down topdrive. 15:00 - 17:30 2.50 FISH N DFAL PROD1 POH to 2 7/8" DP, monitor well. 17:30 - 21 :30 4.00 FISH N DFAL PROD1 POH, lay down flex collars, jar and bumper sub, no fish. Mandrel on jars and bumper sub were packed off with formation, the carbide on the gage of the guide shoe showed evidence of normal wear, grapple showed no sign of wear. Lay down overshot. 21 :30 - 00:00 2.50 FISH N DFAL PROD1 Make up 411/16' 5 bladed MM mill, 3 flex collars, oil jar, 11/19/2004 FISH ¡ bumper sub, circ sub and RIH to 3,745' 00:00 - 03:30 3.50 N DFAL PROD1 RIH with baker 411/16" MM mill from 3,745' to 10,980' 03:30 - 04:30 1.00 FISH N DFAL PROD1 Slip and cut drilling line, adjust kick rollers and brakes and service rig. 04:30 - 05:30 1.00 FISH N DFAL PROD1 ,RIH from 10,980' to 12,230' 05:30 - 06:30 1.00 FISH N DFAL PROD1 Circulate bottoms up at 300 gpm, 2350 psi, rotate and reciprocate pipe, rotate string 30 rpm, torque 3400 ftllbs, bottoms up sample showed 90% shale. 06:30 - 12:30 6.00 FISH N DFAL PROD1 Wash and ream from 12,230', Initial flow rate 150 gpm @ 980 I psi rotating 30 rpm, started packing off, rotary torque increasing I and stalling topdrive immediately below the shoe, slowed pump rate, seeing up to 25k over pull when trying to break packoff, i took several hrs to get past the transition zone between Kingak I and Sag at 12,262' continued working string to a depth of 12:30 - 17:30 5.00 FISH N DFAL PROD1 112,806', hole packed off unable to circulate. I Pump out to 12,228' 20 -50 gpm, hole packing off, 20- 25k ,overpull, partial returns 17:30 - 20:00 2.50 FISH N DFAL PROD1 Circulate and condition mud, 300 gpm, 2300 psi rotating string 30 rpm, reciprocating pipe full stand, pump 30 bbl high vis sweep, had a 30% increase in cuttings when sweep came I back, sample showing 90% shale. 20:00 - 21 :00 1.00 FISH N DFAL PROD1 I Began washing and reaming from 12,230' trying to maintain 200 gpm 1,245 psi, rotating at 30 rpm at 12,252' hole packed off torqued up and stalled topdrive, shut down pumps bled off pressure, unable to regain circulation, Pulled back inside shoe 20-25k overpull. worked and rotated pipe to regain circulation would not circulate, pulled back to 12,153', regained circulation by applying 300 psi and slowly working and rotating string. 21:00 - 23:00 2.00 FISH N DFAL PROD1 Circulate hole clean pumping at 300 gpm, 2200 psi, rotating 30 rpm, no increase in cuttings at bottoms up, still seeing 90% shale at shakers. 23:00 - 00:00 1.00 FISH N DFAL PROD1 Drop ball to open circ sub, POH to 11,366' and position circ sub at 5.5" liner top. 11/20/2004 00:00 - 02:00 2.00 FISH N DFAL PROD1 Shear open circ sub, circulate bottoms up working circ sub through 5.5" liner top, 400 gpm, 2900 psi, rotating 30 rpm, 2800 ftllb, had a 50% increase in cuttings at bottoms up, cuttings doubled in size with some larger splinters still 90% shale. 02:00 - 11 :30 9.50 FISH N DFAL PROD1 POH to 2 7/8" spiral HW, monitor well, rig up 2 7/8" handling equipment and power tongs, lay down 33 jts, 27/8" HW, and 85 joints 2 7/8" DP, stand back 10 stds 2 7/8" DP for setting EZSV, lay down BHA 11 :30 - 12:00 0.50 FISH N DFAL PROD1 Clean floor, bring halliburton tools to rig floor. 12:00 - 13:30 1.50 FISH N DFAL PROD1 Make up Halliburton 5.5" EZSV and setting tool, Pickup 10 stds 27/8" DP. Printed: 12/16/2004 4:01:12 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 120/2004 11/20/2004 13:30 - 18:30 5.00 REMCM-N DFAL PROD1 RIH with 5.5" Halliburton EZSV on 4" DP set down 10k at 5.5" Liner top, at 11,231' 18:30 - 19:30 1.00 REMCM-N DFAL PROD1 Make up topdrive, drill string pressured up to 1680 psi EZSV plugged, worked pipe to try and establish circulation, held 1600 psi, POH 1 stand no excess drag, rig up to reverse circulate, pressured up to 1050 psi, shut down pumps pressure bleed to 945 psi and held, no circulation. 19:30 - 00:00 4.50 REMCM-N DFAL PROD1 POH with EZSV, pulled out 10 stands, 10,235' made up topdri'/e to check for circulation string pressured up, would not circulate, tryed again with 20 stands out, 9,278' no circulation, POH to 4,687' 11/21/2004 00:00 - 04:00 4.00 REMCM-N DFAL PROD1 , Check. for circulation @ 4600' would not circulate, POH to 2 7/8" DP, rig up handling equipment and power tongs, stand back 2 7/8" DP. 04:00 - 06:30 2.50 REMCM-N DFAL PROD1 Remove EZSV from setting tool, setting tool and 30' of the first joint 01' 4" DP was packed off with shale, break down setting tool and clean out, lay down bottom single of 4" DP and flush out. 06:30 - 08:00 1.50 REMCM-N DFAL PROD1 I Clean floor, service rig and topdrive 08:00 - 17:30 9.50 REMCM-N DFAL PROD1 Make up 4 3/4" Hughes STX-1 tri-cone bit, 5.5" casing scraper, 10 stds 2 7/8" DP, 75/8" casing scraper, XO, 4 3/4" drilling jars, RIH break circulation @ 5,777' and every 10 stands after to ,ensure drill string is clear, 3.5 bpm @ 325 psi RIH to 11,229' 17:30 - 18:30 1.00 REMCM-N DFAL PROD1 Began washing from 12,229' bit depth with 150 gpm, 375 psi, took weight at 11,984' bit depth, 75/8" scraper at 1 0,951' 18:30 - 21 :30 3.00 REMCM-N DFAL PROD1 Wash from 11,900' to 12,176', 450 gpm, 2350 psi, 30 rpm, torque 3600 ftIlbs, started taking weight at 11,984' 2-5K torque increased to 4300 ftIlbs, topdrive stalled out twice while reaming, torque limit set at 5000 ftIlbs. when the first bottoms up at the higher flow rate came back, saw a significant amount of calcium carbinate, with small amount of shale this cleared up followed by fine shale, the longer we pumped the larger the cutting got, tagged up on the top of the 5.5" liner with the 7 5/8" casing scraper at 11,216', Bit depth of 12,176' 21 :30 - 23:30 2.00 REMCM-N DFAL PROD1 Pump 25 bbllow vis sweep, followed by 50 bbl high vis weighted sweep (11.7 ppg), increased pump rate to 500 gpm, 2850 psi, shale coming across shakers while pumping sweep, just before the low vis sweep came over shakers, hole unloaded, the size of shale cuttings inreased, the high vis sweep brought back more calcium carbinate, with shale mixed in, cuttings began to taper off once high vis sweep was out of the hole, circulated one more complete circulation for additional clean up. 23:30 - 00:00 0.50 REMCM-N DFAL PROD1 Monitor well, pump dry job. 11/22/2004 00:00 - 06:00 6.00 REMCM-N DFAL PROD1 POH with clean out assembly, to 2 718" lay down 75/8" casing scraper, rig up handling equipment and power tongs, 06:00 - 14:30 8.50 REMCM-N DFAL PROD1 Make up 5.5' EZSV and setting tool, RIH to 5,743', break circulation, continue in hole breaking cirulation every 20 stands, no problems going through liner top, Continue in hole to 12,053', 14:30 - 15:30 1.00 REMCM-N DFAL PROD1 Make up pup joint and TIW valve, set EZSV @ 12,053' per Halliburton Rep. perform injectivity test, pressured up to 3,500 psi, bled off pressure, unsting from retainer, test retainer to Printed: 12/16/2004 4:01:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 120/2004 11/22/2004 14:30 - 15:30 1.00 REMCM-N DFAL PROD1 2,500 psi for 5 min. 15:30 - 17:30 2.00 REMCM--N DFAL PROD1 Held PJSm with Co Rep, Toolpusher, cementers and rig crew, pump 5 bbls water, test lines to 3000 psi, pump 10 bbls 15.8 ppg class G cement @ 1.5 bpm, 560 psi, pump 1.5 bbls water behind, and displace with rig @ 3 bpm 435 psi, displace with calculated strokes to balance plug, 109 bbls. CI P at 17:28 17:30 - 19:00 1.50 REMCM-N DFAL PROD1 POH with setting tool slowly to 11,096' 19:00 - 20:00 1.00 REMCM-N DFAL PROD1 Rig up and reverse circulate 150 bbls @ 170 gpm, 1350 psi. no cement to surface, dumped 15 bbls of contaminated mud with trace of cement. 20:00 - 21 :00 1.00 REMCM-N DFAL PROD1 Circulate bottoms up long way @ 300 gpm, 1300 psi. 21 :00 - 00:00 3.00 REMCM-N DFAL PROD1 Pump dry job, blow down topdrive, POH with setting tool to 4,400'. 11/23/2004 00:00 - 01 :30 1.50 REMCM-N DFAL PROD1 POH with 5 1/2" EZSV setting tool to 2 7/8" drill pipe 956' 01 :30 - 03:30 2.00 REMCM-N DFAL PROD1 POH Lay down 30 joints 2 7/8" drill pipe and Halliburton EZSV setting tool. Clear floor. 03:30 - 08:00 4.50 STWHIP N DFAL INT1 PJSM with Schlumberger. Rig up E-line unit. Make up 7 5/8" EZSV bridge plug, CCUGR RIH with EZSV, tie in and set bridge plug at 10,865', POH with running tool. Rig down E-line unit. 08:00 - 08:30 0.50 STWHIP N DFAL INT1 Test 7 5/8" EZSV bridge plug with 3500 psi. OK. 08:30 - 09:00 0.50 STWHIP N DFAL INT1 PJSM with rig crew, Sperry Sun DD and MWD tech and Baker rep on picking up Whipstock and tools. 09:00 - 21 :00 12.00 STWHIP N DFAL INT1 Make up Baker Whipstock and mills BHA. Make up MWD and shllow test same, P/U 9 DC's & 24 HWDP. RIH at 2 minutes per stand. Fill pipe every 30 stands. 21 :00 - 21 :45 0.75 STWHIP N DFAL INT1 Orient Whipstock to 83 Degrees Right. Tag EZSV @ 10,859' Drllers measurement. Set Anchor & shear Mills. 21 :45 - 23:00 1.25 STWHIP N DFAL INT1 Displace well bore to 11.3 ppg. Milling Fluid @ 300 GPM & 1900 Psi. SPR w/ both pumps. 23:00 - 00:00 1.00 STWHIP N DFAL INT1 Mill Window from 10,840 to 10,845'. 100 RPM, 350 GPM & 2400 psi. 11/24/2004 00:00 - 06:00 6.00 STWHIP N DFAL WEXIT Continue Milling Window to 10,852'. Mill Open hole from 10,852' to 10,864'. Rotating at 90 to 100 RPM. Pumping @ 350 GPM & 2450 psi. Torque = 4 to 5K. P/U Wt. = 165K, Dn Wt. = 135K, ROT WT. = 150K. 187 pounds of metal shavings recovered, Noted cement in the cuttings while milling window. 06:00 - 08:00 2.00 STWHIP N DFAL WEXIT Circulate "Super Sweep" @ 350 GPM /2450 psi. while working mills through window. 08:00 - 08:30 0.50 STWHIP N DFAL WEXIT Perform FIT, 11,3 ppg. Mud + 7900' TVD + 520 psi Surface pressure = FIT of 12.57 ppg EMW. 08:30 - 14:00 5.50 STWHIP N DFAL WEXIT POH to BHA, 14:00 - 15:30 1.50 STWHIP N DFAL WEXIT UD 9 ea DC's, MWD & Milling assy. Upper mill in-gauge. 15:30 - 17:00 1.50 STWHIP N DFAL WEXIT Pull Wear Bushing. M/U Jetting Tool & wash Steel cuttings from stack & wellhead. UD Jetting Tool & re-install wear Bushing. 17:00 - 18:45 1.75 STWHIP N DFAL WEXIT P/U & M/U 6 3/4" BHA. Up-load MWD. 18:45 - 00:00 5.25 STWHIP N DFAL WEXIT RIH one stand HWDP & surface check MWD - OK. Continue RIH to 10,686'. 11/25/2004 00:00 - 01 :00 1.00 STWHIP N DFAL WEXIT Cut & Slip Drilling Line & grease wash pipe packing on Top Drive, 01 :00 - 02:00 1.00 STWHIP N DFAL WEXIT Break circulation, Orient tool Face to 80 degrees right. Shut down pumps and slide through window with no problem. Wash Printed: 12/16/2004 4:01: 12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-13 2-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 11/25/2004 01 :00 - 02:00 1.00 STWHIP N DFAL WEXIT & ream to bottom @ 10,866', Found 3' of fill. 02:00 - 22:00 20.00 DRILL N DFAL LNR2 Directional Drill 6 3/4" Hole from 10,866' to 12,220'. 350 GPM I @ 3450 psi. Torque = 5K to 8K, Rot @ 70 to 80 RPM. P/U Wt. I = 185K, Dn, Wt. = 140K, ROT Wt. = 155K. WOB = 5 to 10K. I ECD's stayed within .04 points of calculated - 12.36 ppg. AST 122:00 - 23:00 = 4.59 Hrs. ART = 8,25 Hrs 1.00 DRILL N DFAL LNR2 Circulate bottoms up for samples at Geologist request. 123:00 - 23:10 0.17 DRILL N DFAL LNR2 Drill from 12,220' to 12,230' - same drilling parameters. 23:10 - 00:00 0.83 DRILL N DFAL LNR2 Circulate bottoms up for samples at Geologist request. 11/26/2004 00:00 - 00:15 0.25 DRILL N DFAL LNR2 Drill from 12,230' to 12,238', ROP slowing down. Drilling with same parameters. 00:15 - 01:30 1.25 DRILL N DFAL LNR2 CBU for samples at Geologist request. Samples showing sandstone, Logs correlate to Top of Sag River. Geologist called TO. 01 :30 - 03:30 2.00 DRILL N DFAL LNR2 Circulate weighted, Hi-Vis Sweep. Approx 3X cuttings when sweep at surface, Cleaned up very well. 03:30 - 05:00 1.50 DRILL N DFAL LNR2 POH to 10,780'. No excess drag & no swabbing. Hole took proper displacement. 05:00 - 12:15 7.25 BOPSUP N DFAL LNR2 Pull wear bushing, run test plug & RlU to test BOPE. Test BOPE to 250 psi. - Low & 3500 psi - High. Witness of test waived by John Crisp, AOGCC, RID test equipment. Install wear bushing. 12:15 - 13:00 0.75 DRILL N DFAL LNR2 RIH to 10,262'. encountered tight Hole. 13:00 - 14:00 1.00 DRILL N DFAL LNR2 Ream from 12,062' to 12,082', Continue RIH to bottom @ 12,238' - No Fill. 14:00 - 16:30 2.50 DRILL N DFAL LNR2 Circulate Hi-Vis weighted sweep. Spot lube pill in open hole. 16:30 - 18:30 2.00 DRILL N DFAL LNR2 POH to window @ 10,840'. No excess drag. Pump slug & drop rabbit. 18:30 - 23:15 4,75 DRILL N DFAL LNR2 POH to SHA 23:15 - 00:00 0.75 DRILL N DFAL LNR2 Stand back HWDP, UD Jars, flush MWD & Motor with water. 11/27/2004 00:00 - 01 :45 1.75 DRILL N DFAL LNR2 UD DC"s. Down Load MWD. UD MWD, Motor, Stab., Float Sub & Bit. 01 :45 - 02:30 0.75 CASE N DFAL LNR2 R/U to run 5.5" Drilling Liner. 02:30 - 04:30 2.00 CASE N DFAL LNR2 Run 37 Jts., 5.5",15.5#, L-80, BTC-M Liner, 04:30 - 05:15 0.75 CASE N DFAL LNR2 M/U Saker Flex-Lock Hanger & ZXP Liner Top Packer Assembly. RIH with one stand HWDP. Circulate one Liner volume (35 Bbls.), 05:15 - 10:30 5.25 CASE N DFAL LNR2 RIH with Liner on stands of 4" HWDP & 4" DP out of derrick to 10,696' 10:30 - 10:45 0,25 CASE N DFAL LNR2 M/U Baker cement Head on single & UD on skate. 10:45 - 12:30 1.75 CASE N DFAL LNR2 Circulate and Condition Mud. Pump @ 6 BPM & 1170 psi. PJSM with Schlumberger cementers. 12:30 - 13:30 1.00 CASE N DFAL LNR2 RIH with liner to 12,034'. No Drag. M/U Top Drive, break circulation & stage up to 3 BPM. Wash to 12,040' - Packed Off. 13:30·17:30 4.00 CASE N DFAL LNR2 Unable to regain circulation @ 12,040'. Pull out attempting circulation. Regained circulation @ 11,270' - 3.5 BPM @ 600 psi. Wash back down to 11,461 '; continuing to pack-off. Unable to make further progress. 17:30 - 23:00 5.50 CASE N DFAL LNR2 POH; standing back 4" DP & HWDP. 23:00 - 00:00 1.00 CASE N DFAL LNR2 RlU Casing equipment, Lay down Baker Hgr / Pkr Assy. 11/28/2004 00:00 - 03:00 3.00 CASE N DFAL LNR2 Lay down 37 Jts of 5.5" Liner. RID casing eqipment. Clear & clean Floor. 03:00 - 04:30 1.50 CASE N DFAL LNR2 P/U & M/U 63/4" Clean Out Assembly. RIH w/ HWDP & Jars. Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 11/28/2004 04:30 - 06:00 1.50 CASE N DFAL LNR2 Slip and Cut drilling line. Service Top drive & Crown 06:00 - 10:00 4.00 CASE N DFAL LNR2 RIH with Clean Out Assy. to 10,798' 10:00 - 11 :15 1.25 CASE N DFAL LNR2 Circulate, weighting up mud to 11.5 ppg, 11:15-16:00 4.75 CASE N DFAL LNR2 RIH to 11,145'. Taking weight. Ream from 11,145 to TD @ 12,238' with 375 GPM /2700 psi., 120 RPM wi Torque from I 7500 to 9500, WOB = 2 to 7K, Occasionaly attempting to [ pack-off. 16:00 - 18:00 2.00 CASE N DFAL LNR2 Circulate H-Vis, weighted sweep. 30% increase in cuttings. Large shale pieces sloughing off. 18:00 - 19:00 1,00 CASE N DFAL LNR2 POH to Window. 2nd stabilizer had 40K drag through window. 19:00 - 22:00 3.00 CASE N DFAL LNR2 RIH. Bit / NB Stab stopped @ window. Worked down numerous times - stopped at same spot. Circulated @ 350 GPM and rotated string ABOVE window. Stopped rotation and attempted again. Bit fell through, Ran stand in hole - 2 stabs past window, Pull up stabs and bit above window - no excess overpull at window, Attempt to go down - stopped at same point. Worked string again numerous times and again fell through. Ran one more stand to position stabs well below and above window. M/U Top drive and CBU while rotating @ 130 RPM. Definite PH spike at bottoms up (indicating cement). I Shut down pumps and pulled bit up through window. Again - no overpull. Attempt to go back down through window and stopped IN again at same spot. 22:00 - 00:00 2,00 CASE DFAL LNR2 Pump slug & POH. 11/29/2004 00:00 - 02:00 2.00 CASE N DFAL LNR2 POH With DP to BHA. 02:00 - 03:30 1,50 CASE N DFAL LNR2 Stand back HWDP, UD Stabilizers & Bit. No marks on Stabs. I i Number 1 cone on bit had 6 broken teeth, 03:30 - 05:00 1.50· CASE N DFAL LNR2 M/U Baker Whipstock Milling BHA. 05:00 - 08:45 3,75 CASE N DFAL LNR2 RIH w/ Milling Assy. to 10,828'. 08:45 - 09:15 0.50 CASE N DFAL LNR2 Service Top Drive & Crown, 09: 15 - 11 :00 1.75 CASE N DFAL LNR2 Dress Window with Mills from 10,840' to 10,852'. 350 GPM I 2450 psi., 80 RPM with 5K to 6K Torque. 11:00 -12:30 1.50 CASE N DFAL LNR2 RIH to 11,827' . Tight - Ream to 11,976' Continue RIH to 12,167. Precautionary ream to bottom @ 12,238'. 12:30 - 14:30 2,00 CASE N DFAL LNR2 Circulate Hi-Vis, weighted sweep, 360 GPM /2600 psi. 100 RPM, Torque = 6600. Spot liner ruuning pill. 14:30 - 15:30 1.00 CASE N DFAL LNR2 POH with milling assy. through window to 10,826'. 15:30 - 16:30 1.00 CASE N DFAL LNR2 Attempt to go back down through window - taking weight. Establish rotation and go through with no problem. Break circulation and dress window with mills. 16:30 - 20:30 4.00 CASE N DFAL LNR2 Pump Slug. POH to BHA. 20:30 - 21 :30 1.00 CASE N DFAL LNR2 Stand back HWDP & DC's. Lay down mills. 21 :30 - 22:00 0.50 CASE N DFAL LNR2 Clear floor & R/U to run 5.5" Liner 22:00 - 00:00 2,00 CASE N DFAL LNR2 PJSM M/U Shoe track, check floats and continue running 5.5" Liner. 11/30/2004 00:00 - 00:30 0.50 CASE N DFAL LNR2 Complete running total of 37 jts, 5.5", 15.5#, L-80, BTC-M Liner 00:30 - 01 :00 0.50 CASE N DFAL LNR2 M/U Baker FlexLock Hanger & ZXP Packer Asembly and RIH on stand of HWDP. 01:00 - 01:15 0.25 CASE N DFAL LNR2 Circulate liner volume. 01:15 - 05:45 4.50 CASE N DFAL LNR2 RIH with Liner on HWDP and DP from derrick to 10,791 '. 05:45 - 06:00 0.25 CASE N DFAL LNR2 M/U Baker Cement Head on single and UD on skate. 06:00 - 07:00 1.00 CASE N DFAL LNR2 Circulate & Condition Mud. Stage up to 6 BPM @ 1222 psi. Printed: 12/16/2004 4:01:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 DFAL LNR2 Conduct PJSM with Crew, Cementers & Baker whle circulating. 07:00 - 08:00 1.00 CASE N DFAL LNR2 RIH to 12,225'. Had to work through tight hole from 11,827' to 11,938'. 08:00 - 08:30 0.50 CASE N DFAL LNR2 R/U Cement Head & single to string & RIH to 12,238', 08:30 - 09:00 0,50 CEMT N DFAL LNR2 Break circulation, staging up pumps to 4 BPM & 985 psi. Circulate Annular volume +. 09:00 - 10:15 1.25 CEMT N DFAL LNR2 Switch to Dowell Schlumberger & pump 5 Bbls, 12,3 ppg, I MudPush II. Test lines to 3500 psi. Pump another 15 Bbls I MudPush II followed by 40 Bbls (194 sX), 15,8 ppg. Class "G" sluury with yield of 1.16 cU.ft.lsk. @ 4,5 BPM. Kick Drill Pipe Dart out with 5 Bbls water to flush lines then switch back to rig pumps and displace with 136 Bbls 11.6 ppg. Mud @ 4 BPM, Slow down to P/U liner plug and again prior to bump. Bumped wI 1390 psi. CIP 10:15 Hrs. Did not reciprocate pipe. 10:15 - 10:30 0.25 CASE N DFAL LNR2 Continue to pressure up to 3600 psi to set Flex-Lock Hanger. Set dn 10K. Bleed off pressure & check floats - OK, Rotate C-2 running too out of ZXP packer. Pull up & circulate 30 bbls. set down 60k to set ZXP Packer. Pull up and repeat with rotation. 10:30 -11:30 1.00 CASE N DFAL LNR2 Circulate Bottoms up - No Cement to surface. 11 :30 - 12:00 0.50 CEMT N DFAL LNR2 LID Cement head & single on skate, 12:00 - 13:00 1.00 CEMT N DFAL LNR2 Displace Wellbore with Seawater. 13:00 - 14:00 1.00 CEMT N DFAL LNR2 Break out Cement head from single & LID same. Pump slug & RID Casing equipment. 14:00 - 17:30 3,50 CEMT N DFAL LNR2 POH to HWDP. 17:30 - 19:00 1.50 CEMT N DFAL LNR2 POH LID HWDP & C-2 running tool. RIH w/2 stands DC's - POH LID. 19:00 - 21 :45 2.75 BOPSUP N DFAL PROD2 Pull wear bushing & set test plug. C/O top rams to 2 7/8". Run I jt. 27/8" DP & test rams to 250 psi. low & 3500 psi High. Pull test plug & install wear bushing. 21 :45 - 22:30 0.75 DRILL N DFAL PROD2 RlU to P/U 4 3/4" BHA. PJSM wi DD, MWD hand, Crew & TP. 22:30 - 00:00 1.50 DRILL N PROD2 12/1/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD2 P/U, M/U BHA. 01 :00 - 02:45 1.75 DRILL N DFAL PROD2 Upload MWD. Initial grounding problem. Pulled tools out of mud - OK. Completed upload & shallow tested - OK. 02:45 - 04:00 1.25 DRILL N DFAL PROD2 Complete P/U remainder of BHA. 04:00 - 11 :45 7.75 DRILL N DFAL PROD2 Rabitt and P/U & RIH w/121 Jts, 2 7/8" DP & 33 Jts, 27/8" HWDP from Pipe Shed. 11 :45 - 12:00 0.25 DRILL N DFAL PROD2 Fill pipe & test MWD - OK. 12:00 - 15:45 3.75 DRILL N DFAL PROD2 RIH wI 4" DP from derrick to 12,019', filling pipe & checking MWD every 2,000'. 15:45 - 16:45 1.00 DRILL N DFAL PROD2 Slip & Cut Drilling Line 117'. 16:45 - 17:30 0.75 DRILL N DFAL PROD2 RlU & Test Liner & Lap to 3,500 psi. Hold & Chart for 30 minutes. 17:30 - 18:00 0.50 DRILL N DFAL PROD2 Service Top Drive. 18:00 - 19:00 1.00 DRILL N DFAL PROD2 Replace stem on 4" valve on mud pump. 19:00 - 21:15 2.25 DRILL N DFAL PROD2 RIH. Tag cement @ 12,113'. Drill cement to 12,130', Attempting to pack off continuously. Working pipe - conditions worsening. Suspect heavy mud & cement in liner cannot be lifted by seawater & low AV's. Torque @ 2800 - No Problem. Need to change out to Mud. 21 :15 - 23:45 2.50 DRILL N DFAL PROD2 Displace seawater with 8.4 ppg. Flo-Pro Mud @ 140 GPM & 2600 psi. Torque @ 2300. Printed: 12/16/2004 4:01:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 12/1/2004 23:45 - 00:00 0.25 DRILL N DFAL PROD2 Make connection & wash down to 12,230'. No packing off. 12/2/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD2 Drill Cement, Plugs, Landing Collar & Float Collar. Take SPR's with both Pumps & Drill out Shoe @ 12,236'. Clean out to 12,238'. 01 :00 - 01 :30 0.50 DRILL N DFAL PROD2 Drill from 12,238' to 12,243' & Slide from 12,243 to 12,258'. 145 GPM @ 2475 psi. 32 RPM wI 3300 ftllbs Torque, 01 :30 - 03:15 1.75 DRILL N DFAL PROD2 Circulate bottoms up to clean out cement & cuttings and to balance wellbore for FIT. 03:15 - 04:15 1.00 DRILL N DFAL PROD2 R/U & perform FIT: 8.4 ppg mud +TVD of 8,753' + 745 psi surface pressure = FIT of 10.03 ppg. EMW. RID test equipment. 04:15·00:00 19.75 DRILL N DFAL PROD2 Directional Drill 4 3/4" Hole from 12,258' to 12,870', Pumping @ 150 GPM wI 2,550 psi on bottom & 2260 psi off bottom, Torque off bottom = 3600 to 4000, Torque on bottom = 4100 to 4400, WOB = 2 to 20K, Rotating wI 40 to 45 RPM. P/U Wt = 165K, Dn Wt = 135K, Rot Wt = 150K. AST = 9.21 hrs. & ART = 2.86 Hrs. Pumped Hi-Vis Sweep @ 12,689' - Minimal DFAL increase in cuttings over shaker. 12/3/2004 00:00 - 00:00 24.00 DRILL N PROD2 Directional Drill 4 3/4" Hole from 12,870' to 13,968', Pumping @ 148 GPM wI 2,500 psi on bottom & 2390 psi off bottom, Torque off bottom = 4500, Torque on bottom = 5000 to 5200, WOB = 5 to 7K, Rotating w/40 RPM. P/U Wt = 175K, Dn Wt = 135K, Rot Wt = 155K Pumped Weighted, Hi-Vis Sweep @ 12,976'. Again, just a minimal increase in cuttings over shaker. Pumped Lube sweeps as needed to minimize torque and aid in sliding. AST = 7.48 Hrs. ART = 6.65 Hrs. 12/4/2004 00:00 - 07:00 7.00 DRILL N DFAL PROD2 Directional Drill 4 3/4" Hole from 13,968' to 14,340'. Pumping @ 148 GPM wi 2,600 psi on bottom & 2390 psi off bottom, Torque off bottom = 4500, Torque on bottom = 5000 to 5200, WOB = 5 to 7K, Rotating wI 40 RPM. PIU Wt = 175K, Dn Wt = 135K, Rot Wt = 155K Pumped Lube sweeps as needed to minimize torque and aid in sliding. Torque creeping up - even with lube & bead sweeps, ocassionaly stalling the Top Drive rotary. NPT time ends! 07:00 - 00:00 17.00 DRILL P PROD2 Directional Drill 4 3/4" Hole from 14,340' to 15,110'. Pumping @ 148 GPM wI 2,680 psi on bottom & 2450 psi off bottom, Torque off bottom = 5000, Torque on bottom = 5200 to 5500, WOB = 5 to 7K, Rotating wI 40 to 45 RPM. PIU Wt = 185K, Dn Wt = 135K, Rot Wt = 160K. Hole drank 6 Bbls Mud @ 14,896' and 15 bbls @ 14,959. Taking approx 18 BPH with total losses of 80 bbls. Pumping Lube, Daily AST = 4,68 Hrs, ART = 10.94 Hrs. 12/5/2004 00:00 - 06:00 6.00 DRILL P PROD2 Di rectional Drill 4 3/4" Hole from 15,110' to 15,443'. TD as per Geologist. Pumping @ 148 GPM wI 2,600 psi on bottom & 2450 psi off bottom, Torque off bottom = 5200, Torque on bottom = 5800, WOB = 5 to 7K, Rotating wI 45 RPM. PIU Wt = 185K, Dn Wt = 135K, Rot Wt = 158K. Hole taking approximately 4 BPH. AST = 1.33 Hrs ART = 2.98 Hrs. 06:00 - 08:00 2.00 DRILL P PROD2 Circulate Hi-Vis Sweep. 08:00 - 10:00 2.00 DRILL P PROD2 POH to 12,210' without pumping. Encountered tight spots at 15,330' & 15,271. Wiped clean. 10:00 - 11 :30 1.50 DRILL P PROD2 Service & change oil in Top Drive. Service Crown. 11 :30 - 13:00 1.50 DRILL P PROD2 RIH to 15,367'. No Problems. Precautionary wash to TD @ Printed: 1211612004 4:01:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 12/5/2004 11 :30 - 13:00 13:00 - 17:00 17:00 - 20:30 20:30 - 21 :00 21 :00 - 22:30 12/6/2004 22:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 06:00 06:00 - 08:30 08:30 - 09:00 09:00 - 10:30 10:30 - 18:00 18:00 - 20:00 20:00 - 00:00 12/7/2004 00:00 - 02:00 02:00 - 02:15 02:15 - 04:00 04:00 - 07:15 07:15 - 07:30 07:30 - 09:45 09:45 - 11 :30 11 :30 - 12:00 1.50 DRILL 4.00 DRILL 3.50 DRILL P P P PROD2 PROD2 PROD2 0.50 DRILL P PROD2 I PROD2 I 1.50 DRILL P 1.50 DRILL 1.50 DRILL 0.50 DRILL 4.00 DRILL 2.50 DRILL P P P P P PROD2 PROD2 PROD2 PROD2 PROD2 0.50 DRILL 1.50 CASE 7.50 CASE P P P PROD2 RUNPRD RUNPRD 2.00 CASE P RUNPRD 4.00 CASE P RUNPRD 2.00 CASE 0.25 CASE 1.75 CASE P P P RUNPRD RUNPRD RUNPRD 3.25 CASE P RUNPRD 0.25 CASE 2.25 CASE P P RUNPRD RUNPRD 1.75 CEMT P RUNPRD 0.50 CEMT P RUNPRD Start Rig Release: Rig Number: I Spud Date: 7/27/1990 End: 1Z7/2004 10/27/2004 12/1 3/2004 115,443. No Fill. I Pump Hi-Vis Sweep & circulate hole clean. Spot lube pill. I POH t~ 12 210', ~AD pass from 12,304' up through shoe @ ì 12,236 to 12,210. : Drop ball to open eirc. sub and drop rabbit. Continue POH to i 10,870'. IOen eirc sub wI 3, 700 psi. Wash TOL @ 10,688' into 7 5/8" ! casing. Pump @ 350 GPM, 2725 psi. Rotating @ 30 RPM ! while reciprocating drill string. Sweep brought up good amount i of fine sand. Pump slug. ! POH, standing back 4" DP. i POH, standing back all 4" DP. I R/U to lay down 2 7/8" Pipe. i LID 33 jts of 2 7/8" spiral HWDP and 76 Jts of 2 7/8" DP. i Stand back 15 stands 2 7/8" DP & LID Jars, Bumper sub, eirc I sub & 3 X NM Flex DC's, Flush & Down load MWD, LID MWD, I Motor & Bit. I Clear & Clean Rig Floor. i R/U to run 3.5" Production Liner. I Run 106 Jts, 3.5", 9.2#, 13-Cr-80, Vam-Ace Production Liner i utilizing Dual Stack Tongs & Torque Turn. Fill on fly and top off i every 10 Jts. i RID Liner equipment. P/U 2 7/8" elevators. P/U Baker 'HMC' i Hanger & 'ZXP' Packer Assembly on one stand of 27/8" DP, I Circulate Liner volume @ 4 BPM & 350 psi. I Continue RIH with Liner on 15 Stands of 27/8" DP then I crossing over to 4" DP. I Continue RIH with 3.5" Liner on DP to 12,166'. I M/U Baker Cement head on DP single and LID on Skate. I Circulate & Condition Mud above 5.5" shoe prior to going into I· open hole. 2 BPM@536psi., 3 BPM@676psi., 4 BPM@ 854 psi. Losses while circulating averaging 18 Bbls./ Hr. I Run in Open Hole with 3.5" Liner on 4" DP to 15,418' filling DP I every 10 stands. I Pickup cement head and rig up to circulate. I Break circulation slow stage up pumps to 2.5 bpm @ 1,043 psi. ¡wash from 15,418' to 15,443', held PJSM with Co Rep, I Too/pusher, cementers and crew, while circulating. Hole I conditions near bottom began to pack off and become difficult to work back down. Position pipe 2 ft. off bottom and slow/y work pumps back to 2.5 bb/s. per minute. Attempt to reciprocate pipe again with more of the same conditions. I Position pipe on bottom and stage pumps up, keeping pressures under 1,200 PSI. Pump 5 bbl of CW-100 and test lines to 4,000 psi, Pump remaining 15 bbls CW 100 followed by 20 bbls MudPush II weighted to 9.6 ppg, followed by 52 bbls (185 sX), 15.8 ppg, I Class "G" slury with yield of 1.53 cU.ft./sk. @ 3 BPM. wash up lines through tee, switch to rig pumps and kick out DP dart and displace with 141 bb/s Mud @ 3 BPM. Slow down to P/U liner plug and again prior to bump. Bumped wI 1666 psi. CI P 11 :30 Hrs. Did not reciprocate pipe. Continue to pressure up to 3500 psi to set HMC Hanger. Set Printed: 12/16/2004 4:01:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 1 2/13/2004 Spud Date: 7/27/1990 End: 120/2004 12/7/2004 11 :30 - 12:00 0.50 CEMT P RUNPRD dn 10K, Bleed off pressure & check floats - OK. Pressure up to 1,000 psi, P/U to expose rotating dog sub pump 20 bbls, at 30 I SPM, Reduce pump rate to t 1 bpm, set down 55k to set ZXP I Packer, Saw no indication that packer set. Picked back up to I repeat setting procedure. At app. 45K down there was an indication that the rotating dogs may have slipped back into the liner. Repeated with same results. Picked up and rotated down at 5 rpm applying app. 40K down before seeing dogs go back inside. Pick back up and circulate out cement. Total losses for last 12 hrs = 77 bbls 12:00 - 14:00 2.00 CEMT P RUNPRD Circulate bottoms up, 6 bpm @ 1,750 psi, 10 bbls cement to surface, 14:00 - 15:30 1.50 CEMT P RUNPRD Displace well to 8.6 ppg seawater, 10 bpm @ 2680 psi 15:30 - 20:45 5.25 CEMT P RUNPRD Monitor well, pump dry job, blow down topdrive and POH 20:45 - 21 :45 1.00 CEMT P RUNPRD Monitor well at 2 7/8" DP, Stand back 15 stands of 2 7/8" DP, lay down running tool, no visible damage to running tool, pins on ruuning tool sheared indicating 40k was applied to set liner top packer. 21 :45 - 22:45 1.00 CEMT P RUNPRD Cut and slip drilling line. 22:45 - 23:30 0.75 CEMT P RUNPRD Service Rig 23:30 - 00:00 0.50 CEMT P RUNPRD Rig up and test 3.5" liner, pressured up to 2,400 psi shut down, pressure bled down to 1,600 psi in 5 min. 12/8/2004 00:00 - 01 :00 1.00 SIT N DFAL RUNPRD Service topdrive and crown 01 :00 - 02:00 1.00 SIT N DFAL RUNPRD Clean floor, rig up 2 7/8" handling equipment and power tongs, 02:00 - 02:30 0.50 SIT N DFAL RUNPRD PJSM with rig crew and Baker Rep. 02:30 - 08:30 6.00 SIT N DFAL RUNPRD Make up Baker seal assembly with no-go, pickup 15 stands 2 7/8" DP, lay down power tongs and change out handling equipment. RIH with seal assembly on 4" DP to 12,051' 08:30 - 11 :00 2.50 SIT N DFAL RUNPRD I Break circulation above liner top, at 2 bpm @ 150 psi, 3 bpm @ 323psi, slow pumps to 1 bpm, slack off and sting seals into tie back sleeve, pressure test inside 3.5" liner to 2,000 psi, good test. Slack off 55K down on top of liner top 5 times to attempt to get a setting. No obvious sign that liner packer set. Closed annular and pressured up to 2,540 psi. on the backside, pressure bleed off to 1,750 psi in 12 min. Pressure test surface equipment to 3,000 psi to eliminate any possible leaks on surface. good test. Test liner to 3,500 psi held for 10 min, good test. Pumped down annulus @ 1 bpm with DP open to ensure not pumping by seals, pressure built to 2,285 psi with 5.2 bbls pumped, shut down pressure dropped 500 psi in 7 min. 11 :00 - 12:00 1.00 SIT N DFAL RUNPRD Pumped dry job, blow down topdrive, POH to 11,195' Up wt = 175k, Dn wt = 150k 12:00 - 13:00 1.00 SIT N DFAL RUNPRD Rig up, close annular and attempt to pressure test back side. started pumping at 2 bpm, pressure built to 2,890 psi at a steady rate, then started to decline the pressure dropped to 2500 psi while pumping 1 bpm. shut down bled off pressure. 13:00 - 18:00 5.00 SIT N DFAL RUNPRD POH, to 2 7/8" DP, monitor well. 18:00 - 18:30 0.50 SIT N DFAL RUNPRD Stand back 2 7/8" DP lay down Baker seal assembly. 18:30 - 19:00 0.50 PERFUB P OTHCMP Service topdrive 19:00 - 22:30 3.50 PERFUB P OTHCMP Load perforating guns in pipe shed, PJSM with Co Rep, Toolpusher, Schlumberger, and rig crew. Pickup up DPC perforating assembly per Schlumberger representative. Printed: 12/16/2004 4:01:12 PM · Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 Frnm D 12/8/2004 22:30 - 00:00 1.50 PERFUB P 12/9/2004 00:00 - 03:00 3.00 PERFOB P 03:00 - 08:30 5.50 PERFOB P 08:30 - 09:30 1.00 PERFOB P OTHCMP Rig up 2 1/16" slips and elevators, M/U xo's to perf guns and pickup 29 joints of 21/16" dp from pipe shed. OTHCMP Continue RIH picking up 60 joints 21/16" Dp, change out DP handling equipment, RIH with 15 stands of 2 7/8" DP. OTHCMP Change over to 4" handling equipment and RIH with perf guns on 4" DP to landing collar @ 15,374' OTHCMP Pull up to position bottom shot @ 15,340', drop ball make up todrive and pump ball down @ 1.5 bpm, 365 psi. pressure up to 2,300 psi to fire guns, Shot detection indicated that all shots fired, monitor well, hole static, Perforated intervals: 13,850' - 13,980' 14,060' -14,180' 14,220' - 14,630' 14,690' - 14,735' 15,140' - 15,230' 15,300' - 15,340' 09:30 - 10:30 1.00 PERFOB P OTHCMP POH slowly to above top shot at 13,850, hole took 2 bbl over calculated fill. 10:30 - 12:00 1.50 PERFOB P OTHCMP Monitor well, hole taking 5 to 6 bph. Circulate bottoms up at 3 bpm @ 1,045 psi. had 100 bbls of gas cut mud at bottoms up. Up wt:: 165k, Dn wt = 135k. total losses = 8 bbls 12:00 - 13:00 1.00 PERFOB P OTHCMP Continue circulating bottoms up 3 bpm 1,000 psi, pump dry job, blow down topdrive. 13:00 - 22:00 9.00 PERFOB P OTHCMP POH lay down 4" DP, hole taking 5 bph. 22:00 - 23:00 1.00 PERFOB P OTHCMP Monitor well, change over to 2 7/8" handling equipment, lay down 45 joints of 2 7/8" DP, 23:00 - 00:00 1.00 PERFOB P OTHCMP Change over to 2 1/16" handling equipment, lay down 42 joints of 21/16" DP. Losses for last 12 hrs :: 62 bbls. 12/1 0/2004 00:00 - 00:30 0.50 PERFOB P OTHCMP Held PJSM, with Co Rep, Schlumberger and rig crew on handling perf guns, lay down remaining 18 joints of 21/16" DP. 00:30 - 06:00 5.50 PERFOB P OTHCMP Lay down 2" perf guns and blanks 72 total. All shots fired. Clear floor of all perforating equipment, and handling tools. 06:00 - 07:00 1.00 PERFOB P OTHCMP RIH 26 stans from derrick 07:00 - 09:00 2.00 PERFOB P OTHCMP Lay down 78 joints 4" DP 09:00 - 10:00 1.00 BOPSUPP WHDTRE Drain BOP stack, pull wear ring and install test plug. 10:00 - 11 :30 1.50 BOPSUF P WHDTRE Change top rams to 31/2" X 6" variables. 11 :30 - 12:00 0.50 BOPSUF P WHDTRE Rig up BOP test equipment. Losses for last 12 hrs :: 62 bbls 12:00 - 19:30 7.50 BOPSUPP WHDTRE Test BOP per Nabors testing procedure, to 250 psi low, 3,500 psi high, manual valves on choke and kill lines failed, repair and re-test. John Chrisp with AOGCC waived witness of BOP test. 19:30 - 20:00 0.50 BOPSUP P WHDTRE Rig down testing equipment, blow down choke and kill lines, pull test plug. 20:00 - 20:30 0.50 RUNCOrvP RUNCMP Pickup tubing hanger & landing, make dummy run. 20:30 - 22:30 2.00 RUNCOrvP RUNCMP Rig up to run 3.5" completion, PJSM with Co Rep, Baker, Halliburton and rig crew. 22:30 - 00:00 1.50 RUNCOrvP RUNCMP M/U & run 3.5 13CR Vam Ace Completion 4" Tie back seal Printed: 12/16/2004 4:01:12 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/27/2004 12/13/2004 Spud Date: 7/27/1990 End: 12/7/2004 12/10/2004 22:30 - 00:00 1.50 RUNCOMP RUNCMP assembly 'X' Nipple Assy, 'X' Nipple Assy & Baker Sabl Production Packer Assy. Run 3.5" 9.2# 13CR Tubing as per running order, Makeup Torque 2,820 ftllbs. Losses for last 12 hrs = 60 bbls 12/11/2004 00:00 - 19:00 19,00 RUNCOMP RUNCMP Run 42 joints of 3.5" 9.2# 13CR tubing, make up Halliburton gauge carrier and connect control wire, Continue running 3.5" 9.2# 13cr completion per running order, install protector clamps on every joint, and half clamps on each side of GLM, test cable every 30 joints to ensure integrity. Average running speed 17 joints/hr. Ran 273 joints to 8,819'. Up wt = 75k, Dn wt = 73k, 19:00 - 00:00 5,00 RUNCOM\l RREP RUNCMP Having electrical problems with pipe machine, works intermittently, then quit all together trouble shoot and repair problem. Total losses for last 24 hrs = 105 bbls. 12/12/2004 00:00 - 02:30 2.50 RUNCOM\l RREP RUNCMP Repair and replace wire and plugs on two electronic sensors, on lay down machine. 02:30 - 09:30 7.00 RUNCOtvP RUNCMP Continue running 3.5" 9,2# 13cr completion per running order, from jt # 273,8,819' to joint # 372 @ 12,074' Ran a total of 335 control line protectors and 14 half clamps. 09:30 - 10:30 1.00 RUNCOfvP RUNCMP Make up head pin on joint # 373, circulate down at 34 spm, 130 psi, saw pressure increase when seal assembly enterd tie back @ 12,081', shut down pumps, continue slacking off, set down with seal assembly fully inserted in tie back at 12,086', pull seal assembly from tie back. 10:30 - 14:00 3.50 RUNCOMP RUNCMP Displace well with 290 bbls clean seawater treated with one drum of inhibitor down tubing at 2 bpm, 140 psi, followed by 105 bbls clean seawater. 14:00 - 18:00 4.00 RNTBHG P TUBHGR POH lay down joints # 373-371, pickup 4 space out pups, 2.22', 2.02',3.92',3,92' totaling 12.06', makeup joint # 371, and tubing hanger, insert control wire through tubing hanger and test to 5000 psi. 18:00 - 18:30 0.50 RNTBHG P TUBHGR Land tubing in well head, RILDS, rig up to test backside to 1,000 psi to ensure seal integrity. Top off tubing with water, pressure up to 1,000 psi on back side with tubing open, pressure bled to 780 psi in 10 min. no communication with tubing. 18:30 - 19:00 0.50 RNTBHG P TUBHGR Drop ball and rod, back out landing joint, and install TWC. 19:00 - 20:00 1.00 RUNCOMP RUNCMP Clear rig floor of all tubing handling and completion equipment. 20:00 - 23:00 3.00 WHSUR P WHDTRE Nipple down BOP, nipple up adapter flange and tree, test to 5,000 psi. 23:00 - 23:30 0.50 WHSUR P WHDTRE Rig up DSM lubricator, pull TWC, rig down lubricator. 23:30 - 00:00 0.50 WHSUR P WHDTRE Rig up high pressure lines, pressure up on tubing to 4,200 psi to set packer, test tubing to 4,000 psi for 30 min record on chart. 12/13/2004 00:00 - 01 :00 1.00 WHSUR P WHDTRE Bleed tubing pressure to 1,500 psi, pressure up on annulus to 3,500 psi to test packer, hold for 30 min record on chart. Bleed tubing pressure down to shear RP shear valve in upper GLM, sheared at 2,600 psi. pump through shear valve both ways to ensure clear. 01 :00 - 03:00 2.00 WHSUR P WHDTRE Rig up Little Red, to freeze protect tubing and annulus to 2200', test lines to 2,500 psi, pump 93 bbls diesel down 7 5/8" X 3 Printed: 12/16/2004 4:01 :12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-13 Z-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 10/27/2004 Rig Release: 12/13/2004 Rig Number: Spud Date: 7/27/1990 End: 12/7/2004 12113/2004 01 :00 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 06:00 2.00 WHSUR P 1,50 WHSUR P 1,00 WHSUR P 0.50 WHSUR P WHDTRE 1/2" annulus, 2 bpm @ 400 psi. WHDTRE Rig up lines and U-tube diesel. Install VR plug in IA valve, WHDTRE Rig up DSM lubricator and install BPV, rig down lubricator WHDTRE Rig down Little Red, remove double valve from IA and insatll VR plug. Secure well. Realese Rig @ 06:00 hrs 12/13/2004 Printed: 12/16/2004 4:01:12 PM BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-13A . Job No. AKZZ3369825, Surveyed: 5 December, 2004 Survey Report 10 December, 2004 Your Ref: API 500292006901 Surface Coordinates: 5959099.96 N, 599545.00 E (70017' 51.6713" N, 149011' 37.9288" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 82.76ft above Mean Sea Level S¡""'_I ·.....y-sul! DRIL.L.INrs seAVIt:::eS A Halliburton Company Survey Ref: svy4455 BP EXPLORATION (ALASKA)/NC. Survey Report for Z-13A Your Ref: API 500292006901 Job No. AKZZ3369825, Surveyed: 5 December, 2004 North Slope Alaska BPXA 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) 10835.66 54,370 16.580 7815.36 7898.12 5650.18 N 1250.30 E 5964766.20 N 600720.35 E 1250.30 Tie On Point MWD+IIFR+MS 10840.00 54.420 16.620 7817.89 7900.65 5653.56 N 1251.30E 5964769.60 N 600721.31 E 1.376 1251.30 Window Point 10907.39 54.250 20.660 7857.19 7939.95 5705.42 N 1268.79 E 5964821.68 N 600738.11 E 4.877 1268.79 11002.60 54.520 26.410 7912.66 7995.42 5776.33 N 1299.69 E 5964893.00 N 600768.06 E 4.917 1299.69 . 11098.20 54.140 32.180 7968.44 8051.20 5844.02 N 1337.65E 5964961,18 N 600805.13 E 4.919 1337.65 11193.80 53.400 34.790 8024,95 8107.71 5908.33 N 1380.18 E 5965026.05 N 600846.80 E 2.334 1380.18 11289.63 52.230 36,620 8082.87 8165.63 5970.32 N 1424.73 E 5965088.63 N 600890.52 E 1.951 1424.73 11385.36 51,180 36.080 8142.19 8224.95 6030.83 N 1469.26 E 5965149,72 N 600934.25 E 1.183 1469.26 11485.18 49.970 36.000 8205.59 8288.35 6093.18 N 1514.63E 5965212.67 N 600978.79 E 1.214 1514,63 11580.27 50.130 35.910 8266.64 8349.40 6152.19 N 1557.43 E 5965272.24 N 601020.80 E 0.183 1557.43 11676.56 51.610 38.540 8327.42 8410.18 6211,64 N 1602.62 E 5965332.29 N 601065.20 E 2.617 1602.62 11772.29 52.140 41 .120 8386.52 8469.28 6269.46 N 1650.85 E 5965390.74 N 601112,67 E 2.191 1650.85 11868.05 52.700 45.620 8444,94 8527.70 6324.60 N 1702.95 E 5965446,56 N 601164.03 E 3.769 1702.95 11963.02 52.820 51.990 8502.45 8585.21 6374.35 N 1759.80 E 5965497.06 N 601220.21 E 5.340 1759.80 12058.64 52.450 54.350 8560.49 8643.25 6419.90 N 1820,62 E 5965543.41 N 601280.42 E 1.999 1820.62 12154.47 52.380 54.700 8618,94 8701.70 6463.97 N 1882.46 E 5965588.30 N 601341.67 E 0.299 1882.46 12254.41 51.700 54.440 8680.41 8763.17 6509.65 N 1946.66 E 5965634.82 N 601405.27 E 0.711 1946.66 12271.04 51.750 54.600 8690.71 8773.47 6517.23 N 1957,30 E 5965642.54 N 601415.80 E 0.813 1957.30 12303.14 51.740 55.420 8710.59 8793.35 6531,68 N 1977.95 E 5965657.27 N 601436.26 E 2.006 1977.95 12334.43 51.200 57.220 8730.08 8812.84 6545.25 N 1998.31 E 5965671.11 N 601456.44 E 4.820 1998,31 12366.41 50.630 58,370 8750.24 8833.00 6558.48 N 2019.32 E 5965684.62 N 601477.27 E 3.312 2019.32 . 12399.97 51.000 58,870 8771.45 8854,21 6572.03 N 2041.52 E 5965698.45 N 601499.29 E 1.597 2041.52 12431.76 52.940 58.400 8791.03 8873.79 6585.06 N 2062.90 E 5965711.77 N 601520.50 E 6.213 2062.90 12464.99 55.820 57.940 8810,38 8893,14 6599.31 N 2085.85 E 5965726.32 N 601543.25 E 8.740 2085.85 12496.04 58.650 58.950 8827.19 8909.95 6612.97 N 2108.10 E 5965740.27 N 601565,32 E 9.516 2108,10 12527.76 61.850 59.070 8842.92 8925,68 6627.15 N 2131.70 E 5965754,76 N 601588.74 E 10.094 2131.70 12560.17 66.030 59.770 8857.16 8939.92 6641.95 N 2156.76 E 5965769.90 N 601613.60 E 13.042 2156.76 12591.90 69.260 60.190 8869.23 8951.99 6656,63 N 2182.17 E 5965784.91 N 601638,81 E 10.253 2182,17 12623.32 72.780 60.100 8879.44 8962,20 6671 .42 N 2207.94 E 5965800,04 N 601664.37 E 11 .206 2207.94 12654.96 76.460 58.900 8887.83 8970.59 6686.90 N 2234.21 E 5965815.87 N 601690.45 E 12.192 2234.21 12688.08 79.420 58.640 8894.75 8977.51 6703.69 N 2261.91 E 5965833.03 N 601717.91 E 8.970 2261.91 12720.03 82.610 58.600 8899.74 8982.50 6720.12 N 2288.85 E 5965849.81 N 601744.63 E 9.985 2288.85 12750.28 86.080 59.060 8902.72 8985.48 6735,70 N 2314.60 E 5965865.73 N 601770.18 E 11.570 2314.60 12783.28 88.270 58.040 8904.35 8987.11 6752.90 N 2342.71 E 5965883.30 N 601798.06 E 7.319 2342.71 12814.60 90.030 57.430 8904.81 8987.57 6769.61 N 2369,19 E 5965900.36 N 601824.32 E 5.947 2369.19 10 December, 2004 - 14:13 Page 2 of 5 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-13A Your Ref: API 500292006901 Job No. AKZZ3369825, Surveyed: 5 December, 2004 North Slope Alaska BPXA 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) 12845.32 91.450 56.980 8904.42 8987.18 6786.25 N 2395.01 E 5965917.34 N 601849.92 E 4.849 2395.01 12877.98 92.870 59.250 8903.19 8985.95 6803.49 N 2422.72 E 5965934.94 N 601877.39 E 8.194 2422.72 12909.84 94.760 63.010 8901.07 8983.83 6818.84 N 2450.56 E 5965950.66 N 601905.02 E 13.185 2450.56 12941.63 96.530 64.640 8897.94 8980,70 6832.79 N 2478.95 E 5965964.99 N 601933.22 E 7.552 2478.95 12973.81 97.240 64.760 8894.08 8976,84 6846.44 N 2507.83 E 5965979.02 N 601961.92 E 2.237 2507.83 . 13005.20 96.340 64.470 8890.37 8973.13 6859.81 N 2535.99 E 5965992.76 N 601989.90 E 3.010 2535.99 13037.73 95,750 66.100 8886.94 8969.70 6873.33 N 2565.37 E 5966006.67 N 602019.11 E 5.303 2565.37 13072.26 94,760 68.440 8883.78 8966.54 6886.62 N 2597.09 E 5966020.37 N 602050.64 E 7.332 2597.09 13101.12 93.980 71 .520 8881.58 8964.34 6896.46 N 2624.12 E 5966030.58 N 602077.54 E 10.979 2624,12 13132.50 93.090 75.260 8879.65 8962.41 6905.42 N 2654.13 E 5966039.93 N 602107.43 E 12.229 2654.13 13165.26 92.810 78.960 8877.96 8960.72 6912.71 N 2686,01 E 5966047.64 N 602139.21 E 11.312 2686.01 13197.98 92.810 80.390 8876.36 8959.12 6918.57 N 2718,16 E 5966053.93 N 602171.28 E 4.365 2718.16 13229.56 93.300 83.870 8874.67 8957.43 6922.89 N 2749.40 E 5966058.66 N 602202.46 E 11.113 2749.40 13261.23 93.490 87.370 8872.80 8955.56 6925.30 N 2780.91 E 5966061.49 N 602233.94 E 11.048 2780.91 13293.41 93.400 92.330 8870.86 8953.62 6925.39 N 2813.03 E 5966062.00 N 602266.05 E 15.388 2813.03 13325.00 93.430 96.000 8868.98 8951.74 6923.10 N 2844.47 E 5966060.13 N 602297.52 E 11 .597 2844.47 13356.35 93.770 98.740 8867.01 8949.77 6919.08 N 2875.50 E 5966056.52 N 602328.60 E 8.790 2875.50 13388.33 93.550 100.900 8864.97 8947.73 6913.64 N 2906.94 E 5966051.50 N 602360.11 E 6.775 2906.94 13420.45 93.700 105,850 8862.94 8945.70 6906.23 N 2938.12 E 5966044,50 N 602391.38 E 15.387 2938.12 13452.12 91.980 109.910 8861.37 8944.13 6896.52 N 2968,22 E 5966035.19 N 602421.61 E 13.908 2968.22 13483.61 90.370 110.050 8860.72 8943.48 6885.76 N 2997,80 E 5966024.82 N 602451.33 E 5.132 2997.80 13515.59 91.700 109,790 8860.14 8942.90 6874.87 N 3027.86 E 5966014.33 N 602481.54 E 4.238 3027.86 . 13563.40 91.670 108.760 8858.74 8941.50 6859.09 N 3072.97 E 5965999.15 N 602526.85 E 2.154 3072.97 13611.87 93.030 109.150 8856.75 8939.51 6843.36 N 3118.78E 5965984.03 N 602572.86 E 2.919 3118,78 13658.73 93.210 107.090 8854.20 8936.96 6828.81 N 3163.24 E 5965970.07 N 602617.51 E 4.406 3163.24 13707.52 91.390 105,000 8852.24 8935.00 6815,34 N 3210.09 E 5965957.22 N 602664.54 E 5.677 3210.09 13739.27 88.270 104.610 8852.33 8935.09 6807.22 N 3240.78 E 5965949.51 N 602695.33 E 9.903 3240.78 13771.13 86.080 105.120 8853.90 8936.66 6799.06 N 3271.54 E 5965941.76 N 602726.19 E 7.057 3271.54 13802.23 86,670 104.980 8855.87 8938.63 6791.00 N 3301.51 E 5965934.10 N 602756.27 E 1.950 3301.51 13849.33 88.640 106.460 8857.80 8940.56 6778.25 N 3346.81 E 5965921.95 N 602801.73 E 5.230 3346.81 13897.71 87.130 105.910 8859.58 8942.34 6764.78 N 3393.24 E 5965909.09 N 602848.33 E 3.321 3393.24 13951.45 86.330 105.390 8862.65 8945.41 6750.30 N 3444.90 E 5965895.30 N 602900.18 E 1.775 3444.90 13992,87 85.280 106.060 8865.68 8948.44 6739.11 N 3484.66 E 5965884.63 N 602940.09 E 3.005 3484.66 14045,16 85,770 105.010 8869.76 8952,52 6725.15 N 3534.89 E 5965871.34 N 602990.50 E 2.210 3534.89 14089.29 87.530 105.000 8872.34 8955.10 6713.74 N 3577.44 E 5965860.50 N 603033.20 E 3.988 3577.44 10 December, 2004 - 14:13 Page 3 of 5 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-13A Your Ref: API 500292006901 Job No. AKZZ3369825, Surveyed: 5 December, 2004 North Slope Alaska BPXA 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) 14139.80 88.700 104.600 8874.00 8956.76 6700.85 N 3626.24 E 5965848.25 N 603082.17 E 2.448 3626.24 14185.61 86.980 104.040 8875.73 8958.49 6689.52 N 3670.60 E 5965837.52 N 603126.67 E 3.948 3670.60 14235.17 87.280 104.360 8878.21 8960.97 6677.38 N 3718.58 E 5965826.01 N 603174.81 E 0.884 3718.58 14280,98 86.790 104.520 8880.58 8963.34 6665.97 N 3762.89 E 5965815.19 N 603219.26 E 1.125 3762.89 14327.93 85,770 105.440 8883.62 8966.38 6653.86 N 3808.14 E 5965803.68 N 603264.67 E 2.923 3808.14 . 14376.55 88.210 105.750 8886.18 8968.94 6640.81 N 3854.91 E 5965791.25 N 603311.61 E 5.059 3854.91 14424.12 87.040 105,070 8888.15 8970.91 6628.18 N 3900.72 E 5965779.23 N 603357.59 E 2.844 3900.72 14473,12 85.890 104.430 8891.17 8973.93 6615.73 N 3948.02 E 5965767.40 N 603405.04 E 2.685 3948.02 14518.54 83.910 105.580 8895.21 8977.97 6604.02 N 3991,71 E 5965756.27 N 603448.89 E 5.036 3991.71 14567.88 83.820 105.490 8900.48 8983.24 6590.88 N 4038.98 E 5965743.76 N 603496.32 E 0.257 4038.98 14616.36 83.940 105.580 8905.65 8988.41 6577.97 N 4085.42 E 5965731.47 N 603542.93 E 0.309 4085.42 14662.72 83.210 104.340 8910.84 8993.60 6566.08 N 4129.93 E 5965720.17 N 603587.59 E 3.089 4129.93 14758.59 81.670 103.860 8923.45 9006.21 6542.93 N 4222.10 E 5965698.24 N 603680.06 E 1.681 4222.10 14806.60 82.980 103.880 8929.86 9012.62 6531.52 N 4268.29 E 5965687.44 N 603726.40 E 2.729 4268.29 14853.20 85.460 104.130 8934.55 9017.31 6520.30 N 4313.27 E 5965676,82 N 603771.53 E 5.349 4313.27 14899.74 87.010 104.160 8937.61 9020.37 6508.95 N 4358.30 E 5965666.07 N 603816.70 E 3.331 4358.30 14948.95 86,260 103.260 8940.50 9023.26 6497.31 N 4406.03 E 5965655.06 N 603864.58 E 2.378 4406.03 14993.92 86.510 103.360 8943,33 9026.09 6486.98 N 4449.70 E 5965645.31 N 603908.39 E 0.599 4449.70 15044.49 87.560 103.920 8945.95 9028.71 6475.07 N 4498.78 E 5965634.05 N 603957.62 E 2.352 4498.78 15094.49 86.910 103.610 8948.36 9031.12 6463.18 N 4547.28 E 5965622.81 N 604006.28 E 1 .440 4547.28 15140.71 85.730 103.540 8951.33 9034.09 6452.36 N 4592.12 E 5965612.58 N 604051.25 E 2.557 4592.12 15179.73 85.020 104.010 8954.47 9037.23 6443.10 N 4629.89 E 5965603.82 N 604089.14 E 2.180 4629.89 . 15206,66 83.550 103.530 8957.15 9039.91 6436.72 N 4655.92 E 5965597.79 N 604115,25 E 5.739 4655.92 15237.40 81.590 102.760 8961.13 9043.89 6429.79 N 4685.60 E 5965591,25 N 604145.02 E 6.843 4685.60 15286.06 81.420 102.440 8968.32 9051.08 6419.29 N 4732.57 E 5965581.37 N 604192.12 E 0.738 4732.57 15332.83 82.460 102.330 8974.88 9057.64 6409.36 N 4777.80 E 5965572.04 N 604237.48 E 2.236 4777.80 15409.31 80.730 102.320 8986.05 9068.81 6393.21 N 4851.71 E 5965556.87 N 604311.60 E 2.262 4851.71 15443.00 80.730 102,320 8991.48 9074.24 6386.11 N 4884.19 E 5965550.21 N 604344.18 E 0.000 4884.19 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 Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 90.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15443.00ft., The Bottom Hole Displacement is 8039.76ft., in the Direction of 37.409° (True). 10 December, 2004 - 14:13 Page 4 of 5 DrillQuest 3.03.06.006 BP EXPLORATION (ALASKA) INC. Survey Report for Z-13A Your Ref: API 500292006901 Job No. AKZZ3369825, Surveyed: 5 December, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 10835.66 10840.00 15443.00 7898.12 7900,65 9074.24 5650.18 N 5653.56 N 6386.11 N 1250.30 E 1251.30 E 4884.19 E Tie On Point Window Point Projected Survey . Survey tool program for Z-13A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10835.66 0.00 10835.66 7898.12 15443.00 7898.12 BP High Accuracy Gyro (Z-13) 9074.24 MWD+IIFR+MS (Z-13A) . 10 December, 2004 - 14:13 Page 5 of 5 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-13APB1 . Job No. AKZZ3369825, Surveyed: 14 November, 2004 Survey Report 10 December, 2004 Your Ref: API 500292006970 Surface Coordinates: 5959099.96 N, 599545.00 E (70017' 51.6713" N, 149011' 37.9288" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 82.76ft above Mean Sea Level sp:E!............'J-SUil'! D RIL.L.I NG'S eAVI c:e S A Halliburton Company Survey Ref: svy4415 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-13APB1 Your Ref: API 500292006970 Job No. AKZZ3369825, Surveyed: 14 November, 2004 North Slope Alaska BPXA 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) 11339.16 55.470 23.940 8095.00 8177.76 6043.96 N 1391.63 E 5965161.83N 600856.45 E 1391.63 Tie On Point MWD+IIFR+MS 11385.00 55.320 25.060 8121.04 8203.80 6078.30 N 1407,28 E 5965196.36 N 600871.64 E 2.038 1407.28 Window Point 11485.14 55.890 31.120 8177.64 8260.40 6151.13 N 1446.17 E 5965269.71 N 600909.56 E 5.025 1446.17 11580.97 53.390 36.020 8233.12 8315,88 6216.24 N 1489.31 E 5965335.38 N 600951.84 E 4.918 1489.31 . 11674.95 52.440 37.890 8289.79 8372.55 6276.15 N 1534.38 E 5965395.88 N 600996.11 E 1.882 1534.38 11771.24 51.630 44.850 8349.07 8431.83 6333.08 N 1584.47 E 5965453.47 N 601045.45 E 5.759 1584.47 11867.14 52.000 51.520 8408.40 8491.16 6383.27 N 1640.61 E 5965504.41 N 601100.91 E 5.479 1640.61 11962.34 50.500 52.030 8467.98 8550,74 6429,21 N 1698,93 E 5965551.11 N 601158.62 E 1.630 1698.93 12058.16 49.220 52.310 8529.75 8612.51 6474.14N 1756.78 E 5965596.80 N 601215.87 E 1.354 1756.78 12153.14 49.760 51.580 8591.45 8674.21 6518.66 N 1813,64 E 5965642.07 N 601272.14 E 0.815 1813.64 12243.00 50,000 52,710 8649.36 8732.12 6560.82 N 1867.90 E 5965684.95 N 601325.83 E 0.998 1867.90 12274.75 50.090 52.760 8669,74 8752.50 6575.56 N 1887.27 E 5965699.94 N 601345.00 E 0.308 1887.27 12306,08 52,390 54.000 8689.36 8772.12 6590.13 N 1906.87 E 5965714.77 N 601364.42 E 7.963 1906.87 12338.36 52.470 54.110 8709.04 8791,80 6605.14 N 1927.59 E 5965730.06 N 601384.93 E 0.367 1927.59 12370.54 52.320 54.360 8728.68 8811.44 6620.05 N 1948,27 E 5965745,23 N 601405.42 E 0.772 1948.27 12402,32 53.710 54.550 8747.80 8830.56 6634.80 N 1968.93 E 5965760.26 N 601425.87 E 4.400 1968.93 12434.39 55.440 53.680 8766.38 8849.14 6650.12 N 1990.10 E 5965775,86 N 601446.84 E 5.830 1990.10 12463.34 57.330 53.960 8782.41 8865.17 6664.35 N 2009,56 E 5965790.35 N 601466.11 E 6.578 2009.56 12498.97 59.740 53.480 8801.01 8883.77 6682.34 N 2034.06 E 5965808.65 N 601490.37 E 6.861 2034.06 12530,95 62.040 53.920 8816.56 8899.32 6698.87 N 2056.57 E 5965825.49 N 601512.66 E 7.292 2056.57 12560.36 65,270 54.560 8829.61 8912.37 6714.27 N 2077.96 E 5965841 .17 N 601533.84 E 11.154 2077.96 . 12594.29 69.930 54.910 8842,54 8925.30 6732.38 N 2103.56 E 5965859.61 N 601559.21 E 13.767 2103.56 12629.19 73,200 54.790 8853.58 8936.34 6751.44 N 2130.63 E 5965879.03 N 601586.02 E 9.375 2130.63 12657.82 76.030 55.700 8861.17 8943.93 6767.17 N 2153,31 E 5965895.06 N 601608.49 E 10.349 2153.31 12693.24 79,630 55.490 8868.64 8951.40 6786.73 N 2181.87E 5965915.00 N 601636.79 E 10.180 2181.87 12724.89 81.920 55.960 8873.71 8956.47 6804.32 N 2207.69 E 5965932.93 N 601662.36 E 7.382 2207.69 12753.46 84.310 56.860 8877.13 8959.89 6820.01 N 2231.31 E 5965948.93 N 601685.78 E 8.931 2231.31 12817.85 87.380 57.11 0 8881,80 8964,56 6855,00 N 2285.16 E 5965984.63 N 601739,16 E 4.784 2285,16 12848.49 90.710 56.470 8882.31 8965.07 6871.78 N 2310.78 E 5966001.74 N 601764.56 E 11 .067 2310.78 12884.28 91.320 58.570 8881.68 8964.44 6890,99 N 2340.97 E 5966021.36 N 601794.49 E 6.109 2340.97 12913.06 91 .480 60.470 8880.97 8963.73 6905.59 N 2365.76 E 5966036.28 N 601819.09 E 6.623 2365.76 12945.04 91.050 63.390 8880.27 8963.03 6920.63 N 2393.97 E 5966051.69 N 601847.09 E 9.227 2393.97 12976.82 90.960 66.670 8879.71 8962.47 6934.04 N 2422.77 E 5966065.48 N 601875.71 E 10.323 2422.77 13009,52 91.260 68.260 8879.08 8961.84 6946,57 N 2452.97 E 5966078.41 N 601905.74 E 4.947 2452.97 13036.94 91.360 71.270 8878.45 8961.21 6956.05 N 2478.69 E 5966088.23 N 601931.33 E 10.981 2478.69 10 December, 2004 - 14:15 Page 2 of 4 Dril/Quest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-13APB1 Your Ref: API 500292006970 Job No. AKZZ3369825, Surveyed: 14 November, 2004 North Slope Alaska BPXA 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) 13072.62 91.670 74.350 8877.50 8960.26 6966.59 N 2512.76 E 5966099.22 N 601965.26 E 8.673 2512.76 13104.23 91.140 73.890 8876.73 8959.49 6975.24 N 2543.15 E 5966108.27 N 601995.54 E 2.220 2543.15 13135,25 90.120 75.600 8876.39 8959,15 6983.40 N 2573.08 E 5966116.83 N 602025.35 E 6.418 2573.08 13167.73 91.080 75.990 8876.05 8958.81 6991.37 N 2604.56 E 5966125.21 N 602056,73 E 3,190 2604.56 13198.65 92.070 77. 190 8875.20 8957.96 6998.54 N 2634.63 E 5966132.78 N 602086.69 E 5.030 2634.63 . 13227.97 92.070 78.770 8874.14 8956.90 7004.64 N 2663.28 E 5966139.26 N 602115.27 E 5.385 2663.28 13263.51 91.300 81.300 8873.09 8955.85 7010.78 N 2698.27 E 5966145.87 N 602150.17 E 7.438 2698.27 13295.31 90.710 84.210 8872.54 8955.30 7014.79 N 2729.81 E 5966150.30 N 602181.65 E 9.336 2729.81 13327.05 91.080 87.680 8872.04 8954.80 7017.04 N 2761.46 E 5966152.96 N 602213.27 E 10,993 2761.46 13358.99 92.650 89.220 8871 .00 8953.76 7017.90 N 2793.37 E 5966154.25 N 602245.17 E 6.884 2793.37 13390.86 93.390 91.510 8869.32 8952.08 7017.70 N 2825.19 E 5966154.46 N 602276.99 E 7.542 2825.19 13423.02 94.210 93.630 8867.19 8949.95 7016.26 N 2857.25 E 5966153.45 N 602309.06 E 7.054 2857.25 13456.41 95.370 96.330 8864.40 8947.16 7013.37 N 2890.39 E 5966151.00 N 602342.24 E 8.775 2890.39 13488.28 94,190 99.290 8861.75 8944.51 7009.06 N 2921.85 E 5966147.10 N 602373.75 E 9.968 2921.85 13519.04 91.820 100.570 8860.13 8942.89 7003.76 N 2952.10 E 5966142.21 N 602404.08 E 8.754 2952.10 13551.85 88.890 101.590 8859.93 8942.69 6997.46 N 2984.30 E 5966136,33 N 602436.35 E 9.456 2984.30 13581.49 88,890 104.010 8860.50 8943.26 6990.89 N 3013.19 E 5966130.15 N 602465.33 E 8.163 3013.19 13614.73 90.060 107.430 8860.81 8943.57 6981.89 N 3045.18 E 5966121.57 N 602497.44 E 10.874 3045.18 13646.50 92.470 110.340 8860.11 8942.87 6971.61 N 3075.23 E 5966111.69 N 602527.62 E 11.891 3075.23 13710.45 94.100 108.900 8856.44 8939.20 6950.17 N 3135.37 E 5966091.05 N 602588.03 E 3.399 3135.37 13757.57 94.520 108.680 8852.90 8935.66 6935.04 N 3179.85 E 5966076.51 N 602632.71 E 1.006 3179.85 13805.38 93.900 108.680 8849.39 8932.15 6919.77 N 3225.02 E 5966061.84 N 602678.08 E 1.297 3225.02 . 13849.24 93.890 108.460 8846.41 8929.17 6905.83 N 3266.50 E 5966048.45 N 602719.74 E 0.501 3266.50 13872.59 93.640 108.700 8844.88 8927.64 6898.41 N 3288.58 E 5966041.32 N 602741.92 E 1 .483 3288.58 13901.32 93,730 109.630 8843.03 8925.79 6888.99 N 3315.66 E 5966032.27 N 602769.12 E 3.245 3315.66 13936.33 91.540 112.990 8841 .42 8924.18 6876.29 N 3348,24 E 5966019.99 N 602801.86 E 11.447 3348.24 13969.02 91.110 116.490 8840.67 8923.43 6862.61 N 3377. 92 E 5966006.71 N 602831.72 E 10.784 3377.92 13996.58 90.870 114.430 8840.19 8922.95 6850.77 N 3402.79 E 5965995.20 N 602856.75 E 7.524 3402.79 14031.71 88.210 115,260 8840.47 8923,23 6836.01 N 3434,67 E 5965980.86 N 602888,82 E 7,932 3434.67 14063.34 83.140 116,680 8842.86 8925.62 6822.20 N 3463.01 E 5965967.43 N 602917.35 E 16.642 3463.01 14091.40 82.020 117.480 8846.48 8929.24 6809.54 N 3487.79 E 5965955.10 N 602942.29 E 4.891 3487.79 14127.39 82.050 115.250 8851.47 8934.23 6793.71 N 3519.72 E 5965939.69 N 602974.43 E 6.137 3519.72 14152.16 82.240 112.750 8854.85 8937.61 6783.73 N 3542.14 E 5965930.01 N 602996.97 E 10.028 3542.14 14187.18 82.700 109.810 8859.44 8942.20 6771.13 N 3574.48 E 5965917.84 N 603029.48 E 8.426 3574.48 14222.48 85.430 108.440 8863.09 8945.85 6759.63 N 3607.65 E 5965906.78 N 603062.80 E 8.643 3607.65 10 December, 2004 - 14:15 Page 3 of 4 Dril/Quest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-13APB1 Your Ref: API 500292006970 Job No, AKZZ3369825, Surveyed: 14 November, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 14252,61 86,820 106.280 8865.13 8947.89 6750.66 N 3636.34 E 5965898.19 N 603091.61 E 14283.02 88.670 106.440 8866.33 8949.09 6742.10 N 3665.50 E 5965890,02 N 603120.87 E 14340,00 88.670 106.440 8867.65 8950.41 6725.98 N 3720.13 E 5965874.63 N 603175.72 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 90.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14340.00ft., The Bottom Hole Displacement is 7686,23ft., in the Direction of 28.947° (True), Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11339.16 11385.00 14340.00 6043.96 N 6078.30 N 6725.98 N 1391.63 E 1407.28 E 3720.13 E Tie On Point Window Point Projected Survey 8177.76 8203.80 8950.41 Survey tool program for Z-13APB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11339.16 0.00 8177.76 11339.16 14340.00 8177.76 BP High Accuracy Gyro (Z-13) 8950.41 MWD+IIFR+MS (Z-13APB1) 10 December, 2004 - 14:15 Page 4 of 4 Dogleg Rate (o/100ft) 8.511 6.106 0.000 Vertical Section Comment 3636.34 3665.50 3720.13 Projected Survey BPXA . . Dril/Quest 3.03.06.006 ~ TREE = WELLHEAD = ACTUATOR = KB. ELÐI = BF. ELÐI = KOP= '--'''''''""^,,,·,,^,=_,=~_·_=,v Max Angle = Datum MD = Datum _W.__·_·",_,___·_·_,_,_~_,_",,,~,.,,= 1 0-3/4" CSG, 45.5# L-80, 10 = 9.953" 2672' Top 5-1/2" LNR, - 10,688' Top of Whipstock - 10,865' EZSV Bridge Plug - 10,885' Top 5-1/2" LNR, 11,231' Top of Whipstock 11,385' EZSV Bridge Plug 11,412' Cut TBG - 11,550' TOC 11,900' 7-5/8" x 3-1/2" TIW HBBP PKR (w/RH release latch), 10 = 3.0" -12,014' 3-1/2" TBG, 9.2#, L-80 12071' 3-1/2" x 5-1/2" XO 12071' Top of 5-1/2" LNR 12074' 7-5/8" CSG, 29.7#, 10 = 6.875" 12347' I PBTD H 13017' I DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 RÐI BY REB SIS-MD RNITP JAUKK KB/tlh ?/KAK COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFElY NOTE WAIVER SAFElY NOTE WAIVER SAFElY NOTERÐI. ---4 @ DRj¡¡T . GAS LIFT f'v1ANDRELS ST MD TVD DÐI TYÆ 8 2703 2703 0 3 1/2" X 1 1/2" MMG 7 3203 3198 13 31/2" X 1 1/2" MMG 6 4302 4202 33 31/2" X 1 1/2" MMG 5 5494 5001 55 3 1/2" X 1 1/2" MMG 4 7724 6207 58 31/2" X 1 1/2" MMG ~ 3 9230 7004 56 31/2" X 11/2" MMG 2 10651 7790 52 31/2" X 1 1/2" MMG - ~ "'" 1 11939 8569 52° 31/2" X 1" KBG-2-9 - ~ ~3-1/2" HES X Nipple, ID 2.813"= 2212 3-1/2" 9.2#, 13Cr TBG, ID = 2.992' -1/2" HES X Nipple, ID 2.813"=10581 -1/2" HES RPM Gauge Carrier=10601 D .-13A Actual Completion -1/2" HES X Nipple, ID 2.813"=11998 5-1/2" x 3-1/2" SABL-3 Packer =12021 3-1/2" HES X Nipple, ID 2.75"=12044 3-1/2" HES X Nipple, ID 2.75"=12065 -1/2" Tie back seal assembly=12082 3-1/2" LNR Hanger/ZXP - - 12,074' 5-1/2" 15.5#, L-80 4.95010 @ 12,236 VALVE OCR Dummy Dummy Dummy Dummy Dummy Dummy Dummy LA TCH RKP RK RK RK RK RK RK bottom PBTO -15,374' 3-1/2" Solid LNR, 9.2#, 13Cr -15,441' 4-1/2" Stab, FS, 3-5/8" MTR & 4.75" Bit I Bottom of CMT (25 BBLS below EZSV) -13,150' 5-1/2" 15.5#, L-80 12,243' 12554' H f'v1ARKER JOINT 7 -10 BBL's Squeezed into the Perfs 5-1/2" LNR. 17#, L-80. ,0232 bpf, ID = 4.892" H 13100' I DA TE RÐI BY COMMENTS 10106/04 kwa Prop. Compl. 12/13/04 Alan M Actual Completion 4-3/4" Open hole (PB1 TO) 14,340' PRUDHOE BA Y UNfT WELL: Z-13A ÆRMfT 204-203 API No: 50-029-22069-01 BP Exploration (Alaska) . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Z-13A PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,339.16' MD 11,385.00' MD 14,340.00' 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 ~ ) J ev\ ). du ç Signed 2U ûltrJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 30-Dec-04 ~ ~ L( - J- ¡J '> . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Z-13A PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,339.16' MD 11,385.00' MD 14,340.00' 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 /) / /1 Date ;;( 7)",,).N')- Signed ~ a~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 30-Dec-04 )D'-(-. ~O~ . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well Z-13A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,835.66' MD 10,840.00' MD 15,443.00' MD (if applicable) 30-Dec-04 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 ),7 J~ À.~ ç- Signed ~I/ r el' ~..ijJ0 ( Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ?,J:J GI -. À. () '1 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Z-13A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,835.66' MD 10,840.00' MD 15,443.00' 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 ,.....,11 . 1. 0'./) ~j. Date;' ì JOJ\JvMr(/' Signed lj\ lii~ Jlr Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 30-Dec-04 ?^-a~J-;{(J3 TREE = WELLHEAD = ACTUA TOR = KB, ELEV = BF, ELEV = KOP= Max Angle = m_~~__.~___~,_ Datum MD = DatumTVD= Ze3APB1 P&A U4~~ 10-3/4" CSG, 45.5# ~ L-80, 10 = 9.953" 2672' --- EZSV Bridge P1ug 10,865' Top 5-1/2" LNR, 11,231' Top of Whipstock 11,385' . EZSV - 12,053' 4-1/2" Stab, FS, 3-5/8" MTR & 4.75"Bi/~ þ() EZSV Bridge Plug 11,412' Cut TBG - 11,550' TOC 11,900' 7-5/8" x 3-1/2" TIW HBBP PKR (w/RH release latch), 10 = 3.0" - 12,014' 3-1/2" TBG, 9.2#, L-80 12071' 3-1/2" x 5-1/2" XO 12071' Top of 5-1/2" LNR 12074' 7-5/8" CSG, 29.7#, 10 = 6.875" 12347' DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 REV BY REB SIS-MD RNlTP JAL/KK KB/tlh ?fKAK I PBTD H 13017' -23' MD of Collapsed Kingak 5-1/2" 15.5#, L-80 12,243' 12554' -jMARKERJOINT 1-10 BBL's Squeezed into the Perfs Calculated TOC behind the 7-5/8" CSG Gauge hole -3836' 50% Washout -6673' \ 4-3/4" Open hole (PB1 TO) 14,340' - I 5-1/2" LNR, 17#. L-80, .0232 bpf, 10=4.892" -j 13100' I DATE 10/06/04 REV BY kwa COMMENTS Prop. CampI. COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFETY NOTE WAIVER SAFETY NOTE WAIVER SAFETY NOTE REV, PRUDHOE BA Y UNIT WELL: Z-13A ÆRMIT No: API No: 50-029-22069-01 BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB, ELEV = SF, ELEV = KOP= Max Angle = , ~~M~ "~~_., Datum MD = Datum TVD = _ '__'~'~M .13A Proposed Completion 'b1J4 -I~ 10-3/4" CSG, 45.5# L. L-80, 10 = 9.953" 2672' --- Top 5-1/2" LNR, - 10,690' Top of Whipstock 10,840' EZSV Bridge Plug 10,865' Top 5-1/2" LNR, 11,231' Top of Whipstock 11,385' EZSV Bridge Plug 11,412' Cut TBG - 11,550' TOC 11,900' 7-5/8" x 3-1/2" TIW HBBP PKR (w/RH release latch), 10 = 3.0" - 12,014' 3-1/2" TBG, 9.2#, L-80 12071' 3-1/2" x 5-1/2" XO 12071' Top of 5-1/2" LNR 12074' 7-5/8" CSG, 29.7#, 10 = 6.875" 12347' I PBTD H 13017' I DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 REVSY REB SIS-MD RNlTP JALlKK KB/tlh ?/KAK COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFElY NOTE WAIVER SAFElY NOTE WAIVER SAFElY NOTE REV, 3-1/2" 9.2#, 13CrTBG, 10 = 2.992' 3-1/2" HES X Nipple, 10 = 2.75" - 2,200' ~ Calculated TOC behind the 7-5/8" CSG Gauge hole -3836' 3-1/2" HES Hi-Press X Nipple, 10 = 2.75" 50% Washout -6673' 5-1/2" x 3-1/2" SABL-3 Packer, 10 = 2.78 3-1/2" HES Hi-Press X Nipple, 10 = 2.75" 3-1/2" HES Hi-Press X Nipple, 10 = 2.75" 3-1/2" WLEG 3-1/2" LNR Hanger/ZXP - - 12,085' 5-1/2" 15.5#, L-80 - 12,235' EZSV - 12,053' 4-1/2" Stab, FS, 3-5/8" MTR & 4.75.Bi/~ t:(d PBTO - 15,344' 3-1/2" Solid LNR, 9.2#, 13Cr -15,444' -23' MD of Collapsed Kingak \ 5-1/2" 15.5#, L-80 12,243' 4-3/4" Open hole (PB1 TO) 14,340' 12554' HMARKERJOINT 1-10 BBL's Squeezed into the Perfs - I 5-1/2" LNR, 17#, L-80, .0232 bpf, 10 = 4,892" H 13100' I DATE 1 0/06/04 REV BY kwa COMMENTS Prop. CampI. PRUDHOE SA Y UNrr WELL: Z-13A ÆRMrr No: API No: 50-029-22069-01 BP Exploration (Alaska) . ~û4- 2.D') . Summary and Plan forward 11/20/04 · Decomplete o MIRU o Pull tubing from pre-rig cut o Set EZSV o Set Whipstock and mill a 6-3/4" window in the 7-5/8" casing · Intermediate Section o Kick off in Kingak D interval @ 11385' o Drill 6-3/4" hole to 12,245' (TSAG pick) w/11.2ppg mud o Run & cement 5-1/2" 15.5# L-80 liner · Production Section o Drill out shoe and land 4-3/4" wellbore - 12,850' w/8.4ppg mud · TSAG picked -23'MD / 14'TVD high which led to 5-1/2" liner being set high. This exposed 23' MD of Kingak in the 4-3/4" production hole. Note: This was determined after drilling out the shoe allowing the L WD sensors to log this interval, · The decision was made to drill to TD as quick as possible, limiting the amount of time the Kingak would be open. · At 14,340' the decision was made to trip OOH for a bit. Parameters seen at surface indicated the bit had worn under gauge. · Assembly was tripped OOH. Once on surface it was discovered a -30' fish (Stabilizer, Float Sub, Mud Motor and Bit) was left in the hole. · After reviewing the logs and discussions with the rig team it appeared there was chance the fish was twisted off at the shoe. · Tripped in the hole with an overshot assembly. Saw a pressure increase and weight 7' outside shoe. All parameters (increased pressure and initial weight) indicated we had the fish, POOH. Turned out to be shale packed inside of the overshot · TIH with the same overshot assembly washing to 12,545'. BHA packing off, POOH. . . . TIH with a mill to push the fish to bottom, wash and ream to - 12,806'. Assembly packed off. Pull up hole while attempting to regain circulation. Could not regain consistent circulation until back inside the shoe. Circulate liner clean and attempt to wash to bottom. Assembly packed off again. Decision made to P&A wellbore. . PLANNED OPERATIONS · RIH with 5-1/2" EZSV and set at 12,000'. Establish a injection rate. o Pump 25 bbls 15.8 cement below EZSV (estimated bottom off cement in open hole - 13,150'). Unsting from retainer and start pumping cement (Close the bag and take returns through choke holding pressure to keep the cement from running away). Once the cement is within - 5 bbls of the stinger reengage and bullhead remaining fluid and cement. Unsting from the retainer and lay an additional 5 bbls of cement (200') on top of the EZSV. The estimated TOC will be 11,800' inside the 5-1/2" liner. · RU e-line and RIH with a 7-5/8" EZSV and CCL, set -10,885' (the top of the whipstock should be - 10,865'. If needed, to avoid cutting a collar, the EZSV can be moved up hole (Call and discuss with the town ODE). The T JE is -10,912' MD (new RKBE). The KO at 10,865' allows the window to be in the T JF (a more stable formation than the T JE). RD e-line. Note: We only have 1600' of 5-1/2" 15.5# L-BO BTC w/special clearance collars for this job. The current planned depths will use 1450'. · RU and RIH with a 7-5/8" whipstock and MWD tools for orientation. Set on the 7 -5/8" EZSVand mill a 6-3/4" window with 11.3 ppg LSND mud. FIT to 12.5 ppg. · PU DIRlGRlRES/PWD/DDS tools and a 1.5 motor to drill to TSAG at an estimated depth of 12,169'. Note: Discussion ongoing about the bit selection. Choices are the recent 6-3/4" Hycalog PDC or the 7" Hughes bi-center used with success on well B-05B. · Upon reaching TD circulate well bore clean and trip to the shoe. Hang off and perform the BOPE and any needed rig maintenance (slip and cutting of drill line?). This extra time (6-10 hours) at the shoe will allow the Kingak to "relax" before wiping the hole. Trip back to bottom and circulate the well bore clean. Spot a liner running pill before tripping out of the hole. POOH. · RU/MU 5-1/2" 15.5# L-80 BTC linerw/special clearance collars and RIH. Cement the same. POOH laying down liner running tools. · PU 4-3/4" DIR/GR/RES assembly and a 1.5 motor with PDC. RIH and drill to TD. NOTE: BHA, BIT and operational parameter discussions will take place on Monday with the team. ^1e<:i~iA-/V'c.~( S¡'cU'þ'^-<-{c ve-l~~íJv¡ O'vø'ûrv{ed h_A µC;4 U/W(µ04. W¿----W ~ ( I r \PV-l ¡ I'z. L I ~¡(lO 4 ' TREE" WELLHEAD" 'm'A~<., m<..n.~.___~~« ACTUATOR = KB. ELEV = BF, ELEV " KOP= Max Angle" ~^ _~~~_,n"^ , Datum MD = Datum TVD = .13A Proposed Completion . 10-3/4" CSG, 45.5# ~ L-80, ID = 9.953" 2672' Top 5-112" LNR, - 10,715' Top of Whipstock - 10,865' EZSV Bridge Plug -10,885' Top 5-1/2" LNR, 11,231' Top of Whipstock 11,385' EZSV Bridge Plug 11,412' Cut TBG - 11,550' TOC 11,900' 7-5/8" x 3-1/2" TIW HBBP PKR (w/RH release latch), ID = 3.0" - 12,014' 3-1/2" TBG, 9.2#, L-80 12071' 3-1/2" x 5-1/2" XO 12071' Top of 5-1/2" LNR 12074' 7-5/8" CSG, 29.7#, ID = 6.875" 12347' I PBTD H 13017' ~ DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 REV BY REB SIS-MD RN/TP JAL/KK KB/tlh ?/KAK COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFETY NOTE WAIVER SAFETY NOTE WAIVER SAFETY NOTE REV. 3-1/2" 9.2#, 13Cr TBG, ID = 2.992' 3-1/2" HES X Nipple, ID = 2.75" - 2,200' ~ Calculated TOC behind the 7-5/8" CSG Gauge hole -3836' 3-1/2" HES Hi-Press X Nipple, ID = 2.75" 50% Washout -6673' 5-1/2" x 3-1/2" SABL-3 Packer, ID = 2.78 3-1/2" HES Hi-Press X Nipple, ID = 2.75" 3-1/2" HES Hi-Press X Nipple, ID = 2.75" 3-1/2" WLEG 3-1/2" LNR Hanger/ZXP - - 12,020' 5-1/2" 15.5#, L-80 ____ -12,170' 4-1/2" Stab, FS, 3-5/8" MTR & 4.75" Bit PBTD -15,368' 3-1/2" Solid LNR, 9.2#, 13Cr - 15,468' ! Bottom of CMT (25 BBLS below EZSV) - 13,150' \ 4-3/4" Open hole (PB1 TD) 14,340' 5-1/2" 15.5#, L-80 12,243' 12554' HMARKERJOINT > -10 BBL's Squeezed into the Perfs " _ I 5-1/2" LNR, 17#, L-80. .0232 bpf, ID = 4,892" H 13100' I DATE 10/06/04 REV BY COMMENTS kw a Prop. CampI. PRUDHOE BA Y UNIT WELL: Z-13A ÆRMIT No: API No: 50-029-22069-01 BP Exploration (Alaska) · . ~ ~ !Æ ~ E (ill F !Æ ~!Æ ~ ~~!Æ / FRANK H. MURKO~ GOVERNOR A IfASIiA OIL AND GAS / CONSERVATION COMMISSION / 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-13A BP Exploration (Alaska) Inc. Permit No: 204-203 Surface Location: 981' SNL, 3132' WEL, SEC. 19, TUN, R12E, UM Bottomhole Location: 119' NSL, 1776' EWL, SEC. 08, TIIN, RI2E, UM Dear Mr. Crane: 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 Commissio 0 itness any required test. Contact the Commission's petroleum field inspector at (907) 65 -360 (pager). BY ORDER OF THE COMMISSION DATED this II day of October, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. WGÁ- 10181 z.004 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: 981' SNL, 3132' WEL, SEC. 19, T11N, R12E, UM ' Top of Productive Horizon: 583' NSL, 819'WEL, SEC. 07, T11N, R12E, UM Total Depth: 119' NSL, 1776' EWL, SEC. 08, T11N, R12E, UM' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599545 y- 5959100 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 11378 feet Maximum Hole Angle: 93 degrees . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEr I PERMIT TO DRILL ;\ ED 20 MC 25.005 OCT 0 7 2004 11 b. Current Well Class 0 Exploratory II Development Oil ¿ 0 Multiple Zone o Stratigraphic Test 0 Service 0 CA~;tt&~a~'!~¡ssiOf1 5. Bond: IBI Blanket 0 Single Well 11. Well Namemrnh~er: Bond No. 2S100302630-277 PBU Z-1~Ä / 6. Proposed Depth: 12. Field I Pool(s): MD 15557 TVD 9049 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 047450 8. Land Use Permit: 13. Approximate Spud Date: /'. October 18, 2004 14. Distance to Nearest Property: 10500' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 83.9 feet Z-25 is 1637' away at 14354' 17. Maximum Anticipated Pressures in psig (see 20 AAC_25.035) Downhole: '5700 Surface: ?,.8 'to WGA- 18. Casing Program: Size Casinç¡ 5-1/2" 3-1/2" Hole 6-3/4" 4-3/4" Weiç¡ht 15.5# 9.2# Grade Coupling Lenç¡th L-80 BTC-M 1017' 13Cr80 V AM ACE 3462' MD TVD MD TVD (includinç¡ stage data) 11228' 8116' 12245' 8738' 163cuftClass'G" 12095' 8643' 15557' 9049' 283 cu ft Class 'G' / 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 13100 9259 None 13017 9201 None Structural Conductor 110' 20" 110' 110' Surface 2673' 10-3/4" 1999 cu ft Permafrost 2673' 2673' Intermediate 12347' 7-5/8" 1931 cu ft Class 'G' 12347' 8747' Production Liner 1026' 5-1/2" 215 cu ft Class 'G' 12074' - 13100' 8587' - 9259' 20. Attachments IBI Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8895' - 8997' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements Perforation Depth MD (ft): 12581' - 12725' 21. Verbal Approval: Commission Representative: 22. that the foregoing is true and correct to the best of my knowledge. Crane Title Senior Drilling Engineer Date: Contact Ken Allen, 564-4366 Permit To Drill Number:..20 c¡ - zo. '3 50- 029-22069-01-00 Conditions of Approval: Samples Required 0 Yes ")š,NO Hy ogen Sulfide Measures ,)lYes 0 No Other: ß.O E to ·š ~ ~O P! t ) P e-v c.. C f e·ý ~ s 10 ~ 40L Permit Approval I ,J. rI See cover letter for Date: 10/ ¡I; () T other requirements Mud Log Required 0 Yes ,g'No Directional Survey Required ::S-Yes 0 No S i Iø . 000 duv "¿ce;l 0f2P/ / ,~'- ¥~c... DtfY- OR1G/~~Al APPROVED BY THE COMMISSION Date ~f ~~e . . Planned Well Summary Well Z -13A I I Well Sidetrack 1 II Target I Zone 4 Type horizontal Objective I AFE Number: I PBD 4P2297 I I API Number: 50-029-~1 I L '2.0 {,~ WGIt- Suñace NorthinQ EastinQ I Offsets I TRS I Location 5,959,099.96 599,545 981' FNL 13132' FEL 11 N, 12E, 19 Target Northing Easting I Offsets TRS Location 5,965,973 601,741 4697' FNL 1819' FEL 11 N, 12 E, 7 Target NorthinQ EastinQ I Offsets TRS Location 5,965,980 602,936 4706'FNL/4903'FEL 11 N, 12 E, 8 Bottom Northing Easting Offsets TRS Location 5,965,545 604,343 5161' FNL 13504' FEL 11 N, 12 E, 8 I Planned KOP: Planned Spud: 111 ,378' md 10/18/04 I Planned TD: 115,557' md Planned TVD: 9,049' ¡ Rig: I Nabors 7ES I I BFE: 155.42 I RTE: 183.90' Proximity Issues: Survey Program: Nearest Well: Nearest Property Line Directional Proaram WP05 I Exit point: I 11,378' md 1 8,116' sstvd -600 at 7,372' in the original well bore, -930 at -13,500' in the planned 4- 3/4" production horizontal. There are no close approach issues in drilling Z-13A. All surrounding wells pass major risk criteria. Standard MWD+IIFR+MS Well Z-25, with center-te-center distance of -1637' at 14,354' md. 10,500' to the nearest PBU property line. Approved Well plan: Maximum Hole Inclination: Loaaina Proaram Hole Section: 6-3/4" Intermediate: Required Sensors 1 Service Real time MWD Dir/GRlRes/PWD throughout the interval. Two sample catchers will be required at company man call out. J-02B Sidetrack Version 1.0 Page 1 4-3/4" production: Cased Hole: Open Hole: . . Real time MWD Dir/GRlRes throughout the interval. Two sample catchers will be required at company man call out. RST planned POST rig None planned Mud Proaram Type LSND Hole Section I operation: I Set Whip stock / mill window in 7-5/8" I Density (ppg) I PV I Funnel Vis I yp I Chlorides I API FL I pH 11.2 10-15 65-90 35-40 <1,500 4-6 9.0-9.5 Hole Section I operation: ~J~ I Den~) 110"-"15 I Hole Section I operation: Type I Density (ppg) I PV I FloPro SF 8.4 - 8.6 7 - 12 I Drilling 6-3/4" intermediate interval Funnel Vis I yp I Chlorides I API FL 50 - 80 22 - 28 < 1,500 4 - 6 pH 9.0 I Drilling 4-3/4" production interval Funnel Vis I yp I LSRV I API FL 45 - 60 22 - 30 > 30,000 4 - 8 pH 9.0-9.5 Casina I Tubina Proaram Hole CasinglTubing Wt. Grade Connection Length Top Bottom Size Size / / md/tvd md/tvd 6-3/4" 5-1/2" 15.5# L-80 BTC-M 1,017' 11,228'/8,116' 12,245'/8,738' (w/special clearance collars) 4-3/4" 3-1/2" 9.2# 13Cr-80 VAM ACE 3,462' 12,095'/8,643' 15,557'/9,049' Tubing 3-1/2" 9.2# 13Cr-80 VAM ACE 12,095' Surface 12,095'/8,643' Casing String: Slurry Design Basis: Fluids Sequence I Volume: Casing String: Slurry Design Basis: J-02B Sidetrack Version 1.0 Cementina Proaram 5-1/2", 15.5#, L-80, BTC-M (w/special clearance collars) drilling liner Lead slurry: None planned Tail slurry: fully cemented 5-1/2" X 6-3/4" annulus, plus 80' of 5-1/2", 15.5# shoe track, plus 150' of 5-1/2" x 7-5/8" liner lap. Pre-Flush None planned Spacer 20bbls MudPUSH II at 12.2ppg Lead Slurry None planned I Æ ::2 ,.A Q Tail Slurry 29bbls 1163 cf ~ sx Class 'G', 15.8PP9~ Cf/sk. 3 1/2", 9.2#, L-80, VAM ACE solid production liner Lead slurry: none planned Tail slurry: 2085' of 3-1/2" X 4-3/4" annulus with 40% excess, plus 80' of 3- 1/2", 9.2# shoe track, plus 150' of 5-1/2" X 3-1/2" liner lap, plus 200' of 5-1/2" X 2-7/8" drill pipe annulus. Pre-Flush I 15bbls CW100 Page 2 Fluids Sequence I Volume: Test 7-5/8" casing to surface Intermediate casing window 7-5/8" casing I 5-1/2" liner Intermediate liner shoe . . Pre-Flush Spacer Lead Slurry Tail Slurry 15bbls CW100 20bbls MudPUSH II at 9.6ppg None planned ~/) .h:..-¡ 51bbl/283 cf ~g"sx Class 'G', 15.8ppg (W/Silica)~~3-éf/Sk. CasinQ I Formation InteQritv TestinQ Test Point Bridge plug to surface 20' beyond middle of window Float equipment to surface 20' new formation beyond shoe Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500psi surface 12.5ppg EMW 3,500psi surface 10.0ppg EMW Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blindlshear 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 anticipated BHP: Maximum suñace pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned BOPE test pressure: Well Interval: Maximum anticipated BHP: Maximum suñace pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned completion fluid: Planned BOPE test pressure: 6-3/4" Intermediate liner section 3,639psi at 8,654' sstvd. 2,7 P i (based upon BHP and a full column of gas from TD @ 0.10 pSi/ft) I . e with 11.5 ppg EMW FIT (FIT to 12.5 ppg EMW) Opsi low I 3,500psi high ,/ 250psi low I 3,500psi high - 7 day test cycle until a window is milled in 7-5/8" liner. Once a window is milled a 14 day test cycle can <' commence. 4-3/4" production liner section si at 8,800' sstvd. 2,820 si (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) ~Jn te with 8.8 ppg EMW FIT (FIT to 10.0 ppg EMW) 250psi low I 3,500psi high / 8.4ppg seawater I 6.8ppg Diesel 250psi low 13,500psi high -14 day test cycle Disposal Annular Injection: 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 DS-04. Any metal cuttings should be sent to the North Slope Borough. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 J-02B Sidetrack Version 1.0 Page 3 . . I for injection. All Class I wastes are to be hauled to Pad 3 for disposal. Geoloaic Proanosis Formation MD TVDss Comments TJD 11357 -8100 Kickoff 11378 8116 TJC -8368 TJB -8547 TSGR -8654 gas TSHU -8687 TElL -8792 TSAD (near landing) -8808 oil 45N (near Toe) -8840 oil 45P -8843 oil 44N -8865 oil 43N (at heel) -8890 oil 43N (at toe) -8921 oil 42N -8947 oil/water 42P -8961 oil/water TD -8965 water TD Criteria TD Criteria: Final TD will be logged OWC or polygon hardline, whichever is reached after having drilled enough 43P to have 15 ft of perforations. Do not drill past the end of the target geologic polygon. Fault Proanosis Formation TVDss Estimated Direction of Fault Encountered MD Intersect Intersect Throw Throw Uncertainty Fault 01 Zone 46P 13,650' 8,858' 15' - 50' ~ D to E +1- 150' NOTE: Fault 01 was first identified on the S3 poststack dataset, and was not interprettable on previous volumes. This fault appears to die out in the upper part of Zone 4, and there is no offset present in the TSGR reflector. This leads to a larger uncertainty in the fault throw estimate. It is expected that the fault throw increases with depth, and the fault displays -90 ft. of throw at the lisburne level. The fault strikes North-South, and Z-13A will be crossing Fault 01 at a near perpendicular angle. The fault does not appear on the coherency image in the tech package, since the fault dies out before reaching the reflector where the coherency was extracted. This fault has not been crossed before. The Regional Fault #1 was most likely crossed by the parent well in the upper Kingak. There is a small chance that we will cross it in this well. No losses were encountered while crossing this fault, or anywhere else in Z-13. J-02B Sidetrack Version 1.0 Page 4 . . Operations Summary Pre-RiQ Operations: 1. Bleed OA, IA and tubing pressures to zero. Test the 7-5/8" and Tubing pack-off's, Function all LDS, repair or replace as necessary. !ill Done 07/25/04 PPPOT-IC passed to 3500 psi, PPPOT- T passed to 5000 psi. 2. MIT the OA to 2000 psi. bZJ Done 08/01/04 Passed to 2500 psi. 3. RU Slick line. Pull TTP set 12,006'. RIH, drift tubing, tag TD and perform SBHPT. 4. RU Coil Tubing. Cement P & A Z-13 with coil tubing from the PBTD to - 11900'. Cement calculations . include 22 BBLS for the 5-1/2" tubing, 1-1/2 BBLS for the 3-1/2" tubing and 10 BBLS squeezed into ,/ the perforations for a total of 33-1/2 BBLS of cement. 5. CMIT IA and tubing to 3500 psi for 30 minutes (this should be done post coil cement plug, pre cement plug failed at .42 bpm). 6. RU Slick-line. Drift tubing and tag TOC at 11900' with gauge ring 1 junk basket. 7. RU E-line. RIH and chemical cut tubing in the middle of the joint +1- 11550'. h* Tubing Tally dated 8/25/90 *** Note: Cut will be between GLM 1 & 2, Do not cut shallower than 11,500'. 8. Circulate the well to seawater. Freeze protect the IA and tubing with diesel to - 2200'. 9. Bleed all pressures to zero. Set BPV. Secure well. 10. Remove the wellhouse. If necessary, level the pad. RiQ Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to Sea Water. 3. Monitor OA, IA and T for pressure. Verify well is dead. 4. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 5. Pull 3-1/2" TDS tubing from pre-rig cut at - 11550' (Have a spear on location as a contingency). Tubing is in relatively good condition. The 1999 Kinley caliper recorded shallow line and pitting corrosion. The average penetration is about 30% wall loss with a few joints showing upwards of - 50% wall loss. 6. RU e-line. Run GRlJB for 7-5/8",29.7# casing to top of tubing stub. 7. MU 7-5/8", 29.7# EZSV bridge plug on e-line with CCL. RIH and set - 11398' (Set the bridge plug at ±11398' to avoid cutting a casing collar with the whipstock mill). RD e-line. Close blinds and test 7-5/8'(' casing to 3500 psi for 30 minutes while recording on chart. TMs", l c::> - 401 oA> ý) YO tI A- . 8. PU milling 1 whipstock assembly. RIH picking up DP to top EZSV. Orient and set th~ whipstock. Change well over to 11.2 ppg milling fluid. Note: If MWD signals are too weak to obtain toolfaces, swap over to 11.2 ppg milling fluid before setting the whipstock. "\( 9. Mill a window in the 7-5/8" casing at ±11378' MD plus 20' from mid window. Perform FIT to 12.5 ppg. ,/ POOH for drilling BHA. Verify that the mud weight is at least 11.2 ppg prior to cutting the window. 10. MU the 6-3/4" drilling assembly with DIRlGRlRES/PWD and RIH. Kick off and drill 6-3/4" intermediate interval, dropping inclination and turning at 4°/100' to -50° inclination & -51 ° azimuth. 11. Drill ahead to casing point at Top Sag River to an estimated depth of 12245' MD. / 12. Run and cement a 5-1/2" drilling liner throughout the 6-3/4" hole and back into the 7-5/8" casing 150' / to 11228' MD. Set hanger 1 liner top packer and displace cement with mud. Once cement has been displaced circulate well to sea water displacing entire LSND mud system. POOH. 13. MU 4-3/4" BHA with DIRlGRlRES and RIH to the landi99 collar. 14. Pressure test wellbore to 3500 psi for 30 minutes. 15. While drilling shoe track swap over to the 8.5 ppg FloPro mud system. The complete swap over to 85 / mud should be completed before drilling out the float shoe. Drill 20' of new formation. Perform FIT to 10.0 ppg. 16. Build to horiztonal and drill the 4-3/4" production interval as per directional plan to and estimated TD of 15557' . J-02B Sidetrack Version 1.0 Page 5 . . 17. Run and cement a 3-1/2" 13Cr-80 liner throughout the 4-3/4" wellbore and 150' back into the 5-1/2" drilling liner to 12095' MD. Set liner top packer and displace well to clean seawater above the liner top. 18. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance by 100-200 psi. POOH, LD DP and perf guns. ,/ 19. Run 3-1/2" 13Cr-80 completion tying into the 3-1/2" liner top. 20. Set packer, test and record the tubing to 3500 psi and annulus to 3500 psi for 30 minutes each. 21. Set and test TWC to 1000 psi. 22. ND BOPE. NU and test the tree to 5000 psi. Pull TWC. ./ 23. Freeze protect the well to -2200'. Set BPV and secure the well. 24. RDMO. Post-Ria Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'X' nipple below the new production packer. 3. Install gas lift valves. Job 1: Move In I Ria Up I Test BOPE Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. .:. "Hydrogen Sulfide" SOP. .:. "ADW Rig Move" RP. Issues and Potential Hazards > BOP test interval during this phase is 7 days. > No wells will require shut-in for the rig move onto Z-13A. However, Z-12 is about 35' to the We!.t and Z-14 is about 35' to the East. These are the two closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. > The Z-13 well bore will be secured with the following barriers: .:. Note on barriers during MIRU procedures: · Tubing - Tested cement plug and a BPV. · IA - Tested cement plug and the annular valve. · OA - Kill weight fluid, tested Annulus and annular valve. .:. Note on barriers during ND Tree I NU BOP Procedures · Tubing - Tested cement plug and a TWC. · IA - Tested cement plug and the annular valve. · OA - Kill weight fluid, tested Annulus and annular valve > Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. > Z-Pad is rr.9Jdesignated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Reading Date #1 Closest SHL with H2S Reading Z-12 NA #2 Closest SHL with H2S Reading Z-14 18 1/1/1996 #1 Closest BHL with H2S Reading Z-29 NA #2 Closest BHL with H2S Reading Z-27 NA Max Recorded H2S Reading on the Pad Z-14 18 1/1/1996 Z pad H2S levels are typically 10-20 ppm. J-02B Sidetrack Version 1.0 Page 6 . . :Þ> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: De-complete Well Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ BOP test interval during this phase is 7 days. ~ Monitor the well to ensure the fluid column remains static prior to pulling the completion. ~ Note and record required PU weight to pull tubing at cut point (-11,550'). ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ The existing wellhead is a "FMC/BP Slimhole" completed in 1990. Is has 7-5/8" intermediate casing set on a mandrel hanger and packoff. The current completion is a 11" x 3-1/2" TDS hanger with "H" profile back pressure valve. Have a spear on location as a contingency to pull the Hanger to the floor. ~ There is a 3-1/2" OTIS BVLN and flow coupling at 2100' with 2 encapsulated control lines run to surface. The current tubing tally states there are 33 rubber protectors and 2 steel bands securing the control lines. Job 3: Run Whip Stock Reference RP .:. "Whipstock Sidetrack" RP. .:. "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards ~ BOP test interval during this phase is 7 days until the window is milled into formation. Once the window is milled the 14 day test cycle starts and continues until the rig moves off the well. ~ A 7-5/8 whip stock will be run and set in the existing 7-5/8" casing. ~ According to the volumes pumped, there should be cement behind the 7-5/8" casing at the sidetrack point. ~ There should NOT be the possibility of a centralizer on the 7-5/8" casing at window milling depth. 7-5/8" casing running notes state centralizers were run on the bottom 3 joints and from 2956 to surface on every 3rd joint. ~ The window will be cut in the existing 7-5/8 casing into the Kingak D interval. Ensure entire well bore has been circulated to 11.2ppg mud before milling commences. ~ Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. ~ Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. J-02B Sidetrack Version 1.0 Page 7 . . Job 5: Drill 6-3/4" Intermedaite Hole Interval Reference RP .:. "Leak-off and Formation Integrity Tests" SOP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Management:' RP .:. "Shale Drilling, Kingak and HRZ' RP. Issues and Potential Hazards ~ This well bore will exit the original well in the upper Kingak shale (T JD -11378' MD), and drill :0 the top of the Sag River formation (-12245' MD). For this well, the Kingak will require a mud weight of 11.2 ppg, according to the Kingak Polar plot. Maintain mud weight at 11.2 from the window to 5-1/2" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 9.4 ppg pore pressure at the Sag River depth, a fracture gradient of 11.5 ppg at the 9 5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance is infinite. ~ There is a slight chance we will cross a fault in the intermediate section. The regional fault #1 was most likely crossed by the parent wellbore in the upper Kingak. There is a small chance this well will cross it in this well. No losses were encountered while crossing this fault, or anywhere else in Z-13. The crossing of this fault is deemed a low risk hazard. Job 6: Run and Cement 5-1/2" Intermediate Liner Reference RP .:. "Shale Drilling, Kingak and HRZ' RP. .:. "Intermediate Casing and Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner' RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab I 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. ~ Following the cement job the entire wellbore should be swapped over to sea water before pullir:g out of the hole. Previous wells have had problems getting a good mud swap out due to high pressures and slow pump rates once the "small" -3" tools/BHA are in the hole. J-02B Sidetrack Version 1.0 Page 8 . . Job 7: Drill 4-3/4" Production Hole Interval Reference RP .:. "Leak-off and Formation Integrity Tests" SOP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Managemenf' RP Issues and Potential Hazards ~ The parent Z-13 well bore does not have a history of losses. The Z-13A production section crosses one possible fault, but there is a low-medium probability of having associated losses or hole stability problems. The directional plan was designed to cross this fault as perpendicular as possible. ~ Differential sticking is a concern. The 8.4 - 8.6 ppg mud will be -0.5 ppg over balanced to the Sag River and Ivishak formations. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). ~ Tie the MWD Gamma Ray log back into parent well bore log in the wellsite geologist possession. A 200' MAD pass above the window is usually sufficient. Job 9: Run 3-1/2" Production Liner Reference RP .:. "Modified Conventional Liner Cementing" RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ The completion design is to run a 3-1/2", 9.2#, 13Cr-80 VAM Ace solid liner throughout the production interval. ~ Differential sticking is possible. The 8.4 - 8.6 ppg Flo-Pro will be -0.5 ppg over balanced to the Sag River and Ivishak formations. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 3-1/2" liner will be run to extend -150' back up into the 5-1/2" liner. Phase 10: DPC Perforate Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards ~ The well will be DPC perforated, -150psi overbalanced, after running and cementing the 3-1/2 liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. J-02B Sidetrack Version 1.0 Page 9 . . ~ Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Job 12: Run 3 %" 13Cr-80 Completion Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Casing and Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well to 2200'. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. ~ The completion, as designed, will be to run a 3-1/2",9.2#, 13Cr-80, VAM Ace production tubing string, stinging into the 3-1/2" production liner tieback sleeve. ~ Ensure High pressure X Nipples are used so proper packer setting pressures can be achieved. Take all the normal precautions while running the Yam Ace 13Cr-80 tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Tubing should arrive on location with the proper thread dope. Confirm type of thread compound prior to RIH. Job 13: ND/NU/Release Ria Reference RP .:. "ADW Rig Move" RP. .:. "Freeze Protecting an Inner Annulus" RP. Issues and Potential Hazards ~ No wells will require shut-in for the rig move off Z-13A. However, Z-12 is about 35' to the West and Z-14 is about 35' to the East. These are the two closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ Note on Barriers during the ND BOP I NU Tree procedures: · Tubing - Kill weight fluid and a TWC. · IA - Kill weight fluid and annular valve. · OA - Kill weight fluid, tested Annulus and annular valve. ~ Note on Barriers during the RDMO procedures: · Tubing - Kill weight fluid and a TWC. · IA - Kill weight fluid and annular valve. · OA - Kill weight fluid, tested Annulus and annular valve. J-02B Sidetrack Version 1.0 Page 10 MCEVOY FMC BAKER 91.74' 55.42' c~_n~,._~_'~m._~.....~~ 3099' mum>mmu~u.,.~".~...'"'''''''''' 60 @ 7272' 12576' 8800' SS . TREE = . WELLHEAD = m , ~~'m'~u..~~, ACTUATOR = KB. ELEV = ~~~,~w~uo>...".,~'..'.....m.' BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = Z-13 / Current . ~OTES: ***T X IA COMM. (02/08/03 W AlVER)*** 2100' 1-13-1/2" OTIS SSSV LAND. NIP, ID = 2.75" , 10-3/4" CSG, 45.5#, L-80, ID = 9.953 H 2672' I--.J ~ ST MD lVD 6 3005 2913 5 5820 5100 L 4 8287 6405 3 9979 7318 2 11010 7909 1 11976 8441 GAS LIFT MANDRELS DEV ìYÆ VLV LATCH PORT DATE 7 MEARL SPG RA 16 12/07/95 54 MEARL DMY RA 0 58 MEARL DOME RA 16 12/07/95 58 MEARL DMY RA 0 57 MEARL DMY RA 0 57 MEARL OGLV RA 20 12/07/95 Calculated TOC Gauge hole -3836' 50% Washout -6673' Minimum ID = 2.750" @ 2100' 3-1/2" OTIS SSSV NIPPLE I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 12071' 1 I TOP OF 5-1/2" LNR H 12074' 7-5/8" CSG, 29,7#, 10 = 6,875" H 12347' PERFORA TION SUMMARY REF LOG: CNL ON 08/16/90 ANGLE AT TOP PERF: 46@ 12581' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-118" 4 12581 - 12611 0 11/05/94 2-1/2" 4 12616 - 12646 0 02/13/95 4" 4 12662 - 12725 0 08/21/95 I PBTD H 13017' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" H 13100' DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 OA TE REV BY REV BY REB SIS-MD RNlTP JALlKK KB/tlh ?/KAK COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFETY NOTE WAIVER SAFETY NOTE WAIVER SAFETY NOTE REV. ~ :g: Z' ( ... ~ . ~ . ~ COMMENTS I 12006' H 3-1/2" PARKERSWS NIP, 10=2.750" 12014' 12037' 12058' 12071' 12071' 12081' '17-5/8" x 3-1/2" TIW HBBP PKR (WITH RIGHT-HAND RELEASE LA TCH), ID = 3.00" 1-1 3-1/2" PARKER SWS NIP, ID = 2.750" H 3-1/2" PARKERSWS NIP, ID= 2.750" H 3-1/2" X 5-1/2" XO I H BAKER SEAL ASSYINO SEALS, ID=2.750" 1 H ELMO TT LOGGED 10103/90 I I 12554' HMARKERJOINT , PRUDHOE BAY UNIT WELL: 2-13 PERMIT No: 1900940 API No: 50-029-22069-00 SEC 19, T11N, R12E, 981' FNL, 1821' FWL BP Exploration (Alaska) TREE = MCEVOY . WELLHEAD = FMC " '~~~m~~M",.~ ACTUA TOR = BAKER KB. ELEV = 91.74' ~....~m.,."......~~~ BF. ELEV = 55.42' _~~m~~~._.~.'''~'m_ KOP = 3099' ~""""""""___" ,un"~m';;'.' Max Ang!~.~~ _60 @ 7272' Datum MD = 12576' Datum lVD = 8800' SS . 10-3/4" CSG, 45.5#, L-80, ID = 9.953 1-1 2672' ¡-----J Calculated TOC Gauge hole -3836' 50% Washout -6673' Minimum ID = 2.750" @ 2100' 3-1/2" OTIS SSSV NIPPLE I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2,992" H 12071' I I TOP OF 5-1/2" LNR H 12074' 7-5/8" CSG, 29.7#, ID = 6.875" H 12347' PERFORATION SUMMARY REF LOG: CNL ON 08/16/90 ANGLE AT TOP PERF: 46 @ 12581' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 4 12581 - 12611 0 11/05/94 2-1/2" 4 12616 - 12646 0 02/13/95 4" 4 12662 - 12725 0 08/21/95 I PBTD H 13017' 5-1/2" LNR, 17#, L-80, ,0232 bpf, ID = 4.892" H 13100' Z-13 / Pre-Rig . S~OTES: ***T X IA COMM. (02/08/03 W AlVER)*** 2100' H3-1/2" OTIS SSSV LAND. NIP, ID = 2.75" I ~ ST MD lVD 6 3005 2913 5 5820 5100 L 4 8287 6405 3 9979 7318 2 11010 7909 1 11976 8441 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 7 MEARL SPG RA 16 12/07/95 54 MEARL DMY RA 0 58 MEARL DOME RA 16 12/07/95 58 MEARL DMY RA 0 57 MEARL DMY RA 0 57 MEARL OGLV RA 20 12/07/95 , / ,~., Cut TBG - 11,550' TOC 11,900' / 12006' H 3-1/2" PARKERSWS NIP, ID= 2.750" DATE REV BY COMMENTS DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WArvER SAFETY NOTE WArvER SAFETY NOTE WArvERSAFETY NOTE REV. REV BY REB SIS-MD RN/TP JAL/KK KB/tlh ?/KAK 12014' 12037' 12058' 12071' 12071' 12081' 117-5/8" x 3-1/2" TIW HBBP PKR (WITH RIGHT-HAND RELEASE LA TCH), ID = 3.00" H 3-1/2" PARKER SWS NIP, ID = 2.750" H 3-1/2" PARKER SWS NIP, ID = 2,750" H 3-1/2" X 5-1/2" XO I H BAKER SEAL ASSY INO SEALS, ID = 2.750" I H ELMD TT LOGGED 10103/90 I I 12554' H MARKER JOINT I ) -10 BBL's Squeezed into the Perfs PRUDHOE BAY UNIT WELL: Z-13 PERMIT No: 1900940 API No: 50-029-22069-00 SEC 19, T11N, R12E, 981' FNL, 1821' FWL BP Exploration (Alaska) TREE = . WELLHEAD = ~n~" "n~< ACTUATOR = KB. ELEV = BF. ELEV = " ~.MM.~'n"'''''...'n' KOP= Max Angle = Datum MD = Datum TVD = .-13A ( Proposed Completion . 3-1/2" 9.2#, 13Cr TBG, 10 = 2.992' 3-1/2" HES X Nipple, 10 = 2.75" - 2,200' 10-3/4" CSG, 4S.S# .. L-80, 10 = 9.9S3" 2672' ~ Top S-1/2" LNR, - 11228' ~ Calculated TOC behind the 7 -S/8" CSG Gauge hole -3836' 3-1/2" HES Hi-Press X Nipple, 10 = 2.75" SO% Washout -6673' 5-1/2" x 3-1/2" SABL-3 Packer, ID = 2.78 3-1/2" HES Hi-Press X Nipple, 10 = 2.75" 3-1/2" HES Hi-Press X Nipple, ID = 2.75" 3-1/2" WLEG 3-1/2" LNR Hanger/ZXP - -12,095' I PBTD H 13017' I Top of Whipstock - 11378' EZSV Bridge Plug - 11,398' Cut TBG - 11,550' TOC 11,900' 7-S/8" x 3-1/2" TIW HBBP PKR (w/RH release latch), 10 = 3.0" -12,14' 3-1/2" TBG, 9.2#, L-80 12071' 3-1/2" x S-1/2" XO 12071' PBTO -15,477' 3-1/2" Solid LNR, 9.2#, 13Cr - 15,557' Top of S-1/2" LNR 12074' 7-S/8" CSG, 29.7#, 10 = 6.87S" 12347' I 12554' -fMARKERJOINT I 7 -10 BBL's Squeezed into the Perfs 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" -f 13100' I DATE 08/25/90 03/13/01 06/16/01 10/12/02 11/08/02 02/08/03 REV BY RES SIS-MD RNlTP JA LIKK KB/tlh ?/KAK COMMENTS ORIGINAL COMPLETION FINAL CORRECTIONS WAIVER SAFETY NOTE WAIVER SAFETY NOTE WAIVER SAFETY NOTE REV. DA TE REV BY 10106/04 kw a COMMENTS Prop, CampI. PRUDHOE BAY UNIT WELL: Z-13A PERMIT No: API No: 50-029-22069-01 BP Exploration (Alaska) SURVEY PROGRAM Deptb Fro !À"þth To SurveylPtm¡ T{)o! Created By: Troy Jakabosky 1378.00 15556>19 Planned:: WP05 \132 MWD Checked: Date;_~ Reviewed; Date ~_ WELL DETAILS """" "F)-W Easting Latitude Longitude Slot -1734.62 5959099.96 599545JJÜ ïO"!T51.67!N 149"'1!'37.929W N/A SECTION DETAILS Sec MD Inc TVD +NI·S +EI-W DLeg TFace VSee Target REFERENCE INFORMA nON COMPANY DETAILS BPAmoco Size CASING DETAILS MD Name 12" 12" TVD No. Z-!3A TID Z-!3A 1'2B Z-13A DB Z-!3A T4B Z-!3A UB 5556.19 84.84 107.98 9048,90 6381.49 4883.37 0.00 0.00 8035.59 , TARGET DETAILS · Name TVD +NI-S +EI-W Northing Easting Shape · / :~~o :':-t~A!:H} .,,,. " /' L-liA t4!:1 IV' , /// H"~;r !:-!~A !:.~~ <o""O~Ù\;; ,.. OJr L-liA 121:1 <';;;;;;;~'~ft , ,<: : / L-tJf\ D'" - - - I ¡ , . ", J I ~ . ,~~ I . I n, '", ,ð~ ' 8400 " ..... / I - , - ',,- - :-.. - - . , .. --'''' / .. . I /1 · , - , '''-- ~ I I - - - . f ; , - --,. -', , - - - , - , .. - / .. - :::"~~ '} ""I ,700 I .. _ L I v:: "~,, ","..." J ~ , 5'1; I I I / . // 1$' - I "- '..- , - / /- - , , . 0' ..~" I / .. - , - I " II ~ If! . - - . ¡!..Is _ / '" IAMr "4,,_ " . 31 n",(j 4S00 " """"4'- . / "'" I Z.13 \ D , 7.' P' · .. "- 1/2 , , - - .. " , . ! j 1 1 , , , , , , , , , 1 , , , , , , , , , , , , , , , , , 1 J j j I J 1 , ! j I ¡ ¡ ! 1 J I 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 7800---- 90 7500 '2 :¡§ "" "" c::. '" 15." ¿; -¡:¡ " B " > ~ 8JOO 7800 7500 6600 Vertical 6300 6000 570fJ SURVEY PROOR.A.M Plan: \VM5 (Z.!3iPlanZ.13Aj Depth Pm [}.Jpth To SurveyiPlao Too! Created By: Troy Jakabosky Datø; 1378m Planoed;WPû5V3 MWD Cheçked: Date: WELL DETAILS N,,,,, Nrnthing F..M1ing Latitude Longitude- Slot ·¡134.62 5959{)99.% 599545.00 70"'IT51.67!N 149~11'37.929W TARGET DETAILS Name TVD +NI-S +EI-W Northing Easting Shape REFERENCE INFORMATION COMP.4NY DETAIl.S BP Arnow FORMATION TOP DETAILS No, TVDPath MDPath I 2 3 4 5 6 7 CASING DETAILS No. TVD MD Nartle Size I 2 SECTION DETAILS TVD +N/-S +E/-W DLeg TFace VSec Target Z-13A Z-I3A T2B Z·I3A T3B Z-I3A T4B MD lnc AzÍ 55,32 See I 2 3 4 5 6 7 8 9 10 II 12 !3 14 IS 16 - . ", g ~~¡~: i~ , I .. .. -"-_, :? g~j~: ~~ I : , . "'" 12 9044, 69 , : .. ' : I . , '~, / "," , - ''', I' ' ,-", ~.. : ': : ' " . : ~, - , . :: . .. ;, ¡ /',~. ."'- -" 0< Tvr ""~'."," . - 'I,' /: : . - - : . , - : '/' : . - : ..:: . , it O(i //--, :~-.; t:.: i. '''." . . - ': , ': :; I' :\', ~~ :, / --- , : ,""'" ' , , , :>< ,><- , ',- /' . --"-": --' -,- , ':;" I': i. "__,: -~'-__",., , ..;,. I; i , , -''^, - -.....,_..... -I : , ": "-", . . : au :-_~ : :-' '_,,, ,...--.......,,~-- , : I ;'...... ''^''''' .. . '1'ill' i"-" :' : . "" -~. ,,___" "j . , , : :-~~- ": ~ I p . i , ¡- "_ I; ð H' ' __ :/ "'-- ."." '-;- ...... ,~ r : : : I! ¡; 1 11. I J I j 1 J 1 t !'""'~~. J ..¡ ! ¡ I J ¡ ! j j i·1 ¡ ¡ ¡ ¡ I ¡ ; ¡ I 1 J 1 1 ¡ ! j 1 ¡ J ¡! ¡ II! 1 ! 4800 4000 3600 2800 2000 600 200 6400- 7200 6800 6000 " â "" "" :!. +' f ~ :if " " '" Company: Field: Site: WeD: WeUpath: BP Amoco Prudhoe Bay PB Z Pad Z-13 Plan Z-13A Principal: Yes Plan: WP05 . . BP BP Planning Report Date: 101112004 TIme: 09:46:23 Page: 1 Co-ordinate(NE) Reference: Well: Z-13, True North Vertical (TVD) Reference: 28.5 + 55.4 83.9 Section (VS) Reference: Well (0.OON,O.00E,37.42Azi) Survey Calculation Method: Minimum Cwvature Db: Oracle Date Composed: Version: Tied-to: 61912004 32 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB Z Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 5957230.17 ft 601304.82 ft Latitude: 70 17 Lon~tude: 149 10 North Reference: Grid Convergence: 33.051 N 47.365 W True 0.77 deg WeD: Z-13 Slot Name: Z-13 WeD Position: +N/-S 1893.50 ft Northing: 5959099.96 ft Latitude: +EI-W -1734.62 ft Easting: 599545.00 ft Lon~tude: Position Uncertainty: 0.00 ft Casing Points MD ft 12244.16 15556.00 Formations MD 11796.82 12077.04 12244.16 12296.40 12478.75 12512.48 12591.82 12600.48 12676.12 14721.80 15355.94 15511.69 Targets Name Z-13A Fault 1 -Polygon 1 -Polygon 2 Z-13A Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 Z-13A Fault 3 -Polygon 1 -Polygon 2 70 17 51.671 N 149 11 37.929 W TVD Dlåmeter Hole Size Name ft in in 8737.90 5.500 6.750 51/2" 9048.88 3.500 4.750 31/2" TVD Formations Lithø1mD' ft 0.00 TJD 0.00 0.00 8451.90 TJC 0.00 0.00 8630.90 TJB 0.00 0.00 8737.90 TSGR 0.00 0.00 8770.90 TSHU 0.00 0.00 8875.90 TElL 0.00 0.00 8891.90 TSAD 0.00 0.00 8923.90 45N 0.00 0.00 8926.90 45P 0.00 0.00 8948.90 44N 0.00 0.00 8973.90 43N 0.00 0.00 9030.90 42N 0.00 0.00 9044.90 42P 0.00 0.00 Map Map Description TVD +EI~W Nortlting EastiJ1g Dip. Dir. ft ft ft ft 83.90 6444.18 2793.83 5965580.00 602252.99 70 18 55.044 N 149 10 16.419 W 83.90 6444.18 2793.83 5965580.00 602252.99 70 18 55.044 N 149 10 16.419 W 83.90 7294.97 3198.17 5966436.00 602645.99 70 19 3.410 N 149 10 4.612 W 83.90 7694.13 -433.18 5966787.00 599009.99 70 19 7.342 N 149 11 50.569 W 83.90 7694.13 -433.18 5966787.00 599009.99 70 19 7.342 N 149 11 50.569 W 83.90 6320.72 1089.90 5965434.00 600550.99 70 18 53.834 N 149 11 6.132 W 83.90 4418.57 6058.58 5963598.00 605543.99 70 18 35.104 N 149 8 41.219 W 83.90 6320.72 1089.90 5965434.00 600550.99 70 18 53.834 N 149 11 6.132 W 83.90 9551.91 891.66 5968662.00 600309.99 70 19 25.613 N 149 11 11.904 W 83.90 9551.91 891.66 5968662.00 600309.99 70 19 25.613 N 149 11 11.904 W 83.90 8845.53 1364.38 5967962.00 600791.99 70 19 18.665 N 149 1058.110W . . BP BP Planning Report Company: BPArnoco Field: PrUdhoe Bay Site: PB Z Pad WeU: Z~13 WeUpath: Plan Z-13A Targets Name Deséription Dip. DIr. -Polygon 3 83.90 8737.08 2529.15 5967869.00 601957.99 70 19 17.596 N 149 1024.119 W -Polygon 4 83.90 6794.23 4681.80 5965955.00 604135.99 70 18 58.478 N 149 9 21.332 W -Polygon 5 83.90 8737.08 2529.15 5967869.00 601957.99 70 19 17.596 N 149 1024.119 W -Polygon 6 83.90 8845.53 1364.38 5967962.00 600791.99 70 19 18.665 N 149 1058.110W Z-13A Fault 5 83.90 7398.62 5490.95 5966570.00 604936.99 70 19 4.416 N 149 8 57.712 W -Polygon 1 83.90 7398.62 5490.95 5966570.00 604936.99 70 19 4.416 N 149 8 57.712 W -Polygon 2 83.90 5940.76 5083.57 5965107.00 604548.99 70 18 50.081 N 149 9 9.627 W Z-13AFault4 83.90 6322.67 3283.31 5965465.00 602743.99 70 18 53.847 N 149 10 2.141 W -Polygon 1 83.90 6322.67 3283.31 5965465.00 602743.99 70 18 53.847 N 149 10 2.141 W -Polygon 2 83.90 5398.84 6655.67 5964586.00 606127.99 70 18 44.739 N 149 8 23.779 W Z-13A nD 8737.90 6554.95 1870.89 5965678.53 601328.74 70 1856.136N 149 10 43.345 W Z-13A T4B 8921.90 6835.13 3482.13 5965980.00 602935.99 70 18 58.886 N 149 9 56.333 W Z-13A T3B 8950.90 7012.89 2898.38 5966150.00 602349.99 70 19 0.637 N 149 10 13.363 W Z-13A Geo Poly 8950.90 6427.48 2015.48 5965553.00 601474.99 70 18 54.882 N 149 10 39.128 W -Polygon 1 8950.90 6427.48 2015.48 5965553.00 601474.99 70 18 54.882 N 149 10 39.128 W -Polygon 2 8950.90 6612.17 1814.89 5965735.00 601271.99 70 18 56.699 N 149 10 44.979 W -Polygon 3 8950.90 7247.43 2709.46 5966382.00 602157.99 70 19 2.944 N 149 10 18.873 W -Polygon 4 8950.90 6754.75 4264.21 5965910.00 603718.99 70 18 58.092 N 149 9 33.517 W -Polygon 5 8950.90 6498.87 5006.95 5965664.00 604464.99 70 18 55.571 N 149 9 11.851 W -Polygon 6 8950.90 6234.28 4972.44 5965399.00 604433.99 70 18 52.969 N 149 9 12.863 W -Polygon 7 8950.90 6777.87 2821.26 5965914.00 602275.99 70 18 58.326 N 149 10 15.616 W Z-13A T2B 8968.90 6843.96 2287.04 5965973.00 601740.99 70 18 58.978 N 149 10 31.201 W Z-13A T5B 9048.90 6381.49 4883.37 5965545.00 604342.99 70 18 54.417 N 149 9 15.459 W Plan Section Information MD Inel AzIn¡ TVI) +N/-8 +E/..W DLS .. .1J,,!Jd. Till'ii. ft deg deg ft ft ft degl10OftØegl1()Oftdegl10Qft 11378.00 55.32 24.89 8200.32 6072.26 1404.50 0.00 0.00 0.00 0.00 11398.00 55.56 27.79 8211.67 6087.02 1411.80 12.00 1.22 14.50 85.00 11894.14 50.19 51.83 8513.80 6388.80 1659.49 4.00 -1.08 4.85 112.76 12244.16 50.19 51.83 8737.90 6554.95 1870.89 0.00 0.00 0.00 0.00 Z-13A nD 12264.16 50.19 51.83 8750.70 6564.44 1882.97 0.00 0.00 0.00 0.00 12307.86 52.96 54.55 8777.86 6584.94 1910.38 8.00 6.35 6.21 38.32 12386.44 52.96 54.55 8825.19 6621.32 1961.48 0.00 0.00 0.00 0.00 12812.47 87.00 56.50 8968.90 6843.96 2287.04 8.00 7.99 0.46 3.48 Z-13A T2B 12860.95 90.88 56.51 8969.80 6870.71 2327.46 8.00 8.00 0.02 0.15 12922.74 90.88 56.51 8968.85 6904.80 2378.98 0.00 0.00 0.00 0.00 13466.54 92.72 100.00 8950.90 7012.89 2898.38 8.00 0.34 8.00 86.97 Z-13A T3B 13560.86 92.91 107.55 8946.26 6990.48 2989.81 8.00 0.20 8.01 88.38 14003.67 92.91 107.55 8923.78 6857.11 3411.46 0.00 0.00 0.00 0.00 14077.71 90.00 107,00 8921.90 6835.13 3482.13 4.00 -3.93 -0.75 -169.25 Z-13A T4B 14208.95 84.84 107.98 8927.80 6795.74 3607.13 4.00 -3.93 0.75 169.24 15556.19 84.84 107.98 9048.90 6381.49 4883.37 0.00 0.00 0.00 0.00 Z-13A T5B . . BP BP Planning Report Company: BP Amoco Date: 10/1/2004 Field: Prudhoe Bay Co-ordinate(NE) Reference: Site: PB Z Pad Verdeal (TVD)Reference: WeD: Z-13 Seetion {VS)Referellce: Wellpåth: Plan Z-13A SurveyCalenl'atkÞ!i Method: Survey MD Incl Azim TVD SysTVD N/S E/W DLS ft deg dEIg ft ft ft ft dégl100ft 11378.00 55.32 24.89 8200.32 8116.42 6072.26 1404.50 0.00 5965189.75 600868.82 Start Dir 12/10 11398.00 55.56 27.79 8211.67 8127.77 6087.02 1411.80 12.00 5965204.61 600875.93 Start Dir 4/100 11400.00 55.53 27.88 8212.80 8128.90 6088.48 1412.57 4.00 5965206.07 600876.69 MWD 11500.00 54.07 32.43 8270.46 8186.56 6159.12 1453.58 4.00 5965277.24 600916.75 MWD 11600.00 52.79 37.15 8330.06 8246.16 6225.06 1499.36 4.00 5965343.78 600961.65 MWD 11700.00 51.70 42.02 8391.31 8307.41 6285.97 1549.70 4.00 5965405.35 601011.17 MWD 11796.82 50.85 46.86 8451.90 8368.00 6339.89 1602.54 4.00 5965459.95 601063.29 TJC 11800.00 50.82 47.02 8453.91 8370.01 6341.57 1604.34 4.00 5965461.66 601065.07 MWD 11894.14 50.19 51.83 8513.80 8429.90 6388.80 1659.49 4.00 5965509.62 601119.58 End Dir : 1189 11900.00 50.19 51.83 8517.55 8433.65 6391.58 1663.03 0.00 5965512.44 601123.08 MWD 12000.00 50.19 51.83 8581.58 8497.68 6439.05 1723.42 0.00 5965560.70 601182.84 MWD 12077.04 50.19 51.83 8630.90 8547.00 6475.62 1769.95 0.00 5965597.88 601228.87 TJB 12100.00 50.19 51.83 8645.60 8561.70 6486.52 1783.82 0.00 5965608.96 601242.59 MWD 12200.00 50,19 51.83 8709.62 8625.72 6533.99 1844.22 0.00 5965657.22 601302.35 MWD 12244.16 50.19 51.83 8737.90 8654.00 6554.95 1870.89 0.00 5965678.53 601328.74 Z-13A T1D 12264.16 50.19 51.83 8750.70 8666.80 6564.44 1882.97 0.00 5965688.19 601340.69 Start Dir 8/100 12296.40 52.23 53.86 8770.90 8687.00 6579.61 1903.00 8.00 5965703.62 601360.51 TSHU 12300.00 52.46 54.08 8773.10 8689.20 6581.29 1905.30 8.00 5965705.32 601362.80 MWD 12307.86 52.96 54.55 8777.86 8693.96 6584.94 1910.38 8.00 5965709.04 601367.83 End Dir : 1230 12386.44 52.96 54.55 8825.19 8741.29 6621.32 1961.48 0.00 5965746.09 601418.43 Start Dir 8/100 12400.00 54.05 54.63 8833.25 8749.35 6627.64 1970.36 8.00 5965752.52 601427.23 MWD 12478.75 60.34 55.06 8875.90 8792.00 6665.72 2024.46 8.00 5965791.31 601480.81 TElL 12500.00 62,03 55.17 8886.14 8802.24 6676.37 2039.73 8.00 5965802.16 601495.94 MWD 12512.48 63.03 55.23 8891.90 8808.00 6682.69 2048.83 8.00 5965808.60 601504.95 TSAD 12591.82 69.37 55.60 8923.90 8840.00 6723.87 2108.56 8.00 5965850.57 601564.14 45N 12600.00 70.02 55.64 8926.74 8842.84 6728.20 2114.89 8.00 5965854.98 601570.41 MWD 12600.48 70.06 55.64 8926.90 8843.00 6728.45 2115.26 8.00 5965855.24 601570.77 45P 12676.12 76.10 55.96 8948.90 8865.00 6769.11 2175.09 8.00 5965896.68 601630.05 44N 12684.65 76.79 55.99 8950.90 8867.00 6773.75 2181.96 8.00 5965901.41 601636.86 Z-13A Geo Poly 12700.00 78.01 56.06 8954.25 8870.35 6782.12 2194.39 8.00 5965909.95 601649.17 MWD 12800.00 86.00 56.45 8968.14 8884.24 6837.08 2276.67 8.00 5965965.99 601730.71 MWD 12812.47 87.00 56.50 8968.90 8885.00 6843.96 2287.04 8.00 5965973.00 601740.99 Z-13A T2B 12860.95 90.88 56.51 8969.80 8885.90 6870.71 2327.46 8.00 5966000.28 601781.05 End Dir : 1286 12900.00 90.88 56.51 8969.20 8885.30 6892.25 2360.02 0.00 5966022.25 601813.32 MWD 12922.74 90.88 56.51 8968.85 8884.95 6904.80 2378.98 0.00 5966035.05 601832.11 Start Dir 8/100 13000.00 91.20 62.68 8967.45 8883.55 6943.87 2445.57 8.00 5966074.99 601898.17 MWD 13100.00 91.59 70.68 8965.01 8881.11 6983.41 2537.30 8.00 5966115.75 601989.36 MWD 13200.00 91.96 78.67 8961.90 8878.00 7009.81 2633.62 8.00 5966143.41 602085.31 MWD 13300.00 92.28 86.67 8958.20 8874.30 7022.55 2732.66 8.00 5966157.46 602184.16 MWD 13400.00 92.56 94.67 8953.97 8870.07 7021.38 2832.48 8.00 5966157.61 602283.98 MWD 13466.54 92.72 100.00 8950.90 8867.00 7012.89 2898.38 8.00 5966150.00 602349.99 Z-13A T38 13500.00 92.79 102.68 8949.29 8865.39 7006.32 2931.15 8.00 5966143.87 602382.83 MWD 13560.86 92.91 107.55 8946.26 8862.36 6990.48 2989.81 8.00 5966128.80 602441.70 End Dir : 1356 13600.00 92.91 107.55 8944.27 8860.37 6978.69 3027.08 0.00 5966117.51 602479.11 MWD 13700.00 92.91 107.55 8939.20 8855.30 6948.57 3122.30 0.00 5966088.66 602574.72 MWD 13800.00 92.91 107.55 8934.12 8850.22 6918.45 3217.52 0.00 5966059.80 602670.32 MWD 13900.00 92.91 107.55 8929.04 8845.14 6888.33 3312.74 0.00 5966030.95 602765.92 MWD 14000.00 92.91 107.55 8923.97 8840.07 6858.21 3407.96 0.00 5966002.10 602861.53 MWD 14003.67 92.91 107.55 8923.78 8839.88 6857.11 3411.46 0.00 5966001.04 602865.03 Start Dir 4/100 14077.71 90.00 107.00 8921.90 8838.00 6835.13 3482.13 4.00 5965980.00 602935.99 Z-13A T48 14100.00 89.12 107.17 8922.07 8838.17 6828.58 3503.43 4.00 5965973.74 602957.37 MWD 14200.00 85.19 107.92 8927.02 8843.12 6798.49 3598.65 4.00 5965944.91 603052.97 MWD 14208.95 84.84 107.98 8927.80 8843.90 6795.74 3607.13 4.00 5965942.28 603061.49 End Dir : 1420 . . . BP BP Planning Report Company: Field: Site: WeD: Wellpath: BP AmOCO Prudhoe Bay PB Z Pad Z-13 Plan Z-13A Date: 10/112004 Time: 09:46:23 Page: 4 Co-ordinate(NE) Reference: Well: Z-13, True North Vertieal (TVD) RefereDee: 28.5 + 55.483.9 Section (VS) Referenee: Well (0.ooN,O.00E,37.42A2i) Survey CaleulatioD Method: Minimum Curvature Db: Oracle Survey MD IDel Azim TV» Sys TV» NIS MapE ft deg deg ft ft ft ft 14300.00 84.84 107.98 8935.99 8852.09 6767.74 3693.38 0.00 5965915.43 603148.09 MWD 14400.00 84.84 107.98 8944.97 8861.07 6737.00 3788.11 0.00 5965885.94 603243.21 MWD 14500.00 84.84 107.98 8953.96 8870.06 6706.25 3882.84 0.00 5965856.45 603338.33 MWD 14600.00 84.84 107.98 8962.95 8879.05 6675.50 3977.57 0.00 5965826.96 603433.45 MWD 14700.00 84.84 107.98 8971.94 8888.04 6644.75 4072.30 0.00 5965797.48 603528.58 MWD 14721.80 84.84 107.98 8973.90 8890.00 6638.05 4092.95 0.00 5965791.05 603549.31 43N 14800.00 84.84 107.98 8980.93 8897.03 6614.00 4167.03 0.00 5965767.99 603623.70 MWD 14900.00 84.84 107.98 8989.92 8906.02 6583.26 4261.76 0.00 5965738.50 603718.82 MWD 15000.00 84.84 107.98 8998.91 8915.01 6552.51 4356.49 0.00 5965709.01 603813.94 MWD 15100.00 84.84 107.98 9007.89 8923.99 6521.76 4451.22 0.00 5965679.53 603909.06 MWD 15200.00 84.84 107.98 9016.88 8932.98 6491.01 4545.95 0.00 5965650.04 604004.18 MWD 15300.00 84.84 107.98 9025.87 8941.97 6460.27 4640.68 0.00 5965620.55 604099.30 MWD 15355.94 84.84 107.98 9030.90 8947,00 6443.07 4693.67 0.00 5965604.06 604152.51 42N 15400.00 84.84 107.98 9034.86 8950.96 6429.52 4735.41 0.00 5965591.06 604194.42 MWD 15500.00 84.84 107.98 9043.85 8959.95 6398.77 4830.14 0.00 5965561.57 604289.54 MWD 15511.69 84.84 107.98 9044.90 8961.00 6395.17 4841.22 0.00 5965558.13 604300.66 42P 15556.00 84.84 107.98 9048.88 8964.98 6381.55 4883.19 0.00 5965545.06 604342.81 3 1/2" 15556,19 84.84 107.98 9048.90 8965.00 6381.49 4883.37 0.00 5965545.00 604342.99 Z-13A T58 WELL DETAILS ANTlcCOLLISION SETTrNGS COMPANY DETAILS Name ,,-Ni-S ,E!-W Northing Easting wd!udt: Lo¡¡gítude Slot 2-D Iß9350 -1734.62 5959Ü9Q.96 599-545.00 7(jOj7'51.67!N ¡49~¡ !'37.929W NIA -320 -300 --250 --200 -150 -100 -50 0 270 -50 -100 -150 --200 --250 -300 -320 interpolation MethodMD interval: 25_00 Depth fumge From: 11378.00 To: 15556.19 Maximum Range: t 752.63 Reference: Plan: WP05 BPArnoco o 320 ____ From "~ './ -. 30D.:--~, ~ ¡æ if " . 2JO~ ~" ~ ~ggg /. ...,. .'. ~ ~ 6000 ",.,/ , :y'.' .. 6500 /' .'/ ii'.^, "'.~'" ../.,,- : '\ 70000 / ' ::'. ;/: 20JV._O '. ~.,.. " . : \ 7500 "<i; / /: ..' i . >. ...:.........~... ,\ 8000 30i I~'//;/y;;/;:;.>:: ",~: . .' / .' <.),,: : \' O:!~g I j /".í .., ill!';/ " . .../' .....;. . .'. ':'\ \13000 /1 '.. i··..· ':/ ' . .: '. ..... \14000 . .ff . '.' / \.' \ . r: . .1(/ .'.: ¿ /./. . "<"" \.\ ..i.·.....i'·· ,/~\(:. "i . .. ',: . </./// .... ..'\ .',,\ ".,'.' ,,'.. \ I . ,':/ \.' \\.\\ \ .' \' "" ,,: . I. "/,'., 1 ~ ;.; , . .\\ .\\:.\}. I'; '..' ;:"'., " . ·i'·:····, .. I ..~.:: . '.,' ··\.i'· \.".,: ", '.. : : : : . : . , , : ' : ,I : " .:....' ,.".' ,', ....1 '.\. . " .', ,": ': '. :.', , .'::, " " :.' " ':. . " ~". :'. ,'" , . hi' ':', . , 90 ,'" ".':' ", :. " "': ,:\ ... " .' 'I. .¡ \ \ \. : i.., '. \. ..\,I......\.i' \ . .....1, ~> ..... .', . . '\\\j ;: ;. ,,\\\,I '\~\è \\\y~è u:" (:#;; / ". . . :}Jj¡' ,Ii J \Ii \.... .,' "\1\,\ \\: ....~...~~~\/~. ~.// //.//1" \.,\ ' ' \,\\ . .... ......- '1w\./'l';.... / ill \\., .\\ .. \ . " .\// . ,'. I . ' ,", . :,ii.'.} \. ,'. ,".' .,..' .. 15~/~;\~"\ .' , ,", // '·.l! / \\' ..'..... -- .. ./'/;<;\ \ ! , 240\.' ~ '.;' ..... ;' '..'. '/t~>~/;I( "jÆ20 '\ . ',........ . ".;', ..../ / I \\\'" ..< . . ' .....\ /. .'¡:; \: ., ': .... " . .. '. . / ~< ,/> .;~ .. .' ...... /<y " .').. .... . / ',,:\ ,. "'-.i/, ~ '.. . ".;./ 21 . 150 See MD!nc Azi .. _. I 2 3 4 , 6 1 8 9 !ß II " 13 14 15 16 .. -- 180'20 SURVEY PROGRAM Depth Fm Depth To Survey/Plan 11378.00 155%.19 Planned: WPÛ5 V32 Colour ToMD o 1000 2000 3000 4000 5000 6000 6500 70000 7500 8000 8500 11000 12000 13000 14000 15000 SE('110N DETAILS TVD +Nf".'> 'rfJ~W Too! . MWD WELLPATH DETAILS PlanZ~!3A PtirentWd!fmth: TìeonMD· z..ü !J378.00 Rì£.: Ref Datum: 28.5 ,55.4 &3.9m1 fJri},,>m Ûfigin ~Ni.s --FJ-W Starlmg From TVi) J1.42~ 0.00 0.00 29.90 LE(iEND DLeg TFace vSec Tar&>ct Z-DATID Z-13A T2B 2.13A nB Z-DA 1'48 Z~13A T5B . . BP Anticollision Report Company: Field: Reference Site: Reference WeU: Reference WeUpath: BP Amoco Prudhoe Bay PB Z Pad Z-13 PlanZ-13A . GLOBAL SCAN APPLIED: AU weUpaths within 200'+ 100/1000 ofreference - There are 1IIiiIIiIè..us in this fBdh: WP05 & NOT PLANNED PROGRAli/1 Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 11378.00 to 15556.19 ft Scan Method: Trav Cylinder North Maximum Radius: 1752.63 ft Error Suñace: Ellipse + Casing Casing Points MD ft 12244.16 15556.00 TVD ft 8737.90 9048.88 Diameter in Hole Size in 6.750 4.750 Name 5.500 3.500 5 1/2" 3 1/2" Plan: WP05 Date Composed: Venion: Tied-to: 6/9/2004 32 From: De;;nitive Path Principal: Yes Summary Offset Wellpath > Reference Offset Ctr-Ctr Site WeD WeUpath MD MD Distance ft ft ft PB Z Pad Plan Ivi Z-34i Plan vi Z-34i VO Plan 11380.89 10475.00 923.14 0.00 923.14 Pass: NOERRORS PB Z Pad Z-13 Z-13 V1 11399.99 11400.00 0.43 No Reference Casings PB Z Pad Z-21 Z-21 V3 Out of range PB Z Pad Z-25 Z-25 V1 14347.25 11864.69 1637.91 221.90 1416.01 Pass: Major Risk Site: PB Z Pad Well: Plan Ivi Z-34i Rule Assigned: WeUpath: Plan Ivi Z-34i VO Plan: Ivi Z-34i wp01 V2 Inter-Site Error: Reference Offset SCmi-Majo....þi~ Ctr...ctr. . Nö--Go MD TVD MD TVD Ref Offset TFo+AZl1.'Jj'()-HS CasiDgM~taDce Area ft ft ft ft ft ft degdeg in ft ft 11380.89 8201.97 10475.00 7957.93 47.10 37.22 314.05 288.74 6.125 923.14 0.00 11389.33 8206.76 10500.00 7975.59 46.96 37.10 314.13 287.60 6.125 928.09 0.00 11398.00 8211.67 10525.00 7993.25 46.83 36.97 314.23 286.44 6.125 933.47 0.00 11400.00 8212.80 10550.00 8010.92 46.82 37.05 313.82 285.94 6.125 939.34 0.00 11425.52 8227.31 10575.00 8028.58 46.65 36.96 313.87 284.85 6.125 945.25 0.00 11439.46 8235.30 10600.00 8046.24 46.55 36.95 313.70 284.05 6.125 951.56 11453.33 8243.29 10625.00 8063.91 46.46 36.94 313.54 283.26 6.125 958.14 11467.14 8251.29 10650.00 8081.57 46.37 36.93 313.39 282.47 6.125 965.00 11480.89 8259.28 10675.00 8099.24 46.27 36.92 313.24 281.69 6.125 972.13 11500.00 8270.46 10700.00 8116,90 46.14 36.86 313.20 280.77 6.125 979.55 11500.00 8270.46 10725.00 8134.56 46.14 36.96 312.81 280.37 6.125 987.23 11521.69 8283.23 10750.00 8152.23 45.97 36.87 312.83 279.39 6.125 995.09 11535.14 8291.19 10775.00 8169.89 45.86 36.85 312.71 278.64 6.125 1003.26 11548.51 8299.15 10800.00 8187.55 45.76 36.83 312.60 277.89 6.125 1011.68 11561.81 8307.08 10825.00 8205.22 45.65 36.80 312.49 277.16 6.125 1020.35 11575.02 8315.00 10850.00 8222.88 45.55 36.78 312.39 276.43 6.125 1029.26 11600.00 8330.06 10875.00 8240.54 45.35 36.64 312.51 275.36 6.125 1038.53 11600.00 8330.06 10900.00 8258.21 45.35 36.74 312.18 275.03 6.125 1047.81 11600.00 8330.06 10925.00 8275.87 45.35 36.84 311.85 274.70 6.125 1057.59 11627.05 8346.47 10950.00 8293.53 45.10 36.67 312.04 273.59 6.125 1067,28 11639.84 8354.28 10975.00 8311.20 44.99 36.64 311.97 272.90 6.125 1077.36 11652.54 8362.05 11000.00 8328.86 44.87 36.61 311.91 272.21 6.125 1087.67 11665.16 8369.80 11025.00 8346.53 44.76 36.57 311.85 271.54 6.125 1098.19 11677.68 8377.51 11050.00 8364.19 44.64 36.54 311.80 270.87 6.125 1108.92 11700.00 8391.31 11075.00 8381.85 44.44 36.40 311.93 269.91 6.125 1119.95 11700.00 8391,31 11100.00 8399.52 44.44 36.50 311.66 269.64 6.125 1131.03 11700.00 8391.31 11125.00 8417.18 44.44 36.59 311.40 269.38 6.125 1142.56 11726.85 8407.99 11150.00 8434.84 44.17 36.40 311.65 268.30 6.125 1153.95 11738.91 8415.52 11175.00 8452.51 44.05 36.37 311.62 267.67 6.125 1165.71 11750.87 8423.00 11200.00 8470.17 43.93 36.33 311,61 267.06 6.125 1177.67 NOERRORS 0.00 ft 923.14 Pass 928.09 Pass 933.47 Pass 939.34 Pass 945.25 Pass 0.00 951.56 Pass 0.00 958.14 Pass 0.00 965.00 Pass 0.00 972.13 Pass 0.00 979.55 Pass 0.00 987.23 0.00 995.09 0.00 1003.26 0.00 1011.68 0.00 1020.35 0.00 1029.26 0.00 1038.53 0.00 1047.81 0.00 1057.59 0.00 1067.28 0.00 1077.36 0.00 1087.66 0.00 1098.19 0.00 1108.92 0.00 1119.95 0.00 1131.03 0.00 1142.55 0.00 1153.95 0.00 1165.71 0.00 1177.66 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass TERRIE l HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 154 DATE JO·07~OLf ~~¡;,',''c,'I'' h~ ~~/M6CL, $ IOD ,ÙQ Fo~~ WJí(5) LfULLAHS ~~~ "Mastercard Check" . Anchorage, AK 99501 MEMO Z-J3A ':.25 2000bO':1i1i .~"Ib 2 27111. 55bll· 0 .5~ . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /?1C1 Z- /3A PTD# ..2o~- 2Q? X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (1f API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE fl. Tbe permit is for a new weHboresegment of existing well, , Permit No, .' API No. Production,sbould continue to be reponed as a function' of tbe original API number, stated above. HOLE In accordance witb 20 AAC 25.005(0, an records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for wen (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent UPOD issuance of ~ conservation order approving a spacing nceptioD. (Company Name) assumes tbe liability of any protest to tbe spacing .e:xception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater 1han 30' sample inten'als from below tbe permafrost or from wbere samples are first caught and ] 0' sample iIiter:vals tbrough target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT Z-13A PTD#: 2042030 Company BP EXPLORATION (ALASKA} INC Initial ClasslType DEV 11-01L GeoArea 890 Unit J 1650 1 Pe(lTlitfee attache~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leas_e_number_appropriate__ _______ Yes___ ________ ______ ______ 3 _U_nlque well_n_ame_aod 1J~lTlb_er _ _ . . . . . _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WelUocated inad.efil']e~.P901 . _ Yes _ . _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ . _ _ 5 WelUocated properdlstance_ from driJling ul']iìb.ound.uy_ . . _ _ _ . _ _ _ _ Yes _ . . _ . _ . _ _ _ _ . _ _ _ _ _ _ _ . . _ _ . _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ 6 WelUocated pr.oper .dlstance. from otber wells. _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . . . . _ _ _ . . . _ _ _ _ . . . _ _ _ _ _ . . 7 .S.utficient acreage_ayailable in.dJillilJg unit Yes.. . . . _ _ _ _ _ _ . . _ 8 .If deviated, is. weJlbore platjl']cJu.ded _ _ _ _ . . . _ _ _ . . _ _ _ Yes _ _ _ _ _ . . . _ _ _ _ _ . . . _ . _ _ _ _ . _ .... _ _ . . . _ _ _ 9 .Qper.ator only affected party. _ _ _ _ _ . _ _ _ . . . . _ _ . . _ . _ _Yes . . _ _ _ . . . _ _ . . . . . _ _ _ _ . . . _ _ .... _ _ _ _ _ . . . 10 .Ope(ator bas.appropriate.bood i.nJorce . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . Ye$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 PeOT) it cao be i.ss~ed witbout conserva.tion order _ _ . . . _ _ . _ _ . . . _ _ Yes. _ _ _ _ . . . _ _ _ . . . _ _ _ _ _ . . , . _ _ _ _ . . . _ _ . _ _ . . _ _ _ _ _ . . . _ _ . . . . _ Appr Date 12 Pe{l'1')itc.aobelss~edwitboutadlTlinist(ati\le.approva.I... _ _ _ _... .No. - _.... ...... _ _ _.... _ _ _ _... _ _ _ _ _... _......_ RPC 10/7/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocated wi.thin area alldstrata .authorized by lojectiolJ Orde( # (puUO# in. commeots).{For NA . _ _ _ _ . . . _ . . . . . _ . . . _ _ . _ . . . . _ _ _ . . . _ . _ 15 .AJI Wells. witþin .114.ruile.area.of (eyieW idelJUfied (Fo( servic.ew.ell OI']Iy). . . . . . . . . . . . . . . .NA . . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 PJe-produ~ed iojector; ~uration.of pre-pro~uction less than. 3 montbs. (For_ser:.vi.ce well onJy) _ NA _ .... _ _ . _ _ _ . . . . . . _ _ . . . . _ _ . . . . _ _ _ . . . _ _ _ . . . . 17 AÇMPFïl']dingof ConJ>iJ>teocy_has beenjssued forJbis proiect. _ NA . _ _ _ _ . . . . _ . . . . _ _ _ _ . . . _ _ _ . . . _ _ _ _ . . . _ _ . . . . . _ 18 _C_ooductor st(ing.PJovided . . _ _ _ _ _ . . _ _ _ . . . _ _ _ . . . _ _ _ _ . . .NA . _ _ . _ _ _ _ . . _ _ _ _ _ . . . . _ _ _ _ . . . _ . . . . _ _ _ _ _ _ . . . . _ 19 _S:-orfaœca::>ÏT1g pJotects alLknown USQWs . . _ _ _ _ . . _ _ _ _ . . _ _ _ NA _ . . . _ _ . . . _ _ _ _ _ _ _ . . . _ _ _ . . _ _ _ _ _ . . _ _ _ . . . _ _ . . . . _ 20 .CMT v9l adec;¡~ateJo circulate. oncond.uctor & su_rf. CJ>g . . _ _ _ _ . . _ NA _ _ _ _ _ . . . _ _ _ _ _ . . . _ _ _ . . . _ _ _ . . . _ _ _ _ . . _ _ _ . . . _ _ _ . . . _ 21 _CMT v.ol adec;¡u.ateJo tie-i.nJongstring tosud ¡;sg_ _ _ _ . _ _ _ _ _ . . . _ _ _ NA _ . _ _ _ _ . _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ _ . . _ _ _ _ . . _ _ _ _ _ _ . . 22 .CMTwill coyer.aJl know.npro.ductiye bori¡!:Olls . . _ _ _ . . . _ Yes _ _ _ _ _ . . . _ _ _ _ . . . _ _ _ _ . . _ _ _ . . _ . 23 .C_asiog desigos adequa.te f9( C,.T.. B.&.perruafr9$L _ _ . . _ _ _ _ _ . . _ _ _ . . _ _ Yes _ _ _ . . _ _ _ _ . . . . . _ _ _ .. _ _ . . . _ _ _ _ . . . _ 24 Adequate.tankage.oJ reser:.ve pit _ _ _ . . _ _ _ _ _ . . . _ Yes. . _ _ _ . . Nabors.7ES. _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ . . _ _ _ . . . _ _ _ . . . _ _ _ . . _ _ 25 Jf.are-d(ilt bas.a 10-40;3 for abandollment beelJ apPJoved . _ _ _ . . . . Yes 9/30/2004. _ _ _ . . . _ _ _ _ . . _ _ 26 .Adequatew.e[ll:!ore separation proposed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . _ . . . . . . . . . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . _ . . . . . . _ _ . . 27 Jfdiver.ter Jeq.uiJed, does itmeet reguJa.tions. _ _ _ . . . _ _ _ . . _ _ _ . . . . _ NA . _ _ Sidet(ack. _ _ _ _ _ . . . _ _ . _ . . . _ . _ _ _ . . . _ _ _ . . . _ Appr Date 28DJilIilJgfJuid.progralTl$chematic&eq.uipJisLadequate.. _ _ _ _ _... _ _.... Yes . MaxMW11.2.ppg._ _ _...._ WGA 10/8/2004 29 .S.0PEs,.dothey meetJeguJatiol'] . _ _ _ _ . . _ _ _ _ .Y.es _ _ _ _ . . . . _ 30B.0PEpress raiilJg appropriate; testto (pu.t PSig ¡ncomments>. _ _ _ _ _ . . . _ _ Yes. _ . _ . Test t93500. psi. MSP. _ _ _ . . . 31ChOkeruanjfOld cOlTlpJies w/API RP-53. (May 84>. _ _ _ _ . . . _ _ Yes _ . _ _ _ _ . . . . _ _ _ _ . . . _ 32 Work will oCC.u( withoutoperatjonsbutdown. . . _ _ . . . . _ Yes. _ . _ _ . . . . _ _ _ _ . . . . _ _ . . . . _ 33 .Is. pres.ence. of H2S gas_ prob.able. . . _ _ . . . _ _ _ _ . . . _ No . . Notas H2S pad.. _ _ _ _ _ . . . _ . . . . . _ 34 Mecha.nlcaLcolJdjUon of wells wi.thil'] ,A.OR verified (fors_ervjce welJ only) _ _ . . . _ _ NA _ _ . . . . . _ _ _ . . . . . _ . . . . . _ Program DEV On/Off Shore On Well bore seg Annular Disposal Administration - - - - - - ~ - - - - - Engineering - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - > - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - Geology 35 Pe{l'1')it cao be i.ss~ed wlo hyd(ogen s.ulfide measuœs . 36D_ata.PJeselJted on_ potential QveJpressurezones. . 37Sei.smlcanalysjs of shaJlow gasz9lJes. . . _ _ . . _ _ 38 .Seabed .col']ditiQIJ survey.(if off-sh9(e) _ . . . . _ _ . 39 _ Conta_ct nam.elpÞOlleJorweekly progress. reports [exploratoryooly]. . _ - - - - -- _ . .N.o_ _ _ _ _ _ . _ _ . . . . _ _ _... _ ... NA_ _ _.. _ _ .... _ _ _ _....._ .NA_.. _ _.... NA. . _... _ NA.. _ _ _.. _ _ ..... _ _ _ _.. _ __ - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - ~ - - - - - - - - - - - - - - ~ - - - - - - -- Appr RPC Date 10/7/2004 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - -- - - - - -- - - - - - - - Geologic Commissioner: Date /ry¥ Engineering Commissioner: Date: Date Ð~ /ò / í I ¡ 1- o o . .. . . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infonnation 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 infonnation. Sperry-Sun Dri~ng Services LIS Scan Utility . ti{of- ¿o? $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 15 14:41:30 2005 'I )o7J) Reel Header Service name.... .... ... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/15 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. . . . . . . . . . . . . . . . . . . . .05/03/15 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 Z-13A 500292206901 BP Exploration (Alaska) fIne. Sperry-Sun Drilling Services 23-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003369825 P. SMITH D. FERGUSON MWD RUN 6 MW0003369825 P. SMITH D. FERGUSON MWD RUN 7 MW0003369825 P. SMITH D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 llN 12E 981 3132 82.76 55.42 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 6.750 4.750 CASING SIZE (IN) 7.625 5.500 DRILLERS DEPTH (FT) 10840.0 12236.0 # REMARKS: . . 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERIICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A W IPSTOCK IN THE Z-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 10840'MD/7900'TVD. 4. MWD RUN 5 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL A BIT OF RAT HOLE - SROP DATA ONLY ARE PRESENTED. 5. MWD RUN 6 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4); AND PRESSURE WHILE DRILLING (PWD;. 6. MWD RUN 7 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND EWR4. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 9' UPHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROI~ K. COONEY (SIS/BP) DATED 2 FEBRUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 5 - 7 REPRESENT WELL Z-13A WITH API#: 50-029-22069-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15443'MD/9074'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .05/03/15 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 1 and clipped curves; all bit runs merged. .5000 PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ . START DEPTH 10811.5 10818.5 10818.5 10818.5 10818.5 10818.5 10831.0 STOP DEPTH 15378.0 15388.5 15388.5 15388.5 15388.5 15388.5 15434.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10811.5 15434.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 10820.5 15443.0 BIT RUN NO 5 6 7 MERGED MAIN PASS. $ MERGE TOP 10840.0 10866.0 12238.0 MERGE BASE 10866.0 12238.0 15443.0 # 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 .1IN Max frames per record........... ..Undefined Absent value.. ....... ............ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 10811.5 0.15 19.05 0.59 0.16 0.47 0.45 0.22 Max 15434 304.57 447.69 2000 2000 2000 2000 150.79 Mean 13122.8 100.23 77.9183 11.3875 11.8569 13.5673 29.872 2.4717 First Reading For Entire File......... .10811.5 Last Reading For Entire File....... ....15434 Nsam 9246 9207 9134 9141 9141 9141 9141 9141 First Reading 10811.5 10831 10811.5 10818.5 10818.5 10818.5 10818.5 10818.5 Last Reading 15434 15434 15378 15388.5 15388.5 15388.5 15388.5 15388.5 . File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/03/15 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.. .... .05/03/15 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. 5 .5000 START DEPTH 10840.0 STOP DEPTH 10866.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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: 24-NOV-04 Insite 66.37 Memory 10866.0 10840.0 10866.0 17.0 17.0 TOOL NUMBER 6.750 10840.0 Water 11.30 53.0 9.2 1750 4.2 Based .000 .000 .000 .0 145.0 .0 · MUD CAKE AT MT: .000 - # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units...........Feet Data Reference Point....... .... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. ................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 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 MWD050 FT/H Min 10840 0.47 Max 10866 8.9 Mean 10853 5.75519 Nsam 53 53 First Reading 10840 10840 Last Reading 10866 10866 First Reading For Entire File...... ... .10840 Last Reading For Entire File........ ...10866 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/15 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...... .05/03/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. . BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ 6 .5000 START DEPTH 10820.5 10827.5 10827.5 10827.5 10827.5 10827.5 10866.5 STOP DEPTH 12192.0 12199.0 12199.0 12199.0 12199.0 12199.0 12238.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction...... ..... ..... . Down Optical log depth units.. ...... ...Feet Data Reference Point............. .Undefined . 26-NOV-04 Insite 66.37 Memory 12238.0 10866.0 12238.0 50.0 54.5 TOOL NUMBER 178513 159439 6.750 10840.0 LSND 11. 35 41.0 9.0 700 3.6 3.500 1. 208 1.970 2.400 65.0 201. 2 65.0 65.0 . Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10820.5 12238 11529.3 2836 10820.5 12238 ROP MWD060 FT/H 0.15 304.57 122.153 2744 10866.5 12238 GR MWD060 API 25.14 179.22 114.011 2744 10820.5 12192 RPX MWD060 OHMM 1. 08 1776.62 4.18434 2744 10827.5 12199 RPS MWD060 OHMM 1 1409.47 3.34847 2744 10827.5 12199 RPM MWD060 OHMM 1.18 2000 11.5382 2744 10827.5 12199 RPD MWD060 OHMM 1. 02 2000 12.6109 2744 10827.5 12199 FET MWD060 HOUR 0.22 29.43 1.35991 2744 10827.5 12199 First Reading For Entire File........ ..10820.5 Last Reading For Entire File.......... .12238 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation..... ..05/03/15 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... .., .05/03/15 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 GR RPD 4 header data for each bit run in separate files. 7 .5000 START DEPTH 12192.5 12199.5 STOP DEPTH 15387.0 15397.5 RPM RPS RPX FET ROP $ . 12199.5 12199.5 12199.5 12199.5 12238.5 15397.5 15397.5 15397.5 15397.5 15443.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction....... ..........Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.......... .... .......60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 05-DEC-04 Insite 4.3 Memory 15443.0 12238.0 15443.0 50.6 97.2 TOOL NUMBER 69706 171169 4.750 12236.0 Flo-pro 8.40 55.0 9.1 3000 .0 .950 .364 .980 .900 68.0 188.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT . . FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12192.5 15443 13817.8 6502 12192.5 15443 ROP MWD070 FT/H 0.36 303.97 91. 627 6410 12238.5 15443 GR MWD070 API 19.05 447.69 62.4195 6390 12192.5 15387 RPX MWD070 OHMM 0.59 2000 14.4773 6397 12199.5 15397.5 RPS MWD070 OHMM 0.16 2000 15.5065 6397 12199.5 15397.5 RPM MWD070 OHMM 0.47 2000 14.4377 6397 12199.5 15397.5 RPD MWD070 OHMM 0.45 2000 37.2762 6397 12199.5 15397.5 FET MWD070 HOUR 0.26 150.79 2.94861 6397 12199.5 15397.5 First Reading For Entire File......... .12192.5 Last Reading For Entire File....... ... .15443 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/03/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/15 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. . . . . . . . . . . . . . . . . . . . .05/03/15 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 . . . Sperry-Sun Drilling Services LIS Scan Utility . ó?Dt£2G~ $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 15 14:44:14 2005 If- /J 021 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/15 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. . . . . . . . . . . . . . . . . . . . .05/03/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Z-13A PB1 500292206970 BP Exploration (Alaska), Inc. Sperry~Sun Drilling Services 23-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003369825 B. HENNINGSE A. MADSEN MWD RUN 3 MW0003369825 B. HENNINGSE A. MADSEN MWD RUN 4 MW0003369825 B. HENNINGSE A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 12E 981 3132 82.76 55.42 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 7.500 4.750 CASING SIZE (IN) 7.625 5.500 DRILLERS DEPTH (FT) 11385.0 12230.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE Z-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 11385'MD/8204'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL A BIT OF RAT HOLE - NO DATA ARE PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4); AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND EWR4. 7. THIS WELLBORE WAS LOST DUE TO AN UNRETRIEVABLE FISH. 8. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 11' UPHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROM K. COONEY (SIS/BP) DATED 2 FEBRUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1 - 4 REPRESENT WELL Z-13A PB1 WITH API#: 50-029-22069-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14340'MD/8950'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name..... ....... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ . .5000 START DEPTH 11354.0 11361. 0 11361. 0 11361. 0 11361.0 11361.0 11401.0 . STOP DEPTH 14272.0 14281. 5 14281.5 14281. 5 14281. 5 14281. 5 14329.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 11354.0 14329.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 11365.0 14340.0 BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 11365.0 11643.0 12245.0 MERGE BASE 11643.0 12245.0 14340.0 # 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 .1IN Max frames per record.... ....... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11354 14329 12841. 5 5951 11354 14329 ROP MWD FT/H 0.18 4978.05 95.1545 5857 11401 14329 GR MWD API 15.54 446.77 76.4299 5837 11354 14272 RPX MWD OHMM 0.5 2000 15.3453 5842 11361 14281.5 RPS MWD OHMM 0.1 2000 17.7966 5842 11361 14281.5 RPM MWD OHMM 0.22 2000 20.5889 5842 11361 14281. 5 RPD MWD OHMM 0.28 2000 42.3192 5842 11361 14281.5 FET MWD HOUR 0.25 113.29 4.11801 5842 11361 14281. 5 First Reading For Entire File... ...... .11354 . Last Reading For Entire File...... .....14329 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .05/03/15 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.......05/03/15 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 GR RPD RPM RPS RPX FET ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 11365.0 11372.0 11372.0 11372.0 11372.0 11372.0 11412.0 # 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: # STOP DEPTH 11596.0 11603.0 11603.0 11603.0 11603.0 11603.0 11643.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 05-NOV-04 Insite 66.37 Memory 11643.0 11411. 0 11643.0 53.4 55.9 TOOL NUMBER 178505 90518 7.500 11385.0 . 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 .1IN Max frames per record... ..........Undefined Absent value......... ........... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . LSND 11. 20 55.0 8.8 1500 3.6 .980 .489 .920 2.250 70.0 147.2 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 11365 11643 11504 557 11365 11643 ROP MWD020 FT/H 0.18 149.43 65.8049 463 11412 11643 GR MWD020 API 50.59 126.86 85.3492 463 11365 11596 RPX MWD020 OHMM 0.89 1561. 37 7.8538 463 11372 11603 RPS MWD020 OHMM 1. 22 954.53 10.1049 463 11372 11603 RPM MWD020 OHMM 0.29 2000 63.3744 463 11372 11603 RPD MWD020 OHMM 0.81 2000 92.0097 463 11372 11603 FET MWD020 HOUR 0.5 54.3 10.5901 463 11372 11603 First Reading For Entire File...... ... .11365 Last Reading For Entire File........ ...11643 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .103/15 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...... .05/03/15 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 GR FET RPD RPM RPS RPX ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 11596.5 11603.5 11603.5 11603.5 11603.5 11603.5 11643.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12198.0 12205.0 12205.0 12205.0 12205.0 12205.0 12245.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 06-NOV-04 Insite 66.37 Memory 12245.0 11643.0 12245.0 49.2 52.4 TOOL NUMBER 178505 90518 6.750 11385.0 LSND 11. 20 45.0 9.0 1400 4.1 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .950 .402 .910 2.250 74.0 184.3 74.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point.... ..........Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value...... ............... .-999 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11596.5 12245 11920.8 1298 11596.5 12245 ROP MWD030 FT/H 0.32 237.29 118.914 1204 11643.5 12245 GR MWD030 API 52.55 167.17 119.757 1204 11596.5 12198 RPX MWD030 OHMM 0.69 9.05 2.19182 1204 11603.5 12205 RPS MWD030 OHMM 0.81 9.09 2.28684 1204 11603.5 12205 RPM MWD030 OHMM 1. 02 8.94 2.59154 1204 11603.5 12205 RPD MWD030 OHMM 1.12 9.12 2.82132 1204 11603.5 12205 FET MWD030 HOUR 0.25 15.91 1.57467 1204 11603.5 12205 First Reading For Entire File......... .11596.5 Last Reading For Entire File.......... .12245 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.... ... ... .1.0.0 Date of Generation.... ...05/03/15 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... ....05/03/15 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 GR RPD RPM RPS RPX FET ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 12198.5 12205.5 12205.5 12205.5 12205.5 12205.5 12245.5 STOP DEPTH 14283.0 14292.5 14292.5 14292.5 14292.5 14292.5 14340.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 14-NOV-04 Insite 4.3 Memory 14340.0 12245.0 14340.0 50.1 95.4 TOOL NUMBER 69706 171169 4.750 12230.0 Flopro 8.40 43.0 8.8 3200 5.8 .910 .319 .750 1.100 70.0 212.0 70.0 70.0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ..... ......0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing............ ...... ...60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value..... ................ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12198.5 14340 13269.3 4284 12198.5 14340 ROP MWD040 FT/H 7.87 4978.05 91. 5702 4190 12245.5 14340 GR MWD040 API 15.54 446.77 62.9298 4170 12198.5 14283 RPX MWD040 OHMM 0.5 2000 19.9693 4175 12205.5 14292.5 RPS MWD040 OHMM 0.1 2000 23.1224 4175 12205.5 14292.5 RPM MWD040 OHMM 0.22 2000 21.0342 4175 12205.5 14292.5 RPD MWD040 OHMM 0.28 2000 48.1991 4175 12205.5 14292.5 FET MWD040 HOUR 0.85 113.29 4.13372 4175 12205.5 14292.5 First Reading For Entire File.... ..... .12198.5 Last Reading For Entire File.......... .14340 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/03/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name... ...... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/15 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. . . . . . . . . . . . . . . . . . . . .05/03/15 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 - . _ ~O{-203> . $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 23 15:28:29 2005 ct ~ IJI~ Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 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.................... .05/02/23 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 Z-13A 500292006901 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 23-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003369825 P. SMITH D. FERGUSON MWD RUN 6 MW0003369825 P. SMITH D. FERGUSON MWD RUN 7 MW0003369825 P. SMITH D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 llN 12E 981 3132 82.76 55.42 . . # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 6.750 4.750 CASING SIZE (IN) 7.625 5.500 DRILLERS DEPTH (FT) 10840.0 12236.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE Z-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 10840'MD/7900'TVD. 4. MWD RUN 5 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL A BIT OF RAT HOLE - SROP DATA ONLY ARE PRESENTED. 5. MWD RUN 6 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4); AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 7 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND EWR4. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 9' UPHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROM K. COONEY (SIS/BP) DATED 2 FEBRUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 5 - 7 REPRESENT WELL Z-13A WITH API#: 50-029-22069-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15443'MD/9074'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header . . Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/23 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 GR FET RPD RPM RPS RPX ROP $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 10811.5 10818.5 10818.5 10818.5 10818.5 10818.5 10831.0 STOP DEPTH 15378.0 15388.5 15388.5 15388.5 15388.5 15388.5 15434.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH 10811.5 15434.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 10820.5 15443.0 BIT RUN NO 5 6 7 MERGED MAIN PASS. $ MERGE TOP 10840.0 10866.0 12238.0 MERGE BASE 10866.0 12238.0 15443.0 # 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 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10811.5 15434 13122.8 9246 10811.5 15434 ROP MWD FT/H 0.15 304.57 100.23 9207 10831 15434 GR MWD API 19.05 447.69 77.9183 9134 10811.5 15378 RPX MWD OHMM 0.59 2000 11.3875 9141 10818.5 15388.5 RPS MWD OHMM 0.16 2000 11.8569 9141 10818.5 15388.5 RPM MWD OHMM 0.47 2000 13.5673 9141 10818.5 15388.5 RPD MWD OHMM 0.45 2000 29.872 9141 10818.5 15388.5 FET MWD HOUR 0.22 150.79 2.4717 9141 10818.5 15388.5 First Reading For Entire File......... .10811.5 Last Reading For Entire File.......... .15434 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/02/23 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...... .05/02/23 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: 2 header data for each bit run in separate files. 5 . DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 10840.0 $ STOP DEPTH 10866.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing...,................ .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined . 24-NOV-04 Insite 66.37 Memory 10866.0 10840.0 10866.0 17.0 17.0 TOOL NUMBER 6.750 10840.0 Water 11.30 53.0 9.2 1750 4.2 Based .000 .000 .000 .000 .0 145.0 .0 .0 . . Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10840 10866 10853 53 10840 10866 ROP MWD050 FT/H 0.47 8.9 5.75519 53 10840 10866 First Reading For Entire File......... .10840 Last Reading For Entire File.......... .10866 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/23 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...... .05/02/23 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 GR FET RPD RPM RPX 3 header data for each bit run in separate files. 6 .5000 START DEPTH 10820.5 10827.5 10827.5 10827.5 10827.5 STOP DEPTH 12192.0 12199.0 12199.0 12199.0 12199.0 . RPS ROP $ 10827.5 10866.5 12199.0 12238.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................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 . 26-NOV-04 Insite 66.37 Memory 12238.0 10866.0 12238.0 50.0 54.5 TOOL NUMBER 178513 159439 6.750 10840.0 LSND 11.35 41.0 9.0 700 3.6 3.500 1.208 1.970 2.400 65.0 201.2 65.0 65.0 . . Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10820.5 12238 11529.3 2836 10820.5 12238 ROP MWD060 FT/H 0.15 304.57 122.153 2744 10866.5 12238 GR MWD060 API 25.14 179.22 114.011 2744 10820.5 12192 RPX MWD060 OHMM 1. 08 1776.62 4.18434 2744 10827.5 12199 RPS MWD060 OHMM 1 1409.47 3.34847 2744 10827.5 12199 RPM MWD060 OHMM 1.18 2000 11.5382 2744 10827.5 12199 RPD MWD060 OHMM 1. 02 2000 12.6109 2744 10827.5 12199 FET MWD060 HOUR 0.22 29.43 1.35991 2744 10827.5 12199 First Reading For Entire File..... .... .10820.5 Last Reading For Entire File.......... .12238 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/23 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...... .05/02/23 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 GR RPD RPM RPS RPX FET ROP $ 4 . header data for each bit run in separate files. 7 .5000 START DEPTH 12192.5 12199.5 12199.5 12199.5 12199.5 12199.5 12238.5 STOP DEPTH 15387.0 15397.5 15397.5 15397.5 15397.5 15397.5 15443.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 05-DEC-04 Insite 4.3 Memory 15443.0 12238.0 15443.0 50.6 97.2 TOOL NUMBER 69706 171169 4.750 12236.0 Flo-Pro 8.40 55.0 9.1 3000 .0 .950 .364 .980 .900 68.0 188.4 68.0 68.0 . . 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 .1IN Max frames per record............ . Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12192.5 15443 13817.8 6502 12192.5 15443 ROP MWD070 FT/H 0.36 303.97 91.627 6410 12238.5 15443 GR MWD070 API 19.05 447.69 62.4195 6390 12192.5 15387 RPX MWD070 OHMM 0.59 2000 14.4773 6397 12199.5 15397.5 RPS MWD070 OHMM 0.16 2000 15.5065 6397 12199.5 15397.5 RPM MWD070 OHMM 0.47 2000 14.4377 6397 12199.5 15397.5 RPD MWD070 OHMM 0.45 2000 37.2762 6397 12199.5 15397.5 FET MWD070 HOUR 0.26 150.79 2.94861 6397 12199.5 15397.5 First Reading For Entire File......... .12192.5 Last Reading For Entire File.......... .15443 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... ~ . . version Number.......... .1.0.0 Date of Generation...... .05/02/23 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 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. . . . . . . . . . . . . . . . . . . . .05/02/23 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 Sperry-Sun DritlPng Services LIS Scan Utility . dOc/-liJ3 $Revision: 3 $ , LisLib $Revision: 4 $ Wed Feb 23 15:00:40 2005 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. 1t1)1\¡~ Scientific Technical Services Tape Header Service name. .......... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Z-13A PB1 500292006970 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 23-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003369825 B. HENNINGSE A. MADSEN MWD RUN 3 MW0003369825 B. HENNINGSE A. MADSEN MWD RUN 4 MW0003369825 B. HENNINGSE A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 12E 981 3132 82.76 55.42 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 7.500 4.750 CASING SIZE (IN) 7.625 5.500 DRILLERS DEPTH (FT) 11385.0 12230.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE Z-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 11385'MD/8204'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL A BIT OF RAT HOLE - NO DATA ARE PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4); AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND EWR4. 7. THIS WELLBORE WAS LOST DUE TO AN UNRETRIEVABLE FISH. 8. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 11' UPHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROM K. COONEY (SIS/BP) DATED 2 FEBRUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1 - 4 REPRESENT WELL Z-13A PB1 WITH API#: 50-029-22069-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14340'MD/8950'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number. ...... ... .1.0.0 Date of Generation...... .05/02/23 Maximum Physical Record. .65535 File Type................ LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ . .5000 START DEPTH 11354.0 11361.0 11361.0 11361.0 11361.0 11361.0 11401.0 . STOP DEPTH 14272.0 14281. 5 14281. 5 14281.5 14281.5 14281.5 14329.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 11354.0 14329.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 11365.0 14340.0 BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 11365.0 11643.0 12245.0 MERGE BASE 11643.0 12245.0 14340.0 # 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 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11354 14329 12841. 5 5951 11354 14329 ROP MWD FT/H 0.18 4978.05 95.1545 5857 11401 14329 GR MWD API 15.54 446.77 76.4299 5837 11354 14272 RPX MWD OHMM 0.5 2000 15.3453 5842 11361 14281. 5 RPS MWD OHMM 0.1 2000 17.7966 5842 11361 14281. 5 RPM MWD OHMM 0.22 2000 20.5889 5842 11361 14281. 5 RPD MWD OHMM 0.28 2000 42.3192 5842 11361 14281.5 FET MWD HOUR 0.25 113.29 4.11801 5842 11361 14281.5 First Reading For Entire File......... .11354 . Last Reading For Entire File.......... .14329 File Trailer Service name....... ..... .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..... ..05/02/23 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. ..... .05/02/23 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 GR RPD RPM RPS RPX FET ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 11365.0 11372.0 11372.0 11372.0 11372.0 11372.0 11412.0 # 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: # STOP DEPTH 11596.0 11603.0 11603.0 11603.0 11603.0 11603.0 11643.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 05-NOV-04 Insite 66.37 Memory 11643.0 11411.0 11643.0 53.4 55.9 TOOL NUMBER 178505 90518 7.500 11385.0 . 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................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units. ....... ...Feet Data Reference Point... ...........Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . LSND 11.20 55.0 8.8 1500 3.6 .980 .489 .920 2.250 70.0 147.2 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 11365 11643 11504 557 11365 11643 ROP MWD020 FT/H 0.18 149.43 65.8049 463 11412 11643 GR MWD020 API 50.59 126.86 85.3492 463 11365 11596 RPX MWD020 OHMM 0.89 1561.37 7.8538 463 11372 11603 RPS MWD020 OHMM 1. 22 954.53 10.1049 463 11372 11603 RPM MWD020 OHMM 0.29 2000 63.3744 463 11372 11603 RPD MWD020 OHMM 0.81 2000 92.0097 463 11372 11603 FET MWD020 HOUR 0.5 54.3 10.5901 463 11372 11603 First Reading For Entire File......... .11365 Last Reading For Entire File.......... .11643 File Trailer Service name. ........... .STSLIB.002 Service Sub Level Name. . . Version Number.... ...... .1.0.0 . Date of Generation...... .05/02/23 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...... .05/02/23 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 GR FET RPD RPM RPS RPX ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 11596.5 11603.5 11603.5 11603.5 11603.5 11603.5 11643.5 # 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 EWR4 $ STOP DEPTH 12198.0 12205.0 12205.0 12205.0 12205.0 12205.0 12245.0 06-NOV-04 Insite 66.37 Memory 12245.0 11643.0 12245.0 49.2 52.4 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 178505 90518 # 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): 6.750 11385.0 LSND 11.20 45.0 9.0 1400 4.1 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .950 .402 .910 2.250 74.0 184.3 74.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... .... ....0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing... ...... ........... .60 .1IN Max frames per record.. .......... . Undefined Absent value................... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11596.5 12245 11920.8 1298 11596.5 12245 ROP MWD030 FT/H 0.32 237.29 118.914 1204 11643.5 12245 GR MWD030 API 52.55 167.17 119.757 1204 11596.5 12198 RPX MWD030 OHMM 0.69 9.05 2.19182 1204 11603.5 12205 RPS MWD030 OHMM 0.81 9.09 2.28684 1204 11603.5 12205 RPM MWD030 OHMM 1. 02 8.94 2.59154 1204 11603.5 12205 RPD MWD030 OHMM 1.12 9.12 2.82132 1204 11603.5 12205 FET MWD030 HOUR 0.25 15.91 1.57467 1204 11603.5 12205 First Reading For Entire File.... ..... .11596.5 Last Reading For Entire File....... ... .12245 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..05/02/23 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...... .05/02/23 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 GR RPD RPM RPS RPX FET ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 12198.5 12205.5 12205.5 12205.5 12205.5 12205.5 12245.5 STOP DEPTH 14283.0 14292.5 14292.5 14292.5 14292.5 14292.5 14340.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 14-NOV-04 Insite 4.3 Memory 14340.0 12245.0 14340.0 50.1 95.4 TOOL NUMBER 69706 171169 4.750 12230.0 Flopro 8.40 43.0 8.8 3200 5.8 .910 .319 .750 1.100 70.0 212.0 70.0 70.0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ............ ..0 Data Specification Block Type.....O Logging Direction... ... ...... .... . Down Optical log depth units... ....... .Feet Data Reference Point... ..... ... ...Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record..... ... .....Undefined Absent value................... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12198.5 14340 13269.3 4284 12198.5 14340 ROP MWD040 FT/H 7.87 4978.05 91. 5702 4190 12245.5 14340 GR MWD040 API 15.54 446.77 62.9298 4170 12198.5 14283 RPX MWD040 OHMM 0.5 2000 19.9693 4175 12205.5 14292.5 RPS MWD040 OHMM 0.1 2000 23.1224 4175 12205.5 14292.5 RPM MWD040 OHMM 0.22 2000 21.0342 4175 12205.5 14292.5 RPD MWD040 OHMM 0.28 2000 48.1991 4175 12205.5 14292.5 FET MWD040 HOUR 0.85 113.29 4.13372 4175 12205.5 14292.5 First Reading For Entire File... ...... .12198.5 Last Reading For Entire File...... ... ..14340 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.... ...05/02/23 Maximum Physical Record. .65535 File Type............... .LO Next File Name..... ..... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN . Continuation Number..... .01 Next Tape Name. ......... . UNKNOWN Comments............... ..STS LIS .. Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/23 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ... ........ . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. . Scientific Technical Services Scientific Technical Services