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Home My WebLink About201-054New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-054 6.50-029-22050-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14713 14643 9069 11489 none none 8845 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 29 - 107 29 - 107 1490 470 Surface 3413 10-3/4" 28 - 3441 28 - 3441 3580 2090 Intermediate 11700 7-5/8" 27 - 11727 27 - 9000 6890 4790 Production Perforation Depth: Measured depth: 11900 - 14637 feet True vertical depth:9065 - 9069 feet Tubing (size, grade, measured and true vertical depth)4-1/2 x 3-1/2" L-80 26 - 11554 26 - 8887 11489 8845Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker SABL-3 Liner 3194 3-1/2" 11519 - 14713 8864 - 9071 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2681841120451 4515737 1519 448 153 374 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9071 Sundry Number or N/A if C.O. Exempt: n/a Junk Packer Printed and Electronic Fracture Stimulation Data 5 patch tubing Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028333 PBU 16-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.05 12:54:46 -09'00' Bo York By Samantha Carlisle at 10:00 am, Feb 22, 2021 SFD 2/24/2021 SFD 2/24/2021 ADL 028332 RBDMS HEW 2/22/2021 DSR-2/22/21MGR21FEB2021 ACTIVITYDATE SUMMARY 7/10/2020 T/I/O= MIT T to 2500 psi FAILED / MIT IA to 2500 psi FAILED (Pre Patch) Pumped 1.2 bbls crude down tbg to test TP lost 210 psiin 15 mins. Pressured back up with 0.1 bbls. TP lost 150 psi 1st 15 min and 98 psi in 2nd 12 min. Bled gas off IA. Pressured up IA with 7.25 bbls crude. IAP lost 443 psi 1st 15 min & TP increased 741 psi. FWHPs=1110/154/24 8/20/2020 ***WELL S/I ON ARRIVAL*** SET 3 1/2" WHIDDON CATCHER @ 11,457' MD. PULLED DV FROM 9669' MD. SET INT-OGLV @ 9669' MD. PULLED CATCHER. PULLED 2.75" PX PLUG FROM 11,479' MD. ***WSR CONTINUED ON 8-21-20*** 8/21/2020 ***WSR CONTINUED FROM 8-20-20*** BRUSHED & FLUSHED TBG / GAUGED 2.80" TO 11,441' SLM. SET 2.75" NIPPLE REDUCER @ 11,479' MD (1.781" R NIPPLE). RAN CHECK SET TO CONFIRM NIPPLE REDUCER SET. SET 1.781" RR PLUG @ 11,479' MD. LRS CMIT TxIA 2760 PSI (PASSED). SEE LRS WSR DECISION MADE TO NOT HAVE S/O BELOW A PATCH. SET 3 1/2" WHIDDON CATCHER @ 11,479' MD. PULLED INT-OGLV FROM 9669' MD. SET INT-DGLV @ 9669' MD. PULLED CATCHER. ***JOB COMPLETE / ELINE NEXT TO SET PATCH*** 8/21/2020 T/I/O=200/250/20 Temp=SI Assist Slickline (PATCH TUBING / LINER) CMIT-TxIA to 2624 psi ***PASS*** Pumped 53 bbls 180* crude down Tbg for brush and flush. Pumped 7.7 bbls down Tbg/IA to take pressures to 2761/2727 psi for CMIT-TxIA. Tbg/IA lost 75/75 psi in 1st 15 mins and 28/28 psi in 2nd 15 mins for a total loss of 103/103 psi in 30 mins test. PASS. Bled Tbg/IA to 300/300 psi. Slickline in control of well per LRS departure. FWHP's=300/300/30 IA,OA=OTG **Tags hung on Wing and IA 8/22/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Patch) SET 3-1/2" BAKER 35 KB PATCH 7412' - 7432' ELEMENT TO ELEMENT (top of patch ~ 7410', oal lih ~ 25.70', minimum i.d. = 1.83"). LOG CORRELATED TO READ ACOUSTIC LDL DATED 29-DEC-2019 ***JOB COMPLETE ON 22-AUG-2020*** 8/22/2020 T/I/O=1000/1200/30 ATTEMPT MIT-T (PATCH TUBING / LINER) Pumped 2.2 bbls crude to take Tbg psi to 2770 psi. Tbg lost 270 psi in 14 mins and IA came up 110 psi in the same amount of time. LLR too low for minimum pump rate. FAIL. Bled Tbg to 1500 psi. FWHP's=1500/550/30 8/25/2020 T/I/O = 789/855/26. Temp = SI. LLR TBG (eval failed MIT-T). ALP = 1740 psi, AL SI @ casing valve. T FL @ near surface. Bled gas cap from TBG. Pumped up TP using 1.5 bbls to get to test pressure & 0.14 bbls pumped for LLR. LLR = 6 GPM. Bled TP to starting pressure 1.3 bbls returned. Tags hung. Final WHPs = 780/780/30. SV, WV, SSV, = C. MV = O. IA, OA = OTG. 11:45 Daily Report of Well Operations PBU 16-23A Daily Report of Well Operations PBU 16-23A 9/8/2020 ...Well shut in on arrival... (HES Eline - LDL) LOG RCH ARCHER LEAKPOINT TOOL FROM TTP AT 11,479' TO SURFACE. LEAK SIGNATURE AT 35KB PATCH CONFIRMED WITH STOP COUNTS. ***Job Complete. Well shut in on departure.*** 9/8/2020 T/I/O= 1061/955/25 Temp= S/I Assist E-line w/ LDL. (Patch Tubing/Liner) Pumped 5 bbls crude down TBG to maintain 1800-2000 psi differential to IA while E-line logged. FWHP=2137/257/29. ELine in control of well at LRS departure. 9/9/2020 ***CONT FROM 9/8/2020 WSR*** RDMO ELINE. ***WELL LEFT SHUT IN ON DEPARTURE*** 9/9/2020 T/I/O=213/257/29 Temp= S/I Freeze Protect Flowline (Post E-line) Pumped 3 bbls 60/40 and 118 bbls crude down FL owline, have IGV shut and pressured up Flowline to 1500 psi with 1 bbl 60/40. SV WV SSV= closed. MV IA OA= open. Tags hung. Final Whp's= 213/257/29 10/29/2020 ***WELL S/I ON ARRIVAL***(patch tbg/liner). PULLED 35 KB PATCH @ 7,410' MD (intact). ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE*** 11/7/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Patch Set) SET 3-1/2" x 21' BAKER 35KB ONE-TRIP PATCH 7410' - 7430' ELEMENT TO ELEMENT (top of patch = 7409' md, minimum I.D. = 1.83", oal lih = 25.70'). LOG CORRELATED TO READ ACOUSTIC LDL DATED 29-DEC-2019. ***JOB COMPLETE ON 07-NOV-2020*** 11/7/2020 T/I/O-938/969/22 MIT-T PASSED to 2000 psi (Patch tubing) .Pumped 1 bbl crude to reach test pressure. Tbg lost 20 psi in 1st 15 min and 16 psi in 2nd 15 min. for ttl losses of 36 psi in a 30 minute test (last 2 segments in log) bled back ~0.7 bbls FWHP-969/1117/21. SwV, WV, SSV-closed, MV-open, IA/OA-OTG. 12/19/2020 ***WELL S/I ON ARRIVAL***(patch tbg / liner) SET 4-1/2" WHIDDON ON XO @ 6,789' MD PULLED BK-DGLV'S FROM ST#3 (6,728' MD), ST#4 (3,888' MD) & ST#5 (2,991' MD) SET BK-OGLV'S IN ST#5 (2,991' MD) & ST#4 (3,888' MD) ***CONTINUED ON 12-20-19 WSR*** 12/20/2020 T/I/O = 630/1350/20. Temp = SI. Assist Ops with POP. ALP = 1350, open @ CV. Monitored WHPs post POP. Well popped at 21:00. See log for details. Final WHPs = 530/1690/80. ***Continued on WSR dated 12/21/20.*** 12/20/2020 ***CONTINUED FROM 12-19-20 WSR***(patch tbg / liner) SET BK-LGLV IN ST#3 (6,728' MD) PULL 4-1/2" WHIDDON FROM 4-1/2 x 3-1/2" XO EQUALIZED & PULLED 1.781 RR PLUG FROM NIPPLE REDUCER (11,479' MD) ***WELL LEFT S/I ON DEPARTURE*** Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL 16-23A (PTD 201-054) PATCH SETTING RECORD 11/07/2020 Please include current contact information if different from above. Received by the AOGCC 12/02/2020 PTD: 2010540 E-Set: 34309 Abby Bell 12/02/2020 Ima~ '~roject Well History File Coverl .ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. q~ 1- O_~-~ Well History File Identifier Organizing I~o,,~! [] RESCAN .1D,~ms: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA Diskettes, No. ,~ [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERQINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~~WINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SFIERYL~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ~ NO RESCANNEDBT; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: /si Quality Checked (do,~,,,! III IIIIIIIIIIIII III 12/10/02Rev3NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 48 AUG V 7 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue a01— ° J Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -16 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 16 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (1 0-404) DS-16 Date: 03/0612012 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTO 4 API # cement pumped cement off date inhibitor sealant date ft bbls ft na oat 16-01 1801360 50029205330000 Sealed conductor NA NA NA NA NA 16-02 1801500 50029205440000 Sealed conductor NA NA NA NA NA 16-03 1810110 50029205540000 Sealed conductor NA NA NA NA NA 16-044 1921510 50029205610100 Sealed conductor NA NA NA NA NA 16-05A 2010100 50029205740100 Sealed conductor NA NA NA NA NA 16-06B 2060110 50029205840200 Sealed conductor NA NA NA NA NA 16-07 1852040 50029214300000 Dust Cover NA NA NA NA NA 16-084 1991260 50029205490100 Sealed conductor NA NA NA NA NA 16-094 1910380 50029205580100 Sealed card ctor NA NA NA NA NA 16-104 1991230 50029205060100 Sealed conductor NA NA NA NA NA 16-11 1801180 50029205160000 Sealed conductor NA NA NA NA NA 16-12A 1990190 50029205650100 Sealed conductor NA NA NA NA NA 16-13 1810270 50029205660000 Sealed conductor NA NA NA NA NA 16-14B - 2060030 50029205700200 Sealed conductor NA NA NA NA NA 16-15 1852640 50029214740000 6.0 NA 6.0 NA 39.10 10/25/2011 16-16 1801270 50029205250000 Sealed conductor NA NA NA NA NA 16-17 1852200 50029214410000 72.0 17.0 1.5 9/3/2011 8.60 3/612012 16-18 1852430 50029214610000 34.0 13.0 0.7 913/2011 8.50 10/25/2011 16-19 1852650 50029214750000 16.0 10.0 0.3 9/3/2011 2.60 3/6/2012 16-20 1852850 50029214930000 8.0 NA 8.0 NA 40.80 8/1812010 16-21 1853120 50029215180000 29.0 10.0 0.3 9/3/2011 7.65 10/25/2011 16-22 1900510 8.0 NA 8.0 NA 51.00 8/23/2010 „_- 16-234 2010540 50029220500100 5.3 NA 5.3 NA 32.70 8/23/2010 16-24 1860240 50029215360000 0.8 NA 0.8 NA 8.50 10/25/2011 16-25 - 1920510 50700000 0.3 NA 0.3 NA 10.20 10/25/2011 16-26A 1991270 50029222670100 1.0 NA 1.0 NA 8.50 8/18/2010 16-274 2000040 50029222600100 1.3 NA 1.3 NA 10.20 8/18/2010 16-28 1920620 50029222760000 0.0 NA 0.0 NA 7.65 10/25/2011 16-294 1920660 50029222720000 Sealed conductor NA NA NA NA NA 16-30 1920760 50029222810000 0.8 NA 0.8 NA 6.80 8/18/2010 16-31 1920750 50029222800000 as NA 0.5 NA 5.10 8/18/2010 • 2.o\ - 524 v - & f l WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) Orientation / Bottom Hole Presure Survey: 2K -28 Run Date: 10/31/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -28 Digital Data (LAS), Digital Log file 1 CD Rom 50- 103 - 20385 -00 Bottom Hole Pressure Survey Log ' °'^ , ?0C, N[2, V7 ,;: 2.C1: 1 Color Log 50- 103 - 20385 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 17—A.6 Signed: azzedp. e e r~ :,..,~.:,.;t;"iê'""'''' "~ ' MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inserts\Microfillll_ Marker. doc Wo~ RE: WELL LOG TRANSMITYAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 16-23 A & 16-23 APB 1 June 06, 2003 AK-MM-10099 16-2.3A + PBI: Digital Log Images: 50-029-22050-01, 70 I CD Rom 'PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RE~G THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun 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~?, ""/f'~ 02 Signed: 'Note: This data is replacement fbr any lost or undelivered data fbr well 16-23 A, 16-23A PB 1. To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 16-23A & 16-23A PB1 January 15, 2003 AK-MM-10099 16-23A: Digital Log Images: 50-029-22050-01 16-23A PB 1: Digital Log Images: 50-029-22050-70 1 CD Rom 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED o z zoo BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 2003 Permit to Drill 2010540 MD 14713 ~'' TVD :¢ DATA SUBMITTAL COMPLIANCE REPORT 411812003 Well Name/No. PRUDHOE BAY UNIT 16-23A Operator BP EXPLORATION (ALASKA) INC 9073 J Completion Dat 4/27/2001 --- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22050-01-00 UIC N REQUIRED INFORMATION Mud Log N.__g.o Sample N_.9o Directional Survey ~o~/_~___,_~ ....... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital iTl~_ Media Fmt , D _ Ver LIS Verification Ver LIS Verification Ver LIS Verification Ver LIS Verification (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments M~D Survey FINAL Directional Survey FINAL 'I~IFR Survey FINAL Directional Survey FINAL M~/D Survey FINAL Directional Survey FINAL J~R Survey FINAL Directional Survey FINAL 11691 11691 11691 11691 14646 12930 12930 14646 CH 5/1/2001 Directional Survey, Digital Data OH 5/1/2001 Directional Survey, Digital Data OH 5/1/2001 IIFR Survey, Digital Data OH 5/1/2001 Directional Survey, Paper Copy OH 5/1/2001 MWD Survey, Digital Data OH 5/1/2001 Directional Survey, Paper Copy OH 5/1/2001 IIFR Survey, Digital Data OH 5/1/2001 Directional Survey, Paper Copy Open 1/3/2003 ~t~ 455 Open 1/3/2003 /-~56 Open 1/3/2003 Ope n 1/3/2003 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2010540 MD 14713 TVD Well Cored? Y / N Chips Received? Y / N Analysis Y / N R e r~.iv~.d ? DATA SUBMITTAL COMPLIANCE REPORT 4/'18~2003 Well Name/No. PRUDHOE BAY UNIT 16-23A Operator BP EXPLORATION (ALASKA) INC 9073 Completion Dat 4/27/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ./~Y~/N Formation Tops ~ N APl No. 50-029-22050-04-00 UIC N Comments: $/~ . Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cotton. Atm.- Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 20, 2002 RE: MWD Formation Evaluation Logs 16-23A PB1, AK-MM-10099 1 LDWG formatted Disc with verification listing. API#: 50-029-22050-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING, AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP iExploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 0 200 · ~ WELL LOG TRANSM1TYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska December 20, 2002 RE: MWD Formation Evaluation Logs 16-23A, AK-MM-10099 1 LDWG formatted Disc with verification listing. API#: 50-029-22050-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING, A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun 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: RECEIVED dAN 0,:3 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: MICROBE TREATMENT operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Oiher _ 6. Datum elevation (DF or K~B feet) RKB 66 feet 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Explorato~._ Stratigraphic__ Service__ 4. Location of well at surface 1624' FNL, 4030' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1281' FNL, 859' FEL, Sec. 25, T10N, R15E, UM At effective depth 1209' FNL, 3213' FEL, Sec. 25, T10N, R15E, UM At total depth 1182' FNL, 3282' FEL, Sec. 25, T10N, R15E, UM (asp's 720031, 5929328) (asp's 723348, 5924486) (asp's 720993, 5924488) ~sp~720923, 5924513) 12. Present well condition summary Total depth: measured true vertical 14713 feet Plugs (measured) 9073 feet Effective depth: measured true vertical 14640 feet Junk (measured) 9069 feet Casing Length Conductor 110' Surface 3379' Intermediate 11661' Straddle 4751' Liner 3194' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-23A 9. Permit number / approval number 201-0540 10. APl number 50-029-22050-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Tagged PBTD @ 14640' CTM (08/21/2001). Size Cemented Measured Depth True Vertical Depth 20" 1775# Poleset 110' 110' 10-3/4" 1000 sx CSIII, 300 s 'G' 3445' 3444' & Top Job 155 sx CSll. 7-5/8" 260 sx Class 'G' 11727' 8900' 5-1/2" 290 sx Class 'G' 11600' 8916' 3-1/2" 220 sx Class 'G' 11713' 9073' Perforation depth: measured Open Perfs 11900'- 12140', 12165'- 12205', 12245'- 13190', 14269'- 14637' · true vertical Open Perfs 9065' - 9072', 9074' - 9077', 9078' - 9072', 9063' - 9071' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80, Tubing @ 6789' MD; 3-1/2", 9.2#, L-80, Tubing @ 11522' MD. 5-1/2" x 3-1/2" BKR SABL-3 PKR @ 11457'. 5-1/2" X 3-1/2" BKR 4-1/2" NBS X Nipple @ 2103' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Dat~ OiI-Bbl Gas-Mcr Water-Bbl Casing'~-~¢~ Tubing Pressure Prior to well operation 01/27/2002 214 1225 131 247 Subsequent to operation 02/18/2002 310 1560 208 259 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I hereby c, ertify that the foregoing, is true and correct to the best of my knowledge. .~~~~~ Title: Technical Assistant DeWar/ne R. Schnorr Form 10-404 Rev 06/15/88 · Date February 21,2002 Prepared by DeWayne R. Schnorr 564-51 SUBMIT IN DUPLICATE '~ 16-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/01/2002 01/07/2002 01/14/2002 01/28/2002 01/29/2002 01/30/2002 MISC-CAP SUST.: DRIFT 2.50 CENT TO 11835' SLM (HAW) OBTAIN WELLBORE SAMPLE. MISC-CAP SUST.: TIFL PRE-MICROBE TREATMENT HOT OIL TBG WASH: HOT OIL TBG HOT OIL TBG WASH: PARAFFIN / ASPHALTENE REMOVAL MISC-CAP SUST.: LOAD WELL TO SECURE HOT OIL TBG WASH: MICROBE TREATMENT EVENT SUMMARY 01/01/02 DRIFT 2.50 CENT AND SAMPLE BAILER TO 11835' SLM (HAW) OBTAIN 01/07/02 TIFL PASSED. T/I/O = 220/1520/0 TIFL PASSED (PRE MICROBE STIM). IA FL 01/14/02 HOT OIL TBG WITH 97 BBLS OF 185' F CRUDE. 01/28/02 HOT OIL TBG WITH 97 BBLS HOT CRUDE. 01/29/O2 LOAD WELL WITH SEA WATER, BUG WATER, KCL WATER & DSL FOR TREATMENT. 01/30/2002 FINISH PUMPING BUG JUICE AND DISPLACEMENT. WELL LEFT SHUT IN FOR 14 DAYS. Fluids Pumped BBLS 1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 1 TEST) 10 METHANOL 30 DIESEL 116 KCL WATER 304 CRUDE 689 BUG JUICE 1150 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 65.85 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1624' FNL, 4030' FEL, Sec. 24, T1 ON, R15E, UM (asp's 720031, 5929328) 16-23A At top of productive interval 9. Permit number / approval number 1281' FNL, 859' FEL, SEC 25, T10N, R15E, UM (asp's 723348, 5924486) 201-054 At effective depth 10. APl number 50-029-22050-01 At total depth 11. Field / Pool 1182' FNL, 3282' FEL, SEC 25, T10N, R15E, UM (asp's 720923, 5924513) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14713 feet Plugs (measured) Tagged PBTD @ 14640' CTM on 8/21/2001. true vertical 9073 feet Effective depth: measured 14640 feet Junk (measured) true vertical 9071 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 1775# Poleset 110' 110' Surface 3379' 10-3/4" lOOO Sx CS III, 300 Sx Class G, 3445' 3444' & Top Job 155 Sx CS II Production 11661' 7-5/8" 260 Sx C~ass e 11727' 8900' Straddle 4751' 5-1/2" 290 Sx C~ass e 11600' 8916' Liner 3194' 3-1/2" 220 Sx 15.8 ppg Class G 1 1713' 9073' Perforation depth: measured11900'-12140'; 12165'-12205'; 12245'-13190';14269'-14637'. RECEiVe:: true vertical9065'-9072'; 9074'-9077'; 9078'-9072'; 9063'-9071'. J~U[~ 2 0 2001 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-SO Tubing @ 6789' MD; 3-1/2", 9.2#, L-80 Tubing @ 11522' MD. Alaska 0il & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) 5-1/2" X 3-1/2" Baker SABL-3 PACKER @ 11457' MD; 5-1/2" X 3-1/2" Baker CPH PACKER w/6' tieback@ 11519' MD. 4-1/2" HES X Nipple @ 2103' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ~6/31/2001) 152 893 80 - 300 Subsequent to operation(8~26~2001) 470 1252 320 - 345 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that/,t~e foregoing, is true and correct to the best of my knowledge. Signed Title: DS 16 Surveillance Engineer Date Auqust 27, 2001 Christopher Jenkins Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 16-23A DESCRIPTION OF WORK COMPLETED CT ACID STIMULATION Date Event Summary 7/30/2001: 8/01/2001: 8/19/2001: 8/20/2001: 8/21/2001: 8/22/2001 - 8/23/2001: Performed TIFL - passed. RIH w/Slickline & drifted to 11825' (HAW). Loaded IA w/140 bbls of Crude & 10 bbls Diesel. Performed a CT Acid Stimulation as follows: MIRU CTU & APC Test Separator. PT'd equip. Killed well w/260 bbls of Filtered 2% KCL Water. RIH w/CT & jetted perfs f/11900' to 14640' CTM. Jetted 25 bbls of 12% HCI/10% Xylene across the open perforation intervals located f/: 11900' - 12140' MD (Zone 4) 12165' - 12205' MD (Zone 4) 12245' - 13190' MD (Zone 4) 14269' - 14637' MD (Zone 4) PUH to 11750'. Let soak for 1/2 hr. Jetted an additional 88 bbls of 12% HCI / 10% Xylene across perforation interval. Flushed w/ 230 bbls of 2% KCI Water & POOH w/CT. Final injectivity was 1.1 bpm @ 300 psi. RD CTU. Produced well to APC portable test separator. Acid flowback to APC protable test separator. Placed well BOL & performed a representative welltest. Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL ~ GAS J-'J SUSPENDED r-] ABANDONED J~ SERVICE J-" 2. Name of Operator ! ]~O~~ : 7. Permit Number BP Exploration (Alaska), Inc. ~ 201-054 3. Address~' 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 · 50-029-22050-01 4. Location of well at surface "~ 9. Unit or Lease Name 1624' FNL, 4030' FEL, Sec. 24, T10N, R15E, UM (asp's 720031, 5929328)J'~~,~'~ Prudhoe Bay Unit At Top Producing Interval ~ ~,~ t ~ / 10. Well Number 1281' FNL, 859' FEL, SEC 25, T10N, R15E, UM (asp's 723348, 5924486)1 ~,..~:_~..~_~Z~-~ i 16-23A At Total Depth ~ ~'E,~'i;"~ ~ 11. Field and Pool 1182' FNL, 3282' FEL, SEC 25, T1 ON, R15E, UM (asp's 720923, 5924513)k.~_~_/~.~_.~2.F.T._.~..! 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. RKB 65.85 feetJ ADL 28333 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, it offshore 16. No. ot Completions April 9, 2001 April 19, 2001 April 27, 2001 J N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey J20. Depth where SSSV set 21. Thickness of Permafrost 14713' MD /9073' TVD 14643' MD /9071' TVD YES J~l No J-'J'J 2103' (nipple) feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD DIR/GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 1775# Poleset 10-3/4" 45.5# J-55 Surface 3445' 13-1/2" 1000 ex cs III, 3,00 sx Class G, & Top Job 155 Sx CS II 7-5/8" 29.7# L-80 Surface 11727' 9-7/8" 260 Sx Class G 5-1/2" 17# L-80 6849' 11600' 9-7/8" 290 Sx Class G 3-1/2" 9.2# L-80 11519' 11713' 4-3/4" 220 Sx 15.8 ppg Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2' guns, 4 SPF, & overba/ancedpress 4-1/2" 12.6" L-80 6789' 11457' 11900'- 12140' MD; 9065'-9072' TVD 3-1/2" 9.2" L-80 11522' 11519' 12165' - 12205' MD; 9074' - 9077' TVD 12245' - 13190' MD; 9078' - 9072' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14269' - 14637' MD; 9063' - 9071' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200 Freeze Protect w/92 bbls Diesel (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 11,2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OIL RATIO 5/12/2001 5.0 Test Period >J 785 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 338 psi 24-Hour Rate > 2332 1830 252 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved March 21,2001 (Permit #201-054) -- Form 10-407 ~nit in duplicate_~:m Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ORIGINAL GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. TSAD (Zone 4) 11789' 9035' 31. LIST OF ATTACHMENTS Summary of 16-23A Rig Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the fo~ is tree and correct to the best of my knowledge. Signed~~,,.~ Title BP Drillin.q En,qineer Date June 19, 2001 __ Phil Smith Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1-' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28; If no cores taken, indicate "none". Form 10-407 JUN 2,,5 Z001 Of-ttGll AL Alaska Oil & Gas Cons. Commission Anchorage TREE= 3-1/8" FMC5M WFI LI-EAD= FM( ACTUATOR= AXELSON KB. ELEV = 65.85 BF. ELEV = 38.2" KOP = 3900' Max Angle= 96@11981' Datum MD = 11525' Datum TV Ds s= 8800' 110-3/4" CSG, 45.5#K-55, D =9.953" H 3446' IMinimum D = 2.750" @ 11457' 5-1/2" X 3-1/2" BAKER SABL-3 PKR 4-1/2" 'FBG, 12.6#, L-80 TBT, .0152 bpf, ~-~ ID = 3.958" 6789' 14-/2" X 3-1/2" 'fBG XO, ID = 2.992" H 6789' 7-5/8" X 5-1/2" BKR H LNR TOP PKR H W/9' HR SEfTING SLV, ID = 4.875" | / 6849' 5-1/2" X 3-1/2" BKR CPH PKR I--I W/6'TIEBACK, D = 4.00" 3-1/2" TBG, 9.2#, L-80 NSCT, .0087 bpf, ID = 2.992" IBTM OF SCAB LINER I 7-5/8" X5-1/2" BKR 3-D LNR/HANGER H I' PKR, D = 4.892 11519' 11522' 11600' PEF~ORATIO N SUMMA RY REF LOG: SPERRY-SUN EWR/GR 04/20/01 ANGLEATTOP PB~F: 85 Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Op n/Sqz DA'rE 2" 4 11900 - 12140 O 4/23/2001 2" 4 12165 - 12205 O 4/23/2001 2" 4 12245 - 13190 O 4/23/2001 2" 4 14269 - 14637 O 4/23/2001 17-5/8"CSG, 29.7#, L-80BTC, D =6.875" H 11995' 16-23A SAFETY NOTES: WELL EXCEEDS 70 DEG @ 11827' & GOES HORIZONTAL @ 11951'. 2103' H4-1/2,,HES X-NIP, ID= 3.813" GAS LFT MA I',DRELS 11457' 11479' 11510' 11522' Id5-1/2"X 3-1/2" BKRSABL-3 PKR I ! W/K-22 ANCHOR SEAL ASSY, ID = 2.750" I I-~3-1/2" HES X N~P, ID= 2.750" 1~3-/12" HES XNIP, ID= 2.750"I iELMDTT NOTLOGGED I I 11727' I--~TOPOFWHIPSTOCK I I MILLOUT WINDOW11727' -11734'I RA TAG I ~BTD 10' MARKER JTW/RA TAG 13-1/2" LNR, 9.2#, L-80 NSCT, .0087 bpf, ID = 2.992" H 14713' DATE REV BY COMMI~ITS 06/23/90 ORIGIN& L COMFL ETLON 09/22/94 RWO 04/27/01 CI-I/KAK RIG SDETRACK PRUDHOE BAY UNIT WELL: 16-23A PERMIT No: Z01-054 APl No: 50-029-22050-01 SEC 24, T1 ON;, R15E, 1624' FNL & 1249' FWL BP Exploration (Alaska) BP EXPLORATION Page 1 of 1 Final Well I Event Summary ~Legal Well Name: 16-23 Common Well Name: 16-23^ Event Name: REENTER+COMPLETE Start Date: 3/31/2001 End Date: 4/27/2001 DATE TMD 24 HOUR SUMMARY 3/30/2001 (ft) PJSM on Rig move, lower derrick, moving rig f/Y-20A to DS16-23A 3/31/2001 (ft) Move Rig f/Y20A to DS 1623A, Spot Sub and Pits 4/1/2001 (ft) Fin RU, circ freeze protect diesel from tree+tbg 4/2/2001 (ft) Circ and cond. brine, ND tree / NU BOPs, BOP test, pull BPV 4/3/2001 (ft) Fin POH with Decmpl asmbly, NORM inspect, tbg,, PU/MU fish asmbly 4/4/2001 (ft) RIH w/fishing tools to 11,334'. Catch fish, rel K anchor, & POH. 4/5/2001 (ft) RIH & mill pkr. Cir hole. POH & L/D milling ass'y. 4/6/2001 (fi) RIH w/spear, POH, recovered tail pipe, Run slickline gr/jb, PDS log. 4/7/2001 (ft) Run slickline logs, set whipstock, & RIH. Squeeze perfs & POH. 4/8/2001 (ft) TIH & tag TOC. POH & P/U drlg ass'y, RIH & drill cmt, test csg, & POH. 4/9/2001 (ft) POH & test BOP. P/U Milling ass'y, RIH, & cut window. 4/10/2001 11,755.0 (ft) Cir hole, POH, & L/D BHA. P/U dir BHA, RIH, & run FIT. 4/11/2001 12,237.0 (ft) Perform FIT (EMW = 9.9 ppg). Dir drill to 12,237, Cir hole, & POH. 4/12/2001 12,367.0 (ft) POH & P/U new bit & MWD ass'y. RIH & return to dir drilling. 4/13/2001 12,956.0 (ft) Directional Drilling 4/14/2001 12,810.0 (fi) Cir & cond hole, POH, & P/U BHA # 8. RIH to 6849'. 4/15/2001 12,841.0 (ft) POH & repair MWD tool. RIH & perform open hole side track @ 12,810'. 4/16/2001 13,555.0 (ft) Dir drill f/12,841' to 13,555'. POH for rig repair/BOP test. 4/17/2001 13,789.0 (ft) Complete BOP test & rig repairs. RIH & con't dir drilling to 13,789'. 4/18/2001 14,360.0 (fi) Cont. dir. drll to 13,789 - 143,360. 4/19/2001 14,713.0 (ft) Dir. drill to TMD of 14,713', ST to window, TIH ream sidetrk, POOH 4/20/2001 14,713.0 (ft) POOH, LD excess 2-7/8" DP, MU, RIH w/liner assbly 4/21/2001 14,713.0 (ft) Run liner, circ./cement, set hngr and packer, POOH. 4/22/2001 14,713.0 (ft) Test packoff, RIH w/RTTS & seal assembly, set pkr, test Inr lap, pooh 4/23/2001 14,713.0 (fi) Run TCP guns, perforate, pooh, LD 2-7/8" DP and guns. 4/24/2001 14,713.0 (fi) Fin. LD TCP guns, LD 4" DP, PU, RIH w/cmpl assembly and tbg 4/25/2001 14,713.0 (fi) Land tbg, Press. test -failure, RU slickline, CO RPs, retest, failure 4/26/2001 14,713.0 (fi) Press. test tbg, ND/NU tree, freeze protect, release rig. 4/27/2001 14,713.0 (fi) Fin. NU tree, PT, freeze protect, secure well, release rig. Printed: 6/18/2001 11:15:56 AM BP EXPLORATION Page 1 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 3/30/2001 22:00 - 00:00 2.00 MOB PRE PJSM on rig move w/all involved personnel, lowered derrick, move rig f/Y-20A to DS 16-23A 3/31/2001 00:00 - 08:00 8.00 MOB PRE Move pits and camp from Y20A well location to 16-23A. 02:00 - 03:00 - Daylight Savings Changed, 05:00 - 07:30 - Wait on Securty to escort Sub f/H pad to Ds 16-23 under high power lines due to shortage of personnel. 08:00 - 21:30 13.50 MOB PRE Move rig to 16-23A location. 21:30 - 00:00 2.50 MOB PRE Spotting Sub and Pits 4/1/2001 00:00 - 03:00 3.00 RIGU PRE Continue to set the mud pits, spot the Rig 03:00 - 04:00 1.00 RIGU PRE Change to Daylight Savings Time 04:00 - 12:00 8.00 RIGU PRE RU Rig Floor, interconnect Mud tanks, spot and RU Rig components. RIG ACCEPTED ON DAYWORK AT 11:00 hrs, 4/1/01. i12:00 - 14:30 2.50 WHSUR DECOMP RU to pull BPV w/lubricator. Check for pressure under BPV, well on vacum. RD lubicator. . 14:30 - 16:30 2.00 KILL DECOMP RU to displace diesel, W/O water to build 8.5ppg brine. Test lines to 2,000 psi, found leak in the annulus valve. 16:30 - 23:00 6.50 KILL DECOMP Reverse out diesel from tbg with 8.5# brine. Circulate diesel from annulus w/brine. 23:00 - 00:00 1.00 KILL DECOMP Monitor well. Apparent U-tubing. 4/2/2001 00:00 - 04:00 4.00 KILL DECOMP Weight up, and circulate brine, bringing it to 8.8 ppg. 04:00 - 04:30 0.50 KILL DECOMP Monitor well - dead. Set BP¥ and tested - okay. 04:30 - 07:00 2.50 WHSUR DECOMP ND Tree, control line, and inspect tbg hanger internal and external threads. Install blanking cap. 07:00 - 10:00 3.00 BOPSUF DECOMP NU adaptor flange and BOPE. 10:00 - 12:00 2.00 BOPSUF DECOMP RU for BOP test. Unable to screw into Blanking Plug. Pull testjt and inspect threads - ok. 11:00 - 13:00 2.00 BOPSUF.THGR DECOMP Re-engage Blanking Plug, inadvertently release Blank Plug and ACME threads were galled. 13:00 - 16:00 3.00 BOPSUF DECOMP Test Choke Man. to 250/3500 psi for 10 rain - okay, while waiting on new Blank Plug. FLOOR to TBG SPOOL = 26.30' 16:00- 16:30 0.50 BOPSUF.THGR DECOMP Install new Blanking Plug 18:00- 18:30 0.50 BOPSUF; DECOMP Pull Blanking Plug. 18:30 - 19:30 1.00 BOPSUF DECOMP RU to pull BPV. While entering to pull BPV, broke end off of retrieving tool puller. 19:30 - 20:00 0.50 BOPSUF.THGR DECOMP RU 2-1/4" magnet, and retrieve BPV puller. 20:00 - 21:30 1.50 BOPSUF.THGR DECOMP RU new BPV retrieval tool and pull okay. RD lubricator. 21:30 - 23:30 2.00 BOPSUF DECOMP RU fishing tools to pull tbg hngr. Back out lock downs. 23:30 - 00:00 0.50 BOPSUF DECOMP Stab into and pull hanger to floor. Set string in slips, break control lines. (105K string weight). 4/3/2001 00:00 - 01:30 1.50 PULL DECOMP L/D 3-1/2" spear and tbg hngr. RU Control line spool & tbg equip., losses = 8 bbl/hr. 01:30 - 05:00 3.50 PULL DECOMP L/D 3-1/2" tbg & control line. 05:00 - 06:00 1.00 PULL DECOMP Clear drill floor and check SSSV for press.-okay. Recovered all steel bands, missing 1 buckle. 06:00 - 07:00 1.00 PULL DECOMP Service top drive. 07:00 - 12:30 5.50 PULL DECOMP LD 3-1/2" tbg (tbg appears okay to re-use, after visual inspection). RU tbg handling equip for 2-7/8". 12:30 - 18:00 5.50 PULL DECOMP Laydown 2-7/8" tbg., Total recovery of 3 1/2" x 2 7/8" completion string = 11338.60' 18:00 - 19:30 1.50 PULL DECOMP Install test plug, RU, test lower VBR w/2-7/8" test joint to 250/3500 - okay. Tested safety valve and Dart valve to 250/3500 psi. 19:30 - 20:00 0.50 PULL DECOMP Pull test plug and install Wear Ring. 20:00 - 23:30 3.50 PULL DECOMP Held PJSM, PU/MU Fishing tools and BHA, change out elevators. Printed: 5/1/2001 10:31:39 AM BP EXPLORATION Page 2 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/3/2001 23:30 - 00:00 0.50 PULL DECOMP PU and run 2-7/8" DP to 570'. 4/4/2001 00:00 - 04:30 4.50 PULL DECOMP Con't RIH picking up 2-7/8" DP f/570' to 5300'. 04:30 - 05:00 0.50 PULL DECOMP PJD & secure 2-7/8" handling tools & equip & circulate 2-7/8" DP volume @ 5300'. 05:00-10:30 5.50 PULL DECOMP Con't RIHpickingup4"DPto11,310'.(stgwt=102kup&100kdn). No hole problems. 10:30 - 11:30 1.00 PULL DECOMP Kelly up & circulate hole. Engage fish @ 11,334'. Rotate pipe & release K anchor. 11:30 - 13:00 1.50 PULL DECOMP Circulate bottoms up @ 11,334'. 13:00 - 13:30 0.50 PULL DECOMP Monitor well & check for flow. 13:30 - 14:30 1.00 PULL DECOMP POH f/11,334' to 10,348'. 14:30 - 15:30 1.00 PULL DECOMP Recalibrate Epoch unit & monitor well. 15:30 - 21:00 5.50 PULL DECOMP Con't POH f/10,348' to 380'. 21:00 - 22:30 1.50 PULL DECOMP LID 3-1/2" DC's & fishing tools. Recover 2-7/8" tbg stub & K anchor (fish recovery = 13.03'). 22:30 - 00:00 1.50 PULL DECOMP PJSM, cut & slip drilling line, & service top drive unit & rig. 4/5/2001 00:00 - 00:30 0.50 PULL DECOMP Con't ~ Service rig & top drive unit. 00:30 - 02:30 2.00 PULL DECOMP P/U flat bottomed mill & BHA # 2 & RIH picking up 3-1/2" DC's to 387'. 02:30 - 06:00 3.50 PULL DECOMP R/U 2-7/8" handling tools & equipment. RIH f/387' to 5307'. RID & secure 2-7/8" handling tools & equipment. 06:00 - 08:00 2.00 PULL DECOMP Con't RIH w/4" DP f/5307' to 11,286'. 08:00 - 10:00 2.00 PULL DECOMP Kelly up & circulate hole. TIH & engage packer @ 11,347'. Mill f/ 11,347' to 11,348'. w/2 - 4k wt & 2500 - 4500 # torque. (stg wt = 162 k up, 144 k dn, & 155 k rot). 10:00 - 11:30 1.50 PULL DECOMP Gas breaking out at surface. Pick up, shut down pumps, well flowing~ Shut in well. Monitor well - 0 psi on CSG & DP. Open well & check fl0~. No flow & fluid leve static. 11:30 - 12:30 1.00 PULL DECOMP Con't milling operations. Mill f/11,348' to 11,349' & push pkr to 11,377'. XJ 12:30 - 13:00 0.50 PULL DECOMP Pump sweep & circulate hole from 11,377'. 13:00 - 13:30 0.50 PULL DECOMP Pick up & monitor well. Well flowing. Shut in well. 0 psi on Csg & DP. Open well & monitor well. Fluid level static. 13:30 - 16:30 3.00 PULL DECOMP Con't circulate hole. Flow increase, gas breaking out at surface. Shut in well. 150 psi Csg pressure & 0 psi on DP. Circulate hole thru choke @ SPR of 45 spm @ 600 psi. 16:30 - 17:00 0.50 PULL DECOMP Monitor well. 0 psi on both Csg & DP. Open well & observe fluid level- static. 17:00 - 20:00 3.00 PULL DECOMP POH f/11,377 to 6803'. 20:00 - 21:30 1.50 PULL DECOMP Circulate sweep @ liner top (6849'). Monitor well - static. Pump dry job. 21:30 - 00:00 2.50 PULL DECOMP POH f/6803' to 386'. 4/6/2001 00:00 - 01:00 1.00 PULL DECOMP Con't ~ POH & LID BHA # 2. (Recover +/- 8 # ferrous metal from junk baskets). 01:00-07:00 6.00 PULL DECOMP P/Uspear&BHA#3&RIHto11,613'.(stgwt=165kup,&145kdn). Engage fish @ 11,613'. Stg wt increased to 225 k up, pulled free. Monitor well - static. 07:00 - 08:00 1.00 PULL DECOMP POH f/11,613' to 11,246'. 08:00 - 09:30 1.50 PULL DECOMP Circulate bottoms up. (Note - no gas to surface). 09:30 - 10:00 0.50 PULL DECOMP Monitor well - static 10:00 - 18:30 8.50 PULL DECOMP Con't POH & L/D BHA # 3 & spear. Recover Pkr mandrell & tail pipe (+/- 225'). LID Tail pipe. Clear floor & secure handlling tools. Printed: 5/1/2001 10:31:39AM BP EXPLORATION Page 3 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/6/2001 18:30 - 22:30 4.00 PULL DECOMP PJSM. Rig up slick line tools & RIH w/4.65" gauge ring & junk backer. (one tight spot @ 6868') Tag top of sand @ 11,821'. POH & L/D gauge ring & junk basket. 22:30 - 00:00 1.50 PULL DECOMP M/U & P/U PDS tool & RIH. 4/7/2001 00:00 - 03:00 3.00 PULL DECOMP Con't run PDS log on slickline from PBTD @ 11821' to 5-1/2" liner @ 11,575'. 03:00 - 05:30 2.50 PULL DECOMP R/U & RIH w/3.625" OD dummy whipstock ass'y to PBTD @ 11,821'. POH, L/D dummy whipstock, & R/D & move out HES. 05:30 - 06:00 0.50 PULL DECOMP ~Pump into well & establish injection rate. Final injection rate @ 6 BPM = 1720 PSI. 06:00 - 08:30 2.50 PULL DECOMP R/U Schlumberger. P/U & RIH w/GR - Temp tool to 11815'. POH & Secure Schlumberger equipment. 08:30 - 09:30 1.00 PULL DECOMP Slip & cut drilling line, & adjust brakes on draworks. 109:30 - 14:30 5.00 PULL DECOMP R/U Schlumberger. P/U & M/U whipstock. RIH & tie into GR-CCL log, & set whipstock @ 11,735' (top). POH & RID Schlumberger. 14:30 - 19:30 5.00 PULL DECOMP P/U & M/U Baker cement nozzel & RIH (picking up) 2-7/8" X 4" drill pipe to 11,568'. 19:30 - 20:00 0.50 PULL DECOMP Service Top drive unit & rig. 20:00 - 21:30 1.50 PULL DECOMP RIH f/11,568' to 11,725' & DID NOT TOUCH WHIPSTOCK. POH to 11,221'. 21:30 - 22:00 0.50 PULL DECOMP Shut in well & re-establish injection rate of 2 BPM @ 660 PSI. 22:00 - 23:00 1.00 PULL DECOMP PJSM. PJU Dowell & pressure test pump & lines to 3500 PSI - OK. Mix & pump 15 Bbls of "G" Cement followed by 2 Bbls of fresh water. RID Dowell. 23:00 - 00:00 1.00 PULL DECOMP Displace cement with 56.4 Bbls water. Shut in well & squeeze cement w/additional 30.2 Bbls. Very good squeeze presure was observed. Final squeeze pressure = 2425 PSI. Hold pressure 20 min & release pressure. Monitor well - fluid level static. 4/8/2001 00:00 - 01:00 1.00 PULL DECOMP Circulate hole clean & wash down f/11,221' to 11,512'. Top of cement @ 11,512'. Cement could not be circulated out. 01:00 - 02:30 1.50 PULL DECOMP Circulate bottoms up w/a trace of cement in returns. 02:30 - 08:00 5.50 PULL DECOMP POH & LID cement nozzel. 08:00 - 08:30 0.50 PULL DECOMP Service & adjust top drive unit. 08:30 - 09:30 1.00 PULL DECOMP PJSM. Load pipe shed & strap BHA. 09:30 - 11:00 1.50 PULL DECOMP P/U & M/U 4-3/4" mill & P/U BHA # 4. 11:00 - 15:30 4.50 PULL DECOMP RIH to 11,449' & break circulation. 15:30 - 19:00 3.50 PULL DECOMP Circulate hole & clean out cement f/11,512' to 11,720'. 19:00 - 20:30 1.50 PULL DECOMP Pump Hi-Vis sweep & circulate hole clean. 20:30 - 21:30 1.00 PULL DECOMP Pressure test Csg (as per program) to 4000 PSI for 30 Min - OK. 21:30 - 00:00 2.50 PULL DECOMP POH f/11,720' to 5,750'. Note - Pressure test Choke mainfold while POH. 4/9/2001 00:00 - 04:00 4.00 PULL DECOMP Con't - POH f/5750' to surface & LID BHA # 4. 04:00 - 07:30 3.50 PULL DECOMP Recover wear bushing & set test plug. Pressure test BOP stack (as per BP requirements) to 250 PSI (5 min Iow pressure) & 3500 PSI (10 min high pressure). All BOP componants pressure tested - OK & chart on file. Pull test plug & reset wear bushing. 07:30 - 08:00 0.50 PULL DECOMP Pick up mill & motor & BHA # 5. 08:00 - 14:00 6.00 PULL DECOMP RIH to 11,485', filling drill string every 20 stands & function testing motor. Printed: 5/1/2001 10:31:39AM BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/9/2001 14:00 - 15:30 1.50 PULL DECOMP Wash down (as a precaution) from 11,485' to top of cement @ 11,720' & drill cement to top of whipstock @ 11,727'. (stg wt -' 165 k up & 140 k dh). 15:30 - 16:30 1.00 PULL DECOMP Pump 50 Bbl spacer & displace hole to 8.8 ppg Quickdrill mud system. 16:30 - 00:00 7.50 PULL DECOMP Mill window fl 11,727' to 11,745'. 4/10/2001 00:00 - 02:30 2.50 DRILL LNR1 Pump Hi-vis sweep, drop ball, & circulate hole clean (stg wt = 160 k up & 145 k dn) 02:30 - 08:00 5.50 DRILL LNR1 POH & L/D BHA # 5. Gauge mills = full gauge. 08:00 - 10:00 2.00 DRILL LNR1 Clear floor & secure handling tools. Pull wear bushing, flush & function test BOP stack, & reset wear bushing. 10:00 - 14:30 4.50 DRILL LNR1 P/U & M/U directional BHA # 6. Shallow test motor @ 97' - OK. RIH to 5967'. 14:30 - 15:30 1.00 DRILL LNR1 Slip & Cut drilling line. 15:30 - 16:30 1.00 DRILL LNR1 Service top drive & rig. Fill pipe & flow test MWD ass'y - OK. 16:30 - 19:00 2.50 DRILL LNR1 RIH f/5967' to 11,655'. Fill pipe & fuction test MWD ass'y @ 8750'. 19:00 - 20:00 1.00 DRILL LNR1 Orientate to 12 Deg LHS. Slid thru window (11,727' - 11,734') w/no pump & no rotation with no drag. 20:00 - 22:30 2.50 DRILL LNR1 Directionaly drill 4.65" hole w/2.77 Deg mtr f/11,745' to 11,755'. MWD = GR. (stg wt = 165 k up & 145 k dn). AST = 1.25 & ART = 0. 22:30 - 00:00 1.50 DRILL LNR1 Pump sweep & circulate bottoms up. Prepare for FIT. 4/11/2001 00:00 - 00:30 0.50 DRILL LNR1 Conduct FIT test. Stabilized pressure = 370 PSI (EMW of 9.878 ppg). 00:30 - 18:30 18.00 DRILL LNR1 Dir drill 4.65" hole w/2.77 Deg mtr f/11,755' to 12,237'. MWD = GR. (stg wt - 160 k up & 140 k dn) ART = 0 & AST -- 10.5 hrs. 18:30 - 20:00 1.50 DRILL LNR1 Pump hi vis sweep & circulate hole clean. 20:00 - 00:00 4.00 DRILL LNR1 POH to P/U re-configured directional ass'y. 4/12/2001 00:00 - 03:30 3.50 DRILL LNR1 Con't ,,, POH & LID BHA # 6. 03:30 - 04:00 0.50 DRILL LNR1 Adjust kick pad on mud motor to 1.50 Deg. 04:00 - 04:30 0.50 DRILL LNR1 Clean floor & secure handling tools. 04:30 - 05:30 1.00 DRILL LNR1 P/U & M/U bit # 2. Orient motor & P/U MWD as'y. 05:30 - 11:00 5.50 DRILL LMWD LNR1 Up load MWD & RIH. Shallow test MWD - failed. POH & change out MWD probe & shallow test - OK @ 89'. 11:00 - 17:00 6.00 DRILL LNR1 P/U BHA # 7 & RIH picking up 2-7/8" DP (66 additional its) & con't RIH w/4" DP to top of window @ 11727'. 17:00 - 20:00 3.00 DRILL LNR1 Con't RIH & conduct MAD-PASS from top of liner (@ 11,727') to TD @ 12,237'. 20:00 - 00:00 4.00 DRILL LNR1 Directional drill 4.65" hole w/1.5 Deg mtr f/12,237' to 12,367'. MWD = gr & res. (stg wt = 150 k up, 125 k dn,& 140 k rot). AST = 1 Hr & ART = .75 Hr. 4/13/2001 00:00 - 00:00 24.00 DRILL LNR1 Dir drill w/1.5 Deg mtr f/12,367' to 12,956'. MWD = gr& res. (stg wt = 155 k up, 130 k dn, & 145 k rot) AST = 10.0 Hrs & ART = 2.5 Hrs. 4/14/2001 00:00 - 04:30 4.50 DRILL LNR1 Con't dir drill w/1.5 Deg mtr f/12,956' to 12,997'. MWD = GR / RES. (stg wt = 160 k up, 135 k dn, & 140 k rot). AST = 2.25 Hrs & ART = 0 Hr. 04:30 - 07:30 3.00 DRILL DIR LNR1 Pump Hi- Vis sweep & circulate hole clean. 07:30 - 08:00 0.50 DRILL DIR LNR1 POH f/12,997' to 12.280'. Tight spot @ 12,280'. 08:00 - 10:00 2.00 DRILL DIR LNR1 Work thru tight spot f/12,280' to 12,255'. Tight spot required a max of 35 k overpull. Con't POH to 11,055'. Hole did not take correct amount of fluid for DP pulled out of hole. 10:00 - 10:30 0.50 DRILL DIR LNR1 Monitor well for flow. Well static 10:30 - 11:30 1.00 DRILL DIR LNR1 RIH f/11,055' to TD @ 12,997'. Hole took correct amount of fluid. 11:30 - 14:00 2.50 DRILL DIR LNR1 Pump Hi-Vis sweep & circulate hole clean. No gas seen @ bottoms up. Monitor well. Printed: 5/1/2001 10:31:39AM BP EXPLORATION Page 5 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/14/2001 14:00 - 15:00 1.00 DRILL DIR LNR1 POH f/12,997' to 11,712' (Csg window @ 11,727') & monitor well. Well static. 15:00 - 23:30 8.50 DRILL DIR LNR1 Con't POH, L/D BHA, download & L/D MWD. Orientation on mud motor was 50 Deg off!! 23:30 - 00:00 0.50 DRILL DIR LNR1 P/U bit (rr bit # 2), mud motor & BHA (with loctite on critical threads). 4/15/2001 00:00 - 03:00 3.00 DRILL DIR LNR1 P/U & M/U MWD ass'y & upload tools. RIH to 89' & perform shallow surface test. MWD tools had 'faint' signal. 03:00 - 04:00 1.00 DRILL DIR LNR1 RIH to 1166' & test MWD. No signal rec'd for tools. 04:00 - 05:00 1.00 DRILL DIR LNR1 POH f/1166' & L/D flex DC's & jars. 05:00 - 08:30 3.50 DRILL DIR LNR1 Inspect MWD & mud motor. Down load MWD. Change out pulser & flow tube. Up load MWD & shallow test - OK. 08:30 - 14:30 6.00 DRILL DIR LNR1 P/U BHA & RIH on drill pipe to 11708'. 14:30 - 17:30 3.00 DRILL LNR1 Slip & cut drilling line (93"), adjust brakes, service top drive unit, service crown, & service rig. Repair hydraulic hose on draworks. 17:30 - 18:30 1.00 DRILL DIR LNR1 Con't RIH f/11,708' to 12,737' (no problems with Csg window @ 11,727' - 11,734;'). 18:30 - 21:30 3.00 DRILL DIR LNR1 Pump sweep & circulate hole clean. Begin drilling trough for start of open hole side track f/12,737 to 12,810', on the Iow side of the hole. 21:30 - 00:00 2.50 DRILL LNR1 Directional drill 4.65" hole w/1.83 Deg mtr f/12,810' to 12,841'. MWD - GR & RES. (stg wt = 155 k up & 135 k dn). AST = 1.25 Hrs & ART = 0 Hrs. 4/16/2001 00:00 - 18:30 18.50 DRILL LNR1 Con't directional drilling wi 1.83 Deg mtr f/12841' to 13,555'. MWD - GR & RES. (stg wt = 165 k up, 135 k dn, & 145 k rot) AST = 5.75 Hfs & ART = 5.25 Hrs. 18:30 - 20:30 2.00 DRILL TDRV LNR1 Trouble shoot blower problems in top drive unit. 20:30 - 23:00 2.50 DRILL TDRV LNR1 POH f/13,555' to 9,935' for rig repairs. Note - AOGCC notified of trip out of hole. AOGCC made decision to test BOP at this point. 23:00 - 00:00 1.00 DRILL LNR1 P/U RTTS Storm Pkr & set same @ 40' & hang off drill string. POH & prepare for BOP test. 4/17/2001 00:00 - 01:00 1.00 DRILL LNR1 MU RTTS, RIH and set at 40', test to 1,000 psi. 01:00 - 01:30 0.50 DRILL LNR1 Pull wear bushing. 01:30 - 05:30 4.00 DRILL LNR1 RU & set test pig. Test Annular 250/3500 psi - okay. Test Rams and choke manifold 250/4,000 psi - okay. Test Dart and TIW valves 250/4000 psi - okay. RD test equip. 05:30 - 06:00 0.50 DRILL LNR1 Bleed pressure, and install WB 06:00 - 10:00 4.00 DRILL TDRV ~ LNR1 RIG REPAIR - Change out Blower motor on Top Drive. 10:00 - 11:00 1.00 DRILL LNR1 Test upper and lower rams 250/4000 psi - okay. RD test equip., blow down well. 11:00 - 12:00 1.00 DRILL LNR1 Retreive RTTS pkr. 12:00 - 15:00 3.00 DRILL TDRV LNR1 RIH thru window - okay. Took weight (7,000#, at 12,817') Cont. RIH to 13,555', orient toolface. 15:00 - 00:00 9.00 DRILL LNR1 Drill 13,555' - 13,789'. ART = 2.5 hr, AST 1.25 hr. 4/18/2001 00:00 - 00:00 24.00 DRILL LNR1 Drill from 14,389' - 14,360. Daily total ART - 8 hrs, AST - 6 hrs. Orentation changes in toolface not reslSonding correctly with expected course corrections. Discussed w/engdgeol and agreed to increase toolface orientation by adding 50 degrees. 4/19/2001 00:00 - 10:30 10.50 DRILL LNR1 Drill from 14,360' - 14,713'. ART = 3-1/2 hrs, AST = 3/4 hrs. 10:30 - 12:00 1.50 DRILL LNR1 Pump HI-Vis sweep, C&C, monitor well. 12:00 - 13:00 1.00 DRILL LNR1 Circ sweep out, monitor well, POOH to 11,710', monitor well. 13:00 - 16:30 3.50 DRILL LNR1 Hole stable. TIH and backream OH sidetrack 12,840'-12,817'. 16:30 - 18:30 2.00 DRILL LNR1 Cut/Slip 68' of drill line, adj. brakes, chk linkage, clean under drwks. Service Top Drive. 18:30 - 20:00 1.50 DRILL LNR1 RIH to TD, 14,713' - no prob. Printed: 5/I/2001 10:31:39AM BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/19/2001 20:00 - 23:30 3.50 DRILL LNR1 circ sweep ahead, and spot 70 bbl liner running pill in OH 23:30 - 00:00 0.50 DRILL LNR1 Monitor well, hole stable, POOH to 14,200'. 4/20/2001 00:00 - 02:00 2.00 DRILL LNR1 Cont. POH f/14,200' to 11616' - SLM. 02:00 - 03:30 1.50 DRILL LNR1 Break circ., drop ball, open PBL, circ. and clean hole at 10 bpm and 2,950 psi. Pump slug, nd drop 1-7/8" rabbit. 03:30 - 05:30 2.00 DRILL LNR1 Cont. POOH w/wet string to 8,066' - SLM. 05:30 - 06:00 0.50. DRILL LNR1 RU equip, for 2-7~8" DP. 06:00 - 09:00 3.00 DRILL LNR1 Cont. POOH wet string to 3,524' - SLM. (no correction). '09:00 - 12:00 3.00 DRILL LNR1 POOH to 218', lay down excess 2-7/8" DP (99 jts) 12:00 - 15:00 3.00 DRILL LNR1 Laydown BHA. Inspect directional tools. - okay. LD MWD and mud motor. 15:00 - 15:30 0.50 DRILL LNR1 Service and run WB. 15:30 - 16:00 0.50 DRILL LNR1 Clear & clean rig floor. 16:00 - 16:30 0.50 CASE LNR1 RU csg equip. 16:30 - 23:30 7.00 CASE LNR1 PU float shoe, shoe joint, FC and thread lock same. Run 98 jts 3-1/2" 9.2#/ft, L-80, NSCT tbg with 1 turbolator cent. perjt. RIH to 3,202' filling every 5 jts. Run RA marker. 23:30 - 00:00 0.50 CASE LNR1 MU liner hanger. Circ. liner volume. 4/21/2001 00:00 - 03:00 3.00 CASE LNR1 Continue running 3-1/2" liner to 7,930' on 2-7/8" DP, filling every 10 stands. 03:00 - 06:00 3.00 CASE LNR1 Change out elevators, PU XO, and cont. runing on 4" DP to top of window at 11,727'. 06:00 - 07:00 1.00 CASE LNR1 MU cement head and circ. at the window. 07:00 - 09:30 2.50 CASE LNR1 Run in open hole to TD at 14,713. 09:30 - 12:30 3.00 CASE LNR1 Circ and cond., batch mix cement while reciprocating liner. 12:00 - 15:00 3.00 CEMT LNR1 Pumped 5 bbls spacer and test lines to 4,000 psi - okay. Pumped 25 bbls spacer + 30 bbls of preflush at 9.9 ppg, followed by 220 sx (46 bbls of 15.8 ppg cmt. Flush lines and drop wiper plug and follow with 30 bbl perforating pill. Displace with 117 bbls mud. Bump plug, and pressure up to 3,500 psi. Set liner hanger. Slack off 35K lbs and check hngr. - okay. Bleed off pressure and check floats - okay. Rotate and release from hngr, switch to rig pumps and pressure up to 1,000 psi. Unsting from liner and circ 30 bbls. Set 50K lb. down to confirm that liner set. Circ. out cement from top of liner (approx. 5 bls of cmt returns). 15:00 - 17:30 2.50 CASE LNR1 :Displace well with 8.8ppg brine 17:30 - 18:00 0.50 CASE LNR1 LD cement head. 18:00 - 23:00 5.00 CASE LNR1 :POOH from 11,519' to 4,727' and switch to 2-7/8" tools, POOH. 23:00 - 23:30 0.50 CASE LNR1 RD 2-7/8" tools, clean rig floor. 23:30 - 00:00 0.50 CASE LNR1 RU and pressure casing to 3,500 psi. Held PJSM. 4/22/2001 00:00 - 03:00 3.00 CASE LNR1 Cont. attempt to pressure test casing. Re-check all surface valves and equip. Pressure tests failed. Move perf. guns to pipe shed, and RD running equip. 03:00 - 05:00 2.00 CASE OTHR LNR1 RU FMC and test packoff to 3,200 psi - okay 05:00 - 08:30 3.50 CASE OTHR LNR1 PU/MU seal assembly and RTTS, and RIH to 6,980'. 08:30 - 09:30 1.00 CASE OTHR LNR1 Set RTTS at 6,980' and test annulus above RTTS. Leaking bypass. Unseat pkr and reset. Press. test to 3,500 psi - okay 12:00 - 14:30 2.50 CASE OTHR LNR1 Stab into liner tieback and set down 40K. Press. liner down DP to 3,500psi for 15 min. - okay. Bleed off, unsting. Set down 70K, setting pkr at 55K. PU to 20K down and retest liner lap and annulus to 3,200psi - okay. Unsting from tieback, and close RAMs. Pressure casing to 3,500 psi, leaking off 150 psi in 20 min., repressure and repeat bleed-off. Sting into tieback and pressure up DP/liner to 1000 psi due to RTTS pressure limitations. Trap pressure. Pressure up Printed: 5/1/2001 10:31:39 AM BP EXPLORATION Page 7 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/22/2001 12:00 - 14:30 2.50 CASE OTHR LNR1 annulus/liner lap to 3,500 psi - okay. Held for 30 min. - okay. 14:30 - 15:00 0.50 CASE OTHR LNR1 Bleed off all pressure, pump slug. 15:00- 17:30 2.50 CASE OTHR LNR1 POOH to 6,798' 17:30 - 19:00 1.50 CASE LNR1 Cut and slip 92', clean under drwks. 19:00 - 22:30 3.50 CASE LNR1 POOH and LD RTTS and seal assembly. 22:30 - 23:30 1.00 PERF COMP Clear rig floor and clean, prep for Perf. 23:30 - 00:00 0.50 PERF COMP Pick up perf running tools, RU to run guns. Held PJSM with new crew. 4/23/2001 00:00 - 04:00 4.00' PERF COMP PU, and RIH with 2", 4 SPF TCP guns, 1-1/4" spacing tubing, upper section of 2" TCP guns and 2-1/16" DP to 2,770'. Change to 2-7/8" elevators. 04:00 - 09:30 5.50 PERF COMP RIH to 14,638' (tag landing collar). 09:30 - 10:30 1.00 PERF COMP Pressured up guns to 3,000 psi and fired top and bottom gun sections. Perforated 4 SPF: 11,900'-12,140', 12,165'-12,205", 12,245'-13,190', 14,269-14,637'. 10:30 - 11:30 1.00 PERF COMP POH to 11,803'. 11:30 - 12:00 0.50 PERF COMP Monitor well (seepage loss avg.= 4 bblhr). 12:00 - 15:30 3.50 PERF COMP POOH, LD 4" DP to 7,968'. 15:30 - 20:00 4.50 PERF COMP RU 2-7/8" tools, POOH to 3,239', and LD DP. 20:00 - 00:00 4.00 PERF COMP RU tools to LD 2-1/16" DP and 2" TCP guns. Held PJSM, POOH. 4/24/2001 00:00 - 04:00 4.00 PERF COMP Hold PJSM, cont. LD TCP guns, 1-1/4" spaces DP, and lower gun section. ALL SHOTS FIRED. 04:00 - 05:00 1.00 RUNCOIt COMP Clear floor. Change elev. to 4". 05:00 - 06:00 1.00 RUNCO~ COMP RIH w/4" DP 06:00 - 07:30 1.50 RUNCOI~ COMP POH, LD 4" DP. 07:30 - 09:00 1.50 RUNCOI~ COMP Cut & slip drill line, service Top Drive, adj. brakes. 09:00 - 09:30 0.50 RUNCOr~ COMP Fin. LD 4" DP. 09:30 - 10:30 1.00 RUNCOr~ COMP Pull WB. 10:30 - 17:30 7.00 RUNCOr~ COMP Run cmpl assembly, 3-1/2", 9.2 lb/fi, L-80, NSCT tbg to 4,731'. 17:30 - 18:00 0.50 RUNCOr~ COMP CO tbg handling tools to 4-1/2", continue in hole to 10,425'. 4/25/2001 00:00 - 03:30 3.50 RUNCOr~ COMP Continue RIH w/4-1/2" 12.6 #/fi, L-80, NSCT tbg, and tag up top of liner hngr at 11,518'. Space out and land hngr. 03:30 - 04:00 0.50 RUNCOI~ COMP Tighten Iockdowns and test hanger. 04:00 - 09:30 5.50 RUNCOI~ COMP Circulate clean brine and corrosion inhibitor into well. 09:30 - 10:00 0.50 RUNCOI~ COMP Drop ball and rod, and back out landing joint. 10:00 - 12:00 2.00 RUNCOI~ COMP RU and pressure up on tbg to 4,500 psi to set Baker SABL-3, 5~1/2" x 3-1/2" production pkr at 11456' MD. Bleed back to 4,000 psi and hold for 30 min, pressure bleed down to 3400 psi, csg pressure increased fl 500 to 850 psi; bled pressure off to 0 psi 12:00 - 15:00 3.00 RUNCOr~ 'COMP Pressured up to 2000 psi on tbg, Press. test annulus to 4,000 psi and hold for 30 min.- no test. Communcation between annulus and tbg, bleed off press. Check surface equip. - okay. Press. up annulus to 3,700 psi, sheared RP shear valve. Volume(Pressure) test Csg / tbg to 4000 psi for 30 min, Held, no bleed off 15:00 - 22:30 7.50 RUNCOr~ICTUB COMP PJSM, RU slickline unit, RIH and set catcher at 3,300'. POH/IH and retreive RP at 2,990'. RIH and set new RP Shear valve at 2,990'. POH, RIH and retry, catcher. 22:30 - 23:00 0.50 RUNCOr~ICTUB COMP Press. tbg to 4000. In 20 min., had steady decrease in tbg press, to 3,700 psi, increase in ann. press, to 350 psi. Bleed off press. '23:00 - 00:00 1.00 RUNCOI~ICTUB COMP PU, RU lubricator, hold PJSM. 4/26/2001 '00:00 - 01:30 1.50 RUNCOI~CTUB COMP Test annulus to 1,000 psi - okay. Test tbg to 4,000 psi - same bleed down pattern as before. 01:30 - 04:30 3.00 RUNCOI~ICTUB COMP PU/RIH w/stop catcher on slickline and set at 3,300'. POOH/RIH w/ kickoff tool, and retreive RP valve. POOH/RIH with dummy valve and Printed: 5/1/2001 10:31:39AM BP EXPLORATION Page 8 of 9 Operations Summa Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/26/2001 01:30 - 04:30 3.00 RUNCOI~CTUB COMP set in top GLM. POOH and RIH w/catcher sub. 04:30 - 07:00 2.50 RUNCOI~CTUB COMP Test tbg to 4000 psi for 10 min., lost 200 ps - no test. 07:00 - 09:30 2.50 RUNCOI~CTUB COMP Install lubricator and RU slickline. 09:30 - 12:00 2.50 RUNCOr~CTUB COMP PJSM, RIH w/stop catcher on slickline to 11,460' wire. .12:00 - 13:00 1.00 RUNCOr~CTUB COMP POOH w/slickline. RD lubricator. ~13:00- 14:00 1.00 RUNCOI~CTUB COMP RU/MU Landing joint. 14:00 - 16:30 2.50 RUNCOI~CTUB COMP Press. to tbg to 4,000 psi, lost 225 psi, 15 min. Bleed off press, tighten lock down studs on tbg hngr. Press. up tbg to 1,500 psi, and test annulus to 4,000 psi, monitor for 30 rain - lost 100 psi - okay. Press. up annulus to 1,500 psi, and test annulus to 4,000 psi, monitor well for 30 min, lost 350 psi - okay. LD Landing joint. 16:30 - 20:30 4.00 RUNCOI~CTUB COMP RU slickline unit, RIH and pull dummy valve from top GLM at 2991'. RIH and set RP shear. POOH, RP had not set. Consult w/Prod. Dept., okayed to leave out RP. Left Stop Catcher in hole at X" nipple @ 11,480' md. 20:30 - 21:00 0.50 RUNCOI~ COMP Set TVVC, and test to 2,500 psi from below - okay. 21:00 - 00:00 3.00 RUNCOI~ COMP ND BOP stack/NU adaptor flange and tree. 4/27/2001 00:00 - 01:00 1.00 WHSUR COMP Continue to NU tree. Press. test to 5,000 psi - okay. 01:00 - 01:30 0.50 WHSUR COMP RU lubricator to pull TWC. 01:30 - 04:00 2.50 WHSUR COMP RU Hot Oil service, pump 92 bbls diesel, at 2.5 bpm. U-tube well with final btm of freeze protect at 2,200'. 04:00 - 04:30 0.50 WHSUR COMP Set BPV. Press. test to 2,500 psi - okay. 04:30 - 05:00 0.50 WHSUR COMP Remove, second Annular valve. RIG RELEASED: 05:00 hrs, April 27, 2001. Printed: 5/1/2001 10:31:39AM BP EXPLORATION Page 9 of 9 Operations Surnma Report Legal Well Name: 16-23 Common Well Name: 16-23A Spud Date: 4/3/2001 Event Name: REENTER+COMPLETE Start: 3/31/2001 End: 4/27/2001 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/2/2001 16:30 - 18:00 1.50 DECOMP ~ Test Rams to 250~5000 and Annular to 3500 psi - all ok. 4/22/2001 09:30 - 12:00 2.50 OTHR LNR1 ; Release pkr and cont. in hole to 11,518'. Printed: 5/1/2001 10:31:39AM 27-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE SURVEYS Re: Distribution of Survey Data for Well 16-23A ?._ol- Of, ~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,785.12' MD 'MD 14,713.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED I,'iAY 0 1 2001 Aiadm Oil & Gas Cons. DEFiNiTIVE North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 16, Slot ~ 6-23 16-23A MWD Job No. AKMMlO099, Surveyed: f9 April, 200~ SURVEY REPORT 27 April, 2001 Your Reft API-500292205001 Surface Coordinates: 5929327.86 N, 72003~.30 E (70° ~2' 33.6665" N, Kelly Bushing: 65.85ft above Mean Sea Level 148° 13' 32.2360" W) DRILLING SERVICES Survey Reft sVYl0804 A Halliburton Company North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 16-23A MWD Your Ref: API-500292205001 Job No. AKMMlO099, Surveyed: 19 April, 2001 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 12785.12 89.350 264.730 9003.03 9068.88 12818.46 89.110 270.180 9003.48 9069.33 12848.25 84.490 273.280 9005.14 9070.99 12877.91 81.790 276.860 9008.68 9074.53 12914.42 86.340 278.970 9012.46 9078.31 12941.19 91.690 277.150 9012.92 9078.77 12971.31 94.250 276.440 9011.36 9077.21 13007.18 94.490 276.520 9008.62 9074.47 13034.98 92.340 278.700 9006.97 9072.82 13067.35 90.830 282.450 9006.07 9071.92 9006.28 9007.13 9007.26 9006.21 ' 9003.34 13096.58 88.370 287.100 13127.77 88.490 289.540 13161.37 91.050 286.910 13194.46 92.620 286.600 13253.39 92.950 289.770 9072.13 9072.98 9073.11 9072.06 9069.19 13297.11 93.050 287.510 9001.05 9066.90 13345.83 92.340 287.820 8998.76 9064.61 13389.13 91.140 288.630 8997.45 9063.30 13438.27 91.020 287.930 8996.52 9062.37 13506.11 90.710 294.900 8995.50 9061.35 13531.78 90.950 289.060 8995.12 9060.97 13577.75 91.420 288.110 8994.17 9060.02 13627.59 92.430 292.000 8992.50 9058.35 13720.67 93.600 285.900 8987.60 9053.45 13757.58 94.210 303.530 8985.06 9050.91 13811.62 92.400 287.470 8981.93 9047.78 13865.33 90.430 287.710 8980.60 9046.45 13907.96 88.090 289.020 8981.15 9047.00 14002.20 86.210 283.440 8985.84 9051.69 14092.08 87.630 288.130 8990.67 9056.52 5514.52 S 2555.64 E 5923890.15 N 722746.53 E 5516.00 S 2522.35 E 5923887.70 N 722713.30 E 5515.10 S 2492.63 E 5923887.73 N 722683.57 E 5512.50 S 2463.31E 5923889.47 N 722654.18 E 5507.50 S 2427.35 E 5923893.42 N 722618.09 E 5503.75 S 2400.86 E 5923896.40 N 722591.50 E 5500.19 S 2371.00 E 5923899.09 N 722561.55 E 5496.15 S 2335.46 E 5923902.09 N 722525.91E 5492.48 S 2307.96 E 5923904.96 N 722498.31 E 5486.54 S 2276.15 E 5923909.97 N 722466.35 E 5479.09 S 2247.90 E 5923916.59 N 722437.89 E 5469.29 S 2218.31 E 5923925.52 N 722408.02 E 5458.78 S 2186.40 E 5923935.10 N 722375.82 E 5449.25 S 2154.73 E 5923943.70 N 722343.89 E 5430.88 S 2098.82 E 5923960.43 N 722287.46 E · 5416.93 S 2057.45 E 5923973.18 N 722245.71E 5402.16 S 2011.08 E 5923986.59 N 722198.92 E 5388.63 S 1969.97 E 5923998.92 N 722157.44E 5373.22 S 1923,32 E 5924012.96 N 722110.36 E 5348.46 S 1860.21 E 5924035.87 N 722046.55 E 5338.86 S 1836.42 E 5924044.77 N 722022.49 E 5324.21S 1792.85 E 5924058.14 N 721978.52E 5307.14 S 1746.07 E 5924073.85 N 721931.26 E 5276.96 S 1658.20 E 5924101.45 N 721842.55 E 5261.63 S 1624.88 E 5924115.81N 721808.80 E 5238.49 S 1576.35 E 5924137.53 N 721759.61E 5222.26 S 1525.17 E 5924152.25 N 721707.98 E 5208.83 S 1484.72 E 5924164.50 N 721667.15 E 5182.53 S 1394.38 E 5924188.15 N 721576.09 E 5158.13 S 1308.05 E 5924210.04 N 721489.08 E Alaska Drilling & Wells PBU EOADS 16 Dogleg Rate (°/100ft) Vertical Section Comment -3535.07 16.36 -3502.63 18.67 -3473.26 15.05 -3443.97 13.72 -3407.71 Tie On Point 21.11 -3380.98 8.82 -3350.97 0.71 -3315.30 11.00 -3287.60 12.48 -3255.25 18.00 -3226.10 7.83 -3195.20 10.92 -3161.90 4.84 -3129.01 5.40 -3070.66 5.17 -3027.42 1.59 -2979.11 3.34 -2936.21 1.45 -2887.50 10.28 -2820.90 22.77 -2795.74 2.31 -2750.21 8.06 -2701.07 6.66 -2609.13 47.68 -2573.54 29.86 -2521.55 3.69 -2468.25 6.29 -2426.01 6.24 -2332.36 5.44 -2242.99 27 April, 2001 - 8:45 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23A MWD Your Reft API.500292205001 Job No. AKMMlO099, Surveyed: 19 April, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 14185.30 88.580 281.810 8993.76 9059.61 5134.07 S 1218.09 E 5924231.46 N 721398.46 E 14277.54 87.140 279.050 8997.20 9063.05 5117.39 S 1127.44 E 5924245.50 N 721307.37 E 14370.06 89.020 283.730 9000.31 9066.16 5099.13 S 1036.83 E 5924261.11 N 721216.26 E 14463.00 88.280 285.620 9002.50 9068.35 5075.59 S 946.95 E 5924282.01 N 721125.73 E 14557.84 90.090 290.210 9003.85 9069.70 5046.43 S 856.74 E 5924308.54N 721034.72 E 14648.80 88.400 285.560 9005.04 9070.89 5018.51 S 770.21 E 5924333.93 N 720947.41 E 14671.06 88.340 284.390 9005.68 9071.53 5012.76 S 748.72 E 5924339.05 N 720925.76 E 14713.00 88.340 284.390 9006.89 9072.74 5002.34 S 708.11 E 5924348.28 N 720884.86 E All data is in Feet 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. Magnetic Declination at Surface is 26.923° (23-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 280.700° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14713.00ft., ~The Bottom Hole Displacement is 5052.21ft., in the Direction of 171.943° (True). Dogleg Rate (°/lOOrt) 6.85 3.37 5.45 2.18 5.20 5.44 5.26 0.00 Alaska Drilling & Wells PBU EOA DS 16 Vertical Section Comment -2150.13 -2057.97 -1965.54 -1872.85 -1778.80 -1688.59 -1666.40 -1624.57 Projected Survey 27 April, 2001. 8:45 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23A MWD Your Ref: API.500292205001 Job No. AKMMlO099, Surveyed: 19 April, 2001 North Slope Alaska Alaska Drilling & Wells PBU EOADS 16 Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (rt) (ft) (ft) 12785.12 9068.88 5514.52 S 2555.64 E 14713.00 9072.74 5002.34 S 708.11 E Comment Tie On Point Projected Survey Survey tool program for 16-23A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 11695.51 8978.79 11695.51 8978.79 14713.00 9072.74 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (16-23) MWD Magnetic (16-23APB1 MWD) 27 April, 200t - 8:45 Page 4 of 4 DrillQuest 2.00.08.005 North Slope Alaska Alaska Drilling & Wells PBU EOA DS ~6, Slot ~6-23 ~6-23A Job No. AKZZlO124, Surveyed: 19 April, 2001 DEFIN TIVF-- S UR VEY REPORT 27 April, 2001 Your Reft API.500292205001 Surface Coordinates: 5929327.86 N, 72003~.30 E (70° ~2' 33.6665" N, f48° 13' 32.2360" Vi/) Kelly Bushing: 65.85ft above Mean Sea Level DRILLING SERVICES A Halliburton Company Survey Ref: svyl0802 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 12785.12 89.350 263.820 9003.02 9068.87 12818.46 89.110 270.280 9003.47 9069.32 12848.25 84.490 273.180 9005.13 9070.98 12877.91 81.790 278.190 9008.68 9074.53 12914.42 86.340 279.640 9012.45 9078.30 12941.19 91.690 279.420 9012.91 9078.76 12971.31 94.250 280.670 9011.35 9077.20 13007.18 94.490 279.120 9008.62 9074.47 13034.98 92.340 282.300 9006.96 9072.81 13067.35 90.830 284.020 9006.07 9071.92 13096.58 88.370 288.570 9006.27 9072.12 ~3127.77 88.490 290.000 9007.12 9072.97 13161.37 91.050 294.000 9007.26 9073.11 13194.46 92.620 296.180 9006.20 9072.05 13253.39 92.950 295.170 9003.34 9069.19 9001.05 8998.76 8997.44 8996.52 8995.49 13297.11 93.050 295.640 13345.83 92.340 296.470 13389.13 91.140 297.000 13438.27 91.020 297.450 13506.11 90.710 296.810 9066.90 9064.61 9063.29 9062.37 9061.34 13531.78 90.950 297.400 8995.12 9060.97 13577.75 91.420 292.150 8994.17 9060.02 13627.59 92.430 292.200 8992.49 9058.34 13720.67 93.600 296.040 8987.60 9053.45 13757.58 94.210 298.220 8985.08 9050.93 13811.62 92.400 297.750 8981.97 9047.82 13865.33 90.430 299.830 8980.64 9046.49 13907.96 88.090 298.510 8981.19 9047.04 14002.20 86.210 297.320 8985.88 9051.73 14092.08 87.630 289.840 8990.71 9056.56 Sperry-Sun Drilling Services Survey Report for 16-23A Your Ref: API-500292205001 Job No. AKZZI0124, Surveyed: 19 April, 2001 Alaska 'Drilling & Wells PBU EOADS 16 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (rt) (rt) 5497.51S 2544.53 E 5923906.83 N 722734.93 E 5499.22 S 2511.25 E 5923904.14 N 722701.71 E 5498.33 S 2481.53 E 5923904.17 N 722671.98 E 5495.41S 2452.24 E 5923906.23 N 722642.62 E 5489.79 S 2416.38 E 5923910.81 N 722606.61 E 5485.36 S 2389.99 E 5923914.47 N 722580.10 E 5480.11S 2360.37 E 5923918.85 N 722550.34E 5473.97 S 2325.14 E 5923923.97 N 722514.95 E 5468.81S 2297.88 E 5923928.33 N 722487.55 E 5461.44 S 2266.37 E 5923934.77 N 722455.84 E 5453.24 S 2238.33 E 5923942.15 N 722427.57 E 5442.95 S 2208.90 E 5923951.58 N 722397.85 E 5430.36 S 2177.76 E 5923963.25 N 722366.35 E 5416.34 S 2147.81E 5923976.40 N 722336.01E 5390.84 S 2094.76 E 5924000.34 N 722282.24 E 5372.11S 2055.32 E 5924017.92 N 722242.27 E 5350.73 S 2011.60 E 5924038.01 N 722197.95 E 5331.26 S 1972.95 E 5924056.35 N 722158.75 E 5308.79 S 1929.26 E 5924077.54 N 722114.42 E 5277.85 S 1868.89 E 5924106.70 N 722053.18 E 5266.16 S 1846.04 E 5924117.72 N 722030.00 E 5246.91S 1804.33 E 5924135.75 N 721987.74 E 5228.11 S 1758.20 E 5924153.20 N 721941.08 E 5190.13 S 1673.38 E 5924188.69 N 721855.20 E 5173.34 S 1640.61 E 5924204.52 N 721821.95 E 5148.02 S 1592.97 E 5924228.43 N 721773.59 E 5122.17 S 1545.92 E 5924252.91 N 721725.81 E 5101.39 S 1508.70 E 5924272.59 N 721688.00 E 5057.33 S 1425.54 E 5924314.21N 721603.59 E 5021.46 S 1343.34 E 5924347.67 N 721520.38 E Dogleg Rate (°/'~00ft) 19.39 18.30 19.08 13.07 20.00 9.46 4.36 13.79 7.07 17.69 4.6O 14.13 8.12 1.80 1.10 2.24 3.03 0.95 1.05 2.48 11.46 2.03 4.31 6.12 3.46 5.33 6.30 2.36 8.46 Vertical Section Comment -2621.04 -2587.79 -2558.06 -2528.73 -2492.79 -2466.35 -2436.66 -2401.34 -2374.01 -2342.41 -2314.25 -2284.68 -2253.36 -2223.22 -2169.82 -2130.13 -2086.11 -2047.19 -2003.20 -1942.40 -1919.39 -1877.41 -1831.03 -1745.69 -1712.68 -1664.69 -1617.29 -1579.78 -1496.01 -1413.32 Tie On Point 27 April, 2001 - 8:~4 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for f 6-23A Your Ref: API-500292205001 Job No. AKZZ`/Of24, Surveyed: `/9 April, 200'/ North Slope Alaska Measured Depth (ft) 14185.30 14277.54 14370.06 14463.00 14557.84 Sub-Sea Vertical Local Coordinates Global Coordinates Incl. Azim. Depth Depth Northings Eastings Northings Eastings (fi) (fi) (fi) (fi) (fi) (fi) 88.580 283.080 8993.80 9059.65 4995.08 S 1254.04 E 5924371.44 N 721430.35 E 87.140 281.780 8997.24 9063.09 4975.24 S 1164.03 E 5924388.65 N 721339.80 E 89.020 287.320 9000.35 9066.20 4952.01 S 1074.57 E 5924409.26 N 721249.70 E 88.280 287.380 9002.54 9068.39 4924.31S 985.88 E 5924434.37 N 721160.24 E 90.090 290.510 9003.88 9069.73 4893.52 S 896.20 E 5924462.53 N 721069.70 E 14648.80 88.400 290.570 9005.08 9070.93 4861.61S 811.04 E 5924491.94 N 720983.64E 14671.06 88.340 290.460 9005.72 9071.57 4853.81 S 790.20 E 5924499.13 N 720962.59 E 14713.00 88.340 290.460 9006.93 9072.78 4839.16 S 750.92 E 5924512.63 N 720922.90 E All data is in Feet 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. Magnetic Declination at Surface is 26.923° (23-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vedical Section is from Well Reference and calculated along an Azimuth of 270.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14713.00ft., The Bottom Hole Displacement is 4897.08ff., in the Direction of 171.179° (True). Dogleg Rate (°/~OOrt) 7.32 2.10 6.32 0.80 3.81 1.86 0.56 0.00 Alaska Drilling & Wells PBU EOADS16 Vertical Section Comment -1323.66 -1233.38 -1143.61 -1054.54 -964.44 -878.84 -857.89 -818.41 Projected Survey DrillQuest 2.00.08.005 27 April, 200'1 - 8:'14 Page 3 of 4 Sperry-Sun Drilling Services Survey Report for 16-23A Your Reft API-500292205001 Job No. AKZZ10124, Surveyed: 19 April, 2001 North Slope Alaska Alaska Drilling & Wells PBU EOA DS 16 r Comments Measured Depth (ft) 12785.12 14713.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9068.87 5497.51 S 2544.53 E 9072.78 4839.16 S 750.92 E Comment Tie On Point Projected Survey Survey tool program for 16-23A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (fi) (ft) (ft) (ft) 0.00 0.00 11695.51 8978.79 11695.51 8978.79 14713.00 9072.78 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (16-23) AK-6 BP_IFR-AK (16-23APB1) 27 April, 200~ - 8:~4 Page 4 of 4 DrillQuest 2.00.08.005 27-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 16-23APB1MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,695.51'MD Window / Kickoff Survey: 11,727.00' MD Projected Survey: 12,997.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED PlAY 0 1 2001 NaC, a Oil & 6~ C(~s. Coaai~aon Anchorage DEFJNJT VE North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~ 6, Slot ~ 6-23 16-23APB 1 MWD Job No. AKMMlO099, Surveyed: 14 April, 2001 SURVEY REPORT 27 April, 2001 Your Ref: API-500292205070 Surface Coordinates: 5929327.86 N, 720031.30 E (70° 12' 33.6665" N, Kelly Bushing: 65.85ft above Mean Sea Level 148° 13' 32.2360" Vi/) DRILLING SERVICES Survey Reft svyf0803 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 16-23APB1 MWD Your Ref: API-500292205070 Job No. AKMM10099, Surveyed: 14 April, 2001 DEFINITIVE North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11695.51 48.570 150.250 8912.94 8978.79 11727.00 48.410 150.580 8933.81 8999.66 11732.72 48.860 151.550 8937.59 9003.44 11763.14 55.670 156.300 8956.20 9022.05 11796.01 63.880 160.730 8972.74 9038.59 11826.77 70.040 164.420 8984.78 9050.63 11858.87 79.240 167.940 8993.27 9059.12 11885.89 82.620 170.720 8997.53 9063.38 11920.41 86.110 174.150 9000.92 9066.77 11951.04 92.960 176.720 9001.17 9067.02 11981.35 95.810 183.200 8998.85 9064.70 12015.39 ' 92.620 190.300 8996.35 9062.20 12045.64 88.370 199.480 8996.08 9061.93 12073.58 84.390 205.500 8997.85 9083.70 12107.39 82.200 219.260 9001.82 9067.67 12138.05 81.970 226.010 9006.04 9071.89 12166.93 87.880 233.740 9008.60 9074.45 12193.59 84.030 242.990 9010.48 9076.33 12227.48 88.890 250.500 9012.58 9078.43 12261.64 93.820 250.370 9011.77 9077.62 12291.99 94.430 250.340 9009.59 9075.44 12319,13 94,060 250.230 9007.58 9073.43 12350.22 94.030 249.930 9005.39 9071.24 12379,85 90.220 241.480 9004.29 9070.14 12411.05 86.800 237.440 9005.10 9070.95 12441.76 86.030 237.990 9007.02 9072.87 12476.94 86.950 238.570 9009.17 9075.02 12503.46 88.770 240.560 9010.16 9076.01 12541.23 91.630 243.780 9010.03 9075.88 12571.58 93.350 246.500 9008.71 9074.56 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4869.75 S 3141.69 E 5924551.72 N 4890.25 S 3153.33 E 5924531.56 N 4894.01S 3155.41E 5924527.87 N 4915.62 S 3165.93 E 5924506.58 N 4942.03 S 3176.28 E 5924480.48 N 4969.02 S 3184.73 E 5924453.74 N 4999.05 S 3192.09 E 5924423.94 N 5025.26 S 3197.03 E 5924397.88 N 5059.31S 3201.55 E 5924363.98 N 5089.82 S 3203.98 E 5924333.56 N 5120.02 S 3204.01E 5924303.37 N 5153.70 S 3200.02 E 5924269.58 N 5182.90 S 3192.25 E 5924240.17 N 5208.65 S 3181.60 E 5924214.12 N 5236.94 S 3163.67 E 5924185.32 N 5259.27 S 3143.11 E 5924162.41 N 5277.78 S 3121.14 E 5924143.26 N 5291.71S 3098.52 E 5924128.68 N 5305.05 S 3067.48 E 5924114.44N 5316.48 S 3035.31 E 5924102.08 N 5326.66 S 3006.80 E 5924091.07 N 5335.79 S 2981.32 E 5924081.20 N 5346.35 S 2952.16 E 5924069.79 N 5358.52 S 2925.21 E 5924056.84N 5374.37 S 2898.35 E 5924040.22 N 5390.74 S 2872.44 E 5924023.10 N 5409.20 S 2842.57 E 5924003.78 N 5422.62 S 2819.73 E 5923989.70 N 5440.25 S 2786.33 E 5923971.10 N 5453.00 S 2758.82 E 5923957.56 N 723313.54E 723325.78 E 723327.96E 723339.11E 723350.22 E 723359.46 E 723367.69 E 723373.39 E 723378.90 E 723382.22 E 723383.13 E 723380.12 E 723373.21E 723363.31E 723346.21E 723326.31E 723304.89 E 723282.69 E 723252.05 E 723220.22 E 723192.02 E 723166.82 E 723137.98 E 723111.39 E 723085.01E 723O59.59 E 723030.27 E 723007.82 E 722974.96 E 722947.83 E Dogleg Rate (°ll00ft) 0.93 14.96 25.56 27.55 22.86 30.54 16.11 14.14 23.88 23.30 22.81 33.43 25.79 40.93 21.82 33.60 37.50 26.35 14.44 2.01 1.42 0.97 31.26 16.96 3.08 3.09 10.16 11.40 10.60 Alaska Drilling & Wells PBU EOA DS 16 Vertical Section Comment -3209.38 -3221.30 -3223.43 -3234.26 -3244.97 -3253.80 -3261.58 -3266.88 -3271.87 -3274.74 -3275.18 -3271.66 -3264.31 -3254.01 -3236.48 -3216.23 -3194.52 -3172.11 -3141.25 -3109.24 -3080.88 -3055.53 -3026.52 -2999.74 -2973.11 -2947.43 -2917.82 -2895.16 -2862.02 -2834.69 Tie On Point MWD Magnetic Window Point 27 April, 2001 - 8:45 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23APB1 MWD Your Ref: API-500292205070 Job No. AKMMlO099, Surveyed: 14 April, 2001 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) (ft) Global Coordinates 12600.42 94.800 247.060 9006.66 9072.51 5464.34 S 2732.39 E 5923945.45 N 12634.64 93.660 250.020 9004.14 9069.99 5476.82 S 2700.63 E 5923932.05 N 12664.31 91.570 253.580 9002.78 9068.63 5486.08 S 2672.48 E 5923921.98 N 12689.47 91.260 248.690 9002.16 9068.01 5494.21 S 2648.69 E 5923913.16 N 12724.77 89.350 254.690 9001.97 9067.82 5505.29 S 2615.19 E 5923901.10 N 12753.97 88.650 262.510 9002.48 9068.33 5511.06 S 2586.59 E 5923894.51 N 12785.12 89.350 264.730 9003.03 9068.88 5514.52 S 2555.64 E 5923890.15 N 12816.82 91.940 269.510 9002.67 9068.52 5516.11 S 2524.00 E 5923887.63 N 12851.67 95.920 270.460 9000.28 9066.13 5516.12 S 2489.24 E 5923886.61 N 12879.35 99.140 271.050 8996.66 9062.51 5515.76 S 2461.80 E 5923886.17 N Eastings (ft) 722921.74 E 722890.36 E 722862.49 E 722838.94 E 722805.79 E 722777.37 E 722746.53 E 722714.95 E 722680.20 E 722652.77 E 12909.45 102.020 272.590 8991.13 9056.98 5514.82 S 2432.23 E 5923886.25 N 12941.16 104.300 277.310 8983.91 9049.76 5512.16 S 2401.48 E 5923888.01 N 12997.00 104.300 277.310 8970.11 9035.96 5505.28 S 2347.81 E 5923893.33 N 722623.18 E 722592.37 E 722538.52 E All data is in Feet 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. Magnetic Declination at Surface is 26.923° (23-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 270.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12997.00ft., The Bottom Hole Displacement is 5985.01ft., in the Direction of 156.903° (True). Dogleg Rate (°/100ft) 5.39 9.25 13.90 19.47 17.84 26.88 7.47 17.15 11.74 11.82 10.81 16.18 0.00 Alaska Drilling & Wells PBU EOADS16 Vertical Section Comment -2808.42 -2776.84 -2748.82 -2725.14 -2691.80 -2663.29 -2632.39 -2600.77 -2566.01 -2538.57 -2508.99 -2478.21 -2424.45 Projected Survey 27 April, 2001 - 8:45 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23APB1 MWD Your Reft API-500292205070 Job No. AKMMlO099, Surveyed: 14 April, 2001 North Slope Alaska Alaska Drilling & Wells PBU EOADS 16 Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11695.51 8978.79 4869.75 S 3141.69 E 11727.00 8999.66 4890.25 S 3153.33 E 12997.00 9035.96 5505.28 S 2347.81E Comment Tie On Point Window Point Projected Survey Survey tool program for 16-23APBI MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 11695.51 8978.79 11695.51 8978.79 12997.00 9035.96 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (16-23) MWD Magnetic (16-23APB1 MWD) _ 27 April, 2001 - 8:45 Page 4 of 4 DrillQuest 2.00.08.005 DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~ 6, Slot ~ 6-23 16-23APB1 Job No. AKZZI0124, Surveyed: 14 April, 2001 SURVEY REPORT 27 April, 2001 Your Reft API-500292205070 Surface Coordinates: 5929327.86 N, 720031.30 E (70° 12'33.6665"N, Kelly Bushing: 65.85ft above Mean Sea Level 148° 13' 32.2360"W) DRILLING SERVICES · Survey Ref: svyl0801 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 16-23APB1 Your Ref: API.500292205070 Job No. AKZZ10124, Surveyed: 14 April, 2001 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11695.51 48.570 150.250 8912.94 8978.79 11727.00 48.410 150.580 8933.81 8999.66 11732.72 48.860 151.550 8937.59 9003.44 11763,14 55.670 156.300 8956.20 9022.05 11796.01 63.880 160.730 8972.74 9038.59 11826.77 70.040 164.420 8984.78 9050.63 11858.87 79.240 167.940 8993.27 9059.12 11885.89 82.620 170.720 8997.53 9063.38 11920.41 86.110 174.150 9000.92 9066.77 11951.04 92.960 176.300 9001.17 9067.02 11981.35 95.810 184.990 8998.85 9064.70 12015.39 92,620 192.950 8996.34 9062.19 12045.64 88.370 201.720 8996.08 9061.93 12073.58 84.390 208.410 8997.85 9063.70 12107.39 82.200 220.020 9001.81 9067.66 12138.05 81.970 227.130 9006.03 9071.88 12166.93 87.880 234.920 9008.59 9074.44 12193.59 84.030 242.670 9010.48 9076.33 12227.48 88.890 250.150 9012.57 9078.42 12261.64 93.820 249.940 9011.76 9077.61 12291.99 94.430 250.180 9009.58 9075.43 12319.13 94.060 250.360 9007.57 9073.42 12350.22 94.030 249.740 9005.38 9071.23 12379.85 90.220 245.550 9004.28 9070.13 12411.05 86.800 238.780 9005.09 9070.94 12441.76 86,030 237.800 9007.01 9072.86 12476.94 86.950 240.330 9009.17 9075.02 12503.46 88.770 242.510 9010.16 9076.01 12541.23 91.630 244.570 9010.02 9075.87 12571.58 93.350 248.530 9008.70 9074.55 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4869.75 S 3141.69 E 5924551.72 N 723313.54E 4890.25 S 3153.33 E 5924531.56 N 723325.78 E 4894.01S 3155.41 E 5924527.87 N 723327.96 E 4915.62 S 3165.93 E 5924506.58 N 723339.11 E 4942.03 S 3176.28 E 5924480.48 N 723350.22 E 4969.02 S 3184.73 E 5924453.74 N 723359.46 E 4999.05 S 3192.09 E 5924423.94N 723367.69 E 5025,26 S 3197.03 E 5924397.88 N 723373.39 E 5059.31S 3201.55 E 5924363.98 N 723378.90 E 5089.81S 3204.09 E 5924333.57 N 723382.33 E 5120.00 S 3203.76 E 5924303.38 N 723382.88 E 5153.50 S 3198.47 E 5924269.74 N 723378.56 E 5182.34 S 3189.46 E 5924240.65 N 723370.41 E 5207.58 S 3177.66 E 5924215.08 N 723359.34E 5235.30 S 3158.82 E 5924186.82 N 723341.32 E 5257.28 S 3137.90 E 5924164.24 N 723321.05 E 5275.35 S 3115.56 E 5924145.53 N 723299.24 E 5289.12 S 3092.84 E 5924131.10 N 723276.93 E 5302.63 S 3061.87 E 5924116.69 N 723246.37 E 5314.29 S 3029.78 E 5924104.11N 723214.63 E 5324.61S 3001.32 E 5924092.96 N 723186.49 E 5333.75 S 2975.85 E 5924083.08 N 723161.29 E 5344.33 S 2946.70 E 5924071.66 N 723132.46 E 5355.59 S 2919.32 E 5924059.61 N 723105.43 E 5370.14 S 2891.76 E 5924044.26 N 723078.30 E 5386.25 S 2865.69 E 5924027.40 N 723052.7i E 5404.30 S 2835.57 E 5924008.48 N 723023.13 E 5416.97 S 2812.30 E 5923995.13 N 723000.24 E 5433.80 S 2778.49 E 5923977.32 N 722966.94 E 5445.86 S 2750.68 E 5923964.45 N 722939.49 E Dogleg Rate (°/100ft) 0.93 14.96 25.56 27.55 22.86 30.54 16.11 14.14 23.44 30.09 25.13 32.21 27.82 34.71 22.98 33.76 32.39 26.28 14.45 2.16 1.52 1.99 19.10 24.30 4.05 7.64 10.70 9.33 14.21 Alaska Drilling & Wells PBU EOADS 16 Vertical Section Comment -3209.38 -3221.30 -3223.43 -3234.26 -3244.97 -3253.80 -3261.58 -3266.88 -3271.87 -3274.85 -3274.93 -3270.11 -3261.51 -3250.06 -3231.61 -3211.00 -3188.91 -3166.39 -3135.61 -3103.68 -3075.37 -3050.03 -3021.03 -2993.81 -2966.46 -2940.61 -2910.75 -2887.66 -2854.09 -2826.45 Tie On Point AK-6 BP IFR-AK Window Point 27 April, 2001 - 8:f4 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23APB1 Your Ref: API.500292205070 Job No. AKZZ10124, Surveyed: 14 April, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12600.42 94.800 249.050 9006.66 9072.51 5456.27 S 2723.87 E 5923953.27 N 722912.99 E 12634.64 93.660 251.760 9004.13 9069.98 5467.71S 2691.72 E 5923940.89 N 722881.19 E 12664.31 91.570 256.640 9002.78 9068.63 5475.78 S 2663.21 E 5923932.00 N 722852.92 E 12689.47 91.260 255.850 9002.15 9068.00 5481.76 S 2638.78 E 5923925.31 N 722828.68E 12724.77 89.350 259.820 9001.97 9067.82 5489.20 S 2604.28 E 5923916.87 N 722794.41E 12753.97 88.650 262.280 9002.48 9068.33 5493.74 S 2575.44E 5923911.49 N 722765.72 E 12785.12 89.350 263.820 9003.02 9068.87 5497.51S 2544.53 E 5923906.83 N 722734.93 E 12816.82 91.940 268.570 9002.66 9068.51 5499.61S 2512.91 E 5923903.80 N 722703.38 E 12851.67 95.920 269.560 9000.28 9066.13 5500.18 S 2478.15 E 5923902.22 N 722668.66 E 12879.35 99.140 270.350 8996.65 9062.50 5500.20 S 2450.72 E 5923901.40 N 722641.23 E 12909.45 102.020 272.630 8991.12 9056.97 5499.43 S 2421.14 E 5923901.30 N 722611.65 E 12941.16 104.300 276.270 8983.90 9049.75 5497.04 S 2390.37 E 5923902.80 N 722580.82 E 12997.00 104.300 276.270 8970.11 9035.96 5491.13 S 2336.58 E 5923907.14 N 722526.88 E All data is in Feet 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. Magnetic Declination at Surface is 26.923° (23-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 270.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12997.00ft., The Bottom Hole Displacement is 5967.59ft., in the Direction of 156.949° (True). Dogleg Rate (°/lOOft) 5.34 8.57 17.88 3.37 12.48 8.76 5.43 17.07 11.77 11.97 12.12 13.29 0.00 Alaska Drilling & Wells PBU EOADS16 Vertical Section Comment -2799.78 -2767.80 -2739.40 -2715.06 -2680.67 _2651.90 -2621.04 -2589.45 -2554.71 -2527.27 -2497.69 -2466.89 -2413.02 Projected Survey 27 April, 2001 - 8:14 Page 3 of 4 Dr#lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 16-23APB1 Your Ref: API-500292205070 Job No. AKZZlO124, Surveyed: ~4 April, 200~ North Slope Alaska Alaska Drilling & Wells PBU EOA DS 16 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) {ft) 11695.51 8978.79 4869.75 S 3141.69 E 11727.00 8999.66 4890.25 S 3153.33 E 12997.00 9035.96 5491.13 S 2336.58 E Comment Tie On Point Window Point Projected Survey Survey tool program for ~6-23APBI From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 11695.51 8978.79 11695.51 8978.79 12997.00 9035.96 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (16-23) AK-6 BP_IFR-AK (16-23APB1) 27 April, 2001 - 8:~4 Page 4 of 4 DrillQuest Z00.08.005 U~/ZZ/ZUU~ 1U:36 FAX ,qU7 564 4264 BP EXPLORATION bp March 21,2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 t~O01 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED HAR 2 2001 Alaska 0il & Gas Gons. Commission Ancflom(je Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list ~f well work tentatively. sch6duled for March 19 - 26, 2001: Well Work Planned 05-0 lC CTE PERFORATION 05-18A CTE ADD PERFORATION 06-24A CT ACID STIMULATION W/DIVERTER 12-15 SAG HYDRAULIC FRACTURE TREATMENT 13-27A NK-65i CT ADD PERFORATION W/WORK PLATFORM CHEMICAL CUT TUBING (PRE RIG ST) CTE ADD PERFORATION S-101 S-103 ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely, ~ ,e'..~ Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells ~KA 0IL AND GAS CONSERVA~i~ION CO~V~ISSION TONY KNOWLES, GOVERNOR 333 W. 7TM 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, AK 99519-6612 Re: Prudhoe Bay Unit 16-23A BP Exploration (Alaska) Inc. Permit No: 201-054 Sur Loc: 1624'SNL, 1249'EWL, Sec. 24, T10N, R15E, UM Btmhole Loc. 1195'SNL, 2031'EWL, Sec. 25, T10N, R15E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above referenced well. ' The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607'. Sincerely, Commissioner BY ORDER OF THE COM]~ISSION DATED this ~j//~ day of March, 2001 dlf/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,. ALASK/~''' STATE OF ALASKA ~ L AND GAS CONSERVATION COMI~,,.,SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Ddll [] Reddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 65' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028333 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1624' SNL, 1249' EWL, SEC. 24, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1774' SNL, 4351' EWL, SEC. 25, T10N, R15E, UM 16-23A Number 2S100302630-277 At total depth 9. Approximate spud date 1195' SNL, 2031' EWL, SEC. 25, T10N, R15E, UM 03/25/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028332, 1195' MDI No Close Approach 2560 14829' MD / 9059' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11729' MD Maximum Hole Angle 91 o Maximum surface 3030 psig, At total depth (TVD) 8800' / 3910 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stare data) 4-3/4" 3-1/2" 9.2# L-80 MBT 3279' 11550' 8886' 14829' 9059' 235 sx Class 'G' REC. -iVED 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary MAR O '7 Z0Ol Total depth: measured 11995 feet Plugs (measured) true vertical 9178 feet Alaska 0il & Gas Cons. Commission Effective depth: measured 11898 feet Junk (measured) Anchorage true vertical 9114 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 1775# Poleset 110' 110' Surface 3375' 10-3/4" 1000 sx CS III, 300 sx 'G', 155 sx CS 3445' 3444' Intermediate Production Liner 11911' 7-5/8" 260 sx Class 'G' 11981' 9169' Scab Liner 4751' 5-1/2" 290 sx Class 'G' 6849' - 11600' 6091' - 8918' Perforation depth: measured 11790' - 11847' (eight intervals) trUe vertical 9043' - 9081' (eight intervals) 20. Attachments I~!' Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Dril'ling Program ........ [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements I Contact Engineer Name/Number: Phil SCh, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreg~1n.g is true and erect to the best of my knowledge Crane'~~--~~..-~ ~ Senior Drilling Engineer Date ~ "7-" Signed Lowell Permit Number '" ~' I'"APi NL~mbe"r ......... '""'" "' ............ }' ~.~ Approval Date I See cover letter / - ¢, '-/ 150- 029-22050-01 } "~//-.~ ~'7~ ~r ] f(~i, other requirements Conditions of Approval: Samples Required [] Yes [] No Mud/L(~g F~quired [] Yes ~'No .. Hydrogen Sulfide Measures J~ Yes [] No Directional Survey Required J~'Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,,1~3.5K psi.f;~ Approved By D "[ayloi' Se~.~moun~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAL Sul~ Triplicate I Well Name: 116-23A RECEIVED ~AR 0 7 ZOO1 Drill and Complete Plan Summary Alaska 0il & Gas Cons. Commission Anchorage J Type of Well (service / producer / injector): j Side-track Pre-produced injector Surface Location: Target Location: Zone 4B Ivishak Sand Bottom Hole Location: X = 720,031 Y = 5,929,328 1624' FNL 1249' FWL S24T10N R15E Umiat X = 723,294 Y = 5,923,990 TVDss 9001 3504' FSL 4351' FWL S25, T10N, R15E Umiat X = 720,957 Y = 5,924,501 TVDss 8987 4084' FSL 2031' FWL S25, T10N, R15E Umiat J AFE Number: J4J0466 J J Estimated Start Date:J3/25/2001 J I MD: 114829 I I TVD: 19059' J Rig: J Nabors9ES J Operating days to complete: J25.0 I BF/MS= 136.5' I I RKB: 165.0 I Well Design (conventional, slimhole, etc.): I Slimhole I Objective: I Zone 4B, Ivishak Sand Mud Program: 4 3/4" Production 3 1/2" Csg QuikDril-n / 6% NaCI w/ClaySeal Interval Density Visc(~sity YP PV pH APl ' HTHP TD (ppg) (seconds) Filtrate Filtrate 14,829' 8.8-9.0 40-50 20-25 5-8 9.0-9.5 <-10 NC DirectiOnal: KOP: I 11729' MD, Build 22°/100' Maximum Hole Angle: Close Approach Wells' 91° None Logging Program: Production Cased Hole Drilling/LWD: DIR/GR/RES Cement Evaluation' USIT DS16-23A Permit to Drill Page 1 RECEIVED Formation Markers: Alaska Oil & Gas Cons. Commission Formation Tops MDbkb TVDss Comments Anchorage Top Shublik 8917' Top Sag River N/A Sadlerochit 4B 8967' 8/2000 BHSP = 3910 psi @8800' (8.54 EMW) HO/T 9000' - all other recent BHST's in area <8.0 ppg EMW) 4A Casinq/Tubinq Proqram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 4 3A" 3 1/2" 9.2# L-80 MBT 3279' 11,550'/8886 14,829'/9059' Tubing 3 1/2" 9.2# L-80 NSCT 4750' 6800'/6061' 11,550'/8882' Tubing 4 1~,, 12.6# L-80 NSCT 6800' Surf 6800'/6061' Cement Calculations: Casing Size 13-1/2" Production Liner Basis: 3100' open hole annular volume + 30% + liner lap + 200' DP X casing annulus + 85 shoe tract I Total Cement Volume: Lead Tail N/A 49 bbls (275 ft3) class G @ 15.8 ppg & 1.17 Yield: 235 sacks Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: · Planned BOPtest pressure: · Planned completion fluid: 3910 psi @ 8800' TVDss -Ivishak Sands 3030 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 3500 psi (required for casing test) 8.8 ppg brine / 6.8 ppg Diesel DS16-23A Permit to Drill Page 2 RECEIVED MAR 0 ? Z001 Drilling Hazards/Contingencies: Aiaska 0il & Gas Cons. Commission HYDROGEN SULFIDE - H2S Anchorage · DS-16 is designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. · The highest level of H2S recently: · The closest wells to DS16-23: · The closest BHL to planned DS16-23A: 16-13, 307 ppm, Nov-2000. 16-30, 103 ppm, Nov-2000 16-24, 80 ppm, June-1998. 16-26A, 27 ppm, Nov-2000. Due to pad proximity to the Deadhorse airport, special FAA notifications are required prior to the rig moves on and off of DS 16. See the Pad Data Sheet for details. Several incidents of moderate impact stuck pipe and lost circulation have occurred on DS16 in the production interval. Be prepared with the lost circulation decision tree and always adhere to proper drilling practice for hole cleaning. · None DRILLING CLOSE APPROACH: Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. DS16-23A Permit to Drill Page 3 DRILL AND COMPLETE PROCEDURE SUM **DEADHORSE AIRPORT NOTIFICATION REQUIRED, PAl RY SHEET** Pre-Rig Work: 1. RU slickline and drift the tubing, tag TD. Dummy off GLM's as for CTU work. 2. RU CTU, lay carbolite sand to raise top of fill to 11,810' (last tag 1,836'). 3. RU slickline, verify top of sand. 4. Chemical cut the 2-7/8" tubing in the lowermost 10' pup joint the production packer. Attempt to cut in the 1/3 of the pup joint to leave at least a 6' stub for fi 5. Kill the well with seawater. Reverse circulate the annulu with 210 bbls 9.3 ppg NaCI followed by 95 , bbls diesel. Bullhead the tubing with 78 bbls 9.3 ppg protect the well to 2000' and provide an equivalent of last survey) or _+90 psi overbalance. Set a BPV in the tubing hanger and test from Secure the well. Remove wellhouse and preparation cost on the handover form. followed by 17 bbls diesel. This will freeze ppg at the perforations (8.54 ppg SBHP at 1000 psi. Block open TRSSSV. Level the pad and provide the total well Rig Operations: 1. Pull BPV, circulate out freeze protection f d. Set TWC 2. ND tree, NU and test BOPE to 250 psi / 3500 psi high. Pull TWC. 3. Pull and lay down tubing from the chel :al cut at _+11,330'. 4. RU slickline and drift to the top of sa depth with dummy whipstock. 5. Run PDS log across 7 5/8" casing top of fill to base of scab liner. Request a "quick-turnaround" of the log interpretation. 6. RU e-line and set the whi hside to kick off at 11,729' MD. Adjust whipstock orientation with offset weight bars prior to RIH required to avoid setting he slips in corroded casing. 7. RIH with 3-1/2" DP and cer ent nozzle. DO NOT TAG the whipstock. Stop RIH to just above whipstock depth. 8. Circulate 10 bbls cement t end of drill pipe, shut in and bullhead squeeze the cement to cover the perforations and whi :. Hesitate squeeze as necessary. Circulate to dress off op of cement to 11,675' MD (50' above 9. MU 4.8" window millin, assembly and RIH to top of cement. Test 7" casing to 3500 psi for 30 mins. 10. Dress-off cement an~ mill window. 11. RIH w/4 3,4" al BHA to window depth. Drill 4 3,4" hole as per directional plan to TD. 12. Make wiper trip lole conditions require and spot liner running pill across open hole section. 13. Run 3 W', 9.3#, .80 liner to TD with liner lap to 50' inside the 5 ~" scab liner. Cement in place and hang-off on Bal ~r ZXP/HMC liner top packer/hanger. 14. Drop drill & displace cement with perforating pill and seawater. Displace the well to clean seawater ab( the liner top. POOH w/liner running tool. 15. Pick-up red length of 2 1/16" CS Hydril workstring & perforate 3 W' liner. 16. Run 4 Y2" 3 Y2", 12.6# L-80 tubing, packer, WLEG, profile nipples, GLM's, & SSSV(Xnipple). See attached schematic for details. Reverse circulate the well to clean, inhibited seawater,. 17. Drop ball and rod, set production packer and test tubing and annulus to 3500 psi. 18. Install ~ check. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Pull TWC. 20. circulate sufficient diesel to freeze protect the tubing and annulus to 2000' U-tube the diesel. 21. LII & test BPV. Secure the well and rig~down / move off. RECEIVED DS16-23A Permit to Drill MAR 0 7 Naska Oil & Gas Cons, Commission Anchorage Page 4 DRILL A,,N,,D,COMPL,ETE P, ROCEDU, RE SUMMARY ~*,DEADHOR,S,E, AIRPORT, NOTIF!CAT, ION RE~U.,IR,ED,,SEE PAD,DATA ,SHEET*,*, Pre-Rig Work: 1. RU slickline and drift the tubing, tag TD. Pull dummy GLV from bottom station. 2. RU CTU, lay carbolite sand to raise top of fill to 11,810' (last tag at 11,836'). 3. RU slickline, verify top of sand. 4. Chemical cut the 2-7/8" tubing in the lowermost 10' pup joint above the production packer. Attempt to cut in the 1/3 of the pup joint to leave at least a 6' stub for fishing. 5. Kill the well with seawater. Reverse circulate the annulus with 210 bbls 9.3 ppg NaCI followed by 95 bbls diesel. Bullhead the tubing with 78 bbls 9.3 ppg NaCI followed by 17 bbls diesel. This will freeze protect the well to 2000' and provide an equivalent of 8.7+ ppg at the perforations (8.54 ppg SBHP at last survey) or ±90 psi overbalance. 6. Set a BPV in the tubing hanger and test from below to 1000 psi. Block open TRSSSV. 7. Secure the well. Remove wellhouse and flowlines. Level the pad and provide the total well preparation cost on the handover form. Rig Operations: 1. Pull BPV, circulate out freeze protection fluid. Set TWC 2. ND tree, NU and test BOPE to 250 psi Iow / 3500 psi high. Pull TWC. 3. Pull and lay down tubing from the chemical' cut at ±11,330'. 4. Fish the cut tubing stub from the packer with overshot. 5. Mill and recover packer/tailpipe assembly. 6. RU slickline and drift to the top of sand depth with dummy whipstock. 7. Run PDS log across 7 5/8~ casing from top of fill to base of scab liner. Request a "quick-turnaround" of the log interpretation, 8, Shut in at the BOP and perform injectivity test at 2 bpm, 2000 psi max. If injection is possible higher, consider increasing the cement volume to allow more flexibility during the hesitation squeeze. 9. RU e-line and set the whipstock high side to kick off at 11,734' MD. Adjust whipstock orientation with offset weight bars prior to RIH as required to avoid setting the slips in corroded casing. 10. RtH with 2-7/8" DP and cement nozzle. DO NOT TAG the whipstock. Stop RIH to 50' above whipstock depth. 11. Circulate 11 bbls cement to the end of drill pipe (10 bbls ahead, 5 bbls behind fresh water). Shut in and bullhead squeeze the cement to cover the perforations and whipstock. Hesitate squeeze as necessary. Circulate to dress off top of cement to 11,685' MD (50' above whipstock). 12. MU 4.75" window milling assembly and RIH to top of cement. Test 7" casing to 4000 psi. 13. Dress-off cement and mill window. 14. RIH w/4.65" directional BHA to window depth. Drill 4.65" build/turn section. 15. Trip for BHA, drill remainder of section as per directional plan to TD. 16. Make wiper trip as hole conditions require and spot liner running pill across open hole section, 17. Run 3 %", 9.2#, L-80 liner to TD with liner lap to 50' inside the 5 ½' scab liner. 18. Displace cement with mud, set hanger and packer, circulate excess cement to surface. POOH w! liner running tool. 19. Perform liner cleanout with 2 %" bit and 2 1/16" CS Hydril. Test casing to 4000 psi. Circulate the well to 8.7 ppg brine. SLM out of hole. 20. Pick-up required length of 2 1/16" CS Hydril workstring & perforate 3 %" liner _+1000' w/2" guns, 4 spf, overbalanced. 21. Run 4 %" x 3 %", L-80 tubing, packer, WLEG, profile nipples, GLM's, & SSSV (X nipple). See attached completion schematic for details. Reverse circulate the well to clean, inhibited seawater,. 22. Drop setting ball and rod, set production packer and test tubing and annulus to 4000 psi. 23. Install two-way check. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Pull the TWC. DS16-23A Permit to Drill Page 5 16-23 Ri_ site Summary of Drillin_cl Hazards POST THIS NOTICE IN THE DOGHOUSE DS-16 is a designated H2S site. Post and read the H2S contingency plan in the doghouse and perform regular evacuation drills as directed by the Toolpusher and Drilling Supervisor. Post wind direction and designated meeting point tourly on the rig floor. Ensure Deadhorse Airport has been notified prior to moving the rig on and off of the pad. v' Siderite and pyrite concentrations at the top of zone 4B should be avoided by geo-steering beneath. v' Minimize chance of differential sticking by maintaining Iow density drilling fluid properties, however heed the pore pressure of 8.5+ ppg EMW. v' Ensure adequate supplies of LCM are available to manage lost circulation while drilling. Review the lost circulation decision tree prior to spud. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. RECEIVED MAR 0 7 ZOO1 Alaska 0i~ & Gas Cons. Commission Anchorage DS16-23A Permit to Drill Page 5 ' . SITE 16-23 Current Scherr ..,c Tubing: 3 1/2" 9.2# L-80 Premium Thrd · ii-- /I--- ~ 3 1/2" Gas Lift Mandrel/Valve 1 .. ~ 3 1/2" Gas Lift Mandrel/Valve 2 Casing: 10 3/4" 45.50# K-55 3,446'--~~1 /J---- ~ · 3 1/2" Gas Lift Mandrel/Valve 3 i I Crossover 3 1/2" x 2 718" Top of 5 1/2" Liner 6,849' 3 1/2" Gas Lift MandrelNalve 4 Tubing: 2 7~8" 6.50# L-80 Premium Thrd.-- 3 1/2" Gas Lift MandrelNalve 5 /~ 3 1/2" Gas Lift MandrelJalve 6 3 1/2" Gas Lift MandrelNalve 7 ~ ~ 2 7/8" HES 'X' Nipple / ~ Crossover 2 7/8" x 3 1/2" Tubing: 3 1/2" 9.2# L-80 Premium Thrd. Scab Liner: 5 1/2" 17.00# L-80 Packer 11,346' \ /-- Crossover 3 1/2" x 2 7/8" ~ ~ 2 7/8" HES 'X' Nipple Tubing: 2 7/8" 6.50# L-80 Premium Thrd.-- ~ ~ 2 7/8" Parker SWN Nipple REcEiVED Bottom of 5 1/2" Liner 11,600' M~R 0 ? ;~001 --- TopPed. 11,790' , i Alaska 0il & Gas Cons. Commission ~ _. Anchorage -- Last Tag (1/11/00) 11,836' ' PBD 11,898' Casing: 7 5/8" 29.70# L-80 11,981' DATE REV. BY COMMENTS 12-18-00 SRKA Current Schematic PRUDHOE B~Y I, INIT WELL: 1 6-23A BP Exploration (Alaska) I DRIL( ~ITE 16-23A, Proposed Cor~".pletion' · ~ - .4 112" 'X' Landing Nipple Casing: 10 3/4" 45.50# K-55 3,446' ~ · Tubing: 4 1/2" 12.6# L-80 Premium Thrd. ~ 4 1/2" Gas Lift MandreIJalve 1 Crossover 4 1/2" x 3 1/2" Tubing: 3 1/2" 9.2# L-80 Premium Thrd. ~. ~ .Top of 5 1/2" Liner 6849' 3 1/2" Gas Lift MandrelNalve 2 3 1/2" Gas Lift MandrelNalve 3 ~3 1/2" Gas Lift MandrelNalve 4 RECEIVED ~3 1/2" Gas Lift MandrelJalve 5 ~AR 0 ? ZOO1 Alaska 0il & Gas Cons. Commission Anchorage ~II~ -Scab Liner: 5 1/2" 17.00# L-80 ! - ~ 3 1/2" 'X' Landing Nipple Packer I ~ ~ ~ .3 1/2" 'X' Landing Nipple 'HMC' Hydraulic Liner Hanger 11,550' , ' . Bottom of 5 1/2" Liner 11 ,,600' ' ~~Top of Window 11,735 , Whipstock I Plug Back Depth 14,750 --~ ' i ---- ~-'-- TD 14,829' in 4 3/4" Hole ~ ~ ·:: ~To- Perf 11 790' I: . :5 P · , ~ --- Original PBD 11 Casing: 7 5/8" 29.70# L-80 11,981' · ' DATE REV. BY COMMENTS 12-18-00 SRKA Proposed Completion PRUDHOE BAY UNIT WELL: 16-23A BP Exploration (Alaska) i Report Date: November 29, 2000 Client: Alaska Drilling & Wells Reid: PBU- EOA (Drill Sites) Structure I Slot: DS161 DS16-23 Well: DS16-23 Borehole: DS16-23A Proposal Name I Modified Date: DS16.2'3A (P3) I November 29, 2000 Tort I AHD I DDI I ERD ratio: 298.974° 19781.01 It 16.67911.077 Grid Coordinale System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 7012 33.783, W1481332.104 Location Grid N/E Y/X: N 5929327.860 ftU$, E 720031.300 ftUS Grid Convergence Angle: +1.66965227° Grid Scale Factor:. 0.99995500 Grid Coordinates Geographic Coordinates Tie-In Survey 11729.28 48.43 150.57 9003.07 -3225.86 -4888.11 3152.01 0.00 5924533.89 723324.24 N 70 11 45.702 W148 12 0.757 Top Window 11735.00 48.40 150.59 9006.87 -3228.02 -4891.84 3154.11 0.51 5924530.22 723326.45 N 70 11 45.665 W 148 12 0.696 Base Whipstock 11748.00 50.48 150.59 9015.32 -3233.00 -4900.44 3158.96 16.00 5924521.77 723331.55 N 70 11 45.580 W 148 12 0.555 KOP Bid 22/100 11760.00 50.48 150.59 9022.95 -3237.67 -4908.50 3163.50 0.00 5924513.84 723336.32 N 70 11 45.501 W 148 12 0.424 11800.00 59.28 150.59 9045.94 -3254.15 -4936.98 3179.56 22.00 5924485.85 723353.20 N 70 11 45.221 W 148 11 59.958 HOT Entry 11883.70 77.70 150.59 9076.50 -3293.25 -5004.52 3217.63 22.00 5924419.45 723393.22 11900.00 81.28 150.59 9079.47 -3301.33 -5018.48 3225.50 22.00 5924405.72 723401.49 90° Pt 11939.60 90.00 150.59 9082.48 -3321.22 -5052.84 3244.87 22.00 5924371.94 723421.86 End Bid ! Crv 22/100 11944.16 91.00 150.59 9082.44 -3323.52 -5056.82 3247.11 22.00 5924368.03 723424.21 12000.00 91.20 162.87 9081.36 -3346.31 -5108.00 3269.13 22.00 5924317.52 723447.71 N 70 11 44.556 W 148 11 58.855 N 70 11 44.419 W148 11 58.627 N 70 11 44.081 W 148 11 58.065 N 70 11 44.042 W 148 11 58.000 N 70 11 43.538 W 148 11 57.362 HOT Exit 12100.00 91.42 184.88 9079.05 -3358.41 -5206.80 3279.73 22.00 5924219.07 723461.19 12200.00 91.43 206.88 9076.53 -3332.68 -5302.36 3252.54 22.00 5924122.76 723436.79 12201.25 91.43 207.16 9076.50 -3332.13 -5303.48 3251.97 22.00 5924121.63 723436.26 12300.00 91.23 228.89 9074.18 -3272.86 -5380.78 3191.53 22.00 5924042.60 723378.10 12400.00 90.86 250.89 9072.33 -3187.66 -5430.63 3105.56 22.00 5923990.27 723293.62 N 70 1142.567 W148 11 57.058 N 70 11 41.627 W148 11 57.846 N 70 11 41.616 W148 11 57.862 N 70 11 40.856 W148 11 59.616 N 70 11 40.368 W148 12 2.110 DS16-23A (P3) report.xls 0 Page 1 of 2 11/2g/2000-2:03 PM Grid Coordinates Ge~raphic Coordinates I Station ID IUD I Incl I Azim I TVD I VSec I FU-S I E/-W I DLS Nortfling I Easflng LatitudeI Longitude ~) (~) I°) (It) (It) (ft) (ft) (°llOOff) (ftUS) (flUS) End Crv 12498.49 90.36 272,55 9071,27 -3091.01 -5444.72 3008.69 22.00 5923973.37 723197,21 N 70 11 40.228 W 148 12 4.920 Tgt / Crv 10/100 13252.83 90.36 272.55 9066.50 -2337.01 -5411.12 2255.11 0.00 5923985.00 722443.00 N 70 11 40.561 W 148 12 26.777 13300.00 90.35 277.27 9066.21 -2289.97 -5407.08 2208.13 10.00 5923987.66 722395.93 N 70 11 40.601 W 148 12 28.139 13400.00 90.31 287.27 9065.63 -2192.07 -5385.85 2110.54 10.00 5924008.04 722297.76 N 70 11 40.810 W 148 12 30.970 End Crv 13447.40 90.29 292.01 9065.39 -2147.20 -5369.92 2065.91 10.00 5924020.66 722252.69 N 70 11 40.967 W 148 12 32.264 TD 14829.34 90.29 292.01 9058.50 -858.29 -4852.01 784.70 0.00 5924501.00 720957.00 N 70 11 46.063 W 148 13 9.423 Legal Description: Surface: 3856 FSL 4031 FEL S24 TION R15E UM Tie-In: 4048 FSL 881 FEL S25 TION R15E UM Tgt / Crv 10/100: 3525 FSL 1779 FEL S25 TION R15E UM TD / BHL: 4084 FSL 3249 FEL S25 TION R15E UM No~hinaiY}rffUS] Eastina (X)[~US] 5929327.86 720031.30 5924533.89 723324.24 5923985.00 722443.00 5924501.00 720957.00 DS16-23A (P3) report.xls Page 2 of 2 11/29/2000-2:03 PM VERTICAL SECTION VIEW Client: Alaska Drilling & %qel]s We!l: !1816 23A {P3) Field: PBU EOA (Drill Sites) ~Section At: 270.87 deg 7500, 8000. 8800- 9ooo- 9500 - 10000- -4000 -3500 -3000 -2500 -2000 ~1500 -1000 Ve~ical Section Depa~ure at 270.87 de~ from (0.0, 0.0). (1 in = 500 feet) -500 Al ;ho age PLAN VIEW Client: Alaska D!iiling & We}is We 1: DSi6 23A (P3) Pield! PBU EOA (Drill Sites) v v v 5O0 ~4000- -4500- -5000- -5500- -6000- -6500- 5OO 1000 1500 2000 2500 3000 I True North %/0' ~i,~ ' mo~d Azimum 272.55~ 3500 4000 1000 1500 2000 2500 3000 3500 4000 <<< WEST EAST >>> --4000 --4500 --5000 --5500 H 1_ 8 2 8 5 4 o~,,~o,,o~ I VENDOR ALASKAO I LA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET O12C201 CKO12901Em 1OO. OD 1OO. OD PYMT £:OMMENTS' Peri'it to D~ill f'ee HANDL]NO INST: S/H - Teeeie Hub~ le X4&28 AI~ACHED CHECK ms ,# PAYM;N'T FOR ITEMS DE~n;=;u ABOVE. m(e]f!ll~ ] 1 OO. OD 1 OO. OD ,: :BP.EXPLORATION (ALASKA).~:JNG, :.. ':: '!":::~.O,.',.;§bj~":, 19i~'12 ~:.i!~,',:,:.::'::::i':!:: ~'.~ :??:i::~ :,,':i;~;:,:: ":" :.:: "AN~HO~AG:E?!ALAS~~: 99519-6612 '"' '! ';:i:.'i~ '"!': .. - '.'::' . ":., :.",:":ii, ,.;' .:'i: :AN;:~.~F..IUATE,0F :,,~'~," ';:': :', ..... ;' ';,:~:~[~ ::,,,:::,'" NAT~ON~,:pI~:B~RK ':~' .~:: ::," ~' CON~ ';:~,.,~::.,:,;~, :j, :~EEV~hD, Ohlb ,,.','::. ,:',. ::' .~ ;,::,.,;, :. :,:: ',.., :.:,, .... , :., .,', .:,,: ,. :,. ,,.,:,, .,,;. ,:::.' 412 "OOl PAY Td,I ':;Th:e: ORDER oNE '",:HUNDREDi~'~!i:'& ;~.33~: ~$T 7TH ::~.A.~ENU'.E::;i":i:'' SlU :.:::,;,:,f,.:,2., 'i:~':,:;'~.:'.~'"'? ':;ii?:.!!,:i',:. ,,..,,:",: ,:7:??, ..... DATE ' O 1./30 ! O i :'" :::i~OUNT $100. O0 ~ ~,::. !:i OD.....: :,...::::. AK c~501 ANCHORAOE IIm Z'~m ~ 5 hllm m.'O L, & ~-0 ~ q Sm: O0~S t, h ;im qll= WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~' 4F o / .~(.~ INIT CLASS ' {/ ADMINISTRATION 1. Permit fee attached ....................... WELL NAME//~,g',-,2--3,,,z"/ PROGRAM: exp dev ,~/ reddl,~:;~ , serv /~' ,.:..o,, ~,.~'"/-' GE ~'?,,-'J UNIT" 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can. be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Conductor stdng provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... . BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to '~S~,.% L.~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. ;EOLAREA Y N Y N Y N. YN YN .. YN Y N YN Y y N.~ Y N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. ~DATE 26. '~,~,~.- ! 27. ' ~' - ' 28. 29. GEOLOGY 30. 31. 32. Permit can be issued w/o hydrogen sulfide measures ..... Y N :,,/ . .. Data presented on potential overpressure zones ....... Yv/'~ Seismic analysis of shallow gas zones ............. //~ ~ ////~, Seabed condition survey (if off-shore) ............. ' - ' Contact name/phone for weekly progress reports [exploratory o/n~] Y N Y Iq Y N Y N Comments/instructions: ENGINEERING:. ' UlC~n~lar ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain.waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freShwater; or cause drilling waste... to surface; (C) will not impair meChanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E). will not circumvent 20 MC 25.252 or 20 AAC 25.412. GEOLOGY: COMMISSION: wellbore sag ann. disposal para req ?/~ 5',,~ ON/OFF SHORE ,,'~tJ / / c:~nsoffice\wordian~diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ., No Special'effort has been made to chronologically organize this category of informatiOn. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 19 15:09:48 2002 Reel Header Service name ............. LISTPE Date ..................... 02/12/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/12/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MWD RUN 1 AK-MM-10099 R. FRENCH R. BORDES 16-23A 500292205001 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 19-DEC-02 MWD RUN 2 MWD RUN 3 AK-MM-10099 AK-MM-10099 R. FRENCH S. LAITILA M. ANTHONY J. RALL 24 i0N 15E 1624 1249 65.85 38.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.650 7.625 11727.0 3RD STRING PRODUCTION STRING 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 EFFECTED BY MEANS OF AN OPEN-HOLE SIDETRACK AT 12810'MD IN THE 16-23A PB1 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL; DGR; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). EWR4 DATA FOR THE MWD RUN 1 INTERVAL WERE ACQUIRED WHILST RIH FOR MWD RUN 2. THESE DATA WERE MERGED WITH THE EWR4 DATA FROM MWD RUN 2 - NO SEPARATE MAD PASS PRESENTATION IS INCLUDED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 1/10/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 3 REPRESENT WELL 16-23A WITH API~: 50-029-22050-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14713'MD/9073'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. 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 ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 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 RPD RPM RPS RPX FET ROP $ .5000 START DEPTH 11691 0 11725 0 11725 0 11725 0 11725 0 11735 0 11740 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 14646 5 14657 5 14657 5 14657 5 14657 5 14657 5 14713 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11691.0 12237.0 2 12237.0 12809.5 3 12810.0 14713.0 MERGED MAIN PASS. $ 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 .liN 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 Name Service Unit Min Max DEPT FT 11691 14713 ROP MWD FT/H 0.06 407.25 GR MWD API 15.57 445.08 RPX MWD OHMM 0.1 2000 RPS MWD OHMM 0.1 2000 RPM MWD OHMM 0.1 2000 RPD MWD OHMM 0.04 2000 FET MWD HOUR 0.49 58.95 Mean Nsam 13202 6045 86 2959 5946 47 2829 5912 14 5885 5866 17 2814 5866 18 0347 5866 38 2795 5866 7.43466 5846 First Reading 11691 11740.5 11691 11725 11725 11725 11725 11735 Last Reading 14713 14713 14646 5 14657 5 14657 5 14657 5 14657 5 14657 5 First Reading For Entire File .......... 11691 Last Reading For Entire File ........... 14713 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 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 ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11691.0 12187 . 5 ROP 11740 . 5 12237 . 0 $ LOG HEADER DATA DATE LOGGED: 11-APR- 01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12237.0 TOP LOG INTERVAL (FT) : 11727.0 BOTTOM LOG INTERVAL (FT) : 12237.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 48.9 MAXIMUM ANGLE: 95.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 74168 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 4.650 DRILLER'S CASING DEPTH (FT) : 11734.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.80 46.0 9.5 46000 14.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 168.8 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11691 12237 11964 1093 ROP MWD010 FT/H 0.15 190.05 76.7982 994 GR MWD010 API 22.01 256.57 51.7001 994 First Reading 11691 11740.5 11691 Last Reading 12237 12237 12187.5 First Reading For Entire File .......... 11691 Last Reading For Entire File ........... 12237 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 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 ....... 02/12/19 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPX RPS FET GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11725 0 11725 0 11725 0 11725 0 11735 0 12188 0 12237 5 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 12809 5 12809 5 12809 5 12809 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12809 5 12809 5 12809 5 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: 14-APR-01 Insite 4.3 Memory 12810.0 12237.0 12810.0 86.0 104.3 TOOL NUMBER 74168 126589 4.650 11734.0 QUIKDRIL-N 8.80 48.0 9.3 46000 6.5 .100 .040 .080 .100 68.0 192.0 68.0 68.0 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11725 12809.5 ROP MWD020 FT/H 2.52 317.36 GR MWD020 API 17.52 138.45 RPX MWD020 OHMM 0.1 2000 RPS MWD020 OHMM 0.1 2000 RPM MWD020 OHMM 0.1 2000 RPD MWD020 OHMM 0.04 2000 FET MWD020 HOUR 0.85 45.3481 Mean 12267.3 77.2485 36.3613 19.184 23.5699 22.5152 32.8528 15.9259 Nsam 2170 1145 1244 2170 2170 2170 2170 2150 First Reading 11725 12237.5 12188 11725 11725 11725 11725 11735 Last Reading 12809 5 12809 5 12809 5 12809 5 12809 5 12809 5 12809 5 12809 5 First Reading For Entire File .......... 11725 Last Reading For Entire File ........... 12809.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 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 ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12810 0 12810 0 12810 0 12810 0 12810 0 12810 0 12810 0 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 GM Dual GR EWR4 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 (OHM_M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL STOP DEPTH 14657 5 14657 5 14657 5 14657 5 14646 5 14713 0 14657 5 19-APR-01 Insite 4.3 Memory 14713.0 12810.0 14713.0 81.8 94.2 TOOL NUMBER 74168 126587 4.650 11734.0 QUIKDRIL-N 8.80 48.0 9.1 38000 4.0 .220 .100 .175 .180 70.0 168.0 70.0 7O.O 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 .liN 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 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 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 12810 0.06 15 57 0 75 0 71 0 59 0 28 0 49 Max 14713 407.25 445.08 1827.07 2000 1960.86 2000 58.95 Mean Nsam 13761.5 3807 91 4968 3807 49 7858 3674 11 8904 3696 13 5893 3696 15 4041 3696 41 4656 3696 2.49525 3696 First Reading 12810 12810 12810 12810 12810 12810 12810 12810 Last Reading 14713 14713 14646 5 14657 5 14657 5 14657 5 14657 5 14657 5 First Reading For Entire File .......... 12810 Last Reading For Entire File ........... 14713 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/12/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/12/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 19 13:08:28 2002 Reel Header Service name ............. LISTPE Date ..................... 02/12/19 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 ..................... 02/12/19 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-10099 R. FRENCH R. BORDES 1ST STRING 2ND STRING 16-23A PB1 500292205070 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 19-DEC-02 MWD RUN 2 AK-MM-10099 R. FRENCH J. RALL 24 i0N 15E 1624 1249 .00 65.85 38.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.650 7.625 11727.0 3RD STRING PRODUCTION STRING 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 A WHIPSTOCK IN THE 16-23 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT ABOUT 11727'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 2 COMPRISED DIRECTIONAL; DGR; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). EWR4 DATA FOR THE MWD RUN 1 INTERVAL WERE ACQUIRED WHILST RIH FOR MWD RUN 2. THESE DATA WERE MERGED WITH THE EWR4 DATA FROM MWD RUN 2 - NO SEPARATE MAD PASS PRESENTATION IS INCLUDED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 1/10/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 AND 2 REPRESENT WELL 16-23A PB1 WITH API~: 50-029-22050-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12997'MD/9036'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. 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 ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name .... '...STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SLR4MARY PBU TOOL CODE START DEPTH GR 11691.0 RPD 11725.0 RPM 11725.0 RPS 11725.0 RPX 11725.0 FET 11735.0 ROP 11740.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 12930 0 12941 5 12941 5 12941 5 12941 5 12941 5 12996 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11691.0 12237.0 2 12237.0 12996.5 MERGED MAIN PASS. $ 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 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11691 12996.5 ROP MWD FT/H 0.15 317.36 GR MWD API 17.52 405.61 RPX MWD OHMM 0.1 2000 RPS MWD OHMM 0.1 2000 RPM MWD OHMM 0.1 2000 RPD MWD OHMM 0.04 2000 FET MWD HOUR 0.85 45.3481 Mean 12343.8 71.1908 48.8516 28.0004 32.112 33.9378 110.773 14.6357 Nsam 2612 2513 2479 2434 2434 2434 2434 2414 First Reading 11691 11740.5 11691 11725 11725 11725 11725 11735 Last Reading 12996.5 12996.5 12930 12941.5 12941.5 12941.5 12941.5 12941.5 First Reading For Entire File .......... 11691 Last Reading For Entire File ........... 12996.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 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 ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11691 . 0 12187 . 5 ROP 11740 . 5 12237 . 0 $ LOG HEADER DATA DATE LOGGED: 11-APR- 01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12237.0 TOP LOG INTERVAL (FT): 11727.0 BOTTOM LOG INTERVAL (FT) : 12237.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.9 MAXIMUM ANGLE: 95.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 74168 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.650 DRILLER'S CASING DEPTH (FT) : 11727.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N MUD DENSITY (LB/G): 8.80 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 46.0 9.5 46000 14.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 168.8 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11691 12237 11964 1093 ROP MWD010 FT/H 0.15 190.05 76.7982 994 GR MWD010 API 22.01 256.57 51.7001 994 First Reading 11691 11740.5 11691 Last Reading 12237 12237 12187.5 First Reading For Entire File .......... 11691 Last Reading For Entire File ........... 12237 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 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 ....... 02/12/19 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX FET GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11725 0 11725 0 11725 0 11725 0 11735 0 12188 0 12237 5 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 12941 5 12941 5 12941 5 12941 5 12941 5 12930 0 12996 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 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 14-APR-01 Insite 4.3 Memory 12997.0 12237.0 12997.0 86.0 104.3 TOOL NUMBER 74168 126589 4.650 11727.0 QUIKDRIL-N 8.80 48.O 9.3 46000 6.5 .100 .040 .080 .100 68.0 192.0 68.0 68.0 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11725 12996.5 ROP MWD020 FT/H 0.21 317.36 GR MWD020 API 17.52 405.61 RPX MWD020 OHMM 0.1 2000 RPS MWD020 0HMM 0.1 2000 RPM MWD020 OHMM 0.1 2000 RPD MWD020 OHMM 0.04 2000 FET MWD020 HOUR 0.85 45.3481 Mean 12360.8 67.5215 46.945 28.0004 32.112 33.9378 110.773 14.6357 Nsam 2544 1519 1485 2434 2434 2434 2434 2414 First Reading 11725 12237.5 12188 11725 11725 11725 11725 11735 Last Reading 12996.5 12996.5 12930 12941.5 12941.5 12941.5 12941.5 12941.5 First Reading For Entire File .......... 11725 Last Reading For Entire File ........... 12996.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE