Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
180-015
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250216 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # BRU 232-04 50283100230000 132037 1/18/2025 AK E-LINE Perf CLU 08 50133205340000 204005 2/13/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 1/2/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 12/13/2024 YELLOWJACKET SCBL CLU 7 50133205310000 203191 1/25/2025 YELLOWJACKET SCBL IRU 44-36 50283200890000 193022 1/21/2025 AK E-LINE Plug/Perf KALOTSA 10 50133207320000 224147 2/11/2025 YELLOWJACKET SCBL KALOTSA 9 50133207310000 224145 1/26/2025 YELLOWJACKET SCBL KBU 22-06Y 50133206500000 215044 1/11/2025 YELLOWJACKET SCBL KU 13-06A 50133207160000 223112 1/12/2025 YELLOWJACKET SCBL MRU M-25 50733203910000 187086 1/15/2024 AK E-LINE PPROF NCIU A-21 50883201990000 224086 1/6/2024 AK E-LINE Plug/Perf PBU 06-05A 50029202980100 224115 1/14/2025 HALLIBURTON RBT PBU 09-35B 50029213140200 224122 2/3/2025 HALLIBURTON RBT PBU B-12B 50029203320200 224133 1/20/2025 HALLIBURTON RBT PBU D-12 50029204430000 180015 12/19/2024 BAKER SPN PBU F-08B 50029201350200 212040 1/27/2025 HALLIBURTON RBT PBU NK-41A 50029227780100 197158 12/18/2024 YELLOWJACKET CBL PBU S-100A 50029229620100 224083 1/5/2025 HALLIBURTON RBT Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. 162-037 T40080 T40081 T40082 T40082 T40083 T40084 T40085 T40086 T40087 T40088 T40089 T40090 T40091 T40092 T40093 T40094 T40095 T40096 T40097 PBU D-12 50029204430000 180015 12/19/2024 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.18 13:06:47 -09'00' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 .; t r' 4 "A e ?MI! J T. x '91 � - Mr. Tom Maunder ' 9" EI rte Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 3 Anchorage, Alaska 99501 Alls€ce t it & GAs Co c LaLz Subject: Corrosion Inhibitor Treatments of GPB D Pad :;t►yt€Fitsyfrt; Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 0-05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 .....___---> 0-12 _ 1800150 50029204430000 _ NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 0-17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 0-31 A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 OPERABLE: D-12 (PTD #18001 ) TxIA integrity restored Page 1,$f~ ~ ~ ~ ~<.~„~~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIllntegrityEngineer@BP;~] Sent: Monday, September 21, 2009 8:59 AM ~~~~~~5'~~ To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Schwartz, Guy L(DOA); Maunder, Thomas E(DOA) Cc: Stone, Christopher Subject: OPERABLE: D-12 (PTD #1800150) TxIA integrity restored All, ~ ~ Well D-12 (PTD #1800150) passed an MlTlgafter the gas lift valV"~'S"'vVere d"ummied off. The passing test verified that tubing integrity has been restored. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please be careful when POPing as the IA ifs fluid packed. ~ Thank you, Torin From: NSU, ADW Well Integrity Engineer ~G~'~~i~~~ "d~>> ~ t~ ~~;~~ .F 4 Sent: Saturday, September 19, 2009 8:07 PM / To: 'Regg, James B(DOA)'; NSU, ADW Well Integriry Engineer; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Schwartz, Guy (DOA) <guy.schwa~@alaska.gov>; 'Maunder, Thomas E (DOA)' Cc: Stone, Christopher Subject: UNDER EVAIUATION: D-12 (PTD #1800150) TxIA communication All, r Well D-12 (PTD #1800150) is exhibiting sustained casingpressure on the IA. The wellhead pressures were 700/2400/0 on 9/17/09. The well broke MOASP on 9/09/09, however, the following day a TIFL was conducted .- that passed verifying manageable TxIA communication. With the recent pressure build up, the well has been reclassified as Under Evaluation and may remain on production. The plan forward is as follows: 1. S: Set DGLVs 2. F: MIT-IA to 3000 psi, LLR if fails A TIO Plot and welibore schematic have been included for reference. « File: D-12 TIO Plot.doc »« File: D-12. pdf » ~ Please call with any questions or concerns, Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 11 /5/2009 PBU D-12 PTD 1800150 9/21 /2009 TIO Pressures a~ ~ ~ ~ a~ a _ ~ ~ ~ ~ f Tubing Pressure (psi) i I f IA Pressure (psi) ~ ~ IA MOASP ~ f OA Pressure (psi) ~ I OOA Pressure (psi) :V ~ OOOA Pressure (psi) ° ~f OA SP r I ~ ~ ' i ~ ~ 1 I ' ~~ I D i 1 i 6l30~2009 7M 5C2009 Tr31 I2009 8M SC~009 8C31 f1009 9115~009 i ~ 7REE = 4" CIW WEILHEAD= ~~ FMC ACTUATOR= BAKER C KB. ELEV = BF. ELEV =~ KOP = Max Angle = 71.5' 47' 3100' 22 @ 3700' Datum MD = 8979' Datum NDss= 88Q0' ~ SAF ES ~~ ~ ---~ 2100' (--~4-1/2" OTIS SSSV NIP, ID = 3.813" 2$12' 9-5/8" DV PKR GAS LIFi" MANdRELS 13-3/8" CSG, 72#, L80, ID = 12.347" ~-~ 2706~ Minimum ID = 3.813" @ 2100' 4-112" OTIS SSSV NIPPLE ST MD 7VD DEV TYPE VLV LATCH PORT DATE 5 3334 3324 14 MMGM DdME RK 16 4 4534 4482 17 MMGM SO RK 20 3 5620 5517 9 MMGM DMY RK 0 2 6623 6516 2 MMGM DMY RK 0 1 7625 7518 1 MMGM dMY RK Q 05(25/06 7$(i7' -L4-1/2" HES X NIP, ID = 3.813" ~ 781$' 9-5!&" x 4-1l2" BKR S-3 PKR, ID = 3.85" 7841 ° 4-1 i2" HES X NIP, ID = 3.813" 7863' UNIQUE MACHINE C3V ERSHOT -{D = 4.615" 7$'74° ~-{ 9-5/8" x A-1/2" 071S PERM PKR, ID = 3.85" TOP OF 7" LNR ~-{ 7914' 7'J33' --~4-1/2" PKR SWS NIP, ID = 3.813" 7~~7' 1 ELMD TT - LOGGED 04l09/00 ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ld = 3.958" 0-j 7'$37' 9-5l8" CSG, 47#, L-8d, ID = 8.681" ~-~ $406' PERFORATION SUMMARY REF LOG: SWS-BHCS ON 05/14/80 ANGLE A7 TOP PERF: 1 a~ 9055' Note : Refer to Production DB for historical perf data SIZE SPF INTERVA~ C}pn/Sqz DATE 3-1/8" 4 9055 - 9085 S 09l14191 3-1t8" 4 9090 - 9698 O 04112/93 3-1/8" 4 91Q6 - 9116 Q 10/1Q/91 3-118" 4 9116 - 9130 O 10(10/91 8930' I-~ ~ ~KER JOINT 9314' ~ FISH - 4-1/2" TAIIPIPE W/PKR SWN NIPPLE I W/PLUG - 04(d9/00 - ~ENGTH +- 18' PBTD --( g366, 7°' LNR, 29#, L80, .0371 bpf, ID = 6.184" 9426' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/19/80 ORIGINAL COMPtET10N 03/23t00 RWO Q5J19i06 KSB(TLH GLV CIO (05/13/06) 05/25/06 dAVlPJC GlV C(O 06/24/06 PJC GLV CORRECTIONS 03/23/09 JLW/SV WELLHEAD CORR PFtUDNOE BAY UN17 WELG: D-12 PERMIT No: ~1800150 APl No: 50-029-20443-00 Sec. 23, T11 N, R13E BP Exploration (Alaska} 03/25/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wa_II .Inh !k 1 ,... n.. N0.5150. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPC-03 AXBD-00015 MEM PRODUCTION PROFILE / 03/13/09 1~ 1 05-27B BOOR-00002 MEM CBL 03/08/09 1 1 L2-24 AWL9-00025 PRODUCTION PROFILE 03/22/09 1 1 Y-OSB AWJB-00011 MCNL j' 11/09/08 1 1 D-12 12113022 RST ~ 12/04/08 1 1 LGI-04 12103707 RST _ / ~ ~ 12/25/08 1 1 . _~_.~~..~.-.-~--~~.-...~..~.. ~... . ...• V,v.~..~u.. ~~~V ~~a-•Vf11~11~V \/I~G VVr, CMVfI IV. BP Exploration (Alaska) Inc. `~ Petrotechnical Data Center LR2-1 "~ }~ ~ ~~ ' ~~ 900 E. Benson Blvd, Anchorage, Alaska 99508 \{ ;~ M2 °~ D174~{tl Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • 12/18/08 ~chlumberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll ~..~. u N0.5011 .~, • ~.~ A .. , t~ 4F e_mo- _..~• ~ ~ r• Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11-34 12071901 -- ----•• ••~•• USIT LI - vaac 10/17/08 ow. liVWf 1 VU 1 V-219 12103700 USIT d - 11/21/08 1 1 D-12 12113022 INJECTION PROFILE 12/05/08 1 1 R-11A 12096929 USIT _ (, 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG (p - / ~- ~ a 12/06/08 1 1 F-19 AWJI-00011 MEM LDL (_ 12/08/08 1 1 18-29B AWJI-00010 MEM LDL ~ b 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE f 4~ --(S 12/04/08 1 1 18-148 12005233 MCNL 09/21/08 1 1 18-06B 12083417 MCNL - 10/28/08 1 1 18-14C 12066551 MCNL ~ 10/06/08 1 1 05-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 ~ L 'a - ~~ 3 f °~ ~ Wl''f -T ~f - ~ C PI FACE Af_I(AIA111/I CIIRC oc rv~oT ov @~nw uw~n_ ww~n n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: • • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth _..s _ ~---°- Received by: 9/J6/ob REC\::.\Vt:U STATE OF ALASKA . SEP 1 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION . þ¡ls Cons. commission REPORT OF SUNDRY WELL oPERA1fð~Þchorage ~ . ßJ¿ 1. Operations Performed: OtherD Abandon 0 Repair Weill&) Plug Perforations 0 Stimulate 0 Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 180-0150 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20443-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.50 D-12 8. Property Designation: 10. Field/Pool(s): ADL-028285 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9434 feet true vertical 9326.0 feet Plugs (measured) None Effective Depth measured 9366 feet Junk (measured) 9314 Fish 4-1/2" Tailpipe W/PKR SWN NIP W/Plug (04/09/00) true vertical 9260.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 30 - 110 30.0 - 110.0 1490 470 SURFACE 2677 13-3/8" 72# L-80 29 - 2706 29.0 - 2706.0 4930 2670 PRODUCTION 1942 9-5/8" 47# L-80 27 - 9426 27.0 . 9318.0 6870 4760 LINER 628 7" 29# L-80 7914 - 9426 7807.0 - 9318.0 8160 7020 Perforation depth: Measured depth: 9055-9085, 9090-9098, 9106-9116, 9116-9130 5CANNED SEt 2 0 2DU5 True vertical depth: 8948-8978,8983-8991,8999-9009,9009-9023 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 26 - 7937 Packers & SSSV (type & measured depth): 9-5/8" DV Packer @ 2612 9-5/8" Baker 5-3 Packer @ 7818 9-5/8" Otis PERM Packer @ 7874 4-1/2" Otis 55SV nipple @ 2100 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Reoresentative Daily Averaae Production or Iniection Data . Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 795 37434 338 --- 1110 Subsequent to operation: 860 38655 361 --- 1109 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ Oil!!] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer AI .........1 ~ j¿JI Signature .AJ:à hL... Phone 564-5174 Date 9/12/06 !"C'KI JIUIS t:Jt'l SEP 8 Form 10-404 Revised 4/2004 0 R \ G \ t~ A L 1 2006 . . .- D-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/25/2006 TESTEVENT --- BOPD: 1,062 BWPD: 426 MCFPD: 37,820 05/26/2006 PULLED PX PLUG BODY FROM 7816' SLM ***WELL LEFT S/I*** 05/25/2006 SET DGL V IN ST A# 1. MADE SEVERAL RUNS W/2.25" BAILER, 4 1/2" GR & GS TO PX PLUG BODY @ 7816' SLM ATTEMPTING TO PULL. IN PROGRESS. 05/24/2006 ****WELL SHUT IN ON ARRIVAL*** (post BH weld) PULLED PRONG FROM PXN @ 7813' SLM. 05/21/2006 T/I/O= 01010 Temp = SII MIT OA PASSED to 2000 psi. (Post Wellhead repair) Pressure up OA to 2000 psi wI 2.6 bbls crude. 1 st 15 min test lost 200 psi, 2nd 15 min test lost 20 psi with a total of 220 psi in 30 min test. Final WHP's= 01010 05121/2006 TIIIO=VACNAC/O+ Temp=SI WHPs (Post Welding). TBGP decreased 100 psi, the lAP decreased 100 psi and the OAP remained unchanged since 05/19. 05/19/2006 TIIIO= 130/12010 (REG COMPL) Well Head Repair - Freeze protect IA and Tbg with 10 bbl methanol spear followed by 150 bbls crude pumped down IA. U-Tube IAxTbg with crude. Freeze protect flowline wI 7 bbls neat and 120 bbls crude. Final WHP's= 01010 05119/2006 T/I/O=100/10010+. Temp=SI. Assist with Bradenhead weld. Initial TBG & IA FL's @ 70'. OA FL near surface. Rig up N2 purge across the OA and started welding the bradenhead. Welded 3 beads across the top and 3 beads across the bottom of the bradenhead. Weld complete. Monitored for 30 minutes. Replaced cellar boards and rigged down equipment. Final WHP's= 100/10010+. 05118/2006 T/I/O= 85190/15. Temp= SI. Bradenhead Weld. Tubing and IA FL @ surface. OA FL near surface. Bled tubing and lAP to 0+ psi in 20 minutes. Bled OAP to 0 psi in 1 minute. Rigged up N2 to tubing taking returns from lA, approximately 7 bbls returns. U-tubed tubing and IA with N2. Monitored for 30 minutes. Tubing FL @ 72' (1 bbl). IA FL @ 66' (4 bbls). Purged OA with N2. Final WHP's= 110/11010. 05117/2006 TIIIO= 540/54010. CIRC OUT [pre Braden head repair]. Pump a 5 bbl methanol spear and 572 bbls of 1 % KCL down the TBG. Return up the IA through a loop to the flowline. Final WHP= 200/220/40. 05116/2006 T/I/O=500/480/10. Temp=SI. Photograph wellhead, Prep WH for BH weld. TBG FL @ 408' «7 bbl). fA FL @ 786' (43 bbl). OA FL Near Surface. IA & OA casing valves have integral flange's installed. OA still needs to have a companion valve installed to flow N2 for the weld job. OA has a flange with a 2" bullplug and a 1/2" NPT plug. Need to bleed OAP to 0 psi and check if the VR plug is removed. Well support installed valves and piping for eire-out. Ordered 2 each bleed trailers and 1 each heater from equipment hauler (401), to be delivered tonight for bleed and N2 purge tomorrow. Cleaned and photographed wellhead. Page 1 . . 1" D-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/15/2006 T/I/O = SSV/500/10. Temp = SI. Eval wellhouse and wellhead for upcoming BH weld. Bradenhead area needs to be cleaned. OA needs companion valve installed for N2 purge. IA needs 3" integral flange installed. Needs eire-out installed. Clean gravel needed in cellar. 05/14/2006 T/I/O = 2020/120010. CMIT TxlA PASSED to 3000 psi. Continue WSR from 5/13/06. Lost 20psi 1 st 15min, Opsi 2nd 15min. Freeze protecte flowline, bled down pressures. FWHP's = 400/300/10 05113/2006 T/I/O = 208011800/20. CMIT TxlA to 3000. Bleed gas off IA. Final WHP's = 2020/120010. 05/13/2006 *** WELL FLOWING ON ARRIVAL *** (set Up, pull sta#1, emit) DRIFT TO 7900' SLM W/3.80 GAUGE RING,4.5" BLB SET PX PLUG BODY @ 7825' SLM PULL STA#1 DGLV @ 7611' SLM. SET PRONG @ 7820' SLM.(1 3/4" F.N. 102" OAL) PLUG SEEM'S TO BE HOLDING ****LEFT WELL SHUT IN**** ***LEFT STA#1 OPEN*** FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 5 Methanol 22 Neat Methanol 572 1 % KCL Water 746 Crude 1346 TOTAL Page 2 'TREE = 4" CrN SAF TES WELL HEA D= OCT D-12 ACTUA TOR= BAKERC KB. ELEV = 71.5' BF. ELEV = 47' KOP= 3100' 2100' -14-1/2" OTIS SSSV NIP, ID= 3.813" I Max Angle = 22 @ 3700' . Datum MD = 8979' ~ 2612' -19-5/8" OV PKR I Datum TVDss= 8800' GAS LIFT MANDRELS 113-3/8" CSG, 72#, L80, 10 = 12.347" I 2706' H ~ ST MD TVO DEV TYÆ VLV LA TCH PORT OATE 5 3334 3324 14 MMGM DOME RK 16 4 4534 4462 17 MMGM SO RK 20 U 3 5620 5517 9 MMGM DMY RK 0 2 6623 6516 2 MMGM DMY RK 0 1 7625 7518 1 MMGM DMY RK ¡,. 0 OS/25/06 . 7807' -14-1/2" HES X NIP, ID = 3.813" I Minimum ID = 3.813" @ 2100' 18 7818' H 9-5/8" x 4-1/2" BKR S-3 PKR, 10 = 3.85" I 4-1/2" OTIS SSSV NIPPLE ..2S. I 7841' - 4-1/2" HES x NIP, 10 - 3.813" I , " 7863' -1 UNIQUE MACHINE OVERSHOT - ID = 4.615" I III :8': ........ 7874' -19-5/8" x 4-1/2" OTIS ÆRM PKR, ID = 3.85" I ¡..:::::::: TOP OF 7" LNR I 7914' . I . I 7933' -14-1/2" PKR SWS NIP, ID = 3.813" I I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 7937' I 7937' H ELMD TT - LOGGED 04/09/00 I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 8406' ... I 8930' -1 MARKER JOINT I PERFORA TION SUMMARY REF LOG: SWS-BHCS ON 05/14/80 I ANGLE AT TOP PERF: 1 @ 9055' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ! 3-1/8" 4 9055 - 9085 S 09/14/91 3-1/B" 4 9090 - 909B 0 04/12/93 3-1/8" 4 9106 - 9116 0 10/10/91 3-1/B" 4 9116 - 9130 0 10/10/91 [ I 9314' FISH - 4-1/2" TAILPlÆ W/PKR SWN NIPPLE W/PLUG - 04/09/00 - LENGTH +- 18' 1 PBTDI 9366' I 1 7" LNR, 29#, LBO, .0371 bpt, ID = 6.1B4" I 9426' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrT 05/19/80 ORIGINAL COM PLETION WELL: D-12 03/23/00 RWO ÆRMrT No: '1800150 05/19/06 KSB/TLH GLV C/O (05/13/06) API No: 50-029-20443-00 OS/25/06 OAV/PJC GLV C/O Sec. 23, T11N,R13E 06/24/06 PJC GL V CORRECTIONS BP Exploration (Alaska) ,"-", STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil COmpany of California (UNOCAL) Development: 172 feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK R9519-624~, Service: X Swanson River Unit 4. Location of well at surface Co~u t~ #2,1/ 8. Well number 1824' FNL & 2010' FEL SEC. 33, TSN, R9W, SB & M SRU 32-33 WD At top of productive interval 9. Permit number Same- Vertical Hole At effective depth 10. APl number Same - Vertical Hole 50- 133-20337 At total depth 11. Field/Pool Same - Vertical Hole Swanson River/Sterling 12. Present well condition summary Total depth: measured 2520 feet /' Plugs (measured) 2450' true vertical 2520 feet , Effective depth: measured 2450 feet Junk (measured) true vertical 2450 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 10-3/4" No 80' 80' Surface Intermediate Production 2499' 7" 700 SX 2499' 2499' Liner Perforation depth: measured 2100'-2228', 2234'-2278', 2316'-2424' true vertical Same - Vertical Hole Tubing (size, grade, and measured depth) 3-1/2", N-80, 9.2# BTC AB Mod to 2,057' Packers and SSSV (type and measured depth) Baker FHL Retrievable Packer @ 1997' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X Schematic X 14. Estimated date for commencing operation 15. Status of well classification as: August 19, 2002 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver ~ Date approved Service: Water Disposal 17. I hereby~egoin~'~e,~e~ to the best of my knowledge. Signed. ~-~ ~ ~.~ ~ Title: Drilling Engineer. Date: ,)<~-{-'e.. r" FOR COMMISSION USE ONLY ~ IApproval No. Conditions of approval: Notify Commission so representative may witness '~{~ Plug integrity. ~ ,t BOP Test. Location clearance Mechaj~ical Integrity Test_.~C ,, Subsequent form r~quired lo- AUG 'i ? 2002 Ong~nal S~gneo c~) Alaska OiJ & i:i~:i; C~,~?..; '.,~,,,,,,.-~,.~. / Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Proposed Workover Procedure Swanson River Field Well SRU 32-33 WD August 2002 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. MIRU Nabors Pulling Unit. Install BPV and N/D Tree. N/U and test BOPE to 3,000 psi. M/U robing hanger and pull to unseat production packer. Pull and L/D robing and packer. Make clean out mn as/if required. Run production packer on 3-1/2" Hydril 533, 9.3#, L-80 Tubing. Land robing hanger and set production packer at +/- 1,950'. Test tubing to 3,000 psi. Test tubing x 7" casing annulus to 1,500 psi. N/D BOPE and N/U Tree. Test Tree to 3,000 psi. UNOCAL ) Swansoh ,river Field SRU 32-33WD As completed 3/24/95 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP 10-3/4" 0' 7" 23# K-55 0' Tubing: 3-1/2" 9.2 N-80 SC BTC AB mod 0' BOTTOM 90' 2499' 2057' Hole in robing at 400' Scale in tubing at 1,058' JEWELRY AND WELLBORE DETAIL NO. Depth Item 1 0' 2 1967' 3 1997' 4 2046' 5 2057' Vetco 7" tbg hgr w/xover from 3-1/2" EUE to 3- 1/2" BTC 3-1/2" X nipple, 2.81 '" ID Baker FHL retrievable pkr, 3.00" ID 3-1/2" X nipple, 2.81'" ID Shear out sub, 2.992" ID Hole in tubing at 1975' TD = 2499 MD PBTD = 2450' PERFORATION DATA TOP BTM ZONE SPF 2100' 2228' 4 9/85 2234' 2278' 4 9/85 2316' 2424' 4 9/85 SRU 32-33WD 3-24-95 Schematic.doc 08/12/02 DRAWN BY: TAB UNOCAL ) SIZE Swansoh ,river Field SRU 32-33WD Proposed CASING AND TUBING DETAIL WT GRADE CONN TOP 10-3/4" 0' 7" 23# K-55 0' Tubing: 3-1/2" 9.3 L-80 HYD 533 0' JEWELRYANDWELLBOREDETAIL NO. Depth Item 1 0' 2 1910' 3 1950' 4 1990' 5 2030' Rector 7" tbg hgr 3-1/2" BTC 3-1/2" X nipple, 2.81 '" ID Baker SAB Packer, 4.00" ID 3-1/2" X nipple, 2.81 '" ID WLRG, 2.992" ID BOTTOM 90' 2499' 2030' TD = 2499 MD PBTD = 2450' PERFORATION DATA TOP BTM ZONE SPF 2100' 2228' 4 9/85 2234' 2278' 4 9/85 2316' 2424' 4 9/85 SRU 32-33WD Proposed Schematic.doc 08/12/02 DRAWN BY: TAB 1502 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~ ~ ' 0 ~' Commissioner ~QiOo~7 Tom Maunder, P. I. SupervisOr v~,(-~'x~ ~'' DATE: April 20, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday. Ar~ril 20. 200!; I traveled to BPXs D Pad and witnessed the semi annual _ . safety valve system testing. As the attached AOGCC SafetY Valve System Test Report indicates I witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on wel/D~06 had a ~slow leak when pressure ~tested. This valve was serviced and the retest ~tnessed bnthiS date. Merv Liddlow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through' inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in fair conditions. Sum. mary: I witnessed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20wells, 40 components, 1 failure 2.5% failure rate 25 wellhouse inspections A,tt~,,c, hm~,, n,,t; svs PBU D Pad 4-20-01 CS X,, Unclassified .. Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit~ad: Pmdhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4/20 HPS 660 Well Permit Separ Set L/P Test Test Test Date Oil, WA(I, (liN& Number Nu,mber ,, PSI , psI Trip Code C0,de Code passed GAS or CYCLE D-01A 1970780 154 125 125 P P OIL D-03A 2001340 154 125 125 P P OIL D-04A 1871250 ..... D'-o~ ' 1700060 660! 550 450 P ' P ' ' '0IL D-06A 1970430 660 550 600~ P 4 OIL D'-07A 1931570 6601 550 525' P P " '4/20/0'1 '' oiL D-08 1790360 D-09A 1990850 ~60 550 525~ P P ' ' 'OIL D-10 1790530 660 550 ~'25 P 'P ' ' OiL D-ilA '1951830 660 ~550 " 525 P '" P ' ' ' OIL D-12 1800150 660 550 530 P P OIL D-13A 2000810 D-14A' i961530 ........ D-15A 1972120 D-16 ' 1811710 660 550 ' '500 ' P' P ' ' OXLi D- 17A 1960460 D-18 '1811880 D-20 ' 1820440 154 125 ' '120 P P ' ' OIL D-21 1820~20 154 125 125 P P .... oIL D-22A 1972040 D-23A 1961880 660 550 525 P P OIL D-24 1852990 D-25A '2000240 154 125 100 P P ' ' oIL D-26A 1970870 660 550 '525 P' ' P OIL D-27 ' 1860330 ' '660 ' 550 ~50 'P 'P ' ' OIL D-28A 1952130 660 550 550 P P OIL D-29 1852530 154 ' 125 110 P P 'OIL D-30 1960260 D-31A '1960950 660 5~0 '550 P P oiL , D-33 1960360 660 550 550 P P OIL RJF 1/16/01 page 1 of 2 SVS PBU D Pad 4-20-01 CS Well Number Wells: Permit 'I SePar Set Number PSI ~ PSI :~20 Components: . L/P.I TeSt:.! Test I Te~t ! Date Trip ] Code ] Code] Code] Passed 40 Failures: ,· 1 Failure Rate: Oil, WAG, GINJ, GAS or CYCLE 2.50% r~19o Day Remarks: The surface, safety, valve on weE D.-6 had slow leak wh, ~,. pressure.tested. Valve was .serviced and retestcd.sarae day ~. : ...................................... .I I Jll I J I I I . I II I I II l~ IIII I I ~lll_l LI .. ~ I / i . i..i i · .......... ~,..,. , . i RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS STATE OF ALASKA ALASK~ DIL AND GAS CONSERVATION CON. ~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name"of Ope'~ator ...................... 5. '~-ype of well': 6. Datum Elevation (DI~' or KB) ........ BP Exploration (Alaska) Inc. [] Development KBE = 71.50' AMSL [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Ni~i~ 2930' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM' -' -'"- D-12 9. Permit Number / Approval No. At top of productive interval 180-015 300-023 ,,, , , , ,, 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UM 10. APl Number At effective depth 50-029-20443-00 1579' NSL, 927' WEL, SEC. 23, T11N, R13E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 1580' NSL, 928' WEL, SEC. 23, T11N, R13E, UM Pool ...... 12. Present well condition summary Total depth: measured 9434 feet Plugs (measured) true vertical 9326 feet Effective depth: measured 9366 feet Junk (measured) true vertical 9260 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" x 30" 14 cu yds Arcticset 110' 110' Surface 2679' 13-3/8" 3820 cu ft Permafrost II 2706' 2704' Intermediate 8381' 9-5/8" 1235 cu ft Class 'G', 130 cu ft PF 'C' 8406' 8299' Production Liner 1512' 7" 295 cu ft Class 'G' 7914' - 9426' 7807' - 9318' RECEIVED Perforationdepth:measured 9090'-9098', 9 06'-9 30' APR 04 2 000 Sqzd: 9055'- 9085' true vertical 8983' - 8991', 8999' - 9023' .AJa~a 011 & Gas Cons. C0mmissi0n Sqzd: 8948'- 8978' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 7864'; 4-1/2", 12.6#, L-80 from 7865' - 7965' Packers and SSSV (type and measured depth) 9-5/8" Baker 'S-3' Packer at 7818'; 4-1/2" SSSV Nipple at 2100' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIgINaL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ......... ,, 15. Attachments ......... 1.~.. Statue"of w(~'i'i'"class'ification's as:.......... [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~,~._~_.., ~ Title TechnicalAssistant III Date Form 10-404 Rev. 06/15/88 Submit In DuplicatE Facility Date/Time 21 Jan 00 22 Jan O0 Progress Report PB D Pad Well D-12 Page 1 Rig Nabors 7ES Date 27 March 00 00:00-06:00 00:00-04:30 04:30 04:30-06:00 06:00 06:00-06:00 06:00-08:30 08:30 08:30-16:00 Duration 6hr 4-1/2 hr 1-1/2 hr 24 hr 2-1/2 hr 7-1/2 hr 16:00 16:00-20:00 20:00 20:00-22:30 4hr 22:30 22:30-04:30 2-1/2 hr 04:30 04:30-06:00 6 hr 04:30-06:00 06:00-11:00 06:00-08:00 08:00 08:00-10:30 10:30 10:30-11:00 1-1/2 hr 1-1/2 hr 5hr 2hr 2-1/2 hr 1/2 hr Activity Move rig Rigged down Drillfloor / Derrick R/D rig floor. Bridle up. Lower pipe chute. Lower derrick. Secure lines. Prep rig for rig move. Equipment work completed Rig moved 5.00 % Move rig off West Beach 07. Prepare to move rig down road. Rig off station Move rig (cont...) Rigged down Lines / Cables Prepare rig for move on road. Move rig to end of pad. Wait 1/2 hr on security. Equipment work completed Rig moved 75.00 % Moved sub base to D-pad. Rig off station Rigged up Drillfloor / Derrick Prepare and raise derrick. Raise pipe chute. Equipment work completed Rig moved 90.00 % Set mats and herculite. Spot sub on D-12. At well location - Cellar Rig moved 100.00 % Set mats and herculite for pits. Spot pits. Berm pits and sub base. At well location - Cellar Rigged up Drillfloor / Derrick Finish R/U top drive and rig floor. Rigged up Drillfloor / Derrick Spot and berm cuttings tank. Hook up geramino line, mud lines. Hook up top drive and rig up rig floor. Take on seawater. Move rig (cont...) Rigged up Drillfloor / Derrick (cont...) Spot and berm cuttings tank. Hook up geramino line, mud lines. Hook up top drive and rig up rig floor. Take on seawater. Equipment work completed Rig accepted at 0800 hrs 1/22/2000. Rigged up Surface lines Hook up circ hoses to tree. R/U drill site maint lubricator. Stopped: To hold safety meeting Held safety meeting Hold pre-spud safety and environmental meeting. Reviewed pre-spud checklist. Reviewed well and commitment to safety/enviromnental. 11:00 11:00-12:00 11:00-12:00 12:00 12:00-13:00 lhr lhr lhr Completed operations Wellhead work Removed Hanger plug Pulled BPV with lubricator. Equipment work completed Test well control equipment RECEIVED · . APR 04 2000 & C m. Oa-n.i; ;0, An or Facility Date/Time 23 Jan O0 Progress Report PB D Pad Well D-12 Page 2 Rig Nabors 7ES Date 27 March 00 12:00-13:00 13:00 13:00-15:00 13:00-13:30 13:30 13:30-15:00 15:00 15:00-17:00 15:00-17:00 17:00 17:00-23:00 17:00-18:30 18:30 18:30-23:00 23:00 23:00-03:30 23:00-00:00 00:00 00:00-03:30 03:30 03:30-05:00 03:30-05:00 05:00 05:00-06:00 05:00-06:00 05:00-06:00 06:00-09:00 06:00-09:00 09:00 Duration 1 hr 2~ 1/2 hr 1-1/2 hr 2 hr 2 hr 6 hr 1-1/2 hr 4-1/2 hr 4-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 3 hr 3 hr Activity Installed High pressure lines Finished install circ lines from tree to choke. Equipment work completed Fluid system Held safety meeting Held Pre-spud safety/environmental meeting with crew #2. Completed operations Circulated at 7865.0 ft Pressure test lines to choke, 1500 psi. Circ diesel freeze protect thru choke and gas buster to slop tank. Operation stopped due to Incident Spill. Suspend operations Held drill (Spill) Stopped to clean up diesel spill. Diesel plume from gas buster exhaust dispersed into gusting winds. Clean up snow/ice on pad. Completed operations Fluid system Circulated at 7865.0 ft Finish circ diesel from annulus. Stopped: To flowcheck well Reverse circulated at 7865.0 ft Reverse circ diesel from inside tubing. Cont'd to circ well volume, well static. Hole displaced with Seawater - 125.00 % displaced Wellhead work Installed Hanger plug Installed TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree N/D tree and adapter. Tubing hanger threads galled, grind tip from bad LDS, function LDS' s. Equipment work completed Nipple up BOP stack RECEIVE[) Rigged up BOP stack Equipment work completed R / TeStTestedWell controlBoP stackequipment ~m ~P 0 4 ~000 R/U and testing BOP's at report t' e~Ja~kaOil&~asCons. Commil~ion Tested BOP stack ,t~l~0fa~ Tested pipe rams, blind rams, choke and kill line valves, choke and floor safety valves to 250/3000 psi. Tested Hydril to 250/2500 psi. Tested accumulator. Test witnessed by C. Scheve AOGCC. Test well control equipment (cont...) Tested BOP stack (cont...) Tested pipe rams, blind rams, choke and kill line valves, choke and floor safety valves to 250/3000 psi. Tested Hydril to 250/2500 psi. Tested accumulator. Test witnessed by C. Scheve AOGCC. Pressure test completed successfully - 3000.000 psi Facility Date/Time 24 Jan 00 Progress Report PB D Pad Well D-12 Page 3 Rig Nabors 7ES Date 27 March 00 Duration Activity 09:00-10:30 09:00-10:30 10:30 10:30-22:30 10:30-12:30 12:30 12:30-14:00 14:00 14:00-21:30 21:30 21:30-22:30 22:30 22:30-02:00 22:30-00:00 00:00 00:00-02:00 02:00 02:00-03:00 02:00-03:00 03:00 03:00-04:00 03:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00-20:00 06:00-17:00 17:00 17:00-20:00 1-1/2 hr 1-1/2 hr 12 hr 2 hr 1-1/2 hr 7-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 2 hr 1 hr 1 hr 1 hr 1 hr 2 hr 2hr 14hr llhr 3hr Wellhead work Retrieved Hanger plug Pulled TWC w/lubricator. APR 0 4 000 Equipment work completed Pull Gas lift completion, 4-1/2in O.D. ,aJa~aOil& Oaa C°na.C°mm~ Pulled Tubing on retrieval string to 30.0 ft ~6,III~10[~ P/U spear and pulled tubing hanger to floor. 125K up wt. L/D spear Stopped: To change handling equipment Rigged up Tubing handling equipment R/U Nabors casing and HES control line spooling unit. Work completed - Tubing handling equipment in position Laid down 7865.0 ft of Tubing POH L/D 195 jts 4-1/2" tubing, (5) GLM's, SSSV. Cut = 2.4'. Tubing junked due to corrosion. Retrieved 25 rubber clamps and 4 SS bands. Found hole in tubing in pup jt above SSSV. 195 joints laid out Rigged down Tubing handling equipment Equipment work completed 5in. Communication test string workstring run Ran Drill collar to 288.0 ft (6-1/2in OD) P/U (9) DC' s. Stopped: To pick up/lay out tubulars Ran HWDP to 710.0 ft (5in OD) PFU 23 jts HWDP. P/U HES RTTS & SSCV. Set at 28', below 9-5/8" mandrel hanger. Completed run with Retrievable packer to 28.0 ft Perform integrity test Tested Casing - Via annulus Pressure tested 9-5/8" casing to 3000 psi for 30 min, OK. Pressure test completed successfully - 3000.000 psi Wellhead work Tested Seal assembly Closed blind rams and pressured to 3000 psi. 9-5/8" packoff leaked. Suspended pressure test on Seal assembly, observed leak Bled off 1200 psi in 5 min. Nipple down BOP stack Removed BOP stack N/D BOP' s. Wellhead work Removed Seal assembly Attempted to remove 9-5/8" packoff. Back out lock down screws on casing head. 4 broke, 6 seized up, 4 removed successfully. Aborted equipment work Unable to remove packoff. Installed Seal assembly Chase threads and install LDS that were removed. Reinstall gland nuts where possible. (Some LDS broke or bent). ~n Facility PB D Pad Progress Report Well D-12 Page 4 Rig Nabors 7ES Date 27 March 00 Date/Time 25 Jan 00 20:00 20:00-23:30 20:00-23:30 23:30 23:30-03:00 23:30-01:30 01:30 01:30-02:30 02:30 02:30-03:00 03:00 03:00-06:00 03:00-03:30 03:30 03:30-05:30 05:30 05:30-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-09:30 07:00-08:30 08:30 08:30-09:30 09:30 09:30-06:00 09:30-12:00 12:00 Duration 3-1/2 hr 3-1/2 hr 3-1/2 hr 2 hr 1 hr 1/2 hr 3 hr 1/2 hr 2 hr 1/2 hr 1 hr 1 hr 2-1/2 hr 1-1/2 hr lhr 20-1/2 hr 2~ 1/2 hr Activity Equipment work completed Nipple up BOP stack Rigged up BOP stack N/U tubing spool and BOP's. Test to 300 psi. Equipment work completed 5in. Drillpipe workstring run Retrieved Retrievable packer Retrieve HES RTTS. Completed operations Laid down 709.0 ft of HWDP 23 joints laid out Laid down 288.0 ft of Drill collar Stopped: To change handling equipment Run Tubing, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Ran Tubing to 2193.0 ft (4-1/2in OD) Ran 53 jts 4-1/2", L-80, IBT-MOD tubing for circulation string. Stopped: To circulate Rigged down Tubing handling equipment Equipment work completed Fluid system Freeze protect well - 165.000 bbl of Diesel R/U HBR and pump diesel down tubing taking returns up annulus. Completed operations 5in. Drillpipe workstring run Rigged up sub-surface equipment - Retrievable packer P/U and set 9-5/8" RTFS and storm choke on drill pipe. Tested to 500 psi. Released. Equipment work completed Rigged down Surface lines R/D HBR. Blow down lines. Equipment work completed Nipple down BOP stack Removed BOP stack · N/D BOP stack and tubing spool. Cover casing spool, released rig for move to Gwydyr Bay gl. Equipment work completed Rig released 1200 hrs 1/25/2000. RECEIVED RPR 04 000 AiWa Oil & Gas Cor . Facility PB D Pad Date/Time 20 Mar 00 21 Mar 00 09:00-02:00 09:00-02:00 02:00 02:00-04:00 02:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-09:30 07:00-09:30 09:30 09:30-11:00 09:30-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-15:30 12:00-15:30 15:30 15:30-19:30 15:30-19:30 19:30 19:30-06:00 19:30-06:00 22 Mar 00 06:00 06:00-09:30 06:00-08:00 08:00 08:00-09:30 09:30 09:30-11:00 09:30-11:00 11:00 11:00-14:00 11:00-13:30 13:30 13:30-14:00 14:00 14:00-18:00 Progress Report Well D-12 Page 1 Rig Nabors 4ES Date 27 March 00 Duration 17hr 17 hr 2 hr 2 hr 2 hr 2 hr lhr 1 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 3-1/2 hr 3-1/2 hr 4 hr 4 hr 10-1/2 hr 10-1/2 hr 3-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 3 hr 2-1/2 hr 1/2 hr 4 hr Activity Move rig Rig moved 100.00 % At well location - Slot Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Rigged up BOP stack Stopped: To hold safety meeting Nipple up BOP stack (cont...) Rigged up BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi 3-1/2in. Drillpipe workstring run Retrieved Retrievable packer Completed operations pull rtts to surface & lay dn same. Fluid system Circulated at 2200.0 ft circ out freeze protection. (diesel) Hole displaced with Brine - 100.00 % displaced Pull Tubing, 4-1/2in O.D. Laid down 2200.0 ft of Tubing 53 joints laid out Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run rig hes & fih with 8.5" GR/JB to 7865 Completed run with Junk basket/gauge ring from 0.0 ft to 7865.0 ft Run Single completion, 4-1/2in O.D. Ran Tubing to 7865.0 ft (4-1/2in OD) Ran 187its. 4.5" tbg. & space out SAB-3 with 9' pup. Completed run with Permanent packer to 7818.0 ft Wellhead work Installed Tubing hanger install tbg. hanger & rilds. & lay dn landing jt. & verify ability to reverse circ. around unique overshot. Equipment work completed Installed Hanger plug set & test twc. & blow dn lines. Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed RECEIVED Wellhead work Installed Xmas tree install tree & test to 5000 psi. Equipment work completed Removed Hanger plug Equipment work completed Fluid system APR 04 2000 Alaska 0tl & Gas Cons. Commissio AnchoTage Facility PB D Pad Progress Report Well D-12 Page 2 Rig Nabors 4ES Date 27 March 00 Date/Time 14:00-18:00 18:00 18:00-19:30 18:00-19:30 19:30 19:30-22:00 19:30-22:00 22:00 22:00-06:00 22:00-00:00 23 Mar 00 00:00 Duration 4 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 8 hr 2 hr Activity Circulated at 7865.0 ft circ sea h20 treated with 25 gal./100 bbl. Hole displaced with Inhibited brine - 100.00 % displaced Run Single completion, 4-1/2in O.D. Functioned Permanent packer drop ball & set pkr. to 3500 psi. & monitor for 30-min.& bleed to 2000 psi. & psi. annulus to 3000 psi. & monitor for 30-min. ok. Equipment work completed Fluid system Freeze protect well - 170.000 bbl of Diesel shear RP & freeze protect annulus & tbg. Completed operations Wellhead work Installed Hanger plug set bpv & rd cellar & secure well & clean pits. Rig Released & Waiting on Trucks to move back to MPU & hot stack, over well. Equipment work completed RECEIVED APR 04 2000 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~L~ DATE: January 23, 2000 Chairman THRU' Blair Wondzell, P. i. Supervisor FROM' Chuck Scheve,~ ~ SUBJECT: Petroleum Inspector BOPE Test Nabors 7ES PBU D-12 PTD # 180-0015 Sunday, January 23, 2000: I traveled to BPX's D Pad and witnessed the initial BOPE test on Nabors Rig 7ES working over Well D-12. As the attached AOGCC BOPE Test Report indicates, the test lasted 3.5 hours and there were no failures. The testing went very well with the test procedure being practiced by the Nabors crew allowing the testing to be completed in a minimum number of steps. The rig was very clean and all equipment appeared to be in excellent condition. The location was clean and all extra equipment was properly stored. Summary: I witnessed the initial BOP test on Nabors Rig 7ES working over BPX's D-12 well. NABORS 7ES, 1123/00, Test Time 3.5 Hours, No Failures Attachment: BOP Nabors 7ES 1/23/00 X Unclassified Confidential (Unclassified if doc. removed ) BOP Nabors 7ES 1-23-00 CS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: NABORS Rig No. 7ES PTD # SSD Rep.: D-12 Rig Rep.: Set @ Location: Sec. X Weekly Other 80-15 DATE: Rig Ph.# John Rawi 1/23/99 659-4103 Larkin / Coyne T. R. Meridian Um. MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen,: OK Well Sign OK Upper Kelly/IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP PTD On Location Yes Hazard Sec. YES Ball Type Standing Order Posted YES Inside BOP Test Quan. Pressure P/F 1 250 / 3500 P 1 250/3500 P 1 250/3500 P 1 250/3500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln, Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press, P/F 1 250/2500 P 1 250/3500 P 1 250/3500 P 1 250/3500 P 1 250/3500 P 2 250~3500 P 1 250~3500 P N lA MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No, Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3500 P 32 250/3500 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btrs: 5 @2100 2,900 P 1,550 P 0 minutes 30 sec, minutes 15 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 3.5 Hours, Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test Distribution: orig-Well File c - Oper,/Rig C - Database c - Trip Rpt File c -Inspe ,tour.... ~;I'UZ1 L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: ~. 7ES 1-23-00 CS Chuck Scheve STATE OF ALASKA ALASKA ,..-AND GAS CONSERVATION CO,..:~IlSSION REPORT OF SUNDRY WELL OPERATIONS i ;.~erations performed: ~ Operation Shutdown ~ Stimulate ~ Plugging ~ Perorate ~'~;:~ ' ~ Pull Tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Alter Casing 1--1Repair Well [] Other Temporary Suspension 5. Type~:zf. well: 6. Datum Elevation (DF or KB) Development KBE = 71.50' AMSL I--I Exploratory 7. Unit or Property Name [] Stratigraphic Prudhoe Bay Unit [-'] Service 4. Location of well at surface 2930' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UM At effective depth 1579' NSL, 927' WEL, SEC. 23, T11N, R13E, UM At total depth 1580' NSL, 928' WEL, SEC. 23, T11 N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9434 feet 9326 feet 9366 feet 9260 feet Length Size 110' 20" x 30" 2679' 13-3/8" 8381' 9-5/8" Plugs (measured) Junk (measured) 8. Well Number D-12 9. Permit Number / Approval No. 180-015 300-023 10. APl Number 50- 029-20443-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plug set in tubing tailpipe at 7954' (01/00) Cemented MD 14 cu yds Arcticset 110' 3820 cu ft Permafrost II 2706' 1235 cu ft Class 'G', 130 cu ft PF 'C' 8406' 1512' 7" 295 cuft Class 'G' 7914' - 9426' measured 9090'- 9098', 9106' - 9130' ORIGINAL Perforation depth: Sqzd: 9055'- 9085' true vertical 8983' - 8991', 8999' - 9023' Sqzd: 8948' - 8978' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2197'; 4-1/2", 12.6#, L-80 from 7865' - 7965' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) TVD 110' 2704' 8299' 7807'-9318' 9-5/8" Otis 'HCM' Permanent Packer at 7874'; 9-5/8" HES RTTS & SSCV at 29' Treatment description including volumes used and final pressure Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl 14. Prior to well operation: 'Sabsequent to operation: 16. Status of well classifications as: [] Oil [] Gas i--I Suspended . .~ttachments Copies of Logs and Surveys run -~: [] Daily Report of Well Operations REC FEB 11 Bi)(M) Almlm Ol & ~ ~oCommimm~on Casing Pressure Tubing Pressure Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~'~I1~'~ ~ j Title Technical Assistant Ill Prepared By Name/Number: Date ~''~ 0 "~)(~ ~'~i. H,,~,i~, 5~'~-~~28 ,,1~ Submit In Duplicate~ Form 10-404 Rev. 06/15/88 PRUDHOE BAY, ALASKA TO: Anchorage PE's Date: 11/9/00 I FROM: ROMBERG Well Name: D-12 Main Category: WlRELINE Sub Category: RWO 4P9038 Operation Date: 1/9/00 · ' ii D-12 RWO 4P9038 HES #1 SIP---450 IAP=680 OAP=700 WHT=SI WHP=SI MIRU. RIH w/4W' XXN PLUG TO XNLN @ 7932' WLM. SET. POOH. RIH w/41,~'' CHECK-SET TO SAME. POOH. TOOL SHEARED. BLED TUBING FROM 550 PSI TO 440 PSI. (CAME UP TO 460 PSI). RDMO. LEFT WELL SHUT IN (& TAGGED). SUMMARY: SET PLUG IN 41/z'' XN NIPPLE AT 7932' WLM. RAN CHECK-SET TOOL. CAME BACK SHEA~D. BLED TUBING FROM 550 PSI TO 440 PSI. PRESSURE HELD. ESTIMATED COST = $2,700 t,,. Diesel Used INONE I Methanol Used INONE !~ D-12 Tubing Cut 1/10/00 PRUDHOE BAY, ALASKA TO: PBU Reports Group FROM: Scott Bundy Well Name: ID-12 Main Category: I Ri~ Prep Sub Category: ITubing Cut Operation Date: IJanuary 10, 2000 Date: I1/10/00 Est. Cost: $14,300 Job ID#: N/A Cost Code: 4P9038 (9335-070-735) Objective: Chemically cut tubing in preparation for a rig workover. OPERATIONS SUMMARY:. NOTE: All depths correlated to SWS Jewelry log dated 10/10/91. RU SWS. RIH with tubing puncher. Shot 5 holes from 7810' to 7812' elmd. Tubing equalized with IA. RIH with 10' of string shot. Shot from 7846' to 7856' elmd ( covers the shot depth and the anchor setting depth). RIH with 3 3/8" chemical cutter. Cut tubing at 7855' elmd ( 3' below the SWS nipple leaving approx. 7' of stub looking up, cut depth equates to 7865' drillers depth). The severing head indicated that the tool functioned. Based on the condition of the head there is a possibility that a partial cut may have occurred in approximately 30% of the circumference. The 30% in question is distributed in three segments around the head. The general consensus is that the cut was successful. ,, 1/10/00 Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shut In 400 700 650 na na na TIME OPERATION 1300 RU SWS. 1400 Hold Safety Meetin~l. Discuss job objectives with crew. SWS "SAFE" system is being utilized. 1415 Power down. Arm tubing punch. 1425 Pick up toolstring. Stab onto well. PT lubricator with WHP. 1435 RIH with tubing punch (5 shots over 2'). 1525 Tie-in to SWS Jewelry Log (10/10/91). CCL to top shot = 19'. 1540 Position tubing punch at 7810 elmd' - CCL @ 7791' elmd. (upper portion of first full joint above the SWS-nipple @ 7862'). WHP = 400 psig lAP = 700 psig 1545 Fire tubing punch, lAP and WHP indicate that punch fired and communication is established. WHP = 500 psig 1547 Log off. POH with tubing punch. 1620 At surface. All shots fired. 1625 MU string shot. 1645 RIH with 10' of string shot. CCL to top of string shot = 16'. 1725 Tie-in and position across the target interval (7846' to 7856' elmd). CCL @ 7830' elmd. 1735 Fire string shot. Log off. POH. D-12 Tubin(~ Cut 1/10/00 1 D-12 Tubing Cut 1/10/00 1800 At surface - good burn indicated. 1825 Make-up ( 3 3/8" dia.) chemical cutter. CCL to severing head = 25.8'. Anchor to severing head = 9', 1900 RIH with cutter. 2020 Tie-in and position cutter at 7855' elmd (3' below upper SWS nipple). CCL @ 7829.2' elmd. 2045 Fire cutter. Good indications at surface. 2050 POH with cutter. 2200 At surface - cutter head appears to have made a good cut over at least 70% of the circumference. 2215 Secure well. Rig down SWS. 2230 Notify Pad operator and PCC. Well is shut in. Final Well Status Whp lap Oap GIp FIp Fit psi psi psi psi psi °F Flowing 650 700 650 na na na D-12 Tubina Cut 1/10/00 2 PRUDHOE BAY, ALASKA TO: PE REPORT GROUP FROM: YEAGER PAOLINO WELL NAME: ID-12 MAIN CATEGORY SUB CATEGORY IPRESSURE TEST I OPERATION DATE 101/11/00 DATE: I1/11/00 OPERATION: WITH PLUG IN TAIL PIPE AND TUBING CUT, PRESSURE TEST TO 3000 PSI IN PREP FOR RIG WORK OVER INITIAL PRESSURE: SIWHP = 660 PSIG, IAP = 680 PSIG, OAP = 680 PSIG. 0130 HRS: MIRU HB&R, SAFETY MEETING AND PRESSURE TEST HARDLINE TO 3500 PSI Time WHP lAP OAP Fluid BPM Total Fluid COMMENTS Type BBIs Temp 0159 660 680 680 DSL 1 0 AMB START PUMPING DOWN I.A. 0204 1020 1175 700 DSL 5 20 AMB PRESSURE SLOWLY COMING UP 0209 1900 2000 740 DSL 5 40 AMB 0212 3000 3060 760 DSL 5 49 AMB SHUT DOWN AND MONITOR 0227 2680 2620 760 PUMP BACK UP 0228 3060 3000 780 DSL 1 51 AMB SHUT DOWN AND MONITOR 0243 2680 2620 840 PUMP BACK UP 0247 3030 3060 850 DSL 1.25 52 AMB SHUT DOWN AND MONITOR 0302 2730 2675 1060 PUMP BACK UP 0305 3030 3100 1060 DSL 1 53 AMB SHUT DOWN AND MONITOR 0335 2930 2940 1480 GOOD TEST, BLEED BACK 0350 820 900 940 BLED BACK 23 BBLS, RIG DOWN HB&R Final Pressures: SIWHP = 820 PSIG, IAP = 900 PSIG, OAP = 940 PSIG. Fluid Summary: PUMPED 53 BBLS DIESEL CONCLUSION: D-12 PASSED PRESSURE TEST AFTER A COUPLE OF BUMP UPS. OAP WAS SLOWLY COMING UP DURING ENTIRE OPERATION Facility PB D Pad Progress Report Well D-12 Page 1 Rig Nabors 7ES Date 31 January 00 Date/Time 21 Jan 00 22 Jan 00 00:00-06:00 00:00-04:30 04:30 04:30-06:00 06:00 06:00-06:00 06:00-08:30 08:30 08:30-16:00 16:00 16:00-20:00 20:00 20:00-22:30 22:30 22:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00-11:00 06:00-08:00 08:00 08:00-10:30 10:30 10:30-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-13:00 Duration 6 hr 4-1/2 hr 1-1/2 hr 24 hr 2-1/2 hr 7-1/2 hr 4 hr 2-1/2 hr 6 hr 1-1/2 hr 1-1/2 hr 5 hr 2hr 2-1/2 hr 1/2 hr 1 hr 1 hr 1 hr Activity Move rig Rigged down Drillfloor / Derrick R/D rig floor. Bridle up. Lower pipe chute. Lower derrick. Secure lines. Prep rig for rig move. Equipment work completed Rig moved 5.00 % Move rig off West Beach 07. Prepare to move rig down road. Rig off station Move rig (cont...) Rigged down Lines / Cables Prepare rig for move on road. Move rig to end of pad. Wait 1/2 hr on security. Equipment work completed Rig moved 75.00 % Moved sub base to D-pad. Rig off station Rigged up Drillfloor / Derrick Prepare and raise derrick. Raise pipe chute. Equipment work completed Rig moved 90.00 % Set mats and herculite. Spot sub on D- 12. At well location - Cellar Rig moved 100.00 % Set mats and herculite for pits. Spot pits. Berm pits and sub base. At well location - Cellar Rigged up Drillfloor / Derrick Finish R/U top drive and rig floor. Rigged up Drillfloor / Derrick Spot and berm cuttings tank. Hook up geramino line, mud lines. Hook up top drive and rig up rig floor. Take on seawater. Move rig (cont...) Rigged up Drillfloor / Derrick (cont...) Spot and berm cuttings tank. Hook up geramino line, mud lines. Hook up top drive and rig up rig floor. Take on seawater. Equipment work completed Rig accepted at 0800 hrs 1/22/2000. Rigged up Surface lines Hook up circ hoses to tree. R/U drill site maint lubricator. Stopped: To hold safety meeting Held safety meeting Hold pre-spud safety and environmental meeting. Reviewed pre-spud checklist. Reviewed well commitment to safety/enviromnenta~EG~,~l~L Completed operations Wellhead work Removed Hanger plug Pulled BPV with lubricator. Equipment work completed Test well control equipment Progress Report Facility PB D Pad Well D-12 Page 2 Rig Nabors 7ES Date 31 January 00 Date/Time 23 Jan O0 12:00-13:00 13:00 13:00-15:00 13:00-13:30 13:30 13:30-15:00 15:00 15:00-17:00 15:00-17:00 17:00 17:00-23:00 17:00-18:30 18:30 18:30-23:00 23:00 23:00-03:30 23:00-00:00 00:00 00:00-03:30 03:30 03:30-05:00 03:30-05:00 05:00 05:00-06:00 05:00-06:00 05:00-06:00 06:00-09:00 06:00-09:00 09:00 Duration 1 hr 2 hr 1/2 hr 1-1/2 hr 2 hr 2 hr 6 hr 1-1/2 hr 4-1/2 hr 4-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 3 hr 3 hr Activity Installed High pressure lines Finished install circ lines from tree to choke. Equipment work completed Fluid system Held safety meeting Held Pre-spud safety/environmental meeting with crew g2. Completed operations Circulated at 7865.0 ft Pressure test lines to choke, 1500 psi. Circ diesel freeze protect thru choke and gas buster to slop tank. Operation stopped due to Incident Spill. Suspend operations Held drill (Spill) Stopped to clean up diesel spill. Diesel plume from gas buster exhaust dispersed into gusting winds. Clean up snow/ice on pad. Completed operations Fluid system Circulated at 7865.0 ft Finish circ diesel from annulus. Stopped: To flowcheck well Reverse circulated at 7865.0 ft Reverse circ diesel from inside tubing. Cont'd to circ well volume, well static. Hole displaced with Seawater - 125.00 % displaced Wellhead work Installed Hanger plug Installed TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree N/D tree and adapter. Tubing hanger threads galled, grind tip from bad LDS, function LDS's. Equipment work completed Nipple up BOP stack Rigged up BOP stack Equipment work completed Test well control equipment Tested BOP stack R/U and testing BOP's at report time. Tested BOP stack Tested pipe rams, blind rams, choke and kill line valves, choke and floor safety valves to 250/3000 psi. Tested Hydril to 250/2500 psi. Tested accumulator. Test witnessed by C. Scheve AOGCC. Test well control equipment (cont...) Tested BOP stack (cont...) Tested pipe rams, blind rams, choke and kill line valves, choke and floor safety valves to 250/3000 psi. Tested Hydril to 250/2500 psi. Tested accumulator. Test witnessed by C. Scheve AOGCC. Pressure test completed successfully - 3000.000 psi Progress Report Facility PB D Pad Well D-12 Page 3 Rig Nabors 7ES Date 31 January 00 Date/Time 24 Jan 00 09:00-10:30 09:00-10:30 10:30 10:30-22:30 10:30-12:30 12:30 12:30-14:00 14:00 14:00-21:30 21:30 21:30-22:30 22:30 22:30-02:00 22:30-00:00 00:00 00:00-02:00 02:00 02:00-03:00 02:00-03:00 03:00 03:00-04:00 03:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00-20:00 06:00-17:00 17:00 17:00-20:00 Duration 1-1/2 hr 1-1/2 hr 12hr 2 hr 1-1/2 hr 7-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 2hr 1 hr 1 hr 1 hr lhr 2hr 2 hr 14hr llhr 3hr Activity Wellhead work Retrieved Hanger plug Pulled TWC w/lubricator. Equipment work completed Pull Gas lift completion, 4-1/2in O.D. Pulled Tubing on retrieval string to 30.0 ft P/U spear and pulled tubing hanger to floor. 125K up wt. L/D spear Stopped: To change handling equipment Rigged up Tubing handling equipment R/U Nabors casing and HES control line spooling unit. Work completed - Tubing handling equipment in position Laid down 7865.0 ft of Tubing POH L/D 195 jts 4-1/2" tubing, (5) GLM's, SSSV. Cut = 2.4'. Tubing junked due to corrosion. Retrieved 25 rubber clamps and 4 SS bands. Found hole in tubing in pup jt above SSSV. 195 joints laid out Rigged down Tubing handling equipment Equipment work completed 5in. Communication test string workstring run Ran Drill collar to 288.0 ft (6-1/2in OD) PULI (9) DC's. Stopped: To pick up/lay out tubulars Ran HWDP to 710.0 ft (5in OD) P/U 23 jts HWDP. P/U HES RTrS & SSCV. Set at 28', below 9-5/8" mandrel hanger. Completed run with Retrievable packer to 28.0 ft Perform integrity test Tested Casing - Via annulus Pressure tested 9-5/8" casing to 3000 psi for 30 min, OK. Pressure test completed successfully - 3000.000 psi Wellhead work Tested Seal assembly Closed blind rams and pressured to 3000 psi. 9-5/8" packoff leaked. Suspended pressure test on Seal assembly, observed leak Bled off 1200 psi in 5 min. Nipple down BOP stack Removed BOP stack N/D BOP' s. Wellhead work Removed Seal assembly Attempted to remove 9-5/8" packoff. Back out lock down screws on casing head. 4 broke, 6 seized up, 4 removed successfully. Aborted equipment work Unable to remove packoff. Installed Seal assembly Chase threads and install LDS that were removed. Reinstall gland nuts where possible. (Some LDS broke or bent). Progress Report Facility PB D Pad Well D-12 Page 4 Rig Nabors 7ES Date 31 January 00 Date/Time 25 Jan 00 20:00 20:00-23:30 20:00-23:30 23:30 23:30-03:00 23:30-01:30 01:30 01:30-02:30 02:30 02:30-03:00 03:00 03:00-06:00 03:00-03:30 03:30 03:30-05:30 05:30 05:30-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-09:30 07:00-08:30 08:30 08:30-09:30 09:30 09:30-06:00 09:30-12:00 12:00 Duration 3-1/2 hr 3-1/2 hr 3-1/2 hr 2 hr 1 hr 1/2 hr 3hr 1/2 hr 2hr 1/2 hr 1 hr 1 hr 2-1/2 hr 1-1/2 hr lhr 20-1/2 hr 2-1/2 hr Activity Equipment work completed Nipple up BOP stack Rigged up BOP stack N/U tubing spool and BOP's. Test to 300 psi. Equipment work completed 5in. Drillpipe workstring run Retrieved Retrievable packer Retrieve HES RTTS. Completed operations Laid down 709.0 ft of HWDP 23 joints laid out Laid down 288.0 ft of Drill collar Stopped: To change handling equipment Run Tubing, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Ran Tubing to 2193.0 ft (4-1/2in OD) Ran 53 its 4-1/2", L-80, IBT-MOD tubing for circulation string. Stopped: To circulate Rigged down Tubing handling equipment Equipment work completed Fluid system Freeze protect well - 165.000 bbl of Diesel R/U HBR and pump diesel down tubing taking returns up annulus. Completed operations 5in. Drillpipe workstring run Rigged up sub-surface equipment - Retrievable packer PFU and set 9-5/8" RTTS and storm choke on drill pipe. Tested to 500 psi. Released. Equipment work completed Rigged down Surface lines R/D HBR. Blow down lines. Equipment work completed Nipple down BOP stack Removed BOP stack N/D BOP stack and tubing spool. Cover casing spool, released rig for move to Gwydyr Bay #1. Equipment work completed Rig released 1200 hrs 1/25/2000. STATE OF ALASKA -"~- ALASKA ~IL AND GAS CONSERVATION CG, v, MISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: I~ Development [] Exploratory J--I Stratigraphic [--I Service 4. Location of well at surface 2930' SNL, 1067' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11 N, R13E, UM At effective depth 1579' NSL, 927' WEL, SEC. 23, T11N, R13E, UM At total depth 1580' NSL, 928' WEL, SEC. 23, T11N, R13E, UM ORIGINAL Datum Elevation (DF or KB) KBE = 71.50' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-12 9. Permit Number 180-015 10. APl Number 50- 029-20443-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9434 feet Plugs (measUred) true vertical 9326 feet Effective depth: measured 9366 feet Junk (measured) true vertical 9260 feet Casing Plug set in tubing tailpipe at 7954' (01/00) Length Size Cemented M D TVD Structural Conductor 110' 20" x 30" 14 cu yds Arcticset 110' 110' Surface 2679' 13-3/8" 3820 cu ft Permafrost II 2706' 2704' Intermediate 8381' 9-5/8" 1235 cu ft Class 'G', 130 cu ft PF 'C' 8406' 8299' Production Liner 1512' 7" 295 cu ft Class 'G' 7914' - 9426' 7807' - 9318' RECEIVED Perforation depth: measured 9090'- 9098', 9106'-9130' Sclzd: 9055'- 9085' true vertical 8983'- 8991', 8999'- 9023' ~aSJg3 0il & GasC0ns. C0_l!L~;E!i Sqzd: 8948'- 8978' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2197'; 4-1/2", 12.6#, L-80 from 7865' - 7965' Packers and SSSV (type and measured depth) 9-5/8" Otis 'HCM' Permanent Packer at 7874'; 9-5/8" RTTS SSCV 29' 13, Attachments j~] Description summary of proposal [] Detailed operations program J--J BOP sketch 14. Estimated date for commencing operation I 15. Status of well classifications as: I January 24,2000 16. If proposal was verbally approved -' Oil [] Gas [] Suspended Blair Wondzell Name of approver contact Engineer Name/Number: Date approved Scott Kolstad, 564-5347 James Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~----------"~,,_._-¢--~ ,. ~ Dan Stone Title Senior Drilling Engineer Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance J Approval No...~)~ ' ~)~ Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL SIGNED BY ~.oo~~Commissioner Approved by order of the Commission Robc,'t ,%'. C;-,,i~enson corm 10-403 Rev. 06/15/88 Date Submit In Triplicate A a_ ka ared rvices rilling RECEIVED To: AOGCC From: Scott Kolstad Subject: JAN 26 J O00 Prepare Well D-12 for Temporary Suspension Operations BP Exploration / ARCO Alaska Inc. Date: January 24, 2000 This memo is written to provide preliminary information prior to submission of Sundry form 403 as a description of the proposed temporary suspension program on well D-12. The purpose of this suspension is to allow removal (by drilling out) of at least 8 of the 9-5/8" lock down screws as a non-rig activity. Verbal approval was granted by Blair Wondzell this afternoon, 1/24/00. Summary: Activity to date on well D-12 has involved the pre-rig work scope detailed below plus the removal of the original tubing string and pressure integrity testing to 3000 psi of the 9-5/8" casing down to a plug set in the tailpipe at 7954' depth. The current ongoing activity is the removal and replacement of the 9-5/8" casing pack off which requires removal of the lock down screws for that pack off. The removal of the lock down screws is not progressing favorably and it appears that at least 8 of these screws have twisted off and will require drilling out for their replacement. In an effort to optimize rig work activity, the following is proposed: 1. NU the BOP stack. 2. Pull the RTTS, DP, and DC below. 3. RIH with ~ 2,200' of new 4 ~", 12.6#/ft, L-80, IBT-Mod tubing below a HFS RTTS storm packer and SSC valve. 4. Diesel freeze protect the tubing and inner annulus below a set and tested (to 500 psi) RTTS storm packer and storm valve to provide a secondary barrier for well control. The fluid below the diesel freeze protection is 8.5 ppg sea water and casings in the well have been successfully pressure tested to 3000 psi. 5. The drilling rig will be released and moved to the next well on the drilling schedule. 6. When the rig is gone, work crews will install weather protection and drill out the remaining lock down screws, perform change out of the 9-5/8" pack off, re-install lock down screws and then pressure test the pack off system. 7. Within 90 days a rig will return to install the new tubing string and complete well work. A summary of the originally planned work scope is listed below: Planned Pre-Rig Work 1. Test the 9 5/8" mandrel pack off and tubing hanger (through test port) to 5000 psi. If the pack off on the 9-5/8" tests OK, completely back out and check each lock down screw for breakage (check one at a time). 2. Drift the 4-1/2" 12.6# tubing through the tubing tailpipe ( to 7955') 3. Set a plug in the tailpipe in the "SWN" nipple at 7954'. 4. Cut the 4-1/2" 12.6#, L-80 tubing with a chemical cutter at just below the "SWS" nipple located at 7862'. It is recommended that a tubing punch be made above the planned cut point to balance fluids in the well and produce a higher success rate on the chemical cut. Ensure that a stub of at least 6' will be left below the cut prior to the next connection below the cut. If it is not possible to cut such that 6' of clean pipe is left below the cut, move the cut point upwards above the "SWS" nipple to a full joint. 5. Test the 9-5/8" casing to 3000 psi against production packer, be sure to hold equivalent pressure on the 4-1/2" tubing to prevent tubing collapse. Set a BPV in preparation of hi,: rig move. Assure annuli are freeze protected to near 2000' depth. There are no surface shut ins required for rig moves. Rig Workover Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean sea water, confirm well is dead. (Note: there are tubing holes 1900-2100'). 2. Pull 4 V2" tubing down to the tubing cut at 7865'+/-. Pressure test the 9-5/8" to 3000 psi for 30 minutes against the packer and plug in tailpipe. 3. Replace 9-5/8" pack off if necessary during pulling of tubing. Step #3 is the current activity as of 1/24/2000 4. Make a GR/JB run on wireline to the tubing stub (7865' approx.). Follow with csg scraper if GR/JB won't go down. 5. PU Unique tubing overshot, WOA tailpipe (with "X" nipples, no "XN" nipples" and use the Halliburton high- pressure RHC profile) and new 4-1/2", 12.6g, L-80, IBT-Mod tubing completion with GLMs. Overshot the tubing stub at 7865' and set packer. 6. Test tubing and annulus to 3000 psi. 7. Freeze protect permafrost zone thru top GLM. 8. Set BPV, ND BOPE, NU and test tree. RDMO. Will have post rig wireline removal of the plug in the tailpipe which will be set in the pre-rig work. Mechanical Information At the present time the 9-5/8" casing has been successfully pressure tested to 3000 psi from below the well head system down to the plug set in the tailpipe. RECEIVED .: TREE: /~'"~' KB. E' ~: 71.50' WELLHEAD: OCT --.._ i. BF. EL~:v = 47.00' ACTUATOR: BAKER 9-5/8" DV Packer 12612' I ~ ~ ~valveHalliburt°nset justRTTSbelowandsurfaceSUbSurface control 13-3/8", 72 #/ft, 12706' I J L-80, BTRS. ..~ 4-1/2", 12.6 #/ft, L-80, IBT-MODTUBING KOP: 2000' i TO + / - 2200' MAX ANGLE: 22°13700' ! "'"'"'"~s I i el freeze protect to +/- 2200' ..I 8.5 ppg sea water I I 9 5~8" and tubing plug I tested to 3,000 psi for 30 minutes 4-1/2", 12.6 #/ft, L-80, TDSTUBING TUBING ID:: 3.958" _ ...... /' CAPACITY: .0152 BBL/FT Cut tubing near 7865' ~ c ~ ~ Rt. Hand Release "SAP" Latch 7873' i~~ii, I~ -- 9-5/8" OTIS HCM Perm. i Packer (3.85" ID) 7874' TOP OF 7" LINER I 7914'1 _ 4-1/2" Parker"SWS" Nipple 17933' I 7" BOT 4-1/2" Parker "SWN" Nipple 7954' (3.725" ID) I Set plug in tailpipe ~ ,_-- 4-1/2"WLEG , 7965' (5.50" OD, 3.854" ID) 7955' ELMD profile at 7954' 95/8", 47#/ft, L-80, BTRS 18406' I--· k pERFORATION SUMMARY REF LOG: SWS-BHCS-5-14-80 MARKER JOINT I o~n I .ql7FRPF INTI::I:IVAI 3 1/8" 4 9055 - 9085' SQUEEZED ,, 4 9090 - 9098' Sqz/Reshot ,, 4 9106 - 9116' Sqz/Reshot " 4 9116- 9130' Sqz/Reshot i , RECEIVED JAN 26 2000 Andtorage PBTD I 9366' I-- 7"29#/ff, I 9426' I~ L-80, BTRS DATE REV. BY COMMENTS PRUDHOE BAY UNIT 5/19/80 INITIAL COMPLETION WELL: D-12 t'43-23-11-13~ 4/12/81 1981 RWO FOR LEAKING PACKER APl NO: 50-029-20443 lO-3-91 FARGO RWOTBG CHANGEOUT ~l=C 23 · TN 11N · RGr: 13E 4-12-93 GM ADD PERFS BP Exploration/Alaskal REC EIVED APR 2. 9 1994 Alaska Oil & Gas Ce~. ~1~~ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date · . Sent by: 21 April 1994 Transmittal of Data Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1PLS STATIC FINAL BL PLS STATIC RF SEPIA 51- ,2-q M-09 PLS STATIC FINAL BL i PLS STATT~ RF SEPIA ,1 PLS STATIC FINAL BL /1 PLS STATIC RF SEPIA s-2o PLS STATIC FINAL BL PLS ST~ RF SEPIA O~ ,l._C[Cj S-37 (32-35-12-12) /1 PLS STATI/~ FINAL BL I PLS S~2~TIC RF SEPIA 0-0% D-11 i PLS STATIC FINAL BL /1 PLS S~ RF SEPIA ~'k~-I ~) R-22 ~iPLS STATI/~FINAL BL PLS ST4~TIC RF SEPIA ~[_~_~ M-04 (23-31-12-13) i PLS STATIC FINAL BL /1 PLS S~H~C RF SEPIA ~-J~% R-23 (42-33-12-13) JPLS STATIC FINAL BL PLS S~C RF SEPIA ~lO0 U-14 (11-20-11-13) 1PLS STATIC FINAL BL 1 PLS ST4~C RF SEPIA 1CN/GR FINAL BL CN/GR FINAL RF SEPIA ~O'""t~--. F-14 (33-35-12-13) 1PFC/GR/CCL FINAL BL PFC/GR/CCL RF SEPIA Run # 1 Run $ i Run # 1 Run # i Run # 1 Run # i Run # 1 Run # I Run # 1 Run # i Run # 1 Run ~ i Run # 1 Run ~ i Run # 1 Run ~ 1 Run # 1 Run ~ i Run # 1 Run ~ I Run # Run # i Run # 1 Run ~ 1 ECC No. 5856.06 2187.03 6169.00 6173.00 5879.06 5617.05 4880.03 2097.05 6102.01 6014.02 5810.02 959.04 Cont/ ~--~ C-38 (41-18-11-14) "~ U{~ D-09 ~Q~5~ D-27 (24-14-11=13) ~lk~ Z-28 ~?_-_- "~ A-23 1. PFC/PERF FINAL BL ~ PFC/P~,RF RF S~.PIA PFC/PERF FINAL BL PFC/PERF RF SEPIA 1-PLS STATIC FINAL BL /1 ~LS s~c RF S~,PIA 1PL STATIC FINAL BL 3~L~STATIC RF SEPIA .1PLS FINAL BL / /1PLS FINAL RF SEPIA Run # 1 5785.02 Run # 1 Run # 1 5132.01 Run # 1 Run # 1 4979.03 Run # 1 Run # 1 6162.00 Run # 1 Run # 1 5783.03 Run # 1 I Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA a~,.,,~, OIL AND GAS CONSERVATION COMMISb ,.I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well . Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 ~t. Location of well at surface 2350' NSL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UPM At effective depth 1579' NSL, 927' WEL, SEC. 23, T11N, R13E, UPM At total depth 1580' NSL, 928' WEL, SEC. 23, T11 N, R 13E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Service RECEIVED APR 1 9 1994 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) KBE = 71.50 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number D- 12 (43-23-11-13) PBU 9. Permit number/approval number 80-15 / 10. APl number 50- 029-20443 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9434 feet BtG~ 9326 feet 9363 feet BKB 9255 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Structural - Conductor 110 Surface 2681 Intermediate 8381 Production -- Liner 1513 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 14 c.y. 135 135 3820 c. f. 2706 2704 1264 c. f. 8406 8298 20x30 133/8 9 5/8 : 7 295 c.f. 9055'-9085', 9090559098', 9106559130' 7913-9426 7805-9316 true vertical subsea Tubing (size, grade, and measured depth) 4-1/2', 12.6#, L-80, TDS tubing to 9765'MD Packers and SSSV (type and measured depth) 9 5/8" Otis 'HCM' Permanent Packer @ 7874'MD, 4-1/2' Otis SVLN @2094'MD 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re.Dresentative D~.ily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2251 .~" 13514 306 0 397 2891 ~/ 13734 394 0 432 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~/l~,~a~ ~ ~ ~ Title SeniorTechnicalAssistantl Form 10-404 ~e~ 06)15/88 // 16. Status of well classification as: Oil X Gas Suspended .. Service SUBMIT IN DLFPLI6ATEN ~' 4/12/93 WELL D-12(43-23-11-13) Reperf The following interval were reperforated using 3 3/8" guns, 4 SPF, 60° orientation and 90° phasing. 9090' - 9098' MD fjh 12/21/93 R£C£1V D ap~ 1 9 1994 Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 15 April 1994 RE: Transmittal of Data Sent by: ANCH. EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL H-33 (32-21-11-13) ~" ~)% W-08 (11-26-11-12) ~'~ K-07 (23-33-12-14) # DESCRIPTION Jl DIFLCN LDWG TAPE+LST ~ PDK/GR LDWG TAPE+LST jl CN/GR LDWG TAPE+LIST ~/1 CN/GR LDWG TAPE+LIST ECC No. Run # 1 6178.00 Run # 1 4117.01 Run # 1 3770.02 Run # 1 5810.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP/PBU ~. OGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at ~A-04~~'O~ PFC 04/07/93 91 ~-F~ A-23 _ ~O PDK-100 04/06/93 91 %' A-24~-~ PFC 04/04/93 91 ,~ B-07.~J\~ PFC 04/17/93 91 B-15'%'% A PRODUCTION LOG 04/16/93 91 B-34~'~..'! PFC 04/15/93 91 ~0C-26~ PFC 04/11/93 91 ~ D-i~' P~C 04/12/9~ 91 \E-10" PRODUCTION LOG 04/17/93 91 E-11~~ PRODUCTION LOG 04/14/93 91 F-i~'~' CCL/PERF 04/06/93 91 .~H-17 ,~ PFC 04/13/93 91 ~ $-2~ PFC 04/06/93 91 ,~J-15 ~% LEAK DET 04/15/93 91 ~ S-15~~'' PRODUCTION LOG 04/04/93 91 ~.\~-35 ~ P~C 04/08/93 #1 ~ X-02~ PRODUCTION LOG 04/16/93 91 Y-15~~ PRODUCTION LOG 04/10/93 91 Y-1 PRODUCTION LOG 04/10/93 91 DATE: 04/21/93 T# 84491 below. If you have any (907) 564-4004. 10500.00-10893.00 ATLAS 11050.00-11495.00 ATLAS 10754.00-11037.00 ATLAS 11550.00-11800.00 ATLAS 9180.00- 9450.00 ATLAS 11600.00-11950.00 ATLAS 11371.00-1].795.00 ATLAS 8700.00- 9200.00 ATLAS 11450.00-11694.00 ATLAS 10350.00-10705.00 ATLAS 9985.00-10240.00 ATLAS 10280.00-10670.00 ATLAS 9604.00- 9920.00 ATLAS 11000.00-11500.00 ATLAS 3000.00-11610.00 ATLAS 9600.00- 9900.00 ATLAS 9500.00- 9920.00 ATLAS 9930.00-10320.00 ATLAS 2200.00-10280.00 ATLAS 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 II !1 II II I! II II II Il Il II II II Ill Information Control~ ~L Well Records ~~ ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519.6612 (907) $61-5111 3 DATE: 12/15/92 T# 84175 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. - ~ 6~!~ CC-02A ~PDK-100~ (~"RR~3 12/06/92 #1 D-12~-/~ PRODUCIBILITY 12/08/92 #1 S-27 ~,,~ PRODUCIBILITY 12/08/92 #1 Y-18^~,~4~ ' PRODUCIBILITY 12/07/92 #1 2500.00- 3564.00 ATLAS 5 " 8900.00- 9280.00 ATLAS 5 " 10500.00-10872.00 ATLAS 5 " 10840.00-11178.00 ATLAS 5 " Information Control Well Records RECEIVED DEC 2 2 1992. Alaska 011 & Gas Cons. Commission Anchorage ,,~-"-,, STATE OF ALASKA f~-'"'~ AL ,A OIL AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIO I Stimulate X Plugging .... Perforate x Alter casing Repair well 5, Type of Well: Development X Exploratory Stratigraphic ,, Service 9434feet Plugs (measured) 9326feet 1. Operations performed: Operation shutdown Pull tubing ' 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, A. nchorage, Alaska 99519-6612 4. Location of well at surface 2350'NSL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UPM At effective depth 1579' NSL, 927' WEL, SEC. 23, T11N, R13E, UPM At total depth 1580' NSL, 928' WEL, SEC. 23, T11N, R13E, UPM 'i 2. Preseni well condition' summary Total depth: measured true vertical BKB Other 6, Datum elevation (DF or KB) KBE = 71,50 AMSL feet 7, Unit or Property name Prudhoe Bay Unit 8. Well number D-12 (43-23-11-13) PBU 9, Permit number/approval number 80-15/ 10. APl number 50- 029-20443 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9366feet Junk (measured) BKB 9260feet Casing Structural Conductor Surface Intermediate Production Liner PerfOration depth: measured Length Size Cemented .. 110 20x30 14c. y. 2681 13 3/8 3820 c.f. 8381 9 5/8 1264 c.f. .. 1513 7 295 c.f. 9055'-9085', 9090'-9098', 9106'-9130' Measured depth 135 27O6 8406 7913-9426 True vertical depth BKB 135 2704 8298 7805-9316 true vertical subsea Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TDS tubing to 9765'MD Packers and SSSV (type and measured depth) g 5/8" Otis 'HCM' Permanent Packer@ 7874'MD, 4-1/2" Otis SVLN @2094'MD 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 0 CT 2 1 1992 AJasJ(a 0JJ & ~1.~ ctln~_ ~nmml.~ion 14. Prior to well operation Subsequent to operation 15. Attachments Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1130 ~ 6304 23 0 1460 j 2545 3O 0 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations .>4_ Oil X Gas Suspended Signed ~,, .~~ ~/~'~--~ .~7/~~ Title SeniorTochnicalAssistantl Form 10-404 Rev 06/15/88 / Anch0ra Tubln~ressure 2218 1081 Service WELI~ D-12(43-23-11-13~ CTUWO/Renerf 09/14/91 CTUWO laid plug for RWO using the following fluids: 587 bbls PW(W/ 2% SURF) to load well 5 bbls EW(Preflush) 16 bbls Cement 16 bbls EW(Spacer) 65 bbls PW 32 bbls MEOH (Freeze Protection CT) 80 bbls MEOH (Freeze Protection Well) Well cleaned out to 8720' 250 bbls load fluid behind pipe CEMENT: 15.5 ppg class g cement containing, .2% CFR-3, .12%HR-12,.15 GAL/SK HALAD-344 L 09/21/91 The following intervals were reperforated using 3 3/8" guns, 4 SPF, random orientation and 120° phasing. 9106'- 9130' MD 7/18/92 fjh REEEIVED Gao Cons. Gommission gnchorago ALasKA OIL AND GAS CONSERVATION COMMIS~,,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate AL Pull tubing X Alter casing Repair well Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 2350' NSL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UPM At effective depth 1580'NSL, 927'WEL, SEC. 23, T11N, R13E, UPM At total depth 1580' NSL, 928' WEL, SEC. 23, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 9434 feet true vertical BKB 9326 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 71.50 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-12(43-23-11-13) 9. Perr~it number/approval number 80-15~Conservation order 258 10. APl number 50- 029-20443 'i 1. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured 9363 feet true vertical BKB 9255 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size true vertical Tubing (siZe, grade, and measured depth) Cemented Measured depth True vertical depth RECEIVED MAY - 5 199 Alaska 0il & Gas Cons. Comm%sstot~ 4-1/2", 12.6#, L-80, TDS tubing to 9765'MD Anchorage Packers and SSSV (type and measured depth) 9-5/8" Otis 'HCM' Permanent Packer @ 7874'MD, 4-1/2" Otis SVLN @ 2094'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby~;?ify that the foregoing is true and correct to th,~t of my knowledge. Signed /~.x--~,.. y~,_~ C ;? Title Workover Engineer Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ACTIVITY SUMMARY for WEL_~ PROJECT 145093 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : D-12 Page: 1 DRLG RIG : NONE WO/COMP RIG: DOYON 16 (COMP) KILL: 1.5 NU ND: 4.0 OTHER: 2.0 PL TBG: 10.5 09/30/91 ( 1) L/D 7" TBG. MW: 8.5 Seawater TD: 0 MOVE RIG TO D-12. RIG ACCEPTED @ 14:00 HRS, 9/29/91. CIRC PB: 0 OUT DIESEL. N/D TREE. N/U BOPE. TEST BOPE. PULL HGR. SUPV:JCL CIRC. POOH, L/D 7" TBG. (145093) DAILY: $ 24,515 CUM: $ 24,515 EFC: $ 735,000 (COMP) PL PBR: 9.5 PL PKR: 14.5 10/01/91 ( 2) POOH W/ PKR. MW: 8.5 Seawater TD: 0 RIH W/ OVERSHOT. FISH FOR SLICK STICK. POOH W/ SAME. RIH PB: 0 W/ MILL. MILL ON PKR. CIRC. POOH. RIH W/ SPEAR. FISH SUPV:JCL FOR PKR. POOH. (145093) DAILY: $ 247,497 CUM: $ 272,012 EFC: $ 735,000 (COMP) CLN OUT: 6.5 NU ND: 5.5 OLD PROB: 9.0 PL PKR: 2.5 TEST CSG: 0.5 10/02/91 ( 3) MILL ON JUNK IN HOLE MW: 8.5 Seawater TD: 0 POH WITH FISH. L/D PACKER & TAIL PIPE. INSTALL NEW PB: 0 PACKOFF AND TEST SAME. TEST BOPE. TEST CASING. RIH TO TOP SUPV:NJS OF CEMENT @8575'. CLEAN OUT CEMENT TO 8820'. TAG UP ON JUNK. REV CIRC. POOH. RIH W/MILL. MILLED ON JUNK @8871' o (145093) DAILY: $ 39,565 CUM: $ 311,577 EFC: $ 735,000 (COMP) CLN OUT: 15.0 OLD PROB: 8.0 RUN PKR: 1.0 10/03/91 ( 4) RUN GAUGE RING JUNK BASKET MW: 8.5 Seawater TD: 0 CLEAN OUT JUNK/FILL TO 9363'. CIRCULATE. POH. RIH WITH PB: 9363 SCRAPER. REV CIRC. DISPLACE WELL WITH SEAWATER. POH. RIG SUPV:NJS UP CAMCO. RIH W/GR/JB. (145093) DAILY: $ 26,293 CUM: $ 337,870 EFC: $ 735,000 (COMP) RUN COMP: 17.0 10/04/91 (-- 5) RELEASE RIG @ 2300 HRS MW: 8.5 Seawater TD: 0 MAKE GR/JB RUN. RUN 4-1/2" COMPLETION. ND BOPE, N/U TREE PB: 9363 & TEST TO 5000 PSI. SET PACKER. DISPLACE ANNULUS W/140 SUPV:NJS BBLS DIESEL. SET BPV, SECURE TREE AND WELLHEAD. RLEASE RIG @ 2300 HRS 10-3-91. (145093) DAILY: $ 30,194 CUM: $ 368,064 EFC: $ 735,000 RECEIVED MAY - ,5 1992 Alaska Oil & Gas Cons. CommisSio~ Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/15/91 T# 82924 BP CASED HOLE LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 10/10/91 #1 7700.000 9321.000 10/09/91 #2 11850.00 12483.00 Inforraation Control Well Records Adrian J. Martin RECEIVED 0C1' 2 9 1991 Alaska Oil & Gas Cons. Commission Anchorage SCH SCH BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/26/91 T# 82874 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. D-12 %~'~TUBING PUNCHER 09/21/91 ~1 7648 8048 SCH Information Control Well Records Adrian J. Martin .. RECEIVED OCT 0 8 ka Oil & Gas Cons. CommissJorl- Anchorage TO: BP EXPLORATION · DISTRIBUTION FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE ~NALS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 .. Date: 02/22/91 T#:82136 Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. D-06 PROD-F .. / 02/10/91 #1 9050-9461 CAMCO D-12 PROD-F ~.~.~)~/"'[ ~1 ~,~ 02/10/91 #1 8900-9200 CAMCO D-23 CCLJTEM p...~,~ ~)~X.~ 02/11/91 #1 10150-10490 CAMCO G-30 LEAK DST ... ;"'~' . ........ 02/09/91 __ #1 _. 8600-9630 CAMCO H-17 PITS 02/09/91 #1 10350-10690 CAMCO # 5" 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSClENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 01/18/91 T#:82009 · FROM: SUBJECT: Information Control Well Records LR2-1 BP (~A.,~ED HOLE FINAL,~ Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. D-12 TDT-P BORAX 01/13/91 #1 8650-9332 SCH N-08 PRES FALL OFF 01/12/91 #1 9650-9846 SCH RECEIVED JAN 2 ~ 19.ql Alaska 0il & ~as Or, ns Commission Anchorage Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS R ES~F_J~~_.. ARCHIVES Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 31, 1,989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well D-12 (43-23-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) L. Burke (MB12-1) Well Records (LR2-1) w/10 D-12 Well File a' Bragg ' ger Production Engineering RECEIVE.D Oil & Gas cons, Commi~ior~ A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. sTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF .SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2, Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2350' NSL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UPM At effective depth 1579' NSL, 927' WEI_, SEC. 23, T11N, R13E, UPM At total depth 1580' NSL, 928' WE/., SEC. 23, T11N, R13E, UPM 12. present well condition summary Total depth: measured true vertical BKB Stimulate x Plugging .. Alter casing . Repair well 5. Type of Well: Development _X Exploratory Stratigraphi~ ,, Service 9434 feet Plugs (measured) 9326feet Perforate Other 6. Datum elevation (DF or KB) KBE = 71.50 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-12 (43.23-11-13) PBU 9. Permit number/approval number 80-15 / 8-879 10. APl number 50- 029-20443 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9366feet Junk (measured) BKB 9260feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB 110 20 x 30 14 c.y. 135 135 2681 13 3/8 3820 c.f. 2706 2704 8381 9 5/8 1264 c.f. 8406 8298 measured .. 1513 7 295 c. fo 9055~9085~ 9090~9098~ 9106~9130' 7913-9426 7805-9316 true vertical subsea 8876~8951°(three~tervals) Tubing (size, grade, and measured depth) 7" L-80 to 7839' with 4 1/2" tailpipe to 7974' Packers and SSSV (type and measured dePth) 9 5/8" Bakerpacker at 7839'; 4 1/2" SSS V & insert at 2097'_.. 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14.. Reoresentative Daily Averaee Production or Iniect~"~Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation "15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1210 3186 12 2080 9292 21 16. St~usofwellclassEic~ion as: Oil X Gas ...... Suspended 0 1896 0 2051 Service 17. I hereby certify that the forego~g is true and correct to the best of my knowledge. Signed Title Manager Production Engineering F°rm 1(~4 Rev 06/15/88 (//~/ SUBMIT IN DUPLICA~I'I~ WELL · D-12 (43-23.11.13~ PBU STIMULATION OPERATIONS A 15% HC1 perforation wash followed by a scale inhibition treatment was performed on thc following perforated interval in Well D-12. 9106'- 9116'MDBKB The treated interval was isolated from the upper gas-coning interval by setting an inflatable packer at 9100' MD BKB. Thc acid wash was pumped 11/27/88 via coiled tubing as follows: 1000 gal. 15% HCI w/OSR diverter 1000 gal. diesel w/10% mutual solvent Displace to pcrfs with sca or produced water The packer was released and the well put back on production immediately and tested. The following scale inhibition treatment was performed 12/9/88 via coiled tubing with an inflatable packer set as above: 10 bbls. diesel prcflush with mutual solvent 10 bbls. EDTA w/OSR diverter 71 bbls. scale inhibitor w/OSR diverter 130 bbls. seawater The well was left shut in for 24 hours, then returned to production and tested. jm 1/23/89 RECEIVED FEB 2 2 _\las .Oil & Gas Cons. Commission .... ~'~i~ ~chorage Standc~rd Alaska ~ Production Company ~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION November 21, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well D-12 (43-23-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (9) cc: L. Burke (MB12-1) D-12 Well File nager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation Shutdown ~ Re-enter suspended well,,., Alte~ casing Repair well . .. Plugging,,, Time extension . Stimulate x Change approved program . '" Pull tubing ,, , ' Variance __ PerfOrate O~hm, 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Standard Alaska Production Company De~opment x KBE = 71.50 AMSL feet Exploratory 3. Address Sa'alJgraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Sen~ce Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2350' NSL, 1067' WEL, SEC. 23° T11N, RI3E, UPM At top of productive interval, 1575' NSL, 924' WEL, SEC. 23, T11N, R13E, UPM At effective depth 1579' NSL, 927' WEL, SEC. 23, TI IN, R13E, UPM At total depth 1580' NSL, 928' WEL, SEC. 23, T1 IN, R13E, UPM D-12 (43-23-11-13) PBU 9. Permit number 80-15 10. APl number 50- 029-20443 11. Field/Pool Prudhoe Oil Pool 12. PreSent well condition summary Total depth: measured true Vertical 9434 feet BKB 9326 feet Plugs (measured) Effective depth: measured' 9366 feet Junk (measured) true vertical BKB 9260 feet Casing Length Size Cemented Structural -- Measured depth True vertical depth BKB Conductor 110 20 x 30 14 c.y. Surface 2681 13 3/8 3820 Cof. Intermediate 8381 9 5/8 1264 c.f. 135 2~6 8406 135 2704 8298 Production Liner 1513 7 295 c.f. Perforation depth: measured 9055'-9085; 9090'-9098; 9106'-9130' true vertical subsea 8876'-8951' (three intervals) Tubing (size, grade, and measured depth) 7" L-80 to 7839' with 4 1/2" tailpipe to 7974' 7913-9426 7805-9316 Packers and SSSV (type and measured depth) 9 5/8' 8akerpacker at 7839'; 4 I/2' SSSV & ~nsert at 209~,~ ~'.-~ '~, ~ !-'.13. Attachments Description Summary of proposal × Detailed operations program · 14. EStimated date for oommencing operation 15. Status of well classification as: November/December 1988 , 16. If propoSal was verbally approved Oil X Gas Name of approver Date approved Service 17. I hereby Cer~y that 'the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Condit o~ns of aPProval: NOtify COmmission so representative may witness Plug integrity... BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required ~ ORIGINAL SIGNED BY Approved by order of the Commission I flNNIE C, SMITH Commissioner Form 10-403 Rev 06/15/88 ~pproved Copy . Suspended Date #. ~,/ BOP sketch _.Z._ SUBMIT IN TRIPLICATE I AP, rov No. WELL D-12 (43-23-11-13) PBU STIMULATION PROPOSAL A 15% HCl perforation wash followed by a contingent scale inhibition treatment is proposed for the following perforated interval in Well D-12. 9106'- 9116' MD BKB The interval tO' be treated will be isolated from the upper gas-coning interval by setting an inflatable packer between 9098' and 9106' MD BKB. The acid wash will be pumped via coiled tubing as follows: 1000 gal. 15% HCI w/OSR diverter 1000 gal. diesel w/10% mutual solvent Displace to perfs with sea or produced water The packer will be released and the well put back on production immediately and tested. Depending on the results of the HCI wash, the following scale inhibition treatment will be performed via coiled tubing with an inflatable packer set as above: 10 bbls. diesel preflush with mutual solvent 10 bbls. EDTA w/OSR diverter 21 bbls. scale inhibitor w/OSR diverter 120 bbls. seawater The well will be left shut in for 24 hours, then returned to production and tested. jm 11/18/88 Coiled Tubing Blou/-Out-Prcvcnters Coiled Tbing Pack-Off ~==~._~ ' ' ~__.__.___~=~ Blind Rams u ~ ~ i' u Cutter Rams ' Chlcksan (Kill Llne) Slips Pipe Rams Pump-In Sub (Ciccula te/R e turn s) Well Head -~-'L.--' Swab., Valve Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 561-5111 STANDARD ALASKA PRODUCTION February 1, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well D-12 (43-23-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, . JTB: JAM Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 D-12 Well File J.~. B'rown, Supervisor Gravity Drainage RECEIVED A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. /'"', STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COM, ,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 71.50 AMSL Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 2350' NSL, 1067' WEL, Sec. 23, TllN, R13E, UPM At top of productive interval 1575' NSL, 924' WEL, Sec. 23, TllN, R13E, UPM At effective depth 1579' NSL, 927' WEL, Sec. 23, TllN, R13E, UPM At total depth 1580' NSL, 928' WEL, Sec. 23, TllN, R13E, UPM 7. Well number D-12 (43-23-11-13) 8. Approval number 7-972 9. APl number 50-- 029-20443 10. Pool Prudhoe Oil Pool PBU 11. Present well condition summary Total depth: measured true vertical 9434 feet Plugs (measured) 9326 feet BKB Effective depth: measured true vertical 9366 feet Junk (measured) 9260 feetBKB 12. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented ---- 110' 20"x30" 14 c.y. 2681' 13 3/8" 3820 c.f. 8381' 9 5/8" 1264 c.f. __ 1513' 7" 295 c.f. measured 9055'-9085', 9090'-9098', 9106'-9130' true vertical (ss ) 8876' - 8951' (three in%ervals) Tubing (size, grade and measured depth) 7" L-80 to 7839' with 4 1/2" tailpipe to 7974' Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 7839'; 4 1/2" SSSV & insert at 2097' Stimulation or cement squeeze summary Measured depth True Vertical depth BKB 135' 135' 2706' 2704' 8406' 8298' 7913'-9426' 7805'-9316' Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2610 5758 100 0 1852 Subsequent to operation 3110 5048 130 0 1786 14. Attachments~' ~' ,~,~ Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 14 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ()..,IL "//'~.¢. Form 10-040404~ Rev. 12-1-85 Title Supervisor Gravity Drainage Date Submit in Duplicate Well D-12 (43-24-11-13) PBU Additional Perforating Operations The following additional intervals were perforated January 14, 1988 using Gearhart 3 1/8" HSC carrier guns at 4 spf: 9090' - 9098' MD BKB (8911' - 8919' TVDss) 9116' - 9130' MD BKB (8937' - 8951' TVDss) Depths are referenced to BHCS, 5/14/80. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations. RECEIVED FEB - Alaska Oil & Gas Cons. 1/27/88 0800Z Standard Alaska Production Compa~ 900 East Benson Boul~..~rc, P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION December 18, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well D-12 (43-23-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, JTB: JAM Enclosures (9) cc: J. L. Naas (MB12-1) D-12 Well File J.~. Brown, Supe;visor Gravity Drainage RECEIVED Alaska 0;1 & ~'as Cons. CommJssJorr A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. /'-""% STATE OF ALASKA "'"~ AL~,..,,'",-, OIL AND GAS CONSERVATION CO~,,,v,,.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate~![] Other 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 71.50 AMSL feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 2350' NSL, 1067' WEL, Sec. 23, TllN, R13E, UPM At top of productive interval (top Ivishak/Sadlerochit) 1575' NSL, 924' WEL, Sec. 23, TllN, R13E, UPM At effective depth 1579' NSL, 927' WEL, Sec. 23, TllN, R13E, UPM At total depth 1580' NSL, 928' WEL, Sec. 23, TllN, R13E, UPM 7. Well number D-12 (43-23-11-13) PBU 8. Permit number 80-15 9. APl number 50--029-20443 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9434 feet Plugs (measured) 9326 feet BKB Effective depth: measured 9366 feet Junk (measured) true vertical 9260 feet BKB Casing Length Size Cemented Structural -- Conductor 110 ' 20"x30" 14 coy. Surface 2681' 13 3/8" 3820 c.f. Intermediate 8381' 9 5/8" 1264 c.f. Production -- Liner 1513' 7" 295 c.f. Measured depth 135' 2706' 8406' 7913'-9426' Perforation depth: measured 9055' - 9085' 9106' - 9116' true vertical (ss) 8876' - 8937' (tWo intervals) Tubing (size. grade and measured depth) 7" L-80 to 7839' with 4 1/2" tailpipe to 7974' Packers and SSSV (type and measured depth) Baker packer at 7839'; 4 1/2" $$$V ~ insert at 2097' 12.Attachments True Vertical depth BKB 135' 2704' 8298' 7805' -9316' RECEIVED DEC 2 ! 1~67 ~laska 0~t & Gas Cons. C0mm[ssi0rt Anch0r~n~ Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation January 1988 14. If proposal was Verbally approved Name of approver Date approved 15. J hereby certify that the foregoing is true and correct to the best of my knowledge Si~ed .~.~.~~ Title Su[oervisor Gravity Drainage J ' B~°wn Commission Use Only Date IZ../I7/~' Conditions of approval Approved by ! Notify commission so representative may witness Approval No. [] Plug integrit~pp~:)V~l~i~J/ [] Location clearanceI "~/ ', /'/~' Returned _ - by order of LONNIE C. SMtTtl Commissioner the commission Date ,/¢,~-~,~/ Form 10-403 Rev 124-85 Submit in triplicate Well D-12 (43-23-11-13) PBU Addltlonal Perforating Proposal We propose to perforate the following intervals during January 1987 at 4 spf. Add'l. Add'l. 9090' - 9098' MD BKB (8911' - 8919' TVDss) 9116' - 9130' MD BKB (8937' - 8951' TVDss) Depths are referenced to BHCS, 5/14/80. k lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations. j~ul~ 12/17/87 0800Z FLOW TUBES & PACKOFF BOWEN PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE F/OWLINE VALVE GREASE LINE RECEIVED DEC 2 1 1S67 Alaslm Oil & Gas Cons. Commission Anchorage RISER GREASE ,· / MANIFOLD GREASE PUMP --.~ GREASE RESERVOIR BOP SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON GETTY ~o: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmittal Only)~ 311 I "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265.0000 MAIL: POUCH 6.612 ANCHORAGE. ALASKA 99502 1/20/83 Date: Tr. ans.#:,._ 3052 CC#: 56052 REFERENCE: /T'SO. HIO. CA~E'D.. HO~LE FINAL LOGS he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: B-8~ CNL 11/23/82 #7 8900-9778 Sch 5" C-3-- CNL I1/25/82 #2 9200-10167 Sch 5" D-4-'~ CNL 11/28/82 #9 9900-10670 Sch 5" · ~D-1-2''~ CNL 11/28/82 #1 8.500-9350 Sch 5" F-14/ CNL 12/11/82 #1 9800-10632 · Sch 5" G-iO~ CNL 11/26/82 #2 9200-10032 Sch 5" J-11~ CNL 11/29/82 #1 10050-10900 Sch 5" B-12-- Flowmeter 12/18/82 #1 8800-9400 .GO 5" G-17-" Spinner 11/29/82 #1 10950-11270 GO 5" R-4 J Spinner 12/5/82 #1 9500-9850 GO 5" R-18z Spinner 12/16/82 #1 9800-10150 GO 5" R-19~ Spinner I2/11/82 #1 9550-9850 GO 5" B-12 DFT 6/18/82 #1 8800-940'0 GO 5" H-6~ Temp.Survey 12/25/82 #1 9600-9982 Camco 5" M-4~ DFT 12/20/82 #1 11200-11740 GO 5" M-8'~ Temp. Survey 12/15/82 #1 9894-11706 Camco 5" X-l-" . Temp.Survey 12/27/82 #1 88'00-9300 Camco 5" C-27- EPL 12/13/82 #1 9800-10150 Sch 5" B-12~ Hydro Log 12/18/82 #1 8800-9400 GO 5" M-4- Hydro Log 12/20/82 #1 11200-11740 GO 5" (4/82) R[C[IVFD DATE .~I~,,,, I"~8~- ~ Victoria Aldridge Development Geology ~ Well Records TP1-5. Alaska 0il & Gas Cons, Comrniss[0. Anchorage CO,::P,,r4Y SOHIO ALASi;~ PETROLEUM "~ ~ SFO ARCO_ EXXON PHILLIPS ATE OF AK CENTRAL FILES(CC#'s-Transmittal 3111 "C" AIJCHOI{AG[, ALASKA 3ELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: ]-17-83 Trans.~:_,3012 CC~: 56012 eplace-* ~ent tape) /-,/82) RECERENC£: //SOHIO MAGNETIC LIS TAPES & LISTINGS ~ /~e following materia~ is being submitted herewith.-Please acknowledge receipt by signing ~ copy of this letter and returning ~t to thru ofhce:-- S~-14~ · ' 4 'Tape Pos. ~ DIL/BHC/FDC/CNL/GR 10/19/82 #1&2 656 i 02149 * A_ 28/OH * C-26 ' OH. * D-21-' OH * A-4- CH * H-17/OH * A-25 OH * D~12 ~CH * A-29 OH * D-4 CH * 3-7 CH * A-27 OH. * B-7 CH. * C-8 CH * S-13 OH * B-24 CH * R-9 CH * E-2 CH * S-6 OH. * H-11 CH * 3-11 CH * B-8 CH DIL/BHC/FDC/CNL DIL/BHC/FDC/CNL/GR DIL/BHC/FDC/CNL/GR CNL DIL/BHC./LDT/CNL/GK D~L/~C/~C/CU~. CU~ DIL/BHC/FDC/CNL/GR CNL CNL DIL/BHC/FDC/CNL CNL CNL DIL/BHC CNL TDT CNL DIL/~C/~N T~T CNL CNL 10/20/82 11-I-82 11-1-82 11/22/82 12/18/82 8/18/82 11/28/82 11/22/82 11/28/82 11/14/82 9-26-82 ii/20/82 11/21/82 10/~/82 1o1~I82 12/6/82 11/16/82 11/28/82 11/22/82 11/29/82. 11/23/82 #1 66022 02150 #1 66033 02148 #1 66032 02143 ~3 66105 02146 #1 66223 02145 #1 65546 02144 #1 66167 02143 #1&2 66162 02142 #9 66166 02141 #1 .66124 02140 #l&2 65662 02139 #3 66132 02138 #4 66131 02137 #2 65722 02136 .#1 65723 02135 ~1 66152 01234 #11 66074 02133 ~2 ..66164 02132 #1 66172 02131 #1 66170 02130 .#7 66111 02129 DATE _ _ · *SFO & EXXON: An Asterisk:(*) next to a listing above means you should have received the. Tape(s) and Listing(s) directly from the respective service company. Please confirm this. ~ .- .~.~___~~%~[K~ren Mestas-Venn n~c~,v~ .... (~_ ~.-~-~ '~/'/~>-~ r,~D~velopment Geology AlaSka Oil & Gas Cons. Commission Anchorage ,. · . . SOH I 0 RES I R I CTED SOHIO ALASKA PETROLEUM COMPANY TO: SFO/UNIT/STATE ARCO ....... (-Marathon) Phillil~ ............. Transmittal O,,n, 1,y I J I1__ - I III _ ........ 311'1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 12/1/81 REFERENCE: cToh¥~'SOHIO FINAL DATA CASED HOLE FINAL LOGS following material is being.~ubmitted herewith. Please acknowledge receipt by signing a of this letter and returning it to this office:-- SFO/UNIT/STATE: (-Marathon) CASED HOLE FINAL LOGS A-1 ..... CCL/Perf. (Go) 9/~81 #1 5" DZ12 Spinner/CFS (Go). 9/30/8'1 #1 5" G-6 Spinner/CFS (Go) 10/18/81 #1 5" X-15 Spinner/CFS (Go) 10/30/81 #1 5" RECEIVED - - "' -klasl~b~&"Gas Cons. Commis~ior~ . Ca DATE r " eter Anch0[~g0 WellDeV~nt'.ords Geology SOHI0 RES I CTED SOHIO ALASKA PETROLEUM COMPANY · 311 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Da%e: 10/29/81 .#- 1148. REFERENCE: SOHIO FINAL DATA ~.- ........... The following material is bein~',;;'ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: (-Marathon) PRESSURE DATA ;~12 ~ Bottom-Hole Pressure DJta Form & Survey (Go) 9/30/81 G-6 " " " " '" " (Go) 10/lS/81 X-8 " " " " " " (Camco) 10/2-4/81 NOV DATE Alaska 0il & Gas, Cons. C0mmiss/0. Anch0rag~- 'SOHIO CONk IDEi tTIAL SOHIO ALASKA PETROLEUM COMPANY ARCO C~vrm SFO/UNIT/STATE: ~k~ ....... -- (-Marathon) PtxilliM ....... - - - . 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 8/21/81 # 1000'E REFERENCE: following material is being ~;ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-8 / B- 6','" B-8 D-3 / ...... D-i2 y D_13 ,.// D-15 L. F-4 ~ F-10~ F-ii F-13_/ H-11-- R-2 J/ x-11V CNL (Sch) 6/25/81 #4 5" TDT-M (Sch) 7/2/81 #2 5" TDT-M (Sch) 7/22/81 #2 5" TDT-M (Sch) 7/28/81 #1 5" CNL (Sch) 5/29/81 #1 5" DDNLL (Dres) 5/25/81 #1 5" DDNLL (Dres) 6/13/81 #1 5" DDNLL (Dres) 7/12/81 #1 5" DDNLL (Dres) 7/27/81 #1 5" CNL ($ch) 6/27/81 #2 5" CNL (replaces final log (Sch) 5/21/81(correct date) .#7 5" incorrectly dated 5/2/81) DDNLL (Dres) 6/24/81 #1 5" DDNLL (Dres) 6/23/81 #1 5" DDNLL (Dres) 6/25/81 #1 5" DDNLL (Dres) 7/13/81 #1 5" TDT-M (Sch) 6/29/81 #2 5" DDNLL (Dres) 5/8/81 #1 5" DDNLL :" (Dres) 7/15/81 #1 5" ?~bOpment Geology Records ' SOHIO ALASKA PETROLEUM COMPANY June 23, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Wells[~ ~[ 3, & ~u~ D-1 H-10 H-ii Enclosed, in duplicate, are the following forms for the above- named wells: 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notices & Reports on Wells; 3. Form 10-404, Monthly Report of Drilling & Workover Operations. very truly, GJP: ja Enclosures cc: Well File #17 S. R. Bur~y A. E. Leske Geology "'~ STATE Of ALASKA '~'~, ALASKA L,~_ AND.GAS CONSERVATION CG.,,.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well .... OIL [] GAS [] SUSPENDED [] .ABANDONED]-] SERV'ICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 80-15 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20443 4. Location of well at surface 9. Unit or Lease Name 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1397' NSL, 934' WEL, Sec. 23, TllN, R13E, UPM D-12 (43-23-11-13) At Total Depth 11. Field and Pool ,1580' NSL, 9128' WEL, Sec. 23, TtlN, R13E, UPM Prudhoe Bay '5. EleVation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Oil Pool · KRF. = 71.50 ' AMSLI ADL 28285 12. Date Spudded 13. Date T.$. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4/30/80 5/14/80 5/17/81I feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9434'MD 9326'TVD 9366'MD 9260'TVD YES ~ NO []I 2000 feet MD 1950 1 GL 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, BHCS/GR, FDC/CNL/GR/Ca]. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · · . 20"x30" Insulate~ lConducto: Surface 110 ' 36" 14 cu.yds. Ar~t~_s~t 13 3/8" 72# L-80 Surface 2706' 17 1/2" 3820 cu. ft. Permafro,~;t II 9 5~8" 47~ L-80 Surface.. '-8413." 12 1/4" 1134 cu. ft. Class G: 130 cu.ft. Permafro:;t C 7" 29# L-80 7923' 9426' 8 1/2" 295 cu. ft. Class 24. Perforations open to Productio9 (MD+TVD of Top and Bottom and - 25. TUBING RECORD · interval, size and.number) MD ?v'D SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool - Top: 905-~' 8947 ' 7" 7964 ' 7R59 ' Bottom: 9116. . 90.08. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9055-9085'BKB 0.5"@4spf (Ref,BHCS/GR,5/14/80) ..DEPTH INTERVA.L (MD) AMOUNT & KIND OF MATERIAL USED 9106_9116 ,BKB:'' ,, ,, (' ,,: ) , , - , . . . ': .: .'~ :..~ . :.~ . 27. pRODucTION TEST Dat. e :First P~od.uctio0 ; ·: .... , .....: Method of Operation (Flowing, gas lift,etc.) 5/17/81 "' 'FlOWing ' Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO - , .... . ~:. .... TEST PERIOD I~ . .... . . ~ . . Flow.lubing Casing Pressure . . CALCULATED I~ OIL~B. BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ... 24-HOUR ·RATE I~ 28. CORE DATA· Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. -. . ~one · JUL 0 8 .... . .. ~ -': .... ~ .. : -- A/asia 01i & (3a~ Cons Co'nrnis~ion tmc.horag~ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29.. 30.. GEOLOGIC MARKERS ' FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 8600 ' " 8421 ' Shublik 8630 ' 8451' Ivishak 8705 ' 8526 ' 34. L,s'r'oF ATTAO --NTS ' None , 32. I hereby cert~tha/~7~g is true and correct to the best of my knowledge si,,e~~~~~ ~ Title District Field k' ~.~~ ~o~ ~zzsga ,, E~ineer INSTRUCTIONS General: -This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. · Item 1' Classification of Service. Wells: Gas injection, water injection, steam injection, air injection, salt Water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measUrements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is. completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the .data 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 cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersil~le, Water In- jectiOn, Gas Injection, Shut-in, Other-exPlain. Item 28: If no cores taken, indicate "none". PERFORATING DATA - Well D-12 May 5, 1981: Pressure tested tubing and inner annulus. May 17, 1981: Rigged up Dresser Atlas and perforated the following intervals using 3 1/8" carrier guns at 4 spf: 9055' -9085' BKB (Ref. BHCS/GR, 5/14/80) 9106' - 9116' BKB ( " ) Put well on production. May 31, 1981: Shut well in to prepare for static pressure survey. June 2, 1981: Ran static pressure/temperature survey at 8800' TVDss. June 3, 1981: Set and tested SSSV in ball valve nipple ca. 2000'. Well .on production. STATE OF ALASKA AEASKA~-'~LAND GAS CONSERVATION C, i~MISSION 'i SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~-I 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 80-15 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20443 OTHER 4. Location of Well At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 71.50 ' AMSL 12. I6. Lease Designation and Serial No. ADL 28285 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D-12 (43-23-11-213 11. Field and Pool Prudhoe Bay Prudhoe Oil Pul Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO.' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations I~ Altering Casing r-] Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting 'any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated on May 17, 1981, using Dresser Atlas 3 1/8" carrier guns at 4 spf: 9055' - 9085' BKB (Ref. BHCS/GR, 5/14/80) 9106' - 9116' BKB ( " ) An SSSVwas set and tested in the ball valve nipple ca. 2000'. RECEIVED ere~~/g Alaska Oi~ & Gas Co/~s. 14. I h is true and correct to the best of my knowledge. Anchorage Signed,//~',~ ~ A~--...._ ) ~ (A,/~ Title District Field E~ineer Date ' - '- G- J Pli a ' / -- By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . ~ , /--., STATE OF ALASKA "'"M ' ALASKA ! AND GAS CONSERVATION C( ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company, 80-15 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20443 4. Location of Well at surface 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 5qqR = 71.50' AMSL ADL 28285 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. D-12 (43-23-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. June ,19 '81 12. Depth at end of month, footage drilled; fishing jobs, directional drilling problems, spud date, remarks 3. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 116. DST data, perforating data, shows of bl2S, miscellaneous data See attachment RECEIVEO JUL 0.8 /llaska Oil & (~as Cons. Commission ereby~t f~o Anchorage 17. I h lng is true and correct to the best of my knowledge. .~IC, NF~ [X~~ TITLE DlStr lct Field Enqlneer DATE Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 April 22, 1981 CONFIDENTIAL Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (43-23-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of April, 1981. RHR:ja Enclosures cc: Well File ~17 Yours very truly, District Drilling Engineer~ RECEIVED MAY - 7 1981 Alaska 0ii & Gas Cons. Commission Anchorage - ~ STATE OF ALASKA ALASKP"~L AND GAS CONSERVATION C/~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well at surface 99502 2930' SNL, 1067' WEL' Sec. 23, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 71.50 ' AMSLI ADL 28285 7. Permit No. 80-15 8. APl Number s0~29-20443 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. D-12 (43-23-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the MOnth of April ,19 81 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks This is an unperforated well. Using tubing jet punch, shot holes in tubing from 7742'- 7744'. Reverse circulated diesel to 9.6 ppg. NaC1. Moved in rig. Nippled down Xmas tree. Rigged up & tested BOPE. Pulled 7" tubing & seal assembly. Retrieved leaking packer. Cleaned out well to 9382'. Ran 203 jts. 7" '26# IJ4S tubing with Baker pro- duction packer. Landed tubing at 7974' w/ball valve nipple at 2096'. Installed & tested tree. Changed tubing over to diesel. Set packer at 7853', tested tubing to 3000 psi, 13. Casing or liner run and quantities of cement, results of pressur9 tests okay. Released rig at 0100 hrs., 4/13/81. 14. Coring resume and brief description 15. Logs run and depth where run I (3. DST data, perforating data, shows of H2S, miscellaneous data KELEIVEI)' MAY - ? 1981 Alaska Oil & Gas Oons. Commissior~ Anchorage I17. I hereby certify that the fore_~oing i,~s true and correct to the best of my knowledge. SIGNED NOTE--Report on this form is required for each ca r month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form '10404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY March 18, 1981 3111 'C" STREET ANCHORAGE' A LASKAi'-' ~:, ANCHORAGE, Al Alaska Oil & Gas Conservation~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (43-23-11-13) Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This report contains our proposal to replace the leaking production packer on Well D-12. RHR:ja Enclosures cc: Well File 917 Yours very truly, R. H. Reiley District Drilling Engineer STATE OF ALASKA ALASK~IL AND GAS CONSERVATION C~MISSION SUNDRY i iOTICES AND REPORT' ON WELLS i.. DRILLING WELL I-~ COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address : Pouch 6-612, Anchoraqe, Alaska 99502 4. Location of Well At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 7. Permit No. 80-15 8. APl Number 50-029-20443 9. Unit or Lease Name Prudhoe Bay Un~f. 10. Well Number D-12 (43-23-11-13) 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 71.50' AMSL I ADL 28285 12. Check Appropriate Box lo Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) . Perforate [] Alter Casing [] '~ Perforations [] Altering Casing Stimulate [] Abandon I-') Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to replace the leaking production packer. Operations estimated to start May 1, 1981. This is an unperforated oil well. Program is as follows: .1. Shoot hole in tubing, reverse circulate diesel out of tubing to 9.6 ppg. NaC1.2. Move in rig, nipple down Xmas tree. Rig up and test BOPE. 3. Pull tubing from well and retrieve leaking packer. 4. Set new packer on 7" plastic-coated tubing, install back pressure valve 'in tubing, hanger. 5. Nipple down BOPE, install Xmas 'tree. 6. Displace tubing to diesel, set packer, test, secure well, and move off rig. The previous Sundry Notice of October 21, 1980,' was not acted upon. notification of our rescheduled intention to work over Well D-12. This is a second · Alaska 0il & (]as Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~-~-'~j~'~'''"- Title District Drilling Engineer The space below for Commission use ~ Reiley Conditions of Approval, if any: Approved by Form 10~t03 Rev. 7-1-80 By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT/STATE: (-Marathon) ARCO Chevrou ...... -- i i i i1__ . Mobil __ _ SFO . ~ ,, ,, · .... } "__. ' - - _ '2 ..... . .- . -_ -COM --"cOMM ANCHORAGE, ANCHORAGE ALASK~~ ~E~ l'-'l j ..... I STATT~] 11/13/80 ' H4~O-~F'ER: LFILF; REFERENCE: SFO/UNIT/STATE: ~~ThOHIO FINAL CASED HOLE LOGS e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to. this office:-- B-4 Spinner 10/20/80 H1 D-10 EPL 10/28-30/80 Hi ~ CCL/Perf. 10/21/80 H2 H-8 EPL 10/28-30/80 Hi Q-2 Spinner 10/30/80 Hi Q-2 Spinner 10/24/80 H1 Y-4 Perf. CCL 10/21/80 H1 Kuparuk 22-11-12 Temp. Log 11/3/80 Hi 5" 5't 5" 2"/5" 5" 5" 5't 5" Carol Krieter Well Records 19 Alaska Oil & (3as Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY October 24, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENTIAL Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (43-23-11-13) Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. WRH: ja Enclosures cc: Well File #17 Yours very truly, W. R. Hicks Acting District Dr~illing Engineer ALASKA ~IL AND GAS CONSERVATION C~. ;MISSION SUNDRY NOTICES AND REPORTS DRILLING WELL[] ' COMPLETED WELL[] 80-15 t'--i-'~ n~OL-----i I 8. APl Number 99502 50- 029-20443 17i C, TaTTEC--I J Prudhoe Ba ' .~ 10 Well Number | __.._ -'---------'--~. 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM D-12 (43-23-i 11. FieldandPool Prudhoe Bay 5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo. Prudhoe Oil Pool KBE=71.50'AMSL; BFE=47.00'AMSL ADL 28285 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well FI Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a sUbmitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This tubing in this well was pulled between October 6 and 11, 1980 to replace the packer prior to perforating and plaCing on production. Rig was accepted at 1300 hours, October 6, 1980. Nippled down tree and nippled up BOPE. Displaced tubing to 9.6 ppg. NaC1, pulled and layed down 7" tubing, Guiberson packer, and tail assembly. Ran 203 jts. 7" tubing to 7938'. Landed tubing with ball valve at 2088'. Installed and tested tree. Displaced tubing to diesel, set packer at 7835'. Tested tubing to 3600 psi, okay. Released rig at 0400 hours, October 11, 1980. Note: Suspected Guiberson packer failure October 17, 1980... Sundry Notice sent October 21, 1980 stating our intention to replace leaking production packer a second time with new Baker packer· ~ ......... ~ Signed \,,} The space below for Commission use W· R o Hicks the best of my knowledge. Title Actinq District Drilling Engineer Date Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate ,, ,,.,/ J J COM~.,/~'I SOHIO ALASKA PETROLEUM COMPANY F--I~-~~ ~.o.o.~.[~~g ! TELEPHONE {~~ ~STAT TEc'~J Alaska Oil & Gas Conservation'Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (43-23-11-13) Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This report contains our proposal to replace the leaking production packer on Well D-12. WRH: ja Enclosures cc: Well File #17 Yours very truly,~~--~ Acting District Drilling Engineer STATE OF ALASKA .:~', ALASKA ~L AND GAS CONSERVATION CC.,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E3 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 80-15 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20443 4. Location of Well OTHER E] At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE=71-:- 50'AMSL; BFE=47.00 'AMSLI ADL 28285 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D-12 (43-23-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool . Check ApPropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tubing [] Other r~i Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. DesCribe Proposed or Co~npleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to replace leaking produCtion packer. Operations estimated to start November 3, 1980. This is an unperforated oil well Program is as follows: le 2. 3. 4. 5. 6. 7. Shoot hole in tubing, reverse circulate diesel out of tubing to 9.6 ppg. NaC1. Move in rig, nipple down Xmas tree. Rig up and test BOPE. Pull tubing from well and retrieve leaking Guiberson packer. Run wireline casing caliper log. ' Set new Baker packer on 7" plastic-coated tubing. Leave diesel inside tubing, nipple down BOPE. Rig up Xmas tree, test, and move rig off. 14.1 h erebI~at~t h e ~g(~ a~,or/~ Signed ~ ~,,.J ~ ~ J"~:~'" ~ J/ 2 / f W R ~ks The space below or Commission use · · best of my knowledge. Title Acting District DriZZinq Engineer Date Conditions of Approval, if any: Approved by~ Form 10-403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION HOY le H. Hami 1ton Chairman/Commissioner Thru~ Lonnie C. Smith Commissioner oug mos Petrleum Inspector October 13, 1980 Witness BOPE test on Sohio's D-12 Well, Sec. 23, TllN, R13E, UM. Per- mit No. 80-15, Being worked over by Nabors Rig 18E. ~.Onday october :6:,: 1980~ I departed my residence @ 1:30 pm for a 3=00 pm departure on Sohio charter arriving Deadhorse at 5:00 pm. I arrived Nabors 18E @ 6z00 pm. Tuesday October 7, 1980: The BOPE test commenced at 4:00 am al{era.testing the Choke manifold an attempt was made to test the 7" pipe rams, the test could not be conducting because of a leak in the 7" casing hanger. The leak was caused by missing bull plugs in 'the control line ports within the 7" hanger assembly. With the aid of two sacks of Barite a 3000 psi test was conduct- ed on the 7" pipe rams and annular preventor. The 7" csg. was then pulled and the entire BOPE stack tested to 5000 psi. Wednesday October_8,.. 1980: The BOPE test was concluded at 2:00 pm~ .... i fill'ed out an A'O.G.C.C. BOPE test report which is at- tached. In summary: I witnessed the BOPE test on Sohio's D-12 well being worked over by Nabor's Rig 18E. Because of the missing bull plugs.~.in We 7" casing hanger assembly the complete test was not conducted prior to pulling the 7" casing. However after the casing was pulled the entire BOPE stack was tested to 5000 psi. I filled out an A.O.G.C.C.' BOPE test report which is attached. ~ O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Location: Sec %~ T%I%Q RI~ M ~,~ Drilling Contractor,~~ Well ID- I Z Representative Permit # ~ '~ Casing Set Rig #.. ~, ,~ Representative. Location, General Well Sign General Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM Full Charge Pressure ~C~ psig Pressure After Closure ~&~ psig 200 Psig Above Precharge Attained: BOPE Stack Annular Preventer Pipe Rams ~ Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Test Pressure Check Valve Tee t Re sulks: Fa ilures ~OOO min 1~ sec Full Charge Pressure Attained: I min ~sec N2 Z~;Q~ ~'1~2~1~;3 Z~&~ ~sig ~k~ Controls: Master O~ Remote ~ Blinds switch cover ~ Kelly and Floor Safety Valves Upper Kelly I Test Pressure Lower Kelly I Test Pressure Ball Type t Test Pressure Inside BOP t Test Pressure Choke Manifold C~ Test Pressure No. Valves 1~ ~o0 No. flanges Adjustable Chokes Hydrauically operated choke Test Time,,,,~ hrs. Repair or Replacement of failed equipment to be made within ..... days and Inspector/Commission office notified. ~ I I Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector SOHIO ALASKA PETROLEUM COMPANY CONFIDENTIAL September 24, 1980 3111 'C" STREET ANCHORAGE, ALASKA ~.. TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99502 Attn: Mr. H. H. Hamilton Re: Well D-12 (43-23-11-13) Gentlemen: Enclosed please find, in triplicate, Form 10-403, Sundry Notices and Reports on Wells, for the above-referenced well. Very truly yours, SOHIO ALASKA PETROLEUM COMPANY RHR:mlh Enclosures District Drilling Engineer REV. 1-10~73 Subml t "I ntentions" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. V~/~LLLBWELLGAS O OTHER ~- NAME OF OPERATOR Sohio Alaska Petroleum Company 5. APl NUMERICAL CODE 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, ~ 99502 D-12 (43-23-11-13) 4. LOCATION OF WELL At surface 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 71.50' AMSL Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23e TllN, R13E, UPM 12. PERMIT NO. 80-15 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~] PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Replace Leaking Production Packer SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Operations estimated to start October 5, 1980. This is an unperforated oil well. Shoot a- hole in tubing. Reverse circulate diesel out of tubing to 9.6 ppg. NaC1. Move in rig. Nipple down Xmas tree. Rig up and test BOPE. Pull tubing from well. Retrieve leaking Guiberson packer. Set new packer on 7" plastiC-coated tubing. Leave diesel inside tubing. Nipple down BOPE. Rig up Xmas tree, test, and move rig off. Subsequent Work Reportecl on Form No./~ Dater/.~/~/~.0 16. I hereby C~lf~go~e and correct SIGNED (This space for State ~ce u~) / / CONDITIONS O~PROVAL' gY 0RD~R OF THE CO~IISS[ON T,TLEmSTRXCT Dax~,t,x~s g~Gx~v.v.a DATE ,,~' 3. U'{ ~ COMMISSIONER See Instructions On Reverse Side DATE Al~proved ~lumed B.O.P. I;5 S,~:~NC K CONFIGURATION 5/8" TRIPLE RAM STACK 50O0 PSi WP WORKOVER ANNULAR PREVENTER KILL LINE HAND HAND CHECK GATE GATE · I 1_ I I PIPE RAMS © PIPE RAM.S F DRILLING SPOOL I I BLIND RAMS -© 4" CHOKE LINE GATE HYDR. ASST. GATE SEi:' 2 5 kl~.sks, 0i! & 0 ,.,'. 35 SOHIO ALASKA PETROLEUM COMPANY August 20, 1980 State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99509 Attn.: Mr. H. H. Hamilton Re: Well D-ii (11-23-11-13) ;. D-12 (43-23-11-13); X-6 (33-01-10-13); and Y-5 (24-34-11-13) Gentlemen: Enclosed please find, in triplicate, Form 10-403, Sundry Notices and Reports on Wells, for the above-referenced wells. Very truly yours, S~O A_!~A PETROLEUM COMPANY L DG~s~;i~c~i;~eald %~gineer GJP:LS:mlh Enclosures cc: S. R. Bundy A. E. Leske Drilling File Geology Form '10-403 REV. 1a10-73 Submit "1 ntentlon~" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for sUch proposals.) WELL OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR ?ouch 6-612, Anchorager ~ 99502 4. LOCATION OF WELL At surface 2930' SNn, 1067' WEn, Sec. 23, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT,. GR, ets) KBE = 71.50' AMSL 14. Check Appropriate Box To Indicate NatUre of Notice, Re ~API NUMERICAL CODE 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285 7. IF INDIAN, ALLOTTEE OR TRIBE NAME · 8. UNIT, FARM OR LEA'SE NAME Prudhoe Bay Unit 9. WELL NO. D-12 (43-23-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 23, TllN, R13E, UPM 12. PERMIT NO. 80 -15 )ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING l.~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent (retells, and give pertinent dates, including estimated date of starting any proposed work. , The following intervals will be perforated .during August/September, 1980, using Dresser 3 1/8" carrier guns at 4 s.p.f.: 9055'-9085' BKB (Ref. BHCS/GR 5-14-80) 9106'-9116 ' B~.B (" " ") A SSSV will be set and tested in the ball valve nipple ca. 2000'. AU6,3.5 ' (This. ;p~'e~~*~ "~~r S~,~t'~fflce uS~Rl ~fftA[ SIGNED CO~3~!SStONER APPROVEDBY ~Y ;~A~RY %~, .[U~RTiTLE ~ CONDITIONS OF APPROVAL, IF ANY= ~? 0RD~R OF TH~ CO~,~S~ON DATE DATE LS: mlh See Imtructions On Reverse Side Approved Copy Returned SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: ~ON PHILLIPS SFO 3111 'C" STREET ANCHORAGE, ALASi TELEPHONE (907) 265 MAI L: POUCH 6~61 ANCHORAGE, ALASKA .- 7/7/80 #25~ ! co~//~.~ ~ - '--j 'COMM.'il I RES EN5 i J l 'ENG.~_.. ! J3 ENG.-,Y¢ 'J ,:, 1.4E-N.~ j' ~:T' OEOL / 3 GEOL/---'J T,,,T_TEC--I -i "s'rAT'-fEd--J : I '~ . 'CONFER:' ~] 'F.~m -J REFERENCE: /~0~0 MAGNETIC TAPES · / f'he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- 5/14/80 Tape #60531 E-3 1/7/80 Tape #60267 N-6 1/16/80 Tape #60210 Anne Barns Well Records RECEIVED JUL ~. 0 1980 Al~ka 0il & Anchorage / SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION To:SFO/UNIT/STATE -- -- i h'b- bii ........ _ .. Phillips .... ..__: _ R~.'=,.E ......... $~-'O _ ,_ : .. REFERENCE: SOHTO CASED ~0~[ ~[~ lOGS 3111 'C" ST[ ANCHORAGE, TELEPHONE (90; MAI L: ANCHORAGE, 6/16/80 ./The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- D-11 B-16 E-8 N-7 X-7 Temp. Log 5/12/80 #1 Spinner Log 5/23/80 #1 Temp. Log 5/25/80 #1 Temp. Log 5/24/80 #1 Spinner Log 5/18/80 #5 Temp.,Log 5/13/80 #1 511 5' 5" 5' 5" 5" Anne Barns Well Records 19 SOHIO ALASKA PETROLEUM COMPANY June 17, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton ANCHORAGE, ALA~~ES ENG-- -'i MAIL: POUCH 6-61 ANCHORAGE, ALASKA I 4 /1GE~ CO ZD " I STAr FILF: .... .,. Well D-12 (43-23-11-13) Enclosed, in duplicate, is Form P-7, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Survey. This well has ~een suspended pending perforating operations. RHR: ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer Form P--7 ;~ SUBMIT IN DUP.,., :E* STATE OF ALASKA (see o;~r In- structions on reverse side) el L AND GAS CONSERVATION COMMITTEE ._ WELL COMPLETION OR RECOMPLETION REPORT AND LOG* 1,a. TYPE OF WELL: OIL GAS r-'-I WELL[~ WELLi I DRYr'--] Other b. TYPE OF COMPLETION: NEW 4-~-A WORK r--1 DEEP- PLUG r--I DIFF. [~1 WELt-~)u~ OVER I I EN O BACK.I I RESER..I I Other 2. NAME OF OPERATOR Sohio Alaska Petroleum ~¥ 3. ADDRESS OF OPERATOR · Pouch 6-612 Anchoraqe, Alaska 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM At top prod. interval reported below---~-°~cr R. SST 1575' NSL, 925' W~, 8OC 23, TllN, R13E, UPM At total depth 1580' NSL, 928' WEL, Sec. 23, Tlln, R13E, UPM OIIIGINAL 5. APl NUMERICAL CODE 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9~'1~2 °i43-23-11-13) lb,_F_I. Ei~ AND POOL, OR WI LDCAT Prudhoe Bay, Prudhoe Oil Poo: 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, TllN, R13E, UPM 12. PERMIT NO. 80-15 13. DATE SPUDDED 114. DATE T.D. REACHED 115. DATE COMP, SUSP, OR ABAND. 116. ELEVATIONS (DF, RKB, RT, GR,,ETC~ 117. ELEV. CASINGHEAD 4/30/80 '15/14/80 -I 5/19/80 II KBE = 71.50' AMSL:*? ~ 47.00' AMSL ',. OTAL DEPTH ,TVD "0. PLUG BAcK · TVDi20. 'F MULT'P'E COMPL.. ! lvJJ~ ' '.['VLI I DEPTH HOW MANY* 21. ROTARY TOOLS II~ITE'RVALS DRILLED BY CABLE TOOLS 9434' 9326' 19366' MD 9260' ~ota& 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL SURVEY MADE ~one Y~$ . TYPE ELECTRIC AND OTHER LOGS RUN 25. CASING RECORD (Report all strings set In well) CASING SIZE 20" x 30" .... 13 3/8" 9 5/8" 7" 26. WEIGHT, LB/FT. / GRADE / DEPTH SET (MD) InSulated qonductDr 110' i -s0 i 47~ IL-80 I ' 8413, SIZE I TOP (MD) I ~. PERFORATIONS OPE,N TO PRODUCTION None 30. 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) HOLE SIZE 36" 17½" 12%" 8~- CEMENTING RECORD 14 cu.¥ds. Arcticset Conc 3820 cu, ft. pe~a~afrost II 1134 cu. ft. Class G.- 130 1295 cu.ft. Class G. ' LINER RECORD BOTTOM (MD) [ SACKS CEMENT I (Interval, size and number) . ~. ~! ~.' AMOUNT PULLED rede ~u,ft. Permafrost 27. -TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 7964 ' 7859 ' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. ~EPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED PRODUCTION ~ ~. ~ ~ ~~ DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) I WELL STATUS (Producing or I ~.. i.~ , I shut-In) PRESS. 24-HOUR RATE ITEST WITNESSED BY 32. LIST OF ATTACHMENTS Well Historv. Well Iz3cc~_ D~r~f~onal Survey 33.1 hereby certify_th/C~th--e 'forego~g and~34~h~ In~l~n.~io~is complete and correct a"s d~termlned ,rorr~,ll available records. *(See instructions and Spaces for Additional Data on Reverse Side) 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the de~ails of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, -- WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPT ,. B~ .. Sag R. SST 8600' 8421' Shublik 8630 ' 8451' Ivishak 8705 ' 8526 ' · 36. CORE DATA, ATTACH BRIEF DESCR}PT~ONS OF L~THOLOGY, POROSITY, FRACTURES,"APPARENT D~PS AND DETECTED SHOWS OF O~L, GAS OR WATER. Well ~D-12 (43-23-11-13) ~11 History April, 1980 Spud well at 0600 hrs. April 30, 1980., Drilled 17½" hole to 1870'· May, 1980 Drilled 17½" hole to 2715'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2706'. Cemented with 3820 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2663', tested casing to 3000 psi, okay. Drilled out to 2740' ran leak-off test to 0.8 psi/ft, gradient. Directionally drilled 12¼" hole to 8426'. Ran 217 jts. 9 5/8" 47# L-80 Buttress casing to 8413'. Cemented in two stages: First stage with 1134 cu. ft. Class G cement; second stage through D.V. packer at 2612' with 130. -cu. ft' Permafrost C cement preceded by Arctic Pack. Cleaned out to~ 8363', tested casing to 3000 psi, okay. Drilled to 8436' , ran fonuation competency test to 0.7 psi/ft· gradient. Directionally drilled 8½" hole to ~'. Ran open.hole logs' Ran 38 jts. 7" 29# L-80 Buttress casing to 9426'. Cemented with 295 cu. ft. Class G cement. Cleaned out to 9366', tested casing to 3000 psi, okay. Ran (/EL and performed inflow test on 7" liner lap - no inflow.. Displaced well to NaC1. Ran 206 jts. 7" 26# L-80 AB-IJ-4S tubing to 7964' Landed tubing with ball valve at 2-116' Displaced tubing to diesel. Set packer at 7859', tested tubing to 3500 psi, okay. Installed and tested tree. Released rig at 1000 hours, May 19, 1980. d. A. Fouch~ President Mr. Gary Plisga Sohio Alaska Petroleum 3111 C. Street Anchorage, Alaska 99503 June 2, 1980 Re: Our BossGyroscopic Survey Job No. Boss-16594 'Nell D-12 Prudhoe Bay Field North Slope, Alaska Date of Survey: May 26, 1980 Dear Mr. Plisga: please find enclosed the "Original" and sixteen copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity-to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclsoures SOH[O ALASKA PETROLEIJP, CONPANY D-12 T R TOWNSHIP 23T11R13 PRUDHOE BAY ALASKA TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH PAGE SPERRY-SUN WELL . XVEYING COFPANY ~ ANCHORAGE, ALASKA ' .DATE OF S'URVE¥ MAY.'2Ge lg80 "c'oMP'UTATION DATE .......... BOSS GYROSCOPIC SURVEY MAY 29, 1980 dOB NUMBER BOSS-1659q KELLY BUSHING ELEV. = ... OPERATOR-dOHN SAMEL . COURSE .~<:'~./: ,'>'C OuR sE OoG'LEG-.,~, TOTAL ' :'''~ ~ INCLINATION "DIRECTION' 'SEVERI'TY ' RECTANGULAR "CoORDI'N'J~'T~'S DEG MIN DEGREES DEG/lOO NORTH/SOUTH EAST/WEST 71.50 FT. VERTICAL SECTION 0 lO0 200 300 qO0 5O0 0.00.,..i. · -7.1.50 '.': ..'10'0,'00 ..'.."/'>'%' 28.50 200'00, '128,50 300,00 22R,50 399,99 328,49 0 0 E 0,0'0: .- 0 .2 :~ :...:. ..: ~ ..,,,-.:$. 15.~.89: W -o41... .3~ S G 16 :::-;: q'-'89, E .- ,92 S 0 23 S 35,60 id · 0 31 S 19.19 W .18 2.14 S 0'.00 600 599.98 528W48 O 44 S 14.19 E ,42 3,19 S 0 46 S 34.10 E .'27 q,38 S 0,00 .88 ~ · 70 W 1 · 69 W 3- 02 · '15,. W 4.29 700 699.97 628'47 80 0 79 9.96 ?2B,'q 6 900 899.95 828.45 1000 999.94 928.44 1100 1099,':)2 1028,42 1200 1199,88 1128,38 1300 1299.84 1228,34 lq00 1399,81 1328,31 1500 1499,79 1428.29 1600 1599.78 1528,28 1700 1699.78 1628,28 1800 1799,77 172.8,27 0.39 0 '.~- ,:::::-4 1 ........... 0 56 0 53 [ 21 · i -" 38' I. 32 1 .... 0 51 0 0 28 0 26 43,80 E ,17' 5,36 65,80 E ' .'":26:~.,"'.'!6,03 79.69 E ....... ':54 ......... 6,13 65.19 E ,2q 5.65 65.19 E .46 4,82 57,q0 E '"3'5 3,55 45,20 E ""35 ..' 1.~2 41.90 E .56 51.90 E .22 57,29 E ,20 S 25,69 E ' °69 ,08 1,57' 2,~9 3,07 2,95 . .. S ,65 E 5,39 S '.;?'. I..58/i: E"" 6 · 21 s ............ 2,9~' E ........ 6.55 .... 1900 "1899,77 1828,27 2000 1999'74 1928,24 0 ql 1 q3 2100 2099,66 2028,16 2200 2199,53 2128.03 2300 2299.35 2227.85 42 10 2~00 25'O'0 2600 2700 S 2~',.0 E '""'25 S 63, 9 E 1,26 S 54, 9 E ....... 1,0~ S 63,50 S 63.80 2399.11 2498'85 2598.59 2,06 N · 83 N 1'2'3' S E .68 3.85 S E .61 6.55 S E · ,30 9,50 S .'. E -' ' ,07 12,52 E .5q 15,99 E .93 2o,5'8"S S S S .2327,61 2q27,35 2527.09 2698.32 2626.82 16 S 65 '-.19 64 · 89 '5.7 ' 39 44.80 2800 2900 3000 , 2798,00 2726,50 4 54 2897,48 2825.98 6 39 2996,52 2925.02 9 3 S S S 40. 0 25.60 20.10 E ,75 E 2.25 E 2,51 26,50 35,00 47,61 S 4,45 E 6,35 S 6,24 E 5,86 S 8,53 ~E 5,0i' S 10,71 E 3,69 N 12.45 E 2.14 'N ..... i3','?~ E ........ .9o N lq ,69 E ,17 N 15.51 E -, N 16,03 E -,~- 16,44 E"' ,90 18-02-E .. 2,39 21' ;;~7 E 4,~9 25.66 E 8,35 ~1.10 E . 11.97 37 -29 E - 15 S ]'.. '43,78 E 20,10 S 50,09 E" 24,64 55;76' E ............... 30,1& ...... 61,13 E 36,94 66,38 E 46,2'4 71,59 E 59.51' ALASKA PETROLEUM COMPANY SPERRY SUN WELL V - . EYING COMP ANY.. AN'CHORAGE~ ALASKA..~.. L' - DATE'OF SURVEY MAY 26'9 PAGE 2 1980 D-12 T R TOWNSHIP PRUDHOE BAY ALASKA COMPUTATION DATE BOSS GYROSCOPIC SURVEY MAY' 29e 1980 dOB NUMBER B0SS-1659A KELLY BUSHING ELEV, : 71.50 FT. TRUE SUB -SE A COURSE:' OPER ATOR-dOHN "C OUR SE D O'G- LEG TO T'A L SAMEL MEASURED VERTICAL DEPTH DEPTH VERTICAL INCL INATI ON DEPTH DEG MIN 3100 3095,1.3 3200 3193-37 3300 3291.05 3023 · 63 1 O' '::. 3121.87 11 .27 3219,55 3316,A7 15 15 3A12.56 16 55 3507,39 20 2 3AO0 3387.97 3500 3A8A.06 3600 3578.89 DIRECTION SEVERITY RECTANGULAR COORDINATES .... VERTICAL DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION S'19. 0 E -1,01 63.23 S 77,13 E 75,9b S 15,89 E -'1.,53 81,03 S 82.,69 E 9A,~+ S 14,19 E m ?:? S 88,21.,E 115,72 S 17.89 E 2.25 1 ~ 5 m' 2~ s ........ 9'5.0'6 ....E 1~0.15 s 25.z0 E 2.55 z50. 5 s z05.27 z67.26 S 25.I0 E 3.12 179.65 S 118.72 E 197.89 3700 3800 3900 3672,22 3600,72 22: 0 $ 2A.69 E"' :.:.:..:: 1.'98 212.19 S 133,82'E 252,60 3765.18 3693,68 21 I3 S 2~+, 0 E . '82 2A5,75 S 1A9,01 ..E 268,33 3858,70 3787,20 :20'i':.:13 S 23,89 E;"" .':.:/ i::1"00" 278,10 S 1'63,38.'E 302,72 3952,9~ 3881.qq 18 50 S 21. 0 E 1,69 .... 3'08'98 S 176,17 E 335.38 q0~7.85 3976,35 17 51 S 18,19 E 1,33 338,62 S 186,7A E 366,~2 ~163.02 4071,52 17 55 S 17.19 E .31 367.87 S 196.08 E 396.87 AO00 qlO0 q200 qSO0 q238,17 A166.67 17 55 S 16,69'E ' '15 397,30 S 205,05 E A27,q3 ~t353.A8 ~+261.98 1'7 'lB S 15, O 'E ; ,78 ~'.. ~26.,~3 S 213'33 E ~57,56. q~29.02 ~357.52 16 59 S 13. 0 E-" :~ '":'.. '68 .... :' q55.05 S 220'~7 E q86.99 ~700 ~800 4900 A52~,85 Aq53.35 16 1~ S 13.30 E ,75 ~+82,89 S 226.97"E 515.55 4620,96 qSA9.~+6 15 49 S 10.30 E .93 509.91 S 232.63 E ~+717.32 q645.82 15 10 S 9.39 E .69 536.23 S 237.20 E 569._ 4813.95 A7A2.~+5 14 38 S 7.89 E .65 561,66 S 2q1.08 E 595.58 5O00 5100 A910.79 q839.29 lq lA S 6.50 E 5007.76 A936.26 1~) 1 S 3.69 E · SA 586.41 S 2q4,21 E 620.AR · 72 610,73 S 2~6,$8 E 6A4.80 1,60 W 1,81 633.81 S 2A-6',86 E 667,60 8.69 W 1.81 65q.81 S 2~5,02 E 687,94 . 19.50 W 2.18 67q,2~ S 2~0,15 E 706.19 23,10 W 1,20 692,07 S 235,25 E 722,50 29,60 W 1,61 707.57 S 225.61 E 736.~,1 32.10 W 1,~0 720,59 S 217.87 E 7q7.Sq 5200 5300 5400 5105.05 5033,55 12 ~1 5202,79 5131,29 11 A1 5300,7~ 5229,2~ 11 31 5500 5600 5700 5398.89 5327.39 10 32 5A97.38 5q25.88 9 23 5596.22 552~.72 8 2 585 590 600 6100 . . 5695,38 5623.88 6 A6 579q.76 5723,26 6 0 5894l .27 5822.77 5 1 5 S 31,19 W 1.28 731,55 S 211,10 E 757.A3- S 31,60 W .77 7~1,05 S 205,30 E 765.7q S 32,10 W .75 7,q. 9.37 S '200,15 E 773,02 S 39, 0 W ,Sq 756,~0 S 195.15 E 779.05- 5993,90 5922,q0 q. 39 SOHIO .ALASKA~ PETROLECE COMPANY SPERRY'SUN WELL~ b~tVEYING COMPAhY D-12 T R TOWNSHIP 23T11R13 PR UDHOE BAY ALASKA ANCHORAGE, ALASKA · COMPUIATIOfq DATE MAY 299 1980 PAGE coURSE :. COURSE ~ATE OF SURVEY MAY 26$ BosS' '6--~R' OS C(~PI'C -SURVE Y dOB NUMBER BOSS-1659q KELLY BUSHING ELEV. = OPERATOR-dOHN SAMEL · 1 71,50 FT. TRUE ·SUB'SEA MEASURED VERTICAL VERTICAL INCLINATION DIRECTION DOG'LEG '::: TOTAL :, SEVERITY RECTANGULAR co~RD'I'NA'T~S ..... ' ""VE RT'ICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 6200 6093.,59 .:.:60-22,09 63o0 6193 6qO0 6221.66 6500 6.393.3.03 6.321.53 6600 6.q. 92.93 6421 6700 6592,85 6521,.35 .3 ::' S 39,19 W . ',. 7q..: .,..... .... 2o71 SI m , ,,,':182 o12 E ' 2 ql S 45,79 W ,50 776,~2 S 178,75 E 2 2q S 50.89 W .36 779..38 S '175.q3 E 2 19 S 59. 0 W .35 781.75 $ 172.07 E 78q.lr) 788.8, 792.7'8 795.83 798.1.5 799.89 6800 6900 7000 7100 6692,77 6621,27 6792'69 6721,19 6892,61 6821,11 2: 18 S EO.lO S 66,69 · ~ 2 :~ s 69. o 6992,56 6921,06 1 q5 S 71,10 W · 05 .:,'783.80 S '168,58'E': .2 7 · 2 8.:,::. · 27 788" lq S ....... i'5'8"' A2" E 801,28 ~02,~1 803,19 803.75 7200 7300 7092,52 7021,02 i 22 S 89.89 W 7192,49 7120,99 1 25 N 85,60 W .6q 788.6q S 1.55.78 E .1~x 788.55 S 153.3q E 80`3,77 803,25 7qO0 7500 7600 7700 72.92,~6 7220-96 7392,43 7320,93 7~92,q0 7420.90 7592~38 7520.88 75, 0 73.60 68,60 W W W 1 6 N 60,10 W · 23 785.'7~ S 150.8~ E 1 48 · 38:E 1 1~,~",'28 E 802..38 801.26 800.12 798,92 780O 7900 7692.36 7620.86 7792.35 7720.85 1 7 0 q3 N 56. OW · 08 78A,75 S lq2.63 E 797."~ · ~2 783,79 S 1~1,36 E 796. 8000 8100 R200 8300 8~00 ¢.500 8600 8700 8800 7892.3~ 7820.8q 7992,33 7920.83 8092.32 8020.82 0:51 0 51 N ;50.10 : N 16.10 N" 6.10 8192.31 8120.81 8292,29 8220.79 8`392,28 8320,78 53 56 0,80 2~.10 22 · 79 8q92.26 8q20.76 8592.25 8520,75 8692,25 8620,75 0 59 N 88.59 0 32 N 88.80 0 21 N q9.70 ,22 ,26 ,15 .11 1.05 782,87 S 781,66 S 780.20 S 778';'~? S 777.03 S 775,q 2 S 77Q,6~ S 77q.61 S 77~,~0 S lqO .60 E lq0.11 E 139.82 E 139'75'E la?O.1A E lqO,SA E 142.03 E lq3,36 E 1~4.. 06 E 795,39 79q.ll 792.63 791'11' 789,57' 788,11 787,55 787.76 787.68 8900 9000 9100 9200 8792,25 8720,75 8892,25 8820,75 8992,2q 8920.7q 0 20 0 12 0 q3 1 1 9092,23 9020,73 N 30,50 S 6q.89 N 79.60 N qR,20 .12 ,52 .58 ,56 773.95 S 773.77 S 773.73 S 773. Ol S lq*.q5 lqqeq4 '143,66 142.36 E E. E E 787.30 787,12 786.9q 786,01 SOHIO D'12 ALASKA PETROLEUM COMPANY SPERRY-SUN ~ELL ")RVEYING ANCHORAG~.,' ALASKA COIVP ~NY T R TOWNSHIP 23TllR15 COKPUTATIOK DATE ') PA GE q DATE OF SURVEY MAY 2G,~ 1980 BOSS GYROSCOPIC SUR'VE'Y PRUDHOE BAY ALASKA MEASURED DEPTH TR.UE SUB-SEA COURSE VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG HIN MAY 299 1980 COURSE D I-~-E-_CT'I ON DEGREES dOE NUMBER BOSS-1659q KELLY BUSHING ELEV. = 71.50 FTo OPERATOR-JOHN SAMEL -.. DOG'LEG TOTAL S'E'V'ERI'TY:'"'RECIANGO'[ARI''COORD'iNATES''1 VERTICAL" DE.G/lO0 NORTH/SOUTH EAST/WEST SECTION 9300 9192..21 9120.71~:..-..: ~- ! 12 9325 9217'.21 ' ' 91q5'.71 1. 9'~34 ' ".' .'9326' 1 5 ~ A5..70 W 77i.6'8 S lqO.9~':E 784;~5 ........ lq.O ,58 E 78A,. 0 S 769.89 S 139":09 ~' E'" 782.36 HORIZONTAL DISPLACEMENT = 782.36 FEET AT SOUTH,, 10 DEG. 1~+ I~IN. EAST AT MD = 9q3~ THE CALCULATION ~PRO.CEDURES ARE BASED ON THE,.,USE':OF. THREE::.,.rDIMENSIONAL RADIUS OF,'::CURVATURE MEiHOD. : SOHIO ALASKA P ETRC~LEL~ COMPANY SPERRY-SUN WELL .. VEYING COMPANY ANCHORAGE9 ALASKA DATE OF SURVEY MAY 269 -_ )PAGE 5 1980 D-12 T PRUDHOE ALASKA R TOWNSHIP 23T11R15 CONPUTATION DATE BAY MAY 2°.9 1980 ,JOB NUMBER BOSS-1659A KELLY BUSHING ELEV. 71.50 FT. INTERPOLATED V4LLES FOR EVEN lO00 FEET OPER ATOR-UOHN OF MEASURED DEPTH SAMEL MEASURED TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD -TVD VERTICAL DEPTH 100 200 DEPTH DEPTH NCRTH/SOUTH EAST/WEST 0,00 '71,50 0,00 0,00 0 999 0 1999 0 2996 ,gq 928,q~ 5,65 S ~+, .7~+ 1928-24 .83 N 18, · 52 2925,02 47,61 S 71o 45 E 02 E 59 E DIFFERENCE 0.00 .26 3.q8 CORRECTION .20 3.22 AO0 500 600 0 3952, 0 4910, 0 5896. 9q 3881.4q 308.98 S 176. 79 4839.29 586.~+1 S 27 5822.77 7q9.37 S 200, 17 E 21 E 13E A7,06 89,2I 105,73 43'58 42,15 16,52 70O 800 9OO 0 6892. 0 7892. 0 8892. 61 6821.11 787.01 S 161, 34 7820,84 782.87 S 1AO, 25 8820,75 773.77 S 144. 52 E GO E 44 E 107.39 107,66 107.75 1,66 .28 .09 THE C 9326. ALCULATION 19 9254.69 769,89 S 1:39, PROCEDURES ARE BASED ON THE USE OF T 09 E HR EE 107.81 DIMEkSIONAL RADI US OF .0¸6 CURVATURE METHOD. SFERRY-,SUN WELL ')RV EYING ANCHORAGE,, ALASKA SOHIO ALASKA PETROLEUM COMPANY COMPANY DATE OF SURVEY MAY 26, PAGE 6 1980 D-12 T R TOWNSHIP 23T11R13 COMPUTATION DATE PRUDHOE BAY MAY 29, 1980 ALASKA dOB NUMBER BOSS-1659q KELLY BUSHING ELEV. OP£R ATOR-dOHN SAMEL = 71,50 FT, 'INTERPOLATED VALUES FCR EiVEN.'i. iOO:,iFEET O:F SUB-SEA DEPTH ...... TRUE SUB-SEA MEASURED VERTICAL VERTICAL MD-TVD DEPTH DEPTH DIFFERENCE 0 0-00 71 TOTAL RECTANGULAR COORDINATES DEPTH NCR. TH/SOU .," .':..;"'E AS.T/W EST · ~71 ,'50 0'00 ..... O-O0 VERTICAL CORRECTION 171 2,71 71,50 0,00 ,i. 5 S · 171.50 100,00 ,79 S ,19 W .00 271.50 200.00 1.28 S .00 .00 371 q71 571 371,50 300,00 1,.90:S ,62 W q71,50 400,00 2.8~ S ,78 W 571,50 .:'500.00 q-06 S ,37 W · 01 ,01 -02 .00 .01 .01 671 671,50 600.00 5,13 S ,40 E 771 771,50 700,00 5,89 S 1.26 E 871 871.50 800.00 6.21. S 2.47 E .03 .01 ,01 .01 971 1071 1171 1271 1371 lA71 971,50 1071 · 50 1171,50 ' 900.00 5.8q S 4°05 E .06 1000.00 5.11 S 5.63 E .07 llO0,O0 3',99 S 7°8q E ,lb 1200-00 2.36 S 10.16 E .14 1300,00 ,46 S 12,01 E ,18 lqO0.O0 1.26 N 13.~+6 E .21 1271 1371 1471 ,5O ,50 ,50 ,01 · 03, '.! ,Oq .°0 3 1571 1671 1771 1571 1671 1771 °5O .50 .50 1500'DO 2,28 N 14,~3 E 1600,00 2,9A N 15, 31 E 1700,00 3,15 N 15,93 E .22 .22 .23 ,01 ,01 ,00 · .) SOH!O ALASKA PETROLEU~ COMPANY D-12 T R TOWNSHIP PRUDHOE BAY ALASKA 23TllR13 SPERRY-SUN WELL VEYING COMPANY ANCHORAGE; ALASKA CORPUTATION"'DATE RAY 29,~ 1980 SURVEY .~ PAGE 1980 dOB NUMBER BOSS-1659~ KELLY BUSHING ELEV, = OPERATOR-JOHN S.AM. EL 71,50 FT, INTERPOLATED VALUES FOR EVEN':~.io0 F£ET..OF 'SUB-SEA.: DEPTH ~EASURED DEPTH TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH TOTAL RECTANGULAR COORDINATES FC-TVD NORTH/SOUTH EAST/WEST.. .DIFFERENCE .... VERTICAL CORREC'T ION 1871 1971 2071 2171 22,72 1871', 50 ~i i'800.00 19'71.50 ......... 1, oo.oo 2071,50 2000,00 2171,50 2100,00 227.1.50 2200,00 · q5 S 20,19 E '3,16 S 2~+,26 E · 23 ,.00 · 25 ........... "02 ............... · 30 .06 ,~$ ,12 · 59<' :. . ,.-,- .17 2372 2~72 2572 2673 2773 2371,5'0 ..': 23 00 * 00 2~.7.1,' 50 ....-2~00,00.:' ........ 2873 297q 3075 3177 3279 3382 3592 3699 2571.50 2500.00 lq .9~+ S 2671.50 2600,00 19,16 S 2771,50 2700,00 2~,75 S 2871,50 2800'00 32,27 S 2971,50 2900,00 ~3,86 S 3071,50 3000,00 59,28 S 317i,50 ......... 3100,O0 ' ' 76,77 S 3271.50 3200.00 97.21 S 3371,50 3300,00 120.97 S ~+8. ~ E 5~, 3~ E 59,67 E 65, 07 E" 70,22 E 75'77 E 87,08 E 93,67 E 3~71,50 3q. O0,O0 1~+7.51 S 3571.50 3500,00 177,25 S 3671,50 3600,00 211,93 S 1,3~ .26 1,60 ,27 1,90 3'16 ,82 ~,50 1,3~ 6,16 ........ 1'"6'9 8.~2 2,23 11.~3 3.01 15,39 3.96 20.65 5,26 27,72 7,08 103, 71 E 117, 59 E 133,7.0 E SOHIO ALASKA PETROLEUP COMPANY SPERRY-SUN WELL .)~V EYING ANCHORAGE, ALASKA COPPANY DATE OF SURVEY MAY 26, ) PAGE 8 1980 D-12 T R TOWNSHIP PRUDHOE BAY ALASKA 23TllR15 COMPUTATION DATE MAY 29, 1980 ,JOB NUMBER BOSS-1659q KELLY BUSHING ELEV, 71.50 FT. INTERPOLATED VALI;ES FOR EVEN l'O0 FEET OF SUB' SEA OPERATOR-dOHN SAMEL DEPTH TRUE MEASURED VERTICAL SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES ~D -TVD VERTICAL DEPTH DEPTH 3806 DEPTH NORTH/SOUTH EAST/WEST .'5771.50 :5700.00 3913 3871.5{3 3800.00 4019 25971 °50 25900. O0 4`12q ~+071.50 2q'8,,00:S 150.01 E 282.~-1 S 165.29 E 314`.89 S 178.~,4` E 345.85 S 189.12 E DIFFERENCE 35,28 4`8.11 53,34` CORRECT ION 7,55 6.86 ............. 5.97 5.23 4229 ~335 4171,50 4100,00 4`271,50 4200.00 ~371.,50.. ' q300,O0 376'67 S 198.80 E 58.43 5,09 407.63 S 208,15 E 6:3,53 5,10 ~37.89 S 216,40 E 68.33 ~,80 q6q8 4752 4856 959 5062 4`471,50 q571,50 4500,00 ~671,50 ~600,00 ~,771.50 ~700-00 ~,871.50 4,971.50 ~,67.66 S 223.38 E 72.91 496.10 S 230, 03 E 77,08 523.93 S 2:55.15 E 81.01 5165 5071,50 5000,00 5268 5171,50 5100. O0 5370 5271,50 5200,00 550'66 S 2.'59.53 E 576.50 S .. 243.07 E 601,68 S. ' 245, 80 E 626,25 S 2~7,07 E 6q8,4`1 S 246.00 E 668.62 S 24` 2,14 E 9~. 11 96,55 '58.65 ~,.57 4o18 3,93 :5.6 0 3.35 3.16 2'99 2.44 2.11 5472 5371.50 53~0.00 5573 5q71.50 5400.00 5675 5571.50 5500.00 687,38 S 235.2,3 E 703.85 S 227.72 E 717,63 S 219.72 E 108,6~ 102,27 103.54 1.98 1,65 1.27 SOHIO ALASKA PETROLEUM COMPANY SPERRY-SUN WELL. EYING COMPANY ' ' ANCHORAGE'~ ALASKA. · · · · , DATE OF ,SURVEY MAY 26, ,) PAG~ 1980 D-12 T R TOWNSHIP 23T11R13 PR UDHOE BAY ALASKA COMPUTATION DATE MAY 2~ 1980 dOB NUMBER BOSS-1659A KELLY BUSHING ELEV. = 71.50 FT. MEASURED INTERPOLATED TRUE SUB-SEA VERTICAL VERTICAL OPERATOR-JOHN .. VALUES FOR.. EVEN 1,_ D_ Omm FE.ET. OF ,SU'B''SEA'':DEPTH TOTAL RECTANGULAR COORDINATES MD--TVD VERTICAL SA~EL DEPTH DEPTH DEPTH NCRTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5671'50 5600.00 5876 5771.50 5700.00 5977 5871.50 5800.00 6g77 5971.50 5900.00 729.13 S 212.56: E ......... 10zt--/+5 ..... .92 738,97 S 206,58 E 1~5,12 7/+7,60 S 201.25 E 1~5,63 75/+.98 S 196,30 E 6177 6071.50 6000.00 6278 6171,50 6100.00 6378 ,: 6271,50 '62.,00-'00 6/+78 6371.50 6300.00 761,18 S 191"30 E 106,35 766,88 S 186,77 E 106,61 ,27 771.81 S -182,'86. E 106,81 ,20 775.71 S 179,/+7 E 106,9/+ ,13 6578 6/+71,50 6/+00,00 6678 6571,50 6500, O0 778,81 S 176.13 E 107,05 ,10 781.30 S 172.81 E 107.13 .09 6778 6878 6978 6671'50 6600.00 6771'50 6700:'00 6871.50 6800'00 7078 6971',5D 6900,00 783,37 S :.: 16 9' 33 E 107.22 , . · 785,26 S 165'78 E I67,30 786,75 S .: 162,22 E 107.37 787.93 S 159.04 E 107.43 7178 7071.50 7000.00 7279 7171.50 7100.00 788,64 S 156o28 E 107,/+7 788,59 S 153,86 E 107,50 ,Oq .03 7379 7479 7579 7271.50 7200-00 7371,50 7300,00 7/+71.50 7AO0.O0 788,,26 S 151.36 E 167.53 787.57 S 148-88 E 107.57 786'8q S 1/+6.57 E 107.60 ,03 ..... -- i~.'~'::::i:-~ ..... ~-----~'~ .......... -~'PERRY-SUN WELL RVEYING COMPANY · '. ANCHORAGE',~ ALASKA SOHIO ALAsKA:pETRO:LEuM COPPANY D ATE OF SURVEY MAY 26~ 1980 D-12 T R TOWNSHIP 23711R15 PRUDHCE BAY ~LASKA COMPUTATION DATE MAY 299 1980 dOB NUMBER B0SS-1659~+ KELLY BUSHING ELEV. = OPERATOR'dOHN ,SAMEL 71.50 FT. TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ~D-TVD VERTICAL' DEPTH NORTH/SOUTH EAST'/WEST '; DIFFERENCE CORRECTION 7779 7671.50 7600.00 781+.98 S lq2.97 E 107.Gq 7879 7771.50 7700.00 783.96 S lZ+1.55 E 107.65 7979 7871-50 7800.00 783.07 S 1~0.72 E Z07.GG ,02 °02 .01 8079: : ' 7971.50 : 7900'00 8179~ -~807I:.50':~-:~:? 8000'00 8279" 8!71,50 '00 8379 8271.50 8200.00 777.38 S 139.99 E 8q79 8371.50 8590,00 775,73 S lq0,71 E 8579 8~71,50 8~00,60 77~+,65 S 1~1,67 E 778.9 9 s :: !.3'?:' 75 E 8679 8571-50 8500.00 77q,62:?:S ' lq. 3.16 E 8779 8671.50 '8600,00 77~1,q9 S' .1Q'3,97 E . 8879 8771.50' 8780,00 lqq-39 E 8979 8871.50 8800.00 773.7q S 1~q.51 E 9079 8971'.50 8900.00 773,78 S 1~,3.92 E 9179 9071,50 9000.00 773.26 S 1~+2.6~ E 107,71 107.72 107,7q 107' 75 107'75/'i :107 · 75' i~.'":i 1C!7.7'5 107.76 107.77 · 01 :-: ,01 .02 ,0! .00 ,01 9279 9171.50 9100,00 771.99 S lql,25 E 9379 9271.50 9200,00 770,62 S 139.8~ E 9~3q 9326,19 925fl,69 769.89 S 139.09 E 1~7,79 107,80 107.81 .02 .02 .01 THE CALCULATION PROCEDURES USE A LINEAR INIERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM PADIUS OF CURVATURE) POINTS Sohio Alaska Petr~ ,leum woil-D2.12 ; ........... "_::..i~-i ...: _ ..; ............... : ................... : ...... Horizontal ProjeCtion ' ': - --~ .................................................... : Scale 1" = 100' ......... ,. May 26, 1980 ........ -[., : · I Contro]ied Drilling Consultants P.O. BOX 11~g PAL.ME.~ ALAS~ gg645 PHONE: 376-5423 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AX 99502 RE~ Magnetic Single Shot Survey Job No. A 0.580-013 Well D-12 Prudhoe Bay Field North Slope, Alaska Date of Survey~ May 2, 1980 to May 13, 1950 Dear Mr., Rose~ Please find enclosed the ~Original# ar~i six (6) copies of our Magnetic Single Shot Survey on the above well. The method use~ in calculating the survey was radius of curvature. The depth interval of the survey was 2?00 to 9435. Thank you for giving us this opportunity to be of service. Yours ~ very truly, Controlled Drilling Consultants Cecil W. Harrin~on~~ Direc$i~nal Supervisor :OMPLETION REPORT ,OHIO ALASKA PETROLEUM !AGNETIC SINGLE SHOT SURVERY :ADIUS OF CURVATURE METHOD OF COMPUTATION :OMPUTED FOR CDC BY FN L iNDSEY & ASSOC 15 MAY 80 WELL D-12 K B ELEV 7t,50 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COI,,1PUTER TRUE lEAS. DRIFT VERTICAL ,EPTH ANGLE: DEPTH D M SUB DR iFT SEA DIREC DEG. o o oo.oo , o.oo 2700 0 2699.86 2 : N O.OOE 277~ 4 30 2773,76 2702.26 553,00E 2868 5 45 2867.38 2795.88 S40.OOE 2961 8 0 2959.71 2888.21 S32.00E 3055 9 30 3052.61 29181.11 S29.00E 3149 10 30 3145.18 3073.68 S28.00E 3273 12 30 3266,69 3195.19 S24,00E 3365 14 15 3356.19 3284.69 $24.00E 3459 15 45 3446.98 3375.48 S31.OOE 3583 18 45 3565.39 3493.89 $36eOOE 3674 21 45 3650.76 3579.26 S35.00E 3794 2] 15 3762.41 3690.91 S33.00E 3918 20 15 3878.36 3806.86 $33.00E ~075 18 15 4026.58 3955.08 S31.OOE 4234 18 15 4177.58 4106.08 S29,00E 4358 17 45 4295.51 4224,01 S27.00E 4512 17 15 4442.38 4370.88 S25,00E 4668 16 0 4591.86 4520.36 S23.00E 6827 15 15 4744.98 4673.48 S21.OOE 5005 14 15 4917.11 4845.61 S17.00E 5129 13 45 5037.43 4965.93 S13.00E 525a 11 45 5159.34 5087.84 S 7.00E 5380 11 45 5282.70 5211.20 S 6.OOW 5503 10 15 5403.44 5331,94 S12.00W TOTAL COORDINATES 0.00 S 0.00 W 23.56 N 0.00 W 24.84 N 2.56 E 19.07 N 8.64 E 10.07 N 15.18 E 2.24 S 22.43 E 16.58 S 30.22 E 38,80 S 41.06 E 58.24 S 49.71 E 79.81 S 60.94 E 110.45 S 81.22 E 136.09 S 99.51 E 172.55 S 124.10 E 209.40 S 148.03 E 253.29 S 175.46 E 296.41 S 200.35 E 330.24 S 218.34 E 371.86 S 238.64 E 412.63 S 256e79 E 452,33 S 272,83 E 495.18 S 287.59 E 524.15 S 295.35 E 551.30 S 300.14 E 576,90 S 300.36 E 600,07 S 296.69 E C L 0 S U R E S DISTANCE ANGLE D N S 0.00 S 0 0 0 W 23,56 N 0 0 0 W 24.97 N 5 53 45 E 20,94 N 24 22 40 E i8.21 N 56 25 47 E 22.54 S 84 17 14 E 34.47 S 61 14 25 E 56e49 $ 46 37 8 E 76.57 S 40 29 0 E 100.41S 37 21 54 E 137.11 $ 36 19 47 E 168.60 S 36 10 29 E 212.55 $ 35 43 29 E 256.44 $ 35 15 29 E 308.13 S 34 42 ~0 E 357.77 $ 34 3 22 E 395.89 S 33 28 16 E 441.8~ S 32 ~1 25 E 486.01 S 31 ~ ¢~ E 528.25 S 31 5 50 E 572.63 S 30 8 49 E 601.63 S 29 24 2 E 627.71 S 28 33 53 E 650.41 S 27 30 12 E 669.41 $ 26 18 32 g DOG LEG SEVER~I'Y DEG/iOOFT 0.037 4.848 1.337 2.425 1.598 1.064 1.620 1.902 1.687 3.300 0.471 0.806 1.280 0.394 0.430 0,344 0.807 0.480 0.578 0.442 1.612 2.097 1.229 SECT ION DISTANCE _2~'00 -2'2.80 -15.42 -~.83 9.13 25.18 49.67 70.84 130.2P 202.65 245.12 295.38 344.11 381,87 427,74 472e14 514.87 560.17 590.12 617.41 641.81 662.68 OHIO WELL D-12 SINGLE SHOT SURVEY 15 NAY 80 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B N ELECTRONIC COMPUTER TRUE EAS, DR!FT VERTICAL .EPTH ANGLE DEPTH SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5659 8 45 5557.29 5485,79 S21.OOW 5815 6 45 5711.86 5640,36 S21,OOW 6002 5 15 5897,83 5826,33 $23.00W 6481 2 45 6375.63 6304.13 S31.OOW 6962 1 45 6856.25 6784,75 S58,00W 7441 I 0 7335.11 7263,61 NSI.OOW 7919 0 30 7813.07 7741,57 N58.00W 8366 0 a5 8260.04 8188,54 N37.00E 9364 0 45 9257.95 9186.45 N53.00W 624.73 $ 289,39 E. 644,37 S 281.85 E 662,49 S 274,52 E 692.24 S 259.37 E 705.58 $ 246,26 E 707,83 $ 235.23 E 705.65 $ 229.41 E 701.39 S 228.62 E 689.74 S 226.98 E 'D EXTENDED TO 9434 9434 0 45 9327.95 9256.45 N53.00W 689,19 S 226,25 E CLOSURES DI STANCE ANGLE D M $ 688,50 S 24 51 15 E 703,32 $. 23 37 28 E 717,12 S 22 30 30 E 739,24 S 20 32 24 E 747,32 S 19 14 22 E 745.89 $ 18 23 0 ~ 742,01S 18 0 35 E 7~7,71 S 18 3 13 E 726.13 S 18 12 56 E 725.38 S 18 10 28 E DOG LEG SEVERITY DEG/iOOFT 0,97i 1.282 0,802 0,522 0.208 0,157 0,105 0.106 0o000 SECTION DISTANCE 683,83 700,14 715.07 '738.61 747,19 745,89 742.00 737.71 726.13 725,38 OTTO~ HOLE CLOSURE 725,38 FEET AT S 18 10 28 E ) i©HIO WELL D'12 iEASURED DEPTH AND OTHER DATA FOR ) SINGLE SHOT SURVEY EVERY EVEN 100 FEET OF SUB SEA DEPTH, 15 'MAY 80 MEASURED DEPTH TRUE VERTICAL SUB DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 172 '272 372 47 2 572 672 772 872 972 1072 1172 1272 1372 1/+72 1572 1672 1772 1872 1972 2072 2172 2272 2372 2a72 2572 2672 2772 2872 2973 3074 3176 3278 3381 3484 3589 172. 100 272. 200 372, 300 472, 400 572, 500 672. 600 772, 700 872. 800 972. 900 1072. 1000 1172. 1100 1272. 1200 1372. 1300 1472. 1400 1'572. 1500 1672. 1600 1772, 1700 1872. 1800 1972, 1900 2072. 2000 2172. 2100 2272. 2200 2372. 2300 2472. 2400 2572. 2500 2672. 2600 2772. 2700 2872. 2800 2972. 2900 3072. 3000 3172, 3100 3272. 3200 3372. 3300 3472. 3400 3572. 3500 0 0 0.09 N 0 0 0.23 N 0 0 0.44 N 0 01 0.71N 0 0 1,05 N 0 0 1.45 N 0 0 1.92 N 0 0 2.45 N 0 0 3,05 N 0 0 3.71 N 0 0 4,43 N 0 0 5,22 N 0 0 6,08 N 0 0 6.99 N 0 0 7.98 N 0 0 9.03 N 0 0 10.14 N 0 0 11.32 N 0 0 12,56 N 0 0 13,87 N 0 0 15.24 N 0 0 16.67 N 0 0 18.17 N 0 0 19.74 N 0 0 21.37 N 0 0 23.06 N 0 0 24,87 N 0 0 18.76 N 1 1 8,65 N 2 1 5.01 S 4 2 21.00 $ 6 2 39.78 S 9 3 61.81 S 12 3 85,70 S 17 5 112.02 S 0.00 W 0.00 W O.OOW 0,00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0,00 W 0,00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 2.42 E 8.90 E 16.06 E 23,96 E 32,53 E 41,49 E 51e34 E 64.55 E 82.36 E OHIO WELL D-12 EASURED DEPTH AND OTHER DATA FOR ) SINGLE SHOT SURVEY EVERY EVEN 100 FEET OF SUB SEA DEPTH. 15 MAY 80 MEASURED DEPTH TRUE VERTICAL SUB DEPTH SEA HD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3696 3804 3911 4017 ~+122 4228 4333 4438 4542 4647 4751 4854 4958 5061 5t6z+ 5266 5369 5471 5572 5673 5774 5875 5976 6076 6176 6277 6377 6477 6577 6677 6777 6877 6977 7077 7].77 3672, 3600 3772. 3700 3872. 3800 3972. 3900 4072- 4000 4172. 4100 427'2. 4200 4372. 4300 4472. 4400 4572. 4500 4672. 4600 4772. 4700 4872. 4800 4972. 4900 5072, 5000 5172, 5100 5272. 5200 5372. 5300 5472, 5400 5572. 5500 5672. 5600 5772, 5700 5872. 5800 5972. 5900 6072. 6000 6172. 6100 6272. 6200 6372. 6300 6472. 6400 6572. 6500 6672. 6600 6772. 6700 6872, 6800 6972, 6900 7072. 7000 24 32 39 45 50 56 61 66 70 75 79 82 86 89 92 94 97 99 100 101 102 103 104 104 104 105 105 105 105 105 105 105 105 105 105 7 8 7 6 5 6 5 4 5 4 4 3 3 2 2 1 1 1 1 1 0 0 1 0 0 0 0 0 0 0 0 142.77 175,51 207.27 237.~4 265,94 294.65 32~,38 351,84 379.88 407.23 433,46 458.95 484.02 508,32 532,12 553.73 574.58 594.30 611.60 626.70 639.70 650.71 660.22 668.47 675.73 682.11 687.54 692.07 695.93 699.23 701.96 704.15 705.82 707.10 707.87 104.16 E 126,02 E 146.65 E 165,81 E 182,97 E 199,38 E 214,82 g 229,10 E 242.35 E 254.49 E 265.41 E 275,33 E 284.07 E 291.38 E 297,07 E 300,41 E 300,58 E 297.85 E 293,82 E 288,63 E 283.64 E 279e37 E 275,49 E 271.91 E 268,50 E 265,26 E 262.24 E 259,48 E 256.91 E 254,20 E 251,~1 E 248,60 E 245.87 E 243e29 E 240,81 E ;:OHIO WELL D'12 SINGLE SHOT SURVEY IEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 15: MAY 80 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORB INATES 7277 7172. 7:00 105 0 7377 7272. 7200 105 0 7477 7372. 7300 105 0 7577 7472, 7400 105 0 7677 7572. 7500 105 0 7777 7672. 7600 105 0 7877 7772. 7700 105 0 7977 7872. 7800 105 0 8077 7972. 7900 105 0 81.77 8072, 8000 105 0 8277 8172, 8100 105 0 8377 8272, 8200 105 0 8477 8372, 8300 105 0 8577 8472, 8400 105 0 8677 8572, 8500 105 0 8777 8672. 8600 105 0 8878 8772, 8700 1C6 8978 8872, 8800 106 9078 8972. 8900 106 0 9178 9072. 9000 106 0 9278 9172. 9100 106 0 9378 9272. 9200 106 0 708.18 708.08 707.72 707.36 706.9i 706.41 705.88 705.33 703.51 702.38 701.27 700.31 699.49 698.85 698.40 698.13 698.08 698.23 698.59 699.13 689.63 238,49 E 236.41 E 234.62 E 231,74 E 230.63 E 229.73 E 229.00 E 228.44 E 228,15 E 228,22 E 228.71 E 229.59 E 230.61 E 2~1,75 E 232.98 E 234.27 E 235.57 E 236.87 E 238.13 E 239.32 E 226.84 E iOHIO WELL D-12 NTERPOLATED VALUES FOR, EVEN T RUE MEASURED VERT/: CAL DEPTH DfEPTH lO00 SUB SEA 1000 999. 928. 2000 1999. 1928. 3000 2998. 2926. 4000 3955. 3884, 5000 4912e 4-840. 6000 5895. 5824. ?000 6894. 6822. 8000 7894. 7822. 9000 8893. 8822. SINGLE SHOT SURVEY FEET OF MEASURED DEPTH. TOTAL COORDINATES 3.23 N 12,,92 N 5.26 N 232.75 $ 494.00 S 662 . 33, S 706 , 16 $ 705.17 S 698.10 S 0,00 W 0.00 W 18,11 E 162.89 E 287,23 E 274,60 E 2~+5.27 E 228.85 E 235 · 87 E i5 MAY 80 ..... : .... HORIZONTAL .VIEW __ ' ! ' - [ ............. SOHIO ALASKA. PETROLEUM ~ ....... i ' ....... WELL D- 12. .......... ' ..... RADIUS OF CURVATURE · i ' ": ·" '~ - ~ -. -~ · .'.- .'-.. ' -MAGNETIC SINGLE SHOT · "-; ..... SCALE~ III-- i i , ' ' MAY 15, 1980 i DEPTHS SHOWN ! : : : '" ' i ':': ''' ' ~' - '" : "' 'j i'.'' .i .' .ii-'- : · . ! ' -,"l'i ; '- '" : ........ . ' ' - '' ' ~.. ,,, oOO ~'* 9 ~,.00 .% ' . ........ ~ .:--:.-~':.-: ........ .... CLOSURE_..S 18 .i0. 28..E',725' TMD= 94'34' '- .... ~ .... '. I.... ~ , - . ...............,' ;"'; . i.._'~ ......... . ............ ' -'-'!7_':T"77~'"."!/'"7!*"7;';';~;"7'' ;7'-'*i-':_ - ; .............................! '~: , ' ' . L,_.: ....... . ~ . ......... , ..... ,,, : · , .: .................... ~ ........................................ o -" "'": ~ ......... ' ........... .i": .......................... . VERTICAL SECTION · · .- ...... : ............ SOHIO ALASKA PETROLEUM - - 400 " -- - WELL D-12. - - RADIUS OF. CURVATURE 8oo .... MAGNET~ICo,.,,,,=, SIiNoGoLoE, SHOT ........................... ~ ..... ; ......................... MAY 15 19S0 .......... i ....... 1200 ................. ..... i ; .... ~ · - ; t ' . ........ : - -- .. i .. ! ; . ' .... ...... ,. - · 2400 .... ~ - 2800 '* , , $200 .... '. ' , ~ , . ; r :~6oo-~ ,:. ; ,'. ~-' i'"':,': '"" :: . ,: , . : :. . . oo~ '' . \'' "i .... ; '; .........i ....... ' : ......... ! ALL DEPTHS 'SHOWN / ' \ '." .' . ' .:-: i' '-" '= ' '..I ARE TVD. ' l: ~ ', , ~2oo~ i . ~. -": ,'[' - :-'-.i' "-i _ ~ : ', ' . , ' ' · 600} i '-i..-~ ,-,'--,:-: :~ !- { ' :' ' ', , ...... . ,' .......... ,... ~. . !. . , ~ , ,, -..~ 6000 ................ : ................, ......................7 .................. ~ ......................... ~" i ..................... I : . . - . 6400 ..... i 1600 .... 2000 6800 7200 760 8000 8400 8800 9~0(~ , CONFER: FILF: SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 6/16/80 #207 REFERENCE: SFO/UNIT/STATE: SOHIO OPEN HOLE FINAL DATA ~0 Ilowing material is being submitted herewith. Please acknowledge recei?t by signing a copy of this letter and returning it to this office:-- D-12 DIL/SFL 5/14/80 D-12 BHCS 5/14/80 D-12 FDC 5/14/80 D-12~ RFT 5/14/80 ........ D~ic~ FDC/CNL 5 / 14 / 80 9-12 Magentic Single Shot Survey D-12 Gyroscopic Survey #1 #1 #1 #1 #1 5/2-13/80 5/26/80 Anne Barns Well Records 2" & 5" 2" & 5" 2" & 5" 2" & 5" SOHIO ALASKA PETROLEUM COMPANY June 5, 1980 3111 'C" STREET~ ANCHORAGE, AL~K~--- MAIL: POUCH 6-612 Alaska Oil & Gas CoD~ervation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (.43-23-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-namedw~ll for the month of May, 1980. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer Fot, m No. 10-46'4 ,/~ SUBMIT IN DUPLICATE REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285. WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 D-12 (43-23-11-13) 4. LOCATION OF WELL At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,' ~P~__d_hoe Oil Pool 11. SEC. T. R, M. (BOTTOM HOLE OBJECTIVE) Sec. 23, TllN, R13E, UI::~I 12. PERMIT NO. 80-15 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. May, 1980 Drilled 17 1/2" hole to 2715'. Ran 6.9 jts. 13 3/8" 72# L-80 Buttress casing to 2706'. Cemented with 3820 cu. ft. Permafrost II ceanent. Installed and tested BOPE. Cleaned out to 2663', tested casing to 3000 psi, okay. Drilled out to 2740', ran leak-off test to 0.8 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8426'. Ran 217 jts. 9 5/8" 47# L-80 But+_resS casing to 8413'. C~ted in two stages: First stage with 1134 cu. ft. Class G ~t; second stage through D.V. packer at 2612' with 130 cu. ft. Permafrost C c~t preceded by Arctic Pack. Cleaned out to 8363', tested casing to 3000 psi, okay. Drilled to 8436', ran formation cc~petency test to 0.7 psi/ft, gradient. Directionally drilled 8 1/2" hole to 9434'. Ran open hole logs. Ran 38 jts. 7" 29# L-80 Buttress casing to 9426'. Cemented with 295 cu. ft. Class G cement. Cleaned out to 9366', tested casing to 3000 psi, okay. Ran CBL and performed inflow test on 7" liner lap- no inflow. Displaced well to NaC1. Ran 206 jts. 7" 26# L-80 AB-IJ-4S tubing to 7964'. Landed tubing with ball valve at 2116'. Displaced tubing to diesel. Set packer at 7859', tested tubing to 3500 psi, okay. Installed and tested tree. Released rig at 1000 hours, May 19, 1980. EFW: ja 14. I hereby cer~~ TiTL~)istrict Drillinq EnqineerDATE ~' ~ ' ~ D SIGNED NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SOHIO ALASKA PETROLEUM COMPANY 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well D-12 (.43-23-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover .Operations, for the above- ~ well for the month of April, 1980. Yours very truly, AMR: ja Enclosures cc: Well File #17 Austin Reid Acting District Drilling Engineer Form~o. 10-404 f~ SUBMIT IN DUPLICATE REV. 3-1-70 : ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612., Anchorage, Alaska 99502 D-12 (43-23-11-13) 4. LOCATION OF WELL At surface: 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 23, TllN, R13E, BI:lq 12. PERMIT NO. 80-15 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. April, 1980 Spud well at 0600 hours, April 30, 1980. Drilled 17 1/2" hole to 1870'. EFW: ja 14. I hereby certify that the foregoing is tja4e an correct Austin ~-td TITLEDistrict Drilling E~gineerDATe ~/~/~o. . NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committ~ by the 15th of the succ~ding month,units otherwise direct~l. Alaska Oil and Gas Conservation Ca~ission Hoyl e H. H~rni 1 ton Chairman of the ~~/'ion C<xrmi ss i~er May 5, 1980 Bobby D; roster~.-2T- PetroletE Inspector Witness BOPE test on S OHIO's D-12 Sec. 23, TllN, H13E, LM Permit #80-15 Frida~y.., May 2, 1980 i'-t'ra~e"led this '~te to Prudhoe Bay after beir~ contacted by Mr. John Salario, SCHIO dr i 11 in~ foremm~, request in~ an inspector to wi tness the upccming BOPE test on D-12. ~a turda¥, May The BOPE test began at 8:30 AM and was concluded at 11:00 AM. the test are attached to this report. The results of In s~mmry I witnessed the BOPE test on S/~IOms D-12. Attach~ Monday, .Ma[. 5, 1980 Mr. John saiari0 'Co~tacted Mr. Doug ~nos at the A.O.G.C.C. office this date and informed him that the Kelly -~-alve had been repaired and tested to 5000 psig. The test was o.k. Ala:O Oil and Cas Conservation Fiel'd Insl~:chion of B].c~,'ou~'- Pcevention I~qu:J.D:'.)2nt oca .io ,: s c_2_ T//.¥ Location, General ~ Well Sign ~~ C~ner~l Housckccping ~~ BO?E S kack ~nular Preve~,'ker___ / __ Pipe R,-~,~ 2 Blind R~ns / Choke Line Valves / U.C.R. Valve 1 ~Kill Line Valves / Check Valve ~ [Test Pres sure ACCTJP,,~ LATOR SYST E74 Full Charge Pressure~_~O ........ })sig' Pressure After C[osurc_/_ ~_ ~ ........ !/:', J.q 200 psig A~x~vc Prccha~-g'_~ Att,.~'inc(: ........ ~,',:,n_~:~: . Full ~arge Pressure Attained: ~ min~ so Con~°ls: M~ster ~.~ Valves Uppeu Kel ly___~___ Lower Kelly_ / Bal 1 TYFe_ 3 Inside ~,OP /_ Choke Manifo!d~f_~__'.rest Pressure--~___~._~ .. vazws days and Test Results: Failures_ ~- Test Repair or Replacdnent of failed ~tui~me:,~ to 1~ made Inspector/Commission office notifie~]. orig. - AOa~C cc - Field Otmrator/Sui:'ervisor January 30, 1980 Re= Prudhoe Bay Unit D-12 Sohio Alaska Petroleum Company Permit No. 80-15 Sur'. Loc_.: 2930tSNL, 1067tWEL, Sec. 23, TllN, R13E, UPM. Botto~hole Loc.: I$10tNSL, 820~WEL, Sec. 23, TllN, R13E, UPM. Mr. P.' R. Judd District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Judd: Enclosed is. the approved application for permit to drill the above referenced well. Well samples, core .chips and a mud log are not required. A directional survey is re. Taired. If available, a tape contain- ing the digitized log information on all logs shall be sub- mitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spaWning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinatorws office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~r. P. R. Judd Prudhoe Bay Unit D-12 -2- January 30, 1980 co~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of LabOr is being notified of the issuance of this permit to drill. ~ To aid us in scheduling field work, we would' appreciate your notifying this office within 48 hours after the well ks spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adeguate advance notification so that we may have a witness present. Very truly yours, Hoyle H. Hamit ton Chairman of BY ORD~,~ OF Alas~ Oil &. Gas ConServation Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o e~nc. 1. SOHIO ALASKA PETROLEUM COMPANY January 18, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. H. H. Hamilton Well D-12 (43-23-11-13) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Surveyor's plat showing well location. PRJ: ja Enclosures cc: Well File #17 Yours very truly, SOHIO ALASKA PETRO~ CC~PANY P. R. Judd District Drilling Engineer Form 10-401 REV. 1-1-71 SUBMIT IN TRIP. £E (Other instruction~ on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [] DEEPEN [--] b. TYPE OF WELL OIL GAS SINGLE MULTIPLE WELL O OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Coupany 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 2930' SNL, 1067' WEL, Sec. 23, TllN, R13E, UPM At proposed prod. zone 1610' NSL, 820' WEL, Sec. 23, TllN, R13E, UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 10 miles N-~ of Doadhorse API # 50-029-20443 6. LEASE DESIGNATION AND SERIAL NO. ADL 28285 ?. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bav Unit -- 9. WELL NO. D-12 (43-23-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, TllN, R13E, UPM 12. 14. BOND INFORMATION: V~E Blanket Surety and/or No. American Insurance Co. 3348616 Amount $100,000.00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1610' north of ADL 28286 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2621' west of Well D-5 21. ELEVATIONS (Show whether DF, RT, CR, etc.) est. KBE = 70' AMSL 16. No. OF ACRES IN LEASE 2560 19. PROPOSED DE~H 9386'MD 9274'TVD 17. Ne. ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START March 15, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE MD SETTING DEPTIq~VD Quantity of cement 36" 20"x30" Insulated Co:Ktuctor 110' 110' 8 cu.yds. Arcticset Concrete 17%" 13 3/8" 72# L-80 2700' 2700 ' 4500 cu. ft, Permafrost II 12¼" 9 5/8" 47% L-80 8486' 837'4' 1375 cu.ft. Cla~s G:130 ~,.f~_. 8%" 7" 29~ L-80 9386' 9274' 320 cu.f~. Cla.~ C, See attached proposed drilling program outline. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to ch'ill or deepen directionally, give pertinent data on subiurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify~~g~TrLa d~ DATE District TITLE Drillinq Enqineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ NO DIRECTIONAL SURVEY REQUIRED ~YEs [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES [~i~No OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. gO -/..,(' APPROVAL DATE APPOVED BY TITLE Chairman *See Instruction On Reverse Side BY ORDZR 07 THE COMMISSION January 30, 1980 DATE 01/30/80 PROPOSED DR~.ING AND CC~P~ION PNgGRAM Dry bucket 36" hole to 80' bel°w ground level and cement 30" x 20" insulated conductor to surface using Arcticset concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 4500 cu. ft. Penm~frost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Directionally drill 12 1/4" hole to 8374'+ TVD. Run 9 5/8" 47# L-80 Buttress casing to 8374' TVD and cement first stag~ with 1375 cu. ft. cement. C~ment second stage through D.V. packer collar at 2600'+ with 130 cu. ft. Permafrost C cement. 9 5/8" casing will be hung at surface, ~he 9 5/8" x 13 3/8" annulus will be Arctic Packed. Directionally drill 8 1/2" hole to T.D. at 9274 '+ TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 320 cu. ft. Cl--ass G cement with 18% salt. Run 7" 26# L-80 Atlas Bradford IJ-4S tubing with a production packer assembly at 7824'+ TVD. A subsurface safety valve with dual control lines will be placed a~ 2000' +. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations robe submitted on Sundry NotiCe to follow. - - , .................. M--~o~o~o~) i ..... ! ......................... I~ ..................... ] ...... ', i 0 , . ' ' · i i -- ! / · i ~ : ~ ~i'~I ~, ~ ' "' .... i- ....... [..~ . . ; ~ . ; . ; . o- . .' ~ ~[~! ! , : -, / · ~- / .; ~ .i;~,~J ~-i' { .! t ~~ ~ ' : t~! -!,o~i-~· i "-~ I · i - ~ q · ' ' . . ' ·I__ ' · t~,-~l o-~ ~ .''- , :_~z~. - t.. ...~' ~ ,- ~ C~,N) LAT. = 70~7: ~12~ '~ ; · ~ T i " ' *' ' t ~' ' - , ' - ~ [ . C :! ~: ~ . i .I. ! ' ,' -. I ! ' i · , . .'i.. .', · - ~' '.'! ,~4~- ' ~ ~ : I . L ' '- ~ ! i ~~D-e ' ' .'; · ' ' I ' :'" I ....... F ........ - ......... I ........... q ......... ! .......... ~c~,o~.~ .......... ~ .......... I .......... ! -' / . : I I i 1: .'i- . :{. . I o~ , / ~ :. i . , I I ~ -i . . ' ' . a / I t ' ~ ' ~ · = ' " ! ...... ~ ........... ~ ....~:6 ....... i ............ I .....'- - { ......... 2~ .......... i ............ ! 't- : - I . .i .I. ~ - i ~ . . . ! o~ J ~ ~ ~ ~ '! ~I .... '..-l. .:. :-_ ........ -.~:..: ..'.i.':._ -t':' '~ ..... :.. i .... ~..: .... ~ ..... -::: .......... I.. · . , i I ! 1 I~ 1- - i - ~ i i ! PORTION' OF TI SCALE I"= N, R. 13 E, U~ I/Z MILE o./?i 't~/'/ i.2.~.11'..15 ) -=o! [ suu~, o.,.~.~, it.,.,.~.,,.,,.,.~; ' O,/tl 'Z)'ltl II; IJI . ~'t ' /',~/-z.~.//-/$~. -o_ 354° · PAD_ DETAI,L SCALE i;'= 500 CERTIFICATE OF SURVEYOR · · . . ! hereby certify'thor lam prope;'ly registered to proct'ice lend surveying in the Stole. of Alosko (]nd thor this plot · represents o locotion survey of the wellp(]d shown end the wells thereon. This_survey wosmode by me or under my supervision . . . cndoll dimensions end other detoilS ore correct. Bottom hole Iocotions ore furnished by others. Dote Surveyor AS- STAKE3 PAD "D" EXTENSION":' Locoted in Surveyed for SOHIO PETROLEUM COMPANY F.M. LINDSEY 8~ ASSOCJ LAND E, HYDRC'SRAPHlC SURVEYORS CHECK LIST FOR NE%; ;,~LL PERMITS Company _ - ~ No 1. Is the permit fee attached ............................ 2. Is ~ell to be located in a defined pool / 3. Is a registered survey plat attached ................................ /~ 4. Is w~ll located proper distance frcm property line .................. /~/{ 5. Is well located proper distance frcm other wells .................... ¢ ~- 6. Is sufficient undedicated acreage available in this pool ............ ~ 7. ,,,~ well to be deviated .................... · .......................... ~ Remarks Lease & Well No. Item Approve (1) Fee (2) Loc.f~. Date 8. Is operator the only affected party ................................. · 9. Can permit be approved before ten-day wait .......................... _0. Does operator have a bond in force .................................. /~/~ .1. Is a conservation order needed ................................. ~ .... L2. Is administrative approval needed ................................... (3) Adm'.]rn. ,~t,,/,~- L3. Is conductor, string provided ........................................ ~ L4. Is enough cement used to circulate on conductor and surface ......... ~5. Will cement tie in surface and intermediate or production strings ... L6.~ '~ ~ill cement cover all known productive horizons ..................... L7. Will surface casing protect fresh water zones ....................... LB. Will all casing give adequate safety in collapse, tension and burst.. L9. Does BOPE have sufficient pressure rating - Test to ~--~dO psig .. Approval Reccmmended: (4) Casg. ~ (5) BOPE~ %dditional Requir, ements: rev: 12/12/79 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX,' ,. No 'special'effort has been made to chronologically organize this category of information. PRUDHOE B~¥~o;~ ~ ~ e°t~t~l~lott WESTERN ATLAS Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 D - 12 (43-23-11-13) 500292044300 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 12-APR-94 5810.02 R. ECK C. PARKER 23 liN 13E 2930 1067 71.50 69.50 47.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 8406.0 3RD STRING 7.000 9426.0 PRODUCTION STRING 4.500 7965.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 30-APR-80 SWS BASELINE DEPTH 8592.0 8594.0 8595.0 8596.0 8597.5 8622.5 8623.5 8635.0 8635.5 8643.5 8644.0 8649.0 8660.0 47.00 29.00 12.60 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 8591.5 8593.5 8594.0 8595.0 8597.0 8622.0 8622.5 8634.0 8635.0 8642.0 8643.0 8648.0 8659.5 8681.0 8681.5 8683.0 8684.0 8692.5 8693.0 8693.5 8694.0 8694.5 8696.0 8702.5 8710.5 8711.5 8712.0 8713.5 8714.5 8715.0 8715.5 8794.5 8890.0 9081.5 9132.5 9136.0 9138.0 9166.0 9167.0 9168.0 9170.0 9170.5 9171.5 9183.0 9186.5 9203.5 9226.0 9227.0 9245.0 9247.5 9248.0 9249.0 9258.0 9258.5 9279.0 9294.0 9299.5 9302.0 9302.5 REMARKS: 8680.5 8681.5 8683.0 8683.5 8692.0 8693.0 8694.0 8695.0 8695.5 8696.0 8702.0 8710.0 8710.5 8711.5 8713.0 8713.5 8714.0 8715.0 8794.0 8889.0 9081.0 9132.0 9137.5 9139.5 9166.5 9167.0 9168.0 9170.5 9171.0 9171.5 9185.0 9188.5 9204.0 9227.0 9227.5 9245.5 9247.5 9248.0 9248.5 9257.5 9258.5 9279.0 9295.0 9300.0 9302.5 9303.0 CN/GR Cased Hole. LOG TIED TO SONIC DATED 14-MAY-80. CN LOGGING PARMS: LIMESTONE MATRIX CHISM OFF CALIPER CORRECTION = 10.625" CASING CORRECTIONS OFF SALINITY = 0 PPM PUMPED 255 BARRELS OF SEAWATER PRIOR TO LOGGING. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING DOWNLOADED FROM BP EXPLORATION UPS/CSS ON il-APR-94. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY o 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" .FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8493.0 9312.0 8493.0 9320.0 BASELINE DEPTH 8490.0 8495.5 8511.5 8535.0 8559.0 8579.0 8592.0 8594.0 8595.0 8596.0 8597.5 8622.5 8623.5 8629.5 8635.0 8635.5 8643.5 8644.0 8649.0 8660.0 8662.5 8673.0 8681.0 8681.5 8683.0 8684.0 8691.5 8702.5 8710.5 8711.5 8712.0 8713.5 8714.5 8715.0 8715.5 8745.0 8790.0 8853.0 8890.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... NPHI 8490.0 8497.5 8513.0 8534.0 8558.0 8578.5 8591.5 8593.5 8594.0 8595.0 8597.0 8622.0 8622.5 8629.0 8634.0 8635.0 8642.0 8643.0 8648.0 8659.5 8661.5 8672.0 8680.5 8681.5 8683.0 8683.5 8691.5 8702.0 8710.0 8710.5 8711.5 8713.0 8713.5 8714.0 8715.0 8744.5 8788.0 8852.0 8889.0 8896.0 8945.0 8947.5 8950.5 9081.5 9088.0 9100.0 9132.5 9136.0 9138.0 9166.0 9167.0 9168.0 9170.0 9170.5 9171.5 9183.0 9186.5 9203.5 9231.5 9241.0 9254.0 9279.0 9292.5 9325.0 $ REMARKS: 8895.0 8944.0 8947.0 8950.0 9081.0 9087.0 9099.0 9132.0 9137.5 9139.5 9166.5 9167.0 9168.0 9170.5 9171.0 9171.5 9185.0 9188.5 9204.0 9231.0 9241.5 9255.0 9279.0 9291.5 9325.0 PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: 1 2 3 4 5 Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-L FUCT 2418 68 1 CPS NUCT 2418 68 1 CPS TENS 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) Total Data Records: 40 1014 BYTES * Tape File Start Depth = 9325.000000 Tape File End Depth = 8490.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10027 datums Tape Subfile: 2 271 records... Minimum'record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: ~RCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8500.0 9312.0 8500.0 9320.0 BASELINE DEPTH GRCH 8490.0 8503.5 8513.0 8538.0 8559.0 8567.5 8587.0 8593.5 8595.0 8595.5 8597.0 8598.0 8599.5 8600.5 8602.5 8604.0 8605.5 8608.0 8609.0 8611.0 8612.0 8613.0 8615.0 8616.0 8616.5 8617.5 8623.0 8624.0 8625.0 8633.0 8635.5 8642.5 8643.0 8644.5 8651.5 8660.5 8661.0 8593.5 8609.0 8610.0 8611.0 8623.0 8624.0 8624.5 8635.0 8643.5 8644.0 8644.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... NPHI 8490.0 8507.5 8517.0 8540.0 8561.5 8571.0 8590.5 8598.5 8599.0 8600.0 8600.5 8601.0 8602.0 8602.5 8604.0 8604.5 8607.0 8613.5 8615.5 8616.0 8616.5 8617.0 8633.0 8651.5 8660.0 8661.0 8664.0 8665.0 8667.5 8668.0 8680.5 8681.5 8682.5 8685.5 8686.0 8688.5 8689.0 8692.0 8693.0 8696.0 8697.0 8697.5 8702.0 8705.0 8706.0 8714.5 8715 .'5 8721.0 8722.0 8722.5 8723.0 8743.5 8753.0 8754.0 8762.0 8765.5 8784.0 8785.5 8790.0 8793.0 8793.5 8794.0 8794.5 8796.0 8796.5 8799.0 8800.5 8801.5 8803.0 8821.0 8823.5 8842.5 8847.0 8847.5 8853.0 8857.0 8857.5 8882.0 8883.5 8884.0 8887.5 8888.5 8898.5 8901.0 8903.0 8903.5 8681.5 8682.0 8685.0 8686.5 8689.0 8690.0 8697.0 8697.5 . 8698.0 8702.0 8714.5 8716.0 8721.5 8722.0 8723.0 8723.5 8783.5 8792.5 8793.0 8794.0 8821.0 8823.5 8887.0 8664.0 8664.5 8667.0 8668.0 8680.5 8693.0 8694.0 8705.5 8706.0 8743.5 8752.5 8753.5 8763.5 8767.0 8784.5 8788.5 8792.0 8792.5 8793.0 8793.5 8796.5 8798.0 8798.5 8800.0 8841.0 8845.5 8846.5 8851.5 8856.0 8857.0 8881.0 8882.5 8883.5 8888.0 8898.0 8900.0 8902.0 8903.0 8918.0 8922.0 8924.5 8941.0 8943.5 8950.0 8982.0 8985.0 8988.5 8989.0 8989.5 8992.0 8998.5 9039.5 9055.0 9066.0 9078.5 9082.5 9083.0 9094.5 9095.5 9100.5 9105.0 9106.0 9107.0 9109.5 9128.5 9130.0 9131.0 9139.5 9140.0 9150.0 9153.0 9163.5 9164.5 9166.0 9166.5 9167.0 9167.5 9168.5 9172.0 9182.5 9184.5 9192.0 9202.0 9208.0 9211.0 9214.5 9221.5 9222.0 9225.5 9231.5 9235.5 9236.5 9244.0 9245.5 9248.0 9254.0 9258.5 9261.5 9082.0 9083.0 9094.5 9095.0 9105.5 9153.5 9164.0 9164.5 9166.0 9167.0 9168.0 9168.5 9172.0 9184.0 9186.0 9202.0 9208.0 9225.0 9235.0 9235.5 9244.5 9246.0 9256.5 9260.0 8917.5 8921.0 8923.5 8940.5 8943.0 8950.0 8981.0 8984.0 8987.0 8987.5 8988.5 8991.0 8999.0 9040.0 9055.0 9065.5 9078.5 9095.0 9100.5 9104.5 9106.0 9108.5 9129.0 9130.5 9131.0 9137.5 9138.0 9150.5 9167.0 9191.0 9210.5 9213.5 9220.5 9221.0 9230.0 9243.0 9253.5 9263.5 9277.0 9279.0 9280.5 9281.0 9283.0 9292.0 9298.5 9316.0 9317.5 9325.0 $ REMARKS: 9262.0 9275.5 9277.0 9279.0 9279.0 9281.0 9289.0 9296.5 9314.0 9316.0 9325.0 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ??MATCH2A. OUT / ? ?MATCH2B. OUT $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-L 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) Total Data Records: 40 1014 BYTES * Tape File Start Depth = 9325.000000 Tape File End Depth = 8490.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10027 datums Tape Subfile: 3 242 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8500.0 9312.0 8500.0 9320.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH NPHI 8490.0 8490.0 8501.0 8502.0 8513.0 8512.0 8517.5 8517.5 8543.0 8543.0 8562.0 8563.5 8587.0 8586'.0 8593.0 8593.0 8594.0 8594.0 8594.5 8595.0 8595.0 8595.5 8603.5 8603.0 8606.0 8605.5 8606.5 8606.5 8611.5 8611.5 8612.5 8612.0 8614.0 8614.0 8614.5 8614.5 8615.5 8615.0 8616.0 8615.5 8617.0 8616.0 8618.0 8617.0 8619.0 8617.5 8620.5 8619.0 8627.0 8627.0 8634.5 8634.0 8635.5 8634.5 8644.5 8644.5 8645.5 8645.0 8647.5 8647.0 8649.0 8648.5 8659.5 8659.5 8663.0 8662.5 8665.0 8665.0 8681.5 8681.5 8682.5 8682.0 8683.0 8682.5 8688.5 8691.0 8691.5 8692.5 8693.5 8696.0 8697.0 8703.0 8706.5 8713.5 8715.5 8720.0 8723.5 8739.0 8751.0 8774.0 8783.5 8791.0 8792.0 8794.0 8794.5 8795.0 8796.5 8800.5 8801.0 8802.0 8802.5 8803.0 8820.0 8822.5 8843.0 8892.0 8897.5 8902.0 8903.5 8906.5 8907.0 8914.5 8915.5 8925.0 8925.5 8930.0 8939.0 8940.0 8949.0 8991.5 8992.0 8993.0 8993.5 8999.0 9000.0 9049.5 9051.5 9052.0 9081.5 9087.5 9094.5 9095.5 9097.0 9097.5 8688.5 8692.0 8697.5 8703.0 8723.5 8783.0 8794.0 8820.0 8822.5 8901.0 8902.5 9081.0 9094.0 9094.5 9096.0 9097.0 8692.0 8693.5 8694.0 8696.5 8706.0 8713.0 8715.5 8720.0 8738.0 8750.0 8772.5 8789.5 8790.0 8792.0 8792.5 8794.0 8797.5 8798.0 8798.5 8799.5 8800.0 8842.5 8891.5 8896.5 8905.5 8906.5 8914.0 8914.5 8924.0 8925.0 8929.5 8939.0 8939.5 8948.5 8991.5 89.92.0 8992.5 8993.0 8999.0 9000.0 9048.5 9050.5 9051.5 9087.0 9099.5 9101.5 9102.0 9102.5 9105.5 9125.5 9126.5 9127.0 9131.0 9135.0 9138.0 9139.0 9139.5 9140.0 9140.5 9153.0 9161.5 9.164.0 9173.0 9179.5 9188.0 9192.5 9195.5 9202.0 9231.5 9240.5 9245.5 9246.0 9248.0 9251.5 9258.0 9260.5 9261.5 9274.0 9276.0 9281.0 9295.5 9296.0 9308.0 9311.0 9316.5 9325.0 $ REMARKS: 9105.0 9135.0 9139.0 9153.0 9161.5 9163.5 9172.5 9189.0 9195.0 9245.0 9246.5 9256.5 9259.5 9260.5 9275.0 9296.0 9307.0 PASS 3. FUCT, NUCT, 9098.5 9100.5 9101.5 9102.0 9124.5 9125.5 9126.5 9130.5 9140.0 9140.5 9141.5 9142.0 9164.5 9178.0 9190.5 9203.5 9231.0 9240.5 9246.0 9251.5 9272.5 9280.0 9293.5 9294.0 9309.0 9315.0 9325.0 & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3A. OUT / ? ?MATCH3 B. OUT $ : BP EXPLORATION : D - 12 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-L 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 2O * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data RecOrds: 40 Tape File Start Depth = 9325.000000 Tape File End Depth = 8490.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20054 datums Tape Subfile: 4 213 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8500.0 9312.0 8500.0 9320.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH NPHI 8490.0 8490.0 8501.0 8500.5 8518.0 8517.0 8542.5 8544.0 8562.0 8563.0 8593.0 8593.5 8595.0 8595.5 8596.5 8596.0 8597.0 8596.5 8598.0 8597.0 8605.5 8605.5 8604.5 8608.0 8608.0 8609.0 8608.5 8611.0 8610.0 8612.0 8611.0 8613.5 8612.5 8614.0 8613.5 8614.5 8615.5 8615.0 8616.5 8615.5 8617.0 8616.0 8618.0 8616.5 8618.5 8617.0 8619.0 8618.5 8619.5 8619.5 8623.0 8623.0 8623.5 8623.5 8624.5 8624.0 8635.0 8634.5 8636.0 8635.0 8642.5 8642.0 8643.0 8642.0 8644.0 8643.5 8645.0 8644.0 8645.5 8644.5 8646.5 8645.0 8647.5 8646.5 8648.0 8647.5 8650.0 8656.0 8657.0 8658.0 8671.0 8671.5 8674.0 8675.0 8681.0 8685.0 8685.5 8690.5 8692.0 8694.5 8696.0 8703.5 8704.5 8705.0 8705.5 8707.0 8708.0 8713.5 8714.0 8715.5 8718.0 8718.5 8720.5 8739.0 8740.5 8741.5 8744.0 8769.5 8773.5 8776.0 8784.5 8785.0 8785.5 8788.5 8790.0 8792.5 8793.5 8794.5 8795.5 8799.0 8800.0 8802.5 8836.0 8837.5 8842.0 8848.0 8853.0 8853.5 8888.0 8894.0 8895.0 8896.0 8896.5 8897.0 8898.0 8899.5 8670.5 8671.5 8685.0 8686.0 8704.0 8704.5 8705.5 8707.5 8708.0 8713.5 8714.5 8715.5 8769.5 8792.0 8853.0 8897.0 8648.5 8656.5 8657.5 8658.0 8674.0 8674.5 8680.5 8691.0 8692.5 8695.5 8697.0 8705.0 8717.5 8718.5 8720.5 8739.5 8741.0 8741.5 8744.0 8772.5 8775.0 8783.0 8783.5 8784.5 8787.0 8788.5 8792.0 8792.5 8793.0 8796.5 8797.0 8799.5 8834.5 8836.0 8841.0 8847.0 8851.5 8888.0 8893.0 8893.5 8894.5 8895.5 8896.0 8899.0 8901.0 8902.0 8902.5 8903.0 8907.5 8908.0 8909.0 8910.0 8912.5 8913.0 8922.5 8943.5 8975.0 9009.5 9044.0 9O5O.5 9052.0 9071.0 9073.5 9081.5 9084.0 9091.0 9091.5 9094.0 9095.0 9102.5 9104.5 9105.0 9135.5 9139.5 9140.5 9157.5 9172.0 9181.0 9185.0 9192.0 9198.0 9203.5 9210.5 9211.0 9226.0 9231.0 9243.5 9244.5 9248.5 9254.5 9261.0 9280.5 9301.0 9305.0 9316.0 9325.0 $ REMARKS: 8902.0 8902.5 9080.5 9090.0 9091.0 9093.5 9094.0 9104.0 9136.5 9157.5 9172.0 9182.5 9186.5 9198.0 9203.5 9225.5 9244.0 9246.5 9259.0 9303.0 8900.5 8901.0 8906.5 8907.5 8908.5 8909.0 8911.5 8912.5 8922.0 8943.0 8976.0 9010.0 9044.0 9050.5 9052.0 9070.0 9073.0 9083.0 9101.5 9103.5 9140.0 9141.0 9192.0 9209.5 9210.0 9229.5 9242.5 9254.5 9279.5 9298.5 9314.5 9325.0 PASS 4. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH4A. OUT / ??MATCH4B. OUT CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool COde samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-L 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 40 Tape File Start Depth = 9325.000000 Tape File End Depth = 8490.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code deCoding summary: Rep Code: 68 20054 datums Tape Subfile: 5 223 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: 1, 2, 3, 4 1, 2, 3, 4 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 4 PASSES. $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-L 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 34 Tape File Start Depth = 9325.000000 Tape File End Depth = 8490.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28410 datums Tape Subfile: 6 57 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8492.0 2418 8492.0 $ LOG HEADER DATA STOP DEPTH 9321.0 9329.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ 18-MAR-94 FSYS REV. J001 VER. 1.1 1814 18-MAR-94 9348.0 9326.0 8500.0 9324.0 1800.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): 0.000 9426.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS) : 40 NEAR COUNT RATE HIGH SCALE (CPS): 1040 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-L 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TTEN 2418 68 1 LB 4 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 28 122 23 5 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 135 Tape File Start Depth = 9329.500000 Tape File End Depth = 8492.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53565 datums Tape Subfile: 7 Minimum record length: Maximum record length: 210 records... 46 bytes. 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8497.0 2418 8497.0 $ LOG HEADER DATA STOP DEPTH 9319.0 9328.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ 18-MAR-94 FSYS REV. J001 VER. 1.1 1851 18-MAR-94 9348.0 9326.0 8500.0 9324.0 1800.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9426.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 40 NEAR COUNT RATE HIGH SCALE (CPS) : 1040 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-L 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 133 Tape File Start Depth = 9328.000000 Tape File End Depth = 8497.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** · LIS representation code decoding summary: Rep Code: 68 61661 datums Tape Subfile: 8 Minimum record length: Maximum record length: 208 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8497.0 2418 8497.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9321.0 9330.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS _ FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX D~N$IT¥: HOLE CORRECTION (IN): THERMAL LIMESTONE 0.00 10.625 18-MAR-94 FSYS REV. J001 VER. 1.1 1927 18-MAR-94 9348.0 9326.0 8500.0 9324.0 1800.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9426.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 40 NEAR COUNT RATE HIGH SCALE (CPS) : 1040 TOOL STANDOFF (IN): REMARKS: PASS 3. $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) 0.0 ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-L 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 134 Tape File Start Depth = 9330.000000 Tape File End Depth = 8497.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86896 datums Tape Subfile: 9 Minimum record length: Maximum record length: 209 records... 62 bytes 1006 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8498.0 2418 8498.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9322.0 9330.5 18-MAR-94 FSYS REV. J001 VER. 1.1 2009 18-MAR-94 9348.0 9326.0 8500.0 9324.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507XA 1310XA 2418XA 2323NA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9426.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW 'SCALE (CPS): 40 NEAR COUNT RATE HIGH SCALE (CPS): 1040 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 4. $ CN : BP EXPLORATION WN : D - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-L 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB API API API API Log Crv Crv size Length Typ Typ Cls Mod 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TypE# 0) 1006 BYTES * Total Data Records: 134 Tape File Start Depth = 9330.500000 Tape File End Depth = 8498.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 94972 datums ~Tape Subfile: 10 Minimum record length: Maximum record length: 209 records... 62 bytes 1006 bytes Tape Subfile 11 is type: LIS 94/ 4/12 01 **** REEL TRAILER **** 94/ 4/12 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 12 APR 94 9:27a Elapsed execution time = 18.95 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * . . ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORAION WELL NAME : D-12 (43-23-11-13) FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292044300 REFERENCE NO : 97054 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN : FLIC REEL NAME : 97054 CONTINUATION # : PREVIOUS REEL : COM~ENT : BP EXPLORATION, D-12 (43-23-11-13) , PRUDHOE BAY, 50-029-20443-O0 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN : FLIC TAPE NAME : 97054 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, D-12 (43-23-11-13) , PRUDHOE BAY, 50-029-20443-O0 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D-12(43-23-11-13) API NUMBER: 500292044300 OPERATOR: BP EXPLORAION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-FEB-97 JOB NUMBER: 97054 LOGGING ENGINEER: S. DECKERT OPERATOR WITNESS: KEN BULLOCH SURFACE LOCATION SECTION: 23 TOWNSHIP: lin RANGE: 13E FNL: 2930 FSL: FEL: 1067 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 71.50 DERRICK FLOOR: 70.60 GROUND LEVEL: 47.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 8406.0 47. O0 2ND STRING 7. 000 9426.0 29. O0 3RD STRING 4. 500 7955.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9246.5 9241.5 9237.5 9232.5 9229.5 9229.0 9220.0 9217.5 9211.5 9204.0 9203.0 9193.5 9189.5 9174.0 9167.0 9164.0 9158.5 9155.0 9142.5 9141.0 9137.0 9134.5 9129.5 9114.0 9106.0 9100.0 9099.5 9087.5 9087.0 9083.5 9081.0 9080.0 9066.5 9043.5 9033.5 8995.0 8973.5 8950.5 8947.5 8944.5 8934.0 8930.5 8927.5 8927.0 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88888.0 88889.0 9247.5 9241.5 9241.5 9237.5 9232.5 9232.5 9229.0 9229.0 9221.0 9217.5 9211.0 9203.5 9203.5 9194.0 9189.5 9189.5 9174.0 9174.0 9167.0 9167.0 9163.5 9158.5 9154.5 9143.0 9141.0 9137.0 9137.0 9134.5 9129.0 9115.5 9106.0 9100.0 9100.0 9087.5 9087.5 9083.5 9081.0 9081.0 9066.5 9044.0 9044.0 9033.0 8995.0 8974.0 8950.5 8948.0 8944.5 8933.5 8931.0 8927.0 8927.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 8925~0 8925.5 8922.0 8922.0 8918.5 8917.5 8904.0 8903.0 8903.5 8903.0 8900.0 8900.0 100.0 99.5 100.0 REFIARKS: THIS FILE CONTAINS THE CASED HOLE EDIT FOR BP EXPLOR- ATION WELL D-12 (43-23-11-13) TDTP. THERE IS ONE BASE- LINE PASS, THREE BORAX PASSES, AND A FLUSHED PASS. THE AVERAGE PASS IS THE SAME AS THE BASELINE PASS. FIVE RAW DATA FILES ARE ALSO PRESENTED. THE DEPTH ADJUST- MENTS SHOWN ABOVE REFLECT CASED HOLE GR TO OPEN HOLE BCS GR, AND CASED HOLE SIGM TO OPEN HOLE BCS GR. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IgI3MBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9250.0 8899.0 TDTP 9250.0 8899.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: REMARKS: THIS FILE CONTAINS TDTP PASS #1 (BASE PASS #1). THERE WERE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 488349 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 488349 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TCANTDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 488349 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 488349 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 488349 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 488349 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9251 . 000 SIGM. TDTP 18. 645 TPHI. TDTP 30. 695 SBHF. TDTP SBHN. TDTP 50 . 827 SIGC. TDTP 1 . 995 SIBH. TDTP 60. 933 TRAT. TDTP SDSI. TDTP O. 424 BACK. TDTP 55.148 FBAC. TDTP 10. 580 TCAN. TDTP TCAF. TDTP 1301 O. 619 TCND. TDTP 24334. 566 TCFD. TDTP 7329. 040 TSCN. TDTP TSCF. TDTP 2074. 882 INND. TDTP 1892. 385 INFD. TDTP 371 . 342 GRCH. TDTP TENS. TDTP 1360. 000 CCL. TDTP O. 000 DEPT. 8898. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 45.497 1.711 32068.777 5114.203 -999.250 -999.250 -999.250 -999.250 -999.250 10.711 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9250.0 8898.0 TDTP 9250.0 8898.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9245.0 9242.0 9239.0 9233.0 9232.5 9221.0 9216.5 9212.0 9211.0 9208.5 9205.0 9203.0 9198.5 9195.5 9194.0 9190.5 9189.5 9182.0 9180.5 9174.5 9167.5 9165.5 9165.0 9159.0 9155.5 9147.0 9144.0 9143.0 9140.5 9138.0 9134.0 9130.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88887.5 9245.0 9241.5 9241.5 9238.5 9232.5 9232.5 9221.0 9216.5 9211.0 9210.5 9206.5 9207.5 9203.0 9203.5 9197.0 9196.5 9193.5 9189.5 9189.0 9179.5 9179.5 9174.0 9173.5 9167.0 9167.0 9163.5 9163.5 9158.0 9154.5 9148.0 9143.0 9143.0 9139,5 9137,0 9137.0 9134,5 9129.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FBB-1997 11:47 PAGE: 9125.0 9118.5 9116.5 9106.5 9104.0 9100.0 9097.5 9088.0 9087.5 9081.5 9066.5 9066.0 9063.0 9052.5 9049.5 9044.0 9042,0 9036.0 9029.5 9009.0 9005.0 8998.5 8981.0 8964.0 8962.5 8950.5 8945.0 8944.5 8939.5 8934.5 8932.0 8929.5 8928.0 8925.5 8922.5 8918.0 8913.5 8911.0 8905.5 8904.0 8902.0 8900.5 100.0 9126.5 9119.0 9115.0 9105.5 9103.5 9100.0 9096.5 9087.0 9080.5 9066.5 9063,5 9053.5 9049.5 9043.5 9031.5 9011.5 9001.0 8966.0 8950.5 8944.5 8939.5 8932.5 8929.5 8927.0 8922.0 8917.5 8909.0 8904.0 8900.0 98.0 9104.0 9100.0 9087.5 9065.5 9063.0 9043.5 9035.0 9004.5 8980.0 8961.5 8944.5 8933.5 8925.0 8913.0 8902.5 8899.5 99.0 REMARKS: THIS FILE CONTAINS BORAX PASS #1 OF THE TDTP. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASE PASS #1 GRCH, AND BORAX PASS #1 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 488349 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 488349 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 488349 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 488349 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 488349 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 488349 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: ** DATA ** DEPT. 9250. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 TCAN. TDTP -999.250 TSCN. TDTP -999.250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 27.063 DEPT. 8896.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999. 250 INND. TDTP -999 . 250 INFD. TDTP -999. 250 GRCH. TDTP 20. 703 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~rn~RY LDWG TOOL CODE START DEPTH GRCH 9250.0 TDTP 9250.0 STOP DEPTH 8898.0 8898.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 10 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88888.0 9245.0 9245.0 9241.5 9241.5 9241.5 9232.5 9232.5 9232.0 9232.0 9219.5 9221.0 9219.0 9219.0 9216.5 9217.0 9211.5 9210.5 9211.0 9211.0 9207.5 9207.0 9206.0 9206.5 9203.0 9203.5 9200.0 9200.0 9195.5 9195.5 9193.5 9193.5 9190.0 9189.5 9189.0 9189.0 9179.5 9179.5 9179.5 9174.0 9174.0 9173.5 9167.5 9167.0 9167.0 9166.5 9163.5 9162.0 9158.5 9158.0 9154.0 9153.0 9148.0 9148.0 9146.5 9145.5 9143.0 9143.0 9140.0 9139.5 9138.0 9137.0 9137.5 9137.0 9135.5 9134.5 9128.5 9129.0 9118.0 9119.0 9106.0 9106.0 9100.0 9100.0 9099.5 9100.0 9088.0 9087.5 9087.5 9084.0 9083.0 9081.5 9081.0 9078.0 9077.5 9076.5 9075.0 9067.0 9066.5 9064.5 9063.5 9065.0 9054.0 9053.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 11 9051 0 9047 5 9044 0 9043 5 9042 0 9034 5 9016.0 9013.5 9011.0 9005.5 9001.0 8981.0 8962.0 8956.5 8950.5 8945.0 8944.5 8942.0 8934.5 8927.0 8925.5 8924.5 8921.0 8918.0 8916.0 8909.5 8909.0 8903.5 8902.5 100.0 $ 9050.0 9047.5 9044.0 9040.0 9015.5 9011.5 9001.0 8957.0 8950.5 8944.5 8939.5 8933.0 8927.0 8924.5 8922.0 8917.5 8915.0 8908.5 8901.5 99.0 9043.5 9033.5 9010.0 9004.5 8980.0 8961.5 8944.5 8933.5 8925.0 8917.5 8909.0 8902.5 99.0 REMARKS: THIS FILE CONTAINS BORAX PASS #2 OF THE TDTP. THE DEPTH ADJUSTMENTS SHOWN ABOVEREFLECT BORAX PASS #2 GRCH TO BASE PASS #1 GRCH, AND BORAX PASS #2 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 88 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 12 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 488349 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 488349 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 488349 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 488349 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 488349 O0 000 O0 0 3 1 I 4 68 0000000000 CCL TDTP V 488349 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9250. 000 SIGM. TDTP 19.145 TPHI. TDTP 29. 562 SBHF. TDTP SBHN. TDTP 51 . 319 SIGC. TDTP 2. 278 SIBH. TDTP 61 . 473 TRAT. TDTP SDSI. TDTP O. 642 BACK. TDTP 233 . 080 FBAC. TDTP 44. 646 TCAN. TDTP TCAF. TDTP 10957. 686 TCND. TDTP 24602. 168 TCFD. TDTP 7418. 638 TSCN. TDTP TSCF. TDTP 2141.970 INND. TDTP 1991.406 INFD. TDTP 387.496 GRCH. TDTP TENS. TDTP 1470. 000 CCL . TDTP O . 000 46.030 1.664 26362.297 5153.209 45.063 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 13 DEPT. 8897. 000 SIGM. TDTP 12.439 TPHI. TDTP 12. 454 SBHF. TDTP 55. 505 SBHN. TDTP 67.518 SIGC. TDTP O. 298 SIBH. TDTP 84 . 303 TRAT. TDTP 1 . 260 SDSI. TDTP 0.284 BACK. TDTP 235.799 FBAC. TDTP 44.478 TCAN. TDTP 38215.422 TCAF. TDTP 24221.332 TCND. TDTP 22960.559 TCFD. TDTP 10757. 402 TSCN. TDTP 7467.125 TSCF. TDTP 4732.742 INND. TDTP 2070.698 INFD.TDTP 671.706 GRCH. TDTP 28.219 TENS. TDTP 1435. 000 CCL. TDTP O . 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9250.0 8898.0 TDTP 9250.0 8898.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 14 BASELINE DEPTH GRCH 88888.0 88887.5 9242.5 9242.0 9241.5 9233.0 9232.0 9225.5 9221.0 9216.5 9217.0 9212.0 9211.5 9210.5 9204.5 9203.0 9200.0 9200.0 9196.5 9196.0 9190.5 9189.5 9190.0 9180.0 9175.0 9174.0 9174.0 9167.5 9167.0 9164.5 9158.5 9158.0 9154.5 9154.5 9144.0 9143.0 9142.5 9141.0 9140.5 9139.5 9137.0 9135.0 9134.5 9130.0 9129.0 9127.0 9126.5 9104.0 9100.0 9100.0 9098.5 9088.0 9087.5 9081.5 9080.5 9074.0 9074.5 9066.0 9064.5 9064.5 9044.5 9044.0 9043.5 9038.0 9013.0 9005.0 9002.0 9001.5 8980.0 8961.5 8951.0 8952.0 8947.0 8944.0 8944.5 8934.5 8930.5 8926.5 8927.0 8924.5 8922.0 8922.0 8917.5 8917.0 TDTP ....... 88887.0 9241.5 9232.5 9225.0 9221.0 9211.0 9203.5 9195.5 9189.5 9179.5 9173.5 9167.0 9163.5 9136.5 9104.5 9100.0 9087.5 9065.5 9043.5 9038.0 9012.5 9004.5 8979.5 8961.5 8947.0 8944.5 8934.0 8930.5 8924.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 15 8916.0 8915.0 8912.5 8912.5 8903.5 8902.5 8902.0 8901.5 8900.0 8900.0 100.0 99.5 100.0 REMARKS: THIS FILE CONTAINS BORAX PASS #3 OF THE TDTP. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASE PASS #1 GRCH, AND BORAX PASS #3 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 4 1 1 4 68 0000000000 SIGH TDTP CU 488349 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 488349 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 488349 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 488349 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 488349 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIBH TDTP CU 488349 O0 000 TRAT TDTP 488349 O0 000 SDSI TDTP CU 488349 O0 000 BACK TDTP CPS 488349 O0 000 FBAC TDTP CPS 488349 O0 000 TCAN TDTP CPS 488349 O0 000 TCAF TDTP CPS 488349 O0 000 TCND TDTP CPS 488349 O0 000 TCFD TDTP CPS 488349 O0 000 TSCN TDTP CPS 488349 O0 000 TSCF TDTP CPS 488349 O0 000 INND TDTP CPS 488349 O0 000 INFD TDTP CPS 488349 O0 000 GRCH TDTP GAPI 488349 O0 000 TENS TDTP LB 488349 O0 000 CCL TDTP V 488349 O0 000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9249. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 8897 500 -999 250 -999 250 -999 250 -999 250 -999 250 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP TCND. TDTP -999. 250 TCFD. TDTP - 999. 250 TSCN. TDTP INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP CCL. TDTP -999 . 250 -999.250 -999.250 -999.250 -999.250 56.281 -999.250 -999.250 -999.250 -999.250 34.875 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 17 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 -FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0. 5000 FILE SUF~VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9250.0 8898.0 TDTP 9250.0 8898.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9241.5 9237.5 9232.5 9232.0 9220.5 9217.5 9216.0 9211.5 9204.0 9196.5 9189.0 9179.5 9174.0 9173.5 9167.0 9164.0 9158.0 9147.0 9142.0 9137.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88888.0 9241.5 9241.5 923 6.5 9232.5 9232.5 9221.0 9219.0 9217.0 9211.0 9211.0 9203.5 9203.5 9196.0 9189.5 9189.5 9179.5 9179.5 9173.5 9174.0 9167.0 9167.0 9164.0 9158.0 9148.0 9147.0 9141.0 9137.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 18 9134 5 9129 0 9110 0 9104 0 9103 5 9100 0 9099 5 9087.5 9087.0 9082.0 9080.5 9075.0 9066.5 9062.0 9044.5 9042.5 9035.0 9015.5 9012.5 9005.0 9002.5 8999.5 8994.5 8979.0 8972.0 8961.5 8956.0 8944.0 8940.0 8933.5 8925.5 8924.5 8917.0 8915.5 8912.5 8908.5 8903.5 8900.5 8900.0 100.0 $ 9134.5 9129.0 9109.0 9105.5 9100.0 9087.5 9081.0 9074.5 9066.5 9043.5 9015.0 9002.5 9000.0 8973.5 8957.0 8944.5 8939.5 8924.5 8917.5 8915.0 8908.5 8900.0 100.0 9104.0 9100.0 9087.5 9083.0 9063.0 9043.5 9034.5 9013.0 9005.0 8995.0 8979.0 8961.5 8944.5 8933.5 8925.0 8917.0 8913.0 8903.0 8900.0 99.5 REMARKS: THIS FILE CONTAINS FLUSHED PASS #1 OF THE TDTP. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT FLUSHED PASS #1 GRCH TO BASE PASS #1 GRCH, AND FLUSHED PASS #1 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGMA SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNTDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 488349 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 488349 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TCANTDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 488349 O0 000 O0 0 5 1 1 ~4 68 0000000000 TSCF TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 488349 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 488349 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 488349 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 488349 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 20 ** DATA ** DEPT. 9250. 000 SIGM. TDTP 18. 619 TPHI. TDTP SBHN. TDTP 51. 235 SIGC. TDTP 2.547 SIBH. TDTP SDSI. TDTP O. 640 BACK. TDTP 245.142 FBAC. TDTP TCAF. TDTP 11008.141 TCND. TDTP 24126.266 TCFD. TDTP TSCF. TDTP 2125. 095 INND. TDTP 2044. 837 INFD. TDTP TENS. TDTP 1455. 000 CCL. TDTP O . 000 28.299 SBHF. TDTP 61 . 145 TRAT. TDTP 45. 496 TCAN. TDTP 7442. 496 TSCN. TDTP 397. 662 GRCH. TDTP 42.685 1.649 26072.828 5033.297 61.844 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER: 6 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, TDTP $ REM_ARKS: THE ARITHMETIC AVERAGE IS EQUAL TO BASE PASS #1. ONLY ONE BASE PASS WAS RUN. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PNAV PU-S 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PNAV 488349 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PNAV CU 488349 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 INND PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PNAV CPS 488349 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 488349 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-FEB-1997 11:47 PAGE: 22 ** DATA ** DEPT. 9251.000 SIGM. PNAV 18.645 TPHI.PNAV 30.695 SBHF. PNAV 45. 497 SBHN. PNAV 50.827 SIGC. PNAV 1.995 SIBH. PNAV 60.933 TRAT. PNAV 1. 711 SDSI.PNAV O. 424 BACK. TDTP 55.148 FBAC. TDTP 10.580 TCAN. PNAV 32068. 777 TCAF. PNAV 13010.619 TCND.PNAV 24334.566 TCFD.PNAV 7329.040 TSCN. PNAV 5114.203 TSCF. PNAV 2074.882 INND. PNAV 1892.385 INFD.PNAV 371.342 GRCH. TDTP -999.250 DEPT. 8898.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 10. 711 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 9250.0 8898.0 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 23 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 30-JAN-97 CP42.2 938 30-JAN-97 9325.0 9315.0 8898.0 9250.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... THERMAL DECAY TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY TOOL NUMBER ........... TCC B 421 SGC-SA-294 CBC EB 88 CBS DA 160 TCM509 WDMAA 419 STM CA 39 CT E-LINE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9426.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TI~,IPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.60 219.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 24 TOOL STANDOFF (IN): REMARKS: CORRELATED SWS TDTP LOG DATED 13-1-91, FILE 24. SQZ PERFS NOT OPEN ANDNOT CHANNELING TO OPEN PERFS. THIS FILE CONTAINS RAW DATA FROM BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS1 PU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PSI 488349 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS1 CU 488349 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PSI CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TCNDPS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS1 CPS 488349 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS1 LB 488349 O0 000 O0 0 7 I 1 4 68 0000000000 GR PS1 GAPI 488349 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS1 V 488349 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9250.000 SIGM. PS1 18.645 TPHI.PS1 30.695 SBHF. PS1 SBHN. PS1 50.827 SIGC. PS1 1.995 SIBH. PS1 60.933 TRAT. PS1 SDSI.PS1 0.424 BACK. PSI 55.148 FBAC. PS1 10.580 TCAIV. PS1 TCAF. PS1 13010.619 TCND.PS1 24334.566 TCFD. PS1 7329.040 TSCN. PS1 TSCF. PS1 2074.882 INND.PS1 1892.385 INFD. PS1 371.342 TENS.PSi GR.PS1 15.633 CCL.PS1 0.000 DEPT. 8898.000 SIGM. PS1 12.302 TPHI. PS1 14.956 SBHF. PS1 SBHN. PS1 47.056 SIGC. PS1 1.323 SIBH. PS1 50.539 TRAT. PS1 SDSI.PS1 0.220 BACK. PSI 156.258 FBAC. PS1 26.902 TCAN. PS1 TCAF. PS1 38739.250 TCND.PS1 32694.445 TCFD. PS1 12838.447 TSCN. PS1 TSCF. PS1 5265.416 INND.PS1 2052.146 INFD. PS1 537.741 TENS.PSi GR.PS1 17.453 CCL.PS1 0.000 45.497 1.711 32068.777 5114.203 1360.000 37.590 1.449 71939.344 9777.953 1355.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 26 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~VIARY VENDOR TOOL CODE START DEPTH TDTP 9250.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 8897.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... THERMAL DECAY TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS 30-JAN-97 CP42.2 938 30-JAN-97 9325.0 9315.0 8897.0 9250.0 900.0 NO TOOL NUMBER ........... TCC B 421 SGC-SA-294 CBC EB 88 CBS DA 160 TCM 509 WDM AA 419 STM CA 39 CT E-LINE 9426.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 27 FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.60 219.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED SWS TDTP LOG DATED 13-1-91, FILE 24. SQZ PERFS NOT OPEN ANDNOT CHANNELING TO OPEN PERFS. THIS FILE CONTAINS RAW DATA FROM BORAX PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 28 TYPE REPR CODE VALUE .............................. 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 PU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CU 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 i 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 CPS 488349 O0 000 O0 0 8 1 1 4 68 0000000000 LB 488349 O0 000 O0 0 8 1 1 4 68 0000000000 GAPI 488349 O0 000 O0 0 8 1 1 4 68 0000000000 V 488349 DEPT SIGM PS2 TPHI PS2 SBHF PS2 SBHNPS2 SIGC PS2 SIBH PS2 TRAT PS2 SDSI PS2 BACK PS2 FBAC PS2 TCANPS2 TCAF PS2 TCND PS2 TCFD PS2 TSCN PS2 TSCF PS2 INND PS2 INFD PS2 TENS PS2 GR PS2 CCL PS2 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9250.000 SIGM. PS2 18.858 TPHI.PS2 31.279 SBHF. PS2 SBHN. PS2 51.981 SIGC. PS2 2.127 SIBH. PS2 63.285 TRAT. PS2 SDSI.PS2 0.556 BACK. PS2 226.268 FBAC. PS2 47.462 TCAN. PS2 TCAF. PS2 11654.730 TCND.PS2 24652.012 TCFD. PS2 7466.142 TSCN. PS2 TSCF. PS2 2161.854 INND.PS2 1877.006 INFD.PS2 391.194 TENS.PS2 GR.PS2 27.063 CCL.PS2 0.000 DEPT. 8897.000 SIGM. PS2 10.487 TPHI.PS2 13.522 SBHF. PS2 SBHN. PS2 82.934 SIGC. PS2 0.078 SIBH. PS2 112.897 TRAT. PS2 SDSI. PS2 0.187 BACK. PS2 226.912 FBAC. PS2 43.266 TCAN. PS2 TCAF. PS2 25904.895 TCND.PS2 21077.574 TCFD. PS2 9836.932 TSCN. PS2 TSCF. PS2 4936.574 INND.PS2 1987.801 INFD.PS2 514.966 TENS.PS2 45.356 1.710 28509.375 5288.247 1375.000 63.508 1.349 42145.578 8031.485 1380.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 29 GR.PS2 20.141 CCL.PS2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : TDTP LOG HEADER DATA FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SOIV~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9250.0 8897.0 DATE LOGGED: 30-JAN-97 SOFTWARE VERSION: CP42.2 TIME LOGGER ON BOTTOM: 938 30-JAN-97 TD DRILLER (FT) : 9325.0 TD LOGGER (FT) : 9315.0 TOP LOG INTERVAL (FT): 8897.0 BOTTOM LOG INTERVAL (FT) : 9250.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 30 THERMAL DECAY TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : TCC B 421 SGC-SA-294 CBC EB 88 CBS DA 160 TCM 509 WDM AA 419 STM CA 39 CT E-LINE 9426.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.60 219.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED SWS TDTP LOG DATED 13-1-91, FILE 24. SQZ PERFS NOT OPEN AND NOT CHANNELING TO OPEN PERFS. THIS FILE CONTAINS RAW DATA FROM BORAX PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-FEB-1997 11:47 PAGE: 31 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS3 PU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS3 488349 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS3 CU 488349 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS3 CPS 488349 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS3 LB 488349 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS3 GAPI 488349 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS3 V 488349 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 32 ** DATA ** DEPT. 9250.000 SIGM. PS3 SBHN. PS3 51.319 SIGC.PS3 SDSIoPS3 0.642 BACK. PS3 TCAF. PS3 10957.686 TCND.PS3 TSCF. PS3 2141.970 INND.PS3 GR.PS3 45.063 CCL.PS3 19.145 TPHI.PS3 2.278 SIBH. PS3 233.080 FBAC. PS3 24602.168 TCFD. PS3 1991.406 INFD. PS3 0.000 29.562 SBHF. PS3 61.473 TRAT. PS3 44.646 TCAN. PS3 7418.638 TSCN. PS3 387.496 TENS.PS3 46. 030 1. 664 26362.297 5153.209 1470.000 ** END OF DATA ** * ** * FILE TRAILER * * * * FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT . O10 SERVICE : FLIC VERSION : 00i CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: O . 5000 FILE SUF~W~ARY VENDOR TOOL CODE START DEPTH ........................... TDTP 9250.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 8897.0 30-JAN-97 CP42.2 938 30-JAN-97 9325.0 9315.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 33 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8897.0 9250.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... THERMAL DECAY TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY TOOL NUMBER ........... TCC B 421 SGC-SA-294 CBC EB 88 CBS DA 160 TCM 509 WDM AA 419 STM CA 39 CT E-LINE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9426.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.60 219.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED SWS TDTP LOG DATED 13-1-91, FILE 24. SQZ PERFS NOT OPEN ANDNOT CHANNELING TO OPEN PERFS. LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-FEB-1997 11:47 PAGE: 34 THIS FILE CONTAINS RAW DATA FROM BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS4 PU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS4 488349 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS4 CU 488349 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 INNDPS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 35 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INFD PS4 CPS 488349 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS4 LB 488349 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS4 GAPI 488349 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS4 V 488349 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 9250.000 SIGM. PS4 18.253 TPHI.PS4 30.449 SBHF. PS4 SBHN. PS4 52.791 SIGC. PS4 2.363 SIBH. PS4 64.436 TRAT. PS4 SDSI.PS4 0.604 BACK. PS4 249.501 FBAC. PS4 51.517 TCAN. PS4 TCAF. PS4 11099.857 TCND.PS4 24748.645 TCFD.PS4 7435.522 TSCN. PS4 TSCF. PS4 2147.166 INND.PS4 1854.615 INFD.PS4 401.325 TENS.PS4 GR.PS4 56.281 CCL.PS4 0.000 42.028 1.703 27299.770 5280.891 1435.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: O . 5000 FILE SUMMARY LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 36 TDTP LOG HEADER DATA VENDOR TOOL CODE START DEPTH 9250.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE THERMAL DECAY TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ STOP DEPTH 8897.0 30-JAN-97 CP42.2 938 30-JAN-97 9325.0 9315.0 8897.0 9250.0 900.0 NO TELEMETRY CARTRIDGE THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY THERMAL DECAY TOOL NUMBER TCC B 421 SGC-SA-294 CBC EB 88 CBS DA 160 TCM 509 WDM AA 419 STM CA 39 CT E-LINE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9426.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.60 219.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 37 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED SWS TDTP LOG DATED 13-1-91, FILE 24. SQZ PERFS NOT OPEN AND NOT CHANNELING TO OPEN PERFS. THIS FILE CONTAINS RAW DATA FROM FLUSHED PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS5 PU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SBHN PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 38 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TRAT PS5 488349 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS5 CU 488349 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TCANPS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TCNDPS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS5 CPS 488349 O0 000 O0 0 i1 1 1 4 68 0000000000 TSCN PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 INiVDPS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS5 CPS 488349 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS5 LB 488349 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS5 GAPI 488349 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS5 V 488349 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 9250.000 SIGM. PS5 18.619 TPHI.PS5 28.299 SBHF. PS5 SBHN. PS5 51.235 SIGC. PS5 2.547 SIBH. PS5 61.145 TRAT. PS5 SDSI.PS5 0.640 BACK. PS5 245.142 FBAC. PS5 45.496 TCAN. PS5 TCAF. PS5 11008.141 TCND.PS5 24126.266 TCFD. PS5 7442.496 TSCN. PS5 TSCF. PS5 2125.095 INND.PS5 2044.837 INFD.PS$ 397.662 TENS.PS5 GR.PS5 61.844 CCL.PS5 0.000 42.685 1.649 26072.828 5033.297 1455.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN : FLIC TAPE NAME : 97054 CONTINUATION # : 1 PREVIOUS TAPE : COM~IENT : BP EXPLORATION, D-12 (43-23-11-13) , PRUDHOE BAY, 50-029-20443-O0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 11:47 PAGE: 39 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN · FLIC REEL NAME : 97054 CONTINUATION # : PREVIOUS REEL : COF~IENT : BP EXPLORATION, D-12 (43-23-11-13) , PRUDHOE BAY, 50-029-20443-O0 LI'S TAPE VERIFICA'T:ION ~I~TING! VP OIO,HO1 VERIF!CATION LISTING PAGE I $ REEL HEADER ** ERVICE NAME :$ERVIC ATE ~8~t12i/16 RIGIN ~ :01, REV!OU$ REEL ~ OMMENTS ~LIBRAR¥ TAPE :01 ********** EOF NAME ISERVIC,O01 NAME LENGTH : 1024 TYPE REVIOUS Fi~E : * INFORMATION RECORDS NEM CONTENTS N : SOHIO ALASKA N ~ D - 12 N : PRUDHOE BAY ANG: O~N: lIN ECTI 23 OUNI NTH, SLOPE TATI * COMMg PETR, CO. TYPE CATE SIZE CODE 000 000 022 065 000 000 006 000 000 012 065 000 000 004 0~5 000 000 004 065 000 000 002 065 000 000 010 065 000 000 001 065 000 000 006 065 CNL PSi 0 3'4 92 0 0 4 0 i 68 NRA P&2 ~ 0 '0 ~ ~ CNL PS2 0 R PS2 GAPI 0 0 0 I 68 PHI PS3 PU 0 68 2 0 0 4 0 ~ 68 RAT P$3 0 42 ! 0 0 4 0 . 68 N~A p&3 0 0 0 0 0 4 0 ! 68 CNb P~3 0 34 92 0 0 4 0 ! 68 CNb PS3 0 34 93 0 0 4 0 ! 68 R P$3 GAP! 0 3! 32 0 0 4 0 ! 68 NL ~PT 8900 CNL 4332 RAT 84 R 2 4252 EPT 8800 :Nb 4800 RAT 3 R 27 CNL 4504 ~PT 8700 CNL 3732 RAT 4 3936 BPT 8600, CNL 4066, RAT 6, 0000 ::NPHi ~:~4 0000 FCNI., 88 FCNL 885: 0000 NPH! . 2!0 0000 FCNL 1100 031 RNRA i87 NPHI 2~ 0000 FCNL 1045 0000 NPH! 18, 0000 FCNL 1316. ]~31 RNRA 3. 25 NPHI 17. 0000 FCNL 1312, 0000 NPHI 22 0000 FCNL 916! 5195 RNRA 3 1875 NPHI 23. 0000 FCNL 869, NPHI 36, 3633 RNRA 4. 5O00 G R 28 5000GR 31 45:90 NRAT 0000 GR 7206 NCNb 4844 NRAT 0000 GR 0664 NRAT 0000 GR 6284 NCNL 6270 NRAT 0000 GR 8027 NRAT 5000 GR 9206 NCNb 5840 NRAT 00o0 GR 4746 NRAT 5000 GR 4996 NCNb 42284, 31,6563 71:oooo 7754 29,4063 4 4297 99 0625 3876 0000 4 5234 98 8125 5,9531 193,5000 4168,0000 RNRA NPHI FCNb RNRA RNRA NPHX FCNL RNRA RNRA NPHI FCNb 9961 0000 3,5833 17,0410 1336,0000 3,4599 .9479 2 ,5352 901,~000 4, 065 4063 608,0000 C N 6 R * TAPE TRAIbER *~ ERV~CE i ,,i AME :~ERVZC ATE ~82/12/16 R~GIN IFSIA APE NAME ~ '0 ONTINUATION ~ · 1 EXT TAPE NAME ) OMMENT8 ~blBRARY TAPE * REE6 TRAIbER ERVICE HAME ATE :82/12/16 RIGIN : EEb NA~E : ONTINUATION # ~0~ EXT REEL NA~E OMMENTS )bIBRARY TAPE 11 000000 11 000000 1111 O0 O0 11il oo O0 I1 O0 0000 11 O0 0000 I1 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 1i O0 O0 111111 000000 111111 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 o000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666666 000000 666666 000000 66 O0 O0 66 O0 O0 6b O0 0000 66 O0 0000 66~66666 O0 O0 O0 66666666 O0 O0 O0 66 66 0000 O0 66 66 0000 O0 66 66 O0 O0 66 ~6 oo O0 666066 000000 666666 000000 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 U U DDDD U U D D U U D D U U D D U U D D U U D D UUUUU DDDD 333333 11 333333 11 33 33 1111 33 33 1111 33 ~1 33 1 33 11 33 I1 33 11 33 11 ~3 33 11 33 33 11 333333 111111 333333 111111 H H OOO EEEEE H H O O E HHHHH O O EEEE H H O O E H H OO0 EEEEE RECE[VED JUL 1 0 1980. *START, USER PCAL [10707,60531] JOB MUNITOR SWS KLlOE37 APR-80. *START, *START, USER PCAL [10707,60531] JOB MONITOR SWS KLlOE37 APP-80. *START* SHIP SEQ. SHIP SEQ. 2103 DATE 2103 DATE 20-jUN-80 20-JUN-80 17:18:11 17:18:11 VV ~V EEEEEEEEEE RRRRRRRR YV ¥¥ EEEkEEEEEE RRRR~RRR VV YV EE RR RR VV VV EE RR RR VV VV EE RR RR VV YV EE RR RR VV VV EEEEEEEE RRRRRRRR VV VV EEEEEEEE ~RRRRRRR VV ¥~ EE RR RR VV VV EE RR RR VV VV EE RR RR VV VV EE RR RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR 1IIIII iiiiii II Ii II II II II I1 II 1I II II111I iiiiii YY YY YY YY YY YY YY YY YY YY 000000 000000 333333 000000 000000 333333 O0 O0 O0 O0 33 33 O0 O0 O0 O0 33 33 O0 0000 O0 0000 33 O0 0000 O0 0000 33 O0 O0 O0 O0 O0 O0 33 O0 O0 O0 O0 O0 O0 33 0000 O0 0000 O0 33 0000 O0 0000 O0 33 O0 O0 O0 O0 ,33 33 O0 O0 O0 O0 33 33 000000 000000 333333 000000 000000 333333 *START, USER PCAL [10:07,60531] dOB SHIP SEQ. MONITOR SWS KL10E37 APR 80. *START, FILE: DS~H:VERiFY.003<05/>[10707 60531] CREATED: PRINTED: 20-dUN 80 17:1~:26 QUEUE SWITCHES: /FILE:FORT /COPIES:I /$PACING:I /LIMIT:59 /FORMS:NORMAb 2103 DATE 20-JUN-80 20-JUN-80 17:09:03 17:18:11 SCHLUMBERGER COMPUTING CENTER 10707,60531 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: O1 PREVIOUS REEL NAME: COM~iENTS: LIS FORMAT CUSTOMER TAPE DATE: 80/ 6/20 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: b0531 DATE: 80/ 6/20 SERVICE NAME: EDiT TAPE CI3NTINUAT1ON NUMSER: 01 PREVIOUS TAPE NAME: C[]MMENTS: TAPE COMMENTS CASING DRILLER 9.875~8406/BiT SIZE 8.5/FLUID TYPE GEL'RES/ DENS IO.0/VISC 36/PM 9.0/FLUID bOSS 6.8 RM 2.51@63 F'/RMF' 2 51~64 ~/RMC 2 35~67 F/MAX REC TMP 176 TAKEN ~'ROM RUN~ID~L LOGGED 14MA~80 EOf ~'ILE HEADER LENGTH: 62 BYTES FIL~ NAME: EDIT .00! MAX]MUM PHYSICAL R~iCORD LENGTH: PREVIOUS F1LE NAME: 1024 BYTES WELL SITE INP:ORMATION RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECT]ON: COUNTY: STATE: 178 BYTES SOHIO ALASKA PETRO. CO. D-12 PRUDHOE DAY 13E 11N N. SLOPE ALASKA DATA ~ORMAT SPECI~'ICAI"ION LENGTH: 610 BYTES ~]TRY BLOC[{S: TYPE 0 SIZE 1 REP CODE 66 EN~I, Ry 0 DATUM SPECif'ICATiON BbDC~<S: ENTRY lC TUUL SVORD~ UNITS APl APl AP1 AP1 FIL£# SIZE EXP PROC SAM REP DEPT 1 DEPT 2 SP DIb $ ILD DIL 4 IbM 5 SFLU DiL 6 GR DIL 7 DT D1L 8 GR CNL 9 CALl CNL 10 DRHO FDC 11 NPHI CNL 12 RHOB CNb 1] NRAT CNL 14 NCNL CNL 15 FCNL CNL FT 0 0 0 0 0 4 0 0 ! 68 0 0 MV 7 ! 0 0 0 4 0 0 1 68 0 0 OHMM 7 12 46 ,O 0 4 0 0 ! 68 0 0 OHMM ? 12 44 0 0 4 0 0 I 68 0 0 OHMN 7 22 1' 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 O 0 4 0 0 1 68 0 0 U$/F ? 52 32 0 0 4 0 0 I 68 0 0 GAP1 42 31 32 0 O 4 0 0 I 68 0 0 1N 42 28 ! 0 0 4 0 0 ! 68 0 0 G/C3 42 44 0 0 O 4 0 0 1 68 0 0 PU 42 68 2 0 0 4 0 0 1 68 0 0 G/C3 42 35 ! O 0 4 O 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 O 4 O 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 DEPTH 9449 o 000 9400,,000 9300.000 9200.000 9100.000 9000.000 8900.000 8800.000 8700.000 8600.000 8500.000 MNEMONIC VALUE SP -13.109 GR 103.188 DRHU 0.313 NCNb 2632.000 SP -19,250 GR 95'563 DRHO 0.078 NCNb 2446,000 6P -54.250 GR 61.625 DRHO 0.032 NCNL 2748.000 6P -88.125 GR 27.266 DRHO 0.042 NCNb 2492.000 SP -51.469 GR 11,0.813 DRHO 0.077 NCNb 2102.000 SP -109.500 GR 21.344 DRHO 0.011 NCNb 2646.000 SP -99.375 GR 28.078 DRHO 0.002 NCNL 2902.000 SP -114.625 GR 23.500 DPHO 0.030 NCNL 2508.000 SP -61,563 GR 100,188 DRHO 0.008 NCNb 2846.000 SP -48.250 GR 201.000 DRHO -0.003 NCNb 2394,000 SP -44,000 GR 94.938 DRHO 0,215 NCNb 1585.000 MN EMUNIC iLD DT NPHI FCNL 1LD DT NPHI FCNL iLD DT NPHi fCNL ILD DT NPHI ~'CNL iLD DT NPHI FCNL 1LD DT NPHI fCNL IbD DT NPHI FCNL ILD DT NPHI FCNL ILD DT NPHI fCNL ILD DT NPHI FCNL ILD DT NPHI fCNh VALUE 3.689 75.000 31.104 800.500 3.689 74.750 27.930 731.000 9.289 74,375 16.602 1188.000 89~ 75 847 O0 3,965 79.000 28 125 629.'ooo 26 469 913750 22.607 943.000 15.984 81.563 18.506 1162.000 68.938 92.563 24.023 903.500 24,500 76.000 18.066 1193.000 4.148 107.188 34.277 bi4.000 1.01,5 106.563 35.596 396.250 MNEMONIC GR RHOB GR iLM GR RHOB ibM GR RHOB GR IbM GR RHOB GR RHOB GR RHOB IbM RHO8 IbM GR IbM GR RHOB VALUE 3.385 131.250 2,561 3.746 127,063 2.598 10.414 55.875 2.547 3.021 27~578 2 371 4.082 109.688 2.088 19.063 24.109 2.240 15.227 30.781 2.344 45.844 22.391 2.250 27.266 103.063 2.549 4.309 200.875 2.400 1.136 95.438 2.475 MNEMONIC SFLU CALl NRAT SE'bO C ALI NRAT SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAT 8FLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAT CALl NRAT SFLU CALl NRAI' VALUE 3.703 8.500 3.006 4.078 8.836 2.912 12.102 9.133 2.172 b.820 8.555 2.553 3.328 9.555 2.984 22.953 8.578 2.531 29.750 8.641 2.262 65.063 8.555 2.b27 51.563 9.320 2.289 5.371 9.078 3.34b 1.629 11.703 3.590 DEPTH 8400,000 8374.000 MNEMONIC Gi~ DIRHO NCNL SP DRHO NCNL VALUE -57.938 50.938 -0.063 1526.000 -999.250 -999.250 -0.684 1662.000 1LD DT NPHI FCNL DT NPRi ~CNL VALU~ 2000.000 87.188 49.854 348.750 -999.250 -999.250 48.779 353.250 MNEMONIC GR RHOB VALUE 2000,000 58.844 1.536 -999.250 76.375 1.850 MNEMONIC SFLU CALl NRAT SFLU CALl NRAT VAbU~ 0.790 11.648 4.523 -999.250 8.828 4.273 SUMMARY O~'~ DATA RECORDS NUMBER OF RECORDS: 135 LENGTH O~~ RECORDS: 966 BYTES LENGTH OF LAST RECORD: 426 BYTES ~" ILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECURD LENGTH: NEXT fILE NAME: TAPE TRA1LER LENGIH: 132 BYTES TAPE NAME: 60531 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT TAPE NAME: COMMENTS: 1024 B~TES DATE: 80/ 6/20
