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196-057
THF MATFRIAI.. UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 P M L ATE E W IA L U N D ~ R T H C:LORBMFILM.DOC iS M ARK PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 03/12/98 RUN RECVD 96-057 96-057 96-057 96-057 96-057 7046 7047 SWC RPT CDN - FINAL CDR - FINAL 05/03/96 05/03/96 05/13/96 05/03/96 05/03/96 96-057 COMP THEM-EPI NU g~'BL & SEPIA 1 05/03/96 96-057 DIPOLE SONIC 96-057 DIR SURV ~I~BL & SEPIA ~ASCII 05/03/96 05/03/96 96-057 DAILY WELL OPS END OF WELL RPT ~R'~EPOCH 10-407 R COMPLETION DATE / / / R ~ ~! 2ff~ / TO )~ /~ / And received? no Are dry ditch samples required? 06/03/96 ~/,~ ~' I ~.6 ~-/~/~,(, / ~'/,~o/~',,, / Was the well cored? ~3 no Analysis & description received? Are well tests required? y~~ no Received? Well is in compliance ~, Initial COMMENTS no T PERMIT AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 03/09/98 DATA T DATA PLUS RUN RECVD 96-057 7046 ~T~ SCHLUM. MWD/CDR/CDN 05/03/96 96-057 7047 T'/SCHLUM RFT 05/03/96 96-057 SWC RPT q~CORELAB 05/13/96 96-057 96-057 CDN - FINAL CDR - FINAL ~'BL & SEPIA ~ BL & SEPIA 05/03/96 05/03/96 96-057 COMP THEM-EPI NUq5 BL & SEPIA )> ~- 7~ kS 1 05/03/96 96-057 DIPOLE SONIC J~BL & SEPIA ~D~ASCI I 96-057 DIR SURV 05/03/96 05/03/96 96-057 END OF WELL RPT ~R EPOCH 06/03/96 10-407 ~ COMPLETION DATE ~ /2~// q6/ ~'/~0/ ~/ DAILY WELL OPS R 33/,~ /q~/ TO ~/~ /q~/ Are dry ditch sampl~ required? ~ no And received? Was the well cored? :~ no Analysis & description received? .~,e~~ no Are well tests required? ~! no Received? .~ no Well is in compliancet Initial COMMENTS 96 ...... 0'"- ~"S .... ;., ? ? (3 Z~. ? I'-t I II 96--~057 S W ;'/..: RPT ~;R E LAB 96 .... 057 CP, N .... FINAL ~'ff.'BI 96~.--0"57.. CDR - FINAL. .~,~::,L M W D/" C D R / C D N RFT 96--057 COi','iF' TIdEH---EPl NU(.,I,/BI.. 8: SEF'ZA /?~?' 9,SZ~, 96 .... C}57 DIPOL. E SONZC i.~ E,L. & SEPIA /?~,~o _ ?~2} 96 .... 057 96-~ C)5 ? i 0 .... ¢ CO~,~F'L. ETZC.,N DATa ..?/;..'-/;'% / 1.:.:' ,':~'l 5i '~ :t 'j D ,::.i 'L e: 0 z~ / ::~ 0 / 9 ? R I.j i',.I D A 1' [:.~ .... R E C V D 05/" 03/' 96 05 / 0 ':'/' 05/i3/96 (.15 / Ci :~:~ / 96 05 / 03 / 96 I 0 5 / O, 3 / ..?o 6 '1 0 S/0 3 / 9 6 0 S / 03 / 96 DAZLV W,'-~LL ()PS L,~,<'"- _2/'¢~ ,/"/6 / Ai"e dr"y dS'tc:i', samp'ies r'equ'Jr"ed? ~ C ,Lt., hq N E N T S I r, 'i t -f a l Ana'l ys'i s lq o Well Name: APl if: Location: CONP!DEN; per AOGCC reg. 20 AAC 25.537 WELL SUMMARY ARCO Nanuk #1 50-103-20238-00 ASP: x=379,116 y=,5,957,741 zone:4 S/T/R: 2627' FSL, 868 FWL, sec 19, T11hi, R5E Lease Number: Rig: Elevation: Spud Date: Total Depth: TD Date: Completion Date: Completion Status: Formation @ Casing Record: Production Tests: Geological Tops: Base Permafrost Top West Sak Top Shale Wall Top Albian Top Albian B Top Albian C HRZ K-1 LCU Top Jurassic Total Depth (driller) ADL 384211 Doyon 141 G.L. = 9.6' K.B. = 38' March 12, 1996 7630' MD (-7592' SS) driller March 19, 1996 March 23, 1996 Plugged & Abandoned Jurassic Kingak (Nuiqsut) 16" @ 107' MD 9 5/8" @ 1792' MD none (see RFT below) MD 759' 1010' 2392' 4045' 5245' 5830' 6682' 6900' 6980' 7210' 7630' AUG 'l 9 't996 Alaska Oil & Gas Cons. Commi~lon SS -721' -972' -2354' -4007' -5207' -5792' -6644' -6862' -6942' -7172' -7592' Conventional Cores: none E] ARCO Exploration Company E] ARCO Oil and Gas Company {~ r~ ARCO Alaska, Inc. {~ Record Of Shipment Of Confidential Information IDistrict: Alaska AOGCC Attn.' Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 From: ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn.' Kelli Thibodeau (907)265-6240 (X) Enclosed ( )Under separate cover ()Via /Alpine 3 / Bergschrund 2 ,/Bergschrund 2A -~ Nanuk I ~ Neve 1 ~Temptation 1 /~Temptation lA Well Summary Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Sidewall Core Description Run I as Displayed by ARCO Sidewall Core Description Run 2 as Displayed by ARCO Well Summary Report as Displayed by ARCO Sidewall Core Description - Rotary as Displayed by ARCO Core Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Core Chip Description as Displayed by ARCO Core Chip Description as Displayed by ARCO Well Summary Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Note - PleAse verify and acknowledge receipt, by signing and retur.ning a copy of this transmittal. _, 08/16/96 Receivec~c~i~/" (~ ' Date Remarks: Please Note that all included information is CONFIDENTIAL. P~ E C E IV E P A'JG 19 1996 · Alaska 0il & 623 Cons. Commission:': -- Anchorage ~ & LOCATION-. -CLEARANCE REPORT - . State of Alaska . : -_ ... · . _ . . . . . . Memorandum To ' File': · ALASKA 0IL & C~AS 'CONSERVATION COMMISSION · . . · .' · ..... .', PTI) No. ~ 6 - oo~7 . . Lease ~m~- 3~11 - . . Well N-~e.' ~uu~' ] operator . ~'~o 'Location 5~ lfl-:'-~'iIM~ ~-~ ~'~. .- .. . ....':_ . Abnd Date Spud: ~,~,91~ · "TD~ ~6~O:. ., Completed · . Note casing size, wt, depth, cmt vol, '&.procedure. Sfc Csg: '-~ ' tops :i - ~-_ Perf intervals - "-- O' : Review the well file, and-comment on plugging, well head status, and location clearance - provide loc. clear, code. l~l~' ~, P~u~ ~ ~', i~15' ~')~0o' '~- -.. , .~~-p~ ~v Ay Z%-o'; ,~u~~_ Weli head ~ut off: ~ .. ~~o~ ~~C~ ~~ ~cation -Clear.ce: ~ O ' Conclusions Code Signed Date · I TONY K/VOWLE$, GOVERNOR ALASKA O~L AND GAS CONSERYAT~ON CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 25, 1996 Land Department, ATO 1470 David Sutter, Manager ARCO Alaska, Inc. P O Box 100360 Anchorage, Alaska 99510-0360 Location Clearance, Various North Slope Wells- Revised July 23, 1996 letter for Neve #lA Dear Mr. Sutter: On July 9 and 10, 1996 our representative, John Spaulding, accompanied your Larry Brown on a location clearance inspection of various North Slope locations. He recommended Location Clearance for the following four North Slope exploratory wells: Well Name PTD No. Neve #IA 96-044 Alpine #3 96-007 Nanuk #1 96-057 Temptation # lA 96-074 Final Location Clearance is hereby approved for the four above listed ARCO North Slope exploratory wells. The Commission will require no additional work on subject wells; however, ARCO remains liable if problems with the wells occur in the future. cc: Blair Wondzell lcar4ns TONY KIVOWLE$, GOVERNOR ALASKA OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 23, 1996- -.. . o Land Department, ATO 1470 David Sutter, Manager ARCO Alaska, Inc. ' P O Box 100360 Anchorage, Alaska 99510-0360 Re: Location Clearance, Various North Slope Wells Dear Mr. Sutter: On July 9 and 10, 1996 our representative, John Spaulding, accompanied your Larry Brown on a location clearance inspection of various North Slope locations. He recommended Location Clearance for the following four North Slope exploratory wells: Well Name PTD No. Neve # 1 95-215 Alpine #3 96-007 Nanuk # 1 96-057 Temptation #IA 96-074 Final Location Clearance is hereby approved for the four above listed ARCO North Slope exploratory wells. The Commission will require no additional work on subject wells; however, ARCO remains liable if problems with the wells occur in the furore. David W. Jo ton cc: Blair Wondzell lcar4ns MEMORANDUM TO: THRU: David Jo~n, . Chairman Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 10, 1996 FILE NO: i991gjdd.doc FROM: John spaulding, ~J~,k, SUBJECT: Petroleum Insp. Location Clearance Nanuk #1 Wildcat ARCO Alaska Inc. PTD c~(~- ~--/'~ Wednesday July 10, 1996' ! traveled this date to inspect the area around ARCO's Nanuk #1 well. The AOGCC inspection report is attached for reference. The well head has been removed and the casing stub capped and buried. The area directly over the well has a good mound off gravel for water drainage. The area around the location has been well cleaned and looks very good. Summary: I inspected the Nanuk #1 clearance at this time. location and recommend a location _ Attachments: i991gjdd.xls Unclassified X Confidential (Unclassified if document removed) Confidential STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) FILE INFORMATION: Operator: ARCO ALASKA INC. Address: ANCHORAGE AK. Surface Location: F L, F L Section 19 ,T llN ,R 4E ,M U Well Name: NANUK #1 PTD No.: 96-0057 APl No. 50- Unit or Lease Name: NA Field and Pool: WILDCAT Downhole P&A Date: Inspection Date: I 20 AAC 25.125 - ABANDONMENT MARKER: I Approval Date: Steel Post OD: (4" min) "Length (10' min.) ft. Height Above Final Grade Level (4' min.) Top of Marker Post Closed With: (Welded, Cmt., Cap), Set: (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? All openings closed ? With Marker Plate Diameter: Marker Plate Attached To: Wellhead "Thickness: "Distance Below Final Grade Level: ft. Cutoff Csg Other Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Unit / Lease Name: Well Name: Remarks: Surface Location: F L, F L Section ,T , R , M Inspection Date: I 20 AAC 25.170 - LOCATION CLEANUP: PITS: Filled In: NA Liners Removed or Buried: NA SURFACE CONDITION OF PAD AND / OR LOCATION · Clean: YES ( Note when different from file information) Approval Date: Debris Removed: YES CONTURED ( Rough, Smooth, Contoured, Flat, Compacted ) Type &Quan. of Debris if any remaining on pad and / or location: TYPE AND CONDITION OF SURROUNDING AREA · TUNDRA ( Wooded,Tundra,Grass, Brush, Dirt,Gravel,Sand) Clean: YES Type &Quan. of Debris if any remaining on surrounding area · TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: ICE ROAD ( Dirt, Gravel, Ice, Other) Clean: YES Type &Quan. of Debris if any remaining on access road or surrounding area · CLEANUP WORK REMAINING TO BE DONE ' NON~ AREA IS IN VERY GOOD SHAPE AND CLEAN RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes X No ( If "No" See Reason ) Distribution: orig - Well file c - Operator c- Database c- Inspector Reason: FINAL INSPECTION: Yes X No INSPECTED BY: John H. Spaulding DATE: 7/9/96 FI-000 (Rev. 3/93) 199LGJDD.XLS ARCO Alaska, Inc. AtlanticRichfi¢ldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE- June 2, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: I Sepia Copy Displayed by Schlumberger: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Sepia Copy Displayed. by Schlumberoer: Temptation lA CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTiCLE DEPTH I Biueline Copy Displayed by Schlumberaer: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Biueline Copy Temptation 1 CDN FINAL CDN FINAL CDR FINAL CDR FINAL Displayed by Schlumberger: A PRINT PRINT TRUE VERTiCLE DEPTH PRINT PRINT TRUE VERTICLE DEPTH TO: AOGCC Attn.: Mr. Robert P Crandaii 3001 Porcupine Dr Anchorage Alaska 99501 DATE: June 2, 1996 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: DIGITAL DATA Displayed by Schlumberger: Bergschrund 2A 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ASCII Format-Depth-adjusted Directional Survey Temptation lA 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ASCII Format-Depth-adjusted Directional Survey END OF WELL REPORTS Displayed By EPOCH WELL LOGGING INC.: Bergschrund 2A Nanuk I O~1- (~ Neve 1 Temptation 1 Temptation lA If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: A..pproved for transmittal by: d ~ i~ Manager, Nodh Alas Ioration ~a 0,t & G~s ~ns. C0mrnission ~n¢orage STATE OF ALASKA ALAS~,,,-, OIL AND GAS CONSERVATION COMMIL _ ,ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS r-'-] SUSPENDED ~ ABANDONED r~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, In¢ 96-57 3 Address i8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20238 4 Location of well at surface 9 Unit or Lease Name 2627' FSL, 869' FWL, SEC 19, T 11 N, R 5E, UM ?"?'~?i~.-~i?,7;:.r:~ ~: . N/A At Top Producing Interval ~ ........... ~!~':J ~ '~I~C,&'~J~I 10 Well Number SAME ?i .?~//~r~~.- . _ NANUK #1 At Total Depth ~ 1i Field and Pool SAM E ~-'.-%'_~'~-~'=~-~, ~i ~ WI LDCAT 5 Elevation in feet (indicate KB, DF, etc.) 6 E~A~E:~fgnation and Seria~'~'~'"'-'"'?~ RKB 38' ABOVE SL ADL 384211 12 Date Spudded 13 Date T.D. Reached ~14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore I16 No. of Completions 12-Mar-96 19-Mar-96 3~24-96 AbandonedI NA feet MSLI NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey F1 7630'MD, 7630"I'VD YES ~--~ NO ~ ~A feetMD =800' N^ 22 lype Electric or Other Logs Run LWD: GR, RES, NEUTRON, DENSITY W/L: DSI, CNT, LDT, GR, RFT, MSCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE W'T iGRADE TOP BTM ;HOLE SIZE CEMENT RECORD 16" 62.58# B SURF 107' 20" ~230 sx AS I 9.625" 53.5# L-80 SURF 1792' 12.25" 325 SX AS Ill & 610 SX AS 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED See attached operations summary 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift. etc.) I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ¢ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE ¢ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY MAY 0 1996 Anohorago Form 10-407 Submit in duplicate ~9. : 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. TO BE SENT BY EXPLORATION GEOLOGY 31. LIST OF A'I-FACHMENTS AS-BUILT SURVEYS, P&A DIAGRAM, AND DIRECTIONAL SURVEYS AND DAILY DRILLING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CORE LABORATORIES BASIC ROCK PROPERTIES A I~,~INC. N~.~~IE LL FINAL REPORT Performed for: ARCO ALASKA, INC. 700 G Street, Rm: ATO1450 Anchorage, Alaska 99501 April 24, 1996 Performed by: Core Laboratories, Inc. Rock Properties Laboratory Dallas Advanced Technology Center Carrollton, Texas 75006 File: DAL-96092 The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed repre- sent the best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil. gas. coal or other mineral, property, well or sand in connection with which such report is used or reiied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. PETROLEUM SERVICES April 24, 1996 Ms. Rene Hannon ARCO Alaska, Inc. 700 G Street Rm: ATO1450 Anchorage, Alaska Subject: CMS-300TM Permeability and Porosity of Core Samples Nanuk No. I Well File: DAL-96092 Dear Ms. Hannon, Please find enclosed the results of basic rock properties testing performed on thirty-four 15/16 inch diameter rotary core plug samples delivered to our laboratory for analysis. A description of laboratory procedures is included with the testing results. Preliminary data was provided by fax on April 3, 1996. The plug samples were returned to the client on April 24, 1996. We appreciate the opportunity to have been of service to ARCO Alaska, Inc. If you have any questions or if we may be of further assistance, please call us at (214) 466-2673. Sincerely, Daniel J. Scott Rock Properties Laboratory Dallas Advanced Technology Center Core Laboratories, Inc. 1875 Monetary Lane, Carrollton, Texas 75006-7012, (214) 466-2673, Telex 163166, CORDAL UT, Fax (214) 323-3930 ARCO Alaska, Inc. File: DAL-96092 PROJECT PARTICIPANTS Basic Properties Data Evaluation Report Preparation Daniel J. Scott Final Review Melanie F. Dunn ' Core Laboratories ARCO Alaska, Inc. File: DAL-96092 Sample Preparation and Analysis BASIC ROCK PROPERTIES Analytical Procedures . Thirty-four 15/16 inch diameter rotary plug samples were received for testing. Each sample was removed from its shipping bottle and dry trimmed to form a right cylinder plug. Two samples were held for possible oil extraction and analysis, these samples were numbered 5a and 28a and then tested. The remaining thirty-two plugs were assigned sample numbers and checked for fluorescence, then weighed to 0.01 grams. Each sample was loaded into a pre-boiled Dean-Stark apparatus for distillation to determine residual fluid saturations. The Dean-Stark glassware were sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Extraction time for each sample was approximately 30 hours. After Dean-Stark distillation the samples were placed in a vacuum oven at a temperature of 140°F for twenty-four hours. After the samples cooled, weights were determined. The length and diameter of each sample were measured with digital calipers. Grain volumes were measured in a matrix cup at ambient conditions by the AutoPorosimeterTM using Boyle's law, with helium as the gaseous medium. Grain density was calculated for each sample using the dry sample weight and grain volume data. During these procedures, exposure to the atmosphere was minimized to preclude absorption of moisture. Permeability and porosity were measured using the CMS-300TM at 800 psi confining stress. A standard system leak test of the CMS-300TM was performed before testing to ensure correct equipment operation. A calibrated, known volume check cylinder and a known permeability check plug were run with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability (Kair), along with parameters helium slip factor (b) and the Forcheimer inertial resistance factor beta (r~). Porosity for each plug sample was calculated using Boyle's law by the CMS-300TM with grain volume and pore volume by: Porosity, percent = Vp · 100 Vp + Vg Where: Vp = Pore volume at net confining pressure (cc) Vg = Grain volume (cc) Core Laboratories CMS-300 QUALITY CONTROL DATA Net Confining Stress: 800 psi QC Sample Porosity, fraction umber measured I actual RPD 25-2 1.020 1.000 0.2 QC Sample Permeability to Air, millidarcys Number measured I actual RPD 328B 7.23 7.25 0.3 RPD (relative percent difference) = absolute value ((actual value-measured value)/actual value * 100) Acceptance criteria for porosity -- +/- 0.5 porosity units Acceptance criteria for permeability in this range = +/- 5% 25-2 pore volume -- 8.084 Core Laboratories Permesb~,:~&ty vs, Porosity o© ~00.0 G.O~i Poros~t.y (Boy]es La~ He): ~; 800 CORE ANALYSIS RESULTS(CMS-300 Hydrostatic Confinement) ARCO Alaska, Inc. File: DAL-96092 Nanuk No. 1 15-April-1996 Colville Delta Exploration , , , Rotary .... Net 0,verburden Pressure: 800 psi Dean Stark ' ' Rotary Plug Permeability Grain Saturation Core Depth, Klinkenberg,I to Air, Porosity, Density, 'Oil I Water, Number feet mill!darcys, millidarcys percent ~lm/cc percent PV percent PV Description Rotary Core Analysis Data 1 6150 0.36 0.53 13.4 2.62 14.5 60.6 2 6151 5.46 6.77 17.3 2.70 10.5 52.8 3 6152 0.56 0.81 14.8 2.68 20.4 63.0 4 6153 1.62 2.16 1 5.8 2.71 1 5.8 70.6 5 6154 1.93 2.46 16.4 2.70 13.4 75.5 5a 6155 6 6162 1.05 1.45 1 5.9 2.72 12.7 67.3 7 6165 9.17 10.86 17.6 2.69 10.8 52.4 8 6170 0.21 0.34 13.8 2.70 14.8 65.0 9 6172 0.33 0.50 14.0 2.71 13.7 70.6 10 6173 2.06 2.71 19.3 2.72 3.2 55.4 11 6174 1.1 2 1.53 1 5.8 2.69 9.9 67.3 12 6175 1.42 1.93 18.0 2.76 17.1 66.7 13 6176 1.74 2.32 16.3 2.69 16.8 66.3 14 6196 0.82 1.16 15.6 2.68 18.7 69.2 15 6197 0.60 0.88 16.5 2.71 7.5 72.8 16 6198 1.52 2.05 17.3 2.69 23.6 54.9 17 6205 1.00 1.38 1 5.3 2.68 26.1 71.5 18 6208 0.09 0.16 11.9 2.66 1 2.2 85.1 19 6209 0.13 0.22 12.6 2.65 18.7 77.6 20 6210 1.45 1.95 1 5.8 2.71 17.5 71.6 21 6212 2.50 3.23 16.3 2.68 0.0 84.2 22 6221 0.74 1.06 14.8 2.69 16.2 80.2 23 6231 1.80 2.33 16.0 2.68 0.0 100.0 24 6250 4.03 5.00 16.7 2.68 1 7.8 65.3 25 6254 2.07 2.69 16.0 2.71 14.4 76.2 26 6264 0.44 0.63 14.0 2.67 13.5 83.0 Sst dk gry vf gr slty arg no fluor Sst dk gry vf gr slty arg dull gld fluor Sst dk gry vf gr slty arg no fluor Sst brn-gry vf gr dull gld fluor Sst brn-gry vf gr dull gld fluor Core Chips -- No Analysis Sst brn-gry vf gr dull gld fluor Sst brn-gry vf gr dull gld fluor Sst gry-brn vf gr v slty v arg dull gld fluor Sst brn-gry vf gr arg Slty dull gld fluor Sst gry-brn vf gr arg slt¥ dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn-gry vf gr arg slty dull gld fluor Sst brn-gry vf gr arg slty dull gld fluor Sst brn-gry vf gr arg slty dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn-gry vf gr slty arg frac dull gld fluor Sst brn-gry vf gr v slty arg dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn-lt gry vf gr slty arg dull gld fluor Sst brn-lt gry vf gr sli slty sli arg Sst brn-gry vf gr slty arg dull gld fluor Sst brn-lt gry vf gr slty sli arg dull gld fluor Sst brn-lt gry vf gr slty sli arg Sst brn-lt gry vf gr slty arg dull gld fluor Core Laboratories CORE ANALYSIS RESULTS(CMS-300 Hydrostatic Confinement) ARCO Alaska, Inc. Nanuk No. 1 Colville Delta Exploration File: DAL-96092 15-April- 1996 Rotary Net Overburden Pressure: 800 psi Dean Stark Rotary Plug permeability . Grain Saturation Core Depth, Klinkenberg, I to Air, Porosity, Density, Oil I Water, Number feet millidarcys millidarcys percent gm/cc percent PV percent PV :Description Rotary Core Analysis DaTM 27 6281 0.63 0.92 1 5.1 2.71 1 2.6 83.9 28 6286 0.10 0.18 1 2.9 2.69 14.9 73.5 28a 6975 363. 378. 26.0 2.70 26.8 45.7 29 6977 588. 594. 24.2 2.65 22.6 45.4 30 7264 <0.001 <0.001 3.9 2.69 30,9 56.8 31 7272 0,75 1.03 1 5,5 2.68 16.7 58.4 32 7278 0,32 0.48 14.7 2.68 13.7 41.2 Sst brn-gry vf gr slty arg dull gld fluor Sst brn-gry vf gr slty arg dull gld fluor Sst brn m gr even brt gld-yel fluor Sst brn f-m gr dull gld fluor Sst brn vf g v slty sli calc foss spry gld fluor Sst brn vf gr slty sh lams sli calc wh fluor Sst brn vf gr slty sh lam sli calc wh fluor Corn Laboratories CONFiDENTiAL ARCO Alaska, lnc: ~,,. ? Perl~OGCCteg. 20 Af4C 25.537 Sidewall Core Description-Rotary Operator and Well Name Arco Alaska Inc Nanuk #1 Ct' ~ ~'-O ~' '7 Section of Location 2627' FSL & 868' FWL Sec 19 111N R5E Date August 16, 1996 Shot 49 Recovered 43 Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % Intensit Color color fluor color sum Y 6144 1/4" shale, laminated, silty, drk gry, soft no _ ..¢~ ~' ..... show~!.? . 6145 1/2" silty shale, dark gray, fractured shown° 6146 1/4" silstone, salt and pepper color no 6148 no recovery 6149 no recovery 6150 1.5 silty, vfgr qtz ss, horizontal laminations, none fnt 20 pale It blue fnt It fnt It yell poor lithics about 20%, firm straw 6151 1.5 fgr qtz ss, silty, lithics 10% none fnt 5 pale It blue fnt fnt It yell- poor straw grn 6152 1.5 silty fgr-vfgr lithic ss none fnt 10 fnt It blue fnt It yell-grn poor straw v slow strmg 6153 1.5 silty vfgr ss none v fnt 10 fnt It blue fnt fnt slow poor straw string It yell-grn 6154 1.5 vfgrlithicss, silty none mod 20 fnt It blue fnt fnt yell- poor straw grn slow strmg 6155 .75 fractured vfgr qtz ss, lithics 20% none fnt 10 fnt It blue fnt fnt yell- poor straw grn slow strmg 6156 no recovery Remarks Described by Gerry Van Kooten AR3B-2389-B RECEIVED AUG 1 9 996 Alaska Qil & Gas Cons, Comraissi~ And~o~age ARCO Alaska, Inc. .,ONFiDENTI L per AOGCC reo. 20 AAC 25.537 Sidewall Core Description-Rotary Operator and Well Name Arco Alaska Nanuk #1 ~'~ - O~"'7 Section of 1 Location Date August 16, 1996 Shot I Recovered Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % Intensit Color color fluor colorsum Y 6160 .5 v fg lithic ss, silty, fractured, firm none v fnt 10 v fnt It bluev fnt fnt yell- v poor straw grn slow strmg 6162 1.5 vfgr silty ss, lithics 10% none vfnt 10 vfnt It bluevfnt fntyell- vpoor straw grn slow strmg 6165 1.5 si fdable silty fgr ss none fnt 20 v fnt It bluev fnt fnt yell- poor straw grn slow strmg 6170 1.5 si friable silty fgr ss, clay matdx none fnt 25 v fnt It bluev fnt fnt yell- fair straw grn slow strmg 6171 .5 fractured siltstone none v fnt 10 v fnt It bluev fnt v fnt v poor straw milky yell 6172 1.5 vfgrsiltyqtzss, lithics 15% none fnt 20 vfnt It bluevfnt milkyyell poor straw slow strmg 6173 I vfgrss none vfnt 10 vfnt It bluevfnt milky yell poor straw slow strmg 6174 1.5 vfgrss none vfnt 10 vfnt It bluevfnt milky yell poor straw slow strmg 6175 1.5 vfgr Ithic ss, si friable none v fnt 1 fnt It bluev fnt yell-gm v poor straw slow strmg 6176 1.5 vfgrlthicss none v fnt 5 fnt It bluev fnt yell-grn poor straw slow strmg 6179 .25 shale chips no show 6188 no recovery Remarks Described by Gerry Van Kooten AR3B-2389-B ARCO Alaska, lnc; ,',~ Sidewall Core Description-Rotary Operator and Well Name Arno Alaska Nanuk #1 Section of i [ Location Date August 16, 1996 Shot Recovered Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % Intensit Color color fluor color sum Y 6196 1.5 sandy silstone none v fnt 5 fnt It blue light milkyyell- v poor straw grn slow strmg 6197 1 siltyvfg ss, lithics 5% none v fnt 1 fnt It blue light milkyyell- v poor straw grn slow strmg 6198 1 siltyvfg ss none v fnt 1 fnt It blue light milkyyell- v poor straw grn slow strmg 6202 .25 siltstone, broken pieces no show 6203 .25 siltstone, broken pieces no show 6204 no recovery 6205 1.5 vfgr, vsiltyss none none 5 fnt It blue light milkyyell- v poor straw grn slow strmg 6208 1.5 vfgr, vsilty ss none none 5 fnt It blue light milkyyell- v poor straw grn slow strmg 6209 no recovery 6209 1.5 fgr silty ss, lithics 15% none none 5 fnt Itblue light milkyyell- vpoor straw grn slow strmg 6210 1 fgrsiltyss none none 10 fnt Itblue light milkyyell- poor straw grn slow strmg 6212 1.5 fgrsiltyss none vfnt 5 fnt Itblue light milkyyell- vpoor straw grn slow strmg Remarks Described by Gerry Van Kooten AR3B-2389-B ARCO Alaska, inc. ,'~ Sidewall Core Description-Rotary Operator and Well Name Arco Alaska Nanuk #1 Section of 1 Location Date August 16, 1996 Shot I Recovered Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % Intensit Color color fluor color sum Y 6221 1.5 vfg siltyss none none 1 fnt It blue fnt milkyyell- poor light grn slow straw strmg 6231 1.5 fg silty ss none v fnt 20 fnt It blue fnt milkyyell- fair light grn slow straw strmg 6250 1.5 fg silty ss none v fnt 40 fnt dull fnt milkyyell- fair gold light grn mod straw strmg 6254 1.5 fg siltyss none vfnt 15 fnt It blue fnt milkyyell- poor light grn mod straw strmg 6264 1.5 fg siltyss none v fnt 20 fnt It blue fnt milkyyell- poor light grn slow straw strmg 6281 1.5 fg siltyss none v fnt 15 fnt It blue fnt milkyyell- poor light grn mod straw strmg 6285 1.5 vf gr qtz ss to siltstone patch mod 40 fnt It blue fnt It yell-grn fair y brn light straw 6975 1.5 fdable qtz ss, f gr brn strg 90 mod gold It milky yell Exc straw 6977 1.5 fgr qtz ss, rounded grains, well srted, patch mof 95 faint It yell- It grn-yell Exc dissolution vugs, firm y strg grn straw 7264 1.5 qtz ss, vfgr w/ abundant clay, lithics 10- spotty faint 10 mod yell- none none Poor 15%, py grn 7272 1.5 vf-fgr qtz ss w/accessory py, lithics mod 85 dull It yell- It It yell Exc about 20%, frm-hrd strg grn straw 7278 1.5 vf gr qtz ss, comm py, gd sorting, firm brn mod 90 mod yell- pale yell Exc strg grn straw Remarks Described by Gerry Van Kooten AR3B-2389-B CONFIDENTIAL per AOGCC reg. 20 AAC 25.537 ARCO ALASKA INC. NANUK NO. 1 Section 19, T 11N-R5E U M Wildcat Colviile Delta North Slope, Alaska Epoch Well Logging, Inc. I'A~I E OF CONTENTS 1. Well Resume 2. Daily Chronology 3. Daily Activity Summary Mud Record 5. Bit Record 6. Morning Reports 7. Drilling Curve 8. Rig Acivity 9. Formation Log 10. Drilling Dynamics Log 11. MWD Combo Log WELL RESUME OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: · STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE ~.D.): CONTRACTOR: RIG ~:: RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY ENGINEERS: TOOLPUSHERS: MUD COMPANY: MUD TYPES: HOLE SIZES: CASING DATA: MUDL~ING SERVICES: TYPE UNIT: UNIT #: LOC~GING GEOLOGISTS: SAMPLE TECHNICIANS: ELECTRIC LOC~ BY: LOG INTERVALS: DST INTERVALS: CORED INTERVALS: CORING COMPANY: WELL STATUS: ARCO ALASKA INC. NANUK NO. 1 SEC. 19, T11 N R5E, UM COLVILLE DELTA 2627' FSL, 868' FWL 39.0' RKB 9.6' GL NORTH SLOPE BOROUGH ALASKA MARCH 11,1996 7630' MARCH 19, 1996 DOYON DRILLING COMPANY NO. 141 SCR DIESEL-ELECTRIC (2) NATIONAL Al 700 (6" X 1 RENEE HANNAN BILL PENROSE/DONNIE LUTRICK CHUCK SCHEVE / TOM COVINGTON BAIL'OlD DRILLING FLUIDS, INC. SPUD TO 1800' / LSND TO 7630' TD 20"TO 10G', 12 1/4" TO 1800', 8 1/2" TO 7630" 16= AT 108", 9 5/8" AT 1787" EPOCH WELL LOGGING, INC. (FID)GAS DETECTION DML/RIGWATCH/RIGTRAK 6 JOHN MORRIS, LEES F. BROWNE DAVE I~OE, BRAD GREEN SCHLUMBERGER NO DOPE NONE NONE NONE NO DOPE. TIGHI' HOLE ii i i il , l i i i DAILY CHRONOL 0(3 Y NANUK NO. 1 I Il I I III I III I 3-12-96: 3-13-96: 3-14-96: 3-15-96: 3-16-96: 3-17-96: 3-18-96: 3-19-96: Finish rigging up. Pick up BHA and hold safety meeting. Fill hole with mud and check mud system for leaks. Drill and clean to bottom of conductor. Repair flow line. Drill to 270'. POOH to service Anadrill MWD tool. Lay dowm MWD tool and pick up new MWD tool. Inspect bit - locked up with piece of metal - bit OK. Run in hole and drill from 270' to 410'. POOH to conductor and repair cuttings auger. Wipe hole 10 stands. Drill from 410' to 1546'. Drill from 1546' to 1800'. Circulate hole clean. POOH. Hole tight at 136' and 1544' - 15 klbs overpull. RIH and circulate hole clean. POOH and lay down BHA. Rig up and run 9 5~8" casing. Circulate through casing. Hold safety meeting. Cement 9 5~8" casing and rig down casing equipment. Lay down casing equipment and cementing equipment. Nipple down diverter. Hold safety meeting. Nipple up BOPE. Pick up BHA and RIH. RIH. Drill cement form 1658' to 1674'. Pressure test casing. Drill cement to casing shoe at 1799'. Lost 60 barrels of mud. Hole then stabilized. Run leak-off test. Drill to 2791'. Circulate bottoms up and wipe hole to casing shoe. Encountered tight hole. Drill ahead from 2791' to 2795'. Drill from 2795' to 3791'. Circulate a high viscosity sweep. Make short trip to casing shoe. Drill ahead from 3791' to 4790'. Make a short trip to casing shoe. Make a short trip to 3774'. Hole intermittently tight at 4150' to 3963'. Drill from 4790' to 5793'. Wipe hole 11 stands. Drill from 5793' to 6736'. Drill from 6736' to 6796'. Circulate hole clean and make a wiper trip to casing shoe. Encountered tight hole from 6216' to 5180' with intermittent swabbing. Repair flow line and service rig while at casing shoe. Drill ahead from 6796' to 7200' with a controlled ROP of 60 feet per hour. Drill from 7386' to total depth of 7630'. DALLY ACTIVITY SUMMARY: SPUD TO T.D. [ I Arco Alaska, Inc. i i I ' i WELL: ' NANUK #1 ACTIVITY ;HOURS 12: 13 14 i 15; 16; 17 18 19 Drill/Core 89.0 4 15.5 2.5 11.5 19.5 ;'2.0 14.0 Trip/BHA 35.0 5.5 4.0 7.5 6.0 3.0 1.5 7.5 Circulate 8.0 4.0 1.5 0.5 2.0 ..W...o..,.k. ?. ?..~!.g. ............................... .O.._~_ ..................................., i ......................... . ............... L ...........................................0.~ Casing/Cementing 25.5 / 13.5 5 5 6 5 BOP Testing/Rig-Up 10.5 _ 10.5 / Misc.____ Rigup 9.0 9.0/, ~ ! I 'Other 8.5 8.8 ! !' I T 06:00 DEPTH 7630 270 . 1653 ' 1800 .i 1800 ] 2884 4855 i~ ..... .!.67969~41 ........ . ....... 7630.~..3.~ FOOTAGE 7523 163 1383 147 0 1084 1971 DAILY AVG 940.4 I ~ t ! i ARCO ALASKA, INC. Mud Data Provided By: Well: NANUK ~1 BAROID .... i DATE DEPTH MW ViS PV YP GELS FILTRATE,?,AKE SOLIDS SAND M.B. CAF pH K. MIiALK. FIL. CI- Ca+ 3/11/96 234 10.0 86 66 48 18/26 10.8 2 8.0 0.5 25,0 9,0 0 0.1/0.28 650 40.0 3/12/96 234 10.0 86 66 48 18/26 10.8 2 8.0 0.5 25.0 9.0 0 0.1/0.28 650 40.0 3/13/96 1377 10.0 64 16 24 18/20 9.6 2 10.0 3 25.0 8.5 0 0.0/0.18 500 40.0 ! 3/14~96 1800 10.0 58 22 24 18/34 9.4 3 11.0 NA 22.5 7.5 0 0.0/1.60 500 0.0 3/15/96 1800 10.0 44 17 9 2/8 8.4 2 11.9 0.1 20.0 8.5 0 0.0/2.20 1500 20.0 3/16/96 2790 10.4 47 14 9 4123 6.8 2 9.9 TR 22.5 8.6 1.4 0.0/2.10 2400 400,0 3/17/96 4787 10.3 46 14 10 3/15 6.0 2 10.9 TR 22.5 8.8 0 0.0/0.80 1100 320.0 3/18196 6576 10.2 46 21 20 4/11 6.3 2 11.0 TR 30.0 8.8 0 0.0/0.70 700 , 3/19196 7601 10.2 43 20 13 5/11 4.0 2 12.0 IR 20.0 9.0 0 0.1/0.80 600 100.0 BIT RECORD ARCO ALASKA. INC. NANUK #1 BIT # SIZE MAKEAND SERIAL ,.lETS DEPTH DEPTH FEET ON BTI~ AVG WOB BIT RPM PUMP PRES MUD MUD GRADE TYPE NUMBER IN OUT HOURS ROP Iow-high-avg Iow-high-avg low-hi~lh-av~l WT VIS T-B-G I 12.25 STC MA1SL LE5651 2X15,1X1O 107 1800 1693 10.0 169.0 1-29-.14 24-406-119 1106-2576-2041 10.0 48 2-2-WT-A-E-I-ER-TD 2RR 8.5 HYCA SX70 B2 F+GV 17754 6X10 1800 7630 5830 37.0 157.6 1-30-7 111-403-367 1897-4028-3310 10.2 43 2-2- E R-A-N/A- 1/16-CT/BT-T D Epoch Well Logging, Inc. EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-12-96 05:00 Depth: 270' 0'D) YESTERDAY: 109' Last Casing: 16" @ 109' 24 Hour Progress: 161' BIT INFORMATION: No. Size Type 1 12.25" STC MAISL S/N LE5657 Jets 1x10,2x15 Interval Ftg Hours Condition 109'-270' 161' 1.4 In Hole DRILLING PARAMETERS: HIGH Rate of Penetration 297 at 246' Torque 105 at 249' Weight on Bit 12 at 251' Rotary RPM 109 at 139' Pump Pressure 1310 at 225' LOW AVERAGE 25 at 206' 127 ft/hr 62 at 260' 79 amp 1 at 232' 5 Klbs 86 at 250' 100 rpm 1211 at 150' 1262 psi DRILLING MUD REPORT: Report Depth' 234' MW 10.0 VIS 86 PV 66 YP 48 GELS SOL 8 OIL 0 SD .5 MBT 25.0 pH 18/26 FL 10.8 9.0 Cl- 65O GAS S[~/IMARY: HIGH LOW Total Ditch Gas (units) 0 at ' at ' Total Cuttings Gas (units) at ' at ' Methane (C-1) (ppm) at ' at ' Ethane (C-2) at at Propane (C-3) at at Butane (C-4's) at at Pentane(C-5's) at at Background Gas: 0 units Trip Gas: na units at Connection Gas: 0 units Wiper Gas: na units at FC 2 Ca+ 40 AVERAGE units units ppm ppm ppm ppm ppm , , LITHOLOGY' 90% gravel, 10% sand ACTIVITY SUMMARY:Finish rigging up, pick up BHA, hold safety meeting, fill hole with mud, check mud system for leaks, drill and clean to bottom of conductor, repair flow line, drill to 270', POOH to service Anadrill MWD tool. ESTIMATED PORE PRESSURE: 9.5 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML ML~LOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: Jotul Morris EPOCH WELL LOGGING, INC. MORNING REPORT ARCO AI SKA INC. NANUK #1 Date: 3-13-96 05:00 Depth: 1546' el'D) YESTERDAY: 270' Last Casing' 16" @ 110' 24 Hour Progress: 1276' BIT INFORSLATION: No. Size Type 1 12.25" STC MAISL SIN Jets Interval Ftg Hours Condition LE5657 1X10,2X15 110'-1546' 1436' 4.8 IN HOLE DRILLING PARAMETERS: HIGH LOW AVERAGE Rate of Penetration 972 at 1182' 32 at 1373' 238 ft/hr Torque 133 at 586' 22 at 1373' 97 amp Weight on Bit 29 at 1277' 1 at 1374' 15 Klbs Rotary RPM 130 at 1195' 24 at 302' 112 rpm Pump Pressure 2576 at 395' 1106 at 382' 2077 psi DRILLING M-LTD REPORT: Report Depth: 1377' MW 10.0 ViS 64 PV 16 YP 24 GELS SOL 10 OIL 0 SD 3 MBT 25 pH 18/28 FL 9.6 FC 2 8.5 Cl- 500 Ca+ 40 GAS SUM/MARY: H IG H LOW AVERAGE Total Ditch Gas (units) 15 at 882' 1 at 471' 4 units Total Cuttings Gas (units) 0 at ' at ' units Methane (C-1) (ppm) 2980 at 882' 100 at 471' 865 ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4's) at at ppm Pentane(C-5's) at at ppm Background Gas: 3 units Trip Gas: 2 units at 270' Connection Gas: 0 units Wiper Gas: 5 units at 1408' LITHOLOGY: 70% SAND, 30% CLAYSTONE ACTIVITY SUMMARY:Lay down 54WD tool, pick up new MWD tool, inspect bit--locked up with piece of metal, bit o.k. Run in hole, drill 270' to 410'. P.O.O.H. to conductor, repair cuttings auger. Run in hole, drill to 1408', wipe hole 10 stands, drill to current T.D. ESTIMATED PORE PRESSURE: 9.5 ppg REMARKS: Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bm Penrose/Dome Lutrick Report By: John Moms EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-14-96 05:00 Depth: 1800' (-I'D) YESTERDAY: 1546' Last Casing: 16" @ 110' 24 Hour Progress: 254' BIT INFORMATION: Size Type 1 12.25" STC MAISL S/N Jets LE5657 lXl 0,2Xl 5 Interval Ftg Hours Condition 110'-1800' 169' 10.0 NA DRILLING PARAMETERS: HIGH Rate of Penetration 481 at 1533' Torque 121 at 1442' Weight on Bit 25 at 1741' Rotary RPM 128 at 1452' Pump Pressure 2339 at 1639' LOW AVERAGE 23 at 1724' 209 ft/hr 76 at 1493' 94 amp 2 at 1501' 14 KIbs 75 at 1478' 111 rpm 2127 at 1532' 2255 psi DRILLING MUD REPORT: Report Depth: 1800' MW 10.0 VIS 58 PV 22 YP 24 GELS SOL 11 OIL 0 SD na MBT 22.5 pH 18/34 FL 9.4 FC 3 7.5 CI- 500 Ca+ 0 GAS SLrMMARY: HIGH LOW AVERAGE Total Ditch Gas (units) 6 at 1646' .6 at 1726' 3 units Total Cuttings Gas (units) 0 at ' at ' units Methane (C-1) (ppm) 1190 at 1646' 120 at 1726' 602 ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4's) at at ppm Pentane(C-5's) at at ppm Background Gas: 3 units Trip Gas: units at ' Connection Gas: 0 units Wiper Gas: 3 units at 1800' LITHOLOGY: 70% CLAYSTONE, 30% SAND ACTIVITY SUMMARY: Dfi]] to 1800', circulate hole clean, pull out of hole, hole tight at 136' and 1544'--15 klbs overpull. Run in hole, circulate hole clean, pull out of hole, lay down BHA, rig up and run 9 5/8" casing. Circulate through casing, hold safety meeting, cement casing, rig down casing equipment. ESTIMATED PORE PRESSURE: 9.5 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms EPOCH WELL LOGGING, 1NC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-t 5-96 05:00 Depth: 1800' (TD) YESTERDAY: 1800' Last Casing: 9 5/8" 24 Hour Progress: 0' BIT INFORMATION: No. Size Type S/N Jets Interval Ftg Hours Condition 2RR 8.5" HYCA SX70 17754 6X10 1800'- 0' 0 IN HOLE DRILLING PARAMETERS: HIGH LOW AVERAGE Rate of Penetration 0 at ' at ' ft/hr Torque at ' at ' amp Weight on Bit at ' at ' Klbs Rotary RPM at ' at ' rpm Pump Pressure at ' at ' psi DRILLING MUD REPORT: Report Depth: 1800' MW 10.0 VIS 44 PV 17 YP 9 GELS 2/8 FL 8.4 FC 2 SOL 11.9 OIL 0 SD .1 MBT 20 pH 8.5 Cl- 1500 Ca+ 20 GAS SUN[MARY: H IG H LOW AVE RAG E Total Ditch Gas (units) 0 at ' at ' units Total Cuttings Gas (units) at ' at ' units Methane (C-1) (ppm) at ' at ' ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4's) at at ppm Pentane(C-5's) at at ppm Background Gas: 0 units Trip Gas: NA units at ' Connection Gas: NA units Wiper Gas: NA units at ' LITHOLOGY' NO NEW HOLE. ACTIVITY SUMMARY:Lay down casing equipment and cementing equipment, nipple down diverter, hold safety meeting, nipple up BOPE, test BOPE, pick up BHA, run in hole. ESTIMATED PORE PRESSURE: 9.5 ppg Epoch Persomtel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Domfie Lutrick Report By: Joint Moms EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-16-96 05:00 Depth: 2795' (TD) YESTERDAY: 1800' Last Casing: 9 5/8" at 1792' 24 Hour Progress: 995' BIT INFORMATION: No. Size Type SIN Jets 2RR 8.5" HYCA SX70 17754 6xl 0 Interval Ftg Hours Condition 1800'-2795' 995' 5.2 In Hole DRILLING PARAMETERS: HIGH Rate of Penetration 514 at 2605' Torque 114 at 1851' Weight on Bit 14 at 2195' Rotary RPM 402 at 2234' Pump Pressure 3333 at 2159' LOW AVERAGE 61 at 2188' 219 ft/hr 52 at 2079' 86 amp 2 at 2743' 6 Klbs 299 at 2645' 268 rpm 1897 at 2273' 2889 psi DRILLING MUD REPORT: Report Depth: 2790' MW 10.4 VIS 47 PV 14 YP 9 GELS SOL 9.9 OIL 0 SD tr MBT 22.5 pH GAS SU-~~Y: HIGH LOW Total Ditch Gas (units) 400 at 2636' 1 Total Cuttings Gas (units) 3 at 2720' 0 Methane (C-1) (ppm) 72521 at 2636' 120 Ethane (C-2) 2493 at 2636 0 Propane (C-3) 866 at 2727 0 Butane (C-4's) 373 at 2636 0 Pentane(C-5's) at Background Gas: 40 units Connection Gas: 25-200 units 4/23 FL 6.8 FC 2 8.6 CI- 2400 Ca+ 480 AVERAGE at 1939' 60 units at 2785' .4 units at 1939' 11184 ppm at 2317 317 ppm at 2347 78 ppm at 2348 50 ppm at ppm Trip Gas: na units at ' Wiper Gas: 315 units at 2791' LITHOLOGY: 40% CLAYSTONE, 50% SHALE, 10% TUFF ACTIVITY SUMMARY:Run in hole, drill cement from 1658' to 1674', pressure test casing. Drill cement, casing shoe to 1799'. Lost 60 bbl mud, hole then stabilized, performed leak-off test. Drill to 2791 ', circulate bottoms up and wipe hole to casing shoe--hole is tight--, drill 2791' to 2795' ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA i c. NANUK #1 Date: 3-17-96 05:00 Depth: 4790' C'D) YESTERDAY: 2795' Last Casing: 9 5/8" at 1792' 24 Hour Progress: 1995' BIT INFORMATION: No. Size Type S/N Jets 2RR 8.5" HYCA SXT0 17754 6X10 Interval Ftg Hours Condition 1800'-4790' 2990' 14.8 IN HOLE DRILLING PARAMETERS: HIGH Rate of Penetration 505 at 4423' Torque 110 at 4420' Weight on Bit 30 at 4708' Rotary RPM 363 at 4723' Pump Pressure 3682 at 3904' LOW AVERAGE 27 at 3713' 259 ft/h r 45 at 2884' 79 amp 2 at 3917' 6 Klbs 79 at 4334' 356 rpm 2157 at 3294' 3279 psi DRILLING MUD REPORT: Report Depth: 4787' MW 10.3 ViS 46 PV 14 YP 10 GELS 3/15 FL SOL 10.9 OIL 0 SD TR MBT 22.5 pH 8.8 Cl- 6.0 FC 2 1100 Ca+ 320 GAS SUMMARY: HIGH Total Ditch Gas (units) 968 at 4060' Total Cuttings Gas (units) 380 at 4100' Methane (C-1) (ppm) 14397'0 at 4060' Ethane (C-2) 8876 at 4071 Propane (C-3) 7328 at 4071 Butane (C-4's) 4096 at 4071 Pentane(C-5's) 1924 at 4071 LOW 2 at 0 at 208 at 0 at 0 at 0 at 0 at AVERAGE 3371' 78 units 4725' 51 units 3243' 11894 ppm 2840 731 ppm 3402 451 ppm 4725 259 ppm 4725 68 ppm Background Gas: 55 units Connection Gas: 0 to 412 units Trip Gas: units at ' Wiper Gas: 645 units at 3791' LITHOLOGY: ACTIVITY SUMMARY: Drill 2795' to 3791', circulate hi vis sweep, short trip to shoe, drill 3791' to 4790' short trip to shOe. ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Pezrrose/Donnie Lutrick Report By: John Moms EPOCH WELL LOGGING, 1NC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-18-96 05:00 Depth: 6736' 0'D) YESTERDAY: 4790' Last Casing: 9 5/8" at 1792' 24 Hour Progress: 1946' BIT INFORMATION: No. Size Type SIN Jets 2RE 8.5" HYCA SX70 17754 6Xl 0 Interval Ftg Hours Condition 1800'-6736' 4936' 26.3 IN HOLE DRILLING PARAMETERS: HIGH Rate of Penetration 456 at 5111' Torque 120 at 6308' Weight on Bit 25 at 5865' Rotary RPM 403 at 5914' Pump Pressure 4028 at 5585' LOW AVERAGE 13 at 5954' 216 ft/hr 27 at 5825' 98 amp 2 at 6173' 9 Klbs 70 at 5262' 367 rpm 3400 at 5262' 3509 psi DRILLING MI. JD REPORT: Report Depth: 6576' MW 10.2 VIS 45 PV 21 YP 20 GELS 4Ill FL SOL 11 OIL 0 SD TR MBT 30 pH 8.8 Cl- 6.3 FC 2 700 Ca+ 80 GAS SUb.~Y: H IG H LOW Total Ditch Gas (units) 1220 at 6221' 5 at Total Cuttings Gas (units) 320 at 6320' 0 at Methane (C-1) (ppm) 96389 at 6221' 897 at Ethane (C-2) 16543 at 6221 61 at Propane (C-3) 21362 at 6221 8 at Butane (C-4's) 13687 at 6221 0 at Pentane(C-5's) 5557 at 6221 0 at AVERAGE 6016' 86 units 5840' 37 units 6016' 11293 ppm 6016 940 ppm 5095 773 ppm 6030 447 ppm 6148 173 ppm Background Gas: 40 units Trip Gas: NA units at ' Connection Gas: 0-185 units Wiper Gas: 290 units at 5793' LITHOLOGY: 70% SHALE, 20% SILTSTONE, 10% SANDSTONE ACTIVITY SUMMARY: Wipe hole to 3774', intermittantly tight at 4150' to 3963'. Drill 4790' to 5793', wipe hole 11 stands, drill to current T.D. ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DM[, MUDLOGGING Arco Reps: Bm Penrose/Donnie Lutrick Report By: John Moms EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA INC. NANUK #1 Date: 3-19-96 05:00 Depth: 7630' (TD) YESTERDAY: 6736' Last Casing: 9 5/8" at 1792' 24 Hour Progress: 894' BIT INFORMATION: No. Size Type S/N Jets 2RR 8.5" HYCA SX70 17754 6X10 Interval Ftg Hours Condition 1800'-7630' 5830' 37.0 IN HOLE DRILLING PARAMETERS: HIGH Rate of Penetration 332 at 6943' Torque 114 at 7413' Weight on Bit 16 at 7625' Rotary RPM 387 at 7402' Pump Pressure 3768 at 7498' LOW AVERAGE 29 at 7525' 113 ft/hr 73 at 7199' 94 amp 1 at 6774' 6 Klbs 62 at 7583' 364 rpm 2985 at 7359' 3417 psi DRILLING MUD REPORT: Report Depth: 7601' MW 10.2 VIS 43 PV 20 YP 13 GELS SOL 12 OIL 0 SD TR MBT 20 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 395 at Total Cuttings Gas (units) 200 at Methane (C-I) (ppm) 39796 at Ethane (C-2) 4293 at Propane (C-3) 6140 at Butane (C-4's) 4372 at Pentane(C-5's) 1509 at 5/12 FL 4.0 FC 2 9.0 CI- 600 Ca+ 1 O0 LOW AVERAGE 6983' 5 at 7552' 48 units 7310' 0 at 7270' 11 units 6983' 607 at 7552' 5935 ppm 7276' 54 at 7552' 532 ppm 6983' 46 at 7552' 491 ppm 7276' 21 at 6926' 332 ppm 6983' 0 at 7625' 73 ppm Background Gas: 40 units Trip Gas: NA units at ' Connection Gas: 0-80 units Wiper Gas: 525 units at 6795' LITHOLOGY- 70% SHALE, 20% SILTSTONE, 10% SAND ACTIVITY SUMMARY: Drill to 6796' circulate hole clean, wipe hole to shoe. Tight from 6216' to 5180', with intermittant swabbing. Repair flow line at casing shoe and service rig. Drill from 6796' to 7200', begin controlling R.O.P to 60 fr per hour. Drill to 7386'. Drill ahead from 7386' to T.D. at 7630'. ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Morris DRILLING TIME SCHEDULE DEPTH (THOUS~OS) 0 ~2 -4 -6 -8 -10 0 1 2 3 4 3~ 11-96 to 3~ 19-96 5 6 7 8 9 DAYS 10 11 12 13 WELL LOGGING ARCO ALAS~ INC. NANUK 1 2,500 2,000 1,500 1,000 500 0 0 2 4 6 8 t0 BOP Testing/Rig-Up 5% Casing/Cementing 13% Work or~ RiG O% Circulate 4% Misc, Rigup 5% EFC ~iCBHA 19% Other 4% ARCO A~SKA, BANUK #1 RIG ACTiViTiES: SPUD TO Drill/Core 47% [] Drill/Core [] Trip/BHA ID Circu late [] Work on Rig [] Casing/Cementing [] BOP Testing/Rig-Up [] EFC [] Misc. Rigup [] Other Date: 5/10/96 ARCO ALASKA INCORPORATED WELL SUP94ARY REPORT Page: 1 WELL:NANUK #1 RIG:NO RIG WELL ID: AX9343 AFC: AX9343 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20237-00 03/11/96 (1) TD: '( 0) SUPV:DCL 03/12/96 (2) TD: 270'( SUPV:DCL 03/13/96 (3) TD: 1653'( SUPV:WJP 03/14/96 (4) TD: 1800'( SUPV:WJP 03/15/96 (5) TD' 1800'( SUPV:WJP 03/16/96 (6) TD: 2884'( SUPV'WJP 03/17/96 (7) TD: 4855'( SUPV:WJP 03/18/96 (8) TD' 6796'( SUPV:WJP 03/19/96 (9) TD: 7630'( SUPV:WJP 163) 1383) 147) 0) 1084) 1971) 1941) 834) MW' PV/YP: APIWL: N/U DIVERTER Move rig from Alpine #3. Assemble modules. Start NU diverter. MW: 10 PV/YP: 66/48 APIW-L: 10.8 REPLACE MWD Function test diverter. Held pre-spud safety meeting. Spud 0000 3/12/96. Drill from 107' to 270'. MWD failure. MW: 10 PV/YP: 14/22 APIWL: 10.8 DRILLING 12.25" HOLE Drill 12.25" hole 270' to 1653' MW: 10 PV/YP: 16/20 APIWL: 5.6 N/D DIVERTER Drill 1653' to 1800'. Run 9-5/8" casing to 1788'. Cement casing. CIP @ 0010 hrs. Floats did not hold. Extend top job line to 107'. Pump top job. MW: 10 PV/YP' 17/9 APIWL: 8.4 DRILLING CEMENT Safety stand down. N/U BOPE. Test BOPE to 250/3000 psi. RIH w/HWDP. Drill soft cement to 1650' MW: 10.4 PV/YP: 14/9 APIWL: 6.8 DRILLING 8.5" HOLE Drill soft cement 1650' to 1658', hard cement 1658' to 1674'. Pressure test 9-5/8" casing to 2500 psi for 30 minutes, OK. Drill cement 1674' to float collar at 1701' Drill 10' of new hole to 1810'. Conduct LOT. Drill 8.5" hole 1810' to 2884' MW: 10.3 PV/YP: 14/10 APIWL: 6.0 DRILLING 8.5" HOLE Drill hole from 2884' to 4855'. MW: 10.2 PV/YP- 21/20 APIWL: 6.3 CIRC(PREP FOR CLEANOUT TRIP TO SHOE) Drill 8.5" hole from 4855' to 6796' MW: 10.2 PV/YP: 20/13 APIWL' 4.0 CONDITIONING HOLE FOR LOGS POH to surface casing shoe. Hole tight 6216' to 5480'. Drill 8.5" hole 6796' to 7630' Trip out to 6600' Slight overpull at 7307', no swabbing, good fill-up. RIH to TD. Hole in good condition. C&C hole for logs. 03/20/96 (10) TD: 7630'( SUPV:DCL 0) MW: 10.2 PV/YP: 25/19 APIWL: 4.4 WIPER TRIP POH. Monitor well at shoe. No problems. Run DSI/CNT-G/LDT/ GR from WL TD 7628' to shoe at 1792' 03/21/96 (11) TD: 7630'( SUPV:DCL 03/22/96 (12) TD: 7630'( SUPV:DCL 0) 0) MW: 10.2 PV/YP: 16/12 APIWL: 4.6 SCHLUMBERGER MSCT RIH TO 7575'. Wash and ream to 7630' Monitor well. Run AMS-GR-RFT..Tgqk_pres.$u~9 readings. Took samples. POH. RIH w/MSCT. Cut 12 cores[ MW: 10.2 PV/YP: 16/12 APIWL: 4.6 PREP FOR PLUG #3 Continue to d~UdSres!. Pump cement. 03/23/96 (13) TD' 7630'( SUPV:DCL 0) MW: PV/YP: APIWL: ND BOPE Spot 20 bbls hi-vis pill. Pump cement. POOH. WOC. Tag cement at 3285'. RIH w/EZSV and set at 1715'. Pump cement. Test casing to 500 psi. RIH with bridge plug and set at 250'. Pump cement. ND BOPE. 03/24/96 (14) TD: 7630'( SUPV:DCL 0) MW: PV/YP: APIWL: RIG RELEASED ND BOPE. Prep for move. Release rig @ 1500 hrs. 3/11/96. End of WellSummary for Well'AX9343 ~OM :~RCO DRILLING OO¥ON 141 18:01 PAGE NO, 1 JJJJlJJJJ JJJJJJJJlJ ttilliil, i Iltlttlttt COMPANY ARCO ~LA$1~ ~ELL M~ME MANUS NO, 1 LOCAtlOH I ~OLVILLE ~£LTA LOCATION 2 NSB, MAGH£TIC ~ECLINATtON 2~,7o DATE: MELL HUMBER 0 NELL HEAD LOCATION: LAT(H/-S) 0,00 AZIMUTH FRO~ ROTARY TABLE TO TA£G£T IS t G 0,00 TIE IN POINT(TIP) : MEASURED DEPT~ 0,00 TRUE VERT. D£PTH 0,00 IHCLINATI~H 0,00 AZIMUTH 0,00 LATITUD£(N/-5) DEPARTUR£(£/'g) FROM :ARCO ~11~ P.O4/OS D~PTH ft 179,33 248.41 347,18 427,72 YNT£RVAL VERYICAL TARGET STATIQM ~ZIML{YH D£PYH S£CYION INCLN, YT ft f~ d~ deq ft 0,0 0.00 O.OO 0.00 0,00 0,00 177,3. 27~,33 0,0{ 0,14 281,35 0.04 ~9.1 24a.4~ 0.04 0,09 ~07,0B ~8,~ 347,18 -0,~2 0,26 1Z7,6a -0.12 80,5 ~Z7,7Z -0.2S 0.38 94,56 -0.25 527,40 99.7 527.39 -0.24 0,41 86,42 618,59 71,2 618,58 -0,24 0;51 ?0,00 710.B9 92.3 710,86 -0,17 0.46 80.Z4 802,8? 92,0 802,87 '0.14 0,94 92,24 878,28 75.4 $7~,26 -0,30 0.71 104.43 924,90 984,78 1081,62 1175,79 126~,24 1360.01 1448.05 1542.72 1727.42 I752.17 1834,97 192~.30 2021,32 2111,~4 2205,04 2486,03 2576,33 2763,47 28~6,44 2949,76 3044,18 3532.41 4019,60 4484,77 4953,47 $410,57 46,4 924.87 '0,37 0,71 a&,56 61,Y 784,75 -0,36 0,54 8~,07 94,8 1081,58 -0,10 0,60 59.42 94.2 1175,75 O,dO 0.40 26,91 90,5 1246.20 1,37 0,46 i5,44 93,8 135~,96 Z.04 0,40 8.40 ~8.0 1448,00 2,73 0,49 348,63 94,7 1542,46 3,50 0,46 6,83 71,8 1634,4~ 4,16 0.3~ 3~.~6 Y2.9 1727.36 4.4~ 0,03 166,43 24,7 I752,11 4,41 0,06 141,~3 82,8 I~34,?Z 4,40 0,08 71,92 91,3 1926,25 4,44 0,22 &1,81 ?5,0 20Z1,26 4,56 O.6d 63,52 90,6 . ~llI,8a 4,68 0,12 73,2! 93,1 2204,98 4,73 0,20 85,28 ?6,4 2301,39 4,81 0,17 61.02 76,4 2398,02 4,91 0,~4 73,25 87,9 ~485,97 4,99 0,20 73,{6 90,3 2576,26 ~,OZ 0,18 94,75 93,3 2669,~3 ~,11 0,24 ~0,36 73,~ 2743,41 5,26 0,~2 72,42 ~3,2 2856,58 5.45 0,34 40.79 73,1 2949.70 ~.66 0,43 76,94 94,4 3044,11 5,82 0,45 74,1~ 489,g 3532,32 4.1~ 0.57. 92.59 . 487.2 401V,47 6,9~ 0,44 70,94 465,Z 4484.43 6,67 0,59 68.64 448,7 4953,32 9,49 0,43 71,76 457.1 5410,40 9,06 0,Z5 111.77 £/'W f: ft 0,00 O,OO 0,00 -o,Z2 0,~2 -0.25 0,]4 280,12 0.00 0,12 178,64 0,42 0,49 121,03 d~/ lO~f~ 0.00 0.08 0,34 0,1S 0;27 -0,24 1.11 1,13 10~,02 0,05 -0,24 1.83 1,65 97,32 0.10 -0,17 2,6z 2,61 ?3.78 0,1~ -0.14 3,73 3,73 72,14 0,55 -0,30 4,80 4,81 93,54 0,41 -0,37 "0,36 '0,10 0,60 1,37 5.34 5,38 93,f6 0,47 · 6,04 6,05 Y3,38 O,2e 6,92 6,9R Y0,81 0,31 7.5~ 7.60 ~5,51 0,34 7,87 8,00 80,15 0,17 6,01 8,46 71,18 0,20 7,97 8,7! 46,2~ 0,16 8,01 9,0Z 6g,58 0,12 ~,ol ~.15 al.o7 o.42 6,02 ~,15 61,18 0,11 8.10 ?,ZZ 61,51 0,10 8,24 9,45 41,95 0,16 8,7I 9.83 6Z,3~ 0,09 8,9~ 10,14 42,48 0,15 Z,06 3,50: 4,16i 4,431 4,40! 4,44i 4,541 4,681 4,73~ 9~25 lO,3? 42,94 4.81~ ?,54 10,69 43,24 4,711 9,7~' 10,95 63,34. 4,??: 10,03 11,20 6~,57 5,02i 10.33 11,48 64,07 5.11' 10.64 11,{0 64.37 5,26i 10.~? IZ,lS 64.43 5,4~ 11.41 12.64 ~4.4~ 5,6~ 11,97 13.24 44,74 5.8~ 12.49 13,74 65.37 0,I5 0,14 0,00 4.1~ 14.97 I~,04 70,04 0,04 6.95 21.98 23,06 72,46 0.05 8,67 26,d~ ZS,0~ 71.00 0.01 9.4{ 30.68 32,11 72.&0 0.05 ?.0~ 33.30 34.51 74.75 0.05 ~£~$UR£D INTERVAL VERTICAL TARGET STATION ~ZIRUTH DEPTH DEPTH S£CTION INCLH, N/-~ ft ft ft ft de~ de9 Yt 5885,~3 475,0 5&65.3d 10.30 0.44 27,~2 10,30 6364,23 47&,7 63&4,04 14,0Z 0,52 5,08 14,07 ~833.&7 46~,4 68.33.47 17.28 0.32 34.04 17.28 7269,01 4S5.3 7288,79 l?.d8 0,50 47.35 . 754Z.51 Z~,~ 754Z,Z? 21.17 O,5& S3.31 21,17 PROJ;CT£D SURVEY TO TD 7~30.00 87.5 7&27,77 lCJC3~;- 0~5-18 18:0~5 DSPARTUR~ DISPCAC£fl~NT at ~ZIflUTH ~LS £/-W ft ft deq lOOft 35,09 3~.5~ 73.&S O.lO 36~13 S~,77 66.71 0.04 37,22 43.B6 43,35 0.04 41,GU 44,17 62,71 0,03 41.71 47.01 62,54 0.00 ~113 P. 0S/0S TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Pomupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: May 10, 1996 Transmitted herwith is the followinq data: REPORTS: Alpine 3 "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories Bergschrund 2A "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories o I)-'7 ,J~aanuk 1 "BASIC ROCK PROPERTIES" - Final Report as Displayed by Corn Laboratories Temptation 1 "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: MAY' 1 3 1996 /Uaska Oil & Gas Cons. Commission Approved for transmittal by: F. M. Hon~'y,~u{t Manager, North Alaska E~/~ration TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: May 2, 1996 Transmitted herwith is the followinq data: DIGITAL DATA Displayed by Schlumberger: Nanuk 1 6" 'Open Reel Tape-LDWG Format-"Open Hole Edit" MWD CDPJCDN & Wireline DSI/LDT/CNTG with paper file listing 10" Open Reel Tape-LDWG Format-"Open Hole" RFT FIELD AQUIRED DATA with paper file listing 3.5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) REPORTS: Nanuk I Wireline Tops as Displayed by ARCO If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: A~roved for transmi~al by: Manager, No~h Alaska ~loration TO: AOGCC Attn.- Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.- Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: May 2, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: 1 Sepia Copy Displayed by EPOCH: Temptation 1 Formation Log 2" = 100' (107' to 77750') Temptation lA Formation Log 2"= 100' (1816' to 8950') 1 Blueline Copy Displayed by EPOCH: Temptation 1 Formation Log 2" = 100' (107' to 77750') Temptation lA Formation Log 2"= 100' (1816' to 8950') 1 Sepia Copy Displayed by Schlumberger: Nanuk 1 CDN FINAL PRINT CDR FINAL PRINT COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHOLOGY DENSITY DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S 19-MARCH-1996 I Blueline Copy Displayed by Schlumbercjer: Nanuk 1 CDN FINAL PRINT CDR FINAL PRINT COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHOLOGY DENSITY DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S 19-MARCH-1996 WELL SUMMARY Well Name: APl #: Location: Rig: Elevation: ARCO Nanuk #1 50-103-20238-00 ASP: x=379,116 y=5,957,741 zone:4 S/T/R: 2627' FSL, 868' FWL, sec 19, T11 N, R5E Doyon 141 G.L. = 9.6' K.B. = 38' Geological Tops: Base Permafrost Top West Sak Top Shale Wall Top Albian Top Albian B Top Albian C HRZ K-1 LCU Top Jurassic Nuiqsut Total Depth (driller) MD SS 759' -721' 1010' -972' 2392' -2354' 4O45' -4007' 5245' -52O7' 5830' -5792' 6682' -6644' 6900' -6862' 698O' -6942' 7210' -7172' 7494' -7456' 7630' -7592' Conventional Cores: none 0il& Gas Cons. Commission ~.chorage ORIGINAL NANUK #1 ACTUAL PLUG AND ABANDON DIAGRAM 16" CONDUCTOR AT 107' RKB CASING CUTOFF 3' BELOW GROUND LEVEL WELL IDENTIFICATION PLATE WELDED TO CASING STUB SURFACE CEMENT PLUG 30'-250' BRIDGE PLUG AT 250' 12-1/4" HOLE ESTIMATED TOP OF PLUG #4 @ 1615' CEMENT RETAINER AT 1715' BASE OF PLUG #4 @ 1900' TAGGED TOP OF PLUG #3 @ 3285' BASE OF PLUG #3 @ 4150' 8-1/2" HOLE ESTIMATED TOP OF PLUG #2 @ 5735' BASE OF PLUG #2 @ 6789' TOP OF PLUG #1 @ 6789' BASE OF PLUG #1 @ TD i10.2 LB/GAL MUD ': ::2 :.'..': :.'..': :.'..:. :.'..': :.'.:: :.'..': ::2 -'.'..'.' ".'..': :.'..': ': :.'..'.' :.:.': :.'..". :.'..': :.'..': ".'..'.' -':.:: :.'..': ".'.-': :.'.:: ::2 ': :.'.:: :.:.': :.'..': :.'..': ::2 ::..'.' ::2 :.:.'.' :.'.-': :.::: :.:.';: ': "-'..': "-;.': :.'.-': :.'..': :.'..': :.'..': :.'..': :.'..': :.'..'.' :;2 :.'..':: 2O BBL HI VIS 110.2 LB/GAL MUD 9-5/8" SURFACE CSG AT 1792' RKB NOTE: 10.2 PPG KILL WEIGHT MUD PLACED BETWEEN ALL PLUGS 3800'-4100' HYDROCARBON BEARING ZONE- K2 ,': ::2 :.'.-': ::2 :.'..': ::2 :.'..': :.'.:: ::2 :.l.'.' :.':': :22 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::: .': :.'..'.' :.'..': :.'..': :;2 :.'..': :;2 :.'..': :.'..': :.'..': :.'.-'; :.;.': ': :.'..". :.'..': :.'.-': :;2 :.'..': :.'.;: :.'.-': :.i.'.' ".'..': :.'.-': :;2 ': :.'..': :.:.': :.'..': :.'..': :-'..': :-'..': :.'..'.' :.'..'.' ::2 ::2 :.'2 ".".'..'::2..':".'..':::..':".'2:2.2::2..'::2..'::2..'::2.:::2..': · : :....': :.'..': :....': :....': '....:: :..:'.. :....': :....'.. :....': :.:;: :.'..:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.:," .'. :,?:' .: :," .'. :,' ~'. :,' .: :,' .'.:".'.:'.'.:' .::'.'.l :::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.::'.".::'.".::'.".::':'.::'.".::'.".::'.".:::':::'.':::'.".::'.".:! 7 2 0 0- 7 3 5 0' BEAR I N G ZON E, J-4 (:::'":::'"::'"::":'::::'::::':::"2:"'"::"':::'":::'"::t TD AT 7630' MD HYDROCARBON 61 45'-6300' BEARING ZONE - ALBIAN '.,/.,..//I. : :....'.. :....': :....': ::: I.'..':L~.': .'.~ ARCTIC-SET CEMENTS CLASS G CEMENT WITH ADDITIVES FJ 4/13/96 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) FILE INFORMATION: Operator: Arco Alaska Inc Address: P.O. Box 100360 Anchorage Alaska 99510 Surface Location: 2627 F S L, 869 F W L Section 19 ,T 11N ,R 5E ,M Well Name: Nanuk #1 PTD No.: 96-57 APl No. 50- 103-20237 Unit or Lease Name: N/A Field and Pool: WildCat Downhole P&A Date: Inspection Date: I 20 AAC 25.125 - ABANDONMENT MARKER: I Approval Date: Steel Post OD: (4" min) "Length (10' min.) ft. Height Above Final Grade Level (4' min.) Top of Marker Post Closed With: (Welded, Cmt., Cap), Set: (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? All openings closed ? With Marker Plate Diameter: 20 Marker Plate Attached To: Wellhead "Thickness: 3/4 "Distance Below Final Grade Level: Cutoff Csg ,k' Other 5 ft. Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Arco Alaska Inc Unit / Lease Name: Well Name: NANUK #1 Remarks: ADL 384211 Surface Location: 2627 F s L, 869 F w L Section 19 ,T 11N ,R 5E ,M U Inspection Date: 20 AAC 25.170 - LOCATION CLEANUP: PITS: Filled In: N/A Liners Removed or Buried: SURFACE CONDITION OF PAD AND / OR LOCATION: ( Note when different from file information) Clean: Y Approval Date: N/A Debris Removed: OK* ICE ( Rough, Smooth, Contoured, Flat, Compacted ) Type &Quan. of Debris if any remaining on pad and / or location: TYPE AND CONDITION OF SURROUNDING AREA: TUNDRA ( Wooded,Tundra, Grass, Brush, Dirt,Gravel,Sand) Clean: Type &Quan. of Debris if any remaining on surrounding area: TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: ICE ( Dirt, Gravel, Ice, Other) Clean: Type &Quan. of Debris if any remaining on access road or surrounding area: CLEANUP WORK REMAINING TO BE DONE: Return in summer for final cleanup RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes No X ( If"No" See Reason ) Distribution: orig - Well file c- Operator c- Database c- Inspector Reason: Return after breakup for final cleanup and location clearence inspection. FINAL INSPECTION: INSPECTED BY: Yes No Louis R Grimaldi DATE: 4/1/96 FI-000 (Rev. 3/93) Y99JDBDD.XLS MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Jo~n,~ Chairman Blair Wondze11~¢~¢ P, I. Supervisor FROM: Lou Grimaldi~ ~ SUBJECT: Petroleum Inspector DATE: March 28, 1996 FILE NO: Y99JDADD.DOC Surface Cement plug Arco Nanuk #1 Exploratory PTD 96-0057 Thursday, March 28, 1996: I traveled to Arco's exploratory well Nanuk #1 to witness the surface abandonment of this well. The wellhead and casing were cut off to a depth of five feet below the original tundra level. The space inside the 9 5/8 casing was filled with a substance that appeared to be clabbered mud. The 9 5/8 by 13 3/8 annulus had no cement or mud evident at surface. I discussed this situation with Bill Penrose (Drilling foreman) who will wash out the 9 5/8 casing and fill both the 9 5/8 casing and 9 5/8 X 13 3/8 annulus. I plan to return to this well for observation of these operations. Monday, April 1, 1996: I returned this morning to check on the repairs made to this wells surface plug. The mud in the 9 518 casing had been washed out to a depth of 10 feet where hard cement was found. A batch of portland cement was mixed and the 9 5/8 and 9 5/8 X 13 3/8 annulus were filled to the top with it. I found a solid top plug when I arrived. The surface plate was welded on in my presence. The glow hole will be filled in and a final location inspection will be performed after the ice pad melts away. SUMMARY: I inspected the surface plug and attachment of the marker plate on Arco's exploratory Nanuk #1 Attachments: Y99JDBDD.XLS Photographs attachments: Mike Zanghi (Arco drilling engineer) ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: March 27, 1996 Transmitted herwith is the foilowinq data: Enclosed is the following data: LOGS: 1 Sepia Copy Displayed %~00~ Alpine 3 Formation Log qp-~,t.~ Bergschrund 2 Formation Log q~- t77'9 Nanuk 1 Formation Log q3-._~,~-Neve 1 Formation Log by EPOCH: 2" = 100' (108' to 7649') 2" = 100' (107' to 8600') 2" = 100' (110' to 7630') 2" = 100' (108' to 7700') Blueline Copy Displayed by EPOCH: Alpine 3 Formation Log Bergschrund 2 Formation Log Nanuk 1 Formation Log .~.._ Neve 1 Formation Log 2" = 100' (108' to 7649') 2" = 100' (107' to 8600') 2" = 100' (110' to 7630') 2" = 100' (108' to 7700') 1 Sepia Copy Displayed by Schlumberger: 0~.~t(~ Bergschrund 2 ~-CDN FINAL PRINT [~T~RUE VERTICAL DEPTH CDN FINAL PRINT CC/DR FINAL PRINT ~--'I~RUE VERTICAL DEPTH CDR FINAL PRINT (~I~IPOLE SONIC IMAGER- P & $ AND UPPER DIPOLE - 21-FEBRUARY-1996 · (~T~RUE VERTICAL DEPTH DIPOLE SONIC FINAL PRINT RECEIVED t AR 2 9 996' Ala~a ~ & Gas Cons. Commission Anchorage TO: AOGCC Attn.: Mr. Robert P Crandail 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: March 27, 1996 Transmitted herwith is the followinq data: 1 Blueline Copy Displayed by Schlumberger: qC-',,.t 9 Bergschrund 2 ~CDN FINAL PRINT ~'~RUE VERTICAL DEPTH CDN FINAL PRINT ~DR FINAL PRINT --'TRUE VERTICAL DEPTH CDR FINAL PRINT 'I~IPOLE SONIC IMAGER - P & S AND UPPER DIPOLE - 21-FEBRUARY-1996 ,-.-TRUE VERTICAL DEPTH DIPOLE SONIC FINAL PRINT DIGITAL DATA: ~ ~ Bergschrund 2 ,../1 6" Open Reel Tape-LDWG Format-"Open Hole Edit" CDR CDN DSi 1~3h paper listing copy .5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: RECEIVED MAR 2 9 ~996' Ap, p,p~ro~ved for transmittal by: - - F. M~.. I-yoneycutt '" Manager, North AI~ Exploration ], ~a ~, 25, 1996 4' 22PM ~A~,CO ALASKA iNC ARCO Alaska, lin.. Post Office Bo~ 100360 Anchorage, Alaska 99!510-0360 Telephone 90T 276 1215 March 25, 1996 No. 8466 ?. 2/5 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re; Weekly Operations Report ARCO Temptation #1 Pmmit No. 96-006 ARCO Bergschrund #2A Permit No. 96-033 ARCO Nanuk #1 Permk No. 96-057 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Temptation Bergschrund #2A Sidetrack and Nanuk #I wells being drilled in the Colville delta area. The Nanuk gl was drilled to 7630' TD, logged and P&A. The Doyon rig was then moved back to the Bergschrund ice pad. The Bergschrund #2A is drilling out cement in the surface casing. The Temptation well is drilling surface hole at 1200'. If you have questions or require additional information, please contact Fred lohnson at 265-1492. Sincerely, Fred Johnson Drilling Engineer AR3B-6003 93 R£CEIV£D MAR 2 6 1996 Alaska 0il & (It~ Con~. commission Anchorage 242-261X~ ARCO ALASKA Date: 3/25/96 ARCO ALASKA INCORPOBATED WELL SUMFIA/{Y REPORT Page' 1 WELL: NANUK $1 RIG:NO WELL ID: AX9343 AFC' AX9343 STATE: ~ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD; WILDCAT SPUD' START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20237-00 03/Z8/96 (8) TD: 6796'( $UPV:WJP 1941) MW: 10,2 PV/YP: 21/20 APIWL: 6.3 CIRC(PREP FOR CLEANOUT TRIP TO SHOE) Drill 8.5" hole from 4855' %o 67961 03/19/96 (9) TD: 7630'( SUPV:WJ? 834) MW: 10.2 PV/YP: 20/13 APIWL: 4.0 CONDITIONING HOLE FOR LOGS P0H to surface casing shoe. Hole tight 6216' to 5480'. Drill 8.5" hole 6796' to 7630'. Trip out to 6600'. Slight overpull at 7307', no swabbing, good fill-up, RIH to TD. Hole in good condition. C&C hole for logs. 03/20/96 (10) TD: 7630'( SUPV:DCL 0) MW: 10.2 PV/YP: 25/19 APIWL; 4.4 WIPER TRIP POH. Monitor well at shoe, No problems. Run DSI/CNT-G/LDT/ GR from WL TD 7628' to shoe at 1792'. 03/21/96 (11) TO: 7630'( SUPV:DCL 0) MW: 10,2 PV/YP: 16/12 AP/WL: 4.6 SCHLUMBERGER MSCT RIH TO 7575', Wash and ream to 7630', Monitor well. Run AMS-GR-RFT. Took pressure readings. Took samples. POH. RIH w/MSCT. Cut 12 cores, 03/22/96 (12) TD: 7630' ( $UPV: DCL 0) MW: 10.2 PV/YP: 16/12 APIWL: 4.6 PREP FOR PLUG ~3 Continue to cut cores. Pu/~p cement. 03/23/96 (13) TD: 7630'( SUPV:DCL 0) MW: PV/YP: APIWL: ND BOPE Spot 20 bbls hi-vis pill. Pump cement. POOH, WOC. Tag cement at 3285'. RIH w/EZSV and set at !715'. Pump cement. Test casing to 500 psi. RIB with bridge plug and set at 250'. Pump cement. ND BOPR. 03/24/96 (14) TD: 7630 ' ( SUPV: DCL 0) MW: PV/YP- AP/WL: RIG RELEASED ND BOPE. Prep for move. Release rig @ 1500 hrs. 3/11/96. End of WellSummary for Well:AX9343 R£CEIV D M.~R 2 6 199G Alaska Oil & Ga~ ¢on~. commigsion ARCO Alaska, Ir Post Office oox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 t215 TRANSMITTAL TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Robert Crandall SAMPLES SENT: 80- 2720' 272O-5420' 5420-6860' 6860- 7630' DATE: March 22, 1996 AIRBILL: AIRLAND646128 CHARGE CODE: AX9343 AFT#: ABV-06-03-22-03 WELL NAME: Nanuk #1 SAMPLE TYPE: Dry cuttings SENT' BY: Angela T. Langston UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: Arco Alaska, Inc. 619 E. Ship Creek Ave Suite 104 Anchorage, AK. 99510 Attn: Dan Przywojski r' AR 2 ~Jaska Oi! & Gas Cons. Comr~ission Anchorage AR3B-6003-93 242-2603 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 22, 1996 THRU: Blair Wondzell, P. I. Supervisor FROM: John Spaulding,'¢'-~ J, k,', SUBJECT: Petroleum Insp. FILE NO: n9wlcvdd.doc Open Hole Cement Plug ARCO Nanuk 1 Exploration PTD 96-57 Friday March 22, '!996: I traveled this date to ARCO's Nanuk 1 exploration well to witness an open hole cement plug in the plug and abandon program.' The AOGCC plug and abandon report is attached for reference. The open hole plug was set across the hydrocarbon 'bearing zone located at 3800' md to 4100' md. The balanced cement plug extended from 4150', 50~ below the zone to 3285' md, 550 above the zone. Drill string weight of 15,00 lbs. was set down on the cement to establish depth and integrity. Summary: I witnessed the successful tag of the open hole cement plug at ARCO's Nanuk 1 well. Attachments: n9wlcvdd.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERI/ATION COMMISSION Plug And Abandonment Report Operator: ARCO Well Name: Operator Rep.: D. Luttrick PTD No.: 96-57 Lease No.: Well No.: 1 Sec. T-R S19, T11N, R5E Total Depth: 7630 Elevation: Date: NANUK#1 3/22/96 Meridian: UMIAT Mud Wt.: ppg. CASING DATA: Drive Pipe: N/A O.D." Set 6: ft. With Penetration Conductor: 16 O.D." Set 6: 107 ft. Surface: 9 5/8 O.D." Set 6: Intermediate: N/A O.D." Set 6: ft. Prodctn: O.D." Set 6: 1792 ft. ft. PLUGGING DATA: 1. Open Hole Plugs: across hydrocarbon bearing zone @ 3800' - 4100'; balance cement plug from 4150' to 3285'; witnessed tag with 15K of weight at 3285' 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: REMARKS: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet Distribution: odg - Well File c- Operator c- DNR/DOG c- Database c - Rpt File c- Inspector Inspector (s): John H. Spaulding FI-000 (Rev. 3/93) N9WLCVDD.XLS F.'O2FM ARcO ALASKA ARCO Alaska, Inc. iii FACSIMILE TEA .NSMISSION ! Iate: ~ ~ Time: umber of Pages (Cover +): __ From: Phone: Location: i Location: ~Copies To: i FAX #: Phone #: II I II II I II i iq · II BI I IIIIIlIII II~lIlIII [ II I II II I i II ! II II I lIIIlIIII ~ IIIIII k~MIlllll i II I Il 11 II ~ II I Il II II [ II · II II II , Iml · II II II , II · II II II ii ii !! ,,'"' II II la Il ii I1 II I Il II II ii II II I II II II Il II II I Ii II II II II II I II II Il ii Ii Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATO-1209 .[ ! i _ i Comments: Mar. 20, 1996 2:03PM AR_CO ALASKA iNC ARCO Ala$~ka, inc.' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 No. 8~7 P, 2/6 March 19, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950'[-3192 Re: Sundry Notice to Plug and Abandon ARCO Nanuk #l Permit No. 96-57 Dear Commissioner Johnston, The ARCO Nanuk #1 well has been drilled to 7630' MD and plans are being made to plug and abandon. ARCO Alaska, Inc. hereby applies for sundry approval with a variance to plug and abandon the ARCO Nanuk #1, permit number 96-57. A detailed plug and abandonment procedure is enclosed. ARCO requests a variance to the requkements of 20 AAC 25.105 (1) for the cement plug #1 (6950'-7630') placed as shown at total depth on the attached diagram. ARCO proposes to place plug #1 in the well per 20 AAC 25.105 (fl) using caliper hole volumes plus 25 % excess cement volume without recording the actual location or integrity. Plug #I at total depth will be placed on the bottom of the hole which will prevent any chance of the cement falling downhole. High viscosity mud will be placed below plug ~f2 and #3 to prevent the cement from falling downbole. ARCO also requests a variance to the requirements of 20 AAC 25.120 Well Abandonment Marker. Rather than place an above ground marker over the wellbore, ARCO proposes to weld a cover plate to the casing stub 3' below ground level with the information required in 20 AAC 25.120 (b) bead welded to the top. The location will then be backfilled with gravel. If you have questions or require additional information, please contact Fred Johnson at 265-1492 in our Anchorage office. Sincerely, Drilling Engineer KRU Ddllsite Development Mar. 20. 1996 2'03PM AR~O ALAS}EA iNC t~o. 55~'/ F. ~/b 4~ STATE OF ALASKA AIJ~FA OIL AND GAS GONSERVATION OOMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ..~ Suspend Alter casing _ Repair well _ Change approved program_ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension Stimulate Puli tubing _ Vadance _ ~'erforate _ --Other 2. Name of Operator _,ARCO Alaska. I_ng_. 3. Address BOX 100360, Anchorage, AK 99510 5. Type of Well: Development E×plora~ory Stratigraphic Service 4. Location of well at surface 2~27' FSL, 869' FWL, Sec. 19, T11N, RSE, UM At top of productive interval Same At effective depth At totsl depth Same ORIGINAL 6. Datum elevation (DF or KB) RKB 38; Above SL 7, Unit or Property name N/A feet 8, Well number . Nanuk 4/1 9. Permit number 96-~7 10, APl number 5o-1 O3-2_0237 11. Field/Pool Wildcat 12, 13, Present weft condition summary Total Depth: measured true vertical Effective depth: measured true vel{ica[ Casing Length Structural Conductor 80 ' Surface 1767' Intermediate Production Liner Perfora, don del)th: measured: None 7630' 7630' 16" 9-5/8" true vertical: None Tubing (size, grade, and measured depth: None Packers and $S$V (type and measured depth): None Attachments P&A Wellbore feet feet feet Cemented 300 Sx AS 1 325 Sx AS III & 610 Sx AS I Measured depth True vertical depth 107' 107' 1792' 1792' RECEIVED Descriplion summary of proposal _ MAR 2 0 1996 Alaska 0il & Gas Cons. Commission Anchorage Detailed operation program ._~ BOP sketch 14, Estimated date for commencing operation 15. Status o! well cras$i[ic~don as; March 81, 1.99.6 Oil Gas 16. If proposal was verbaily approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signe~....-~,4.~~ J~,,C./'~'~z~(-Tq' Title DH,I Site Development SuR.erviso_r ¢ FOR COMMISSION USE ONLY Conditions of apl~roval: Notify Commission so representative may witness ,Suspended I_lAppr°vai No~_ ~ Plug integrity ~ Mechanical Integrity Test BOP Test ..A. pproved by the order of the Commission _ Location clearance ~ Subsequent form require 10- ~Of~r°Ved Copy Original Signed By ~,~e/~ Oavid W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1996 2'03PM ARCO ALASKA TNC NANUK #1 PROPOSED PLUG AND ABANDON DIAGRAM No. 8337 P. 4/6 CONDUCTOR AT 107' RKB 3000 PSI WELLHEAD EQUIPMENT SURFACE CEMENT PLUG 30'-250' BRIDGE PLUG AT 260' 12-1/4" HOLE TOP OF PLUG #4 @ 1600' BASE OF PLUG #4 @ 1900' TOP OF PLUG #$ @ 3600' BASE OF PLUG #3 @ 4150' 8-1/2" HOLE TOP OF PLUG #2 @ $945' BASE OF PLUG #2 @ 6350' TOP OF PLUG #1 @ 6950' BASE OF PLUG #1 @ TD i10.2 LB/GAL MUD 20 BBL HI VIS -10,2 LB/GAL MUD J CEMENT RETAINER AT 1700' 9-5/8" SURFACE CSG AT 1792' RKB NOTE: 10.2 PPG KILL WEIGHT MUD PLACED BETWEEN ALL PLUGS 3800'-4100' HYDROCARBON BEARING ZONE- K2. RECEIVED MAR 2 0 1996 ~aeka Oil & 6as Cons. 6ommissiorl Anchorage HYDROCARBON 6145'-6300' BEARING ZONE - ALBIAN "- HYDR~~N 72oo-735o' BEARING ZONE, J-4 TD AT 7630' MD ARCTIC-SET CEMENTS CLASS G CEMENT WITH ADDITIVES FJ 3/20/96 20. !996 2'03PM ARCO ALAS A INC No. 8337 P. 5/6 NANUK #1 PLUG AND ABANDONMENT PROCEDURE Notify AOGCC 24 hrs, prior to beginning any P&A activity (907) 279-1433 3~ 4. RIH with open-ended drill pipe to TD (7630'). Lay a 66,7 bbl (326 sx) balanced cement plug from 6950'-7630'. (estimated top of cement plug with excess is 6781') 2. Pull up ten stands slowly, and circulate out DP. Note: ARCO has requested the AOGCC waive the requirement per 20 AAC 25.105 (1) to test this plugs location and integrity. Rill to ±6600'. Spot a 20 bbl hi-vis pill from 6350'-6600'. sx) balanced cement plug from 5945'-6350'. is 5740') 5. Pull up 10 stands slowly, and circulate out DP. . Pull up to 6350' and lay a 48.1 bbl (235 (estimated top of cement plug with excess . ~3' 8. POOH. Pickup muleshoe. RIH and tag cement plug with 15,000 lb. Document plug location and integrity for AOGCC. Notify AOGCC in advance for opportunity to witness. POOH tO __+4400'. Spot a 20 bbl hi-vis pill from 4150'-4400'. sx) balanced cement plug from 3600'-4150'. is 3326') 9. Pull up 10 stands slowly, and circulate out DP. 10. 12. 13. 14. 15. 16. Pull up to 4150' and lay a 64.8 bbl (316 (estimated top of cement plug with excess 17. POOH. Pickup muleshoe. RIH and tag cement plug with 15,000 lb. Document plug location and integrity for AOGCC. Notify AOGCC in advance for opportunity to witness, RIH with 9-5/8" Halliburton EZSV cement retainer on drillpipe. Set cement retainer at ±'1700' (AOGCC regs require retainer to be set 50'-100' above the shoe). Weight test the retainer with 15,000 lb. Sting into the cement retainer. Hold 500 psi backup pressure on annulus. Establish injection rate. Mix and pump ___30.8 bbl cement (150 sx 15.8 lb/gal Class G). Displace 23.8 bbl cement thru the retainer and dump 7 bbl cement on top of the retainer. Minimum height for cement plug on top of retainer is 50'. Puli 5 stands. Pressure test cement plug and retainer to 500 psi for 10 minutes. Record pressure on a chart and submit to AOGCC. PON, laying down all but 250' of drill pipe. RIH with 9-5/8" bridge plug and set at 250'. Weight test by slacking off all drill pipe weight on it, Place 15.6 bbl (95 sx) of Arctic Set ] cement on top of the bridge plug. With drill pipe at 33', reverse out excess cement Note: top of the surface cement plug is required to be at surface (casing cutoff point) POOH. R E C E IV E D MAR 2 0 1996 ~Jaska Oil & Gas Cons. Commission Anchorage Mar. /.U. 199~ /,'U4FM ARCO ALASKA iftC 18, N/D BOP stack. 19. Rig d(~wr~ and begin final rig demob, 20. Cut all casing strings off at or below 3' below ground level. Remove cellar, Back fill cellar with gravel as needed. Send casing head with stub to Materials for re pal r/red rossi ng. 21. 22, Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC NANUK #1 ADI. 384211 APl# 50-103-20237 2627' FSL, 869' FWL, S19-T11N-R5E,UM Note: ARCO has requested the AOGCC waive the requirement for an above ground P&A mart~er per 20 AAG 25.120. Back fill remaining hole to ground level with gravel. Clean up location. Prepared by: D illing ~ngineer Approved by: KRU DS Development Supervisor ~.. ARCO Alask~ Post Oft, Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Weekly Ope~fions Report ARCO Neve #1 Pen:nit No. 95-215 ARCO Nanuk #1 Permit No. 96-57 Dear Commissioner J'ohnston, Attached is the weekly operations summary for the ARCO Nanuk #1 and Neve #1 wells being drilled in the Colville delta Tea. The Nanuk #1 was spudded on Match 12 and is presently drilling at 6800'. The Neve #1 well was completed with tubing and packer ia preparation of well testing operations. The Pool d~Iing rig is now being moved to the Temptation well location. Lf you have questions or requi~e additional information, please contact Fred Johnson at 265-1492. Sincerely, Fred Johnson Drilling Engineer RECEIVED MAP, 1 9 1996 Alaska Oil & Gas Cons. commission Anchorage A~138-6003-93 242 [693 !8. !996 3' 36PM ~AR. C0 ALASKA iNC No. 8267 P, 4/4 Date: 3/18/96 ARCO3klASF-A INCORPO1RAT~ED W~LL SUMMARY R~PORT Page' 1 WELL:NANUK %1 RIG;NORIG WELL ID' AX9343 AFC: AX9343 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPI/D: START COMP; BLOCK: FINAL: TIGHT HOLE Ami NUMBER: 50-103-20237-00 03/11/96 (1) TD' ' ( 0) $UPV: DCL PV/YP: APIWL: N/U DIVERTER Move rig £romAlpine #3. Assemble modules. Start NU diverter. 03/12/96 (2) TD: 270'( SUPV:DCL 03/13/96 (3) TD' 1653'( SUPV:Wo-P 163) 1383) MW: 10 PV/YP: 66/48 APIWL: 10,8 REPLACE MWD Function test diverter. Held pre-spud safety meeting, Spud 0000 3/12/96. Drill from 107' to 270'. MWD failure. MW: 10 PV/YP: 14/22 APIWL' 10.8 DRiLLING 12.25" HOLE Drill 12.25" hole 270' to 1653'. 03/14/96 (4) TD; 1800'( SUPV:WJP 03/15/96 (5) TD: 1800 ' ( SUPV; WJP 03/16/96 (6) TD: 2884'( $UPV:WJP 147) 0) 1084) ~: 10 PV/YP: 16/20 APIWL: 5,6 N/D DIVERTER Drill 1653' to 1800' Run 9-5/8" casing to 1788', Cement casing. CIP @ 6010 b_rs, Floats did not hold. Extend top job line to 107'. Pump top job. MW: I0 PV/YP: 17/9 APIWL: 8.4 DRILLING CEMENT Safety stand down, N/U BOPR. Test BOPE to 250/3000 psi. RIH w/HWDP. Drill soft cement to 1650'. MW: 10.4 PV/YP: 14/9 A~IWL: 6.8 DRILLING 8.5" HOLE Drill soft cement 1650' to 1658', hard cement 1658' to 1674', Pressure test 9-5/8" casing to 2500 psi for 30 minutes, OK. Drill cement 1674' to float collar at 1701', Drill 10' of new hole to 1810', Conduct LOT. Drill 8.5" hole 1810' to 2884'. 03/17/96 (7) TD: 4855'( SUPV:WJP 03/18/96 (8) TD' 6796' ( SUPV: WJP 1971) 1941) MW: 10,3 PV/YP: 14/10 APIWL: 6,0 DRILLING 8.5" HOLE Drill hole from 2884' to 4855', MW: 10.2 PV/YP: 21/20 APiWL: 6.3 CIRC(PREP FOR CLEANOUT TRIP TO SHOE) Drill 8,5" hole from 4855' to 6796'. End of WellSummar~ for Well:AX9343 RECEIVED MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh_.~n, DATE: Chairma~.~..- ~ March 14, 1996 THRU: FILE NO: Blair Wondzell, .~~ P. !. Supervisor_ . 7~ FROM: Bobby Foster,? ?~' SUBJECT: Petroleum Inspector A9WlCNDD.doc BOPE Test - Doyon 141 ARCO - Explor. - Nanuk # 1 PTD # 96-O057 Colville River Thursday, March 14, 1996: ! traveled this date to ARCO's exploratory well Nanuk # 1 being drilled by Doyon rig 141 and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows the test went very good and there were no failures of any equipment tested. The dg was clean and ali equipment seemed to be in good working order. The ice pad location was clean with good access to all areas of the dg and all extra supplies and equipment was stored properly. Summary: ! witnessed the initial BOPE test on Doyon 141 ddlling ARCO's exploratory well Nanuk # 1 - test time 3 hours - no failures. Attachment: A9WICNDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover. , , , Drlg Contractor: DOYEN Rig No. Operator: ARCO " ' Well Name: NANUK #1 Casing Size: 9.62~" Set @ 1760' Test: Initial X Weekly Other DATE: 3/14/96 141 PTD# 96-0057 Rig Ph.# 263-3122 Rep.: BILL PENROSE Rig Rep.: MORT ,; Location: Sec. 19 T. 11N R. 5E Meridian Um, .. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: '0~ (Gan) PTD On Location YES' Standing Order Posted "YES BOP STACK: Quan, Annular Preventer 1 Pipe Rams '· ;J , Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1' · , , HCR Valves 2 , , Kill Line Valves 1 Check Valve N / A' .. Well Sign OK Drl. Rig OK Hazard Sec. YES , Test Pressure 300/3,000 300/3,000 300/3,000 300/3,000 300/3,000 ,30,,o ,,ooo 300/3,000 P/F P p,., "p P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES ~ES Flow Indicator ' YES' 'YES Math Gas Detector 'YES '~ES H2S Gas Detector YES 'YEs FLOOR SAFETY VALVES: Ouan. Pressure P/F Lower Kelly / IBOP 1 300/3,000 P Ball Type 1 3,00,/3,000. ,- F~' ' Inside BOP ,1 .300/,,3,,,000,, ,P Test CHOKE MANIFOLD: Pressure P/F Ne. Valves 14. I 300/3,000 I P Ne. Flanges ~6I 300/3,000 [, .p. Manual Chokes Functioned P Hydraulic Chokes , 1' ~i Functioned 'P , ACCUMULATOR SYSTEM: System Pressure 3,050 ~ P Pressure After Closure 1,70'0 ....! P 200 psi Attained After Closure 0 minutes 31 sec, System Pressure Attained ' 3''" minutes "25 sec. Blind Switch Covers: Master: YES Remo~e: YES Nitgn, Btl's: 5 (~.2..250 Av~' ' Psig. Number of Failures: 0 ,Test Hrs.:(~Ours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within" , ,0 "daysT. 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: I '279'1433' ~1I I .'111 IT I I. . I I I I II I ]1II I .II.I II I I I II II I I I[II IIII II II REMARKS: GOOD TEST. ,i . Distribution: orig-Welt File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: VV'~nessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AgWICNDD.XLT ~KA OIL AN~D GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ~/hrch 13, t996 Thomas W. McKay, P.E. Senior Drilling ~eer Kuparuk Drill Ske Development ATO 1202 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Requested annular disposal of cement washdowa water from Colvitle Delta exploratory wells Dear Mr. McKaf. The Commission has received your request for'authorization for disposal of cement washdown water from certain Cohille Delta exploratory wells in the annuli of wells currently being dr/lied in the Kupamk River Unit. The washdovm water would be generated by drilling operations at the following exploratory wells during the 1996 season_' Bergschrund #2, Bergschmnd #2A, Alpine #3, Nanuk #1, Neve #1, Neve #IA, and Temptation #1. Disposal would take place into the annuli of wells being drilled by Parker Rig #245, for which annular disposal has already been authorized. We understand that cement washdown water is produced as a result of blending and mixing cement used in drilEng wells. It therefore appears that the cement washdown water you propose for annular disposal is a nonhnzardous waste associated with the act of dr/iling an oil or gas well for exploratory purposes, within the meaning of AS 31.05.030(e)(2). Ordinarily annular disposal is permitted in well armuli located on the same dr/il pad as the well gmerating the waste in question You have explained that the Colville Delta exploratory wells will not have annuli available for disposal operations. The Commission authorizes ARCO Alaska, Inc., to dispose of cemem washdown water from the above-listed Colville Delta exploratory wells in the annuli of wells currerm[y being dh/led within the Kuparuk River unit by Parker Rig #245, subject to the existing tenm and conditions governing annular disposal in the latter wells. This authofizafionis for the 1996 drilling season only. Sincerely, J. David Norton, P.E. Commissioner ~uckennan Babcock Commissioner ARCO Alaska, Inc. Post Office Ko× 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 11, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Sundry Notice for Change in Bottom Hole Location ARCO Nanuk #1 Permit No. 96-57 Dear Commissioner Johnston, Attached is an Application for Sundry Approval to change the bottom hole location for the ARCO Nanuk #1, Permit No. 96-57. The new bottom hole location is 512' north of the original permitted location. A spacing exception for a well in this southwest quarter of Section 19 has been obtained. The bottom hole location shown on the Sundry is slightly different than the location shown on the spacing exception request but is still in the same quarter section. All of the supporting information submitted with the original permit appication remains the same. Estimated spud date for the Nanuk #1 well is later tonight on March 11. ARCO requests that AOGCC review this Application as soon as possible to allow approval prior to spud. Your prompt attention is appreciated. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, Supervisor Kupankk Drillsite Development · , . ,- AR3B-6003-93 242 2603 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 X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service 4. Location of well at surface 2627' FSL, 869' FWL, Sec. 19, T11N, R5E, UM 6. Datum elevation (DF or KB) RKB 37' Above SL 7. Unit or Property name N/A 8. Well number Nanuk #1 feet At top of productive interval Same At effective depth At total depth Same ORIGINAL 9. Permit number 96-57 10. APl number 50-1 03-20238' 1 1. Field/Pool Wildcat ;12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured: None O! Size true vertical: None Tubing (size, grade, and measured depth: None Packers and SSSV (type and measured depth): None feet feet feet feet Cemented Measured depth True vertical depth /vi, ~ V~ 13. Attachments Description summary of proposal_ Detailed operation program _ BOP sketch _ Change Bottom Hole Location 14. Estimated date for commencing operation 15. Status of well classification as: March 11, 1996 Oil __ Gas 16. If proposal was verbally approved O Name of approver ~_;¢'/..,,¢-/,~ ~'/c,/~/~2Z. ~: ~: c Date approved S e rvic e J17. I hereby certify/ that th~ foregoing is true and correct to the best of my knowledge. Signed . .~ ,, Title Drill Site Development Supervisor FOR COMMISSION USE ONLY Conditions of approval: y Commission so representative may witness Suspended Date ~"')~-/ I"~' IApproval N~(,0 Plug integrity __ BOP Test Location clearance I -- o ~l~oved Copy Mechanical Integrity Test _ Subsequent form require 1 --'--Returned Approved by the order of the Commission ~jo g"~t~lN0119[l, Po E. / (¢' .... Commissioner Date ~/..//? (_~ Form 10-403 Rev 06/15/88 SUBMIT I1~ TI~iPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of Work Drill ..X. Redrill __ lb. Type of Well Exploratory X~ Stratigraphic Test _ Development Oil _ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone_ Multiple Zone 2.. Name of C:~erator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, IP(~, KB ht above sea level;40 feet~ Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-384211 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2627' FSL, 869' FWL, Sec. 19, T11N, R5E, UM N/A St~tewid~ At top of productive interval 8. Well number Number 2115' FSL, 842' FWL, Sec 19, T11N, R5E, UM Nanuk #1 #U630~10 At total depth 9. Approximate spud date Amount 2115' FSL, 842' FWL, Sec 19, TllN, R5E, UM 3-10-96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number ot acres in property 15. Proposed depth (MD az~l TVD) property line 842 feet 2.0 Miles 2485 Lease Acres 8r042 MD 8000' TVD feet 16. To be compleled for deviated wells N/A 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 3 00 0 feet Maximum hole an,ie 12° Maximum surface -1'8-7-8 psi~l ~86[1'' At lotaJ deiDth (-I'VD) 3 744 18. Casing program Selling Depth size Specification Top Bottom Qua.ntit~ of cement ~ Hole Casing Wek:jht Grade Couplincj Lenc~th MD TVD MD 'I'VD /include statue data~ 2 0" 16" 62.58# B PEB 8 0' 2 7' 2 7' 110' 110' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1773' 27' 27' 1800' 1800' /:300 sx AS-lily 500sx AS-I 8.5" 7" 26.0# L-80 BTCMoc 7993' 27' 27' 8020' 8020' :1:200 sx Class G ~19. To be completed for Reddfl, Re-entry, and Deepen 013erations. . Present well condition summary i.' ,7 ,~ . ., ..... . :-.' Total depth: measured feet Plugs (measured) ' true vertical feet Effective depth: measured feet Junk (measured i.':,i-L~ '~ ~ :~ ; true vertical feet · . . Casing Length Size Cemented Measured depth True Vertical depth. Structural Conductor .... , -. : ,.--' : Surface ..... ' " ' .... ' ..... "" Intermediate Production - Liner "' '-" ' ' ' ''~ :' '~,~ . '.. ,:~'-:TPJ Perforation depth: measured :':.'.:.'-. ',?:' ...'" .'-.' true vertical - 'i~ .:-;-; ' 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X~ Drilling fluid program X Time vs depth plot X Refraction analysis ~ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that ~1~ loregoir~ is true and correct to the best of my knowledge Si,ned ~J~, ,z~ t.' ~ Titlle KRU Drillsite Development Supervisor Date '" ] ,4/ ~ Commission Use Only Permit Number _ i~-,AEJ,41umber __ I Approval date - ,,-, ,, I See cover letter for ?~--~-7 ! 50-/~::~,..~ - -~-.d::~..~--. ,.~<~2' [ ~ ~- '~''-' ¢~¢:2 J other rec~uirements Conditions of approval Samples required X'Y e s~ N o Mud log required ~ Y e s ~ N o Hydrogen sulfide measures ~ e s X N o, Directional survey required 2~. Yes ~ N o __ 5M; __ 10M; __ 1 5M by order of Approved by Commissioner the commission Date ~ Form 10-401 Rev. 7-24-~~,, ~- "~--- in triplicate MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ DATE: Chairm~ THRU: Blair Wondzeil, ~ FILE NO: P. !. Supervisor FROM: Lou Grimaldi, ~ SUBJECT: Petroleum Inspector March 11, 1996 E9WJCKDD.DOC Diverter Inspection DOYON RIG #141 Arco well Nanuk #1 PTD #96-57 Monday, March .11, 1996: I witnessed the function test of the Diverter system on Doyon rig #141 which was preparing to drill Arco's exploratory well Nanuk #1 in the Colviile Delta area. The 16" straight vent line extended 120' from the well and 105' from the closest point.of the sub-base on rig. The line was not anchored yet as they were still rigging up. The vent line rested on stacked dunnage, I had them chain the line down and stacked four pallets of mud at two points over the chains. The Vent line headed towards the South and gave good down wind protection. The 20" annular preventer functioned properly with a good closure time of 54 seconds. The 16" Knife valve operated quickly and was open well before the annular closed. The accumulator had a adequate recharge time of 3 minutes 15 seconds. The Diverter assembly used by this rig is very impressive and should provide good protection for the rig in case surface gas is encountered. The area surrounding the rig was neat, clean and well organized. SUMMARY: I witnessed the function test of the Diverter system on Doyon rig #141 drilling Arco's exploratory well Nanuk #1. Attachments: E9WJCKDD.XLS CC: Mike Zanghi (Arco drilling Eng.) STATE OF ALASKA Drlg Contractor: Operator: Well Name: Location: Sec. 19 ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Doyon Arco Alaska Inc. Nanuk #1 T. 11N R. Operation: Rig No. Oper. Rep.: Rig Rep.: 5E Development 141 PTD # Date: ~ 3/11/96... Exploratory: X 96-57 Rig Ph. # 263-3122 Donnie Lutrick Mort Heavriland Merdian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: P Drlg. Rig: P Flare Pit: N/A 20" in. 16 '"in. 120' /ft. N/A P P N/A ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: 0 Systems Pressure Attained: 3 Nitrogen Bottles: SIX BOTTLES 2250 Average 3000 psig 1550 psig min. 34 sec. min. 15 sec. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: P P Mud Pits: P P Flow Monitor: P P GAS DETECTORS: Light Alarm Methane P P Hydrogen Sulfide: P P psig DIVERTER SCHEMATIC Camp pipe shed Wind i pits /105' moters North Non Compliance Items Repair Items Within Remarks: Good solid 16" rigup Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: E9WJCKDD.XLS LOUIS i~. Grimaldi DVTRINSP.XLT (REV. 1/94) 1I 3/09/9~! JAD DCS AS-BUi~.~PER KS~ ~ K~O~ 59' ~i W~NI~ M ~ 2~3'~ Scale 1 118' I_ _1 NANUK ~1 ~ 5~1" LOCA~D ~IN PRO~AC~D SEC. 19, ~. 11 N., RGE 5 E. NOT TO SCALE UMIAT MERIDIAN LAT. = 70' 17' 35.229" N LONG. = 150' 58' ~3.~20' W Y = 5,957,7~1.05 NO~S X = 379,116.~7 1. BA~S ~ H~IZ~T~ LOCA~ON AND ~VA~ 2,627' F.S.U, 868' F.W.U /s u.s.e.s. ~ONU~T ~. GROUND ELEV.= 9.6' 2. CO~NA~ ~0~ ARE A~A STA~ P~E TOP ICE PAD E~V.= 11.3' ZONE ~, N.A.D. ~. E~vA~s ~o~ ~ B.P.~.~L D~E BY ~E ~ UND~ ~Y D~RE~T ~T ~ D;~~S ~D ~ D~LS ~ ~~T ")Z,,._~~~o~~.._.~.*- ~ LO-UN SB URY ARCO Alaska, Inca[ ~uK ~ mL~~ ' ~ ~uc~ ~ ~ Subsidiory of Atlontlc Richfield Compony ~-~T i ! ~o~2o~ ,/~/,~ C~-~l~-~OlP~O7 ALASKA OIL AND GAS / CONSERVATION COMMISSION' ; TONY KNOWLE$, GOVEF~NOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 7, 1996 Michael Zanghi KR.U Drill Site Devel Suprv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Namtk No. 1 .ad, CO Alaska, Inc. Permit No: 96-57 Sur. Loc. 2627'FSL, 869'FWL, Sec. 19, T1 iN, RSE, UM Btmhole Loc. 2115'FSL, 842;FWL, Sec. 19, TI IN, KSE, UM Dear Mr. Zanghi: . . . Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoneck The report should be a general/zed synopsis of the week's activities and is exclusively for the Commission's internal use.- Blowout prevention equipment 03OPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approx/mately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness thc test. Notice may be given by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures Depamuent of Fish & Game, Habitat Section w/o enct. Department of Environmental Conservation w/o end. STATE OF ALASKA AI-7[6KA OIL AND GAS CONSERVATION COMI~SION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill __ lb. Type of Well Exploratory.X Stratigraphic Test _ Development Oil _ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone _ Multiple Zone. 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ._ ARCO Alaska1 Inc. KB ht above sea level:40 feet Wildcat 3. Address 6. Properly Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-384211 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2627' FSL, 869' FWL, Sec. 19, T11N, R5E, UM N/A Statewide At top of productive interval 8. Well number Number 2115' FSL, 842' FWL, Sec 19, T11N, R5E, UM Nanuk #1 #U630610 At total depth 9, Approximate spud date Amount 2115' FSL, 842' FWL, Sec 19, T11N, R5E, UM 3-10-96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 842 feet 2.0 Miles 2485 Lease Acres 8,042 MD 8000' TVD feet 16. To be completed for deviated wells N/A 17 Anticipated pressure (see 2o AAC 25.035(e)(2)) kickoff depth 3 0 0 0 f eel Maximum hole angle 12° Maximum surface ~ p;l~ At total depth (TVD) 3 744 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2 0" 16" 62.58# B PEB 8 0' 2 7' 2 7' 110' 110' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1773' 27' 27' 1800' 1800' +300 sx AS-Ill, 500 sx AS-I 8.5" 7" 26.0# L-80 BTCMod 7993' 27' 27' 8020' 8020' +200 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true radical feet Effective depth: measured feet Junk (measured true vedical leet Casing Length Size Cemented Measured depth True Vedical depth Structural , - ..... .si Conductor ~"~"~;' ~:'""' ¢ ~'~' Surface Intermediate Production f ~ & O 0 ~ 1~,~, Liner ~ ~-"i ..'--~ ~ \ Pedoration depth: measured ~.:.~i .... ~'~ .':'~.-, ~-;':.~~,~u~,~, ~ ...... true vedical 20. Attachments Filing fee X__ Property plat X BOP Sketch ~ Diveder Sketch ~ Drilling program Drilling fluid program X Time vs depth plot __X Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby cedify that '~e foregoin~g is true and correct to the best of my knowledge ! Signed~U_~.r Titlle KRU Drillsite Development Supervisor Date ~'~' m(~ I~-'¢[llP. J~umber C°mmissi°nlUse Onl¢~da~~App I See cover letter for Permit Nu -'-~'-~ I 50-,"/O.~ - '~-~O2"~¢~ -'"' other recluirements Conditions of approval Samples required ~XY e s~ N o Mud Io---g required ~ Y e s __ N o Hydrogen sulfide measures __ Y e s .2¢_ N o Directional survey required ~'Yes ~ N o Required workingpressureforBOPE ~2M; ..~ 3 M' __ 5M' __ 10M' ~ 1 5 M Other: dngma! Signed By Approved by David W. Johnston by order of Commissioner the commission Date ~' . Form 10-401 Rev. 7-24-89 Submit in triplicate ~mmission ARCO Alask, a, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. J [ DRAWING NO: LK60'1185 12/0_7/95 NSK 6.01 j LOUNSBURY & ASS~CIATF, S. INC. N~,ET/,~ I I~N~EI~ Sb~V~YOR~ I ii :~ NANUK #1 EXPLORATORY WELL PERMIT EXHIBIT 83 J SHEET: 1,OF,2 IREV: SENT BY: ARCO ALASKA ; 8- 1-96 ; 15'00 ; KPS/~S/CNST/PROJ-~ RE:VI~:,D I o~A'nON RL .i3MI3 92-8~ 907 26E 6224;# 4/ 4 LOCATION 93-50 10 93-22 II N^NUK I AKF. .8O 93,.-11 93-41 B LOCATED WITHIN PROTRACTED SEC, 19, TWP. 11 N., ROE 5 E. UMIA'F MERIDIAN I..AT. = 70' 17' 35" -.o~. = ~.~o. ~,,,~.. 5,9,117 , " 869' F,W.L,, 2,627' F.S,I. ._.j" .-- ¢ 11 N 10 N ARCO Alaska, Inc. ,~, Subsidiory of A,".lontlc Richficld Compony CADD FILE NO. DRAWING NO: LK601183 .92-' 28 Villi. 22 LOUNSBURY ASSOCIATES, INC. NANUK #1 : EXPLORATORY WELL PERMIT EXHIBIT NSK 6.01 d185 SHrET: 2 OF2 REV; AAI 7,,5,27x UTP 15x AHC 11.35~ ~ WHTE 0..38~ ../ N NANUK 81 SURFACE LOCATION NANUK #1 BHL (-~o,35o)/,/ (+~o.3~o) ~' u'rP 19.692,~'('AHC 34,2;:~ !1 UTP 19.692= .HUNT 7.3,36, HUNT 5.75053= RW RES 3.78= 372105 RW RES HUNT 3.36= 31 --98 ~--51 --98 ,~1 /72.5~, ~ UTR; ,/7.5x u'rP 20.0~ ALK4715 ADL 25558 ~ 572107 -UTP 7.5~x~' ; ~f'~2 UTP ~ ~,PC z0.~. ~: . 'F ". ' t~OND) · , ::l -- . (COND) ALK4~6 ' ~4~8 ':aDL 25558 t: '' ADL 25557 ,r ~1 72.5~/''' ~1' 83.9~ UTP 7.~ ~P 16.1x :3APC 20.0~ APC 20.0~ -31-75 ( COND )r::?~'~ ~ AL K 471 ~ ~ ALK4551 ' ADL 25559 j ADL 372095 ~ ~1 63.9= UTP 16.1 UTP 16.1~ ~C 2~ APC 20~ 3-..31-98 ~; K4552; ALK4553 AOL 372096 ALK4557 ADL 372106 UTP 16.1~ _L 3-3 ALK4559 ADL372108 UTF APl 11 AAI ~, UTP / 11- _~5579 AN 58.75~ BPX 33.33~ UTP 7.917x 1-11-02 :601 L75x 55.33~ 7.917~ '/ertical Section Vie'"' Colville Nanuk #1 (Vertical Section Angle' 183.0) 1 ooo ........................................... i ...................... .: ........................................... ~'-" .................. ~ ..................... .~ ............... ...~ .... ~,,.~ .... i .... ;,,,~ .... ~...~ .... i .... L,,~ .... ~,,,;,,.-." ........ ~ .... -~,,,~,,,~ .... ~,,,,~ .... ~ .... ~,,,~ .... ~.,,,~,,,~ .... ~,,,~ .... -;-.-~-,,~ .... ~,, 3000 ........................................... '.' ...................... .~ ...................................... ~ .... ~ ...................... ~ ..................... ~ ............... 6000 ..................................................................................... [ ..................... : : : 7000 ......... ~ ............ '- ........... ~ .... ~ .... ...................... ..................... -' ............ : . -1 )00 0 1000 2000 3000 4000 5000 6000 Vertical Section (Feet) Plan View Colville Nanuk #1 (Vertical Section Angle · 183.0) 't~ o Z East/West (Feet) DPMS Survey Report Nanuk %1 Field Name: Colville Well Name: Nanuk #1 Plan Name: 3/5 Elevation: Oft RKB: Oft SHL: Oft & Oft BHL: 8000ft (8042ft MD) @ -512ft & -27ft J-4: 7210ft (7252ft MD) 0 -512ft & -27ft Page : 1 Date : 5/March/96 Interpolated Planned Survey Summary (Vertical Section Angle : 183.0) 3OO 400 5OO 6OO 700 0 800 0 900 0 1000 0 1100 0 1200 0 1300 0 1400.0 MD Inc Azm 0.0 0.00 183 02 100.0 0.00 183 200 0 0.00 183 0 0.00 183 0 0.00 183 0 0.00 183 0 0 00 183 0 00 183 0 00 183 0 00 183 0 00 183 0 00 183 0 00 183 0 00 183 0 00 183 1500.0 0.00 183 1600.0 0.00 183 1700.0 0.00 183 1800.0 0.00 183 1900.0 0.00 183 2000.0 0 00 183 2100.0 0 2200.0 0 2300.0 0 2400.0 0 2500.0 0 2600.0 0 2700.0 0 2800.0 0 2900.0 0 3000 0 0 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 TVD 0.0 02 100.0 02 200.0 02 300.0 02 400.0 02 500.0 02 600.0 O2 700.O 02 800.0 02 900.0 02 1000.0 02 1100.0 02 1200.0 02 1300.0 02 1400.0 02 1500.0 02 1600.0 02 1700 0 02 1800 0 02 1900 0 02 2000 0 02 2100 0 02 2200 0 02 2300 0 02 2400.0 02 2500.0 02 2600.0 02 2700.0 02 28OO.O 02 2900.0 02 3000.0 3100 0 1 3200 0 3 3300 0 4 3400 0 6 35OO 0 7 3600 0 9 3700.0 10 3800.0 12 3900.0 12 4000.0 12 4100.0 12 4200.0 12 50 183.02 3100.0 00 183 02 3199.9 50 183 00 183 50 183 00 183 50 183 00 183 02 3299.7 02 3399.3 02 3498.6 02 3597.5 02 3696.1 02 3794.2 VS -0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 -0 0 1 3 5 2 11 8 20 9 32 7 47 0 64 0 83.5 N/S 0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0.0 -0 0 0 0 -1 3 -5 2 -11 8 -20 9 -32 6 -47.0 -63.9 -83.4 00 183.02 3892.0 104.3 -104.1 00 183.02 3989.8 125.1 -124.9 00 183.02 4087.6 145.8 -145.6 00 183.02 4185.4 166.6 -166.4 E/W Build Turn Dleg T face 0.0 0.0 0.0 0.0 -0.0 0.0 00 0.0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -0.0 0.0 0 -00 0.0 0 -0 -0 0 -0 -0 -0 -1 1 1.5 0 -1 7 1.5 0 -2 5 1.5 0 -3.4 1.5 0 -4.4 0.0 0 -5.5 0.0 0 -6.6 0.0 0 -7.7 0.0 0 -8.8 0.0 0 0 0.0 0 0 0.0 0 0 1.5 0 1 1.5 0 3 1.5 0.0 15 6 1.5 00 15 0 15 0 15 0 15 0 15 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 5 0 1 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 DPMS Survey Report Nanuk %1 Page : 2 Date : 5/March/96 Interpolated Planned Survey Summary (continued) MD Inc Azm TVD VS N/S 4300.0 12.00 183.02 4283.2 187.4 -187.2 4400.0 12.00 183.02 4381.1 208.2 -207.9 4500.0 12.00 183.02 4478.9 229 0 -228.7 4600.0 12.00 183.02 4576.7 249 8 -249.5 4660 1 12.00 183.02 4635.5 262 3 -261.9 0 11.80 183.02 4674.5 270 5 -270.1 0 11.30 183.02 4772.5 290 5 -290.1 0 10.80 183.02 4870.6 309 7 -309.3 0 10.30 183.02 4968.9 328.0 -327 6 0 9.80 183 02 5067.4 345.5 -345 0 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 0 9.30 183 0 8.80 183 0 8.30 183 0 7.80 183 0 7.30 183 0 6.80 183 02 5166.0 362.1 -361 6 02 5264.8 377.8 -377 3 02 5363.7 392.7 -392 1 02 5462.7 406.7 -406 1 02 5561.8 419.8 -419.2 02 5661.1 432.1 -431.5 0 6.30 183.02 5760 4 443.5 -442.9 0 0 0 4.80 183 0 4 30 183 0 3 80 183 0 3 30 183 6500.0 2 80 183 6600.0 2 30 183 6700.0 1 80 183 5.80 183.02 5859 5.30 183 02 5959 02 6059 02 6158 02 6258 02 6358 02 6458 02 6558 02 6657 6800.0 1.30 183.02 6757 6900.0 0 80 183.02 6857 7000.0 0 30 183.02 6957 8 454.0 -453.4 4 463.7 -463.1 0 472.5 -471.9 7 480 4 -479.8 4 487 2 493 1 499 0 503 9 507 9 5O9 9 511 5 -486.8 7 -493.0 0 -498.3 5 -502.8 1 -506.3 8 -509.1 6 -510.9 9 512.6 -511.8 7060.1 0 7100 0 0 7200 0 0 7252 1 0 7300 0 0 7400 0 0 7500 0 0 7600.0 0 7700.0 0 78O0.O 0 7900.0 0 8000.0 0 8042.1 0 00 183.02 7018.0 512 7 -512.0 00 183.02 7057.9 512 00 183 02 7157.9 512 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 00 183 02 7210.0 512 02 7257.9 512 02 7357.9 512 02 7457.9 512 02 7557.9 512 02 7657.9 512 02 7757.9 512 02 7857.9 512 02 7957.9 512 02 8000.0 512 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 7 -512.0 -15 -16 -17 -18 -19 -19 E/W Build Turn Dleg T face -9.9 0.0 0.0 0.0 0.0 -11.0 0.0 0.0 0.0 0.0 -12.1 0.0 0.0 0.0 0.0 -13.2 0.0 0.0 0.0 0.0 -13.8 -0.5 0.0 0.5 180 0 -14 2 -0.5 0.0 0.5 180 0 3 -0.5 0.0 0 5 180 0 3 -0.5 0.0 0 5 180 0 3 -0.5 0 0 0 5 180 0 2 -0 5 0 1 -0 9 -0 -20.7 -0 -21.4 -0 -22.1 -0 -22.8 -0 5 0 5 0 5 0 5 0 5 0 5 0 -23.4 -0.5 0 -23.9 -0.5 0 -24.4 -0.5 0 -24.9 -0.5 0 -25.3 -0.5 0 -25.7 -0.5 0 -26.0 -0.5 0 0 0 0 0 0 0 5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 0 0.5 180 5 180 0 5 180 0 0 0 0 0 0 0 0 0 0 0 0 0 -26.3 -0.5 0.0 0.5 180 -26.5 -0.5 0 0 0.5 180 -26.7 -0.5 0 -26.8 -0.5 0 -26.9 -0.5 0 -27.0 -0.5 0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 -27.0 0.0 0 0 0.0 0 0 0 0.5 180.0 0 0.5 180.0 0 0.5 180.0 0 0.5 180.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 End Of DPMS Survey Report DIAGRAM AND DESCRIPTION OF DIVERTER SYSTEM TO BE USED (Per 20 AAC 25.005(c)(5)) Per 20 AAC 25.005(c)(3): DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) BOP SCHEMATIC DOYON RIG #141 13-5/8", 5,000 PSI J I I I I I 4 I See listing of individual components on following page DIVERTER SCHEMATIC DOYON RIG 141 HYDRIL MSP 21-1/4" 2000 psi Annular 21-1/4" 2000 psi 16" Outlet Spool (2) 1611~ 62#, PEB Conductor Flowline 16", 200 psi Hydraulic Knife Valve 16" OD Diverter Line ARCO NANUK #1 DOYON 141 13-5/8, 5,000 PSI BOP COMPONENTS Diverter System: 1. 21-1/4", 2000 psi WP, Shaffer MSD annular preventer 2. 21-1/4", 2000 psi WP diverter spool with one 16" outlet. 3. 16", 2000 psi WP hydraulic knife valve on diverter outlet. BOP Stack: 4. 13-5/8", 5000 psi WP, Hydril Type GK annular preventer with companion flange to bell nipple. 5. Double 13-5/8", 5000 psi WP, Hydril Magnum blowout preventer fitted with pipe rams on top and blind rams on bottom. 6. Single 13-5/8", 5000 psi WP, Hydril MPL blowout preventer fitted with pipe rams. 7. 13-5/8", 5000 psi WP drilling spool with two 3", 5000 psi WP outlets Choke Valves: 8. 3" 5000 psi WP Shaffer gate valve with hydraulic actuator. 9. 3" 5000 psi WP OCT manual gate valve. Kill Valve: 1 0. 3" 5000 psi WP OCT manual gate valve. 1 1. 3" 5000 psi WP Shaffer gate valve with hydraulic actuator PRESSURE INFORMATION ARCO NANUK #1 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Nanuk #1 well' Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure D rill i n g (in.) (ft. RKB) (lbs/gal) (lbs/gal) (psi) (psi) 1 6 120 10.9 8.6 53 55 9-5/8 1800 13.6 9.0 842 1075 7 8000' 16.3 9.0 3744 N/A Procedure for Calculating Anticipated Surface Pressure (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP : [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP - (0.11 x D) where' FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (16") ASP = --. --,., [(FG x 0.052) - 0.11]D [(10.9 x 0.052) - 0.11] x 120 55 psi ASP = --.. FPP -(0.11 x D) 842 - (0.11 x 1800) 644 psi . Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11]D = [(13.6 x 0.052) - 0.11] x 1800 = 1075 psi ASP= FPP - (0.11 x D) = 3744 - (0.11 x 8000) = 2864 psi Casing Performance Properties Size Weight Grade (in) (Ib/ft) 1 6 62.58 [] 9-5/8" 53.5 L-80 7 26 L-80 Internal Collapse Cnxn Yield Resistance (psi) (psi) PEB Conductor Casing BTC 7930 662O BTC-Mod 72 4 0 5 41 0 Tensil Strength Joint Body (1000 lbs) 1329 1244 667 604 Casing Setting Depth Rationale 1 6" 120' RKB 9 - 5 / 8" 1800' RKB 7" 8000' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. SUPPORT DOCUMENTS FOR REQUEST FOR EXCEPTION TO 20 AAC25.035(b)(1) (Bifurcation of Diverter Line) ARCO Alaska, Inc. hereby applies for an exception to the provisions of 20 AAC 25.035(b)(1), concerning bifurcation of the diverter line. Following are the major concerns associated with this request. 1) After extensive study of the 1992 Cirque blowout and the performance of the equipment on Cirque, ARCO Alaska, Inc. has determined that a combination of one 16" line with no 90° turns is the optimum design. 2) Effective operation of remote valves positioned 100 feet from the rig are limited. 3) Prevailing winds on the North Slope during the winter drilling season are generally in the direction of NE to SW. With perpendicular placement of the diverter line, there is minimum exposure of gas blowing back onto an ignition source. It is our opinion that with proper placement of the diverter line with respect to prevailing winds in conjunction with the short duration of time while drilling under the diverter, a bifurcated line is not necessary. PROPOSED CASING AND CEMENTING PROGRAM ARCO NANUK #1 (Per 20 AAC 25.005(c)(4)) WELLBORE SCHEMATIC NANUK #1 16" Conductor @ 120' RKB 12-1/4" Hole 9-5/8" Surface Casing @ 1,800' RKB 8-1/2" Hole Top of Cement at approx. 6,700' RKB 7" Production Casing @ 8000' RKB, Cemented to 500' above Jurassic Sands Casing S i~'6-~ 16" Hole Size: 20" Depth: 120' RKB Top of Cement: Surface Excess Calculated: 100% Volume Calc: (120')(0.7855 cuft/ft)(2) = (189 cuft)/(0.93 cuft/sk) = 203 sks 203 sacks ARCTICSET I Slurry Volume 189 cuff Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 2+ hours Casing Size: 9 5~8" Hole Size: 12 1/4" Depth: 1,800' RKB Top of Cement: Sudace Excess Calculated: 100% BHT (Static): 60°F BHT (Circ): 60°F Volume Calc: Lead (1000')(0.3132 cuft/ft)(2) = (626 cuft)/(1.94 cuft/sk)= 325 sks Volume Calc: Tail (800')(0.3132 cuft/ft)(2) = (500 cuft)/(0.93 cuft/sk)= 540 sks Lead: 325 sacks ARCTICSET III + 1/4 #/sk D29 (celloflake) Slurry Volume 630 cuff Slurry Weight 12.1 ppg Slurry Yield 1.94 cu. ft./sk Mix Water 11,11 gps Thickening time 6.0+ hours Tail: 540 sacks ARCTICSET I + 1/4 #/sk D29 (celloflake) Slurry Volume 500 cuff Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 3+ hours Casing Size: 7" Hole Size: 8 1/2" Depth: 8,000' RKB Top of Cement: 6,700' RKB Excess Calculated: 20% (depending on caliper) BHT (Static): 170°F BHT (Circ): 140°F Volume Calc: (8000' - 6700')(0.1268 cuft/ft)(1.2) = (200 cuft)/(1.19 cuft/sk) = 170 sks 170 sacks Class G cement + 2 gps D600(latex) + 0.1 gps D135(stabilizer) + 0.1 gps D47 (defoam) + 3% D53(Gyp) + 0.7% D65(dispersant) + 0.05% D800(retarder) Slurry Volume 200 cuff Slurry Weight 15.8 ppg Slurry Yield 1.19 cu. ft./sk Mix water 5.18 gps Thickening time 3.5 - 4.5 hours PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ARCO Nanuk #1 (Per 20 AAC 25.005(c)(6)) ARCO Alaska, Inc. Proposed Mud Program Nanuk #1 (Colville Exploration) November 20, 1995 General Well Plan: A standard Kuparuk type fresh water spud mud (10.0 ppg) will be used to the 9 5/8" casing point. From there to TD, a fresh water LSND system similar to that used on last winter's Alpine and Fiord tests will be used to drill the 8 1/2" hole. The plan is to treat the fresh water spud mud for cement contamination when drilling out of the 9 5/8" surface shoe and drill ahead in the 8 1/2" hole to TD treating the system as a standard fresh water LSND system. However, as dictated by the actual drilling requirements of this well, an inhibited mud (KCl) may be required to address special coring or formation damage issues. Estimated Casing Program: Hole Size Casing Size TMD 20" Conductor ' 12 1/4" 9 5/8" 8 1/2" 7" ~' I. Surface Hole (12 1/4" Hole to 9 5/8" Casing): 1.) The current plan is to have 800 bbls of 10.0 ppg spud mud at the Baroid Prudhoe Bay Mud Plant to spud this well. The mud will be delivered to the rig with the following target properties: Density - 10.0 ppg Viscosity - 120 sec/qt YP - 35-40 lbs/100ft(2) pH - 9.0-9.5 To drill ahead, maintain the viscosity at initial levels to the base of the permafrost (800'-1000') then reduce the viscosity as allowed based upon actual hole cleaning requirements. A funnel viscosity of 50 - 80 sec/qt may be suitable by the 12 1/4" TD. It should be noted that the actual mud viscosity requirements will vary in this area based upon the actual amount of surface gravel present at each specific location. However, generally only minimum gravel has been noted in this area allowing successful drilling with reduced viscosities. 2.) Due to concerns for gas below the permafrost and to reduce barite mixing activities during spud operations, spud the well with a 10.0 ppg mud weight and basically hold that mud weight to TD of the 12 1/4" surface hole at 1800'. While there is some mud weight latitude from spud to the base of the permafrost at 800'-1000', the mud weight should be a solid 10.0 ppg by the base of the permafrost then held at that weight to the 12 1/4" TD (or as dictated by actual hole conditions). 3.) PAC treatments can be initiated toward the 12 1/4" TD for improved well bore stabilization by reducing the API filtrate to 8-10 cc's. Page - 1 4.) Circulate and short trip the hole prior to running the 9 5/8" casing. A light Desco-CF treatment will be useful to reduce the gel strengths of the mud prior to running the casing and cementing. Note: There should be adequate chemical treatment of the mud to insure rheological stabilization of the system prior to TOH to run the surface casing. As the cement contamination while drilling out of the surface casing on Alpine #1 created significant problems, extra focus should be made to insure this problem does not recur. Condition the mud prior to TOH to run the surface casing and then again after the surface casing has been landed and the rig is circulating the hole prior to the actual cement job itself. Target a pretreatment of 2 ppb Bicarb and I ppb PH6 with .5 ppb Therma-Thin (pilot test for specific treatments) to minimize the effects of the cement contamination when drilling out. When drilling out, continue with bicarb treatments to remove the excess calcium, add PH6 (citric acid) as required to neutralize the pH and treat with thinners as needed for rheological stabilization. 5.) Maximum utilization of solids control equipment is recommended throughout surface hole drilling operations to keep the sand content less than 1% by volume and improve overall drilling conditions. II. 8 1/2" Hole (From 9 5/8" Shoe to Top Zone of Interest): Again, assuming normal spud operations and a salvageable spud mud, the plan is to clean-up the spud mud as required while NU on surface casing and drill ahead with the conditioned spud mud into the 8 1/2" hole. The system will be maintained as a standard fresh water gel/PAC LSND system (as done on the Alpine #lA and #lB sidetracks) for this interval of the well. Mud treatments should be based on an as needed basis for the 8 1/2" hole. 1.) The important initial properties for the initial 8 1/2" hole would include a neutral pH in the 8.5 to 9.0 range, YP in the 10-15 lbs/100 SF range and an API filtrate in the 6-8 cc range. The initial funnel viscosity should be in the 40 to 50 sec/qt range or as dictated by actual well bore conditions. For drill-out, the initial mud weight requirement is for a 9.8-10.0 ppg mud weight. As drilling continues in the 8 1/2" hole, the mud weight should be increased on an as needed basis with barite. The maximum mud weight for the 8 1/2" hole should be in the 10.2 - 11.0 ppg range. To reduce or control the mud weight while drilling ahead, maximize the solids control equipment efficiency and dilute with fresh water as required. Some rig site solids analysis will be required to identify the best mechanism for overall solids control. 2.) The viscosity of the mud in the 8 1/2" hole can be sustained with additions of Aquagel and extender and/or PAC treatments. Xanvis or Biozan can also be used to provide good LSRV support on an as needed basis. These viscosity treatments should be based upon actual hole cleaning requirements. Page - 2 3.) Maximize all solids control efforts. Run as fine as screens possible on the shale shakers. The use of the rig's desander, desilters/mud cleaners and centrifuge should be based upon daily mud solids analysis versus the current mud objectives. With a weighted mud from spud to TD (10.0 ppg+), the application of the various pieces of solids control equipment will change based upon the changing condition of the mud itself. 4.) Treatments with PAC polymers should be used throughout this section of the hole to control the API filtrate in the 6 to 8 cc range or as required based upon actual well bore conditions. Low viscosity or regular viscosity PAC products are available for use. 5.) Control excessive rheological conditions with additional Therma-Thin treatments on an as needed basis. Therma-Thin is an effective polymer deflocculant designed to provide effective rheological stabilization. By maintaining a .25-.5 ppb concentration of Therma-Thin in all make-up additions, better rheological stability will be observed. 6.) The commercial bentonite (Aquagel) concentration should be kept at 2-4 ppb minimum through this intermediate section of hole. 7.) Dilute as necessary and maintain volume with fresh water as required. 8.) Maintain the pH in the 8.5 - 9.0 range with caustic soda additions. 9.) Torq-Trim II or ConDet treatments may be required to reduce balling problems through the "sticky" clays found in this interval of the well. 10.) Continue with tourly treatments of Aldicide-G while drilling this interval of the well. A 5-10 gal/tour treatment rate has proven effective in recent North Slope work. III. 8 1/2" Hole (From of Top Zone of Interest to TD): 1.) Prior to drilling into the zone of interest, the mud should be conditioned as follows to insure mud stability and to reduce the API filtrate for pay-zone protection. One should expect a minimum dilution of 10-15% with fresh water to re-adjust total solids and to make the system receptive to the following treatments: A. Run the pH in the range of 8.5-9.5 with caustic soda. B. The API filtrate should be reduced to the 4-5 cc range with Baranex and PAC's at a 3 : 1 ratio. This will probably require approximately 3 ppb Baranex and .5-1.0 ppb PAC's. Target a HTHP filtrate of 15 cc's at 200 degrees. C. Be aggressive with biocide (Aldacide-G) treatments to reduce/minimize bacterial degradation. A field kit is available to monitor the residual biocide concentration. D. Continue with fresh water dilution as required to adjust the total solids content of the mud. Page - 3 E. Adjust the mud weight as required with Baroid (barite). The anticipated mud weights for this interval of the well is between 10.0 and 11.0 ppg. 2.) To control excessive rheology, treat as required with Therma-Thin (a polymer deflocculant) and/or Desco CF (tannin powder). 3.) At TD, conditioned for logs and possibly a 7" casing job. Primary focus should be on rheological stabilization with caustic treatments for pH control and Desco-CF, Therma-Thin and/or Enviro-Thin thinners to control excessive rheological trends. IV. Suggested Mud Properties: Upper Lower Surf. 8 1/2" 8 1/2" Density 9.8-10.0 9.8-10.2 10.0-11.0 PV 15-25 10-25 20 YP 20-40 10-20 15 Viscosity (Initial) 80-120 40-50 45 (Final) 50-80 Ini. Gel 5-15 5-10 5 10 min. Gel 15-35 10-15 15 API F±i. (Initial) 10-20 6-8 <5 (HTHP @15) (Final) 8-10 pH 9-9.5 8.5-9.0 8.5-9.5 %Solids 4-10 <6% LGS <6% LGS Page - 4 DOYON DRILLING CO. RIG #141 DRILLING FLUID SYSTEM . Maximum Operating SPM: Minimum Operating SPM: Maximum Deliverable HP: Pump Efficiency: Mud System Data and Specifications Mud Pump Motor Efficiency: 2.1 2.2 2.3 2.4 2.5 2.6 2.7 2.8 2.9 Number of Mud Pits: Two Volume of each mud pit: # of sections in each mud pit: Does ng have tdp tank? Yes Does rig have tank Yes Number of surface guns on pits: Dernck Flowline cleaners: No: 3 Single: Shale Shakers: No: Single: Desander. Make: Pioneer Cones Number. Two 447 Bbl. total Volume: 895 448 Bbl. 30 Bbl 6 0 X No. I Volume: 40 X No. 1 Volume: 36 8-Brandt pit mixers Derdck Dual: or Make: Dual: Model: S2-12 Size: 12 Make: X Model: FIo-Line CI Model: Desander Pump: Make: Gallaqher Model: 5X6 * Rated Throughput: 1,000 GPM at: 10 * Manufacturers rated Volumetric capacity at given fluid densities. Desilter of Mud Cleaner: Make: Tri-FIo Model' Low Profile Centrifuges: NOTE: Size: 5" X6" PPg Cones Number. Two Size: 12 Desander Pump: Make: Gallaqher Model: 5X6 Rated Throughput: 1,000 GPM at: 10 Manufacturers rated Volumetric capacity at given fluid densities. Do desanders and desiiters have pressure gauges on inlet?: Make: ALPHA-LAVAL Model: DMNX 418 GPM: 125 Please furnish a schematic of the pits showing location equipment, partitions and current dg up, including agitation. (To be supplied with dg specs upon modifications completion.) Size: 5" X6" PPg Cellar Jet Pump: Air operated Inqersol Rand DiaDhram pump Volume 3.._~" 100 GPM C-2 Contract No. AK95-0375 :;6 FT - O' PUMP IvlODU-LE DOG HOUSE 6~ '::)~ F'T - 0 PUlvlp MODULE I-I~1 SUCTION TANK '¥ MIX PIT I I mm mm mm mm mm mm mm mm mm m m mm F---1 F--7 mm m mm m mm m mm mm m m mm ,m F---1 2zt- F PRESSURE ANALYSIS ARCO NANUK #1 (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) ARCO NANUK #1 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 0 -1000 SURFACE CASING 1800' -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 8 9 10 11 12 13 14 15 16 17 18 EQUIVALENT MUD WEIGHT (LB/GAL) ARCO ALPINE #1 -1000 -2000 -3000 ........... -4000 -5000 -6000 -7000 -8000 MUD WEIGHT CURVE JANUARY 1995 8 9 10 11 12 13 14 15 16 17 18 MUD WEIGHT (LB/GAL) - 1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 ARCO BERGSCHRUND #1 MUD WEIGHT CURVE MARCH 1994 ...... r ...... ~ ...... ;"'i ....... r ...... ~-~'~*'-i~ ...... ~-r- ' '. '~, LOT 13.7 LB/GAL ~~---'-~ ....... ~ ........ i ~ ~ ................... ~'"-'i .................... t ~ ~ ~ ~ [ ............ ---:-~ ........... - -~-~ .......... ~' ....... .... ~' ~ - ..................... .-, - 'r~ _ _ ,~'.-I--~ ---~-[,~ ~ ........... _ ~r'"--'""i_J.. ......... L__~L-"_ ............. ~ .......... .J~"'-'i;.___~ ........ ~ ~ _~.~,, ...... ,"'""'-' ' 1' '"'-- I *-~-~ ~ -'-- '~---' ~ .................. .......... , , ........... ..... __,_~ ............... ~ ~ . ; , _ 8 9 10 11 12 13 14 15 16 17 18 MUD WEIGHT LB/GAL ARCO BERGSCHRUND #2 -1000 9-5/8"SURFACE CASING @ 1827' -2000 -3000 -4000 MUD WEIGHT CURVE Doyon 141 Feb 1996 LLI -5000 ~ -6000 -7000 -8000 -9000 -10000 8 9 10 11 12 13 14 15 16 MUD WEIGHT (LB/GAL) Pore Pressure Prediction for the Nanuk #1 Well (TXCO86-05) correlated to the Alpine #1 Well. The following summarizes the pore pressure work done in the Colville area using the above data. The wireline sonic data was used to predict the pressure in the Alpine #1 well; and the seismic velocity was used for the seismic line. There are no large pressure anomalies above 5000' at this well or seismic line. There is an anomaly at the Nanuk #1 well location on line TXCO86-05 at 5200' which could be due to pressure or a lithology change. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at every CDP location with an automated high resolution velocity analysis program (UHCI process developed by ARCO Exploration and Production Technology). This process produces a very accurate and densely sampled velocity field to cover every CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. These were the steps taken to calculate the pressures: 1) The Gamma Ray log from the Alpine #1 well was used to distinguish the sand intervals from the shales. 2) 3) A Normal Compaction Trend Line (NCTL) was determined in the shales from the wireline sonic data for the Alpine #1. This line indicates the predicted sonic value if these shales were normally compacted (no pressure). If the sonic delta T increases past the compaction line, (this change is/X/XT), then there is an indication of an increase in pressure. Using the mud weight data from the Alpine #1 and Bergschrund #1 wells, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is · PP = C2 * AAT 2 -b C1 * AAT + C0 where C2 = -1.34 e-05; C~ = .0062; Co = .465 4) This NCTL and Translational Trend was used for the seismic line. Alpine #1 Figure # from left l) I is the pore pressure plot from the wireline sonic data. The curves to right are: The black curve is the sonic log. The green dots are the shale intervals. 2) The red line is the Normal Compaction Trend Line. 3) The blue curve is the pore pressure. 4) The green curve is the actual drilling mud weights. 5) The red curve is the fracture gradient. 6) The points labeled "pressure" are RFT measured pressures in equivalent mud weight. 7) "LOT" is the leak off test in equivalent mud weight. There are no major pressure intervals in this well. There are some minor ones at 2000' and 3800' where the mud weights may need to be increased to 10 ppg. At 6800', there is an increase in the sonic AT which is attributed to the kerogen in the shales. This can be seen on the Gamma Ray increase on the logs. Since there was only one leak off test, it was difficult to create a fracture gradient curve. A Gulf of Mexico trend curve was used in this model and appears to be pessimistic. TXCO86-05 (Nanuk #1) Figure #2 ties the wireline data (black curve) from the Alpine #1 (CDP 924) to the seismic travel time (red curve, ITT). The green line is the NCTL. The seismic matches the wireline at 2000'. Figure #3 shows the ITT at CDP 1220 is similar to the Alpine #1 at 2000'. pressures should be the same as the Alpine #1 well. The Figure #4 shows there is no pressure until 5200'. This increase could be due to high pressure or lithology changes. The pressure deeper than 7900' may be due to the kerogen in the shales or lithology changes. Figure #5 is the pore pressure plots over the seismic interval verses depth and Figure #6 is verses time. PROJECT:COL~gLLE_~ 2000 3000 4000 5oo~ 2000 3000 4000 5000 6OO( 6000 7000 7000 800C 8000 8462 ~ ARCO E×p~oration and Production Technology ~Pore Pressure and Fracture Gradient System 2/06/95 Ra~ Wydrinski Scale: Vertical I in= 16791l, Ihxqzonta] I i.= 185 cdp ALPINEI SP610 11111111 11111111 CDP 7 7 8 8 8 8 9 9 9 9 0 0 0 0 i i i i 2 2 2 3 3 3 3 4 570257025702570257 25702570 50505040 5050505 005050 TEST1580 445555 6 570258 2 50500 5 IIit 6777 7025 505 D 375(i.i E P T H fit) 5o0{).o 75013.( 8750.0 usec/f! Projec~ Name: COLVILLE_AAI Cross Section: TXCO8605 tit ParaSol: VELF_DT 210.0 190.0 180.0 170.0 160.0 150.0 140.1) 130.0 120.0 110.0 10{).0 90.0 80,0 70.0 60.0 50.0 40.0 CDP 924 Well: ALPINEI .~.~___ Trend ~i~e rFF curve '--'-- Sonic EDT Feel (Datum sel to MSL) MSL40 60 80 10{I ~20 160 1250 250{) 3750 ~ ARCO Exploration and Productio~ Technology ~ Pore Pressure and Fracture Gradmnt System 112/06/95 Ray Wydrmski D E P T H (0) Scale; Vertical I in= 1679 fl, Itorizxmtal I ia= 185 cdp ALPINE } SP610 CDP 7 7 8 8 8 8 9 9 9 9 0 0 o 0 i I i I 2 2 2 3 5 7025 702 5 7025 70 2 57 2 570 50505040505050 05 0050 TESTI580 334444555 5 666777 570257025 8 257025 05050 0500 505050 25~).0 6250.0 usec/ft Project Name: COLViLLE_AAI Cross Se~:lion: T×CO8605 ITF DataSet: VELF_DT 250,0 240.0 230.0 210.0 190.0 [ 70.0 160.0 150,0 130.0 12(/.0 100.0 90.0 80.0 702) 50.0 40.0 CDP 1220 Well: SP610 ___ TrerM li~e .__._ FFP curve Feet (Datum set to MSL) 40 60 80 I00 120 160 MSL 8750 ~ARCO ~×p~oration a~d Prod~ctio~ Technology ~ Pore Pressure and Fracture Gradient System 2/06/95 Ray Wydrinski Project Name: COLVILLE_AAI Cross Section: TXCO8605 PPDataSet: PLEI180 45 PPG 44555 5 6 57025 8 2 05050 5 6777 7025 5050 1250.0- 2500.0 3750.0 sore0 6250.0 PPg 8.00 8.50 9,00 9.50 Method: Trend Curve NCTL: S88605 180 45 Model: PLIESTOCENE PPG curve al CI)P I22(} Feet (Datum set to MSL) MSL 8 10 12 14 I6 18 20 1250 7500.0 8750.0 10000 Cross S~tlon: TXCOO605 Pore Pressure and Fracture Gradmnt System P~mt~sct: PLEI180 45 PPG Seismic Dataset: TXCO86-05_Z 2/06/95 Ray Wydrinski S~le: ve~ ca n ~ 1679 f~, H~i~m~a[ ~ in ~ 123 cdp 5 8 0 2 4 6 8 0 24 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 0 0 0 0 0 0 0 0 40 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D 3750.0, E P T H (ft) 50(X},C 6250.0 Method: Trend Curve NCTL: SS8605 180 45 Mod~h PLIESTOCENE 7 5 o Ppg 8.00 &50 9.00 9,50 10.50 12.00 12.50 13.50 15.00 15.50 16.00 16.50 75¢X).0 8750.0 10(×8).{} ~ARCO E×p~omtion and Production Techmo[og~i~,~m~: COLVILLE AAI Fracture Gradient System Cros~ S~lion: TXCOS60~ ~ Pore Pressure and ~u DataSel:PLEI180 45 PPG_T Seismic Dataset: TXCO86-05 ]2/06/95 Ray W~dfinski Scale: Verficsl I in = 3~0 msc~, Horizontal ] i~ = 123 cdp ALPINEI SP610 ~ST1580 CDP 7 i i i i i i i ~ ~ i i i i ~ ~ i i i i i ~ i i i ] i ~ i [ i i ~ 5 0.0 Method: NC~: SS8605 180 45 M~¢I: PLIESTOCENE 250.0 500{0 750.0 T 1 M E (ms) 100{10 7 8 8 8 8 8 9 99 9 9 0 0 0 0 0 I I I I I 2 2 2 2 2 3 3 3 3 3 4 4 4 4 4 5 5 5 5 5 6 6 6 6 6 7 7 7 8 0 2 4 6 8 0 24 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 I) 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 5 0 0 0 0 0 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ppg 8,50 9.50 10.50 13.00 I3.50 PROPOSED DRILLING PROGRAM ARCO NANUK #1 (Per 20 AAC 25.005(c)(10)) Surface Hole Drilling Hazard Section Nanuk #1 No specific drilling hazards are expected. Analysis of shallow seismic data does not show any abnormal velocities and offset wells have not encountered any shallow gas. Normal drilling precautions for Exploration drilling should be taken. Minor drill gas and hole sloughing should be expected at the base of the permafrost. Base of permafrost is expected at _+850' RKB. Production Hole Mud weight should be 9.8-10.0 lb/gal prior to drilling the C-30/K5 interval at 2430'. This interval in offset wells contains gas that is thought to be slightly pressured at 9.6 lb/gal. Normal drilling precautions for Exploration drilling should be taken throughout the hole. · Lost circulation has been encountered in several Colville wells. Depth of loss of loss zone is thought to be in the 5000'-7000' interval. Nanuk #1 · General Drilling Procedure Application for Permit to Drill March 1996 (All depths are measured from RKB unless otherwise noted) Move in rig and rig up over pre-installed 16" conductor and cellar. Nipple up and function test diverter. Rig up mudloggers. Make up 12-1/4" bit and bottom-hole assembly and drill surface hole to 1,800' RKB. Run and cement 9-5/8" surface casing. Nipple down diverter, make up casing head, nipple up and test BOPs to 3000 psi. Pressure test 9-5/8" casing to 2500 psi. Drill out cement and float equipment with 8-1/2" bit. Drill 10' of new hole and perform leak-off test. POOH. Make up 8-1/2" bit and bottom-hole assembly with MWD/LWD (GR-Res). Drill 8- 1/2" hole to TD (approx. 8,000' RKB). If warranted, run open-hole logs from TD to the 9-5/8" casing shoe. If log results are favorable, run and cement 7" casing. Nipple down BOP stack, nipple up tubing head, nipple up and test BOP stack. Run cased hole logs if required. Pressure test 7" casing to 3,500 psi. Freeze protect 9-5/8" X 7" casing annulus. Run in hole with conventional DST test string or completion-type test string. Nipple up and pressure test 5,000 psi tree, tool string and manifold. Perforate well underbalanced using tubing-conveyed guns. Flow up the tubing and through surface testing facilities. Test liquids will be stored in tanks on the drilling location and pumped back into the reservoir or hauled to Kuparuk and processed through Kuparuk facilities.. Gas will be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. For long-term flow testing, the rig will be moved off location prior to perforating and will be moved to a different, but nearby, drilling location. After completion of testing, abandon well per AOGCC regs. Rig down and release drilling rig. Thoroughly clean and abandon the ice pad and ice road on the way out. -1000 -2000 -3OOO -4000 -5000 -6000 -7000 -8000 NANUK #1 STRAIGHT HOLE 1996 COLVILLE DELINEATION N/U DIVERTER , 1 DRILL 12-1/4" SURFACE HOLE TO 2000'-- ~,:.--~ DRILL 8-1/2" HOLE TO TD .................................. , ............ a ......................... ................................ 0 5 10 15 20 25 30 DRILLING TIME (DAYS) FJ 10/11/95 ARCO Alaska, Inc. Post Office 8ox 100360 Anchorage, .,~laska 99510-0360 Telephone 907 27-~ 1215 March 5, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Nanuk #1 Dear Commissioner Johnston, Attached is a revised Application for Permit to Drill for the ARCO Nanuk #1. The original Nanuk #1 location required a spacing exception which has been applied for but may not be approved in time to spud the well. Therefore the planned bottom hole location has been moved to a location which does not require a spacing exception. The bottom hole location has been moved approximately 500' south. All of the supporting information submitted with the original permit appication remains the same. A directional plan and property map are also included. Please replace the Form 401 dated March 1 with the revision. Estimated spud date for the Nanuk #1 well is March 10. ARCO requests that AOGCC review this Application as soon as possible to allow approval this week. Your prompt attention is appreciated. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, Kuparuk Drillsite Development AR3B-6003-93 242-2603 ARCO Alaska, Inc'~' Post Office Box 100360 Anchorage. AlasKa ~9510-0380 Telephone 907 ,...70 121 '~ March 1, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Nanuk gl Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCO Nanuk gl, on State lands near the mouth of the Colville River. ARCO will act as operator for itself, Union Texas Petroleum and Anadarko Petroleum Corporation in evaluating acreage previously leased. The proposed well location is approximately 2.0 miles south of the ARCO Alpine glB drilled last winter. The wellsite will be accessed via ice road originating at KRU 2M Pad. ARCO plans to use Doyon Rig 141 to drill this well from an ice pad during the winter of 1996. Nanuk gl is planned as straight hole with a surface and bottom hole location of 2627' FSL, 869' FWL, Section 19, T1 IN, R5E. This location requires a spacing exception. ARCO submitted a request for spacing exception on February 22 for the Nanuk well. The location has been moved slightly north of the location shown on the spacing exception request but is still in the southwest 1/4 of Section 19. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. All waste drilling mud and cuttings generated during the drilling of Nanuk gl will be hauled to either the Kuparuk River Field or Pmdhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be at the base of the Nuiqsut Formation which directly underlies the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO also requests an exception to the shale density requirement in 20 AAC 25.033(e,2,D). The shale density technique does not work well in Alaska due to the variable composition of the shales and the chemical used in the shale density column is listed as an exceptional health hazard. Estimated spud date for this sidetrack is March 10. ARCO requests that AOGCC review this Application as soon as possible to allow approval in a short time period. Your prompt attention to this matter is appreciated. AR3B-6003-93 242-2603 ARCO Alaska, Inc. Post Office ~-3o¥. 100366 Anchorage, Alaska 99510~0360 "relephone 907 276 i2'16 The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program Finally, the following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 3) Geologic Data and Logs (20 AAC 25.071) Mark McDermott, Explorationist 265-6394 If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, Kupanfl( Drillsite Development AP, 3B-6003 93 :. 242-2603 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Annular Disposal of Cement Washdown Water Colville Delta Exploratory Wells Re' Gentlemen' ARCO hereby requests a waiver to the AOGCC Regulations (20 AAC 25.080.) covering Annular Disposal of Drilling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's Colville Delta exploratory wells currently being drilled during the 1996 winter drilling season. Cement washdown water is an integral part of any cement job. Cement is used as a means of pressure control in the wells being drilled. Each casing string, sidetrack olug P&A plug and oth'-'~ ,"~'~"¢nt oluo, mixed for use in d,'il!ing wells produce a ly ~ '-" ......... Yvc, o,,~u,~,, water as a resu,~ ol ih= cement olending relative ~m~ arnoun'~ of ,...~,,,~,,~ .... ~'~'*'"" '* " " ' and mixing operation. We are requesting the Commission determine under 20 AAC 25.080. that this washdown water is a waste associated with the act of drilling a well and permitted for annular disposal. Secondly, ARCO requests permission to transport cement washdown water from the Colville exploratory operations to approved disposal annuli in the Kuparuk River Unit. This waiver is required since cement washdown water is not exempt, and thus cannot be disposed of in Class 2 injection wells in the Kuparuk River Unit. It is also required because the Colville Delta exploratory wells do not have annuli available for annular disposal operations. Normally, the amount of cement washdown water generated for any individual cement job is less than 250 bbls, although it an vary widely depending upon the operation. ARCO Alaska, Inc. is a Subsidiary of AllanricRichfieldCompa~y The wells generating cement washdown water needing a waiver this winter include: Bergschrund #2 Bergschrund #2A Alpine #3 Nanuk #1 Neve #1 Neve #1A Temptation #1 The destination of the waste would be the permitted annuii of the we!is currently being drilled within the KRU by Parker Rig #245. The cement washdown water would be pumped into the permitted annulus that Parker Rig 245 was connected to at that time. Again, the permitted well would be within the Kuparuk River Unit. We appreciate your consideration of this request. If you have any questions or require any additional information on this matter, please contact me at 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. TONY KNOWLE$, ~OVE~NOR 3001 PCRCUP!NE DRIVE ANCHORAGE. ALASKA 99501~3192 ,=NONE: (907) 27~14.?,3 FAX: (SO'Z) 276.-7542 Eebrum?29, 1996 WilIi~,m S. Isaacson Drilling E~ucer Ku~a_mk Drill Ske Development P.O. Box I00Z60 Anchorage, 'AK 99510-,3360 Re: request for waiver to 20 ~kC 25.080(d)(4), .,kn.n~ Di~osal ofDriiling Wasr~ Dear M_r. Isa. acson The Comm/ssion hzs received your re4ues~ for vmiver to 20 AAC 25.080(d)(4), whir& annular disposal of drilling wasr~ from drilling operations in we~ on the same pad. ThC request for waiver is intended for wells I Q-2 ! and ZX-!7. ARCO seek authoriz~on to inje~ drilling wa_~ fi'om the 4 3f4' hoie section ofwe~ IQ-21 and 2X-I7 into thc annulus ora w~LI az either 3H or ~.T pad. Thc 4 314" s~ction ofiM lQ-21 and ZX- 17 wells will be drilled by either Nordic ~ 1 or a coiled mbmg oniz (CTU). Although_ ann~ ar~ avaiiabie for inje~on purposes on the I Q and 2X pads, neither Nordic #t nor th~ CTU have the ability, to grind and inje= tunings for annular di~osal purposes. C, u2d and inje= cagabiliry is avaiiabl~ on Parker 245, wkich is driili,g on the 3H and 3,F pads. f~ 1 ARCO has indicamd that a Class II ciisoos=t well will ~o be available for use 6aring ~e above mention~ driiling ope,'-,~ions. Pies. se be advis~ thaz in addition to the ~-memz washdown mentioned in your reque~, other wastes gene,'-ded &ndng driiling ac-d~ that ar~ ~prav~ for ,~. ? ~;~:cs~. ~2.y ,-:., ~ be ~rov~..~ :St fZ..¢gcsai ~ a Cla~s 17 disposal wcH. Thc Commission Mmby grants a waiver, to ARCO M~ka, Thc. for wells IQ-21 and 2X-17 fi.om the requirements of 20 AAC 25.080(d)(4). Sincere!y, '- Tu~Babcock Commissicn~ . .--,-L PERMIT CHECKLIST FIELD & POOL ,Mt..,,', ¢~,.. COMPANY INIT CLASS/'~, ~/, ~ GEO', m~A ~C PROGRAM~: e der [] redrll [] serv [] wellbore seg [] ON/OFF SHO ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. .(Y_~ N Lease number appropriate ............... ~ N Unique well name and number .............. ~ N Well located in a defined pool .............. Y Well located proper distance from drlg unit boundary..~ N Well located proper distance from other wells ..... ~ Y~ N Sufficient acreage available in drilling unit ..... ~ Y~ N If deviated, is wellbore plat included ........ Y~ N Operator only affected party ............. ~ ~ N Operator has appropriate bond in force ........ Permit can be issued without conservation order .... ~ N Permit can be issued without administrative approval..( N Can permit be approved before 15-day wait ....... < Y_~ N ENGINEERING REMARKS APPR DATE 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.._~.- 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... O N 26. BOPE press rating adequate; test to ~62~ psig. Y N 27. Choke manifold complies w/API RP-53 (May 84) ...... Y~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of N2S gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones .... 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) . . .~4~..~z 34. Contact name/phone for weekly progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: m '~\cheklist rev 11195 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. * ALASKA COMPUTING CENTER * . . ****************************** * ............................ * ....... SCHLUMBERGER * ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : NANUK #1 FIELD NAME : WILDCAT BOROUGH : NORTH SLOPE STATE : ALASKA APINUMBER : 50-103-20238-00 REFERENCE NO : 96098 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 1~ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/19 ORIGIN · FLIC REEL NAME : 96098 CONTINUATION # : PREVIOUS REEL : C024FiENT : ARCO ALASKA INC., WILDCAT, NANUK #1, API #50-103-20238-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/19 ORIGIN · FLIC TAPE NAME : 96098 CONTINUATION # : 1 PREVIOUS TAPE : COM~4ENT · ARCO ALASKA INC., WILDCAT, NANUK #1, API #50-103-20238-00 TAPE HEDJ~ER WILDCAT OPEN HOLE WIRELINE/MWD LOGS r/ELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL : FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: NANUK #1 501032023800 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES ! 9 -APR- 96 WELL CASING RECORD 1ST STRING 2ND STRING RUN1 R~ 2 RUN3 96098 96098 96098 NICOLS NICOLS NICOLS/BAILEY VANKOOTEN 19 liN 5E 2627 868 38. O0 36.50 9.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 1788.0 8.500 LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 19-APR-1996 13.~ 3RD STRING PRODUCTION STRING THIS TAPE CONTAINS MODIFIED LDWG FORMATTED DATA FOR ANADRILL MEASUREMENT WHILE DRILLING CDR & CDN, AS WELL AS SCHLUMBERGER WIRELINE DIPOLE SONIC IMAGER (DAS), LITHO-DENSITY (LDT), THERMAL & EPITHERMAL COMPENSATED NEUTRON (CNTG) AND GAM~A RAY (GR). THE FORMAT OF THIS TAPE WAS SPECIFIED BY WAYNE CAMPAIGN OF ARCO. GR FROM CDR WAS DEPTH-MATCHED TO GR FROM DIPOLE SONIC AND ALL OTHER CDR CURVES WERE SHIFTED THE SAME. TNPH AND RHOB FROM CDN WAS SHIFTED THE SAME AS ABOVE, BUT ALSO SLIGHTLY ADJUSTED TO MATCH WIRELINE TNPH AND RHOB. OTHER CDN CURVES ADJUSTED THE SAME AS RHOB. Please direct any questions to Jim Kohring, GeoQuest Anchorage, (907) 563-1594. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .00! SERVICE : FLIC VERSION · O01CO1 DATE · 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged DEPTH INCREM~ENT : O . 5000 FILE SUM~UL~Y LDWG TOOL CODE START DEPTH GAiV~4A RAY/CDR 99.0 RESISTIVITY/CDR 99.0 NEUTRON/CDN 1714.0 DENSITY/CDN 1720. 0 $ BASELINE CURVE FOR SHIFTS: GR.DAS CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 7523.5 7523.0 7510.5 7510.0 STOP DEPTH .......... 7574.0 7574.0 7514.0 7520.0 .......... EQUIVALENT UNSHIFTED DEPTH CDR TNPH.MWD RHOB.MWD 88884.5 88884.5 88884.0 7519.5 7519.5 7519.5 7505.5 7506.0 7506.0 LIS Tape Ver~lcation Listing Schlumberger Alaska Computing Center 19-APR-1996 13._ _ PA GE: 7505.5 7490.0 7471.0 7468.5 7438.0 7381.5 7380.5 7352.5 7330.0 7276.0 7275.0 7267.5 7218.5 7217.5 7204.0 7203.0 7198.0 7197.5 7179.5 7166.5 7165.5 7155.5 7141.5 6987.0 6977.5 6972.5 6935.0 6900.5 6883.0 6837.0 6821.0 6804.5 6765.5 6762.5 6750.0 6742.5 6729.0 6721.5 671 O. 5 6698.5 6690.0 6672.0 6662.5 6643.0 6635 5 6604 5 6572 5 6568 5 6564 0 6547 5 6547.0 6540.0 6530.0 6522.5 6515.0 7501.0 7482.5 7464.0 7431.0 7372.5 7345.0 7322.5 7269.0 7261.0 7211.0 7196.5 7191.0 7173.0 7159.5 7134.5 6969.5 6964.0 6927.0 6891.0 6872.5 6829.0 6812.5 6796.5 6757.0 6743.5 6735.5 6724.0 6714.5 6703.5 6693.0 6683.5 6666.5 6656.5 6636.5 6630.0 6599.0 6568.0 6562.0 6557.0 6540.5 6533.5 6523.5 6516.0 6508.5 7501.0 7482.5 7464.0 7431.0 7372.5 7345.0 7321.5 7269.0 7261.0 7211.0 7196.5 7191.0 7173.0 7159.5 7149.5 7134.5 6969.5 6964.0 6927.0 6891.0 6872.5 6829.0 6812.5 6795.5 6757.0 6743.5 6735.5 6724.0 6714.5 6703.5 6693.0 6683.5 6666.5 6656.5 663 6.5 6630.0 6599.0 6568.0 6562.0 6557.0 6540.0 6533.5 6523.5 6516.0 6508.5 7501.0 7482.5 7464.0 7431.0 7372.5 7345.0 7321.5 7269.0 7261.0 7211.0 7196.5 7191.0 7173.0 7159.5 7148.0 7134.5 6979.5 6969.5 6964.0 6927.0 6892.5 6872.5 6829.0 6812.5 6795.5 6757.0 6743.5 6735.5 6724.0 6714.5 6703.5 6693.0 6683.5 6666.5 6656.5 663 6.5 6630.0 6599.0 6568.0 6562.0 6557.0 6540.0 6533.5 6523.5 6516.0 6508.5 LIS Tape Vez~ication Listing Schlumberger Alaska Computing Center 19-APR-1996 13._ PAGE: 6504.0 6453.0 6436.0 6422.0 6402.0 6369.5 6360.0 6340.0 6329.5 6328.5 6309.0 6297.5 6296.0 6285.5 6263.5 6253.0 6242 5 6225 5 6208 5 6193 0 6169 5 6163 0 6153 0 6152.5 6103.5 6089.5 6072.0 6065.0 6064.5 6036.5 5990.5 5969.0 5948.5 5936.5 5902.0 5889.5 5875.5 5835.0 5699.0 5663.0 5644.0 5618.0 5600.5 5567.0 5561.0 5542.0 5536.5 5492.0 5487.5 5468.0 5442.5 5429.0 5422.0 5411.0 5378.0 6496.5 6447.5 6429.5 6416.5 6395.0 6362.5 6353.5 6335.5 6323.5 6301.5 6289.5 6277.5 6256.5 6244.5 6233.5 6217.5 6200.5 6185.0 6163.5 6155.5 6145.0 6096.5 6082.0 6066.0 6057.5 6030.0 5982.0 5961.0 5942.5 5929.0 5895.0 5882.5 5869.5 5829.0 5691.0 5657.5 5636.0 5609.5 5593.5 5557.5 5551.5 5533.0 5528.5 5484.0 5480.5 5460.0 5434.5 5421.0 5415.5 5402.5 5369.0 6496.5 6447.5 6429.5 6416.5 6395.0 6362.5 6353.5 6335.5 6323.5 63 Oi. 5 6289.5 6277.5 6256.5 6244.5 6233.5 6217.5 6201.0 6185.0 6163.5 6155.5 6145.0 6096.5 6082.0 6066.0 6057.5 6030.0 5982.0 5961.0 5942.5 5929.0 5895.0 5882.5 5869.5 5829.0 5691.0 5657.5 5636.0 5609.5 5593.5 5557.5 5551.5 5533.0 5528.5 5484.0 5480.5 5460.0 5434.5 5421.0 5414.0 5402.5 5369.0 6496.5 6447.5 6429.5 6416.5 6395.0 6362.5 6353.5 6335.5 6323.5 6301.5 6289.5 6277.5 6256.5 6244.5 6233.5 6217.5 6201.0 6185.0 6162.5 6155.5 6145.0 6096.5 6082.0 6066.0 6057.5 6030.0 5982.0 5961.0 5940.0 5929.0 5895.0 5882.5 5869.5 5829.0 5691.0 5657.5 5636.0 5609.5 5593.5 5557.5 5551.5 5533.0 5528.5 5484.0 5480.5 5460.0 5434.5 5421.0 5413.5 5402.5 5369.0 LIS 'Tape Ve~_~cation Listing Schlumberger Alaska Computing Center 19-APR-1996 13... PAGE: 5362 0 5314 0 5308 0 5301 0 52895 5281 5 5280 5 5279,5 5275.5 5264.0 5240.5 5181.0 5142.0 5103.5 5073.0 5071.5 5027.0 5007.0 4979.0 4832.0 4811.5 4810.5 4752 5 4674 0 4665 5 4658 0 4615 5 4567 5 4524 0 4523~0 4377.5 4342.0 4293.5 4292.5 4250.0 4219.0 4208.5 4195.0 4158.5 4125.0 4103.0 4077.5 4055.0 4027.0 4026.0 4001.5 3963.5 3955.0 3943.0 3929.5 3928.0 3922.5 3896.5 3892.5 3888.5 5355.5 5311.0 5304.5 5297.0 5281.5 5271.5 5266.5 5254.0 5231.5 5172.0 5133.0 5096.0 5061.5 5020.5 5001.0 4972.5 4825.5 4803.5 4742.5 4665.5 4656.5 4649.0 4608.5 4560.0 4515.0 4370.5 4336.0 4284.5 4246.5 4213.5 4200.0 4187.0 4151.5 4120.0 4099.5 4073.5 4050.0 4021.0 3998.0 3960.0 3950.0 3938.0 3919.0 3893.5 3888.5 3884.5 5355.5 5311.0 5304.5 5297.0 5281.5 5271.5 5266.5 5254.0 5231.5 5172.0 5133.0 5096.0 5061.5 5020.5 5001.0 4972.5 4825.5 4803.5 4742.5 4665.5 4656.5 4649.0 4608.5 4560.0 4515.0 4370.5 4336.0 4284.5 4246.5 4213.5 4200.0 4187.0 4151.5 4120.0 4099.5 4073.5 4050.0 4021.0 3997.0 3960.0 3950.0 3938.0 3922.0 3919.0 3893.5 3888.5 3884.5 5355.5 5311.0 5304.5 5297.0 5281.5 5272.0 5266.5 5254.0 5231.5 5172.0 5133.0 5096.0 5063.0 5020.5 5001.0 4972.0 4825.5 4803.5 4742.5 4665.5 4656.5 4649.0 4608.5 4560.0 4515.0 4370.5 4336.0 4284.5 4246.5 4213.5 4200.0 4187.0 4151.5 4120.0 4099.5 4073.5 4050.0 4021. 0 3997. 0 3960. 0 3950.0 3938.0 3926. 0 3919.0 3893.5 3888.5 3884.5 LIS Tape Ver~cation Listing Schlumberger Alaska Computing Center Ig-APR-1996 13.__ PAGE: 3884.5 3857.0 3838.5 3822.5 3801.5 3779.0 3730.0 3729.5 3719.0 3711.0 3650.0 3638.0 3625.5 3582.5 3546.5 3541.0 3527.0 3504.5 3484.0 3416.5 3410.0 3335.5 3309.0 3307 0 3236 0 3233 5 3190 0 3107 5 3107 0 3089.5 3051.0 3032.0 3019.0 3018.5 2986.5 2969.5 2924.0 2923.0 2906.0 2877.5 2846.0 2826.5 2825 5 2785 5 2768 0 2710 0 2650 5 2629 5 2592 0 2473,0 2470.0 2463.0 2450.5 2445.5 2430.5 3853.0 3835.5 3816.5 3799.0 3777.0 3728 0 3718 0 3709 5 3648 5 3636 0 3624 0 3580.5 3545.0 3538.5 3526.0 3496.5 3475.0 3409.5 3402.0 3328.5 3299.0 3229.0 3181.0 3098.5 3079.5 3044.0 3026.5 3011.0 2979.5 2961.0 2916.5 2897.5 2969.5 2838.5 2817.0 2778.0 2759.5 2703.0 2644.5 2623.5 2585.5 2465.0 2457.5 2439.0 3878.5 3853.0 3835.5 3816.5 3799.0 3777.0 3726.0 3718.0 3709.5 3648.5 3636.0 3624.0 3580.5 3545.0 3538.5 3526.0 3496.5 3475.0 3409.5 3402.0 3328.5 3299.0 3229.0 3181.0 3098.5 3079.5 3044.0 3026.5 3011.0 2979.5 2961.0 2916.5 2897.5 2869.5 2838.5 2817.0 2778.0 2759.5 2703.0 2644.5 2623.5 2585.5 2465.0 2457.5 2439.0 2425.0 3878.5 3853.0 3835.5 3816.5 3799.0 3777.0 3726.0 3718.0 3709.5 3648.5 3636.0 3624.0 3580.5 3545.0 3538.5 3526.0 3496.5 3475.0 3409.5 3402.0 3328.5 3299.0 3229.0 3181.0 3098.5 3079.5 3044.0 3026.5 3011.0 2979.5 2961. 0 2916. 0 2897.5 2869.5 2838.5 2817. 0 2778. 0 2759.5 2703. 0 2644.5 2623.5 2585.5 2465. 0 2457.5 2439. 0 2425. 0 LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 13.-~ PAGE: 2426.0 2419.0 2419.0 2412.5 2408.5 2400.5 2395.5 2387.5 2384.0 2373.5 2371.5 2363.0 2344.5 2343.0 2335.5 2318.5 2310.0 2317.0 2296.0 2287.5 2258.0 2251.5 2253.0 2246.5 2244.5 2236.5 2229.5 2223.0 2212.0 2211.5 2205.5 2186.5 2181.0 2177.5 2172.0 2170.0 2163.0 2131.5 2126.5 2087.0 2078.0 2075.0 2067.0 2038.5 2031.0 2009.5 2004.0 1989.5 1982.5 1971.0 1970.0 1964.0 1943.0 1938.0 1927.5 1921.0 1915.0 1907.5 1905.0 1895.0 1894.0 1884.0 1877.5 1868.5 1871.0 1861.5 1844.5 1835.5 1839.0 1827.5 1820.0 1799.5 1797.0 1790.0 1752.0 50.0 50.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. CDR 1 CDR 2 CDR 3 CDN 3 GR.DAS 1 DAS 1 LDT 1 CNTG I 2412.5 2401.5 2387.5 2373.5 2363.0 2335.5 2310.0 2286.5 2251.5 2246.5 2236.5 2223.0 2205.5 2181 0 2172 0 2163 0 2126 5 2078 0 2067 0 2031 0 2004 0 1982 5 1964 0 1938 0 1921 0 1907 5 1895 0 1884 0 1868 5 1861 5 1835 5 1819.0 1790.0 50.0 PASS NO. ........ 1 1 1 1 2 2 2 2 2402.5 2387.5 2373.5 2363.0 2335.5 2310 0 2286 5 2251 5 2246 5 2236 5 2223 0 2205 5 2181 0 2172 0 2163 0 2126 0 2078 0 2067 0 2031 0 2004 0 1982 5 1964 0 1938 1921 1907 1895 1884 1868 1861 1835 1829 1819 1790 1744.5 50.0 MERGE TOP MERGE BASE 99 264 1791 1791 1791 1791 1791 1791 0 264 0 0 1780 0 0 7574 0 0 7520 0 0 7545 0 0 7560 0 0 7617 0 0 7611 0 LIS-Tape Vez,~ication Listing Schlumberger Alaska Computing Center 19-APR-1996 13 .... PAGE: REFiAPJ&S: MWDDeviation and Hole Azimuth was depth adjusted along with the CDR to the Open Hole wireline GR. Bottom hole deviation is less than one degree. DT Shear curve DTSH was reprocessed at AKICS. MWD Field Remarks: Tool Numbers RGS022 &NDS057 logged from ll-19MAR-96. CDR/GR was logged while drilling over Bit runs #1 and #2 down to 1800'. CDR/GR/CDN was then logged while drilling down to TD @7630'. ******************* RUN1 CDR 844 ********************** Res to Bit:12.07 ft; GR to Bit:22.49 ft; Survey to Bit:41.82 ft. Drilled interval 80' to 270'. ******************* RUN2 CDR 844 ********************** Res to Bit:12.07 ft; GR to Bit:22.49 ft; Survey to Bit:41.82 ft. Drilled interval 270' to 1800'. ******************* RUN3 CDR/CDN ********************** Res to Bit:51.68 ft; GR to Bit:62.10 ft; Neut to Bit: 111.69 ft. Dens to Bit: 104.71 ft. Survey to Bit: 81.62 ft. Drilled interval 1800' to 7630'. Rm= 2.26 @68degf; Rmf=2.11 @68degf. Maximum Recorded Temp 155 degf. Wireline Field Remarks: LDT/CNT logged IN COMBINATION W/DSI 19-MAR-96. 1.5" FIN STANDOFFS USED TO CENTRALIZE DSI. SAND MATRIX, ~DEN = 2.65 G/C3. SLOWNESS RESULTS PRESENTED REPRESENT BEST ESTIMATE MADE IN REAL TIME. ADDITIONAL PROCESSING AND QUALITY CONTROL INCLUDING A FINAL SLOWNESS ESTIMATE PROViDED BY GEOQUEST DATA CENTER IN ANCHORAGE. Time Circulation Stopped 0800 19-MAR-96 Time Wireline Logger On Bottom 19:00 19-MAR-96 Rm= 2.16 @68degf; Rmf=l.28 @68degf; Rmc=2.16 @68degf. Rm ~VlRT= 1.017 @lSdegf; Rmf ~ViRT= 0.603 @152 degf. LSNDmud; 10.3 lb~g; Visc 45S; FLoss 4.2C3; PH 8.8 Maximum Recorded Temp 152 degf. Service Order Number 630381 Tool Numbers A24~-AA 712 SGC-SA 455 DSST-A 8026 CNC-GA 63 C~-G 67 PGD-G 282 DRS-C 4824 ECH-MKA 789 PDH-L 2846 $ LIS FORMAT DATA LIS Tape Vez_~ication Listing Schlumberger Alaska Computing Cen~er 19-APR-1996 13._~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 168 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 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 630381 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD Otff4M630381 O0 000 O0 0 1 1 I 4 68 0000000000 RP MWD OH~ff4630381 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHFIM 630381 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OPiMM 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD Otff4~630381 O0 000 O0 0 1 1 1 4 68 0000000000 ROP M~FD FPHR 630381 O0 000 O0 0 1 1 1 4 68 0000000000 FET M~FD HR 630381 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DEV M~FD DEG 630381 O0 000 O0 0 1 1 1 4 68 0000000000 AZ MWD DEG 630381 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB M~ G/C3 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630381 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630381 O0 000 O0 0 1 ! 1 4 68 0000000000 CALNMWD IN 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMCWD IN 630381 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 630381 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 630381 O0 000 O0 0 1 1 1 4 68 0000000000 SCRA DAS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 PR DAS 630381 O0 000 O0 0 ! 1 1 4 68 0000000000 GR DAS GAPI 630381 O0 000 O0 0 1 i 1 4 68 0000000000 MRES DAS OtL~M 630381 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 630381 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 630381 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 630381 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Ve;__ication Listing Schlumberger Alaska Computing Center 19-APR-1996 13. . PAGE: 10 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) O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 630381 DRHO SDN G/C3 630381 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 630381 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 630381 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 630381 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 630381 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 630381 O0 000 O0 0 I 1 1 4 68 0000000000 ENRA CNTG 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 ChiC CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 630381 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. VRP.MWD GR.MWD DRHO.MWD NPHI.MWD PR.DAS TENS. DAS PEF. SDN CPHI. CNTG NRA T . CNT G CFEC. CNTG 7636.500 -999.250 -999.250 -999 250 -999 250 -999 250 2215 000 -999 250 -999 250 -999 250 -999.250 RA.MWD -999.250 RP.MWD DER.MWD -999.250 ROP.MWD DEV. MWD -999.250 AZ.MWD PEF.MWD -999.250 CALN. MWD DT.DAS -999.250 DTSH.DAS GR.DAS -999.250 ~RES.DAS TEND.DAS 838.611 RHOB.SDN CAL1.SDN -999.250 NPHI.CNTG FCNT. CNTG -999.250 NCNT. CNTG ENRA.CNTG -999.250 CFTC. CNTG CNEC. CNTG -999.250 DEPT. 82.000 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD 11.875 DEV. MWD 0.064 AZ.MWD DRHO.MWD -999.250 PEF.MWD -999.250 CALN.MWD NPHI.MWD -999.250 DT. DAS -999.250 DTSH.DAS PR.DAS -999.250 GR.DAS -999.250 MRES.DAS TENS.DAS -999.250 TEND.DAS -999.250 RHOB.SDN PEF. SDN -999.250 CAL1.SDN -999.250 NPHI.CNTG CPHI.CNTG -999.250 FCNT. CNTG -999.250 NCNT. CNTG NRAT. CNTG -999.250 ENRA.CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 CNEC. CNTG -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 0 908 -999 250 -999 250 -999.250 -999.250 VRA . MWD FET.MWD RHOB. MWD DCAL . FfWD SCRA. DAS MTEM. DAS DRHO. SDN ENPH. CNTG CRA T. CNTG CNTC. CNTG -999.250 VRA.MWD -999.250 FET.MWD 129.054 RHOB.MWD -999.250 DCAL.MWD -999.250 SCRA.DAS -999.250 MTEM. DAS -999.250 DRHO.SDN -999.250 ENPH. CNTG -999.250 CRAT. CNTG -999.250 CNTC. CNTG -999.250 -999.250 -999.250 -999.250 -999.250 152.306 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** MAY 0 1996 LIS Tape Ve~__ication Listing Schlumberger Alaska Computing Center 19-APR-1996 13. ~ PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/04/19 ORIGIN · FLIC TAPE NAME · 96098 CONTINUATION # : 1 PREVIOUS TAPE : COMPIENT : ARCO ~ALASKA INC., WILDCAT, NANUK #1, API #50-103-20238-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ' 96/04/19 ORIGIN : FLIC REEL NAME : 96098 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., WILDCAT, NANUK #1, API #50-103-20238-00 t996 Schlumberger * S CHLUMBERGER * ***************************** SCHLUMBERGER WELL SERVICES ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 907/562-2654 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR RFT FIELD TAPE Company Name ARCO ALASKA INC. Well Name NANUK #1 Field Name WILDCAT County NORTH SLOPE State ALASKA Service Order Number 630381 Date Acquired 20-MAR-96 Run Number ONE Job Number Date Processed Files Included 96098 22-APR-96 RFT FIELD ACQUIRED DATA Schlumberger * S CHLUMBERGER * SCHLUMBERGER WELL SERVICES ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHOR3~GE, ALASKA 99518 907/562-2654 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR RFT FIELD TAPE Company Name ~LRCO ALASKA INC. Well Name NANUK #1 Field Name WILDCAT County NORTH SLOPE State ALASKA Service Order Number 630381 Date Acquired 20-MAR-96 Run Number ONE Job Number Date Processed Files Included 96098 22-APR-96 RFT FIELD ACQUIRED DATA Schlumberger LIST Command Listing KEY I LIST SUMMARY 5~NEMONICS Summary output is created by LIST/SUMMARY summaries written for Logical LIS structures: FILE (Abbrev: F) LIS logical file info TAPE (Abbrev: T) LIS logical tape info REEL (Abbrev: R) LIS logical reel info and for the entire LIS/A input logical unit: LU (Abbrev: L) LIS/A logical unit info The field labels appear on some or all of these summaries, as indicated by the abbrev, on right. Summary Field Labels: REELS Number of logical reels on (L ) TAPES Number of logical tapes on (LR ) FILES Number of logical files on (LRT) #PR Number of physical records (LRTF) ~LR Number of logical records (LRTF) #DR Number of data records ( F) #ENC Number of encrypted records ( F) #FM Number of data frames ( F) PI Primary index channel name ( F) PI 1/NITS Primary index units mnemonic ( F) MAXPI Maximum primary index value ( F) MINPI Minimum primary index value ( F) NOTE - DEPTH OF PRESSI/RE TEST IS RECORDED AS CHA/~NEL FDEP. FDEP IS ALSO LISTED IN "CONS" TABLE ON TESTS WHERE THE CSU TABLES WERE DUMPED TO TAPE. FOR FORMATION TEST FILES, "DEPT" INCLUDED IN THESE LISTINGS DOES NOT REFER TO DEPTH OF MEASUREMENT BUT IS AN INTERNAL COUNTER USED WHEN MEASURING IN TIME. IN AN ATTEMPT TO KEEP THIS LISTING TO A REASONABLE LENGTH, ONLY SPECIFIC CHANNELS AND CONSTANTS ARE LISTED. THIS LISTING DOES NOT INCLUDE MB_NY OF THE CHA/~NELS AND CONSTANTS INCLUDED ON THE FIELD TAPE. Schlumberger LIST $1$DIA2:[96098.RFT]RFTFLD.LIS;1 22-AP~ ~6 08:26:33 ** REEL HEADER ** SERVICE NAME : RFTB DATE : 96/03/20 ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 96/03/20 ** FILE HEADER ** FILE NAME : RFTB .020 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set ! type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 28 1 1 4 68 0000000000 0 28 1 1 4 68 0000000000 Data record type 0 DEPT 773520 .lin 6446. FT 1964.7408 M ETIM 0. GR 91.34328 ** FILE TR31ILER ** FILE NAME : RFTB .020 SERVICE NAME : DEPTH- VERSION ~ : 7C0-428 DATE · 96/03/20 MAX. REC. LEN. : 8192 FILE SUNMARY ~LR #PR ~ENC #DR #FM PI PI UNITS MAXPI MINPI 26 59 0 3 239 DEPT .lin 773520 759240 DEPT F 6446. 6327. DEPT M 1964.7408 1928.4696 ** FILE HEADER ** FILE NAME : RFTB .021 SE~;ICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 3 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 30 1 1 4 68 0000000000 0 30 1 1 4 68 0000000000 Data record type 0 DEPT 759180 .lin 6326.5 FT 1928.3172 M ETIM 0. GR 112.8358 ** FILE TRAILER ~* FILE NAME : RFTB .021 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY ~LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 32 65 0 5 483 DEPT .lin 759180 730260 DEPT F 6326.5 6085.5 DEPT M 1928.3172 1854.8604 ** FILE HEADER ** FILE NAME : RFTB .022 SERVICE NAME : DEPTH- VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 5 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV L/NIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 32 1 1 4 GR RFTB GAPI 0 32 1 1 4 68 0000000000 68 0000000000 Data record type 0 DEPT 762120 .lin 6351. FT 1935.7848 M ETIM 0. GR 120. ** FILE TRAILER ** FILE NAME ' k~'B .022 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 32 65 0 5 528 DEPT .lin 762120 730500 DEPT F 6351. 6087.5 DEPT M 1935.7848 1855.47 ** FILE HEADER ** FILE NAME : RFTB .023 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 7 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 34 1 1 4 68 0000000000 0 34 1 1 4 68 0000000000 Data record type 0 DEPT 771180 .lin 6426.5 FT 1958.7972 M ETIM 0. GR 112. ** FILE TRAILER ** FILE NAME : RFTB .023 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR ~ENC #DR #FM PI PI UNITS MAXPI MINPI 33 66 0 6 617 DEPT .liN 771180 734220 DEPT F 6426.5 6118.5 DEPT M 1958.7972 1864.9188 ** FILE HEADER ** FILE NAME : RFTB .024 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 9 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 36 1 1 4 68 0000000000 0 36 1 1 4 68 0000000000 Data record type 0 DEPT 762720 .lin 6356. FT 1937.3088 M -- ETIM 0. GR 70.90909 -- -- -- ** FILE TRAILER ** FILE NAME : RFTB .024 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 32 65 0 5 516 DEPT .lin DEPT F DEPT M 762720 731820 6356. 6098.5 1937.3088 1858.8228 ** FILE HEADER ** FILE NAME : RFTB .049 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 11 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .liN 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVI~E API API API API FILE NUMB N~.,~ SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAP I 63 621 0 86 1 1 4 68 0000000000 0 86 1 1 4 68 0000000000 Data record type 0 DEPT 882060 .lin 7350.5 FT 2240.4324 M ETIM 0. GR 65.45454 ** FILE TRAILER ** FILE NAME : RFTB .049 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 30 63 0 3 255 DEPT .lin 882060 866820 DEPT F 7350.5 7223.5 DEPT M 2240.4324 2201.7228 ** FILE HEADER ** FILE NAME : RFTB .050 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 13 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .liN 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVI~.' API API API API FILE NUMB NL~ SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NIIMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 88 1 1 4 68 0000000000 0 88 1 1 4 68 0000000000 Data record type 0 DEPT 878400 .lin 7320. FT 2231.136 M ETIM 0. GR 38.18182 ** FILE TRAILER FILE NAME : RFTB .050 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 29 62 0 2 194 DEPT .lin 878400 866820 DEPT F 7320. 7223.5 DEPT M 2231.136 2201.7228 ** FILE HEADER ** FILE NAME - RFTB .051 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 15 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 76 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .liN 65 4 11 107 66 1 12 -999.25 68 4 13 1 66 1 14 .liN 65 4 15 73 66 1 16 1 .... 66 1 ......... 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 90 1 1 4 68 0000000000 0 90 1 1 4 68 0000000000 Data record type 0 DEPT 878520 .lin 7321. FT 2231.4408 M ETIM 0. GR 70.90909 ** FILE TP~AILER ** FILE NAME : RFTB .051 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 34 67 0 7 732 DEPT .lin 878520 834660 DEPT F 7321. 6955.5 DEPT M 2231.4408 2120.0364 ** FILE HEADER ** FILE NAME · RFTB .067 SERVICE NAME : DEPTH- VERSION ~ · 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 17 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 178 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 46 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S GR RFTB GAPI 63 621 0 116 1 1 4 68 0000000000 0 116 1 1 4 68 0000000000 Data record type 0 DEPT 882060 .lin 7350.5 FT 2240.4324 M ETIM 0. GR 80. ** FILE TRAILER ** FILE NAME : RFTB .067 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 37 70 0 10 445 DEPT .lin 882060 855420 DEPT F 7350.5 7128.5 DEPT M 2240.4324 2172.7668 ** FILE HEADER ** FILE NAME : RFTB .073 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 19 type 64EB object 0 ENTRY VALUE REPCODE SIZE 0 66 1 0 66 1 178 79 2 1 66 1 1 66 1 0 73 4 IN 65 2 60 73 4 9 .lin 65 4 11 46 66 1 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NLIMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 121 1 1 4 GR RFTB GAPI 0 121 1 1 4 68 OO0000OOOO 68 0000000000 Data record type 0 DEPT 852900 .lin 7107.5 FT 2166.366 M ETIM 0. GR 69.33333 ** FILE TRAILER ** FILE NAME : RFTB .073 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 35 68 0 8 332 DEPT .lin 852900 833040 DEPT F 7107.5 6942. DEPT M 2166.366 2115.9216 ** FILE HEADER ** FILE NAME : RFTB .075 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN.: 8192 Data format specification record Listing of set 21 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 178 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 46 66 1 12 -999'.'25- 68 4 13 1 66 1 14 .liN 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 123 1 1 4 GR RFTB GAPI 0 123 1 1 4 68 0000000000 68 0000000000 Data record type 0 DEPT 766980 .lin 6391.5 FT 1948.1292 M ETIM 0. GR 147.2727 ** FILE TRAILER ** FILE NAME : RFTB .075 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY -- ~LR #PR #ENC ~DR #FM PI PI UNITS MAXPI MINPI -- 38 71 0 11 479 DEPT .lin 766980 738300 DEPT F 6391.5 6152.5 DEPT M 1948.1292 1875.282 ** FILE HEADER ** FILE NAME · RFTB .019 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE · 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 23 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NI3MB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 26 1 1 4 SGP RFTB PSI 81 400 0 26 1 1 4 PONE RFTB 81 400 0 26 1 1 4 PTEN RFTB 81 400 0 26 1 1 4 PHUN RFTB 81 400 0 26 1 1 4 PTHO RFTB 81 400 0 26 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 1493684 5MS ETIM 0. SGP -1.408447 PONE -1. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 1733684 5MS ETIM 120. SGP -1.74361 PONE -1. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 1973684 5MS ETIM 240. SGP -1.84066 PONE -1. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 2213684 5MS ETIM 360. SGP -1.963951 PONE -1. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 2453684 5MS ETIM 480. SGP -2.138803 PONE -2. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 2693684 5MS ETIM 600. SGP -2.237276 PONE -2. ~ ...... PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 2933684 .5MS ETIM 720. SGP -2.287155 PONE -2. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 3173684 .5MS ETIM 840. SGP 279.5663 PONE 9. PTEN 7. PHUN 2. PTHO 0. ** FILE TRAILER ** FILE NAME : RFTB .019 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 58 91 0 36 2847 TIME .5MS 1493684 3201284 ** FILE HEADER ** FILE NAME : RFTB .025 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 25 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 38 1 1 4 SGP RFTB PSI 81 400 0 38 1 1 4 PONE RFTB 81 400 0 38 1 1 4 PTEN RFTB 81 400 0 38 1 1 4 PHUN RFTB 81 400 0 38 1 1 4 PTHO RFTB 81 400 0 38 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 9994197 .5MS ETIM 0. SGP 3309.19 PONE 9. PTEN 0. PHUN 3. PTHO 3. Data record type 0 TIME 10234197 .5MS ETIM 120. SGP 2722.364 PONE 2. PTEN 2. PHUN 7. PTHO 2. Data record type 0 TIME 10474197 .5MS ETIM 240. SGP 2722.672 PONE 2. PTEN 2. PHIIN 7. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .025 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR ~PR #ENC #DR ~FM PI PI UNITS MAXPI MINPI 39 72 0 14 1091 TIME .5MS 9994197 10648197 ** FILE HEADER ** FILE NAME : RFTB .026 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 27 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NIIMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 40 1 1 4 SGP RFTB PSI 81 400 0 40 1 1 4 PONE RFTB 81 400 0 40 1 1 4 PTEN RFTB 81 400 0 40 1 1 4 PHUN RFTB 81 400 0 40 1 1 4 PTHO RFTB 81 400 0 40 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 11332542 .5MS ETIM 0. SGP 3310.279 PONE 0. PHUN 3. PTHO 3. PTEN 1. Data record type 0 TIME 11572542 .5MS ETIM 120. SGP 3309.92 PONE 9. PHUN 3. PTHO 3. PTEN 0. Data record type 0 TIME 11812542 .5MS ETIM 240. SGP 45.18312 PONE 5. PHUN 0. PTHO 0. PTEN 4. ** FILE TRAILER ** FILE NAME : RFTB .026 SERVICE NAME : ST~-~TIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC ~DR #FM PI PI UNITS MAXPI MINPI 40 73 0 15 1157 TIME .5MS 11332542 12026142 ** FILE HEADER ** FILE NAME : RFTB .027 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 29 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 42 1 1 4 SGP RFTB PSI 81 400 0 42 1 1 4 PONE RFTB 81 400 0 42 1 1 4 PTEN RFTB 81 400 0 42 1 1 4 PHUN RFTB 81 400 0 42 1 1 4 PTHO RFTB 81 400 0 42 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 12426208 .5MS ETIM 0. SGP 3308.865 PONE 8. PHUN 3. PTHO 3. PTEN 0. Data record type 0 TIME 12666208 .5MS ETIM 120. SGP 2722.572 PHUN 7. PTHO 2. PONE 2. PTEN 2. Data record type 0 TIME 12906208 .5MS ETIM 240. SGP 3308.281 PONE 8. PTEN 0. PHUN 3. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .027 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY ~LR #PR ~ENC ~DR #FM PI PI UNITS MAi{PI MINPI 38 71 0 13 981 TIME .5MS 12426208 13014208 ** FILE HEADER ** FILE NAME : RFTB .028 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 31 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER ~ LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 44 1 1 4 SGP RFTB PSI 81 400 0 44 1 1 4 PONE RFTB 81 400 0 44 1 1 4 PTEN RFTB 81 400 0 44 1 1 4 PHUN RFTB 81 400 0 44 1 1 4 PTHO RFTB 81 400 0 44 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 13385447 .5MS ETIM 0. SGP 3310.643 PONE 0. PHUN 3. PTHO 3. PTEN 1. Data record type 0 TIME 13625447 .5MS ETIM 120. SGP 2695.136 PONE 5. PHUN 6. PTHO 2. PTEN 9. Data record type 0 TIME 13865447 .5MS ETIM 240. SGP 2724.237 PONE 4. PHUN 7. PTHO 2. PTEN 2. Data record type 0 TIME 14105447 .5MS ETIM 360. SGP 2726.747 PONE 6. PHUN 7. PTHO 2. PTEN 2. ** FILE TRAILER ** FILE NAME : RFTB .028 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 44 77 0 19 1481 TIME .5MS 13385447 14273447 ** FILE HEADER ** FILE NAME · RFTB .029 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format s~=~ification record Listing of set 33 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER ~ LOG TYP CLS MOD NI3MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 46 1 1 4 SGP RFTB PSI 81 400 0 46 1 1 4 PONE RFTB 81 400 0 46 1 1 4 PTEN RFTB 81 400 0 46 1 1 4 PHI/N RFTB 81 400 0 46 1 1 4 PTHO RFTB 81 400 0 46 1 i 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 14551576 .5MS ETIM 0. SGP 3313.491 PONE 3. PHUN 3. PTHO 3. PTEN 1. Data record type 0 TIME 14791576 .5MS ETIM 120. PHUN 0. SGP -4.531242 PONE -4. PTHO 0. PTEN 0. ** FILE TRAILER ** FILE NAME · RFTB .029 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR ~FM PI PI UNITS MAXPI MINPI -- 34 67 0 9 664 TIME .5MS 14551576 14949376 ** FILE HEADER ** FILE NAME : RFTB .030 SERVICE NAME : STATIO VERSION ~ · 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 35 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NI/MB NI3MB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI/MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 48 1 1 4 SGP RFTB PSI 81 400 0 48 1 1 4 PONE RFTB 81 400 0 48 1 1 4 PTEN RFTB 81 400 0 48 1 1 4 PHUN RFTB 81 400 0 48 1 1 4 PTHO RFTB 81 400 0 48 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 15138041 .5MS ETIM 0. SGP 3313.083 PONE 3. PHUN 3. PTHO 3. PTEN 1. Data record type 0 TIME 15378041 .5MS ETIM 120. SGP 2714.219 PONE 4. PTEN 1. PHUN 7. ...... PTHO 2. ' ..... Data record type 0 TIME 15618041 .5MS ETIM 240. SGP 2729.877 PONE 9. PTEN 2. PHUN 7. PTHO 2. Data record type 0 TIME 15858041 .5MS ETIM 360. SGP 3311.152 PONE 1. PTEN 1. PHUN 3. PTHO 3. ** FILE TRAILER ** FILE NAME · RFTB .030 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI -- MINPI 42 75 0 17 1344 TIME .5MS 15138041 15943841 ** FILE HEADER ** FILE NAME : RFTB .031 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 37 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 '-- ~ 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD ~JMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 50 1 1 4 SGP RFTB PSI 81 400 0 50 1 1 4 PONE RFTB 81 400 0 50 1 1 4 PTEN RFTB 81 400 0 50 1 1 4 PHUN RFTB 81 400 0 50 1 1 4 PTHO RFTB 81 400 0 50 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 16124459 .5MS ETIM 0. SGP 3317.115 PONE 7. PTEN 1. PHUN 3. PTHO 3. Data record type 0 TIME 16364459 .5MS ETIM 120. SGP 3316.808 PONE 6. PTEN 1. PHUN 3. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .031 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 32 65 0 7 557 TIME .5MS 16124459 16458059 ** FILE HEADER ** FILE NAME : RFTB .032 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 39 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 ~- 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE Nq3MB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 52 1 1 4 SGP RFTB PSI 81 400 0 52 1 1 4 PONE RFTB 81 400 0 52 1 1 4 PTEN RFTB 81 400 0 52 1 1 4 PHUN RFTB 81 400 0 52 1 1 4 PTHO RFTB 81 400 0 52 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 16661191 .5MS ETIM 0. SGP 3316.203 PONE 6. PTEN 1. PHUN 3. PTHO 3. Data record type 0 TIME 16901191 .5MS ETIM 120.0005 SGP 2700.594 PONE 0. PTEN 0. PHUN 7. PTHO 2. Data record type 0 TIME 17141791 .5MS ETIM 240.3005 SGP 2811.011 PONE 1. PTEN 1. PHUN 8. PTHO 2. Data record type 0 TIME 17382391 .5MS ETIM 360.6005 SGP 2824.217 PONE 4. PTEN 2. PHUN 8. PTHO 2. Data record type 0 TIME 17622991 .5MS ETIM 480.90-~ PHUN 3. SGP 3315.276 PTHO 3. PONE 5. · .... ~' PTEN 1. ** FILE TRAILER ** FILE NAME : RFTB .032 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE S~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 47 80 0 22 1737 TIME .5MS 16661191 17702792 ** FILE HEADER ** FILE NAME : RFTB .033 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 41 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 54 1 1 4 SGP RFTB PSI 81 400 0 54 1 1 4 PONE RFTB 81 400 0 54 1 1 4 PTEN RFTB 81 400 0 54 1 1 4 PHUN RFTB 81 400 0 54 1 1 4 PTHO RFTB 81 400 0 54 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 18004292 .5MS ETIM 0. SGP 3315.432 PONE 5. PHUN 3. PTHO 3. PTEN 1. Data record type 0 TIME 18244292 .5MS ETIM 120. SGP 2768.89 PONE 8. PTEN 6. PHUN 7. PTHO 2. Data record type 0 TIME 18484292 .5MS ETIM 240. SGP 2809.252 PONE 9. PTEN 0. PHUN 8. PTHO 2. Data record type 0 TIME 18724292 .5MS ETIM 360. SGP 2819.363 PONE 9. PTEN 1. PHUN 8. PTHO 2. Data record type 0 TIME 18964292 .5MS ETIM 480. SGP 3314.87 PONE 4. PTEN 1. PHUN 3. PTHO 3. ** FILE TP~ILER ** FILE NAME : RFTB .033 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 47 80 0 22 1750 TIME .5MS 18004292 19053692 ** FILE HEADER ** FILE NAME : RFTB .034 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 43 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NI/MB NIIMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 56 1 1 4 SGP RFTB PSI 81 400 0 56 1 1 4 PONE RFTB 81 400 0 56 1 1 4 PTEN RFTB 81 400 0 56 1 1 4 PHUN RFTB 81 400 0 56 1 1 4 PTHO RFTB 81 400 0 56 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 19298120 .5MS ETIM 0. SGP 3319.512 PHUN 3. PTHO 3. PONE 9. PTEN 1. Data record type 0 TIME 19538120 .5MS ETIM 120. SGP 2731.062 PONE 1. PHUN 7. PTHO 2. PTEN 3. Data record type 0 TIME 19778120 .5MS ETIM 240. SGP 2747.734 PONE 7. PHUN 7. PTHO 2. PTEN 4. Data record type 0 TIME 20018120 .5MS ETIM 360. SGP 2751.795 PONE 1. PHUN 7. PTHO 2. PTEN 5. ** FILE TRAILER ** FILE NAME · RFTB .034 SERVICE NAME : STATIO VERSION # : 7~0~1428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR ~FM PI PI UNITS MAXPI MINPI 43 76 0 18 1432 TIME .5MS 19298120 20156720 ** FILE HEADER ** FILE NAME : RFTB .035 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 45 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 58 1 1 4 SGP RFTB PSI 81 400 0 58 1 1 4 PONE RFTB 81 400 0 58 1 1 4 PTEN RFTB 81 400 0 58 1 1 4 PHUN RFTB 81 400 0 58 ! 1 4 PTHO RFTB 81 400 0 58 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 20389178 .5MS ETIM 0. SGP 3326.719 PONE 6. PHUN 3. PTHO 3. PTEN 2. Data record type 0 TIME 20629178 .5MS ETIM 120. SGP 16.4701 PONE 6. PHUN 0. PTHO 0. PTEN 1. ** FILE TRAILER ** FILE NAME : RFTB .035 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 33 66 0 8 598 TIME .5MS 20389178 20747378 ** FILE HEADER ** FILE NAME · RFTB .036 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 47 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S SGP RFTB PSI PONE RFTB PTEN RFTB PHUN RFTB PTHO RFTB 63 621 0 60 1 81 400 0 60 1 81 400 0 60 1 81 400 0 60 1 81 400 0 60 1 81 4O0 0 60 1 1 4 1 4 1 4 1 4 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 20896054 .SMS ETIM 0. SGP 3326.275 PONE 6. PHUN 3. PTHO 3. PTEN 2. Data record type 0 TIME 21136054 .5MS ETIM 120. SGP 3325.477 PONE 5. PHUN 3. PTHO 3. PTEN 2. ** FILE TRAILER ** FILE NAME · RFTB .036 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR ~PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 32 65 0 7 487 TIME .5MS 20896054 21187654 ** FILE HEADER ** FILE NAME · RFTB .037 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 49 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NI3MB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI3MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 62 1 1 4 SGP RFTB PSI 81 400 0 62 1 1 4 PONE RFTB 81 400 0 62 1 1 4 PTEN RFTB 81 400 0 62 1 1 4 PHUN RFTB 81 400 0 62 1 1 4 PTHO RFTB 81 400 0 62 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 21366498 .5MS ETIM 0. SGP 3330.817 PONE 0. PTEN 3. PHUN 3. PTHO 3. Data record type 0 TIME 21606498 .5MS ETIM 120. SGP 1000.29 PONE 0. PTEN 0. PHUN 0. PTHO 1. Data record type 0 TIME 21846498 .5MS ETIM 240. SGP -9.185883 PONE -9. PTEN 0. PHUN 0. PTHO 0. Data record type 0 TIME 22086498 .5MS ETIM 360. SGP 2740.769 PONE 0. PTEN 4. PHUN 7. PTHO 2. Data record type 0 TIME 22326498 .5MS ETIM 480. SGP 2758.384 PONE 8. PTEN 5. PHUN 7. PTHO 2. ** FILE TP~AILER ** FILE NAME : RFTB .037 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE S~Y '- .... ~ j' ~LR #PR ~ENC ~DR #FM PI PI UNITS MAXPI MINPI 50 83 0 25 1922 TIME .5MS 21366498 22519098 ** FILE HEADER ** FILE NAME : RFTB .038 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 51 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 64 1 1 4 SGP RFTB PSI 81 400 0 64 1 1 4 PONE RFTB 81 400 0 64 ! 1 4 PTEN RFTB 81 400 0 64 1 1 4 PHUN RFTB 81 400 0 64 1 1 4 PTHO RFTB 81 400 0 64 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 22885884 .5MS ETIM 0. SGP 3330.735 PONE 0. PHUN 3. PTHO 3. PTEN 3. Data record type 0 TIME 23125884 .5MS ETIM 120. SGP 2738.473 PONE 8. PTEN 3. PHUN 7. PTHO 2. Data record type 0 TIME 23365884 .5MS ETIM 240. SGP 2748.873 PONE 8. PTEN 4. PHUN 7. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .038 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 38 71 0 13 1037 TIME .5MS 22885884 23507484 ** FILE HEADER ** FILE NAME : RFTB .039 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 53 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NI3MB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S SGP RFTB PSI PONE RFTB PTEN RFTB PHUN RFTB PTHO RFTB 63 621 0 66 1 81 400 0 66 1 81 400 0 66 1 81 400 0 66 1 81 400 0 66 81 400 0 66 1 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 23795276 .5MS ETIM 0. SGP 3339.394 PHUN 3. PTHO 3. PONE 9. PTEN 3. Data record type 0 TIME 24035276 .5MS ETIM 120. SGP 2742.949 PONE 3. PTEN 4. PHUN 7. PTHO 2. Data record type 0 TIME 24275276 .5MS ETIM 240. SGP 2748.52 PONE 8. PTEN 4. PHUN 7. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .039 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 39 72 0 14 1056 TIME .5MS 23795276 24428276 ** FILE HEADER ** FILE NAME : RFTB .040 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 55 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 ~ i 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 68 1 i 4 SGP RFTB PSI 81 400 0 68 1 1 4 PONE RFTB 81 400 0 68 1 1 4 PTEN RFTB 81 400 0 68 1 1 4 PHUN RFTB 81 400 0 68 1 1 4 PTHO RFTB 81 400 0 68 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 24705938 .5MS ETIM 0. SGP 3343.914 PONE 3. PHUN 3. PTHO 3. PTEN 4. Data record type 0 TiME 24945938 .5MS ETIM 120. SGP 2748.68 PONE 8. PHUN 7. PTHO 2. PTEN 4. Data record type 0 TIME 25185938 .5MS ETIM 240. SGP 2752.267 PONE 2. PTEN 5. PHUN 7. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .040 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 40 73 0 15 1139 TIME .5MS 24705938 25388738 ** FILE HEADER ** FILE NAME : RFTB .041 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 57 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NIIMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD ~ ELEM SAMP ETIM RFTB S 63 621 0 70 1 1 4 SGP RFTB PSI 81 400 0 70 1 1 4 PONE RFTB 81 400 0 70 1 1 4 PTEN RFTB 81 400 0 70 1 1 4 PHUN RFTB 81 400 0 70 1 1 4 PTHO RFTB 81 400 0 70 1 1 4 COD (HEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 25696538 .5MS ETIM 0. SGP 3348.995 PONE 9. PHUN 3. PTHO 3. PTEN 4. Data record type 0 TIME 25936538 .5MS ETIM 120. PHUN 8. SGP 2818.271 PTHO 2. PONE 8. <'~" PTEN 1. Data record type 0 TIME 26176538 .5MS ETIM 240. SGP 2829.733 PONE 9. PHUN 8. PTHO 2. PTEN 2. Data record type 0 TIME 26416538 .5MS ETIM 360. SGP 3348.49 PONE 8. PHI/N 3. PTHO 3. PTEN 4. ** FILE TRAILER ** FILE NAME : RFTB .041 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY ~LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 41 74 0 16 1276 TIME .5MS 25696538 26461538 ** FILE HEADER ** FILE NAME : RFTB .042 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 59 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SiZE REP PROCESS ID ORDER ~ LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 72 1 1 4 SGP RFTB PSI 81 400 0 72 1 1 4 PONE RFTB 81 400 0 72 1 1 4 PTEN RFTB 81 400 0 72 1 1 4 PHUN RFTB 81 400 0 72 1 1 4 PTHO RFTB 81 400 0 72 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 26866728 .5MS ETIM 0. SGP 3359.501 PONE 9. PHUN 3. PTHO 3. PTEN 5. Data record type 0 TIME 27106728 .5MS ETIM 120. PHUN 0. SGP -15.01427 PONE -4. PTHO 0. PTEN -1. ** FILE TRAILER ** FILE NAME : RFTB .042 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 33 66 0 8 627 TIME .5MS 26866728 27242328 ** FILE HEADER ** FILE NAME : RFTB .043 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 61 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 ~..~ 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE L53MB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 74 1 1 4 SGP RFTB PSI 81 400 0 74 1 1 4 PONE RFTB 81 400 0 74 1 1 4 PTEN RFTB 81 400 0 74 1 1 4 PHUN RFTB 81 400 0 74 1 1 4 PTHO RFTB 81 400 0 74 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 27457672 .5MS ETIM 0. SGP 3360.189 PONE 0. PTEN 6. PHUN 3. PTHO 3. Data record type 0 TIME 27697672 .5MS ETIM 120. SGP 2772.039 PONE 2. PTEN PHUN 7. PTHO 2. Data record type 0 TIME 27937672 .5MS ETIM 240. SGP 2895.491 PONE 5. PTEN 9. PHUN 8. PTHO 2. Data record type 0 TIME 28177672 .5MS ETIM 360. SGP 2913.353 PONE 3. PTEN 1. PHUN 9. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .043 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR ~PR ~_~ #DR 43 76 0 18 #FM PI PI UNITS"~iV~AXPI MINPI 1390 TIME .5MS 27457672 28291072 ** FILE HEADER ** FILE NAME : RFTB .044 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE · 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 63 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NLIMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 76 1 1 4 SGP RFTB PSI 81 400 0 76 1 1 4 PONE RFTB 81 400 0 76 1 1 4 PTEN RFTB 81 400 0 76 1 1 4 PHUN RFTB 81 400 0 76 1 1 4 PTHO RFTB 81 400 0 76 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 28594912 .5MS ETIM 0. SGP 3360.822 PONE 0. PHUN 3. PTHO 3. PTEN 6. Data record type 0 TIME 28834912 .5MS ETIM 120. SGP 2889.177 POI~ 9. PTEN 8. PHUN 8. PTHO 2. Data record type 0 TIME 29074912 .5MS ETIM 240. SGP 2901.294 PONE 1. PTEN 0. PHUN 9. PTHO 2. ** FILE TRAILER ** FILE NAME : RFTB .044 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 39 72 0 14 1097 TIME .5MS 28594912 29252512 ** FILE HEADER ** FILE NAME : RFTB .045 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 65 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S· -- 63 621 0 78 1 SGP RFTB PSI 81 400 0 78 1 PONE RFTB 81 400 0 78 1 PTEN RFTB 81 400 0 78 1 PHUN RFTB 81 400 0 78 1 PTHO RFTB 81 400 0 78 1 1 1 1 1 1 1 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 29558166 .5MS ETIM 0. SGP 3367.022 PONE 7. PHUN 3. PTHO 3. PTEN 6. Data record type 0 TIME 29798166 .5MS ETIM 120. PHUN 0. SGP -8.679825 PONE -8. PTHO 0. PTEN 0. Data record type 0 TIME 30038166 .5MS ETIM 240. SGP 2826.883 PONE 6. PHUN 8. PTHO 2. PTEN 2. Data record type 0 TIME 30278166 .5MS ETIM 360. SGP 3366.548 PONE 6. PHUN 3. PTHO 3. PTEN 6. ** FILE TRAILER ** FILE NAME : RFTB .045 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC ~DR #FM PI PI UNITS MAXPI MINPI 42 75 0 17 1327 TIME .5MS 29558166 30353766 ** FILE HEADER ** FILE NAME · RFTB .046 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format s~-~cification record Listing of set 67 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 80 1 1 4 SGP RFTB PSI 81 400 0 80 1 1 4 PONE RFTB 81 400 0 80 1 1 4 PTEN RFTB 81 400 0 80 1 1 4 PHUN RFTB 81 400 0 80 1 1 4 PTHO RFTB 81 400 0 80 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 30675616 .5MS ETIM 0. SGP 3376.751 PONE 6. PHUN 3. PTHO 3. PTEN 7. Data record type 0 TIME 30915616 .5MS ETIM 120. SGP 2.509653 PONE 2. PHUN 0. PTHO 0. PTEN 0. Data record type 0 TIME 31155616 .5MS ETIM 240. SGP 2953.799 PONE 3. PHUN 9. PTHO 2. PTEN 5. Data record type 0 TIME 31395616 .5MS ETIM 360. SGP 2971.564 PONE 1. PHUN 9. PTHO 2. PTEN 7. Data record type 0 TIME 31635616 .5MS ETIM 480. SGP 3374.895 PONE 4. PTEN 7. PI-IL~ 3. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .046 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 46 79 0 21 1623 TIME .5MS 30675616 31648816 ** FILE HEADER ** FILE NAME : RFTB .047 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 69 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NI/MB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI/MB ELEM SAMP COD (HEX) ETIM RFTB S SGP RFTB PSI PONE RFTB PTEN RFTB PHUN RFTB PTHO RFTB 63 621 0 82 1 1 4 81 400 0 82 1 1 4 81 400 0 82 1 1 4 81 400 0 82 1 1 4 81 400 0 82 1 1 4 81 400 0 82 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 31924518 .5MS ETIM 0. SGP 3395.281 PONE 5. PTEN 9. PHUN 3. PTHO 3. Data record type 0 TIME 32164518 .SMS ETIM 120. SGP -5.861412 PONE -5. PTEN 0. PHUN 0. PTHO 0. ** FILE TRAILER ** FILE NAME : RFTB .047 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SIIMMARY ~LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 33 66 0 8 633 TIME .5MS 31924518 32303718 ** FILE HEADER ** FILE NAME : RFTB .048 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 71 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 84 1 1 4 SGP RFTB PSI 81 400 0 84 1 1 4 PONE RFTB 81 400 0 84 1 1 4 PTEN RFTB 81 400 0 84 1 1 4 PHUN RFTB 81 400 0 84 1 1 4 PTHO RFTB 81 400 0 84 1 1 4 68 OOO0O00OO0 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 32512094 .5MS ETIM 0. SGP 3396.914 PONE 6. PHUN 3. PTHO 3. PTEN 9. Data record type 0 TIME 32752094 .5MS ETIM 120. PHUN 0. SGP -8.377953 PONE -8. PTHO 0. PTEN 0. ** FILE TRAILER ** FILE NAME : RFTB .048 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 FILE SU74MARY #LR #PR #ENC ~DR ~FM PI PI I/NITS MAXPI MINPI 35 68 0 10 742 TIME .5MS 32512094 32956694 ** FILE HEADER ** FILE NAME · RFTB .052 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 73 type 64EB object 0 ENTRY vALLE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NLIMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 92 1 1 4 SGP RFTB PSI 81 400 0 92 1 1 4 PONE RFTB 81 400 0 92 1 1 4 PTEN RFTB 81 400 0 92 1 1 4 PHUN RFTB 81 400 0 92 1 1 4 PTHO RFTB 81 400 0 92 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 35728768 .5MS ETIM 0. SGP 3749.022 PONE 9. PHUN 7. PTHO 3. PTEN 4. Data record type 0 TIME 35968768 .5MS ETIM 120. SGP 3194.78 PONE 4. PHUN 1. PTHO 3. PTEN 9. ** FILE TRAILER ** FILE NAME : RFTB .052 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 34 67 0 9 716 TIME .5MS 35728768 36157768 ** FILE HEADER ** FILE NAME : RFTB .053 SERVICE NAME : STAT1L-j VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 75 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI3MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 94 1 1 4 SGP RFTB PSI 81 400 0 94 1 1 4 PONE RFTB 81 400 0 94 1 1 4 PTEN RFTB 81 400 0 94 1 1 4 PHUN RFTB 81 400 0 94 1 1 4 PTHO RFTB 81 400 0 94 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 36438616 .5MS ETIM 0. SGP 3905.526 PONE 5. PTEN 0. PHUN 9. PTHO 3. Data record type 0 TIME 36678616 .5MS ETIM 120. SGP 11.20996 PONE 1. PTEN 1. PHUN 0. PTHO 0. Data recor~-~ype 0 TIME 36918616 .5MS <~l ETIM 240. SGP 3185.359 PONE 5. PHUN 1. PTHO 3. PTEN 8. Data record type 0 TIME 37158616 .5MS ETIM 360. SGP 3328.174 PONE 8. PTEN 2. PHUN 3. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .053 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 44 77 0 19 1468 TIME .5MS 36438616 37318816 ** FILE HEADER ** FILE NAME : RFTB .054 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 77 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 96 1 1 4 68 0000000000 SGP RFTB PSI ..... 81 400 0 96 1 1~__.. 4 68 0000000000 PONE RFTB 81 400 0 96 1 1 4 68 0000000000 PTEN RFTB 81 400 0 96 1 1 4 68 0000000000 PHUN RFTB 81 400 0 96 1 1 4 68 0000000000 PTHO RFTB 81 400 0 96 1 1 4 68 0000000000 Data record type 0 TIME 37597032 .5MS ETIM 0. SGP 3902.814 PONE 2. PTEN 0. PHUN 9. PTHO 3. Data record type 0 TIME 37837032 .5MS ETIM 120. SGP 3902.293 PONE 2. PTEN 0. PHUN 9. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .054 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 31 64 0 6 409 TIME .5MS 37597032 37841832 ** FILE HEADER ** FILE NAME : RFTB .055 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 79 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80" ~" 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 98 1 1 4 SGP RFTB PSI 81 400 0 98 1 1 4 PONE RFTB 81 400 0 98 1 1 4 PTEN RFTB 81 400 0 98 1 1 4 PHUN RFTB 81 400 0 98 1 1 4 PTHO RFTB 81 400 0 98 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 37990400 .5MS ETIM 0. SGP 3907.825 PHUN 9. PTHO 3. ........................ PONE 7. PTEN 0. Data record type 0 TIME 38230400 .5MS ETIM 120. SGP 3245.524 PONE 5. PHUN 2. PTHO 3. PTEN 4. Data record type 0 TIME 38470400 .5MS ETIM 240. SGP 3295.108 PONE 5. PHUN 2. PTHO 3. PTEN 9. Data record type 0 TIME 38710400 .5MS ETIM 360. SGP 3297.727 PONE 7. PHUN 2. PTHO 3. PTEN 9. ** FILE TRAILER ** FILE NAME : RFTB .055 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 45 78 0 20 1534 TIME .5MS 37990400 38910200 ** FILE HEADER ** FILE NAME : RFTB .056 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 81 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NI3MB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 100 1 1 4 SGP RFTB PSI 81 400 0 100 1 1 4 PONE RFTB 81 400 0 100 1 1 4 PTEN RFTB 81 400 0 100 1 1 4 PHUN RFTB 81 400 0 100 1 1 4 PTHO RFTB 81 400 0 100 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 39210928 .5MS ETIM 0. SGP 3915.502 PONE 5. PHUN 9. PTHO 3. PTEN 1. Data record type 0 TIME 39450928 .5MS ETIM 120. PHUN 0. SGP -12.70375 PONE -2. PTHO 0. PTEN -1. ** FILE TRAILER ** FILE NAME : RFTB .056 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY ~LR #PR #ENC ~DR ~FM PI PI UNITS MAXPI MINPI 34 67 0 9 657 TIME .5MS 39210928 39604528 ** FILE HEADER ** FILE NAME : RFTB .057 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 83 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 t 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 102 1 1 4 SGP RFTB PSI 81 400 0 102 1 1 4 PONE RFTB 81 400 0 102 1 1 4 PTEN RFTB 81 400 0 102 1 1 4 PHUN RFTB 81 400 0 102 1 1 4 PTHO RFTB 81 400 0 102 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 39828492 .5MS ETIM 0. ~ ~ SGP 3913.73 PHUN 9. PTHO 3. PONE 3. ,~t PTEN 1. Data record type 0 TIME 40068492 .5MS ETIM 120. SGP 3913.809 PONE 3. PHUN 9. PTHO 3. PTEN 1. ** FILE TRAILER ** FILE NAME : RFTB .057 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 31 64 0 6 438 TIME o5MS 39828492 40090692 ** FILE HEADER ** FILE NAME : RFTB .058 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 85 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NIJMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI3MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 104 1 1 4 SGP RFTB PSI 81 400 0 104 1 1 4 PONE RFTB 81 400 0 104 1 1 4 PTEN RFTB 81 400 0 104 1 1 4 PHUN RFTB 81 400 0 104 1 1 4 PTHO RFTB 81 400 0 104 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 40304940 .5MS ETIM 0. SGP 3913.104 PONE 3. PHUN 9. PTHO 3. PTEN 1. Data record type 0 TIME 40544940 .5MS ETIM 120. SGP 3913.099 PONE 3. PTEN 1. PHUN 9. PTHO 3. Data record type 0 TIME 40784940 .5MS ETIM 240. SGP 3913.236 PONE 3. PHUN 9. PTHO 3. PTEN 1. Data record type 0 TIME 41024940 .5MS ETIM 360. SGP 3913.365 PONE 3. PHUN 9. PTHO 3. PTEN 1. Data record type 0 TIME 41264940 .5MS ETIM 480. SGP 3913.401 PONE 3. PHUN 9. PTHO 3. PTEN 1. ** FILE TRAILER ** FILE NAME · RFTB .058 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR ~PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 50 83 0 25 1937 TIME .5MS 403049.40 41466540 ** FILE HEADER ** FILE NAME : RFTB .059 SERVICE NAME : STATIO VERSION # : 7C0-4m~ DATE : 96/03/20 MAX. REC. LEN.: 8192 Data format specification record Listing of set 87 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NI3MB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 106 1 1 4 SGP RFTB PSI 81 400 0 106 1 1 4 PONE RFTB 81 400 0 106 1 1 4 PTEN RFTB 81 400 0 106 1 1 4 PHUN RFTB 81 400 0 106 1 1 4 PTHO RFTB 81 400 0 106 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 41897364 .5MS ETIM 0. SGP 3747.333 PONE 7. PHUN 7. PTHO 3. PTEN 4. ** FILE TRAILER ** FILE NAME : RFTB .059 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR ~ENC #DR ~FM PI PI UNITS MAXPI MINPI -- 28 61 0 3 162 TIME . 5MS 41897364 41993964 ** FILE HEADER ** FILE NAME : RFTB .060 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 89 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER ~ LOG TYP CLS MOD NUMB ELEM SAMP ETIM RFTB S 63 621 0 108 1 1 4 SGP RFTB PSI 81 400 0 108 1 1 4 PONE RFTB 81 400 0 108 1 1 4 PTEN RFTB 81 400 0 108 1 1 4 PHUN RFTB 81 400 0 108 1 1 4 PTHO RFTB 81 400 0 108 1 1 4 COD (HEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 42507560 .5MS ETIM 0. SGP 3745.975 PONE 6. PHUN 7. PTHO 3. PTEN 4. ** FILE TRAILER ** FILE NAME : RFTB .060 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 28 61 0 3 224 TIME .5MS 42507560 42641360 ** FILE HEADER ** FILE NAME : RFTB .061 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 Data format specification record Listing of set 91 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NIIMB NI3MB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NIIMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 110 1 1 4 SGP RFTB PSI 81 400 0 110 1 1 4 PONE RFTB 81 400 0 110 1 1 4 PTEN RFTB 81 400 0 110 1 1 4 PHUN RFTB 81 400 0 110 1 1 4 PTHO RFTB 81 400 0 110 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 378778 .5MS ETIM 0. SGP 3746.238 PONE 6. PTEN 4. PHUN 7. ~-'~' PTHO 3 .... Data record type 0 TIME 618778 .5MS ETIM 120. SGP 3746.221 PONE 6. PTEN 4. PHUN 7. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .061 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE : 96/03/20 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 34 67 0 9 692 TIME .5MS 378778 793378 ** FILE HEADER ** FILE NAME : RFTB .066 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 93 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 115 1 1 4 SGP RFTB PSI 81 400 0 115 1 1 4 PONE RFTB 81 400 0 115 1 1 4 PTEN RFTB 81 400 0 115 1 1 4 68 OO00OOOOOO 68 0000000000 68 0000000000 68 0000000000 PHUN RFTB PTHO RFTB 81 400 0 115 1 1 <_~ 4 81 400 0 115 1 1 4 68 0000000000 68 0000000000 Data record type 0 TIME 337600 .5MS ETIM 0. SGP 242.1341 PONE 2. PHUN 2. PTHO 0. PTEN 4. Data record type 0 TIME 577600 .5MS ETIM 120. SGP 241.7521 PHUN 2. PTHO 0. PONE 1. PTEN 4. Data record type 0 TIME 817600 .5MS ETIM 240. SGP 241.4792 PHIIN 2. PTHO 0. PONE 1. PTEN 4. Data record type 0 TIME 1057600 .5MS ETIM 360. SGP 443.5065 PHUN 4. PTHO 0. PONE 3. PTEN 4. ** FILE TRAILER ** FILE NAME : RFTB .066 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN.: 8192 FILE SIIMMARY #LR #PR #ENC #DR ~FM PI PI UNITS MAXPI MINPI 43 76 0 20 1335 TIME .5MS 337600 1138000 ** FILE HEADER ** FILE NAME : RFTB .068 SERVICE NAME : STATIO VERSION # · 7C0-428 DATE · 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 95 type 64EB object 0 ENTRY vAL~E REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 117 1 1 4 68 0000000000 SGP RFTB PSI 81 400 0 117 1 1 4 68 0000000000 PONE RFTB 81 400 0 117 1 1 4 68 0000000000 PTEN RFTB 81 400 0 117 1 1 4 68 0000000000 PHUN RFTB 81 400 0 117 1 1 4 68 0000000000 PTHO RFTB 81 400 0 117 1 1 4 68 0000000000 Data record type 0 TIME 2059573 .5MS .............................. ETIM 0. SGP 4178.956 PONE 9. PTEN 7. PHUN 1. PTHO 4. ** FILE TRAILER ** FILE NAME : RFTB .068 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 24 57 0 1 11 TIME .SMS 2059573 2065573 ** FILE HEADER ** FILE NAME : RFTB .069 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of ~t 97 type 64EB object ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 118 1 1 4 SGP RFTB PSI 81 400 0 118 1 1 4 PONE RFTB 81 400 0 118 1 1 4 PTEN RFTB 81 400 0 118 1 1 4 PHUN RFTB 81 400 0 118 1 1 4 PTHO RFTB 81 400 0 118 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 2422475 .5MS ETIM 0. SGP 4176.868 PHUN 1. PTHO 4. ............. PONE 6. PTEN 7. ** FILE TRAILER ** FILE NAME · RFTB .069 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY #LR #PR #ENC ~DR #FM PI PI UNITS MAXPI MINPI 27 60 0 1 11 TIME .5MS 2422475 2428475 ** FILE HEADER ** FILE NAME : RFTB .071 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN.: 8192 Data format specification record Listing of set 99 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NLTMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 120 1 1 4 SGP RFTB PSI 81 400 0 120 1 1 4 PONE RFTB 81 400 0 120 1 1 4 PTEN RFTB 81 400. 0 120 1 1 4 PHUN RFTB 81 400 0 120 1 1 4 PTHO RFTB 81 400 0 120 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 409481 .5MS ETIM 0. PHUN-1. SGP -164.5957 PONE -4. PTHO 0. PTEN -6. Data record type 0 TIME 649481 .5MS ETIM 120. PHUN -1. SGP -166.1348 PONE -6. PTHO 0. PTEN -6. Data record type 0 TIME 889481 .5MS ETIM 240. PHUN -1. SGP -157.0531 PONE -7. PTHO 0. PTEN -5. Data record type 0 TIME 1129481 .5MS ETIM 360. SGP -168.5332 PONE -8. PHUN -1. PTHO 0. PTEN -6. ** FILE TRAILER ** FILE NAME : RFTB .071 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE S~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 48 81 0 22 1432 TIME .5MS 409481 1268081 ** FILE HEADER ** FILE NAME : RFTB .074 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 101 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NIIMB NUMB SIZE REP PROCESS ID ORDE'~# LOG TYP CLS MOD NI3MB ELEM SDa~--,'P COD (HEX) ETIM RFTB S SGP RFTB PSI PONE RFTB PTEN RFTB PHI/N RFTB PTHO RFTB 63 621 0 122 1 1 4 81 400 0 122 1 1 4 81 400 0 122 1 1 4 81 400 0 122 1 1 4 81 400 0 122 1 1 4 81 400 0 122 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 778431 .5MS ETIM 0. SGP 3997.194 PONE 7. PTEN 9. PHUN 9. PTHO 3. Data record type 0 TIME 1018431 .5MS ETIM 120. SGP 3436.913 PONE 6. PTEN 3. PHUN 4. PTHO 3. Data record type 0 TIME 1258431 .5MS ETIM 240. SGP 3423.013 PONE 3. PTEN 2. PHUN 4. PTHO 3. Data record type 0 TIME 1498431 .5MS ETIM 360. SGP 3435.383 PONE 5. PHUN 4. PTHO 3. ** FILE TRAILER ** FILE NAME : RFTB .074 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN.: 8192 PTEN 3. FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 50 83 0 24 1559 TIME .5MS 778431 1713231 ** FILE HEADER ** FILE NAME : RFTB .076 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 Data format specification record Listing of set 103 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 124 1 1 4 SGP RFTB PSI 81 400 0 124 1 1 4 PONE RFTB 81 400 0 124 1 1 4 PTEN RFTB 81 400 0 124 1 1 4 PHUN RFTB 81 400 0 124 1 1 4 PTHO RFTB 81 400 0 124 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 Data record type 0 TIME 3111032 .5MS ETIM 0. SGP 3548.605 PHUN 5. PTHO 3. PONE 8. PTEN 4. Data record type 0 TIME 3351032 .5MS ETIM 120. SGP 2956.089 PHI/N 9. PTHO 2. PONE 6. PTEN 5. Data record type 0 TIME 3591032 .5MS ETIM 240. SGP 363.9602 PHUN 3. PTHO 0. PONE 4. PTEN 6. Data record type 0 TIME 3831032 .5MS ETIM 360. SGP 374.754 PHUN 3. PTHO 0. PONE 4. PTEN 7. Data record type 0 TIME 4071032 .5MS ETIM 480. SGP 394.5626 PONE 4. PTEN 9. PHUN 3. PTHO 0. Data record type 0 TIME 4311032 .5MS ETIM 600. SGP 423 3519 PONE 3 PTEN 2. PHUN 4 PTHO 0. Data record type 0 TIME 4551032 .5MS ETIM 720. PHUN 4 SGP 473 7183 PTHO 0. PONE 3 PTEN 7 Data record type 0 TIME 4791032 .5MS ETIM 840. PHUN 5 SGP 541 3759 PTHO 0 PONE 1 PTEN 4 Data record type 0 TIME 5031032 5MS ETIM 960. PHUN 6 SGP 627 2272 PTHO 0 PONE 7 PTEN 2 Data record type 0 TIME 5271032 5MS ETIM 1080. PHUN 7 SGP 726 4216 PTHO 0 PONE 6 PTEN 2 Data record type 0 TIME 5511032 5MS ETIM 1200. PHUN 8 SGP 835 5006 PTHO 0 PONE 5 PTEN 3 Data record t_vpe 0 TIME 5751032 5MS ETIM 1320. PHvu~ 9 SGP 951 8583 PTHO 0 PONE 1 PTEN 5 Data record type 0 TIME 5991032 5MS ETIM 1440. PHUN 0 SGP 1078.668 PTHO 1 PONE 8 PTEN 7 Data record type 0 TIME 6231032 5MS ETIM 1560 SGP 1208.672 PHUN 2. PTHO 1 PONE 8 PTEN 0 Data record type 0 TIME 6471032 .5MS ETIM 1680 PHUN3 SGP 1341.896 PTHO 1 PONE 1 PTEN 4 Data record type 0 TIME 6711032 .SMS ETIM 1800 PHUN 4 SGP 1474.442 PTHO 1 PONE 4 PTEN 7 Data record type 0 TIME 6951032 .5MS ETIM 1920 PHUN 6 SGP 1604.896 PTHO 1 PONE 4 PTEN 0 Data record type 0 TIME 7191032 .5MS ETIM 2040 PHUN 7 SGP 1732.516 PTHO 1 PONE 2 PTEN 3 Data record type 0 TIME 7431032 .5MS ETIM 2160 PHUN 8 SGP 1854.631 PTHO 1 PONE 4 PTEN 5 Data record type 0 TIME 7671032 .5MS ETIM 2280 SGP 1971.185 PONE 1 PTEN 7 PHUN 9 PTHO 1 Data record type 0 TIME 7911032 .5MS ETIM 2400 SGP 2080.186 PONE 0 PHUN 0 PTHO 2 PTEN 8 Data record type 0 TIME 8151032 .5MS ETIM 2520 PHUN 8 SGP 2828.557 PTHO 2 PONE 8 PTEN 2 FILE TRAILER~ ~* FILE NAME : RFTB .076 SERVICE NAME : STATIO VERSION ~ : 7C0-428 DATE : 96/03/21 MAX. REC. LEN. : 8192 FILE SUMMARY #LR ~PR ~ENC ~DR ~FM PI PI UNITS MAXPI MINPI 156 189 0 130 8696 TIME .5MS 3111032 8328032 ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 96/03/21 ** REEL TRAILER ** SERVICE NAME : RFTB DATE : 96/03/21 REEL SUMMARY FILES TAPES ~LR ~PR 1 1 160 193 (EOD) LU SUMMARY FILES TAPES REELS #LR #PR 52 52 52 2281 3997 End of listing $1$DIA2:[96098.RFT]RFTFLD.LIS;1
