Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
186-166
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J ~) _~- _/_~ ~ Well History File Identifier [] [] [] RESCAN DIGITAL DATA Color items: [] Diskettes, No. Grayscale items: [] Other, No/Type Poor Quality Originals: Other: TOTAL PAGES: ~ NOTES: ORGANIZED BY;(BEVERLY~BREN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: 5(.~ (at the time of scanning) SCANNED BY: (BEVERLY~BREN VINCENT SHERYL MARIA LOWELL Is~ ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.wpd (;11 ) ') (~7.. os'?' t<3r¡-oz9 / ?/GJ'(CpCo ¡?f9' .. otf ( I ~'i - eel. Page 1 of 2 Conoc;Phillips Transnlittal #383 Detail Date: 9/29/2004 " Front (PAl Contact): Email: Sandra.D.Lemke@conocophillips.com First Sandra Name: Last L k Name: em e Phone 265-6947 Number: Company: ConocoPhiJlips Alaska Address: 700 G Slreet, ATO 1486 City: Anchorage State: Ak Zip Code: 99510 SCANNED ,U~N () () 2005 To (Extc1"Ital I)arty): Email: Howard_Okland@admin.state.ak.us First Name: Howard Last Name: Oakland Phone Number: Company: Address: City: I State: Zip Code: Sent Via: hand delivery TrmlSlnittal Info: Tracking #: Justification: per 9/26/2004 request from Helen Warman, AOGCC Librarian Quantity 1 1 1 1 1 1 ' Data Dctail: Description Core Analysis report-KRU 30-12; Core Labs CL BP-3-1281; 8/9/1988 Core Analysis KRU 3M-09; 7/2111987; Core Labs Core Analysis Report; KRU 3H-09; 2/22/1988; Core Labs Core Analysis Report; KRU 3K-09; Core Labs; 1/19/1987 Core Analysis Report; KRU 3M-16; Core Labs 8/19/1987 Core Analysis Report- KRU 2T-09; Core Labs; 9/30/1988 Type paper / paper / paper / paper j paper / paper / http://www.ak.ppco.com/transmi ttallpri ntasp ?transno=383 9/29/2004 ) Attachments: Filename: None Received By~~ h j J Î sign~~ko' '/¿¡U.fUav- Approver: Signature: http://www.ak.ppco.com/transmi tta]/pri nLasp ?transno=3 83 Filesize: N/ A )- Date: 9f-~ cf Date: Page 2 of2 C) I?~ C) !?OO4. MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE PLUGGIN & LOCATION CLEA.~,~NCE REPORT State of Alaska .ALASKA 0IL & GAS CONSERVATION COMMISSION Memcrandu_m To File: APi No. Well Name Operator Comp 1 e t ed Note casing size, wt, depth, Cmt vol, ~ procedure. Liner: perf intervals - tops: Review the well file, and' comment on plugging, well head status,~~ location clearance - provide loc. clear, code. , Code t7q Signed ARCO Alaska, Inc. Post Office Anchorage, Alaska 99510 Telephone 907 276 1215 SA~qP LE TRANSHITTAL · hand-carried SHIPPED TO' .. State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE· 5-12- 88 0 P ERATOR ' S,'%x~P LE TYPE· ARCO core chips, plug ends N~IE' see below NUMBER OF BOXES: 63 SAHPLES SF-NT' Lisb L5-21:11 boxes 12088/89 - 12133/34 12123 - 12144 12145/46 - 12149/50 12151/52 - 12198/99 12151/52 - 12198/99 12200/01 - 12223/24 12230/31 - 12288/89 12290/91 - 12371/72 12373/74 - 12390/91 12396/97 - 12406/07 12422/23 - 12425/26 12435/36 - 12445/46 12449/50 - 12463/64 12467½68 - 12471/72 12473/74 -' 12581/81 12482/83 - 12490/91 12492/93 - 12510/11 12520/21 - 12614/15 .5 KRU 2T-9; 1 box KRU 3J-9:12 boxes ~'..S-~. 05- 2150.8 - 22Sg,0S 6320 - 6393 "(~'250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are available)6459.- 6503 6507 - 6545 KRU 3H-9:9 boxes 6548 -6570 6868 - 6908 6911 - 6958 6971 - 7058 KRU 3H-11:2 boxes 3941 - 3954 3970 "3974 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 4061 - 4081 3365.2 - 3501.3 6967 --7009 7027 - 7060 7060 - 7099 7102 - 3174 7199 - 7243 · KRU 3M-9:5 boxes 6531 - 6577.0 6579 - 6618 6637 - 6650 -KRU 3M-16:7 boxes 7580 - 7614 7617 - 7690 SHIPPED BY' ~~ i~_~~- ' ~,~_ Bayview Facility Coordinator UPON RECEZPT OF THESE S~x{PLES, PLEAS~NOTE ANY DZSCREP,aJ~CIES ,aJ~D hLqZL A SIGNED COPY'OF THZS FOt%Xl TO' ARCO ALAStC~, INC. = ANCHORAGE, ALASKA 99510: ATTN: Paleo Lab · .- RECEIVED BY: A DAT~~.' ~ ... · ARCO Alaska. Inc. is a Subsidiary of AllantlcRIchfleldCompany NEW PROJECTS ENGINEERING TRANSMITTAL # 1042 TO: John Boyle State DATE: Dec. 19, 1985 FROM: H. D. White/P. S. Baxter WELL NAME: 2Z-WS-1 3K-6 3K-9 TRANSMITTED HEREWITH ARE THE FOLLOWING: Finals Bluelines and Sepia for each: 2Z-WS-1 Perforating Record 2Z-WS-1 Completion Record 2Z-WS-1 Temperature Log 3K-6 Repeat Formation Tester 3K-6 CET Log Cement Evaluation Log 3K-6 5" Density-Neutron-GR (Porosity) 3K-6 5" Dual Induction/SFL - GR 3K-9 Cyberlook 3K-9 2" Compensated Neutron-Litho Density (Raw Data) 3K-9 5" Compensated Neutron-Litho Density (Raw Data) 3K-9 5" Long Spacing Sonic - GR 3K-9 2" Long Spacing Sonic - GR 3K-9 2" Dual Induction - GR 3K-9 5" Dual Induction - GR 3K-9 2" Compensated Neutron-Litho Density 3K-9 5" Compensated Neutron-Litho Density 3K-9 2" Natural Gamma Ray Spectrometry Log 3K-9 5" Natural Gamma Ray Spectrometry Log 8/26/86 run 1 8/26/86 run 1 8/26/86 run 1 9/16/86 run 2 9/15/86 run 2 9/11/86 run 1 9/11/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 10/7/86 run 1 RECEIPT ACKNOWLEDGED: / .~,,o ~\~ ?.'.~.i"'~DATE: .... ...... _ ......... ~_~'-~ ~ ~__ i'...' . ~ --- - PLEASE RETURN RECEIPT TO: ARCO.R , INC. ATTN. P. Susanne Baxter, ATO-527 P. O. Box 100360 Anchorage, Alaska 99510 STATE OF ALASKA ALASKA~JIL AND GAS CONSERVATION CL~,wMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED}~ SERVICE [] ........ . , 2. Name of Operator' : 7. Permit Number ARCO Alaska, Inc. 86-166 3. Address 8. APl Number .P.: 0. Box 100360~ Anchorage~ AK. 99510-0360 50- 029-21F,56 4. Location of well at surface 9. Unit or Lease Name 1234' FSL, 317' FWL, Sec.35, T13N, R9E, UN K. uparuk River Unil; At Top Producing Interval 10. Well Number N/A 3K-9 At Total Depth 11. Field and Pool 1384' FSL~ 1888' FWL~ Sec.35, T1.3N~ R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 69' RKBI ADL 25519 ALK 2555 , , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. '1 15. Water Depth, if offshore 16. No. of comPietions 10/01/86 10/15/86 10/17/86 .Ii N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back 'DePth (MD+TVD) 19. Directional Survey J 20. Depth where SSSV set 21. Thickness of'permafrost 7443'MD~7.086'TVD 5060'MD~4879'TVD YESx[~ M.WD NO []Ii. N/A feet MD 17~(~' 22. Type Electric or Other Logs Run D I L/GR/LSS, LDT/CNL/NGT/CAL. VSP. D I L/SFL/SP/£AL/GR/FD£/£NI . RH£R FM~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ............... 16" 62.~# H-b,O -~' I r~ f !!0' 2~" !5q0# Pol esot 10-3/4" 45.5# K-.~,; S,,rf ~!79.' 13-!/2" !~.00 sx AS !V & !25 sx Class , , , ,, 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) , , None N/A 26.' '" ACID, FRACTURE, CEMENT sQUEEZE, ETC.' .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ..... Plug f/6730' - 7227' !75 :x Ciao0 C ...... Plug f/5050' _ =~r, ...... Cf--- .............. 27. N/A PRODUCTION TEST · Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-I(/ICF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD II~ ,, , , Fiow Tubing Casing Pressure CALCULATED.1~ OIL-BBL G'AS-MCF WATER-BBL OIL GRAViTY-APl (co'r) Press. 24-HOUR RATE I~ ..... 28. COP E DATA ......... Brief description of lithology, porosity, fractures, aPparent dips and presence of oil, gas or water. Submit core chips. Core data to be submitted when received. DAN/WC1:149 ,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ GEOLOGIC MA ' · RMATION TESTS NAME · Include interval tested, pressure data~ all fluids recovered and gravity, ' · ~ MEAs. DEPTH TRUE VERT. DEPTH GOR, and time of each Phase. N/A N/A · · ~ ,, · . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing.is t~Je and correct to th~ best of my knowledge Signed {~~ ~.~/~ Title Assoc,at:e Eng,neer Date 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 disl:/osal, 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- ing 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 .... STATE OF ALASKA ALASKI .~. AND GAS CONSERVATION COMMI,,_ _ ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ¢q Other F~ Ab:andon Plugging ~ Perforate'-'~'/~ Pull tubing 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval N/A At effective depth 1327' FSL, 1058' FWL, Sec. 35, T13N, R9E, UM At total depth 1384' FSL, 1888' FWL, Sec. 35, T13N, R9E, UM 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3135' feet 7443 'MD feet 7086 ' TVD feet 5060 'MD feet 4879 ' TVD Size Cemented 16" Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) RKB 69 ' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Approval number 420 & 477 9. APl number 50-- 029-21656 10. Pool Kuparuk River Oil Pool 6730'-7227' w/175 sx Class 5060'-5300' w/150 sx Class None Measured depth 1540# Poleset 1 0-3/4" 1400 sx AS IV & 125 sx Class G True Vertical depth 1lO'MD 110'TVD 3172'MD 3170'TVD Perforation depth: measured true vertical None None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12. Stimulation or cement squeeze summary N/ Interv'a'~s treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl . Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments - Daily Report of Well OperatiC)ns ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best o~f mY knowledge Form 10-404 Rev. 12-1-85 Associate Engineer (bAH) $W0/i20 Date fid7 Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily worl< prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field l County, parish or borough ' North Slope Borough I Leaae or Unit Kuparuk River ADL 25519 Auth. or W.O~ no. ITM AF[ AKi410 I Drill . DOyon 9 AP1 50-029-21656 ARCO Alaska, Inc. State Alaska Well no. 3K-9/3K-9A Operator Spudded or W.O. begun [Date [Hour Spudded 10 / 1 / 86 Date and depth as of 8:00 a.m. 10/01/86 10/02/86 10/03/86 10/04/86 thru 10/06/86 10/07/86 10/08/86 Complete record for each day reported 0001 hrs. ARCO W.t. Prior status if a W.O. 56.24% 16" @ 110' 960', (850'), Drlg Wt. 9.2+, PV 17, YP 31, PH 8.5, WL 12.4, Sol 6 Accept rig @ 2030 hfs, 9/30/86. NU diverter sys. 0001 hfs, 10/1/86. Dri to 960'. Spud well @ 16" @ 110' 3108', (2148'), Drlg Wt. 9.4, PV 12, YP 8, PH 8.5, WL 12.8, Sol 8 Drl & surv to 3108'. 472', 0.4°, N45.3E, 472 TVD, 1.23 VS, 1.16N, 1.17E 1483', 0.4°, S27.6W, 1482.96 TVD, -3.41VS, 2.93N, 3.58W 2493', 2.5°, NIO.6E, 2492.73 TVD, 7.36 VS, 10.78N, 6.76E 10-3/4" @ 3172' 3185', (77'), DO cmt 8.4 ppg (wtr in pits) Drl 13-1/2" hole to 3185', short trip, C&C, POOH. RU & rn 77 its, 10-3/4", 45.5#, K-55 BTC csg w/FC @ 3085', FS @ 3172'. Cmt w/1400 sx AS IV & 125 sx C1 "G" w/2% CaC12 & .2% D-46. Displ cmt w/wtr using rig pmps, bump plug. CIP @ 1850 hrs, 10/2/86. ND diverter, NU &tst BOPE. RIH w/BHA, DO flt equip. 3130', 8.4e, N73.SE, 3128.22 TVD, 28.94 VS, 39.65N, 26.75E 10-3/4" @ 3172' 3444', (259'), Coring Wt. 9.0+, PV 24, YP 6, Sol 8 DO flt equip & cmt + 10' new hole. Conduct formation tst to 11.5 ppg EMW. Displ well to EZ Core. Contrl drl 9-7/8" hole to 3365'. RU & cut core #1, 3365'-3388', rec'd 19.3'. Core #2 f/3388'-3419', rec'd 24.5'. Core #3, 3419'-3425', rec'd 19'. Core #4, 3425'-3444', service core bbl. MU core #5. ~ 10-3/4" @ 3172' 3930', (486'), Logging ' Wt. 9.0+, PV 20, YP 7, Sol 15 Rec'd 18.5' f/core #4. Core #5, 3444'-3475', rec'd 31' .... Core #6, 3475'-3506', rec'd 31'. TIH, drl to 3930', circ h°lei<~,~!!.~i~i'i~'i~!~]~i~;:3~,~..~i~.c~;~ TOH. RU & log DIL/GR/LSS, LDT/CNL/NGT/CAL 10-3/4" @ 3172' 3930', (0'), Cln pits Wt. 9.0, PV 5, YP 5, PH 10, WL --, Sol 3 Rn LDT/CNL/NGT/CAL w/high resolution rn. Rn VSP. Cln pits, build wtr base mud. TIH, displ hole to wtr base mud. Cln pits. The above is correct ~' j/~, }~-~...~t~.~~, .. For fo~m ~rep~atlon and dist~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate / ] Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District 1County or Parish IState Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25519 Complete record for each day while drilling or workover in progress 10/09/86 Date and depth as of 8:00 a.m. 10/10/86 10/11/86 thru 10/13/86 10/14/86 10/15/86 10/16/86 Alaska IWell no. 3K-9/3K-9A 10-3/4" @ 3172' 5507', (1577'), Drlg Wt. 9.0, PV 8, YP 4, PH 9.8, WL 9.6, Sol 3 POH. RIH w/turbine, drl 8½" hole to 5507'. 3863', 10.90°, N71.9E, 3848.00 TVD, 163.38 VS, 80.87N, 159.09E 4181', 20.40°, N87.5E, 4150.25 TVD, 259.80 VS, 101.99N, 254.48E 4528', 33.40°, S88.6E, 4449.62 TVD, 433.68 VS, 102.70N, 428.62E 10-3/4" @ 3172' 6370', (863'), Drlg Wt. 9.2, PV 5, YP 2, PH 9.1, WL 10.2, Sol 3 Drl & surv 8½" hole to 6370'. 5526', 31.1°, N83.5E, 5270.72 TVD, 999.30 VS, 106.15N, 994.90E 6032', 22.1°, N81.7E, 5721.10 TVD, 1228.02 VS, 138.43N, 1222.17E 6212', 18.5°, N77.4E, 5889.92 TVD, 1289.97 VS, 149.76N, 1283.58E 10-3/4" @ 3172' 7102', (732'), Coring Wt. 10.0, PV 15, YP 9, PH 9.4, WL 4.4, Sol 10 Drl & surv to 6967'. Core #1, 6967'-7027', rec'd 43'. Core #2, 7027'-7062', rec'd 33'. Core #3, 7062'-7102', rec'd 37'. 6401', 15.5°, N84.4E, 6070.66 TVD, 1344.94 VS, 158.60N, 1338.14E 6935', 12.5°, S82.7E, 6588.47 TVD, 1474.78 VS, 159.62N, 1468.12E , POH. 10-3/4" @ 3172' 7199', (9'), RIH Wt. 10.0, PV 13, YP 8, PH 9.0, WL 5.0, Sol 10 Core #4 f/7102'-7139', rec'd 37'. Core #5 f/7139'-7199' 10-3/4" @ 3172' 7443', (244'), Short trip Wt. 10.1, PV 17, YP 11, PH --, WL 4.2, Sol 11 Rec'd core #5. RIH to 7199', well flowing, SI & circ out ~§'~ ..... .~ . cut mud. Core #6, 7199'-7243', rec'd 44'. RIH, drl f/7243'-7443' 15 std short trip 10-3/4" @ 3172' '*, 7443 ' (0 ' ) , TIH i~.;, ...... 2 ~ Wt. 10.1, PV 17, YP 9, PH 9.5, WL 4.0, Sol 11 Short trip, spot diesel on btm, TOH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL w/hi resolution pass. Rn BHCS & FMS. RD Schl. TIH. 7443' 11° S81 75E 7085 83 TVD, 1576 33 VS, 145.63N, 1570 62E , , · , · · ' The above is correct Signatur For lorrY- p~ep~-ation and ~s~bution ' see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date / / ITitle Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official Or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week i'n which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District. ICounty or Parish 1State Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25519 Date and deptt~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. 10/17/86 Alaska IWell no, 3K-9/3K-9A 10/18/86 thru 10/20/86 10/21/86 10-3/4" @ 3172' 7443', (0'), TIH Wt. 10.1+, PV 17, YP 6, PH 9.5, WL 4.4, Sol 12 · RIH, circ & spot diesel pill, POOH, LD DP. Change of orders. TIH to 7227', spot 500' plug across Kuparuk, f/6730'-7227' (approx) w/175 sx Class G circ, POOH to 5000' & spot 300' plug f/KOP f/5060'-5300' (approx) w/150 sx Class G. Circ out cmt, POOH 92 jts, PU BHA. 10-3/4" @ 3172' 7527', (189'), Prep to rn OHL Wt. 10.4, PV 14, YP 7, PH 9.0, WL 4.4, Sol 14 WOC. 3K-9 Abandoned 10/17/86. 3K-9A commenced 1600 hrs, 10/17/86. TIH, wsh & drl to 5338'. Sidetrack hole to 7527' TD, short trip, C&C, well flowing, SI well. Circ gas cut mud, inc mud wt to 10.2 ppg, short trip, CBU. Inc mud wt to 10.4 ppg, TOH. RU Schl to rn OHL. 5062', 34.8°, S88.7E, 4881.36 TVD, 746.94 VS, 94.70N, 742.79E 6449', 33.1°, N89.4E, 6026.15 TVD, 1525.70 VS, 49.76N, 1524.13E 7527', 31.7°, N87.5E, 6940.25 TVD, 2096.91VS, 63.08N, 2095.30E 10-3/4" @ 3172' 7580', (53'), Rn'g 7" csg Wt. 10.4, PV 17, YP 6, PH 8.5, WL 4.2, Sol 14 Rn DIL/SFL/SP/CAL f/7527'-3172'. Ran GR from 7527 to 1000'. Rn FDC/CNL f/7527'-6800', RD Schl. Drl rathole to 7580', CBU, spot diesel pill, POOH, LD DP. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code North Slope Borough State Alaska IWell no. 3K-9/3K-gA District ICounty or Parish I Alaska Field ~Lease or Unit Kuparuk River I ADL 25519 Auth. or W.O. no. ~Title AFE AK1410 I Drill API 50-029-21656 cost center prior to plugging and I 56.24~ iabandonment of this well i Hour Prior status if a W.O. 10/1/86 0001 hrs. Doyon 9 Operator [ A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date Spudded Date and~depth Complete record for each day reported as of 8:00 a.m. 7" @ 7559' 7580' (0') TD, RR 10.4 ppg NaCl/NaBr brine Rn 179 its + mkr it, 7", 26#, J-55 BTC csg w/FC @ 7472', FS @ 7559'. Cmt w/650 sx 50/50 Pozz & 260 sx C1 "G". Displ w/lO.4 10/22/86 ND BOPE, Instl & tst pack-off. RR @ ppg NaCl/NaBr, bump plug. 2030 hfs, 10/21/86. Old TD Released rig 2030 hrs. Classifications (oil, gas, etc.) O±l INew TD I PB Depth 7580' TD Daie IKind of rig 10/21/86 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day 'Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITM Drilling Supervisor ARCO Alaska, Inc. Post Office Bc 30360 Anchorage, Al,..,,a 99510-0360 T~elephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5804 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tape with Listing --~ 3K-9A 10-19-86 996' --~ 3K-9 10-15-86 995' Receipt Acknowledged' Distribution' D. Wether ~ 01~ ~ ~~mi~io · ' ARC{~ Alaska, I.nc is · Subsidiary of AttanlicRichfieldCo~r, pan¥ 1. Type of Request: STATE OF ALASKA ALASKA _,L AND GAS CONSERVATION COMMIL 3N APPLICATION FOR SUNDRY APPROVALS Abandon ~, Suspend .,-1 Operation Shutdown [] Re-enter suspended well .~ Alter casing ~-_-~' Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ,~_q Perforate [] Other 2. Name of ARCO 3. Address P. 0 4. Location 1234 At top of 1317' FSL, 1794' FWL, Sec.35, T13N, At effective depth N/A At total depth 1323' FSL, 1902' FWL, Sec.35, T13N, Operator Alaska, Inc. 6. Unit or Property name · Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit of well at surface 7. Well number ' FSL, 317' FWL, Sec.35, T13N, R9E, UM 3K-9 productive interval 8. Permit number R9E, UM 86-166 9. APl number 50-- 029-21 656 10. Pool R9E, UM Kuparuk River 0il 5. Datum elevation (DF or KB) 69 ' RKB feet Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Conductor / 80' Surface ~ 3137' 7443 'MD feet Plugs (measured) 7086 ' TVD feet feet Junk (measured) feet Size 1 6" 1 0-3/4" 1. 7228'MD - 6736'MD 2. 5300'MD - 5000'MD None Cemented To surface To surface Measured depth 110'MD 3172 'MD True Vertical depth 110'TVD 31 70 ' TVD Perforation depth: measured true vertical None None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None ECEJVEi) 1986 Alaska Oil & Gas Cons. Commissior~ Anchorafie 12.Attachments Description summary of proposal~ Detailed operations program [Z BOP sketch 13. Estimated date for commencing operation October 16, 1986 14. If proposal was verbally approved Name ofapprover Mr· C. V. Chatterton Date approved 10-16-86 15. I hereby certify that the for~/going is true and correct to the best of my knowledge Signed t~) (~9"'/,/)/~ ~/~L~ ~L.,, Title Associate Engineer ~ Commission Use Only ( HRE ) SA/131 Conditions of approval Notify commission so representative may witness Approved by Form 10-403 Rev 12-1-85 Date I-q Plug integrity [] BOP Test ~ Location clearance Approved Co~p¥' J Approva, No. ¢ I 7 Commissioner by order of ~/~~ the commission Dat bul~mit/i~ triplicate APPLICATION FOR SUNDRY APPROVALS 3K-9 ABANDONMENT Kuparuk River Unit 3K-9 was drilled to a total depth of 7443'MD, 7086'TVD. Open hole logs showed that due to faulting, the Kuparuk sands were not present in commercial quantities. After evaluation of open hole logs, the decision was made to abandon the lower portion of 3K-9, plug back and sidetrack to a new bottomhole location (See Permit to Drill for 3K-9A). 3K-9 will be abandoned as follows: Cmt plug #1: (50' below to 100' above the Kuparuk sands). 175 sx Class "G" w/0.2% D-46 mixed at 15.8 ppg; 1.15 ft$/sx. From 7228' - 6736'MD. Cmt plug #2: (Kick off plug for 3K-9A). 150 sx Class "G" w/0.2% D-46 mixed at 15.8 ppg; 1.15 ft3/sx. From 5300' ~5~00'.~ 10.1 ppg mud will be left in the hole between plug #1 and plug #2. The portion of 3K-9 that is not abandoned will be used to sidetrack and drill 3K-9A. Any questions regarding this subject can be addressed to Harold Engel at 263-4882. SA/131a:dmr 10-20-86 STATE OF ALASKA ALAS AND GAS CONSERVATION COMM APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend ~ Operation Shutdown ~ Re.enter suspended well ~_ Alter casing/~' Time extension '-' Change approved program ~j~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order- PerfOrate- Other- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1234'FSL, 317,FWL, Sec.35, T13N, RgE, UM At top of productive interval 1317'FSL, 1794'FWL, Sec.35, T13N, R9E, UN At effective depth N/A At t~)t~a213d'el~hL, 1902'FWL, Sec.35, T13N, R9E, UM 5. Datum elevation (DF or KB) 69 ' RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-9 8.'Permit number 86-1 66 9. APl number 50-- 029-21 656 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Wue Verticaldepth The altered casing program is outlined on the attached summary of proposed changes. The corresponding directional information is attached. The bottom hole location will not change. Perforation depth: measUred true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ~ Detailed operations program (~ BOP sketch 13. Estimated date for commencing operation ptcrnb 29, 1986 14. If.proposal Was verbally approved None Name of approver Date approved 15. i hereby certify that the foregoing is true and correct to the besf of my knowledge Signed Title Associ ate' Engi neet Commission Use Only ( HR E ) SA/124 Date ~-~_'.'~-~ Conditions o f.~'~Pval [] Plug integrity [] BOP Test Approved Co~3y ~®turnecJ ~)/ Approved by ~y. [~{1[ ~,:SlII~ Notify commission so representative may witness [] Location clearance Commissioner J Approva, No. by order of the comm,ssion Date ./ feet i~ Form 10-403 Rev 12-1-85 Submit in triplicate SUMMARY OF PROPOSED CHANGES The subject well geometry has been altered to accomodate a West Sak core. The revised casing and cement program are listed below. · 18- Casing program ........ Settinc;i Depth - ,. size. · - S, pecifications Tol3 Bottom Quantity of cement - Hole Casing Weight Grade Coupling Leng'th MD · TVD MD TVD (include stage data) - )~i.t! ' llRlt r;? e,,~ H-/~ II/-.lf{ R~lf '~e~! ' '3, e~ f 11e[t 11e[l 4.~t'ttl · . 13-1/2"~10-3/~" ~5.5# '~l-55 RT~ ~13~' ~;t ~ ~17~ ~17~ 1~. ~x A5 I I I · ' HF- Er W 12~ sx C~ass G blend 8-1/2" 7" 26.0~. J-55 BTC 7308~ 3~ 3~~ 73~2~ 6960~ ~50,~x 50/50 poz ~ ~ HF-EFN 150 sx C3ass G - - T0C. a~ 3170'MD . ............ -__L_: ....... K-UP-A~d~-:F~ ~D',~ NORTh-S~O~ ~ ALA.S~A:'L '~'~..;_ ............................................. .. . - I ~ . . . .... z ~ ; , . . ............................................................. : .................... ~.- ........................... - .......................................... _ ~. - BASE. PER AFROST- T~D-1719 . - ! ....... , · . , ~ ....... } ~ ~ '~ ......i ' , ...... , I .. . ~ ..... ~ ~ .......~ .......~ ....... ~ ..... ........... ~ ..................................... ~ .... ~ ..................... ~ .....................~ .............. ' ~ ...... Tt U~U SHDS .... TVD"2689- ' -~ - · ~ ...... KOP~ -TVD"2838~-THD-2838 DEP-O ?. .......... ~ - ~_.:_._~ ,~ ~g EO '0 TVD-3170 THD-3171' DEP"29 ~ .... ~ T/ ~ SAK SNDS -- ~VD-33~.9 T~-3-38~- DEP~66. ' ' , ~ K-12': TV~689"~T~=~699' DEP11.21_ ~ . . , ~ - '- KOP' TVD-~889 T~'~902 _DEP'156 ....... ~ ' .. ~ P~ I~;FT .......................... BEG .... · ' BEG~N ~E DR~ TVD-5224 T~-54~' ~P-918 .......................... ?00_0.. ........................ ;---VERTICAL-SECTION K-5 TVD-5?Ig TI"ID-6047 DEP-1231 DROP 2DEe .t~--I-0~ FT- ........................ T/ ZONE D TVD-6354 TMD-6723 DEP-1459 END ANGLE DROP TVD-6400 THD-6770 DEP-1469 T/. ZONE- C TVD-64SI Tt'ID-6822 DEP-1 480 T! ZONE A TVD-6644 THD-7019 DEP-1521 TARGET CNTR TVD-6704 THD-7080 DEP-1533 BZ._.KUP SND9 .TVD=676~ THD=:?142 OEP=1546- f f TD (LOG PT) TVD=6960 TMD=7342 DEP=1588 lOGO 2GOO TARGET ANGLE 12 DEO Z C= ._. 1DOD - 20.0.0 . ~' i'' ' : '. ' _ - . ~ TARGET CENTER ........... ' ...................................................... :'~¥~--i .... .' ~ ~ -- -. MORTN- ~ -- _ I'AR~]EI' LOCAI'U311 : . . , ~ _ -TD L0CAI'[~fi.'~ , ~ _32.!1' N 86, DEG 4-7 MI N E , ', sec? 1'535' (TO '!T^RGET), , 'i i .~I t , ', 500- 600 I I I / / 3;952 / 1605 'I I i 7'00 ..... i. _ 800 ..... 700.. _ 0 1 00- 200 300 400 500 600 _ . . ~ ' - - -' i"-' ' '-~-::-:-~¥__"i:-':-...:. . i ~ . --LSQ~-~---~---:-i~' ........ ~-:-----'-'i~. ',-- ' : ~ ¥ ............................ i ......................... ~ ......................... ~ '--' ........ F-:----~--!-ii-:-_-:..-.iL:'~_-.-' -!~_. \~,~__:.-. :'_.. ' r-~~ ................... ! ...... "-- ~-' ~' ': ":' :: I ..... ....... ,400_ i- ,~ .:_-: .... :"¥-i-_i- :-~' "-...,i-~:---:'-~.'":-!'' - ' ' '-t --- ~---:" -' .......... ' ............ ~ ....t ...... : ....... ! .........., .............. ~ ..... i 1' ' ..... - ..... ~¥,--:,-":~-'~-~::----'~:::'-~-------.'---:-':,_~_ :.--- ~,, , .... i--~"----'-~--- .... ,"~-~~--:-~- ........... ¥-'i ...................... , ............... :~ .... ~ "- 1-;; .... ':---- ?- ;:-:: -:i-' .- -- :---:-~ --: -'-:--~ .... i:- :::: '-:.-i:~.. :-' :'-.- ..... ', . , ., : ...... ~:~00"_:{--'~-: .... :--~ ~! .... :- !'- '-----i .... :--::'~:' -'--'~ -'-:'~':-:"-i'-:'-:':'-'-----~-':-~ .... ~.~1~:~:._¥~_.~_i-.~.-.-- i.~ - . ~__. . .i :~,..-,,.._~.-~. .~-~.-:.-~f~---- ~i_ _-~-:--~-K--~:P~_!~-~'----'-~'--'--'-'"---~T~*--:=...------' ,-- _::, r~oo___-~_: ..... ~-?-'"~'-.~-.-~---.~- ~ ",i .... ' ............ ~:.: :_[_,' :- ~ .: ,: ::. :._,_,_- '_ .... ,. ............ 1.200:. --~ .............. t .......... ~:~-'-'=-$-' ........ ~ ................. i-: ................ ....... '- ........ ,o.~-~=: ....... :_~_:__:___~ .......... ~_ ....... t .......................... ~.~Oo,'l L'- ~ ~ ' -i .- ,~- .... ~ ~ ' I ....... -,- ........... ~: ,~-,~ ........ , ......... ~-':¥ ...... --!-: ....... ;~'-~~- ...... : ........... ¥-'r ...... ~ ............. . ................. - I--:--.--i-'-::--.' !.-.--~ :- i ' I - ~ ' I 'i" ! 000 ' ,.~.~_'~ : _: 't't :~':~ "- ~: 10 00.' l : / ~ ~ ss '1 ~ /'! 900 9,00: ........... : .... : ............... '-.._~ ............. : .......................... A ........... ! ...... m KUP~RUK R I VER UN I T 20" O I VERTER SCHEM/~T I C DESCRIPTION 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" MCR BALL VALVES DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 035 (b) ~ MA I NTENANCE & OPERAT I ON . 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUOH DIVERTER LINES EVERY !2 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOINNNINO DIVERSION. DO NOT SHUT IN WEL,,L UNDER ANY C I RCUMSTANCES,. S10084002 RI( 7 6 D'[ AGRAM #1 13-5/8" bO(X) PS]' RSRRA BOP STACK I. 16" - 2000 PSI TAN<~ STARTING HEAD 2. il" - 3000 PSI CASING HEAD 3. II" - 3000 PSI X 13-5/8" - 5CK)O PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE R/~S 5. 13-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE AhD KILL LI~ES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RAMS ON TOP, BLIhD RAMS ON BOTTCM. ?. 13-5/8" - 5000 PSI AI~ ACCUMULATOR CAPACITY TEST 1. CHECK A~ FILL ACC~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. A~ THAT ACO. NIJLATOR PRE~ IS 3000 PSI WITH 1500 PSI DO~TREAM OF THE REGIJLATOR. 5. OBSERVE TI~E, THEN CLOSE ALL UNITS SIMULTANEOUSLY AI~ RECORD THE TIt~E A~ PRESSURE RE]v~AINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLIVP OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LO/~ LIMIT IS 45 SECO~ CLOSING TIt,~ AhD 1200 PSI REMAINING PRESSURE. 5 4 2 13-5/8" BOP STACK TEST I. FILL BOP STACK AI~ Q-K)KE MANIF~ WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK DOA~ SCREWS IN WELLHEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN WELIJ-F_AD WITH RULING JT AhD RUN IN LO(~ SCREWS. 5. CLOSE AI~ PREVENTER AhD MANJAL KILL AhO CH(]<E LIhl[ VALVES ADJACENT TO BOP STACK, ALL OTHER VALVES AhD CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 5000 PSI AI~D HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN A~ PREVENTER AND MANUAL KILL AhD CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AhD CHOKE LINES. 6. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. 7. CONTI~E TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AhD 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHCI(E THAT IS NQT A FULL CLOSING POSITIVE SEAL CHOKE. ONLY FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8, OPEN TOP PIPE RAMS AN:) CLOSE BOTTCM PIPE RAMS. TEST BOTTOVl PIPE RAMS TO 250 PSI ~ 5000 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK OUT RULING JT AND PULL OUT OF HOLE. I0. CLOSE BLIND RAMS AND TEST TO 250 PSI AND 5000 PSI. I!. OPEN BLIND RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI AhD 5000 PSI. 15. RECORD TEST IhFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN, AND SEhD TO DRILLING SUPERVISOR. 14. PERFORM CC~LETE BOPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY i 5., 1985 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 13½" hole to 10-3/4" surface casing point according to directional plan. 4. Run and cement 10-3/4" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 9-7/8" hole to West Sak core point. Core West Sak interval with oil base core fluid. 8. After coring, convert oil base mud to water base, drill 8½" hole according to directional plan to Kuparuk core point. Core Kuparuk interval with water base core fluid. Drill sufficient rathole to provide 100' between plug back total depth and bottom of Kuparuk sands. Run open hole logs. 9. Run and cement 7" casing. Pressure test to 3500 psig. 10. Downsqueeze Arctic Pack and cement in 7" x 10-3/4" annulus. 11. Nipple down blow out preventer and install temporary Xmas tree. 12. Secure well and release rig. 13. Run cased hole logs. 14. Move in workover rig. Nipple up blow out preventer. 15. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 16. Perforate and run completion assembly. 17. Nipple down blow out preventer and install Xmas tree. 18. Change over to diesel and set packer. 19. Flow well'to tanks. Shut in. 20. Secure well and release rig. 21. Fracture stimulate. SHALE SHAKERS HUD CLEANER STIR ~. HUD CLEANER STIR _.~. STIR HRE/11 ih TYPICAL HUD SYSTEH SCHEHATIC DRILLING FLUID PROGRAM Spud to 10-3/4" Surface Casin9 West Sak Core Fluid 50/50 Crude~ Diesel Mixture Density 9.6-9.8 9.0-9.3 PV 15-30 yp 20-40 Vi scosi ty 50-1 O0 Initial Gel 5-15 10 Mi nute Gel 15-30 Filtrate APl 20 5O 3O 55 10 25 pH 9-10 NA Solids 10+ 10 Drill out Weight to Weight Up Up to TD 8.7-9.2 10.3 5-15 9-13 8-12 8-12 35-40 35-45 2-4 3-5 4-8 5-12 10-20 6 9.5-10.5 9.5-10.5 4-7 9-12 Drillin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. HRE/10 ih / ?(:; - I (p 0 BOOS SCHOON ST., ANCHORAGE, ALASKA 99518 (907) 349-3541 CORE LABOR01ORlES, IHe. . - CORE ANALYSIS REPORT KRU 1t3K9 Kuparuk Field West Sak Formation North Slope, Alaska 19-Jan-87 8005 SCHOON ST., ANCHORAGE, ALASKA 99518 (907) 349·3541 : .-- CORE LABORA1ORIES, IHe. . J - Section A Summary of Procedures - , ...... KRU #3K9 Kuparuk Field West Sak Formation North Slope, Alaska 19-Jan-87 , - >-- Introduction .:.- Whole Core samples from Kuparuk #3K-9 we11- West Sak Formation were submitted to the Anchorage, Alaska Core Laboratories facility for an extensive series of core analysis measurements. The following is an outline of the procedures utilized in analyzing Kuparuk #3K-9 West Sak formation. JL.-< .. Methodology .. We11site Handling ... Cores were recovered, marked and cut into three foot lengths by Arco personnel at the we11site. Cores were shipped, frozen to the Anchorage Core Laboratory facility. .... ~ Core Gamma Surface Log Gamma Radiation was measured on the entire core utilizing the Core Lab Gamma Logger instrument. The results are reported on the Core Analysis Correlation Coregraph. -:l Laboratory Sampling The three foot core sections were slabbed lengthwise 3/4, 1/4 cut with liquid C02 gas used as the saw coolant. The 1/4 cut portion was covered with transparent 1ucite and utilized as a library set for visual examination. From the 3/4 portion of the core two 1 x 1.5 inch plugs were extricated from each foot for helium porosity, air permeability, and Dean Stark method fluid measurements. Plugs were taken approximately .5 feet apart and from the center of the core with liquid C02 used as the bit coolant. In unconsolidated oil saturated sand sections, liquid nitrogen was used. The remaining 3/4 sections were placed in refrigerated storage at the Anchorage Core Lab facility. - - The samples were trimmed and placed in lead sleeves with 120 mesh screens at the end of each sample and seated frozen at 500 psi. One in. by one in. chips were taken from each foot, wrapped in foil, placed in plastic bags, and shipped to the Arco warehouse in Anchorage, Alaska. -"- Laboratory Procedures ~ Fluid Saturations ...... Fluid saturations were determined by the Dean Stark method. Fresh weights were measured, samples put in thimbles, and then placed in a Dean Stark apparatus for a minimum of 12 hours. Dean Stark recovery readings were then recorded . The samples were then saturated in toluene and an Archimedes Bulk volume measured. The samples were then placed in a Full Diameter Dean Stark Apparatus for hydrocarbon extraction approx. 10 days or until thoroughly clean indicated by no fluorescence under a U.V. light. Once cleaned, the samples were dried in a vacuum oven for a minimum of 24 hours at 150 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. .. "". ,.., -4 -' Porosity Grain volumes were determined after the samples were de-sleeved with a Boyle's Law-Helium Heise Gauge Porosimeter. Bulk volumes were measured by the Archimedes method with toluene utilized as the saturating fluid. Porosity - Overburden - - Pore volumes were measured at 1000 psi confining stress utilizing a hydrostatic holder and a Boyles Law - Helium Heise Gauge Porosimeter. Permeability - Overburden Horizontal permeability to air was measured utilizing a steady state permeameter with a 1000 psi boot pressure. ~ - Plug Analysis - CMS-200 Automated system - In order to simulate reservoir stress conditions, plug samples were run at requested confining stresses in the CMS-200 Automated Core Measurement System. For each sample, a Klinkenberg equivalent liquid permeability, an estimated air permeability, and a helium porosity was measured at confining stresses of 1000, 2000, and then again at 1000 psi. The results are reported in the Tabular section of this report, along with hydrostatic holder measurements for comparison. ~ ..... The Appendices contains technical information concerning plug analysis at overburden conditions utilizing the CMS-200. ..... Core Photography The core was photographed in white and ultaviolet light using a one ft. of core/six in. format. As requested three sets of laminated white and U.V. core photographs are submitted. .. ... Special Conditions ~ Catscan Project ..... Core Lab personnel assisted in the Catscan project which took place at the Providence Hospital in Anchorage, Alaska. - The core was transported from a freezer van to the catscanning room where it was Catscanned in three foot sections. An insulated container packed with gel ice was used to insure that the core remained frozen during the operation. A Catscan Time Log and Inventory which outlines the time the core was out of the freezer and inventory of the specific cores catscanned is included in the tabular section of this report. -- Removed Core Intervals - As requested by Arco Alaska, specified sections of the core, outlined below, were removed before slabbing. They were then dipped in Seal Peal and then immediately frozen. They currently remain in house awaiting instructions. - 1.) 3413.3 - 3413.8* 2.) 3467.4 - 3467.9* * Post Slabbing Depths - - 8005 SCHOON ST., ANCHORAGE, ALASKA 99518 (907) 349-3541 CORE LABORA1ORIES, IHe. . - section B Core Analysis Results - Tabular Data - - KRU #3K9 Kuparuk Field West Sak Formation North Slope, Alaska 19-Jan-87 - - - - - - 1_ /?~ - /~ ~ KRu 3(- 9' 1- - - Tabular Data Dean Stark Analysis - , ÌIIII 1 ,..... - - - I J I I J ARCO ALASKA NC. DATE 9-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TlS,RGC KUPARUK FIELD DRLG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION --- .............. ............ .. .... .. .. .. .. ......- ........ ........ --- ......................... CORE #1 3365.0 - 3386.7 1A 3365.2 0.46 27.0 24.4 3.6 82.2 2.73 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 1B 3365.7 0.31 26.8 24.3 0.0 85.7 2.74 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 2A 3366.2 0.87 25.9 23.7 0.0 85.9 2.72 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 2B 3366.7 0.20 26.5 24.3 0.0 86.7 2.74 SLTST/LT-MLTGY/VARG/SDY/SLCALC/MNR PYR BLEB 3A 3367.2 0.31 27.0 24.4 0.0 89.4 2.74 SLTST/LT-MLTGY/VARG/SDY/SLCALC/MNR PYR BLEB 3B 3367.7 0.12 28.0 24.9 0.0 85.0 2.77 SLTST/LT-MLTGY/VARG/SDY/SlCAlC/MNR PYR 4A 3368.2 0.28 27.7 25.0 0.0 84.8 2.75 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 4B 3368.7 0.55 27.5 24.9 0.5 84.1 2.74 SLTST/lT-MlTGY/VARG/SDY/SLCALC/MNR LAMS/TR SA 3369.2 0.16 27.2 24.3 0.7 85.3 2.74 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 5B 3369.7 0.29 27.8 24.7 0.6 84.7 2.74 SLTST/LT-MLTGY/VARG/SDY/SLCALC/TR PYR 6A 3370.2 0.31 27.3 24.4 2.3 85.2 2.73 SLTST/LT-MLTGY/VARG/SDY/SLCAlC/TR PYR 6B 3370.7 0.57 26.9 24.3 2.0 84.9 2.73 SLTST/LT-MlTGY/VARG/SDY/SLCAlC/MNR PYR 7A 3371.2 0.25 26.7 24.2 0.4 89.0 2.73 SlTST/LT-MLTGY/VARG/SDY/SL CALC/MNR PYR 7B 3371 .7 0.37 27.0 24.4 0.8 87.5 2.73 SlTST/lT-MlTGY/VARG/SDY/SLCALC/MNR PYR 8A 3372.2 0.37 27.5 24.7 0.1 86.9 2.75 SLTST/LT-MlTGY/VARG/SDY/SLCAlC/TR PYR 8B 3372.7 0.48 26.6 24.8 0.9 85.6 2.71 SLTST/LT-MLTGY/VARG/SDY/SlCALC/TR PYR 9A 3373.2 3.03 28.6 26.2 21.4 61.4 2.69 SS/LT OLVGY/VF-FGR/PRED VFGR/SlTY/SLFRI 9B 3373.7 0.34 27.4 24.8 7.1 78.3 2.72 SS/LT OLVGY/VFGR/SLTY/SLCALC/SLFRI/POSS MAGN 10A 3374.2 0.27 26.8 24.3 10.6 75.7 2.74 SS/LT OLVGY/VFGR/SLTY/SlCALC/TR PYR/POSS MAG 10B 3374.7 0.26 26.5 24.1 8.0 77.2 2.73 SS/lT OlVGY/VFGR/SLTY/SlCALC/TR PYR 11A 3375.2 0.68 26.2 23.7 6.9 79.4 2.74 SS/LT OLVGY/VFGR/SLTY/SLCALC/MNR PYR page j J I I I I I I 1 -~ ARCO ALASKA, INC DATE 19-JAN-87 FILE : 8P-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRLG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION --- .... ........ -.......... ..... .. ......... ...... .. .... .... ....-.. - - - .. .. ...... .... ...... .. .. 118 3375.7 1.31 26.5 24.3 8.9 76.0 2.72 SS/LT OLVGY/VFGR/SLTY/SLCALC/SLFRI 12A 3376.2 3.99 28.8 26.3 13.3 67.3 2.70 SS/LT OLVGY/VFGR/SLTY/TR CALC/SLFRI 12B 3376.7 4.01 27.7 25.7 14.5 69.8 2.70 SS/LT OLVGY/VFGR/SLTY/TR CALC/SLFRI 13A 3377.2 2.83 28.4 25.4 11.9 64.1 2.71 SS/lT OlVGY/VFGR/SLTY/TR CALC/SLFRI/TR PYR 13B 3377.8 3.28 29.0 26.5 24.5 51.1 2.69 SS/LT OlVGY/VFGR/SLTY/SLFRI/TR PYR 14A 3378.2 3.30 28.7 25.8 11.3 64.8 2.71 SS/LT OLVGY/VFGR/SLTY/TR CAlC/SlFRI 14B 3378.7 5.35 31.8 28.2 28.3 50.3 2.72 SS/LT OlVGY/VFGR/SLTY/FRI/TR PYR 15A 3379.2 7.54 29.6 26.8 23.2 56.8 2.72 SS/LT OLVGY/VFGR/SLTY/SLCALC/FRI 15B 3379.1 16.52 31.3 28.7 35.7 45.0 2.69 SS/LT OLVGY/VFGR/SLTY/FRI 16A 3380.2 8.14 30.1 27.0 25.7 51.8 2.70 SS/LT OlVGY/VFGR/SLTY/TR CALC/SLFRI 16B 3380.6 10.00 31.5 27.6 25.9 48.9 2.72 SS/lT OLVGY/VFGR/SLTY/FRI 17A 3381.1 14.98 30.5 27.7 33.5 44.6 2.68 SS/lT OlVGY/VFGR/SLTY/FRI 17B 3381.5 123.11 34.8 30.7 51.3 28.4 2.69 SS/lT OLVGY/VFGR/SlTY/FRI 18A 3382. 1 6.43 29.5 25.9 19.9 60.8 2.71 SS/LT OLVGY/VF-FGR/CALC/FRI 188 3382.9 1.01 29.9 26.3 15.9 63.2 2.76 SLTST/lTGY/VARG/SDY/CALC/INTBD VFGR SS 19A 3383.2 NO ANALYSIS - DISAGGREGATED SAMPLE 19B 3383.7 2.50 30.5 27.1 21.9 56.5 2.73 SS/lT OlVGY/VFGR/SLTY/SlCALC/SLFRI 20A 3384.2 5.76 32.2 28.9 33.5 51.1 2.75 SS/LT OLVGY/VFGR/SLTY/CAlC/FRI 20B 3384.1 7.01 29. 26.6 16.4 65.9 2.79 MDST/LT-MLTGY/SLTY/VCALC/ABNT VFGR SDY lAMS 21A 3385.2 NO ANALYSIS - DISAGGREGATED SAMPLE 21B 3385.7 NO ANALYSIS - DISAGGREGATED SAMPLE 22A 3386.2 NO ANALYSIS - DISAGGREGATED SAMPLE 22B 3386.7 NO ANALYSIS - DISAGGREGATED SAMPLE page 2 1 r" r 1 I 1 } 1-' I ARCO ALASKA NC. DATE : 19-JAN-87 FILE BP-3-1188 KRU #3K-9 FORMATION : WEST SAK ANALYSTS TLS,RGC KUPARUK FIELD DRlG FlD : OBM lABORATORY ANCHORAGE NORTH SLOPE, ALASKA LOCATION : T13N-R9E-Sec35 API 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION -.. ............... .... ...... .... .. ............ -..-.. ........ ....-- - .. ................---- CORE #2 3387.0 - 3413.0 23A 3387.2 581 . 16 42.6 38.5 73.7 13.3 2.67 SS/LT OLVGY/VF-FGR/UNCONS SD 23B 3387.8 488.80 41.4 37.3 69.8 13.5 2.69 SS/OLVGY/VFGR/UNCONS SD/TR PYR 24A 3388. 1 491.79 42.3 38.0 69.1 12.7 2.69 SS/OLVGY/VF-FGR/UNCONS SD 248 3388.7 810.03 43.7 37.6 71.9 11.3 2.68 SS/OLVGY/VF-FGR/UNCONS SD 25A 3389.2 1167.47 42.9 37.8 73.8 8.4 2.68 SS/OLVGY/VF-FGR/UNCONS SD 258 3389.8 1026.52 43.2 38.4 71.1 13.2 2.70 SS/OLVGY/VF-MGR/PRED VFGR/UNCONS SD/FOS 26A 3390.2 85.10 39.5 34.6 54.3 23.5 2.74 SLTST/LT OLVGY/ARG/SL CALC/P CONS 26B 3390.7 0.32 32.1 28.0 0.6 84.9 2.85 SLTST/LT OLVGY/ARG/CALC @Q 27A 3391. 2 61.48 34.2 30.9 31.0 45.8 2.70 SS/LT OLVGY/VFGR/SLTY/VFRI 278 3391.7 17.07 32.2 28.2 15.5 56.9 2.74 SS/LT OLVGY/VFGR/VWElL SRTD/FRI 28A 3392.2 0.14 32.2 28.3 0.4 84.2 2.80 SLTST/LTGY-LT OLVGY/ARG/CAlC/CONS 28B NO ANALYSIS - DISAGGREGATED SAMPLE 29A NO ANALYSIS - DISAGGREGATED SAMPLE 29B 3393.7 107.86 35.9 32.6 33.3 39.2 2.70 SS/LT OLVGY/VFGR/MNR SLT/VFRI @Q 30A 3394.2 1.00 31.1 27.2 7.5 74.0 2.70 SLTST/LTGY/VARG/SLCALC/ABNT PYR/CARB FRAGS 30B 3394.7 4.86 31.0 28.1 38.9 41.0 2.72 SS/LT OLVGY/VFGR/SLTY/SLCALC/FRI/MNR SLTST 31A 3395.2 50.49 34.8 32.1 39.2 38.1 2.71 SS/LT OLVGY/VFGR/SLTY/SLCALC/FRI QQ 318 3395.8 233.00 39.7 35.6 48.4 26.2 2.70 SS/OLVGY/VFGR/VWELL SRTD/UNCONS 32A 3396.2 0.74 31.1 27.2 10.5 70.4 2.75 SLTST/LT-MlTGY/VARG/SLCALC/MNR BDD SD 328 3396.7 82.05 36.4 33.1 49.3 28.1 2.69 SS/LT OLVGY/VFGR/SLTY/SlCALC/FRI/TR PYR 33A 3397.2 0.87 32.0 28.2 8.2 76.9 2.75 SLTST/lT-MLTGY/VARG/CALC/MNR LAMS/TR PYR 33B 3397.7 84.93 35.9 32.7 48.7 29.8 2.71 SS/LT OLVGY/VFGR/SLTY/TR CALC/FRI QQ page 3 1 "-- -"" } -' I í f I J ) J 1 [ r J ARCO ALASKA, INC. DATE 9-JAN-87 FILE 8P-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TlS,RGC KUPARUK FIELD DRLG FlD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION - -- .... ....... .. ......... ..- .. ............. ......... ........ ........ - -- .......... .... .......... 34A 3398.2 33.56 36.1 32.5 34.3 39.4 2.69 SS/LT OLVGY/VFGR/SLTY/FRI 348 NO ANALYSIS - DISAGGREGATED SAMPLE 35A NO ANALYSIS - DISAGGREGATED SAMPLE 358 3399.7 40.95 35.5 32.4 29.4 42.7 2.76 SS/LTOLV-OLVGY/VFGR/VWElL SRTD/FRI 36A 3400.1 50.42 36.7 33.3 46.3 34.2 2.71 SS/LT OLVGY/VFGR SLTY/FRI 368 3400.7 152.70 37.9 34.4 50.9 30.1 2.70 SS/OLVGY/VFGR/VWELl SRTD/FRI 37A 3401.2 166.44 38.1 34.6 35.5 27.6 2.71 SS/LT OLVGY/VFGR/SlTY/FRI 378 3401.7 4.89 35.1 31.1 25.1 49.8 2.72 SLTST/LT OlVGY/ARG/TR CALC/SDY LAMS 38A 3402.1 28.24 36.5 32.7 44.2 35.4 2.71 SS/LT OLVGY/VFGR/SLTY/FRI 38B 3402.8 95.15 37.4 33.6 45.4 34.5 2.74 SS/LT OLVGY/VFGR/SLTY/lAM CGR SD/PYR @Q 39A 3403.2 42.38 34.8 31.5 46.8 35.8 2.69 SS/LT OLVGY/VF-FGR/PRED VFGR/SLTY @Q 398 3403.7 38.72 37.0 33.0 43.5 34.8 2.75 SS/LT OLVGY/VFGR/SLTY/FRI/TR PYR 40A 3404.1 32.36 36.1 32.4 47.6 31.6 2.73 SS/LT OLVGY/VFGR/SlTY/FRI 40B 3404.7 1.59 30.7 27.3 12.5 69.5 2.72 SS/lT OLVGY/VF-FGR/SLTY/FRI 41A 3405.2 209.04 37.7 34.6 61.8 24.9 2.69 SS/lT OLVGY/VFGR/SLTY/FRI @Q 41B 3405 .7 8.86 34.8 31.3 29.1 44.6 2.71 SLTST/LT OLVGY/ARG/SDY/CONS 42A 3406. 1 16.82 34.0 30.4 13.4 69.1 2.74 SS/LT OLVGY/VFGR/SlTY/FRI/INTBD SLTST/PYR 428 3406.7 16.78 34.0 30.7 26.1 50.1 2.73 SS/LT OLVGY/VFGR/SLTY/FRI/PYR BlE8S 43A 3407.2 8.64 32.6 29.1 21.2 57.5 2.74 SLTST/LT-MlTGY/VARG/SDY/SlCAlC/TR PYR 43B 3407.8 21.43 34.1 31.1 27.5 51.1 2.71 SS/lT OlVGY/VFGR/SLTY/FRI/BIOTUR8 44A 3408.2 4.69 31.7 29.0 12.2 69.2 2.71 SS/LT OLVGY/VFGR/SLTY/FRI/PYR/SLTY BURS 44B 3408.7 54.50 35.0 32.4 32.3 44.2 2.71 SS/LT OLVGY/VFGR/SLTY/FRI/TR PYR 4SA 3409.2 44.92 34.5 31.4 27.5 53.3 2.70 SS/LT OLVGY/VFGR/SLTY/FRI/MNR MDST 45B 3409.7 NO ANALYSIS - DISAGGREGATED SAMPLE page 4 J -' J I I 1 ) ! I ) ~ .-0 1--.-.--""'11 ---.-' ARCO ALASKA, INC. DATE 19-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRLG FlD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION - .. ....... .. ...... .. .. ........... .... .... .... ........ ......... ......... ....... .. --......-............ 46A 3410.2 542.44 39.2 35.9 49.1 23.5 2.71 SS/LT OLVGY/VFGR/MNR SLT/VfRI 46B 3410.7 3.49 31.0 28.3 9.6 73.0 2.71 SLTST/LT OLVGY/VARG/SDY/SLCALC/POSS MAGN 47A 3411.2 145.21 37.6 33.8 33.7 39.2 2.72 SS/LT OLVGY/VFGR/SLTY/VFRI aa 478 3411.7 NO ANALYSIS - DISAGGREGATED SAMPLE 48A 3412.2 NO ANALYSIS - DISAGGREGATED SAMPLE 48B 3412.7 NO ANALYSIS - DISAGGREGATED SAMPLE CORE #3 NO RECOVERY CORE #4 3413 - 344D.5 49A 3413.2 4.80 28.3 26.3 16.7 67.9 2.70 SLTST/lTGY/VARG/SDY/SlCAlC/ABNT INTBD SS 498 3413.7 NO ANALYSIS - DISAGGREGATED SAMPLE 50A 3414.2 0.68 29.7 27.6 3.3 85.7 2.73 SLTST/LT-MLTGY/VAGR/SDY/SLCALC/TR MAGN SOB 3414.7 0.46 29.4 27.3 5.8 83.0 2.75 SLTST/LT-MLTGY/VAGR/SDY/SLCALC/TR MAGN 51A 3415.2 0.41 29.7 27.3 0.4 85.9 2.75 SLTST/LTGY/VARG/SDY/SLCAlC 51B 3415.7 0.26 28.2 25.6 8.5 80.5 2.78 SlTST/LTGY/VARG/SDY/SLCALC/PYR/POSS MAGN 52A 3416.2 0.62 28.5 25.9 5.1 84.8 2.74 SLTST/LTGY/VARG/SDY/SLCALC/MNR PYR/TR MAGN 52B 3416.7 0.65 28.5 26.1 1.4 85.2 2.75 SlTST/LTGY/VARG/MNR SD/SLCALC CMT/PYR 53A 3417.2 0.42 28.6 26.2 0.4 85.0 2.76 SLTST/LTGY/VARG/MNR SD/SLCALC CMT/PYR 53B 3417.7 0.28 28.3 26.0 0.0 88.1 2.76 SLTST/LTGY/VARG/MNR SD/SLCAlC CMT/CARB 54A 3418.2 0.58 27.9 25.9 0.0 88.5 2.77 SLTST/LTGY/SL CALC/MOD CONS 548 3418.7 0.54 28.0 25.5 0.9 87.4 2.76 SLTST/LTGY/VARG/SL CALC/MOD CONS 55A 3419.2 0.17 28.2 25.4 0.8 87.2 2.77 SLTST/LTGY/VARG/MOD CONS 55B 3419.7 0.31 27.7 25.8 3.8 84.9 2.75 SLTST/LTGY/VARG/SL CALC/MOD CONS page 5 r p 1-- .... I~ I I I I I .. }.. ARCO ALASKA, INC. DATE 19-JAN-87 FILE : 8P-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRlG FLD OSM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION --- .......... .. ...... ..... ............. .. .. .... .. ........ ........ - - - .... .................... 56A 3420.2 0.42 28.4 26.5 1.1 87.9 2.74 SlTST/lTGY/VARG/MOD CONS 568 3420.7 0.47 29.7 25.9 1.2 87.5 2.75 SLTST/VARG/Sl CALC/MOD CONS 57A 3421.2 0.88 28.2 25.4 2.6 85.5 2.74 SlTST/VARG/SL CALC/HOD CONS 578 3421.7 0.24 28.2 25.5 3.2 84.3 2.74 SLTST/LTGY/SL CALC/MOD CONS 58A 3422.3 0.48 28.1 25.6 4.8 83.0 2.74 SLTST/LTGY/SL CALC/MOD CONS 58B 3422.7 0.62 28.9 26.2 10.2 74.6 2.73 SlTST/LTGY/SL CALC/MOD CONS 59A 3423.2 1.03 28.7 25.9 3.8 83.4 2.74 SlTST/lTGY/Sl CALC/MOD CONS 598 3423.7 1.14 28.8 26.3 9.0 75.2 2.76 SLTST/LTGY/Sl CALC/MOD CONS 60A 3424.2 1.18 29.5 26.0 1.5 60.3 2.77 SLTST/LTGY/SL CALC/MOD CONS 60B 3424.7 1.52 28.7 26.4 11.7 71.8 2.74 SLTST/LTGY/SL CALC/MOD CONS 61A 3425.2 1.19 27.9 25.7 7.5 74.9 2.73 SLTST/LTGY/VARG/Sl CALC/SL FRI-FRI 618 3425.7 4.04 30.7 28.0 14.6 66.4 2.72 SS/LT OlVGY/VFGR/VWELL SRTD/SL FRI 62A 3426.2 6.35 32.5 29.2 13.4 66.5 2.72 SS/LT OLVGY/VFGR/VWEll SRTD/SL FRI 62B 3426.8 13.18 33.9 29.9 18.1 60.1 2.70 SS/LT OLVGY/VFGR/VWELL SRTD/SL FRI 63A 3427.2 6.91 32.2 29.2 14.7 64.8 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 638 3427.7 3.30 30.2 27.7 5.8 77.3 2.71 SS/LT OLVGY/VFGR/VWELl SRTD/SL FRI 64A 3428.2 0.26 29.6 27.4 1.7 85.5 2.82 SLTST/lTGY-lT OLVGY/VARG/CALC/CONS 648 3428.7 <.01 4.3 4.2 0.0 92.3 2.75 SS/MGY/VFGR/VWELL SRTD/VCALC/W CONS 65A 3429.2 1. 71 33.5 31.1 8.5 73.4 2.77 SS/MGY/VFGR/VWELL SRTD/CALC/FRI 658 3429.8 6.49 33.3 29.7 10.5 68.5 2.74 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 66A 3430.2 1.36 30.7 28.6 7.7 71.4 2.74 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 668 3430.8 3.74 32.1 28.9 12.1 68.9 2.73 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 67A 3431. 1 2.83 31.6 28.5 9.0 73.2 2.71 SS/lTGY/VFGR/VWEll SRTD/CAlC/FRJ 678 3431.8 6.18 34.0 30.4 9.7 70.3 2.73 SS/lT OlVGY/VFGR/WELL SRTD/FRJ page 6 I ] .., -- r .....·1· Io~_··,_ .-.... .... _~. __......I .......--......... ..--..-.........., I 1 J \ ARCO ALASKA, INC. DATE 19-JAN-87 FILE : BP-3-1188 KRU #3K-9 FURMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRlG FlD OBM lABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCA TI ON T 13N - R9E - Sec35 API : 50-0292-1656-00 DEAN-STARK lEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PS SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION .. - ............ .. ..-........... ............ .. ...... ........ .......... - .. ...................... .. 68A 3432.3 1.35 32.3 29.0 8.2 78.5 2.73 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 688 3432.8 4.39 32.1 29.0 5.7 76.3 2.72 SS/LTGY/VFGR/VWEll SRTD/CALC/FRI 69A 3433.2 8.16 33.6 30.9 14.9 64.8 2.71 SS/lTGY/VFGR/VWEll SRTD/CAlC/FRI 69B 3433.7 7.52 33.0 30.4 13.8 66.1 2.69 SS/lTGY/VFGR/VWELL SRTD/CALC/FRI 70A 3434.2 8.63 34.2 30.9 11.9 67.2 2.71 SS/lTGY/VFGR/VWELl SRTD/CAlC/FRI 708 3434.7 4.48 33.3 30.2 14.3 66.7 2.71 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 71A 3435.2 1.72 31.3 28.6 7.2 76.8 2.73 SS/lTGY/VFGR/VWELL SRTD/CALC/FRI 718 3435.7 2.79 32.3 29.8 9.5 74.8 2.70 SS/lTGY/VFGR/VWElL SRTD/CAlC/FRI 72A 3436.3 4.99 32.8 30.3 7.8 75.4 2.72 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 728 3436.7 5.78 33.7 30.8 12.7 68.9 2.70 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 73A 3437.2 13.60 34.7 31.9 15.0 65.5 2.71 SS/LTGY/VFGR/VWELL SRTD/CALC/FRI 738 3437.7 15.27 35.2 32.5 11.7 68.0 2.71 SS/LTGY/VFGR/VWElL SRTD/CALC/FRI 74A 3438.3 7.03 35.4 31.3 20.5 64.2 2.72 SS/LTGY/VFGR/VWELl SRTD/Sl CALC/FRI 748 3438.7 8.73 36.7 32.1 22.2 64.7 2.74 SS/LTGY/VFGR/VWELL SRTD/Sl CALC/FRI 75A 3439.2 0.94 33.6 30.3 0.3 83.5 2.77 SLTST/LTGY/VARG/SDY/CALC/CONS 75B 3439.6 3.86 33.8 30.6 7.0 74.3 2.73 SS/lTGY/VFGR/VWELL SRTD/Sl CALC/FRI 76A 3440.2 NO ANALYSIS - DISAGGREGATED SAMPLE CORE #5 3440.5 - 3472.0 768 3440.6 NO ANALYSIS - DISAGGREGATED SAMPLE 77A 3441.2 8.38 36.2 32.4 14.5 61.5 2.74 SS/LTGY/VFGR/VWELL SRTD/Sl CALC/FRI 77B 3441. 7 1.97 28.5 26.8 0.9 83.9 2.72 SS/LTGY/VF-CGR/P SRTD/SL CALC/FRI 78A 3442.2 1.67 28.7 25.7 0.5 89.3 2.72 SLTST/LTGY/VARG/SL CALC/MOD CONS page 7 r }o ~ .. L L I I I 1 -' L ~ ~ ARCO ALASKA, INC. DATE 19-JAN-87 FILE BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRLG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA lOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MO POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION .. - ..---- ....... .. .. .. ...... .. - ...... .. .... .. .. .. ...... - -- ----..------.. 78B 3442.7 0.20 29.5 26.0 0.6 87.8 2.76 SLTST/LTGY/VARG/SL CALC/MOD CONS 79A 3443.2 0.24 30.5 27.1 0.3 85.2 2.79 SLTST/LTGY/VARG/SL CALC/MOD CONS 798 3443.7 0.43 29.5 27.2 0.7 86.6 2.76 SlTST/LTGY/VARG/SL CALC/MOD CONS 80A 3444.2 0.17 29.1 26.7 0.8 84.8 2.75 SLTST/LTGY/VARG/SL CALC/MOD CONS 808 3444.7 0.49 29.1 26.1 0.6 86.1 2.75 SLTST/LTGY/VARG/SL CALC/MOD CONS 81A 3445.2 0.90 30.3 27.7 0.0 83.2 2.76 SLTST/LTGY/VARG/Sl CALC/MOD CONS 818 3445.7 0.57 29.5 27.0 0.0 88.5 2.76 SLTST/LTGY/VARG/SL CALC/MOD CONS 82A 3446.2 0.47 31.2 27.8 2.1 82.6 2.76 SlTST/LTGY/VARG/SL CALC/MOD CONS 828 3446.7 0.49 31.0 27.8 0.7 87.5 2.75 SLTST/LTGY/VARG/SL CALC/MOD CONS 83A 3447.2 0.66 31.4 28.1 0.0 87.9 2.76 SLTST/LTGY/VARG/SL CALC/MOD CONS 838 3447.7 0.91 32.2 28.9 0.0 86.4 2.77 SLTST/LTGY/ARG/Sl CALC/MOD CONS 84A 3448.2 0.09 29.6 27.0 0.0 88.6 2.77 SLTST/LTGY/VARG/SL CALC/MOD CONS 848 3448.7 0.76 29.8 27.1 0.0 87.5 2.76 SLTST/LTGY/VARG/SL CALC/MOD CONS 85A 3449.2 0.64 29.6 27.0 0.0 89.3 2.77 SLTST/LTGY/VARG/SL CALC/MOD CONS 858 3449.7 1.09 28.7 26.2 0.0 89.0 2.77 SLTST/LTGY/VARG/SL CALC/MOD CONS 86A 3450.2 0.18 27.3 24.2 0.5 81.2 2.75 SLTST/LTGY/VSOY/20-30% SO/MOD CONS 868 3450.7 0.55 25.8 23.1 0.7 83.9 2.72 SS/LT-OKGY/VF-VCGR/P SRTO/SL FRI 87A 3451.2 1.45 26.5 23.8 13.2 69.3 2.71 SS/LT-DKGY/VF-VCGR/P SRTD/SL FRI 878 3451.8 39.10 35.4 32.4 41.6 37.2 2.71 SS/LT OLVGY/VFGR/VWELl SRTD/FRI 88A 3452.1 49.12 36.7 32.5 38.3 40.4 2.70 SS/LT OLVGY/VFGR/VWELl SRTD/FRI 888 3452.7 70.44 35.9 32.9 41.8 38.3 2.73 SS/lT OLVGY/VFGR/VWEll SRTD/FRJ 89A 3453.2 NO ANALYSIS - DISAGGREGATED SAMPLE 898 3453.7 10.29 32.8 29.2 15.2 67.7 2.72 SS/lT OLVGY/VFGR/VWELL SRTD/FRJ 908 3454.2 48.14 36.2 32.9 40.4 40.8 2.73 SS/lT OlVGY/VFGR/VWEll SRTD/FRJ page 8 ~.._---- 1 --...... 1 .......~ I ----.... I r I r ---r ARCO ALASKA, INC. DATE 19-JAN-87 FilE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRlG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA lOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) Oll% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION ....... ............ ........... .. ... .... ........ ...... ...... -- - ......................... 90A 3454.7 0.83 30.4 27.4 1.8 81.9 2.75 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 91A 3455.2 2.70 30.7 27.5 4.2 76.8 2.73 SS/MGY/VFGR/VWEll SRTD/FRI 918 3455.8 2.63 31.0 27.8 10.6 70.6 2.73 SS/MGY/VFGR/VWELL SRTD/FRI 92A 3456.2 2.70 32.4 28.3 9.6 68.5 2.73 SS/MGY/VFGR/VWELl SRTD/FRI 92B 3456.7 3.66 32.6 28.9 19.3 59.5 2.74 SS/MGY/VFGR/VWELl SRTD/FRI 93A 3457.2 7.69 33.0 29.6 22.3 55.4 2.72 SS/MGY/VFGR/VWELL SRTD/FRI 93B 3457.8 17.07 34.1 30.1 29.6 49.5 2.73 SS/MGY/VFGR/VWELL SRTD/FRI 94A 3458.2 8.54 33.4 29.5 23.8 54.3 2.72 SS/MGY/VFGR/VWELL SRTD/FRI 94B 3458.7 7.73 33.2 29.3 24.0 53.7 2.73 SS/MGY/VFGR/VWElL SRTD/FRI 95A 3459.2 18.28 35.6 30.5 36.3 41.2 2.73 SS/MGY/VFGR/VWELL SRTD/FRI 95B 3459.8 30.82 36.0 32.5 35.3 42.0 2.74 SS/LT OlVGY/VFGR/VWELL SRTD/FRI 96A 3460.2 14.96 33.3 29.9 31.0 48.3 2.70 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 96B 3460.7 0.01 7.0 6.9 0.0 83_2 2.75 SS/LT OLVGY/VFGR/VWElL SRTD/FRI 97A 3461.2 <.01 7.1 6.9 0.1 81.2 2.74 SS/LT OLVGY/VFGR/VWElL SRTD/FRI 978 3461.7 <.01 4.5 4.4 0.0 83.0 2.74 SS/MGR/VFGR/VWELL SRTD/FRI 98A 3462.2 <.01 4.1 4.0 0.0 91.3 2.74 SS/MGR/VFGR/VWELL SRTD/FRI 988 3462.7 <.01 4.1 4.0 0.0 87.1 2.74 SS/MGR/VFGR/VWELL SRTD/FRI 99A 3463.2 0.21 9.0 8.8 4.3 82.6 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 99B 3463.7 NO ANALYSIS - DISAGGREGATED SAMPLE 100A 3464.3 46.33 33.2 30.1 35.1 42.3 2.71 SS/lT OlVGY/VFGR/VWEll SRTD/FRI 100B 3464.6 41.25 33.5 30.7 28.1 57.2 2.81 SLTST/LT OLVGY/20%SS/ARG/CALC/CONS 101A 3465.2 NO ANALYSIS - DISAGGREGATED SAMPLE 1018 3465.7 165.00 37.3 33.8 54.3 25.7 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 102A 3466.3 453 .09 41.9 37.6 62.3 14.0 2.72 SS/LT OlVGY/VFGR/VWELL SRTD/FRI page 9 r ~-~--- ---...... -. -- ---- - --- I r ] I J I -, 1 ARCO ALASKA NC. DATE 9-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TlS,RGC KUPARUK FIELD DRLG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION ...... .. ............ .. .. ............. ..... ........ .... ..... .. .. .. .. .. ...... - .. .. ...... .. .. ... ..... .. .. .. 102B 3466.7 395.44 38.4 35.0 39.9 23.0 2.72 SS/LT OLVGY/VFGR/VWELL SRTD/VFRI 103A 3467.2 386.54 38.9 35.5 51.6 25.4 2.72 SS/LT OLVGY/VFGR/VWELl SRTD/VFRI 103B 3467.7 NO ANALYSIS - SAMPLE RESERVED FOR ARCO 104A 3468.2 296.00 41.0 35.8 65.6 14.8 2.70 SS/LT OLVGY/VFGR/VWElL SRTD/VFRI/(DRlG FLD) 104B 3468.8 424.23 38.3 35.4 51.2 26.6 2.73 SS/LT OLVGY/VFGR/VWELL SRTD/VFRI 105A 3469.2 427.17 35.8 34.0 53.9 25.5 2.71 SS/lT OLVGY/VFGR/VWELL SRTD/VFRI 105B 3469.6 288 .38 37.9 34.7 56.1 23.5 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/VFRI 106A 3470.1 187.52 36.7 33.8 47.9 30.3 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 106B 3470.5 401.05 37.9 34.9 50.2 29.9 2.70 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 107A 3471.4 5.25 31.3 27.6 6.9 72.7 2.77 SLTST/LTGY/ARG/SL CALC/MOO CONS 1078 3471. 7 3.08 31.1 28.4 20.7 60.3 2.73 SS/LTGY/40% SlTST/VFGR/VWELL SRTD CORE #6 3472.0 - 3501.7 108A 3472.2 15.80 32.2 29.4 32.7 48.3 2.72 SS/OLVGY/SLTY/VFGR/WELL SRTD/FRI 108B 3472.7 1.78 30.7 27.9 11.2 73.4 2.75 SLTST/lTGY/40% SS/VARG/SL CALC/CONS 109A 3473.3 4.17 31.9 28.8 19.1 59.6 2.74 SS/LTGY/VFGR/VWELl SRTD/SL FRI 109B 3473.7 1.54 30.8 27.7 14.6 66.5 2.72 SS/LTGY/VFGR/VWELL SRTD/SL FRI 110A 3474.2 0.95 30.8 28.1 4.2 81.9 2.76 SLTST/LTGY/ARG/SL CALC/MOO CONS 110B 3474.7 7.46 33.2 30.3 24.6 56.1 2.72 SS/LTGY/VFGR/VWELL SRTD/Sl CALC/SL FRI 111A 3475.3 0.57 33.1 29.1 4.7 77.7 2.72 SLTST/LTGY/ARG/SL CALC/MOO CONS 111B 3475.6 5.68 32.5 28.4 11.2 71.6 2.70 SLTST/LTGY/20% SS/VARG/MOO CONS 112A 3476.2 0.33 32.2 28.2 0.7 81.9 2.76 SLTST/LTGY/VARG/SL CALC/MOC CONS 112B 3476.8 106.99 39.3 34.8 55.2 25.4 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/UNCONS page 10 , I J .~ ] ARCO ALASKA, INC. DATE 19-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRLG FLD OBM LABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK lEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) Oll% IJTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION .. .. .... .. .... ...... .......... -..........- .. .. .... .. .... .. ...... .. .. . .... .. .. ........ ........ 113A 3477.2 2.89 31.4 28.3 1.0 80.2 2.76 SS/lT OLVGY/VFGR/VWEll SRTD/FRI 113B 3477.8 3.18 31.5 28.9 2.6 80.7 2.72 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 114A 3478.2 3.23 31.8 28.8 4.5 76.8 2.72 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 1148 3478.7 33.01 34.2 30.7 19.9 54.0 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 115A 3479.2 41.97 33.6 30.6 24.9 53.5 2.69 SS/LT OlVGY/VFGR/VWELL SRTD/FRI 1158 3479.6 46.38 35.8 31.9 24.2 48.5 2.74 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 116A 3480.3 96.68 37.2 34.3 64.0 16.6 2.69 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 1168 3480.8 14.55 33.5 30.3 19.3 59.1 2.69 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 117A 3481.2 30.89 34.4 31.3 12.8 63.0 2.70 SS/LT OLVGY/VFGR/VWEll SRTD/FRI 117B 3481.7 60.99 35.1 31.8 32.3 42.3 2.70 SS/LT OlVGY/VFGR/VWELL SRTD/FRI 11SA 3482.2 NO ANALYSIS - DISAGGREGATED SAMPLE 118B 3482.7 6.44 33.3 29.9 9.7 66.4 2.71 SS/LT OlVGY/VFGR/VWELL SRTD/FRI 119A 3483.2 31.58 35.3 32.1 19.9 53.1 2.70 SS/LT OlVGY/VFGR/VWElL SRTD/FRI 119B 3483.7 94.85 36.9 33.1 20.8 53.2 2.69 SS/lT OlVGY/VFGR/VWEll SRTD/VFRI 120A 3484.1 8.13 33.9 29.8 11.9 64.4 2.71 SS/LT OLVGY/VFGR/VWElL SRTD/VFRI 1208 3484.7 55.02 36.3 32.7 24.6 48.0 2.70 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 121A 3485.2 72.61 36.7 33.2 32.8 39.9 2.70 SS/LT OLVGY/VFGR/VWELl SRTD/FRI 121B 3485.9 24.47 35.7 32.5 18.8 59.0 2.70 SS/LT OlVGY/VFGR/VWElL SRTD/FRI 122A 3486.4 6.32 32.1 29.4 9.9 72.8 2.74 SS/lT OLVGY/VFGR/VWELL SRTD/CONS 1228 3486.7 2.61 31.4 28.7 10.9 75.3 2.71 SS/lT OLVGY/VFGR/VWELL SRTD/CONS 123A 3487.2 3.35 32.5 29.8 2.2 83.5 2.74 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 1238 3487.7 5.15 33.1 29.4 8.5 71.6 2.72 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 124A 3488.2 3.43 33.5 30.7 15.4 68.5 2.73 SS/LT OlVGY/VFGR/VWElL SRTD/CONS 1248 3488.7 5.04 33.0 30.0 9.3 70.7 2.73 SS/LT OLVGY/VFGR/VWELl SRTD/CONS page 11 I I ARCO ALASKA NC. DATE 19-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRLG FLD OBM lABORATORY : ANCHORAGE NORTH SLOPE, ALASKA LOCATION TUN - R9E - Sec35 API : 50-0292-1656-00 DEAN-STARK LEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PSI SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION ....... .......... ....... ..... .. .. .. ....... .. ....... .. ......... .. .. .... - -- ---...........-........ 125A 3489.2 Z.30 31.8 28.8 4.0 80.0 2.74 SS/lT OlVGY/VFGR/VWEll SRTD/CONS 125B 3489.8 6.35 33.4 30.4 5.5 76.0 2.71 SS/LT OlVGY/VFGR/VWELL SRTD/CONS 126A 3490.3 5.19 33.4 30.3 3.0 81.4 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 126B 3490.8 19.10 37.2 33.2 6.0 71.1 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 127A 3491.2 22.43 35.1 31.9 16.7 61.2 2.70 SS/LT OLVGY/VFGR/VWELL SRTD/FRI 1278 3491.7 1.53 34.1 31.2 1.2 84.9 2.74 SS/LT OLVGY/VFGR(VWELL SRTD/FRI 128A 3492.1 3.36 31.6 29.1 16.1 66.2 2.71 SS/LT OLVGY/VFGR/VWElL SRTD/CONS 128B 3492.7 5.61 32.8 30.1 8.9 69.8 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 129A 3493.1 2.12 31.4 28.6 9.6 72.7 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 129B 3493.7 5.78 32.4 29.9 17.8 61.2 2.70 SS/LT OLVGY/VFGR/VWEll SRTD/CONS BOA 3494.2 3.59 31.3 29.3 11.0 71.4 2.72 SS/LT OLVGY/VFGR/VWEll SRTD/CONS 130B 3494.6 2.69 31.2 29.1 11.7 69.2 2.70 SS/lT OLVGY/VFGR/VWEll SRTD/CONS 131A 3495.2 3.08 30.5 28.0 9.6 73.3 2.73 SS/lT OlVGY/VFGR/VWELL SRTD/CONS 131B 3495.7 1.70 30.9 28.3 12.6 68.2 2.75 SS/lT OLVGY/VFGR/VWELL SRTD/CONS 132A 3496.2 2.94 31.9 29.1 15.4 62.7 2.72 SS/lT OLVGY/VFGR/VWELl SRTD/CONS 132B 3496.7 21.02 33.0 30.3 22.2 54.3 2.71 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 133A 3497.2 3.21 30.9 28.2 8.7 71.8 2.73 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 133B 3497.8 1.90 30.2 27.6 9.3 71.7 2.72 SS/LT OLVGY/VFGR/VWELL SRTD/CONS 134A 3498.2 0.93 30.3 26.8 9.1 72.3 2.74 SLTST/LTGY/ARG/10·20% SS/CONS 1348 3498.7 2.57 31.1 28.7 15.8 63.6 2.71 SS/lT OLVGY/VFGR/VWElL SRTD/CONS I 135A 3499.2 0.46 29.6 26.9 3.2 71.8 2.74 SLTST/LTGY/ARG/SL CALC/CONS 135B 3499.7 5.12 31.0 28.5 3.3 74.3 2.74 SLTST/LTGY/ARG/10-20% SS/CONS I 136A 3500.2 0.47 29.1 26.8 5.7 79.4 2.74 SLTST/LTGY/ARG/10-20% SS/CONS ! 1368 3500.6 0.72 29.7 27. 6.0 76 2.74 SlTST/lTGY/ARG/10-20% SS/CONS page 12 , T] I I ~ } r J 1 J- ARCO ALASKA, INC_ DATE 19-JAN-87 FILE : BP-3-1188 KRU #3K-9 FORMATION WEST SAK ANALYSTS : TLS,RGC KUPARUK FIELD DRlG FlD OBM lABORATORY : ANCHORAGE NORTH SLOPE, ALASKA lOCATION T13N-R9E-Sec35 API : 50-0292-1656-00 DEAN-STARK lEAD SLEEVE ANALYSIS SAMPLES MOUNTED FROZEN AT 500 PS SAMPLE DEPTH PERM MD POROSITY (%) OIL% WTR% GRAIN NUMBER FEET 1000psig ATM 1000psig PORE PORE DEN M DESCRIPTION .. .. ~ .. .......... .. .... .. ... .. .. .. ........ .. ...... -- - .... .. .. - .. .. .. .... .... .. .. .. ...... 137A 3501.3 6.01 29.4 27.8 4.2 79.8 2.71 SlTST/lTGY/ARG/10-20% SS/CONS 1378 3501.5 2.29 30.9 28.1 7.3 71.1 2.70 SLTST/LTGY/ARG/20-30% SS/CONS , 1_ ì_ :- j 1.... Tabular Data Ove.!:'burden Plug Analysis - CMS-200 , - , ;.- , - - - - ,- \ ¡ ,- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 .. CMS-200 Overburden Pressure Analysis ~ Conv (1) CMS-200 Automated System Conv (1) Sample Depth Pressure Por por Kl Ka (est) Ka NlI1ber (ft) ( Ovben (%) (%) (md) (md) (hyd) ......., ....... ......... ................. .. ................. 1A 3365.2 ATM 27.0 1000 24.4 23.9 0.19 0.54 0.46 2000 23.6 0.14 0.36 - 1000 23.8 0.15 0.40 1B 3365.7 ATM 26.8 '"- 1000 24.3 24.1 0.21 0.49 0.31 2000 23.7 0.09 0.27 1000 23.8 0.10 0.29 ..- 2A 3366.2 ATM 25.9 1000 23.7 23.6 0.71 1.03 0.87 2000 23.1 0.24 0.44 - 1000 23.2 0.25 0.47 2B 3366.7 ATM 26.5 - 1000 24.3 24.1 0.15 0.34 0.20 2000 23.7 0.05 0.17 1000 23.8 0.05 0.18 .. 3A 3367.2 ATM 27.0 1000 24.4 24.2 0.18 0.36 0.31 2000 23.8 0.08 0.20 - 1000 23.9 0.09 0.22 3B 3367.7 ATM 28.0 - 1000 24.9 24.6 0.06 0.17 0.12 2000 24.3 0.03 0.13 1000 24.5 0.04 0.14 - 4A 3368.2 ATM 27.7 1000 25.0 24.8 0.12 0.21 0.28 2000 24.6 0.04 0.13 1000 24_8 0.05 0.14 - page 1 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 CMS-200 Overburden Pressure Analysis - Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure Por por Kl Ka (est) Ka Number (ft) (Ovbd) (%) (%) (md) (md) (hyd) - ..... .... ...... .. .... .. ............ 4B 3368.7 ATM 27.5 1000 24.9 25.0 0.38 0.68 0.55 2000 24.6 0.17 0.38 1000 24.7 0.18 0.40 5A 3369.2 ATM 27.2 -'" 1000 24.3 24.8 0.12 0.26 0.16 2000 24.4 0.07 0.18 1000 24.6 0.07 0.19 5B 3369.7 ATM 27.8 1000 24.7 25.3 0.21 0.43 0.29 2000 24.9 0.11 0.25 ~ 1000 25.0 0.11 0.27 6A 3370.2 ATM 27.3 - 1000 24.4 25.2 0.25 0.47 0.31 2000 24.8 0.14 0.33 1000 25.0 0.15 0.34 -' 6B 3370.7 ATM 26.9 1000 24.3 24.8 0.48 0.75 0.57 2000 24.4 0.23 0.45 -1 1000 24.6 0.24 0.48 7A 3371.2 ATM 26.7 - 1000 24.2 24.7 0.20 0.33 0.25 2000 24.4 0.08 0.17 1000 24.5 0.08 0.18 - 7B 3371.7 27.0 ATM 1000 24./f 24.2 0.14 0.30 0.37 2000 23.9 0.05 0.16 1000 24.1 0.05 0.17 File: BP-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 page 2 ..-- j ,- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 - CMS-200 Overburden Pressure Analysis - Conv (1) CMS-200 Automated System Conv (1) Sample Depth Pressure Por Por Kl Ka (est) Ka Number (ft) (Ovbd) (%) (%) (md) (md) (hyd) ..-........ ..-....-....- -..----...... 8A 3372.2 ATM 27.5 1000 24.7 24.8 0.10 0.23 0.37 2000 24.6 0.04 0.14 1000 24.8 0.05 0.15 8B 3372.7 ATM 26.6 - 1000 24.8 24.5 0.40 0.63 0.48 2000 24.0 0.19 0.36 1000 24.2 0.19 0.37 9A 3373.2 ATM 28.6 1000 26.2 25.8 1.85 3.44 3.03 2000 25.2 1.20 2.36 1000 25.4 1.25 2.46 9B 3373.7 ATM 27.4 1000 24.8 24.9 0.14 0.39 0.34 2000 24.6 0.12 0.33 1000 24.8 0.13 0.35 10A 3374.2 ATM 26.8 1000 24.3 24.5 0.17 0.44 0.27 2000 24.0 0.12 0.33 1000 24.2 0.13 0.35 108 3374.7 ATM 26.5 -. 1000 24.1 24.2 0.18 0.45 0.26 2000 23.8 0.12 0.33 1000 23.9 0.12 0.34 - 11A 3375.2 ATM 1000 23.7 23.7 0.17 0.41 0.68 2000 23.4 0.12 0.32 ~ 1000 23_6 0_13 0.34 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 page 3 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TlS;RGC¡TDT API No: 50-0292-1656-00 - CMS·200 Overburden Pressure Analysis -- Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure por Por Kl Ka (est) Ka NlIIlber (ft) (Ovbd) (%) (%) (met) (met) (hyd) - ............... --.........-- -.......-....-. 11B 3375.7 ATM 26.5 1000 24.3 24.1 0.80 1.55 1.31 2000 23.6 0.45 0.90 1000 23.7 0.47 0.95 12A 3376.2 ATM 28.8 1000 26.3 26.2 2.69 4.72 3.99 2000 25.5 1.77 3.25 1000 25.7 1.87 3.42 12B 3376.7 ATM 27.7 1000 25.7 25.2 2.37 4.26 4.01 2000 24.7 1.11 2.10 1000 24.8 1.15 2.19 13A 3377.2 ATM 28.4 -' 1000 25.4 25.4 2.29 3.26 2.83 2000 24.7 1.14 2.20 1000 25.0 1.20 2.32 13b 3377.7 ATM 29.0 1000 26.5 26.2 2.38 3.18 3.28 2000 25.6 1.28 2.15 -' 1000 25.7 1.46 2.26 14A 3378.2 ATM 28.7 - 1000 25.8 25.5 2.45 2.95 3.30 2000 25.0 1.29 1.72 1000 25.2 1.34 1.80 - 3378.7 14B ATM 31.E; 1000 28.t: 27.6 3.70 6.16 5.35 2000 27.2 3.59 4.61 1000 27.4 3.66 4.75 page 4 l~ Arco Alaska, Inc. tate: 19- Jan-86 File: BP-3-1188 )- KRU #3K-9 Formation: West Sak Lab: Anchorage Kuparuk Field [Irlg Fld: OBM Analysts: TLS¡RGC¡TDT North Slope, Alaska l.ocation : T13N R9E Sec35 API No: 50-0292-1656-00 l-- j ~- CMS-20U overburden Pressure Analysis j 1- Conv (1) CMS-200 Automated System Conv (1) j Sample Depth Pressure Por Por Kl Ka (est) Ka Nunber (ft) (Ovbd) (%) (%) (me!) (me!) (hyd) r ------- -------- --------- 15A 3379.2 ATM 29.6 j 1000 26.8 26.7 5.76 7.30 7.54 2000 26.1 3.81 4.88 ~- 1000 26.3 3.86 5.05 15B 3379.7 ATM 31.3 '..- 1000 28.7 28.4 12.18 15.32 16.52 2000 27.8 10.48 13.02 1000 28.0 11.12 13.86 ~.- 16A 3380.2 ATM 30.1 1000 27.0 26.7 6.95 10.66 8.14 2000 26.2 4.98 8.02 , '"--" 1000 26.3 5.12 8.38 16B 3380.6 ATM 31.5 1000 27.6 27.0 8.55 10.66 10.00 2000 26.4 6.33 8.02 1000 26.6 6.58 8.38 17A 3381.1 ATM 30.5 1000 27.7 27.4 12.70 15.51 14.98 2000 26.8 10.46 12.96 1000 27.0 11.06 13.64 17B 3381. 5 ATM 34.8 - 1000 30.7 30.3 104.04 112.29 123.11 2000 29.6 89.81 97.06 1000 29.8 92.77 100.38 - 18A 3382.1 ATM 29.5 1000 25.9 25.5 5.15 6.38 6.43 2000 24.9 4.14 5.15 1000 25.1 4.27 5.35 page 5 Arco ALaska, Inc. I)ate: 19-Jan-86 File : BP-3-1188 1~ KRU #3K-9 Formation: West Sak Lab: Anchorage 1 Kuparuk FieLd l)rLg FLd: OBM AnaLysts: TLS¡RGC¡TDT North SLope, ALaska Location : T13N R9E Sec35 API No: 50-0292-1656-00 1- i j 1 ~ CMS-200 Overburden Pressure AnaLysis - Conv (1) CMS-200 Automated System Conv (1) SampLe Depth Pressure Por Por KL Ka (est) Ka Number (ft) (Ovbd) (%) (%) (mcI) (mcI) (hyd) ... -............... ................... .......-........... 1SB 3382.9 ATM 29.9 1000 26.3 26.0 0.77 1.39 1.01 2000 25.3 0.46 0.96 , :~ 1000 25.5 0.48 1.00 19B 3383.7 ATM 30.5 - 1000 27.1 26.7 1.85 2.86 2.50 2000 26.0 1.02 1.72 1000 26.2 1.06 1.79 , ;.-.- 20A 3384.2 ATM 32.2 1000 28.9 28.6 4.99 6.63 5.76 2000 28.0 3.87 5.21 1000 28.2 3.96 5.36 20B 3384.7 ATM 29.1 1000 26.6 26.5 5.48 7.22 7.07 - 2000 26.1 4.16 5.47 1000 26.3 4.20 5.60 - 23A 3387.2 ATM 42.6 1000 38.5 38.3 520.22 551.39 581.16 2000 36.6 411. 91 438.84 - 1000 36.8 413.03 440.27 23B 3387.8 ATM 41.4 1000 37.3 37.3 441.85 500.12 488.80 - 2000 35.6 315.60 360.11 1000 36.0 322.76 372.20 24A 3388. 1 ATM 42.3 1000 38.0 37.9 449.91 492.64 491.79 2000 36.0 326.77 361.34 1000 36.4 337.62 373.24 page 6 l~ j Arco Alaska, Inc. [late: 19-Jan'86 File: BP-3-1188 ~- KRU #3K-9 "ormation: West Sak Lab: Anchorage ; Kuparuk Field [Irlg Fld: OBM Analysts: TLS¡RGC¡TDT North Slope, Alaska Location : T13N R9E Sec35 API No: 50-0292-1656-00 ~- I j ì- CMS-201) Overburden Pressure Analysis 1~ Conv (1) CMS-200 Automated System Conv (1) j Sa~le Depth Pressure Por Por Kl Ka (est) Ka NlIIber (ft) (Ovbcl) (%) (%) (md) (md) (hyd) ,- ----....-- --.............. 24B 3388.7 ATM 43.7 1000 37.6 37.4 803.85 853.00 810.03 2000 35.8 663.30 694.99 ~- 1000 36.2 689.28 716.39 25A 3389.2 ATM 42.9 1000 37.8 37.5 812.42 1098.13 1167.47 2000 36.5 683.83 926.62 1000 36.7 691.17 935.09 1 - 25B 3389_8 ATM 43.2 1000 38.4 38.5 NP 1026.52 2000 36.9 ~ 1000 37.1 26A 3390.2 ATM 39.5 1000 34.6 34.3 69.65 79.00 85.10 2000 32.8 56.13 64.23 1000 33.0 56.66 64.76 26B 3390.7 ATM 32.1 1000 28.0 28.5 0.17 0.38 0.32 2000 28.1 0.07 0.19 - 1000 28.3 0.07 0.21 27A 3391.2 ATM 34.2 1000 30.9 30.8 43.02 50.53 61.48 - 2000 30.0 33.91 39.71 1000 30.3 34.82 40.79 27B 3391.7 ATM 32.2 1000 28.2 27.5 11.33 13.63 17.07 2000 26.8 5.64 6.84 1000 27.0 5.78 7.10 page 7 - "- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan·86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 - CMS·200 Overburden Pressure Analysis ..>-- Conv (1) CMS-200 Automated System Conv (1) Saq>le Depth Pressure Por Por Kl Ka (est) Ka Nunber (ft) (Ovbd) (%) (%) (md) (md) (hyd) ,-"'-' ......-.-- ............. 28A 3392.7 ATM 32.2 1000 28.3 28.0 0.11 0.22 0.14 ..>L- 2000 27.6 0.05 0.13 1000 27.8 0.05 0.14 29B 3393.7 ATM 35.9 ,->- 1000 32.6 32.2 100.93 109.56 107.86 2000 31.4 79.67 87.25 1000 31.6 81.97 89.74 ...... 30A 3394.2 ATM 31.1 1000 27.2 27.0 0.70 1.07 1.00 2000 26.6 0.35 0.61 ..... 1000 26.7 0.37 0.64 30B 3394.7 ATM 31.0 .... 1000 28.1 28.7 3.39 6.00 4.86 2000 28.0 2.72 4.90 1000 28.2 2.83 5.08 .... 31A 3395.2 ATM 34.8 1000 32.1 31.8 39.23 44.62 50.49 2000 31.2 33.98 38.82 ,- 1000 31.4 35.03 40.00 318 3395.8 ATM 39.7 - 1000 35.6 35.4 189.99 264.01 233.00 2000 33.7 150.51 211. 78 1000 33.9 151.47 212.00 - 32A 3396.2 ATM 31.1 1000 26.6 26.9 0.42 0.88 0.74 2000 26.6 0.41 0.51 1000 26_5 0.25 0.54 File: BP-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 page 8 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 CMS-200 Overburden Pressure Analysis Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure Par Par Kl Ka (est) Ka NlIIi>er (ft) (Ovbd) (%) (%) (me!) (me!) (hyd) ,'--' ......... ....... ................. ...........-...... 32B 3396.7 ATM 36.4 1000 33.1 33.1 66.21 74.15 82.05 2000 32.5 58.91 66.19 -4 1000 32.7 60.30 67.76 33A 3397.2 ATM 32.0 1000 28.2 28.3 0.42 0.81 0.87 2000 28.0 0.22 0.51 1000 28.1 0.27 0.65 33B 3397.7 ATM 35.9 1000 32.7 33.0 60.09 87.80 84.93 2000 32.4 47.81 69.35 1000 32.6 48.98 71.14 34A 3398.2 ATM 36.1 - 1000 32.5 31.9 25.78 30.27 33.56 2000 31.2 21.26 24.96 1000 31.5 21.81 25.64 - 35B 3399_8 ATM 35.5 1000 32.4 32.3 33.17 47.55 40.95 2000 30.8 22.00 32.17 - 1000 31.0 21.92 32.07 36A 3400.1 ATM 36.7 - 1000 33.3 32.9 40.70 46.43 50.42 2000 32.2 36.73 41.98 1000 32.4 37.73 43.09 - 36B 3400.7 37.9 ATM 1000 34.4 34.0 125.65 136.38 152.70 2000 33.4 109.97 119.46 1000 33_6 112_35 122_30 File: BP'3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292'1656-00 page 9 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 CMS - ;100 Overburden Pressure Ana l ys is Cony (1) CMS·200 Automated System Cony (1) Sample Depth Pressure Por Por Kl Ka (est) Ka Number (ft) (Ovbd) (%) (%) (me!) (me!) (hyd) .. ............- ..-............. 37A 3401.2 ATM 38.1 1000 34.6 34.6 135.81 189.14 166.44 2000 34.0 121.36 169.38 1000 34.2 124.11 173.36 378 3401.7 ATM 35.1 1000 31.1 31.2 3.31 5.70 4.89 2000 30.4 2.54 4.47 1000 30.6 2.64 4.(14 38A 3402.1 ATM 36.5 1000 32.7 32.4 23.33 34.87 28.24 2000 31.8 20.16 30.16 ,~ 1000 32.0 20.68 30.95 38B 3402.8 ATM 37.4 - 1000 33.6 33.3 79.92 87.37 95.15 2000 32.7 71.41 78.19 1000 32.9 73.20 80.15 -' 39A 3403.2 ATM 34.8 1000 31.5 31.3 33.67 48.17 42.38 2000 30.7 30.82 45.11 -' 1000 30.9 31.80 46.46 39B 3403.7 ATM 37.0 - 1000 33.0 32.6 29.39 34.54 38.72 2000 32.0 24.82 29.07 1000 32.2 25.29 29.69 - 3404.1 40A ATM 36.1 1000 32.4 32.0 23.26 28.10 32.36 2000 31.4 19.47 23.44 - 1000 31.6 19.89 23_99 File: BP'3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 page 10 ,.- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19-Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 CMS-;~OO Overburden Pressure Analysis Cony (1) CMS-200 Automated System Cony (1) Sa""le Depth Pressure por Por Kl Ka (est) Ka NUiÐer (ft) (Oybd) (%) (%) (met) (me!) (hyd) - ..--..--..- ................ ... 40B 3404.7 ATM 30.7 1000 27.3 27.1 0.82 1.64 1.59 2000 26.6 0.40 0.93 1000 26.7 0.43 0.99 41A 3405.2 ATM 37.7 1000 34.6 34.2 182.00 216.00 209.04 2000 33.6 132.00 166.00 1000 33.8 136.00 170.00 ATM 34.8 41B 3405.65 1000 31.3 30.7 6.61 8.65 8.86 2000 30.0 5.45 7.20 1000 30.3 5.63 7.44 ATM 34.0 42A 3406.1 1000 30.4 29.9 9.92 11.72 16.82 2000 29.3 6.13 7.37 1000 29.6 6.29 7.64 42B 3406.7 ATM 34.0 1000 30.7 30.0 12.63 15.34 16.78 2000 29.4 10.15 12.40 1000 29.6 10.57 12.92 43A 3407.2 ATM 32.6 1000 29.1 28.4 6.39 8.09 8.64 2000 27.8 4.81 5.98 1000 28.0 4.89 6.15 43B 3407.8 ATM 34.1 1000 31.1 30.5 15.87 18.86 21.43 2000 29.9 12.74 15.32 1000 30.1 13.25 15_94 File: BP-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50'0292-1656-00 page 11 .-. -"'- Areo Alaska, Inc. KRU #3K'9 Kuparuk Field North Slope, Alaska Date: 19-Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP'3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 ~ ,...a, CMS-200 Overburden Pressure Analysis .... Conv (1) CMS-200 Automated System Cony (1) Salq)le Depth Pressure POl' Por Kl Ka (est) Ka N~r (ft) ( Ovbet) (X) (X) (md) (md) (hyd) - ..-..---- -..........- ........... 44A 3408.2 ATM 31.7 1000 29.0 28.7 2.92 4.87 4.69 2000 28.1 2.10 3.64 --' 1000 28.3 2.22 3.82 44B 3408.7 ATM 35.0 ,....-.-.'. 1000 32.4 32.3 42.41 60.81 54.50 2000 31.4 36.74 52.92 1000 31.7 38.11 54.85 - 45A 3409.2 ATM 34.5 1000 31.4 31.3 36.27 40.39 44.92 2000 30.6 30.39 33.82 1000 30.8 31.45 34.98 ATM _! 46A 3410.2 1000 39.2 2000 35.9 36.1 586.81 688.16 542.44 1000 35.5 550.10 650.21 35.7 562.12 574.30 46B 3410.7 ATM 31.0 1000 28.3 27.9 2.52 4.29 3.49 - 2000 27.4 1.67 2.99 1000 27.5 1.79 3.17 47A 3411.2 ATM 37.6 1000 33.8 33.3 112.71 125.30 145.21 2000 32.6 93.04 102.57 1000 32.8 96.29 106.24 - 49A 3413.2 ATM 28.3, 1000 26.3, 25.8 2.97 4.20 4.80 2000 25.2 1_62 2.29 1000 25.4 1.67 2.41 page 12 1- Arco Alaska, Inc. Date: 19-Jan-86 File : BP'3-1188 ,- KRU #3K-9 Formation: West Sak Lab: Anchorage j Kuparuk Field IIrlg Fld: OBM Analysts: TLS:RGC:TDT North Slope, Alaska I.ocation : T13N R9E Sec35 API No: 50-0292'1656-00 ì~ J ,~ CMS-200 Overburden Pressure Analysis j , Cony (1) CMS-200 Automated System Cony (1) ¡~ j Sa~le Depth Pressure Por Por Kl Ka (est) Ka NliIÐer (ft) (Ovbd) (%) (%) (mcI) (mcI) (hyd) ~ .....---- .......... -.....--.-- 50A 3414.2 ATM 29.7 ,- 1000 27.6 27.5 0.35 0.63 0.68 2000 27.0 0.16 0.37 i 1000 27.2 0.17 0.39 , SOB 3414.7 ATM 29.4 1000 27.3 27.0 0.27 0.48 0.46 2000 26.6 0.13 0.30 , 1000 26.8 0.13 0.32 - 51A 3415.2 ATM 29.7 1000 27.3 27.1 0.27 0.52 0.41 2000 26.6 0.12 0.30 1000 26.8 0.13 0.32 51B 3415.7 ATM 28.2 1000 25.6 25.7 0.15 0.34 0.26 2000 25.2 0.10 0.25 1000 25.4 0.10 0.26 52A 3416_2 ATM 28.5 1000 25.9 25.7 0.42 0.59 0.62 2000 25.3 0.13 0.26 1000 25.5 0.13 0.27 52B 3416.7 ATM 28.5 1000 26.1 25.9 0.22 0.42 0.65 2000 25.6 0.13 0.31 1000 25.8 0.14 0.32 - 53A 3417.2 ATM 28.6 1000 26.2 26.1 0.33 0.65 0.42 2000 25.7 0.14 0.37 1000 25.9 0.15 0.39 page 13 - , Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19-Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13M R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 :1- ..1- CMS-200 Overburden Pressure Analysis , Cony (1) CMS-200 Automated System Cony (1) San.,le Depth Pressure Por Por Kl Ka (est) Ka Nunber (ft) (Ovbd) (%) (%) (me!) (me!) (hyd) _L ..... ................. ....--...--- 538 3417.7 ATM 28.3 1000 26.0 25.8 0.21 0.45 0.28 , 2000 25.4 0.08 0.23 1000 25.6 0.08 0.24 - 54A 3418.2 ATM 27.9 1000 25.9 25.9 0.38 0.53 0.58 2000 25.5 0.10 0.24 1000 25.7 0.10 0.25 548 3418.7 ATM 28.0 1000 25.5 25.7 0.35 0.68 0.54 - 2000 25.2 0.12 0.30 1000 25.4 0.12 0.31 - 55A 3419.2 ATM 28.2 1000 25.4 25.7 0.12 0.26 0.17 2000 25.4 0.07 0.18 1000 25.5 0.07 0.19 558 3419.7 ATM 27.7 1000 25.8 25.9 0.20 0.40 0.31 - 2000 25.5 0.11 0.26 1000 25.7 0.12 0.28 56A 3420.2 ATM 28.4 1000 26.5 26.4 0.28 0.49 0.42 2000 26.0 0.13 0.27 1000 26.2 0.11 0.28 - 568 3420.7 ATM 29.7 1000 25.9 25.4 0.31 0.53 0.47 2000 25.0 0.13 0.30 1000 25.2 0.13 0.32 page 14 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19-Jan-86 Format;on: West Sak Drlg Fld: OBM Locat;on : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 CMS-200 Overburden Pressure Analysis Conv (1) CMS-200 Automated System Conv (1) Sample Depth Pressure Por Por Kl Ka (est) Ka Nt.mber (ft) (Ovbd) <%) <%) (md) (md) (hyd) .. .............. -..---..-... 57A 3421.2 ATM 28.2 1000 25.4 25.9 0.60 1.02 0.88 2000 25.5 0.18 0.42 1000 25.7 0.19 0.44 57B 3421.7 ATM 28.2 1000 25.5 25.7 0.17 0.37 0.24 2000 25.3 0.11 0.27 1000 25.4 0.11 0.29 58A 3422.2 ATM 28.1 1000 25_6 25.5 0.31 0.55 0.48 ...- 2000 25.1 0.15 0.34 1000 25.3 0.15 0.36 -' 58B 3422.7 ATM 28.9 1000 26.2 26.2 0.41 0.86 0.62 2000 25.7 0.27 0.65 1000 25.9 0.28 0.37 -' 59 A 3423_2 ATM 28.7 1000 25.9 26.1 0.66 0.87 1.03 -' 2000 25.8 0.23 0.42 1000 25.9 0.24 0.44 -' 598 3423.7 ATM 28.8 1000 26.3 25.9 0.81 1.20 1.14 2000 25.4 0.35 0.64 1000 25.6 0.36 0.67 - 60A 3424.2 ATM 29.5 1000 26.0 25.8 0.75 1.24 1.18 2000 25.3 0.27 0_56 1000 25.5 0.27 0.58 page 15 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North SLope, ALaska Date: 19- Jan·86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 - CMS-200 Overburden Pressure Analysis - Conv (1) CMS-200 Automated System Conv (1) Sa~le Depth Pressure Por Por KL Ka (est) Ka NL.iIOOer (ft) (Owej) (%) (%) (md) (md) (hyd) - ....... ........ ....------.. 60B 3424.7 ATM 28.7 1000 26.4 26.4 0.97 1.78 1.52 2000 25.8 0.49 0.97 1000 26.0 0.48 1.01 61A 3425.2 ATM 27.9 1000 25.7 25.2 0.66 1.00 1.19 2000 24.7 0.34 0.þ1 -, 1000 24.9 0.36 0.65 61B 3425.7 ATM 30.7 1000 28.0 27.5 2.48 3.47 4.04 -' 2000 27.0 1.18 1.82 1000 27.2 1.26 1.94 - 62A 3426.2 ATM 32.5 1000 29.2 29.1 5.07 6.51 6.35 2000 28.5 3.75 4.88 1000 28.7 3.96 5.17 ""'" 628 3426.8 ATM 33.9 1000 29.9 29.6 9.24 11.41 13.18 -' 2000 28.8 6.32 7.94 1000 29.1 6.56 8.34 - 63A 3427.2 ATM 32.2 1000 29.2 29.0 5.32 6.89 6.91 2000 28.6 3.66 4.96 1000 28.7 4.02 5.32 - 63B 3427.7 ATM 30.2 1000 27.7 27.5 2.59 3.56 3.30 2000 26.8 1.64 2_37 1000 27.0 1.73 2.52 page 16 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Format; on: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 CMS-200 Overburden Pressure Analysis Cony (1) CMS-200 Automated System Conv (1) Sa~le Depth Pressure Por por Kl Ka (est) Ka NLllÐer (ft) (Ovbcl) (%) (%) (Ilk:!) (Ilk:!) (hyd) .. .. .. .. ....... .. ......--...... 64A 3428.2 ATM 29.6 1000 27.4 21.3 0.12 0.33 0.26 2000 21.0 0.01 0.23 1000 27.1 0.07 0.24 65A 3428.7 ATM 33.5 1000 31.1 30.9 1.10 1.89 1.71 2000 30.3 0.58 1.08 1000 30.5 0.65 1.17 65B 3429.8 ATM 33.3 1000 29.7 29.4 4.33 5.72 6.49 2000 28.8 2.64 3.67 1000 29.0 2.79 3.89 - 66A 3430.2 ATM 30.7 1000 28.6 28.2 1.07 1.53 1.36 2000 27.7 0.57 0.93 1000 27.9 0.64 0.98 - 66B 3430.8 ATM 32.1 1000 28.9 28.3 2.18 3.39 3.74 2000 27.8 1.62 2.11 1000 28.0 1.70 2.22 67A 3431_ 1 ATM 31.6 1000 28.5 28.3 2.21 3.00 2.83 2000 27.9 1.26 1.87 1000 28.0 1.34 1.98 67B 3431. 7 ATM 34.0 1000 30.4 30.2 4.66 6.20 6.18 2000 29.6 3.67 4.64 1000 29.7 3.92 4.91 page 17 - '- '- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Format;on: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 ..... a.. CMS-200 Overburden Pressure Analysis , Conv (1) CMS-200 Automated System Conv (1) ... Sample Depth Pressure por Por Kl Ka (est) Ka Nunber (ft) (Ovbd) (%) (%) (nd) (nd) (hyd) J.. -.-....--- -..----.....- 68A 3432.3 ATM 32.3 1000 29.0 29.3 1.01 1.78 1.35 :1.... 2000 28.8 0.53 1.02 1000 29.0 0.56 1.09 , 688 3432.8 ATM 32.1 -"- 1000 29.0 29.0 3.07 4.17 4.39 2000 28.5 1.52 2.26 , 1000 28.7 1.59 2.38 69A 3433.2 ATM 33.6 1000 30.9 30.6 5.99 9.24 8.16 .~ 2000 30.0 4.02 6.45 1000 30.2 4.11 6.60 69B 3433.7 ATM 33.0 - 1000 30.4 30.0 5.23 6.79 7.52 2000 29.3 3.69 4.84 1000 29.5 3.82 5.07 - 70A 3434.2 ATM 34.2 1000 30.9 31.0 5.92 9.43 8.63 - 2000 30.3 4.31 6.94 1000 30.5 4.48 7.27 70B 3434.7 ATM 33.3 ¡¡ao 1000 30.2 29.9 2.95 3.64 4.48 2000 29.3 1.82 2.44 1000 29.5 1.94 2.57 - 71A 3435.2 ATM 31.3 1000 28.6 28.3 1.17 1.71 1.72 2000 27.8 0.49 0.83 1000 28.0 0.51 0.88 page 18 1- \ j Arco Alaska, Inc. Date: 19- Jan-86 File: BP-3-1188 1- KRU #3K-9 Formation: West Sak Lab: Anchorage Kuparuk Field Drlg Fld: OBM Analysts: TLS;RGC;TDT North Slope, Alaska Location : T13N R9E Sec35 API No: 50-0292-1656-00 ]~ 1.- CMS-200 Overburden Pressure Analysis j 1- Cony (1) CMS-200 Automated System Cony (1) j Sample Depth Pressure Por Por Kl Ka (est) Ka Nunber (ft) (Ovbd) (%) (%) (me:!) (me:!) (hyd) ,- -.............. .......----- ....--............. j 71B 3435.7 ATM 32.3 1000 29.8 29.3 2.21 3.13 2.79 l~ 2000 28.9 1.44 2.14 1000 29.1 1.50 2.25 1 - 72A 3436.2 ATM 32.8 1000 30.3 29.9 2.77 4.66 4.99 2000 29.4 1.18 2.18 1_ 1000 29.6 1.25 2.31 72B 3436.7 ATM 33.7 1000 30.8 30.2 4.24 5.59 5.78 - 2000 29.7 3.03 4.12 1000 29.9 3.20 4.35 , 73A 3437.2 ATM 34.7 - 1000 31.9 31.4 10.62 15.98 13.60 2000 30.8 8.58 12.98 1000 31.0 8.90 13.49 - 73B 3437.7 ATM 35.2 1000 32.5 31.8 10.26 15.67 15.27 .. 2000 31.1 7.08 10.91 1000 31.3 7.28 11.31 ... 74A 3438_3 ATM 35.4 1000 31.3 31.3 5.65 7.42 7.03 2000 30.4 4.36 5.83 1000 30.6 4.64 6.18 - 74B 3438.7 ATM 36.7 1000 32.1 31.9 6.81 8.92 8.73 2000 31.4 4.86 6.37 1000 31.5 5.26 6.90 page 19 Arco Alaska, Inc. KRU #31(-9 Kuparuk field North Slope, Alaska Date: 19-Jan-86 Formation: West Sak Drlg fld: OBM Location : T13N R9E Sec35 File: BP-3'1188 Lab: Anchorage Analysts: TlS¡RGC¡TDT API No: 50-0292-1656-00 """ - CMS-200 Overburden Pressure Analysis - Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure por Por lel Ka (est) Ka NlIIIber (ft) (Ovbd) (%) (%) (md) (md) (hyd) ~ --........-- .................... 75A 3439.2 ATM 33.6 1000 30.3 30.1 0.47 0.70 0.94 2000 29.6 0.17 0.35 1000 29.8 0.20 0.38 75B 3439.6 ATM 33.8 1000 30.6 30.2 2.51 3.63 3.86 2000 29.6 1.43 2.19 -' 1000 29.9 1.53 2.33 77A 3441. 2 ATM 36.2 1000 32.4 32.1 6.28 8.16 8.38 -" 2000 31.6 5.19 6.65 1000 31.8 4.90 7.05 .. 77B 3441.7 ATM 28.5 1000 25.8 25.3 1.04 1.75 1.97 2000 24.9 0.33 0.65 1000 25.1 0.32 0.69 - 78A 3442.2 ATM 28.7 1000 25.7 26.1 1.20 1.60 1.67 - 2000 25.8 0.22 0.36 1000 26.0 0.18 0.37 - 78B 3442.7 ATM 29.5 1000 26.0 25.8 0.14 0.26 0.20 2000 25.3 0.09 0.19 1000 25.5 0.10 0.21 - 79A 3443.2 ATM 30.5 1000 27.1 26.8 0.17 0.32 0.24 2000 26_5 0.07 0.17 1000 26.7 0.07 0.18 page 20 - - 1~ Arco Alaska, Inc. Date: 19- Jan-86 File: Bp·3-1188 Y· KRU #3K-9 Formation: West Sak Lab: Anchorage Kuparuk Field Drlg Fld: OBM Analysts: TLS¡RGC¡TDT North Slope, Alaska Location : T13N R9E Sec35 API No: 50-0292-1656-00 ,~ j ,.. CMS-200 Overburden Pressure Analysis I j ,. Cony (1) CMS-200 Automated System Cony (1) ì j Sample Depth Pressure Por Por Kl Ka (est) Ka NunÐer (ft) (Ovbd) (%) (%) (md) (md) (hyd) r .............. ................ ................ .. 79B 3443.7 ATM 29.5 1000 27.2 27.0 0.45 0.72 0.43 ì~ 2000 26.5 0.11 0.25 1000 26.7 0.10 0.26 ~ SOA 3444.2 ATM 29.1 1000 26.7 26.6 0.13 0.29 0.17 2000 26.2 O.OS 0.19 10.- 1000 26.4 O.OS 0.20 80B 3444.7 ATM 29.1 1000 26.1 25.9 0.23 0.46 0.49 ... 2000 25.5 0.17 0.29 1000 25.7 0.18 0.31 -. 81A 3444.7 ATM 30.3 1000 27.7 27.5 2.91 4.57 0.90 2000 27.1 0.68 1.09 1000 27.3 0.68 1.15 - 818 3445.7 ATM 29.5 1000 27.0 26.8 0.43 0.68 0.57 .. 2000 26.5 0.08 0.20 1000 26.7 0.08 0.21 .. 82A 3446.2 ATM 31.2 1000 27.8 27.9 0.34 0.60 0.47 2000 27.5 0.10 0.22 1000 27.7 0.10 0.24 - 82B 3446.7 ATM 31.0 1000 27.8 28.1 0.39 0.73 0.49 2000 27.6 0.17 0.38 1000 27.8 0.17 0.40 page 21 - Arco Alaska, Inc. KRU #3K-9 Kuparuk field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: 08M Location : T13N R9E Sec35 File: BP-3-1188 lab: Anchorage Analysts: TLS;RGC¡TDT API No: 50-0292-1656-00 ... - CMS-200 Overburden Pressure Analysis .. Cony (1) CMS-200 Automatecl System Cony (1) Sample Depth Pressure Por Por Kl Ka (est) Ka Number (ft) (Ovbcl) (%) (%) (mcI) (mcI) (hyd) ............. ....____..e.. 83A 3447.2 ATM 31.4 1000 28.1 28.4 0.48 0.80 0.66 2000 28.0 0.09 0.23 1000 28.1 0.09 0.24 83B 3447.7 ATM 32.2 1000 28.9 28.8 0.68 1.05 0.91 2000 28.4 0.15 0.~2 1000 28.6 0.16 0.34 84A 3448.2 ATM 29.6 1000 27.0 26.8 0.08 0.20 0.09 - 2000 26.4 0.03 0.11 1000 26.6 0.03 0.12 ..., 84B 3448.7 ATM 29.8 1000 27.1 27.2 0.57 0.93 0.76 2000 26.7 0.16 0.33 .' 1000 26.9 0.16 0.36 85A 3449.2 ATM 29.6 1000 27.0 26.9 0.54 0.79 0.64 -~ 2000 26.6 0.11 0.24 1000 26.8 0.11 0.25 -, 85B 3449.7 ATM 28.7 1000 26.2 26.3 0.66 0.88 1.09 2000 25.9 0.06 0.15 1000 26.1 0.06 0.17 -' 86A 3450.2 ATM 27.3 1000 24.2 24.0 0.11 0.27 0.18 2000 23.6 0.05 0.15 1000 23.8 0.05 0.16 page 22 '- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File : BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 -'" .... CMS-200 Overburden Pressure Analysis - Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure Por Por Kl Ka (est) Ka NlIIber (ft) (Ovbd) (%) (%) (md) (md) (hyd) , -..-..-.... --........-- ........----- - 868 3450.7 ATM 25.8 1000 23.1 22.8 0.46 0.86 0.55 2000 22.4 0.18 0.40 1000 22.5 0.19 0.44 87A 3451.2 ATM 26.5 1000 23.8 23.2 1.16 1.49 1.45 2000 22.8 0.42 0.66 1000 22.9 0.44 0.71 87B 3451.8 ATM 35.4 1000 32.4 32.0 32.23 36.90 39.10 - 2000 31.4 29.06 33.36 1000 31.6 29.82 34.22 - 88A 3452.2 ATM 36.7 1000 32.5 32.2 44.26 47.80 49.12 2000 31.7 40.00 43.20 1000 31.9 41. 02 45.30 .... 88B 3452.7 ATM 35.9 1000 32.9 32.5 52.58 58.71 70.44 .. 2000 31.8 46.51 52.00 1000 32.1 47.57 53.23 - 89B 3453.7 ATM 32.8 1000 29.2 28.9 4.17 5.24 10.29 2000 28.3 1.60 2.18 1000 28.5 1.62 2.29 - 90A 3454.2 ATM 36.2 1000 32.9 32.7 40.60 46.28 48.14 2000 32_0 35.90 41.01 1000 32.3 36.93 42.14 page 23 .... ".¡. Area Alaska, Inc. KRU #3K-9 Kuparuk Field North SLope, ALaska Date: 19- Jan-86 Format;on: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: Bp·3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 ... .- CMS-200 Overburden Pressure Analysis ..... Conv (1) CMS·200 Automated System Cony (1) Sa~Le Depth Pressure por Par Kl Ka (est) Ka NlIIber (ft) (Ovbd) (%) (%) (RId) (RId) (hyd) ..-l ------- --.-...--- ---.-...--... 90B 3454.7 ATM 30.4 , 1000 27.4 27.0 0.50 0.80 0.83 2000 26.4 0.23 0.45 1000 26.6 0.25 0.48 91A 3455.2 ATM 30.7 1000 27.5 27.4 1.66 3.00 2.70 2000 26.9 0.80 1.53 .- 1000 27.1 0.81 1.59 91B 3455.8 ATM 31.0 1000 27.8 27.4 1.43 2.23 2.63 - 2000 26.9 0.81 1.31 1000 27.1 0.85 1.38 - 92A 3456.2 ATM 32.4 1000 28.3 28.3 1.86 3.40 2.70 2000 27.6 1.24 2.34 1000 27.9 1.31 2.47 - 92B 3456.7 ATM 32.6 1000 28.9 28.6 2.58 3.69 3.66 .. 2000 28.0 1.70 2.50 1000 28.2 1.78 2.63 - 93A 3457.2 ATM 33.0 1000 29_6 29.4 5.60 7.42 7.69 2000 28.8 4.10 5.48 1000 29.0 4.23 5.73 - 93B 3457.8 ATM 34.1 1000 30.1 29.9 12.82 15.83 17.07 2000 29.2 8_40 10_37 1000 29.4 8.61 10.77 page 24 '- 1 t- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 1.-- 1- CMS-200 Overburden Pressure Analysis .L- Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure Por Por Kl Ka (est) Ka NtJ11ber (ft) (Ovbd) (X) (X) (met) (met) (hyd) .1- -..--..-- ..---........ --........-...-- 94A 3458.2 ATM 33.4 L 1000 29.5 29.1 6.72 10.57 8.54 2000 28.5 4.66 7.44 1000 28.7 4.79 7.73 . 94B 3458.7 ATM 33.2 ...... 1000 29.3 29.0 5.50 7.25 7.73 2000 28.4 3.93 5.22 ..L 1000 28.6 4.03 5.43 ERR 95A 3459.8 ATM 35.6 ERR 1000 30.5 30.8 14.24 21.69 18.28 , ~ 2000 29.8 11.17 5.22 1000 30.1 11.66 17.89 - 95B 3459.8 ATM 36.0 1000 32.5 32.2 29.46 43.19 30.82 2000 31.2 25.42 37.37 1000 31.3 25.72 40.14 - 96A 3460.2 ATM 33.3 1000 29.9 29.7 12.66 19.13 14.96 . 2000 29.0 10.71 16.23 -"' 1000 29.1 10.89 16.49 99A 3463.2 ATM 9.0 1000 8.8 8.7 0.17 0.34 0.21 2000 8.2 0.08 0.16 1000 8.3 0.08 0.17 100A 3464.3 ATM 33.2 1000 30.1 29.7 36.88 41.74 46.33 2000 29.1 32_95 37_08 1000 29.3 33.71 37.96 page 25 Arco ALaska, Inc. KRU #3K-9 Kuparuk FieLd North SLope, ALaska Date: 19- Jan-ß6 Format;on: West Sak DrLg Fld: OBM Location : T13N R9E Sec35 FiLe: BP-3-1188 Lab: Anchorage AnaLysts: TLS;RGC;TDT API No: 50-0292-1656-00 CMS-200 Overburden Pressure AnaLysis Conv (1) CMS-200 Automated System Conv (1) SampLe Depth Pressure Por Por KL Ka (est) Ka NUllÐer (ft) (Ovbd) (%) (%) (met) (met) (hyd) ¡- -....--. .....--..--- i 1008 3464.6 ATM 33.5 ~-- 1000 30.7 30.5 36.12 39.61 41.25 2000 30.0 44.00 53.69 1000 30.1 34.46 37.82 101B 3465.7 ATM 37.3 1000 33.8 33.4 127.28 177.83 165.00 2000 32.7 111.25 155.09 1000 32.9 113.27 158.22 102A 3466.3 ATM 41.9 1000 37.6 37.5 519.37 551.00 453.09 2000 36.0 409.80 437.01 1000 36.4 423.64 450.85 102B 3466_7 ATM 38.4 1000 35.0 35.0 374.46 395.89 395.44 2000 34.4 343.27 361.19 1000 34.6 350.10 368.64 103A 3467.2 ATM 38.9 1000 35.5 35.2 338.67 356.27 386.54 - 2000 34.5 311.64 327.40 1000 34.7 318.81 334.91 104A 3468.2 ATM 41.0 1000 35.8 34.7 179.72 252.96 296.00 2000 33.7 154.79 218.90 1000 33.9 155.72 219.94 1048 3468.8 ATM 38.3 1000 35.4 35.0 376.87 393.95 424.23 2000 34_5 350_19 366_13 1000 34.7 357.83 374.25 page 26 ,3... .- Arco ALaska, Inc. KRU #3K-9 Kuparuk FieLd North SLope, ALaska Date: 19-Jan'86 Format;on: West Sak DrLg Fld: OBM Locat;on : T13N R9E Sec35 FHe : Bp·3·1188 Lab: Anchorage AnaLysts: TLS;RGC;TDT API No: 50'0292-1656·00 _JL- ...... CMS-200 Overburden Pressure AnaLysis -.... Cony (1) CMS-200 Automated System Cony (1) San¡>Le Depth Pressure Por por KL Ka (est) Ka Number (ft) (Ovbd) (%) (%) (md) (md) (hyd) ...... ...-................. .....................- 105A 3469.2 ATM 35.8 --- 1000 34.0 34.2 259.25 275 .40 427. 17 2000 33.6 240.60 255.68 1000 33.8 245.81 261.08 -' 105B 3469.6 ATM 37.9 1000 34.7 34.8 382.13 517.64 288.38 2000 34.2 348.02 470.52 - 1000 34.4 355.05 480.23 106A 3470.1 ATM 36.7 1000 33.8 33.5 156.74 168.66 187.52 ....;¡ 2000 32.9 133.82 143.63 1000 33.1 136.78 147.12 - 106B 3470.5 ATM 37.9 1000 34.9 34.5 343.00 465.32 401.05 2000 33.9 310.97 420.86 1000 34.2 318.23 430.71 107A 3471.4 ATM 31.3 1000 27.6 27.4 3.48 5.42 5.25 -' 2000 27.0 2.54 4.02 1000 27.1 2.62 4.32 107B 3471.7 ATM 31.1 1000 28.4 28.1 2.22 3.74 3.08 2000 27.5 1.68 2.94 1000 27.8 1.74 3.04 108A 3472.2 ATM 32.2 1000 29.4 29.2 12.98 15.32 15.80 2000 28.7 10.67 12.38 1000 28.9 10.73 13.12 page 27 ->- Arco Alaska, Inc. KRU #3K·9 Kuparuk Field North Slope, Alaska Date: 19' Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: Bp·3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50·0292,1656-00 .. CMS·200 Overburden Pressure Analysis - Cony (1) CMS·200 Automated System Cony (1) Sample Depth Pressure Por por Kl Ka (est) Ka Nl.JIber (ft) (Ovbc:l) (%) (X) (md) (md) (hyd) -'\ ............ ....-..-..... -............... 108B 3472.7 ATM 30.7 -" 1000 27.9 27.6 1.12 1.59 1.78 2000 27.3 0.73 1.08 1000 27.5 0.75 1.13 ...... 109A 3473.3 ATM 31.9 1000 28.8 28.5 3.31 5.38 4.17 2000 28.4 2.41 4.90 -- 1000 25.1 2.61 4.28 1098 3473.7 ATM 30.8 1000 27.7 27.5 1.12 1.65 1.54 - 2000 26.9 0.68 1.09 1000 27.1 0.74 1.16 110A 3474.2 ATM 30.8 1000 28.1 27.9 0.61 0.93 0.95 2000 27.5 0.27 0.45 - 1000 27.7 0.26 0.48 110B 3474.7 ATM 33.2 1000 30.3 30.2 6.35 9.09 7.46 .... 1 2000 29.6 4.25 6.68 1000 29.8 4.40 6.92 111A 3475.3 ATM 33.1 1000 29.1 29.4 0.28 0.60 0.57 2000 28.9 0.13 0.35 1000 29.1 0.14 0.37 111B 3475.6 ATM 32.5 1000 28.4 28.6 5.54 5.78 5.68 2000 28_1 4_20 4_61 1000 28.3 4.39 4.74 page 28 -~ -L Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19· Jan'86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: Bp·3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292,1656,00 .l .... CMS-200 Overburden Pressure Analysis - Cony (1) CMS·200 Automated System Cony (1) Saq:>le Depth Pressure Por Por Kl Ka (est) Ka NlIIÐer (ft) (Ovbd) (%) (%) (md) (md) (hyd) ...l -..-....-..- .............. 112A 3476.2 ATM 32.2 ..-1 1000 28.2 28.4 0.22 0.43 0.33 2000 28.0 0.09 0.22 1000 28.3 0.09 0.24 -- 112B 3476.8 ATM 39.3 1000 34.8 34.5 96.62 108.78 106.99 2000 33.0 77.13 87.62 1000 33.4 80.64 91.53 113A 3477.2 ATM 31.4 1000 28.3 28.1 1.77 3.17 2.89 2000 27.6 1.10 2.05 1000 27.8 1.18 2.20 113B 3477.8 ATM 31.5 1000 28.9 28.9 1.98 3.61 3.18 2000 28.4 1.29 2.41 1000 28.5 1.37 2.58 114A 3478.2 ATM 31.8 1000 28.8 28.6 2.30 4.02 3.23 - 2000 28.0 1.49 2.69 1000 28.2 1.59 2.89 114B 3478.7 ATM 34.2 1000 30.7 30.5 26.43 38.30 33.01 2000 29.8 19.33 28.15 1000 30.1 20.34 29.60 115A 3479.2 ATM 33.6 1000 30.6 30.4 34.75 49.55 41. 97 2000 29.7 28.38 40.59 1000 29.9 29.59 42.32 page 29 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19'Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP'3-1188 Lab: Anchorage Analysts: TlS¡RGC¡TDT API No: 50-0292,1656,00 CMS·200 Overburden Pressure Analysis Conv (1) CMS-200 Automated System Conv (1) Sa~le Depth Pressure Por Por Kl Ka (est) Ka Number (ft) ( Ovbe!) (%) (%) (md) (md) (hyd) L -..._--- --..---- .....-...- 1158 3479.5 ATM 35.8 1000 31.9 31.6 34.87 40.04 46.38 2000 30.5 26.64 30.60 1000 30.8 27.57 31. 72 116A 3480.3 ATM 37.2 1000 34.3 34.2 83.32 96.34 96.68 2000 32.6 63.97 74.88 1000 32.9 66.72 78.16 1168 3480.8 ATM 33.5 1000 30.3 29.8 11.10 13.41 14.55 2000 29.2 8.31 10.19 1000 29.4 8.73 10.72 117A 3481. 2 ATM 34.4 1000 31.3 31.1 23.52 34.28 30.89 2000 30.4 18.65 27.23 1000 30.7 19.43 28.37 1178 3481.7 ATM 35.1 1000 31.8 32.0 53.09 74.89 60.99 2000 31.4 45.24 63.95 1000 31.6 46.49 65.79 118B 3482.7 ATM 33.3 1000 29.9 29.7 5.37 8.45 6.44 2000 29.0 3.78 6.05 1000 29.2 3.95 6.36 119A 3483.2 ATM 35.3 1000 32.1 31.8 26.51 38.45 31.58 2000 31.2 22.37 32.48 1000 31.4 23.20 33.69 page 30 ~ -"'- Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan'86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: Bp·3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 .J- - CMS-200 Overburden Pressure Analysis Cony (1) CMS·200 Automated System Cony (1) S~le Depth Pressure por Por Kl Ka (est) Ka NUlÐer (ft) (Ovbd) (%) (%) (met) (met) (hyd) -4 --......... .............. ---..----- 119B 3483.7 ATM 36.9 1000 33.1 32.9 80.18 112.14 94.85 --' 2000 32.2 66.19 92.34 1000 32.4 68.54 95.83 -. 120A 3484. 1 ATM 33.9 1000 29.8 29.9 5.24 8.16 8.13 2000 29.2 3.41 5.37 1000 29.5 3.48 5.56 120B 3484.7 ATM 36.3 1000 32.7 32.7 46.99 66.58 55.02 2000 31.9 39.05 55.53 1000 32.2 40.49 57.56 - 121A 3485.2 ATM 36.7 1000 33.2 33.2 58.48 82.46 72.61 2000 32.5 49.62 69.92 1000 32.7 50.82 71.80 121B 3485.8 ATM 35.7 1000 32.5 32.1 18.48 21.58 24.47 2000 31.5 15.29 17.94 1000 31.7 15.88 18.65 122A 3486.4 ATM 32.1 1000 29.4 28.9 4.79 7.86 6.32 2000 28.4 2.20 3.71 1000 28.6 2.34 3.92 122B 3486.7 ATM 31.4 1000 28.7 28.4 2.07 3.00 2.61 2000 27.9 1.22 1.85 1000 28.1 1.28 1.95 page 31 Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: 8P-3-1188 Lab: Anchorage Analysts: TLS;RGC;TDT API No: 50-0292-1656-00 - CMS-200 Overburden Pressure Analysis - Conv (1) CMS-200 Automated System Conv (1) Sample Depth Pressure Por por Kl Ka (est) Ka NUTtIer (ft) (Ovbd) (%) (%) (met) (met) (hyd) ............. .. ................. 123A 3487.2 ATM 32.5 1000 29.8 29.4 2.25 3.70 3.35 2000 29.0 0.80 1.43 1000 29.2 0.80 1.40 1238 3487.7 ATM 33.1 1000 29.4 29.5 2.80 4.69 5.15 2000 29.0 1.50 2.69 1000 29.2 1.55 2.81 124A 3488.2 ATM 33.5 1000 30.7 30.5 2.94 4.73 3.43 2000 30.1 1.94 3.26 1000 30.3 2.06 3.46 124B 3488.7 ATM 33.0 1000 30.0 29.8 3.18 5.12 5.04 2000 29.4 1.58 3.56 1000 29.5 1.68 3.82 125A 3488.7 ATM 31.8 1000 28.8 28.6 1.14 1.99 2.30 - 2000 28.1 0.56 1.07 1000 28.3 0.60 1.14 125B 3489.8 ATM 33.4 1000 30.4 30.3 5.22 6.61 6.35 2000 29.8 4.08 5.23 1000 30.0 4.24 5.44 126A 3490.3 ATM 33.4 1000 30.3 30.0 3.54 4.58 5.19 2000 29_5 2_32 3_11 1000 29.7 2.44 3.29 page 32 --. Arco Alaska, Inc. KRU #3K·9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File : BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 ..-1 ... CMS-200 Overburden Pressure Analysis .. Conv (1) CMS·200 Automated System Cony (1) Sa~le Depth Pressure por Por Kl Ka (est) Ka Number (ft) (Ovbd) (%) (%) (md) (md) (hyd) ---1 .. .. .. ..... ....... ....-............ I ¡ 126B 3490.8 ATM 37.2 --" 1000 33.2 32.7 15.60 18.62 19.10 I 2000 31.9 11.89 14.24 1000 32.2 12.61 15.13 ~ 127A 3491.2 ATM 35.1 1000 31.9 31.7 17.12 20.10 22.43 2000 31.1 14.04 16.44 -, 1000 31.3 14.50 17.01 127B 3491.7 ATM 34.1 1000 31.2 30.8 1.18 1.81 1.53 ~, 2000 30.3 0.71 1.19 1000 30.5 0.76 1.28 - 128A 3492.1 ATM 31.6 1000 29.1 28.6 2.17 3.36 3.36 2000 28.1 1.44 2.55 -- 1000 28.3 1.52 2.68 128B 3492.7 ATM 32.8 1000 30.1 29.6 4.17 6.77 5.61 2000 28.9 3.01 4.98 1000 29.1 3.14 5.20 129A 3493.1 ATM 31.4 1000 28.6 28.6 1.35 2.41 2.12 2000 28.1 0.83 1.55 1000 28.3 0.84 1.61 129B 3493.7 ATM 32.4 1000 29.9 29.4 4.19 6.81 5.78 2000 28.8 3_06 5.17 1000 29.0 3.21 5.41 page 33 .-l -S. Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 -'- -" CMS-200 Overburden Pressure Analysis Cony (1) CMS-200 Automated System Cony (1) Sample Depth Pressure por Por Kl Ka (est) Ka Number (ft) (Ovbd) (%) (%) (me!) (me!) (hyd) --'. .---..-.. .-.-...--- 130A 3494.2 ATM 31.3 --'1 1000 29.3 28.3 2.80 3.49 3.59 2000 27.8 2.25 2.87 1000 28.0 2.33 2.97 -- 130B 3494.6 ATM 31.2 1000 29.1 29.0 3.46 6.13 2.69 2000 28.3 2.78 5..01 1000 28.5 2.89 5.18 131A 3495.2 ATM 30.5 1000 28.0 27.8 1.53 2.69 3.08 2000 27.3 0.57 1.16 1000 27.5 0.58 1.21 131B 3495.7 ATM 30.9 1000 28.3 27.5 1.10 1.63 1.70 2000 27.0 0.78 1.18 1000 27.2 0.83 1.25 132A 3496.2 ATM 31.9 1000 29.1 28.8 1.96 2.79 2.94 2000 28.2 1.30 1.96 1000 27.4 1.37 2.06 132B 3496.7 ATM 33.0 1000 30.3 29.5 15.17 18.59 21.02 2000 28.7 8.90 11.22 1000 28.9 9.44 11.94 - 133A 3497.2 ATM 30.9 1000 28.2 28.0 2.84 3.66 3.20 2000 27.2 1.27 1.81 1000 27.4 1.28 1.83 page 34 - Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19- Jan-86 Formation: West Sak Drlg Fld: OBM Locat;on : T13N R9E Sec35 File: BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 -~ CMS-200 Overburden Pressure Analysis - Conv (1) CMS-200 Automated System Conv (1) Sa~le Depth Pressure Por por Kl Ka (est) Ka NlIIIber (ft) (Ovbd) (%) (%) (md> (md) (hyd) ....._e... ..........._ --......----- 1338 3497.8 ATM 30.2 1000 27.6 27.3 1.32 2.00 1.90 - 2000 26.7 0.91 1.45 1000 26.9 0.95 1.52 134A 3498.2 ATM 30.3 1000 26.8 26.7 0.56 1.07 0.93 2000 26.2 0.36 0.73 1000 26.4 0.37 0.77 134B 3498_7 ATM 31.1 1000 28.7 28.4 1.66 2.56 2.60 2000 27.9 1.36 1.98 1000 28.1 1.52 2.16 135A 3499.2 ATM 29.6 1000 26.9 26.7 0.33 0.61 0.46 2000 26.1 0.22 0.43 1000 26.3 0.22 0.45 135B 3499.7 ATM 31.0 1000 28.5 27.8 3.66 4.59 5.10 - 2000 27.1 1.94 2.66 1000 27.3 2.11 2.85 136A 3500.2 ATM 29.1 1000 26.8 26.7 0.23 0.53 0.47 2000 26.3 0.15 0.37 1000 26.4 0.15 0.39 136B 3500.6 ATM 29.7 1000 27.1 27.0 0.49 0.93 0.72 2000 26.5 0.26 0.60 1000 26.7 0.28 0.64 page 35 ...:>... Arco Alaska, Inc. KRU #3K-9 Kuparuk Field North Slope, Alaska Date: 19-Jan'86 Format;on: West Sak Drlg Fld: OBM Location : T13N R9E Sec35 F;le : BP-3-1188 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No: 50-0292-1656-00 -~ - CMS-200 Overburden Pressure Analysis Saq>le Nl.mber Depth (ft) Conv (1) Pressure Por (Ovbd) (%) CMS·200 Automated System Conv (1) por Kl Ka (est) Ka (%) (md) (md) (hyd) - .................... .. -............-....... 137A 3501.3 29.4 27.8 ---'- ATM 1000 2000 1000 137B 3501.5 ATM 1000 2000 1000 30.9 28.1 27.6 3.03 5.93 6.00 27.1 2.06 4.26 27.3 2.12 4.46 27.9 1.07 2.18 2.30 27.2 0.81 1.53 27.4 0.86 1.72 (1) Conv - Denotes Conventional Analysis Por (ATM) Grain Volumes are determined with Boyles Law Helium He;se Gauge Poros;meter. Bulk Volumes are determined by Archimedes method with toluene utilized as the saturat;ng fluid. Pore volumes and Horizontal Ka are determined in hydrostatic holder with 1000 psi boot pressure. Note - Heise Gauge grain volumes are used in CMS-200 calculations. Detailed Lithological Descriptions - -' -- ,- J Lithologic descriptions were done on all plug samples from the Kuparuk River Unit #3K-9 well - West sak Fo.z:7llation. These aœ ooventional descriptions using a binocular 1- microsoo¡:e, hand lens, JJßS IOCk-oolor chart, grain size scales, OO1lIp3I'ison charts for j parœntage estbnation, and CX>1lIp3I"Í5on charts for sorting and roundness determination. The fol1cwing format was used for describing sandstone and siltstone/1lIldstone. ~-- ¡ J ,- 1.- Sandstone Mudstones/siltstones 1. Color 1. COlor '- 2. Grain size 2. Grain size JOCJdifiers 3. Sorting 3. Cerœnting and/or degree 4. Roundness of consolidation 1---- 5. Celœnting and/or degree 4. % estimation of accessory of oonsolidation minerals 6. % estimation of quartz, 5. SediJæntary structures or lithic frag¡ænts, and features , Jratrix 6. Fracture description 7. % estimation of accessory minerals 1 8. Sedi:Jœntary structures or features 9. Fracture description -- -. -- lA 3365.2 siltstone - Itgy-mltgy, Vaxg and sdy, sl calc, 1lOd cons, tr mica, tr carb frags, tr pyr lB 3365.7 siltstone - Itgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, tr pyr, tr glauc 2A 3366.2 siltstone - ltgy-mltgy, varg and sdy, sl calc, 1lOd cons, tr pyr, tr glauc 2B 3366.7 siltstone - 1tgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, mnr small pyr b1ebs, mnr vfgr sdy lam - 3A 3367.2 siltstone - 1tgy-mltgy, varg and sdy, sl calc, 1lOd cons, mnr small pyr b1ebs, tr carb frags 3B 3367.7 siltstone - ltgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, mnr small pyr blebs, tr carb frags 4A 3368.2 siltstone - 1tgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, grdg to vslty ndst, tr pyr, tr carb frags 4B 3368.7 siltstone - 1tgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, mnr intlam vfgr ss, tr m-cgr 00, tr pyr 5A 3369.2 siltstone - Itgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, tr pyr and ¡x:>s magnetite 5B 3369.7 siltstone - Itgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, mnr vfgr sdy px:kets, t.r-l % pyr, tr carb frags 6A 3370.2 siltstone - 1tgy-mltgy, varg and sdy, sl calc, 1lOd cons, abnt vfgr sdy px:kets, tr pyr b1ebs, tr carb frags 6B 3370.7 siltstone - 1tgy-mltgy, varg and sdy, sl calc, 1lOd cons, mnr vfgr sdy px:kets, 1% pyr blebs 7A 3371.2 Siltstone - Itgy-mltgy, va:rg and sdy, sl calc, 1lOd cons, tr pyr, tr carb frags - 7B 3371.7 Siltstone - 1tgy-mltgy, varg and sdy, sl calc, 1lOd cons, 1% small pyr b1ebs, tr carb frags 8A 3372.2 siltstone - 1tgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, tr small pyr b1ebs 8B 3372.7 siltstone - 1tgy-mltgy, vaxg and sdy, sl calc, 1lOd cons, tr pyr bleb, tr carb frags, grdg to vslty vfgr ss 9A 3373.2 Sandstone - It olv gy, vf-fgr, pred vfgr, well srtd, sbang, tr calc cmt, sl fri, com¡;x>sed pred of 40-50% qtz, 30% lith frags, 20-30% axg and slty mtrx, mnr mica, tr glauc 9B 3373.7 Sandstone - 1t olv gy, vfgr, well srtd, sbang, sl calc, :rrr::Xl cons-s1 fri, com¡çx;¡sed pred of qtz and lith frags, 30-40% axg and slty mtrx, mnr mica, JDS magnetite b1ebs, tr glauc, grdg to sdy-arg sl tst lOA 3374.2 Sandstone - It olv gy, vfgr, well srtd, sbaI¥;]-sbrd, sl calc, m::xi rons, cx::>m¡x:>Sed peed of qtz and lith frags, 30-40% BIg and slty mtrx, mnr mica, tr pyr, [DB nagnetite lOB 3374.7 Sandstone - It olv gy, vfgr, well srtd, sbang-sbrd, sl calc, m::xi cons, cx::>m¡x:>Sed peed of qtz and lith frags, 20-30% BIg and slty mtrx, mnr mica, tr carb frags, tr pyr --'- ..... 1lA 3375.2 Sandstone - 1t olv gy, vfgr, well srtd, sbang, sl calc, m:;x1 rons, oomp:>sed pred of qtz and lith frags, 30-40% BIg and slty mtrx, mnr mica, mnr .wr blabs, tr carb frags ..... 1m 3375.7 Sandstone - 1t olv gy, vfgr, well-m:;x1 well srtd, sbang-sbrd, sl calc, sl fri, cx::>m¡x:>Sed of 50% qtz, 20-30% lith frags, 20-30% BIg and slty mt:rs, mnr mica, tr carb frags ... 12A 3376.2 Sandstone - It olv gy, vfgr, very well srtd, sbang-sbrd, tr calc cmt, sl fri, cx:>IlIpJSed of 50-60% qtz, 20-30% lith frags, 20-30% BIg and slty mtrx ..& 12B 3376.7 Sandstone - It olv gy, vfgr, very well srtd, sbrd-rd, tr calc cnrt, sl fri, cx::>mp::>sed of 50-60% qtz, 20-30% lith frags, 20-30% BIg and slty mtrx, 2-3% mica - 13A 3377.2 Sandstone - 1t olv gy, vfgr, well srtd, sbrd-rd, tr calc cnrt, sl fri, cx::>m¡x:>Sed of 50-70% qtz, 20% lith frags, 20-30% BIg and slty mtrx, 1% mica, tr pyr ~ 13B 3377.8 Sandstone - 1t olv gy, vfgr, well srtd, sbang, sl fri, comp:>seð of 50-60% qtz, 15-25% lith frags, 20-30% BIg and slty mtrx, 2-3% mica, tr pyr 14A 3378.2 sandstone - 1t olv gy, vfgr, wel1-m:;x1 well srtd, sbang, tr calc cnrt, Irrrl rons-slfri, comp:>seð of 60-70% qtz, 10-20% lith frags, 15-20% BIg and slty mtrx, 1-3% mica, tr carb frags -. 14B 3378.7 sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, m::xi oons-fri, comp:>Sed of 60-70% qtz, 10-20% lith frags, 15-20% BIg and slty mtrx, up to 5% mica in places, tr pyr ~ 15A 3379.2 Sandstone - It olv gy, vfgr, well srtd, sbang, sl calc in places, fri, com¡x:>Sed of 70% qtz, 10-20 % lith frags, 15% BIg and slty mtrx, 3-5% mica 15B 3379.7 Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, fri, comp:>seð of 50-60% qtz, 15-25% lith frags, 15-25% BIg and slty mtrx, 2-3% mica 16A 3380.2 Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, tr calc cnrt, sl fri, comp::>sed of 60-70% qtz, 10-20% lith frags, 20-30% BIg and slty mtrx, 3-5% mica, tr carb frags 16B 3380.6 Sandstone - 1t olv gy, vfgr, tr fgr sd, well srtd, sbang-sbrd, fri, rom¡xJSed of 50-70% qtz, 10-20% lith frags, 20-30% BIg and slty mtrx, 2-3% mica 17A 3381.1 sandstone - It olv gy, vfgr, tr fgr, well srtd, sbang-sbrd, fri, cx:>IlIpJSed of 50-60% qtz, 20% lith frags, 20-30% BIg and slty mtrx, ,1-3% mica, tr py.r Sandstone - olv gy, vf-ra:;¡r, pred vfgr, well-llrXi srtd, sbrd-rd, uncons 00, comp:>sed of 60% qtz, 30-40% lith frags, 1-5% sIt, tr-l% mica, bivalve shell fragrœnts 26A 3390.2 siltstone - 1t olv gy, pred sIt, arg, abnt vfgr qtz 00, sl calc, p cons, 5- 10% mica, induoed bed p:u:-al1e1 break 26B 3390.7 siltstone - 1t olv gy, pred sIt, arg, calc cmtd, llrXi cons, abnt mica, mnr cluster of vfgr 00, induoed horizontal open to closed fracture present 27A 3391.2 Sandstone - It olv gy, vfgr, very well srtd, sbrd-rd, very fri, cx:>mfX>Sed of 50-60% qtz, 10-20% lith frags, 10-15% slty mtrx, 3-5% mica 27B 3391.7 Sandstone - 1t olv gy, vfgr, very well srtd, sbrd-rd, sl fri-fri, cx:>mfX>Sed of 40-50% qtz, 10-20% lith frags, 30-40% æ::g and slty mtrx, 3-5% mica, grades to a vsdy sl1:st, induoed bed parallel break ~ l7B 3381.5 ~ 18A 3382.1 -"- 18B 3382.9 .- 19B 3383.7 .. 20A 3384.2 .....1 20B 3384.7 --> 23A 3387.2 - 23B 3387.8 - 24A 3388.1 24B 3388.7 -' 25A 3389.2 - 25B 3389.8 - - - Sandstone It olv gy, vf-fgr, pred vfgr, well srtd, sbang-sbrd, fri, cx:>m¡x:>sed of- 60% qtz, 20-30% lith frags, 10-20% arg and slty mtrx, 1-3% mica Sandstone - 1t olv gy, 30% 1t gy, arg sltst, ss is vf-fgr, pred vfgr, well srtd, sbang-sbrd, calc cmtd in plaoes, fri, cx:>mp:>sed of 40-60% qtz, 20-30% lith frags, 30% arg and slty mtrx, 1% mica siltstone - ltgy, varg and sdy, calc cmtd, llrXi oons, 30% 1t olv gy vfgr slty fri intbd ss Sandstone - It olv gy, vfgr, very well srtd, sbang, sl calc, llrXi cons-s1 fri, cx:>m¡x:>sed pred of qtz and lith frags, 30-40% arg and slty mtrx, 5% mica Sandstone - It olv gy, vfgr, well srtd, sbang-sbrd, calc cmtd, fri, c::omp::>sed of 50-60% qtz, 15-20% lith frags, 30% æ::g and slty mtrx, 2-3% mica, tr lams Mudstone - 1tgy-mltgy, 30% 1t olv gy, vfgr, vs1ty and æ::g lam ss, ICdst is slty with SOJTe 00, vcalc, thn lam of fgr 00 separates ss and JIdst Sandstone - olv gy, vf-fgr, pred vfgr, well srtd, sbrd-rd, uncons, cx:>mp:>sed of 60-70% qtz, 20-30% lith frags, 5-10% slt, tr-l% mica Sandstone - olv gy, vfgr, very well srtd, sbrd-rd, unoons, c::omp::>sed of 60-70% qtz, 20-30% lith frags, 5% slt, tr mica, tr pyr Sandstone - olv gy, vf-fgr, pred vfgr, well srtd, sbrd-rd, uncons, com¡;x>sed of 70% qtz, 20-30% lith frags, 5% sIt, tr mica Sandstone - olv gy, vf-fgr, well srtd, sbang-rd, uncons 00, oomp:>seð of 60% qtz, 30-40% lith frags, 5% sIt, 1-2% mica Sandstone - olv gy, vf-fgr, well srtd, sbang-rd, unoons 00, comp::>sed of 60% qtz, 30-40% lith frags, 5% sIt, 1-2% mica --"- -'- 28A 3392.2 siltstone - ltgy-lt olv gy, pred arg, mnr p::>ckets of vfgr ss, calc cmt, nr::xj- well rons, mnr magnetite bleb 29B 3393.7 Sandstx:>ne - 1t olv gy, vfgr, very well srtd, sbang-sbrd, very fri, oom¡;x:>sed of 50-60% qtz, 20-30% lith frags, 10% arg and slty mtrx, 5-10% mica, induced bed ¡;erallel break .-.1. ..... 30A 3394.2 siltstone - 1tgy, varg, sl calc, nr::xi rons, mnr say lam, abnt pyr and carb material --" 30B 3394.7 Sandstx:>ne - It olv gy, 10% 1tgy arg sltst, ss is vfgr, very well srtd, sbang, sl calc, fri, oom¡;x:>sed of 40-50% qtz, 20% lith frags, 20-30% arg and slty mtrx, 5% mica, 1% carl:> frags, lams present 3lA 3395.2 Sandstone - It olv gy, vfgr, very well srtd, sbrd, sl calc cmt, fri, romp::>sed of 50-60% qtz, 10-25% lith frags, 10-20% arg and slty mtrx, 3% mica, induced bed ¡;erallel break ~ ~ 3lB 3395.8 Sandstone - olv gy, vfgr, very well srtd, sbrd, vfri-U!1rons 00, womp:>sed of 60-70% qtz, 20-30% lith frags, 5-10% arg and slty mtrx, 1-2% mica, calc shell frags - 32A 3396.2 siltstone - ltgy-mltgy, varg, mnr vfgr 00, sl calc, nr::xi rons, mica, mnr bd vfgr slty ss 32B 3396.7 Sandstx:>ne - It olv gy, vfgr, well srtd, sbang-sbrd, sl calc, fri, oomp:>sed of 60% qtz, 20% lith frags, 10-20% arg and slty mtrx, 3% mica, tr pyr 33A 3397.2 siltstone - Itgy-mltgy, varg, calc, nr::xj rons, mica, mnr vfgr say lam, .wr blebs, carb frags 33B 3397.7 Sandstone - It olv gy, vfgr, well srtd, sbrd, tr calc cmt, fri, oo.m¡;x:>sed of 60-70% qtz, 10-20% lith frags, 10-20% arg and slty mtrx, 1-3% mica, induced bed ¡;eralle1 break 34A 3398.2 Sandstone - 1t olv gy, vfgr, very well srtd, sbrd, fri, 50-60% qtz, 10-20% lith frags, 15-25% arg and slty mtrx, 5% mica - - - - 35B 3399.7 Sandstone - It olv-olv gy, vfgr, very well srtd, sbrd, fri, rom¡;x:>sed of 60% qtz, 10-20% lith frags, 10-20% arg and slty mtrx, 5% mica, abnt calc shell frags 36A 3400.1 Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, fri, rom¡;x:>sed of 50-60% qtz, 10-20% lith frags, 15-25% arg and slty mtrx, 3-5% mica 36B 3400.7 Sandstone - olv gy, vfgr, very well srtd, sbrd, fri, rom¡;x:>sed of 50-60% qtz, 10-20% lith frags, 20-30% arg and slty mtrx, 3% mica, induced bed parallel break - 37A 340L2 Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, fri, mmp:;sed of 60-70% qtz, 10-20% lith frags, 10-20% arg and slty mtrx, 5-7% mica 37B 3401.7 siltstone - It olv gy, arg, tr calc cmt, nr:xj cons, 30% vfgr sdy 1æns, abnt mica, tr carb frags 38A 3402.1 sandstone - It olv gy, vfgr, well srtd, sbang-sbrd, fri, oom.fX)SErl of 50-60% qtz, 20-30% lith frags, 15-20% arg and slty mtrx, 5% mica 38B 3402.8 Sandstone - It olv gy, vf-o;¡r, pred vf-fgr, nr:xj srtd, sbang-sbrd, fri, comp:>sed of 50-60% qtz, 20-30% lith frags, 15-20% arg and slty mtrx, 5-7% mica, 1-2% carb frags, tlm lam pyr and o;¡r sd, induced bed parallel op:m fracture - 39A 3403.2 Sandstone - 1t olv gy, vf-fgr, 2% o;¡r, pred vfgr, well srtd, sbang, fri, comp:>sed of 50-60% qtx, 20-30% lith frags, 15-20% arg and slty mtrx, 5% mica 40A 3404.1 Sandstone - It olv gy, vfgr, well srtd, sbang-sbrd, fri, oomp:>sed of 50-60% qtz, 10-20% lith frags, 25-35% arg and slty mtrx, 3% mica .... 40B 3404.7 Sandstone - 1t olv gy, vf-fgr, well srtd, sbang, fri, comp:>sed pred of qtz, lith frags, and abnt arg-s1ty mtrx, 1% carb frags 41A 3405.2 Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, fri, COIlIp:>sed of 50-60% qtz, 20-30% lith frags, 10-15% arg and slty :rntrx, 3% mica, induced bed parallel breaks present 41B 3405.6 - 42A 3406.1 ~ 42B 3406.7 --~- 43A 3407.2 -, 43B 3407.8 siltstone - It olv gy, pred sIt, arg, mnr vfgr 00, m::xI roDS, 5% mica, sorce vfgr sdy lams Sandstone - 1t olv gy, 30% 1tgy arg sdy sl calc intbd sltst, ss is vfgr, well srtd, sbang, fri, CXJIlIlX>Sed of 50% qtz, 20-30% lith frags, 20-30% arg and slty :rntrx, 2-3% dism pyr, 2-3% carb frags . Sandstone - 1t olv gy, vfgr, well srtd, sbang-sbrd, fri, romp:>sed of 40-60% qtz, 20-30% lith frags, 20-30% slty mtrx, 3-5% pyr blebs, 2-3% mica, 2% carb frags siltstone - 1t-mltgy, varg and sdy, sl calc, nr:xj rons, mica, abnt intermixed vfgr sl ty fri ss, tr pyr, tr carb frags, bioturb Sandstone - 1t olv gy, vfgr, well srtd, sbang, fri, comp:>sed of 50-60% qtz, 20-30% lith frags, 20-30% arg and slty:rntrx, 2-3% mica, mnr intermixed arg sltst, bioturb 44A 3408.2 Sandstone - It olv gy, vfgr, well srtd, sbang, fri, COIlIp:>sed pred of qtz, slt, and lith frags, 2-3% pyr blebs, abnt arg-s1ty burs, bioturb 44B 3408.7 Sandstone - It olv gy, vfgr, well srtd, sbang, fri, romp:>sed of 40-60% qtz, 20-40% lith frags, 20-30% arg and slty:rntrx, 2-3% mica, tr dism pyr, mnr arg sltst - -'>- ' - 45A 3409.2 Sandstone - It olv gy, vfgr, well srtd, sbang, fri, romp:>sed of 40-50% qtz' 30-40% lith frags, ~0-20% arg and slty mtrx, 2-3% mica, mnr intbd slty :rrrlst 46A 3410.2 sandstone - It olv gy, vfgr, well srtd, sbrd, vfri, eomp:>sed of 60-70% qtz, 20-30% lith frags, 5% slt, 1% mica 46B 3410.7 siltstone - 1tgy-lt olv gy, vaxg and sdy, sl calc, 1lOO cons, abnt vfgr sdy burs, abnt p:>s magnetite grs 47A 3411.2 Sandstone - 1t olv gy, vfgr, well srtd, sbang, vfri, oomp:>sed of 50-60% qtz, 20-30% lith frags, 10-20% axg and slty mtrx, 1% mica, induced bed parallel break 49A 3413.2 siltstone - ltgy, 40% It olv gy intbd vfgr slty fri ss, sltst is varg, sdy, sl calc, mica, tr magnetite 50A 3414.2 siltstone - It-mltgy, vaxg, sdy, sl calc, 1lOO cons, mica, tr magnetite 50B 3414.7 siltstone - 1t-mltgy, varg, abnt vfgr sd, sl calc, 1lOO oons, mica, tr pyr, tr magnetite 51A 3415.2 siltstone - Itgy, vaxg, sdy, sl calc, ICOd oons, mica, tr carb frags 5IB 3415.7 siltstone - Itgy, vaxg,sdy, sl calc, 1lOO cons, mica, pyr blebs, tr fXJS magnetite -- 52A 3416.2 Siltstone - ltgy, vaxg, sdy, sl calc, ICOd rons, mnr pyr bleb, tr fDS magnetite -- 52B 3416.7 siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 3% pyr blebs, 1% mica, grdg to vslty c1yst 53A 3417.2 siltstone - ltgy, varg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 1% pyr bleb, 1% mica, grdg to vslty clyst 53B 3417.7 siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod cons, 2-3% carb frags, 1% mica, grdg to vs1ty c1yst 54A 3418.2 -" 54B 3418.7 -. 55A 3419.2 ........... 55B 3419.7 --,;;,:,' 56A 3420.2 - 56B 3420.7 - -- siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 3% pyr blabs, 1% mica, grdg to vs1ty c1yst siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 1% pyr blebs, 1% mica, grdg to vslty clyst siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 1% pyr blabs, 1% mica, grdg to vslty clyst siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 2-3% pyr blabs, 1% mica, 2% fos bivalves, grdg to vs1ty clyst Siltstone - 1tgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 1% pyr blebs, 1% mica, grdg to vslty clyst siltstone - Itgy, vaxg, 1-3% vfgr sd, sl calc cmt, :rrod oons, 2-3% carb frags, 1% mica, 1% fos bivalves, mnr vfgr sdy burs, grdg to vs1ty clyst 57A 3421.2 siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc cmt, m:Xl rons, 2-3% carb frags, 1% mica, mnr vfgr sdy blrs, grdg to vs1 ty clyst 57B 3421.7 siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc cmt, m:Xl rons, 2-3% carb frags, 1% mica, mnr vfgr sdy blrs, grdg to vs1ty c1yst 58A 3422.3 siltstone - 1tgy, varg, 1-3% vfgr 00, sl calc cmt, 10CJd rons, 2-3% carb frags, 1% mica, mnr vfgr sdy blrs, grog to vs1ty c1yst, induced bed parallel fracture 58B 3422.7 Siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc cmt, 10CJd rons, 2-3% carb frags, 1% mica, vfgr sdy burs, grdg to vs1ty c1yst 59A 3423.2 siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc cmt, 10CJd rons, 2-3% carb frags, 1% mica, vfgr sdy burs, grdg to vs1ty c1yst 59B 3423.7 siltstone - Itgy, varg, 3-5% vfgr sd, sl calc cmt, 10CJd rons, 2-3% carb frags, 1% mica, 3-5% pyr blabs, vfgr sdy burs, grdg to vs1ty clyst 60A 3424.2 siltstone - Itgy, varg, 3-5% vfgr 00, sl calc cmt, 10CJd cons, 2-3% carb frags, 1% mica, 3-5% pyr blabs, vfgr sdy burs, grdg to vslty c1yst 60B 3424.7 siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc cmt, 10CJd rons, 2-3% carb frags, 1% mica, 1-3% pyr blabs, vfgr sdy burs, grog to vslty clyst 6lA 3425.2 siltstone - 1tgy, varg, 10-20% vfgr sd, sl calc cmt, sl fri-fri, 2-3% carb frags, 1% mica, 1-3% pyr blabs, bioturb, grog to arg-vslty sandstone 61B 3425.7 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, romp:>sed of 40-50% qtz grs, 40-50% lith frags (including carb frags and mica), 10-20% arg-s1ty mtrx, tr-l% magnetite, bioturb, grdg to sdy 11dst 62A 3426.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, oomp:>sed of 40-50% qtz grs, 40-50% lith frags(including carb frags and mica), 10-20% arg-s1ty mtrx, tr-l% magnetite, bioturb, grdg to sdy 11dst 62B 3426.8 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, oomp:>sed of 40-50% qtz grs, 40-50% lith frags (including carb frags and mica), 10-20% arg-s1ty mtrx, tr-1% magnetite, bioturb, grãg to sdy mist _. 63A 3427.2 Sandstone - 1t olv gy, vfgr, very well srtd, sbang-sbrd, fri, romp:>sed of 40- 50% qtz, 20-30% lith frags, 10-20% arg and slty mtrx, abnt intermixed 1tgy sltst, abnt bioturb - - 63B 3427.7 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, romp:>sed of 40-50% qtz grs, 40-50% lith frags (including carb frags and mica), 10-20% arg-s1ty mtrx, tr-l% magnetite, bioturb, grog to sdy 11dst 64A 3428.2 siltstone - 1tgy-lt olv gy, varg, 1-2% vfgr sd, calc cmt, well rons, 3-5% carb frags, 1% mica, half of smpl is Itgy the other half is 1t olv gy, the haJ.f that; is It; olv gy is [X>Ssibly ank.-sid cnrtd 64B 3428.7 .L.- 65A 3429.2 ..L- 65B 3429.8 -"- 66A 3430.2 ..L Sandstone - rrr.;¡y, vfgr, very well srtd, ang-sbId, vcalc cmt, very well roIlS, hd, CD1lI¡x>sed of 30-40% qtz grs, 40-50% lith frags (peed carb frags), 10-20% calc c:nrt mtrx, ¡x>s ank-sid cmt due to high grain density, grog to sdy li1æstone Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, c:omp::>sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst Sandstone - 1tgy, vfgr, very well srtd, ang-sbId, sl calc cmt, sl fri-fri, oom¡x>sed of 30-40% qtz grs, 30-40% lith frags(caxb and mica), 20-30% arg-s1ty mtrx, tr-l% magnetite, grdg to vsdy sltst Sandstone - Itgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, com¡x>sed of 30-40% qtz grs, 30-40% lith frags (caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, mnr bioturb -- 66B 3430.8 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, c:omp::>sed of 30-40% qtz grs, 30-40% lith frags(caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, nrx:1 bioturb ...L 67A 3431.1 -'- 67B 3431.8 -""- 68A 3432.3 ~ 68B 3432.8 .- 69A 3433.2 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, c:omp::>sed of 30-40% qtz grs, 30-40% lith frags(caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, nrx:1 bioturb sandstone - It olv gy, vfgr, well srtd, sbrd, fri, oomp:>sed of 40% qtz, 20- 30% lith frags, 20% arg and slty mt;rx, abnt intennixed arg sltst, bioturb Sandstone - Itgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, oomp:>sed of 30-40% qtz grs, 30-40% lith frags (caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, nrx:1 bioturb Sandstone -ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, CD1lI¡x>sed of 30-40% qtz grs, 30-40% lith frags (caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, nrx:1 bioturb Sandstone - 1tgy, vfgr, very well srtd, ang-sbId, calc cmt, sl fri-fri, oom¡x>sed of 30-40% qtz grs, 30-40% lith frags (caxb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, nrx:1 bioturb 69B 3433.7 Sandstone - 1tgy, vfgr, very well srtd, ang-sbrd, sl calc crcrt, sl fri-fri, c:omp::>sed of 30-40% qtz grs, 30-40% lith frags(caxb and mica), 20-30% arg-slty mtrx, tr-1% magnetite, grdg to vsdy sltst, abnt bioturb 70A 3434.2 Sandstone - 1tgy, vfgr, very well srtd, ang-sbId, calc cmt, sl fri-fri, comp:>sed of 30-40% qtz grs, 30-40% lith frags (carb and mica), 20-30% arg-s1ty mtrx, tr-l% magnetite, grdg to vsdy sltst, abnt bioturb --- ..... - 70B 3434.7 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, oomp:>sed of 30-40% qtz grs, 30-40% lith frags (carb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, grdg to vsdy sltst, abnt bioturb 7lA 3435.2 Sandstone - 1tgy, vfgr, very well srtd, ang-sbId, calc cmt, sl fri-fri, c:omp:>sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg- slty mtrx, tr-l% magnetite, grdg to vsdy sltst, mnr bioturb - 71B 3435.7 sandstone - Itgy, vfgr, very well srtd, ang-sbrd, calc c:mt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-s1ty mtrx, tr-l% magnetite, gràg to vsdy sltst, abnt bioturb 72A 3436.3 sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, abnt bioturb 72B 3436.7 Sandstone - Itgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, comp::>sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-slty mtrx, tr-1 % magnetite, abnt bioturb 73A 3437.2 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-slty mtrx, tr-l% magnetite, fgr sdy lam, abnt bioturb - 73B 3437.7 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, calc cmt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-s1ty mtrx, tr-1% magnetite, fgr sdy lam, abnt bioturb ..-J 74A 3438.3 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, sl fri-fri, comfXJSed of 30-40% lith frags (carb and mica), 20-30% arg-slty mtrx, l:r:g bivalve fos, nrxI bioturb 74B 3438.7 Sandstone - 1tgy, vfgr, very well srtd, ang-sbrd, sl calc cmt, sl fri-fri, comp?Sed of 30-40% lith frags (carb and mica), 20-30% arg-slty mtrx, Irrxi bioturb 75A 3439.2 siltstone - ltgy, varg, 1-3% vfgr sd, sl calc cmt, nrxI cons, 2-3% carb frags, 3% pyr b1ebs, 1% mica, vfgr sdy b.Jrs, pyr b.Jrs 75B 3439.6 sandstone - ltgy, vfgr, very well srtd, ang-sbrd, sl calc cmt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags(carb and mica), 20-30% arg-s1ty mtrx, nrxI bioturb 77A 3441.2 Sandstone - ltgy, vfgr, very well srtd, ang-sbrd, sl calc cmt, sl fri-fri, comp?Sed of 30-40% qtz grs, 30-40% lith frags (carb and mica), 20-30% arg-slty mtrx, abnt bioturb - 77B 3441.7 Sandstone - Itgy, vf-o;¡r, p:::>orly srtd, ang-sbrd, sl calc cmt, sl fri, com[X>Sed of 20-30% qtz grs, 30-40% lith frags, 30-40% arg-s1ty mtrx, arg lam - 78A 3442.2 siltstone - 1tgy, varg, 3-5% vfgr sd, sl calc c:mt, nrxI cons, 1-2% carb frags, 1% mica, grdg to IIdst, Irrxi bioturb 79A 3443.2 siltstone - ltgy, varg, 1-3% vfgr sd, sl calc cmt, Irrxi cons, 1-2% carb frags, - 3% magnetite, 1% mica, grdg to Irdst, tr bioturb 79B 3443.7 siltstone - Itgy, varg, 1-3% vfgr sd, sl calc cmt, nrxI cons, 1-2% carb frags, 3% magnetite, 1% mica, grog to Irdst, tr bioturb 80A 3444.2 siltstone - ltgy, varg, 1-3% vfgr sd, sl calc cmt, nrxI cons, 1-2% carb frags, 1% magnetite, 1% mica, grdg to Irdst, tr bioturb 80B 3444.7 ~ 8lA 3445.2 8lE 3445.7 -- 82A 3446.2 82B 3446.7 - 83A 3447.2 83B 3447.7 -- 84A 3448.2 siltstone - ltgy, vaxg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 3% magnetite, 1% mica, grog to ICdst, tr bioturb siltstone - Itgy, vaxg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 3% magnetite, 1% mica, grog to IIrlst, tr bioturb siltstone - 1tgy, varg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 3% magnetite, 1% mica, grog to ICdst, 120 bioturb siltstone - 1tgy, varg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 3% magnetite, 1% mica, grog to IIrlst, mnr vfgr sdy bur siltstone - ltgy, varg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 1% magnetite, 1% mica, grog to ICdst, 120 bioturb siltstone - ltgy, vaxg, 1-3% vfgr sd, sl calc cmt, rrr::rl cons, 1-2% carb frags, 1% magnetite, 1% mica, grog to ICdst, 120 bioturb siltstone - ltgy, pred axg, sl calc cmt, 1lOO cons, 1% carb frags, mnr slty lams, gro to c1yst siltstone - ltgy, vaxg, sl calc cmt, Irr:xi cons, 1-2% carb frags, tr magnetite, mnr bioturb, gro to IIrlst 84B 3448.7 sil tstone - 1 tgy, va:rg , sl calc cmt, 1rr:xi cons, 1-2% carb frags, mnr bioturb, gro to IIrlst 85A 3449.2 siltstone - 1tgy, varg, sl calc cmt, 1rr:xi cons, 1-2% carb frags, mnr bioturb, gro to IIrlst 85B 3449.7 siltstone - 1 tgy, vaxg, sl calc cmt, 1rr:xi cons, 1-2% carb frags, grd to ICdst 86A 3450.2 siltstone - ltgy, vsdy, sd is vfgr-va;¡r dkgy lith frags, 20-30% sd, sl calc cmt, 1CDd cons, 1% carb frags, tr mica, 3-5% magnetite - many of the magnetite grs are f-cgr, smpl grog to vndy-s1ty ss 86B 3450.7 Sandstone - 1t-dkgy, vf-vcgr, fXXJI'ly srtd, ang-sbrd, non calc, sl fri-fri, comp:>sed of 10-15% qtz grs, 40-50% dk lith frags(including 5% magnetite), and 30-40% axg-s1ty mtrx - 87A 3451.2 Sandstone - 1t-dkgy, vf-vcgr, ¡;;oorly srtd, ang-sbrd, non calc, sl fri-fri, comp:>sed of 10-15% qtz grs, 40-50% dk lith frags(inc1uding 5% magnetite), and 30-40% axg-slty mtrx, mnr slty lam 87B 3451.8 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oomp:>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-slty mtrx, cross laminated - 88A 3452.1 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, composed of 30-40% qtz grs, 40-50% lit:.h frags (carb and mica, tr magnetite), 10-20% axg-slty mtrx, tr lrg bivalve fos 1- 1 88B 3452.7 ,- j 89B 3453.7 t- , 1- 90A 3454.2 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, C0111fDSBd of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite) , 10-20% axg-slty mtrx Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt' cx:>mp::>sed of 30-40% qtz grs, 40% lith frags (carb and mica, tr magnetite), 20- 30% axg-s1ty mtrx, axg 1æns, abnt bioturb Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt' cx:>mp::>sed of 30-40% qtz grs, 40% lith frags (carb and mica, tr magnetite), 20- 30% axg-slty mtrx, mnr bioturb 1_ 1 ~~ 90B 3454.7 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oomp::>sed of 30-40% qtz grs, 40% lith frags (carb and mica, tr magnetite), 20- 30% axg-s1ty mtrx, mnr bioturb 91A 3455.2 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oomp::>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-s1ty mtrx, no bioturb l--" 91B 3455.8 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oom¡:osed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-slty mtrx, tr bioturb 92A 3456.2 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, l~ cx:>mp:>sed of 30-40% qtz grs, 40-50% lith frags(carb and mica, tr magnetite), 10-20% axg-slty mtrx, tr bioturb, lrg bivalve fos 92B 3456.7 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oomp::>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-slty mtrx, no bioturb - 93A 3457.2 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, cx:>mp::>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite) , 10-20% axg-s1ty mtrx, no bioturb 93B 3457.8 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, comp::>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-s1ty mtrx, no bioturb - 94A 3458.2 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, cx:>mp:>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-s1ty mtrx, no bioturb - 94B 3458.7 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, cx:>mp:>sed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-s1ty mtrx, no bioturb 95A 3459.8 Sandstone - rrqy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, oom¡:osed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite), 10-20% axg-slty mtrx, no bioturb 95B 3459.8 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, C01lIfX>Sed of 30-40% qtz grs, 40-50% lith frags(carb and mica, tr magnetite), 10-20% a:cg-s1ty mtrx, no bioturb ...... 96A 3460.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, fri, none-tr calc cmt, comfOSed of 30-40% qtz grs, 40-50% lith frags (carb and mica, tr magnetite) , 10-20% a:cg-s1ty mtrx, no bioturb .... 96B 3460.7 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well roIlS, hd, romJ.X>Sed of 50-60% qtz grs, 20-30% lith frags, 10-20% arg-slty mtrx, grdg to sdy 1s, no bioturb 97A 3461.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well cons, hd, COIlIfOSed of 50-60% qtz grs, 20-30% lith frags, 10-20% arg-s1ty mtrx, grdg to sdy 1s, no bioturb -- 97B 3461.7 Sandstone - rrr;¡y, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well roIlS, hd, com].X>Sed of 50-60% qtz grs, 20-30% lith frags, 10-20% arg-s1ty mtrx, grdg to sdy Is, no bioturb ---" 98A 3462.2 Sandstone - rrr;¡y, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well roIlS, hd, C01lIfX>Sed of 50-60% qtz grs, 20-30% lith frags, 10-20% a:cg-s1ty mtrx, grdg to sdy 1s, no bioturb 98B 3462.7 Sandstone - ra;¡y, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well roIlS, hd, rom].X>Sed of 50-60% qtz grs, 20-30% lith frags, 10-20% a:cg-slty mtrx, grdg to sdy Is, no bioturb 99A 3463.2 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, fri, calc cmt, well roIlS, hd, C01lIfX>Sed of 50-60% qtz grs, 20-30% lith frags, 10-20% arg-slty mtrx, grdg to sdy 1s, no bioturb 100A 3464.3 - 100B 3464.6 10lB 3465.7 - Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, rom].X>Sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, ~1% magnetite), 15-25% a:cg-s1ty mtrx, a:cg lams, IlDd bioturb siltstone - It olv gy, 20% vfgr, well srtd, sbrd, fri, bdd ss, sltst is pred a:cg, calc cmt, IlDd-wel1 roIlS, mnr carb frags Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, comfOSed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, ~1% magnetite), 5-15% a:cg-sl ty mtrx - 102A 3466.3 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc cmt, vfri-unroIlS, romp:>sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, ~ 1% magnetite), 5-15% a:cg-s1 ty mtrx 102B 3466.7 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc cmt, vfri, com].X>Sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% a:cg-sl ty mtrx 103A 3467.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc cmt, vfri, comfOSed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% a:cg-s1ty mtrx 104A 3468.2 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc c:mt, vfri-unoons, CX)1lIp::>sed of 40-50% qtz grs, 30-40% lith frags (carb frags, mica, tr-1 % m:¡gnetite), 5-15% arg-slty mtrx 104B 3468.8 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc c:mt, vfri, oomp::>sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% arg-s1ty mtrx 105A 3469.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc c:mt, vfri, CX)1lIp::>sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% arg-s1ty mtrx 105B 3469.6 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc c:mt, vfri, cx:>mp:>sed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% arg-s1ty mtrx 106A 3470.1 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc c:mt, fri, oomfOSed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-l% magnetite), 5-15% arg-slty mtrx ,~ 106B 3470.5 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc c:mt, fri, CX)1lIfXJSed of 40-50% qtz grs, 30-40% lith frags(carb frags, mica, tr-1% magnetite), 5-15% arg-slty mtrx 107A 3471.4 Siltstone - 1tgy, pred arg, tr vfgr sd, sl calc c:mt, m:xi oons, mnr sdy lams 107B 3471.7 Sandstone - 1t gy, smp1 is 40% 1tgy, sl calc, carb, mica, sltst, ss is vfgr, very well srtd, ang-sbrà, sl calc cmt, sl fri, cx:>mp::>sed of 50-60% qtz, 30-40% lith frags (carb frags, mica, tr-l% magnetite), 10-20% arg-slty mtrx, nrxi bioturb 108A 3472.2 Sandstone - olv gy, smpl is 30-40% sltst, ltgy, varg, sl calc cmt, abnt bioturb and 60-70% vfgr, well srtd, ang-sbrd, fri, cx:>mp::>sed pred of qtz and lith frags, sub borz frac 108B 3472.7 Sandstone - 1t gy, smpl is 60% sltst, Itgy, varg, sl calc c:mt, m:xi oons, 1-2% carb frags, 1% mica, abnt bioturb in sltst, and 40% vfgr ss, very well srtd, ang-sbrd, sl calc cmt' sl fri, pred qtz grs, and lith frags, ss has slty ra:;¡y t1m lams - 109A 3473.3 Sandstone - 1t gy, vfgr, very well srtd, ang-sbrd, sl calc c:mt, sl fri, CX)1lIfXJSed of 40-50% qtz grs, 30-40% lith frags (carb frags, mica, tr magnetite), 20-30% arg-slty mtrx, nrxi bioturb arg lams 109B 3473.7 Sandstone - 1t gy, vfgr, very well srtd, ang-sbrd, sl calc c:mt, sl fri, oomp::>sed of 40-50% qtz grs, 30-40% lith frags (carb frags, mica, tr magnetite), 20-30% arg-slty mtrx, abnt bioturb arg lams, 1% bivalve fos. 110A 3474.2 siltstone - 1t gy, arg, 5-7% vfg sd, sl calc c:mt, m:xi oons-sl fri, 1-2% carb frags, 1-2% mica, vfgr sdy blrs, abnt bioturb 110B 3474.7 Sandstone - 1t gy, vfgr, very well srtd, ang-sbrà, sl calc cmt, sl fri, cx:>mfOSed of 40-50% qtz grs, 30-40% lith frags (carb frags, mica, tr magnetite), 20-30% arg-slty mtrx, abnt bioturb arg lams 1_ " j lllA 3475.3 siltstone - It gy, axg, 1-3% vfg sd, sl calc cmt, 1lDd cons-s1 fri, 1-2% carb frags, 1-2% mica, tr vfgr say burs, abnt bioturb 11lB 3475.6 siltstone - ltgy, smp1 is 80% sltst, 1tgy, v axg, sl calc cmt, 1lDd cons-s1 fri, 1-2% carb frags, 1-2% mica, sltst-ss contact is bioturb, 20% vfgr ss, very well srtd, ang-sbrd, tr calc cmt, fri, comp::>sed pred of qtz grns and lith frags ~- l12A 3476.2 siltstone - 1tgy, v axg, 1% vfgr sd, sl calc cmt, 1lDd cons-sl fri, t-l% carb L frags, 1-2% mica, 3% magnetite, magnetite appears to fill a burrcw l12B 3476.8 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, none-tr calc cmt, uncons-vfri, com¡;;osed of 50-60% qtz grs, 20-30% lith frags (carb frags, mica, tr-l% magnetite), 5-15% axg-s1ty mtrx, 2-3% bivalve fos l13A 3477.2 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, comp::>sed of 50-60% qtz grs, 20-30% lith frags(carb frag5, mica, tr-1% magnetite), 10-20% axg-slty mtrx L '--- l13B 3477.8 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, com¡;;osed of 50-60% qtz grs, 20-30% lith frags(carb frags, mica, tr-l% magnetite), 10-20% axg-s1ty mtrx 114A 3478.2 sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, fri, com¡;;osed of 50-60% qtz grs, 20-30% lith frags(carb frags, mica, tr-l% magnetite), 10-20% axg-s1ty mtrx 114B 3478.7 sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, fri, comp::>sed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-s1 ty mtrx 115A 3479.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, fri, com¡;x:>sed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-s1ty mtrx 115B 3479.6 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, com¡;;osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-1% magnetite), 5-15% axg-sl ty mtrx 116A 3480.3 sandstone - 1t olv gy, vfgr, very well 5rtd, ang-sbrd, 51 calc cmt, fri, com¡;;osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% arg-s1 ty mtrx 116B 3480.8 sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, fri, com¡;;osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-slty mtrx - 117A 3481.2 sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, com¡;;osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-sl ty mtrx 117B 3481.7 sandstone - 1t olv gy, vfgr, very well 5rtd, ang-sbrd, sl calc cmt, fri, comp:>sed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-slty mtrx, dk v t:.hn x-lams - L. 1.- 118B 3482.7 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, oom¡x>sed of 60-70% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 5-15% arg-slty mtrx, IIrX1 bioturb, arg læns .1- 119A 3483.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, romp:>sed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr--l% magnetite), 5-15% arg-sl ty mtrx, arg 1æns 119B 3483.7 sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, v fri, oomp::>sed of 60-70% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 5-15% arg-slty mtrx, mnr dk thn,læns .L.. .1- 120A 3484.1 -L 120B 3484.7 .L l21A 3485.2 ..L 12lB 3485.8 ...1- 122A 3486.4 .-l sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, 51 calc cmt, v fri, CXJInp::>sed of 50-60% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 15-30% arg-s1ty mtrx, IIrX1 bioturb, arg lams sandstone - 1t olv gy, vfgr, very well srtd, ang-5brd, sl calc cmt, fri, oomp:>sed of 60-70% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 5-15% arg-s1 ty mtrx, arg lams Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, CXJInp::>sed of 60-70% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 5-15% arg-sl ty mtrx, arg lams Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc cmt, fri, oomp::>sed of 60-70% qtz grs, 10-20% lith frags(ca.rb frags, mica, tr--l% magnetite), 5-15% arg-slty mtrx, abnt dk v thn lams Sandstone - 1t olv gy, vfgr, grdg to v say ICdst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd rons, oomp::>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr--l% magnetite), 15-30% arg-s1ty mtrx, IIrX1 bioturb, arg lams 122B 3486.7 Sandstone - It olv gy, vfgr, grdg to v say Jrdst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd rons, oomp::>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-s1ty mtrx, IfDd bioturb, arg lams 123A 3487.2 Sandstone - 1t olv gy, vfgr, grdg to v say ICdst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd rons, oom¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-s1ty mtrx, IfDd bioturb, arg lams -- - 123B 3487.7 Sandstone - It olv gy, vfgr, grdg to v say IIrlst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd rons, romp::>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr--l% magnetite), 15-30% arg-slty mtrx, IIrX1 bioturb, arg lams 124A 3488.2 Sandstone - It olv gy, vfgr, grdg to v say ICdst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd rons, CXJInp::>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-s1ty mtrx, IfDd bioturb, BIg lams 124B 3488.7 Sandstone - 1t olv gy, vfgr, grdg to v say ICdst, very well srtd, ang-sbrd, sl calc cmt, sl fri-IfDd cons, com¡;r>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-s1ty mtrx, IfDd bioturb, arg lams - , -'-- 125A 3489.2 Sandstone - It olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, rrrx:1 bioturb, axg lams 125B 3489.8 Sandstone - 1t olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, comp:>sed of 50-60% qtz grs, 10-20% lith frags (carb frags, mica, tr-l% magnetite), 15-30% axg-slty mtrx, rrrx:1 bioturb, axg lams 126A 3490.3 Sandstone - It olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, rrrx:1 bioturb, axg lams - - 126B 3490.8 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc c:rcrt, fri, com¡;osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 5-15% axg-s1ty mtrx, abnt ðk v tbn lams 127A 3491.2 Sandstone - 1t olv gy, vfgr, very well srtd, ang-sbrd, sl calc c:rcrt, fri, comp:>sed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-1% magnetite), 5-15% axg-slty mtrx, axg lams 127B 3491.7 Sandstone - It olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-IOCJd cons, comp::>sed of 50-60% qtz grs, 10-20% lith frags (carb frags, mica, tr-l% magnetite), 15-30% axg-slty mtrx, rrrx:1 bioturb, axg lams 128A 3492.1 Sandstone - 1t olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, abnt bioturb, arg lams 128B 3492.7 Sandstone - It olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-rrrx:1 cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, abnt bioturb, axg lams 129A 3493.1 Sandstone - 1t olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, abnt bioturb, axg lams 129B 3493.7 Sandstone - 1t olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, comp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, rrrx:1 bioturb, axg lams 130A 3494.2 Sandstone - 1t olv gy, vfgr, grdg to v sdy rrdst, very well srtd, ang-sbrà, sl œ.1c c:rcrt, sl fri-1OCrl cons, comp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, rrrx:1 bioturb, axg lams 130B 3494.6 sandstone - lt olv gy, vfgr, grog to v sdy rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, com¡;osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% axg-s1ty mtrx, abnt bioturb, axg lams - 13lA 3495.2 Sandstone - 1t olv gy, vfgr, grdg to v say rrdst, very well srtd, ang-sbrd, sl œ.1c c:rcrt, sl fri-1OCrl cons, comp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-1% magnetite), 15-30% arg-s1ty mtrx, rrrx:1 bioturb, arg lams 131B 3495.7 Sandstone - It olv gy, vfgr, grdg to v sdy lldst, very well srtd, ang-sbrà, sl calc c:mt, sl fri-IOCJd cons, c:omp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% nagnetite), 15-30% arg-s1t;y mtrx, abnt bioturb, arg lams 132A 3496.2 sandstone - 1t olv gy, vfgr, grdg to v sdy ndst, very well srtd, ang-sbrd, sl calc c:mt, sl fri-IOCJd cons, c:omp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-slt;y mtrx, abnt bioturb, arg lams 132B 3496.7 Sandstone - It olv gy, vfgr, very well srtd, ang-sbrd, sl calc c:mt, fri, c:om¡:osed of 60-70% qtz grs, 10-20% lith frags(carb frags, mica, tr-1% magnetite), 5-15% arg-slt;y mtrx, arg lams 133A 3497.2 Sandstone - 1t olv gy, vfgr, grdg to v sdy ndst, very well srtd, ang-sbrd, sl calc c:mt, sl fri-IOCJd cons, c:omp:>sed of 50-60% qtz grs, 10-20% lith frags (carb frags, mica, tr-1% magnetite), 15-30% arg-slt;y mtrx, 1lDd bioturb, arg lams - - 133B 3497.8 Sandstone - 1t olv gy, vfgr, grdg to v sdy ndst, very well srtd, ang-sbrà, sl calc c:mt, sl fri-IOCJd cons, c:om¡:osed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-l% magnetite), 15-30% arg-slt;y mtrx, abnt bioturb, arg lams 134A 3498.2 siltstone - It gy, arg, 10-20% vfg sd, sl calc c:mt, IOCJd cons-sl fri, 1-2% carb frags, 1-2% mica, vfgr sdy bJrs, IOCJd bioturb l34B 3498.7 Sandstone - It olv gy, vfgr, grdg to v sdy ndst, very well srtd, ang-sbrd, sl calc c:mt, sl fri-IOCJd cons, c:omp:>sed of 50-60% qtz grs, 10-20% lith frags(carb frags, mica, tr-1% magnetite), 15-30% arg-slt;y mtrx, abnt bioturb, arg lams - 135A 3499.2 135B 3499.7 - 136A 3500.2 136B 3500.6 137A 3501.3 - 137B 3501.5 siltstone - It gy, arg, 5-7% vfg sd, sl calc c:mt, m:Xl cons-s1 fri, 1-2% carb frags, 1-2% mica, vfgr sdy bJrs, abnt bioturb siltstone - 1t gy, arg, 10-20% vfg sd, sl calc cmt, IOCJd cons-s1 fri, 1-2% carb frags, 1-2% mica, vfgr sdy bJrs, IOCJd bioturb siltstone - It gy, arg, 10-20% vfg sd, sl calc c:mt, IOCJd cons-sl fri, 1-2% carb frags, 1-2% mica, vfgr say bJrs, IOCJd bioturb siltstone - 1t gy, arg, 10-20% vfg sd, sl calc cmt, IOCJd cons-s1 fri, 1-2% carb frags, 1-2% mica, vfgr sdy bJrs, IOCJd bioturb siltstone - It gy, arg, 10-20% vfg sd, sl calc c:mt, IOCJd cons-sl fri, 1-2% carb frags, 1-2% mica, vfgr sdy bJrs, IOCJd bioturb siltstone - It gy, arg, 20-25% vfg sd, grdg to ndy-s1t;y ss, sl calc cmt, m::x! c:ons-sl fri, 1-2% carb frags, 1-2% mica, vfgr say bJrs, IOCJd bioturb --- ..l.. - -- Catscan Time Log and Core Inventory .....l J - - ",- . ÞRD A"IJB.ZA, oc. mIE :~ F.IIE : IP-3-1l88 ¡ FRJ 1t3K-9 R:1MŒKN : wm' SAK 1!NMì'S1B : 'IIS,RI:: MJ9RIK FIElD IHG FID : aM IAH:H'm:Rl : 1!NHI?lŒ: " - N:RIH SInE, AIlS.(A :ro:::rœKN : TI.:NiŒ-Se:!35 API : 5J-a292-1656-00 , - ~ 'mE KG IN) am mJENltR{ IE?lH IE?lH ~ ~ 'mE (3) 'lUE Willsite (1) an-a:ml (2) IBt:e start Etrl (ai: of ft.æær) CI:œ 1t1 1 ~336B ~336B 10-1&86 3:15 3:32 :23 ,- 2 3368-3371 3368-3371 3:32 3:48 :36 3 3371-3374 3371-3374 3:48 4:æ :31 4 3-:574-3TT7 3374-3TT7 4:æ 4:24 :36 5 3TT7-3380 3TT7-3380 4:24 4:43 :40 6 3300-3383 3300-3383 4:43 5:00 :44 7 3383-3385.7 3383-3385.7 5:00 5:35 :52 8 Fbil. 3385.7-3386.7 3385.7-3386.7 N:S 'It±al 0Jt (I):ille.rs D:¡:th3) : 3365.0 - 3388.0 (23.0 ft) 'It±al R:c:D.etB:l : 3365.0 - 3386.7 (21.7 ft) Cl:œ1t2 1 3387-3390 3387-3389.6 10-1&86 5:35 5::B :50 2 3390-3393 3389.6-3392.6 5::B 6:19 :44 3 3393-3396 3392.6-3395.6 6:19 6:38 :40 4 3396-3399 3395.6-33$.6 6:38 6:52 :33 5 3399-34a2 33$.6-3401.6 6:52 7:06 :28 6 3402-34C6 3401.6-3404.6 7:06 7:22 :30 7 34œ-34œ 3404.6-34a7 .6 7:22 7:42 :36 8 34æ-34ll 34Œ.6-341O.6 7:42 7::B :36 9 34ll-3413.0 3410.6-3412.2 7::B 8:12 :30 10 Fbil. 3413.-3413.8 3412.2-3413.0 N:S 'It±al 0Jt (I):ille.rs D:¡:th3) : 3388.0 - 3419.0 (31.0 ft) 'It±al R:c:D.etB:l : 3357.0 - 3413.0 (26.0 ft) CI:œ#3 'lttal Olt (I):ille.rs n:p:h;) : 3319.0 -3425.0 (6.0 ft) 'It±al R:c:D.etB:l : N:> R:a:M:!ly (0.0 ft) 1iRD liDSFA, llC. IID 1t3K-9 l FŒNU{ F.ŒID NIUH srŒE, ~ ImE : 19-ù1!N-87 RIMmrN : WÐI' SAK IKG FID : CDI :u::x:r:æJrN :~-93:!35 F.IIE : IP-3-1JB8 1\NMJlS1S : 'IIS,Iœ I.ÞB:HmRl : .ÞKH:.H'Œ: API : :0-0292-1656-00 ~ 'm£ Iæ 1N) am JNíÆNI(R{ - IEPlH IEPlH ~ <:m3JIN TJ:t.£ (3) 'Ilm Willsite (1) CtJ::ræbrl (2) D3te start Ehi (aJt: of fœ€eer) a:œ #4 - 1 3413-3413.3 3413-3413.3 10-1&-86 (4) 7:58 8:12 :30 2 3413.3-3416 3413.3-3416 8:12 8:33 :30 . (3413.3-3413.8) (3413.3-3413.8) :R:!ro.Ærlœt'i::œ !=;l ~in;J - 3 3416- 34J9 3416-34J9 8:33 8:47 :35 4 3419-3422 3419-3422 8:47 8:57 :2A , 5 3422-3425 3422-3425 8:57 9:00 :21 6 342'"r3428 342'"r3428.1 9:00 9:19 :22 7 3428-3431 3428.1-3431.1 9:19 9:31 :23 8 3431-3434 3431.1-3434.1 9:31 9:45 :26 9 3434-3437 3434.1-3437 9:45 10:01 :30 10 3437-3438.8 3437.1-3438.8 10:01 10:15 :30 II Fbi1 3438.8-3439.3 3438.8-3439.3 N:E 12 Fbi1 . 3439.3-3440 3439.3-3440 N:E 13 Fbi1 344(}-344O.5 344(}-344O.5 N:E 'lè:tal QJt (Jìilla:s D;p:ìs) : 3325.0 - 3444.0 (19.0 it) 'lè:tal ~ : 3413.0 - 3440.5 (Z7.5 it) a:œ #5 1 3439.5-3443 3440.5-3443.9 10-1&-86 10:15 10:32 :31 2 3443-3446 3443.~3446.9 10-19-æ 10:48 ll:œ :21 3 344&-3449 3446.~3449.9 ll:œ ll:15 :30 4 3449-3452 3449.~3452.9 10-1&-86 ~ 5 3452-34!D 3452.~34!D.9 lO-19-æ 2:a5 2:17 :18 - 6 34!D-3458 34!D.~3458.9 2:17 2:Z7 :25 7 3458-3461 3458.~3461.9 2:Z7 2:42 :25 8 3461-3464 3461.~3464.9 10-1&-86 ~ 9 3464-3467 3464.~3467.9 10-19-æ 2:42 3:00 :33 (3466.~ .0) (3467.4-fi7 .9) :R:IIDJerl J::efì:I::e !=;l ~irg 10 3467-3470 3467 .~3470.6 3:00 3:17 :35 12 Fbi1 3501-3501.45 3470.6-3471.3 N:E 13 Fbi1 3501.45-3:œ 3471.3-3472 N:E 'lè:tal QJt (Jìilla:s D;p:ìs) : 3444.0 - 3474.5 (30.5 it) 'Itt:al ~ : 3440.5 - 3472.0 (31.5 ft.) - ÞRD ÄUS!A, Il'C. IW 1t3K-9 .L FU9'RI< FIEID N:RIH SInE, AfN!J.{A mIE : J.9-lmN-e7 RRmXN : m3I' 8M< IRG FID : æ1: ra::mxN : '!1:NiŒ~ EIIE : JP-3-11B8 1\N!'\ll'SIB : 'IlS,KC IÞB:Hnœ'{ : ~ API : 50-0292-1656-00 - am:D\N'm£: ra:; iN) am INiÆNltR{ 'lUE ŒPJH Willsite (1) ŒPJH 0:ne:ta1 (2) JBt:e aas:rN aas:rN TJ}.£ (3) start: Eh:l (at: of fœæsr) - - <1:I:e~ 1 3471-3474 3472.0-3473.4 ID-:I9-a6 3:17 3:28 :28 2 3474-3477 3473.4-3476.4 3:28 3:45 :28 3 3477-3480 3476.4-3479.4 3:45 3:57 :29 4 3400-3483 3479.4-3482.4 3:57 4:12 :Z7 5 3483-3486 3482.4-3485.4 4:12 4:24 :Z7 6 3486-3489 3485.4-3488.5 4:24 4:37 :25 7 34æ-3492 3488.~3491.5 4:37 4:48 :24 8 3492-3495 3491.~3494.5 4:48 4:58 :21 9 ~3498 3494.~3497 .5 4:58 5:10 :22 10 34ær39)1 3497 .~3500. 75 5:10 5:21 :23 11 3501 -3501.45 3500.75-3501.2 N:B 12 3501.45-3!:m 39)1.2-39)1.7 N:B 'Ittal Cl.1t (I)::iJ..lers n:pìE) : 3474.5 - 35a5.0 (30.5 it) 'Ittal Iè::I:J..ered : 3472.0 - 39)1.7 (29.7 it) N::tæ - (1) ~ IIEIÐ.IIBi at æ1.lsite. (2) ~ IIEIÐ.IIBi at <1:I:e Ià::x::rc:tL.riæ, D'c., Þi~, A1æKa. (3) 'Ittal tùre tù:e \as at: of ftæ!ær tmilA'"' at :e:or.iŒrœ lbpital. 'DJ:e \as sta:e:l :in :irsi1.ate::1 a::rra:iœr dJJ::in;J 1:his tine. (4) 'DJ:e ufu:u:al!:Ù with tù:e #9 (<1:I:e:/t2) N:B - N:> Càt:s:Bn na:s.n:ena1: ¡:erfa:IlW. 8005 SCHOON ST., ANCHORAGE, ALASKA 99518 (907) 349·3541 CORE LABORA1OR'ES, tHe. . section C Appendices KRU #3K9 Kuparuk Field West Sak Formation North Slope, Alaska 19-Jan-87 .~ - ~ - SPE 15185 SPE Society of Petroleum Engineers - Automated Core Measurement System for Enhanced Core Data at Overburden Conditions - by O.K. Keelan, Core Laboratories Inc. SPE Member _ Copyright 1986. Society of Petroleum Engineers This paper was prepared lor presentallon at the Rocky Mountain Regional Meeling 01 the Society 01 Petroleum En9ineers held in Billings. MT. May 19-21. 1986. This paper was selected lor presental.on by an SPE Program Committee IoIlowing review of information contained in an abstract submitted by lhe aUlhor(s). Conlenls 01 lhe paper. as presented, have not been r8llÍ8W8d by the Society 01 Petroleum Engineers and 8re subjecllo con'ection by the aulhor{s). The malerial. as presented. does not necessarily rellect any position 01 the Society of Petroleum Engineers. its officers, or members. Papers presenled al SPE meetings are Subject 10 publication review by Editorial Committees of the Society of Petroleum Engineers. Permission to copy is restricted to an abstract 01 not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowfedgment of whe1e and by whom the paper is presented. Write Publications Manager. SPE, P.O. 80x 833836. Richardson, TX 75083-3836. Telex. 730989. SPEDAL ABSTRACT A nelol automated, computer-directed, core meas- urement system furnishes porosity, air permeability, equivalent non-reactive liquid permeability (Klinken- berg), and Forcheimer (turbulence) factor at program- mable, sequential overburden pressures from 500 to 10,000 psi. The system is accurate, precise, and flexible snd furnishes enhanced routine core data. Capabilities and limitations of the system are dis- cussed. Data are presented for selected rock types and a graphical technique is proposed to relate the system measured porosity and permeability values to uniaxial strain conditions. INTRODUCTION .... Formations deposited in ancient times were buried under successive layers of sediments, resulting in increasing depth of burial and subsequent compression of the rock pore spaces. Core cutting and retrieval relieves the reservoir formation pressure and removes the weight of the overburden deposits, allowing expan- sion of the core. Consequently, routinely measured porosity and permeability values are higher than those present in the reservoir. Adjustments to routine data have often been made by applying factors developed by simulating reservoir overburden stress conditions on representative but limited suites of cores from the formations of inter- est. Even then, air permeability data were often mea8ured at low mean preS8ure In the core sample, resulting in gas slippage and air permeability values that were higher than at reservoir pressures. Cor- rections for this slippage effect were often applIed by using published correlations for uniform sand- stones, and ignored in more heterogeneous carbonates where correlations were not valid. Lowpertll88bi1ity \ , References and illustrations st end of paper. 0;: formations have focused attention on the importance of both slippage correction.and overburden effects.l,2 The new automated, core measurement system offers a first-time capability to routinely and economically measure porosity and permeability at simulated over- burden stress conditions, while simultaneously meas- uring 'the gas slippage corrected equivalent liquid permèability as well as the Forcheimer turbulence factor required to predict flow in high-rate wells. When placed in the calibration mode,· .the system is self-calibrating with self-diagnosis of valve leak problems if present. Core sequencing and movement into a hydrostatic core holder, application of up to eight selected sequential overburden pressure meas- urements, interim data display while testing, calcu- lations and final data presentation are performed automatically while under IBM PC control. Pore volume is directly measured by helium injection into the pore space, while permeability and turbulence factor are determined during unstead~-state flow utilizing principles described by Jones. . REVIEW OF FACTORS LIMITING ROUTINE CORE DATA Gas Slippage Effects . Gas slippage effects were documented by Klinken- berg4, and the effect he observed is illustrated on Fig. 1. Unlike non-reactive liquid flolol, where permeability of a rock is a constant, gas perme- ability is seen to vary linearly with the reciprocal mean pressure in the core. Hean pressure Is defined as the average of the up-streaJII and down-stream pressure of the rock sample during flow. It is analogous to thefor.ation pressure. At increasing mean pressures the gasllOlecules are forced closer together such that. the gas becomes tIOre dense, behaves more like a liquid, and 'has slower measured penae~ ability. At infinite mean pres.ure, the reciprocal of Pme$n equals zero· and the gas is visualized as having condense.d and a. flowing like an equivalent inert liquid. . .. . , ." 2 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS Reservoir Turbulence (Kinetic) Effects SPE 15185 - Routine permeability data are measured using air at low mean pressure in the core sample. In contrast, gas reservoirs described as "low pressure" are at high enough mean pressure whereby the reservoir gas permeabi 11ty approaches the equivalent liquid perme- ability from laboratory tests. Results of steady- state flow measurements seen in Fig. 1 require deter- minations at several mean pressures and then extrapo- lation of the data to infinite mean pressure. These tests are time consuming and expensive and have not been routinely determined despite the more representa- tive reservoir permeability value resulting when the slip-corrected Klinkenberg value is used. - Klinkenberg also found that different gasses have different permeability at the same mean pressure but all extrapolate to the same equivalent liquid perme- ability. ""'This resulf~different~11Jpës of the gas permeab 11 i ty versus rec iprocal of mean pressure lines. This has importance in the automated core measurement system which utilizes helium as the flow- ing gas, and which determines both the slip-corrected permeability and a helium slippage factor (b) propor- tional to slope. The need exists to calculate an equivalent air permeability to serve as a common tie point to previously measured core data where nitrogen or air has been used as the flowing gas. This calcu- lation utilizes the helium determined (b) value, and adjusts it to arrive at a slippage factor of (b) for air. Air permeability at commonly used laboratory instrument mean pressure conditions is then calculated using the equation shown on Fig. 1. Overburden Effects - Increasing depth of burial results in increasing weight of overburden sediments tending to compress. the formation rock. An overburden gradient of 1 psi per foot of depth is commonly assumed, a1 though a bulk density log can be integrated to compute this overburden value.5,6 The difference between the over- burden pressure and the formation pressure increases with depth as i llus t ra ted on Fig. 2, and the dif- ference is commonly referred to as the effective or net overburden pressure (NOB). When formation pres- sure is unknown, it is often calculated by multiplying an assumed salt water gradient of approximately 0.5 psi per foot times the formation depth. The differ- ence of these gradients times depth yields the NOB. It is this NOB that primarily controls formation compaction stress, and it is this NOB that is relieved during the coring process and that is re-applied and simulated in the core measurement system. - - Re-application of net overburden pressures on core samples allows adjustment of routine non-stressed core porosity and permeability data to initial reser- voir net overburden conditions. It also allows both porosity and permeability reduction to be monitored as reservoir pressure declines with a resultant in- crease in net overburden. Normalized data illus- trating these changes in porosity and per~eability were generated from measurements on the core measure- ment system and are illustrated on Fig. 3. Great diversity is observed, and different formations exhib- it widely differing sensitivity to overburden stress. Estimates of reservoir flow can be made using Darcy equations and core permeabilities corrected for slippage, overburden and relative permeability effects. However, well test data and laboratory data show that above a critical rate Darcy's equation does not describe fluid or gas flow, but predicts higher flow rates than the wells can deliver. The lower flow rate of the well has been attributed to an effect referred to as turbulence, inertial, or kinetic energy losses. This effect has been studied by Forcheimer and others7, and it can be quantified by core measurements and included as an additional term in the Darcy equation. The turbulence factor has been used to describe ..-, pressure losses and to calculate maximum flow rate during non-Darcy turbulent flow into a well bore. It has been combined with flowing well analysis to predict the economic effects of perforating conditions as well as the number and size of perforations re- quired to maximize productiong. The effect of turbulence on flow is illustrated on Fig. 4 and the Darcy equation modified for tubu- lence is shown. The zero turbulence condition is illustrated by the straight line, where flow rate per uni t cross-sectional area increases in a linear fashion as the pressure drop per unit length in- creases. Above a critical rate the relationship is no longer linear, and an increase in pressure dif- ferential results in less flow than predicted by Darcy flow. The excess pressure drop is due to turbulent, non-laminar flow. and can be calculated by the product of the turbulence factor (Beta) times the density of the flowing fluid and the square of the velocity.9 Relative Permeability Effects Routine core analysis permeability data are gen- erated with a single non-reactive fluid (gas) in the pores of a cleaned and dried core. In the reser- voir both hydrocarbons and interstitial water are present. The water sometimes reacts with the rock, or occupies pore space such that it interferes with hydrocarbon flow, resulting in a lower reservoir permeability to the hydrocarbon than measured during routine core analysis on the clean and dry core. In many reservoirs of moderate permeability with no rock-water reaction and sufficient height above water to be at a minimum irreducible water, the intersti- tial water does not move and has a negligible effect on hydrocarbon permeability reduction. Routine core permeability data corrected for slippage will approxi- mate reservoir values in this case. In other situ- ations, water in the reservoir may reduce hydrocarbon permeability and dry core Klinkenberg data will be optimistically high. THE CORE MEASUREMENT SYSTEM The core measurement system routinely and rapidly overcomes all of the factors limiting conventional core data except for the relative permeability effects due to the presence of irreducible water. This can 156 +. SPE 15J85 Dare K. Keelan 3 also be addressed in the system with additional effort and is discussed under Core Saturation Condition that follows. Equipment Description - The system is packaged in a compact desk top, front loading chassis approximately 2S" wide by 30" high and 15" deep containing back plate connections for helium, nitrogen, vacuum, power and data communi- cations. Major components include (1) an eighteen- sample carousel core plug holder, (2) an automa tic load and unload system, (3) hydrostatic core holder and pressure application assembly, (4) helium volume reference cells and pressure sensing devices, and (5) computer hardware and software. - Equipment Operation -' The system is self-calibrating when the calibra- tion mode is specified, and utilizes stainless steel center-bored cylindrical standards of known pore vol- ume. It is also self-diagnostic, checking for proper valve operation and system leaks if present. Samples are manually loaded into individually numbered posi- tions within the carousel, which is then positioned in the chassis. Sample identification, length and area, for example, are requir~d input to the IBM PC, and grain volume, bulk volume and weight of the sample are optional. Up to eight overburden pres- sures can be designated, which may include both sequential increasing and then decreasing overburden values. - At test initiation, Position 1 of the carousel is automatically rotated into position, a vacuum is pulled on the rubber boot wi thin the core holder, and a vertically upward moving hydraulic ram advances and lifts the sample into the rubber boot. After sample insertion, the vacuum is released and the minimum programmed hydrostatic confining stress 1s applied to the core. A quick permeability approxima- tion measurement is then made for selection of both the upstream volume and pressure to be used during subsequent permeability measurements. . - - Pore volume is then determined by expansion of helium into the core sample from a known volume source at approximately 240 psi. At pressure equili- brium, Boyle's Law is used to compute pore volume. The difference between the confining stress and the equilibrium pore pressure is the net confining stress. During this operation the overburden and internal pore pressures are monitored with digital readout on the chassis, and by a real time visual display of the plot of pore pressure versus time. - Permeability is then measured by flowing helium from the previously selected volume reference cell at the selected pressure through the core. The downstream end of the core is maintained at atmos- pheric pressure. The upstream pressure decline is monitored in real time, and is observed by digital readout and visually displayed in either graphical or tabular form. The difference between the confin- ing stress and the mean pore pressure during flow is the net confining stress. Unsteady-state equations developed by Jones are used ~~ calculate the Klinkenberg slip corrected .' .. permeability, the helium slip factor, and the For- cheimer turbulence factor.3 Air permeability is then calculated as a base to be compared with other non- Klinkenberg measured core information from the field. The next pre-programmed overburden pressure is then applied to the sample and measurements are repeated. After the last permeability measurement is completed for Sample #1, the final selected overburden pressure is released, vacuum is appl ied to the rubber boot releasing the sample, and the core rides downward as the ram retrieves. Data are printed and stored on both hard And floppy disks. The carousel then rotates into the next position and the sequence is repeated until all samples are tested. Data can then be transferred to a central computer for statistical manipulation, graphical dis- play, and core analysis final report generation. CAPABILITIES AND LIMITATIONS Sample Sizes The current carousel will hold a maximum of lS one-inch diameter cylindrical plugs, 3/4 to 3 l/S inches in length. Since pore volume is by direct helium injection, sample ends must be essentially parallel, and data indicate well maintained normally used preparation equipment can furnish adequate sam- ples. Core should have square, not rounded, corners and be free of surface vugs and chipped edges. By mid-year,' sample-size capabilities will include 1 1/2 inch diameter cores, and a 100 sample holder for either diameter that can be substituted for the carousel. Stress Conditions The confining stress is applied hydrostatically (equal on all sides) and can vary from 500 to 10,000 psi. A maximum of eight stresses can be programmed, and increasing as well as decreasing stress can be simulated. The minimum confining stress to yield porosity and permeability data comparable to routine zero stress porosity and routine 400 psi stressed core for permeability measurements is apparently a function of the hardness of the rubber boot that surrounds the core. The boot should be soft enough to conform to sample sides at low confining stress. but hard enough so that it will not flow into pore space at high confining stress and fail to properly release the sample at test conclusion. The current boot material requires at least SOO psi confining stress to conform to the samples, but a new design currently under investigation appears promising in allowing the minimum stress to be reduced to 500 psi. Accuracy and Repeatability The system was designed to yield accurate and reproducible permeability values over a range of 0.01 millidarcies to 2 darc1es. Test data indicate pore volumes can be determined for a range of 0.02 cc to 10 cc. Tables 1, 2 and 3 and Figures 5, 6 and 7 furnish control data on both one inch diameter steel standards and core samples substantiating design specifications. Control data are commented on in Data and Discussion of Results. -' 4 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 15185 Sample Consolidation Host tests to date have been made on consol1dated cores. Limited data indicate Ithat unconsolidated rock mounted in shrinkab Ie tub ing 10 can be run in the device. Investigation of applicability to these type cores as well as metal jacketed samples is yet to be completed. Core Saturation Condition The system was designed to test clean, dry cores. Data indicate valid permeability at irreducible water (Swir) can be measured. Multiple cores should not be batch loaded as evaporation will occur while awaiting analysis, and immobile water is necessary to prevent water redistribution during gas flow and movement from the core. Total evaporation during analysis should be monitored by sample weights. Indicated hydrocarbon pore volume (l.O-Swir) reduction due to overburden will be invalid and masked if the volume seen by injected helium increases due to evaporation. DATA AND DISCUSSION OF RESULTS Accuracy and Repeatability of Steel Standards Each core measurement system is calibrated at 1500 psig confining stress utilizing stainless steel cylinders of known pore volume. Each is subsequently independently checked with a set of steel standards. Typical results of a pore volume accuracy and repeatability check are shown in Table 1. These tests were run overnight in a laboratory with no special temperature control. Maximum pore volume difference observed in 'the seql1ence vas 0.035 cc, which yields a maximum porosity error of 0.27 porosity points (i.e. 10.0 to 10.27 percent) for - a I-inch diameter plug 1 inch in length. This is well within the API RP 40 accepted accuracy of + 0.5 porosity point. II - Table 2 illustrates pore volume accuracy and consistency between variol1s systems checked with a set of common standards. These locations represent various elevations, barometric pressures and tempera- tures, and excellent agreement is seen in measured pore volumes. Permeability checks on steel standards are shown in Table 3. All fall within the + 5% industry stan- dard for plugs of moderate permeability and reproduci- bility is excellent. - Accuracy and Repeatability of Core Plug Standards Suites of cores tested with steady-state perme- ability techniques were used as standards in this evaluation. Air permeability was selected for com- parison as most historical data are in this form and routinely used permeameters develop these data. Mul- tiple measurements were made on carefully calibrated equipment and cross-checked between various instru- ments. to arrive at standard values. Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state air \ pet'1lleabllity measurements. The difference shown is expressed as a percentage of the steady-state value. Three measurements are presented for each sample to illustrate reproducibility. The data indicate three samples w1th a difference greater than 5% of the standard vallie. Two are lower permeability samples, of less than one millidarcy. The + 5% limit was set for higher permeability samples, ãnd the tolerance is normally expanded in the lower range becal1se of the small values measured and sensitivity to mean pressures in the core as permeability becomes lower. For example, if the true air permeability value is 0.020 millidarcies and the tested value found is 0.025, an error of 25% is indicated, although the ~ magnitude of the difference is inconsequential and the permeability in both cases is quite small. A much larger (100%) error results from the incorrect use of the air permeability value of 0.02 to repre- sent reservoir permeability rather than the slippage corrected Klinkenberg value of 0.01 determined for this plug. Figure 6 shows comparisons of zero stress meas- urements utilizing a small volume porosimeter ·(SVP) versus core measurement system porosity data at 800 psi confining stress. Porosity in the system has been calculated using various equations that require different basic data. The zero stress equation util- izes bulk volume determined by mercury displace- ment (BVHg) and grain volume (GV) measured in a U.S.B.M. modified Boyle's Law apparatus using helium as the gas. ø ~ B"Hg-G" BVHg x 100 ............(1) The core measurement system uses equations in decreas- ingorder of preference as shown belovo Pore volume (PV) is by direct injection, and bulk volume is determined by one of three techniques. ø .. PV Jt 100 PV-+<;V ...............(2) ø .. PV x 100 BVHg ............... .(3) ø .. PV x 100 LxA ................(4) In the Fig. 6 data set all porosities agree well with mean porosity differences from the zero stress condi- tion of -0.2, -0.2 and -0.3 porosity points respec- tively. Figure 7 presents individual sample porosity differences comparing values from Equations 2, 3 and 4 with Equation 1. Equation 2 allows for a decreasing bulk volume as confining stress increases. Equation 4 typically yields porosi ty values too low, as rounded corners or broken edges are often not properly accounted for in length (L) and diameter measurements used to com- pute area (A). This results in higher bulk volumes than true; hence, low porosities. Equations 3 and 4 can be modified as illustrated below to allow for decreasing bulk volume as confin- ing stress increases. 158 .~. ~ Sl'E 15J.85 Dare K. Keelan 5 ---"- o . PV BVHg-(PVi-PVn) ............(5) Where PVi . Pore volume in cc at minimum confining stress (800 psig) - PVn - Pore volume in cc at any succeeding stress Overburden Effects _1 Table 4 presents typical system data at various confining stresses on a low and moderate permeability sample. Measurements were made at two locations to evaluate consistency between instruments. Once again, repeatability is good, although Run 2 data indicate samples have not fully rebounded from stres- ses imposed several days earlier during Run 1. Po- rosity arid permeability decrease as expected, and these data indicate values of (b) related to slip- page are essentially independent of confining stress, whereas turbulence factors (Beta) tend to increase as confining stress increases. The Sample A Beta factor at 6000 psig stress decreased remarkably in Run I, and this anomalous behavior was seen again in a second instrument in Run 2. Reasons for this are unknown. ----' Figure 8 presents a typical porosity comparison between system measured porosity at various confining stresses with (1) a porosity generated at zero confin- ing stress and (2) with a helium injection technique commonly employed in Special Core Analysis laborator- ies. The zero confining stress measurement is des- cribed previously as Eq. 1. The "Pore Volume by Helium Injection" was determined with the core con- fined in a hydrostatic boot of lesser hardness than used in the system. Some initial porosity differ- ences between the three techniques is to be expected because some finite stress is required for the direct pore volume measurement techniques to conform the boot to the core exterior. The data indicate that 250 psig yields conform- ance in the softer rubber, while approxiœately 750 psig confining stress was required for the syštem to match the zero stress porosity. All measurements agree within an acceptable tolerance of 0.5 porosity points at the initial values reported, and the system and commonly used helium injection technique agree within acceptable limits throughout the overburden stress range investigated. INVESTIGATIONS IN PROGRESS Pore Volume Compressibility Investigation is ongoing to evaluate core surface conformance effects as the rubber boot surrounding the core is subjected to increased confining stress. This has importance in evaluation of both porosity reduction observed in the system. and pore volume compressibility calculated from system measured pore volumes. Initially the boot is held away frOAl the core surface by tops of grains and/or any high points present. As confining stress increases. the boot conforms more closely and flows into the indented spaces between adjacent sand grains. This translates into a differential pore volume reduction sensed by the s".t_ aa subsequently injected heliUIII sees a smaller volUlDe. While the pore volUllle is smaller. ,. t. the core may not have compressed at all, and the pore volume compressibility calculated from pore vol- ume reduction is erroneously h1.gh. When the boot material fills the surface indentions. subsequent increase in confining stress does compress the rock and result in actual pore volume compressibility. Samples prepared for constant temperature, pre- cise compressibility measurements are normally jack- eted with a heat shrinkable tubing that fills surface indentions so that no conformance problem exists, and early applied confining stresses see only sample~ compression. Figure 9 illustrates pore volume de- crease for a jacketed and non-jacketed core. The jacketed sample also contained water at the time of test. which sometimes softens the rock and yields greater and more representative pore volume compres- sihil1ty than a dry core. This sample was tested, while jacketed, in a hydrostatically stressed compres- sibility apparatus, and the jacket was removed prior to testing the sample in the system. Curve 1 is the first system compressive cycle, and greater pore volume reduction is seen at low net stress than observed on the jacketed core. This is believed due to the boot conformance previously discussed, even though this sample was relatively smooth. Curve 2 is the hysteresis curve, and at the minimum net confining stress of 400 psi obtained after the hysteresis loop, a lesser pore volume than initial is determined. thIs may gradually recover to initial value as a function of time, or may remain permanently reduced depending upon properties of the core and whether the elastic limit was exceeded. Examination of other data from this reservoir indi- cated an elastic limit of slightly greater than 4500 psi. and for this reason this test was not taken above 4000 psi confining stress. Curve 3 represents the second cOlllpressive cycle and Curve 4 Is the final hysteresis curve. Note that the slope of the pore volume curve is essentially the same for the jacketed and non-jacketed tests above a net stress of approximately 2000 psig. Although Cycle 3 is below Cycle I, pore volume compressibilities would be essentially the same at the higher pressures since the slope of the pore volume versus net confin- ing stress is similar. Figure 10 presents porosity as a function of net confining stress. Agreement is well within accepted tolerance for both tests over the range of stresses applied. Note that a net confining stress of approxi- mately 800 psi was required on the Curve 1 compres- sive cycle to yield the pore volume measured on the jacketed core at 200 psi net stress. These data indi- cate boot conformance was occurring in this sample until at least 1500 psi net stress, yet the conform- ance effect on porosity was negligible. Figure II illustrates the sensitivity of calcu- lated pore volume compressibility to initial boot conformance. The early systelD values do not appear to represent true pore volume compressibility. but conformance. While differences in compressibility at low confining stresses are significant. compressibil- ity is an instantaneous value calculated at a selec- ted net confining øtress. and there is no cumulative error. Values at net stresses above 2000 psi repre- sent reservoir conditions at the reservoir depth of burial and values are in reasonable agreement with " \ I 6 " AUTOMATED<CORE MEASUREKENT SYSTEK FOR.' ENHANCED ,CORE DATA AT OVERBURDEN CONDITIONS H,SPE lS18S<~~ ~'.. ~ .->- the jaQketed sample.. (i.e. system value ·of 7.4.x 10-6 versus 9.3 x 10-6 at 4000 psig and much better agreement at 2000 psi.) . The system can furn1sh large volumes of data rapidly which are likely to be much more representa- tive of a formation or its various rock types and lithologies than average correlations in the litera- ture. The data can and should be calibrated to more precise measurements by running a suite of water saturated jacketed cores in a compressibility appara- tus, and arriving at a confidence and adjustment factor to be applied to the system calculated pore volume compressibility values. Irreducible Water (Relative Permeability Effects) Table 5 is a subset of data to illustrate the effect of irreducible water (Swir) on the Klinkenberg permeability. The data are somewhat erratic due to the unusual relationship of porosity and permeability indicated, and Swir appears quite low for two of the three samples. These cores were reported to contain kaolinite and perhaps slight changes in loose particle location in the dry core contributed to these results. In any event, irreducible water saturation of· up to 22.9 percent pore volume had a negligible effect on gas flow in all core tested. This indicates the dry core Klinkenberg permeability would represent gas reservoir permeability in zones containing irreduci- ble water. The samples were then restored with oil and oil permeabilities' were. determined. Sample 3 yielded an 011 permeability equal in value to the Kl1nkenberg values found both on the dry core and the core con- taining irreducible water. The total data set indi- cated that in 40% of the samples tested, Ko at Swir equaled the dry core Klinkenberg value; cònversely, 60% of the samples gave poor comparison. The conclu- sion here is that validation of the Klinkenberg value at Swir as equal to the Ko at Swir must be done on an individual formation basis with independent oil permeability measurements. - Table 6 illustrates the effects of irreducible water on slippage factor and turbulence for the córe identified as Sample 3 in :rab Ie 5. The b value decreased in this and other cores tested in the presence of Swir, while turbulence factor (Beta) remained essentially constant. Conversion of Hydrostatic to Uniaxial Strain Data The core measurement system employs a hydrostatic load to simulate stresses of the rock at net overbur- den conditions. However, numerous authors have indi- cated that reservoir stresses are not hydrostatic. and the reservoir is free to compact in a vertical direction only, with no deformation laterally. This is referred to as uniaxial strain. Teeuw showed tha t uniaxial pore volume compres- sibility was approximately 62% of hydrostatic val- ues12. Anderson presented data comparing hydrostatic loading to uniaxial, and equations to transform hydro- static pore volume compressibility to uniaxial strain conditions13. It follows that a hydrostatic pore volume compression that is too high will result in . , \ ~.{.>¡~\', ':- ::::~i ~j,?:~,:~;:~:,),~-,~~: ;~'<,.:., -;' . a laboratory porosity reduction that ta too Mgh. , . Similar results have·bee~ reported forpermeab1l1ty14. If reservoir compression is only 62% of the laboratory value, then thè reduction in reservoir 'porosity should only be 62% of the measured hydrostatic laboratory value. Nelson concluded permeability could be derived from hydrostatic confining pressure tests by calcu- lating the mean stress in the reservoir and then reading the permeability value from the hydrostatic curve at the calculated mean subsurface stress15. Both porosity and permeability data from the core measurement system can be normalized by dividing each overburden value by the initial value at the minimum confining pressure. This type of data is illustrated on Fig. 12, and the curves allow'a quick approximation of uniaxial strain porosity and permea- bility. The approach illustrated employs the average correction factor of 0.62 proposed by Teeuw. The curves are entered at Point A, the calculated reservoir net overburden 'pressure computed 'as illus- trated in Fig. 2. The porosity "fraction of original" curve intercepted at Point B represents too great a reduction in porosity since porosity was measured under hydrostatic loading. This "fraction of origi- nal" value is adjusted upward using Teeuw's factor by multiplying 0.62 (1.0 - normalized 'porosity factor read at Point B) and - subtracting this product from 1.0. This adjusted value is plotted as Point C, which is the porosity "fraction of original" more representative of reservoir conditions, and which a'pproximates data that would have been measured had the core been tested in a uniaxial strain test. We then move from Point C horizontally to the 'left to intersect the hydrostatic curve. The net overburden pressure Point D corresponding to this intersection is the equivalent 'mean stress on the hydrostatic curve required to yield the reservoir uniaxial strain porosi ty. By moving vertically, we intersect the normalized permeability curve at Point E at the same mean stress. We can then move horizontally to the left to Point F which represents the factor for permeability adjustment. This factor times initial permeability yields the desired permeability value. Reliability of this approach for a particular formation would be improved by having uniaxial perme- ability and porosity measurements to compare with hydrostatic and to develop the actual correction factor for the formation. CONCLUSIONS 1. Klinkenberg corrected permeability. porosity, slippage factor (b) and turbulence factor (Beta) can be accurately and routinely determined in the core measurement system at overburden pres- sures. 2. Overburden pressure effects (including hystere- sis) can be easily studied by designating confin- ing stresses that are automatically applied from 500 to 10,000 psi, and differences in properties at overburden conditions from low stress measure- ments can be significant. 160 ","'. .. - - SPE l51.85 ",-".', Dare K. Keelan 7 3. Kl1nkenberg slippage factors (b) ~ere essentially the same or increased only slightly in the sand- stones tested as overburden pressure increased, and the presence of irreducible water resulted in a decrease in (b) value. 4. The turbulence factor (Beta) increased moderately in the sand stones tested as overburden pressure increased and the presence of i rreducib Ie water had little effect on its value. 5. A minimum confining stress of 800 psi is currently required for the system determined porosity and permeability to equal (1) porosity values at zero stress and (2) air permeability values at 400 psi confining stress now employed in routine core analysis. 6. Helium injection porosity measurement techniques routinely employed in Special Core Analysis labo- ratories yield porosity values in good agreement with those measured on the system. 7. Conformance of the rubber boot to the core sur- face had little adverse effect on system poros- ity values at pressures above 800 psi confining stress, and the jacketed and non-jacketed core yielded similar values of porosity throughout the range of overburden pressures investigated. 8. Pore volume compressibility of the non-jack- eted core was extremely sensitive to boot con- formance at confining stress below 2000 psi. Above this stress compressibilities approxi- mated true values. Compressibilities determined on non-jacketed dry core should be calibrated to best technique values by comparative measure- ments on jacketed, water saturated samples tested in a compressibility apparatus. - 9. Hydrostatically confined porosity and permeabil- ity determined at selected net overburden pres- sures and presented as a fraction of original values allows approximation of both poro8i~y and permeability at uniaxial strain conditions. Note: This is likely to be restricted to well- cemented cores whose behavior follows elastic theory. 10. The system can be used to measure Klinkenberg gas permeablity with irreducible water in the core, and thereby verify whether dry core slippage corrected permeability at confining stress is representative of gas flow with connate water present. 11. Applicability of the system Klinkenberg gas perme- ability (with or without irreducible water pre- sent) to represent oil permeability (Ko) with irreducible water present must be verified by independent measurements of Ko. NOMENCLATURE k - permeability, md KA - permeability to air, md Kœ - Klinkenberg "Liquid" permeability, md b -. Klinkenberg slippage factor, psi ~ . Pmean - arithmetic average pressure in core, psia p - pressure, psia L = length of flow path, ft V = velocity, ft/sec B Beta = turbulence factor, ft-1 ~ gas viscosity. cp P = density of fluid, Ib mass/cu ft ACKNOWLEDGMENTS The author gratefully acknowledges the cant r1- bution of Brian Davis and Lisa Curry and those who developed and implemented the theory resulting in the automated core measurement system. REFERENCES 1. Thomas, R. D. and Ward, D. C.: "Effect of Over- burden Pressure and Water on Gas Permeability of Tight Sandstone Cores," J. Pet. Tech. (Feb. 1972) 120-124. 2. Jones, F. O. and Owens, W. W.: "A Laboratory Study of Low Permeab ility Gas Sands," AIME-SPE 7551 (May, 1979) Denver Low Permeability Gas Reservoir Symposium. 3. Jones, S. C.: "A Rapid Accurate Unsteady-State Kl1nkenberg Permeameter," Soc. Pet. Eng. J. (Oc t. , 1972) 383-397. 4. Kllnkenberg, L. J.: "The Permeability of Porous Media to Liquids and Gases," Drill. and Prod. Prac., API (1941) 200. 5. Christman, Stan A.: "Offshore Fracture Gradients," Soc. Pet. Eng. J. (Aug., 1973) 910-914. 6. Breckels, J. M. and Van Eekelen, H. A. 11.: "Rela- tionship Between Horizontal Stress and Depth in Sedimentary Basins,fl paper SPE 10336 presented at 56th Annual Fall Tech. Conf. and Exhibition, San Antonio, Texas, October 5-7, 1981. 7. Tek, M. R., Coats, K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Gas Through Porous Reservoirs," J. Pet. Tech. (July, 1962) 799-806. 8. McLeod, H. 0.: "The Effect of Perforating Condi- tions on Well Performance," J. Pet. Tech. (Jan., 1983) 31-39. 9. Cornell, D. and Katz, Through Porous Media," 45. 2145. D. L.: .. Flow of Gases Ind. Eng. Chern.. (1953) 10. Griffin, T. J. and Bush, D. C., "Core Analysis in Unconsolidated Reservoirs Using an Improved Consolidation Technique," 36th Annual l1eeting of Petroleum Society of CIM, Edmonton. Alta.. Paper No. 85-36-41, June 1985. 11. API-RP 40: Recommended Practice for Core Analysis Procedures, American Petroleum Institute, Dallas. 12. Teeuw, D.: "predictions of Formation Co1Dpaction from Laboratory Compressibility Data," Soc. Pet. Bng. J. (1971) II, 263-271. : .~. ':.; ,- ".' ,:' a:/ : otf":.j· 4 , :" spa '1518i~ ; " '" r~~t.'! "''':Æ.:7,Y ;'ir,j\~t01{rt .' .;:.ê_~':'tÓ'~'f'V: :.~f~tJ:~t::r:~ "': ":.:":::~- ~.:: :. , ")'<:~t,,,:, '. ·~:/"t ',' ."".. "~ 8 :',¡".'::<;~*~~~j.~.¡;";".f;AUTCÍKÁTED CORE MEASUÌF.KBNT:"SYSTEK,E.ÓR',.ENHANCED;CORE DATA AT OVIÎBURDBH ·CONDITIONS . ·,:·,··,,·....·..··r,·.~··· .~,.: ~'. , .\.- 13. ~.raen. ¡~.A.: ',"Predicting R..~~.'(91r:Çoq41t1on PotrVoluaieCOmp~e8s1b 11i ty , "frOll'i:iJlydro. ta t1c- Strè..LaboratorYData" paper,SP!;l~~U:.pr..eiíted' at the:60thAnnual Technical Conferenèeand Exhi- bition. La. Vegas. September 22-25. 1985. ,......... :.;.~;. ~ ....,. ". )~t : ;. -~ 1_ 14. Gray, D. K., Fatt, I. and Berganin1. G.: "The Effect of Stress on Permeability of Sandstone 1 Cores," Soc. Pet. Eng. J. (1963) 2. 203. 15. Nelson, R. A.: "A Discussion of the Approximation of Subsurface (Burial) Stress Conditions in Lab- oratory Experiments," Geophysical Monograph 24, American Geophysical Union (1981) 311-321. 1 .. .:\ ~:-';1'_~. A~;~i~:~7i:~·,',,~~,~<\ - ."", \ " TNILE 1 " TYPICAL <DR£ I1EAStJRf>IENr SrsrÐI CALJ:8AATIoo N>IO II£P&\TABILITY ANALYSIS 00 S'I'EEL PORE \Q.ltI£ Sl'NIDAADS 1(t o:JNFINrtC sm£SS Sl'1\NDI\RD \OUJHE . 0.195 CC Confining Stress Psig Run I Run 2 Run 3 1000 0.207 (+.012) 0.230 (+.035) 0.223 (+.028) 2000 0.193 (-.002) 0.222 (+.027) 0.215 (+.0201 3000 0.188 (-.007) 0.217 (+.022) 0.210 (".015) 4000 0.184 (-.011) 0.213 (+.018) 0.206 (".011) 5000 0.180 (-.015) 0.210 (+.015) 0.203 (+.008) 6000 0.175 (-.019) 0.207 (+.012) 0.201 (".006) Run 4 RunS 0.224 (+.029) 0.215 (+.020) 0.211 (+.016) 0.207 (+.012) 0.204 (+.009) 0.202 (+.007) 0.222 (+.027) 0.213 (".018) 0.209 (+.014) 0.206 (+.011) 0.203 (+.006) 0.200 (+.005) Sl'ANt\I\RD \OWI1E . 1. 021 ex:: 1000 1.017 (-.004) 1.045 (+.0241 1.043 (+.022) 1.043 (+.022) 1.043 (+.022) 2000 1. 006 (-.013) 1.035 (+.014) 1.034 (+.013) 1.034 (+.013) 1.034 (+.013) 3000 1.002 (-.019) 1.031 (+.010) 1.030 (+.009) 1.029 (+.008) 1.029 (+.008) 4000 0.998 (-.023) 1.027 (+.006) 1.025 (".004) 1.025 (+.004) 1.025 (+.004) 5000 0.994 (-.027) 1.023 (+.023) 1.022 (".001) 1.023 (+.002) 1.022 (+.001) 6000 0.991 (-.030) 1.020 (+.020) 1_020 (-.001) 1.020 (-.001) 1.019 (-.002) ~"ANIlI'JU) \OUI'IE . 3.099 cc 1000 3.101 (+.002) 3.123 (+.034) 3.131 (+.032) 3.128 (+.029) 3.129 (+.028) 2000 3.089 (-.010) 3.121 (+.022) 3.119 (+.020) 3.119 (+.020) 3.117 (+.013) 3000 3.083 (-.016) 3.114 (+.015) 3.113 (+_014) 3.113 (+.014) 3.113 (+.014) 4000 3.077 (-.022) 3.109 (+.010) 3.106 (+.009) 3.108 (+.009) 3.109 (+.010) 5000 3.073 (-.026) 3.105 (+.006) 3.105 (+.006) 3.103 (+.004) 3.105 (+.006) 6000 3.069 (-.030) 3.102 (+.003) 3_101 (+.002) 3.102 (+.003) 3.102 (+.003) 1) CMS ..an ovemig,t in autDlllatic node in 1abo..atory envi..cnnent with variable teope..atu..e. 2) Haxinum..rror of 0.035 ex:: ww1d result in 0.27 porosity percent point error in a s""t'le of·l inch di"""'ter and 1 inch1enqth (i.e. 10.0 to 10.27 porosity percent). TABLE 2 Sl'ANDA1UJ6 0f£CI( IWJS'I1IATIIC <DR£ ~ær SrsrÐI PORE \UaŒ NXJJIIItCi AND CDlSISTЫ:Y ~ LOCATIOOS (AT 1000 PSIG CQ> FlNlIC snu::ss) Standa..d Volumes ~ Aberdeen London· Cal<Jðry* * Dallas Denver 0.195 0.209 (+.014) 0.188 (-.007) 0.212 (+.017) 0.199 (+.004) 0.S45 0.540 (-.005) 0.515 (-.030) 0.547 (+.002) 0.529 (-.016) 1. 021 1.026 (+.005) 0.999 (-.022) 1.016 (-.005) 1.014 (-.007) 1.025 (+.004) 3.099 3.104 (+.005) 3.085 (-.Ò14) 3.092 (-.007) 3.097 (-.002) 3.105 (+.006) 5.109 5.ll8 (+.009) 5.101 (-.008) 5.086 (-.023) 5.108 (+.001) 5.109 (0.000) ·Aft.... 1 yea.. field t..ia1 in Aberdeen ·"Recalibration afte.. field repai.. TABLE 3 <DR£ P£ASURDIENT SrsrÐI AIR PERI1EABILm N:J::oJRN::r AND REPFATABILm O!æK eN Sl'EEL STANIWWG Steady Confining State Stress Sanple K "'""..age PsiQ ~ ~ Run I ~ Run 3 ~ 500 " 1.09 1.05 1.05 1.05 -3.7\ 1000 " 1.04 1.05 1.04 -4.3\ SOO B 29.3 28.7 28.6 28.6 -2.3\ 1000 B 26.8 28.7 28.6 -2.0\ 500 C 48.5 46.5 46.5 46.4 -4.2\ 1000 C 46.4 46.4 46.4 -4.1\ SOO D 73.7 70.7 70.5 70.4 -4.3\ 1000 D 70.6 70.5 70.3 -4.3\ SOO E 1430 1480 1480 1470 +3.3' 1000 E 1490 1490 1480 +4.2\ TABU . TYPICAL CXJRE II!ASUIIDIIN1' 81tS1'Ð4 OCRE DI07t Ia <nIFINIIG S11I£SS IWJSrRAnlG (XN ISTEM:Y 8£naN, II61'IUUM'S SAMPLE A ( LCW I't:I!MEMILITY) Conf iRing Dallas (Run 1) Denver (~n 2)· Streu II K Ka(eat) b(fle) Beta II K Ka(est) b(He) ~:t PsiQ -L ...!!!L ......!!!L- ..!!L n-1 -L ...!!!L ~ ..!!L 500 10.7 .065 .141 56.6 2.75d013 10.7 .055 .130 66.6 1.76xlO13 800 10.6 .057 .132 63.2 2.96xlO13 10.6 .052 .126 6i!.2 2.44xlO13 1000 10.6 .054 .129 67.2 2.74xlO13 10.5 .052 .124 67.7 2.81xl013 2000 10.4 .053 .122 63.0 4.52xlO13 10.4 .050 .118 65.7 3.68xl013 4000 10.2 .048 .114 66.8 4.05xlO13 10.2 .047 .112 67.1 3.71xl013 6000 10.1 .043 .109 75.9 1. 51xlO 13 10.0 .043 .109 74.0 1. 77xl013 SAMPlE 8 (/'DŒRATE P£RMEA8IUTY) SOD 19.6 33.9 37.3 4.88 3. 46xl08 19.3 33.4 36.7 4.80 3. 55xloS 800 19.3 32.8 36.2 4.% 3.65x108 19.1 32.4 35.6 4.84 3.81xl08 1000 19.2 32.4 35.7 4.95 3.80xl08 19.0 32.0 35.1 4.80 3.93xl08 2000 18.9 31.1 34.2 4.95 4.05xl08 18.6 30.7 33.7 4.80 4.23xl08 - 4000 18.5 29.6 32.6 5.04 4.33xl08 18.] 29.2 32.1 4.88 4.54xl08 6000 18.3 28.5 31.5 5.DS 4. 56xl08 18.1 28.3 31.1 4.91 4.77xl08 ·Data set indicated pore space at túœ of ~n 2 had ~ fully rebounded fra1l 6000 psi o::xrpressive forœ inpœed _ral days earlier d.lring ~n 1. TABLE 5 IRREIXIClBU: I>PJER (RElATIVE IÐMENIILIT'! EFFeCTI QI OCRE I1EASURÐ1£NT SYSreK KLINKfNIEIG i'ERf'IENIILrN AND OIL PERHF.A8IUTY J <niFINlJoC STRESS ,t~; .... ~>~~~ . ~~.~t:~~,.~,:";;·~~r"';~·ir~~:,,,,-"......:..·;,,,,,,,,,:&·.,,,:,,,,,"""k~"D~~~ ~"'''\.~~1:~r'"i.:ö-6itttñt~~<·· "~''''''----~'6fi~'-j:''f~.,Jt.,~'~'~·~:'::'~¡...:s.w~~~V~~· > ··---~-l¡;';'I<.~··~J.;.~,-~....._ Permeability:m: Permeability:m: ·· Oty Core Core @ Swir 1<0 @ Swir 800· 4000· 800· 4000· ~ 4000· Sanp1e ~ Porœ ity ---L- Swir ,Pol 1 2 3 374 18.5 29.2 15.5 7.7 17.2 5.0 7.2 22.9 545 32.2 30.1 520 29.5 28.7 543 31.3 31.1 517 29.3 29.6 400 22.3 30.7 ·Confining Stress ··Steady-State Heasurenent TABLE 6 IRREWCIBLE WI\1'ER EFFECT CN SLIPPAGE (b) FACIOO NIt> 'lUR!IIJID Œ (8E:I'A) FACroR J CI:ßFINlJoC STRESS Conf ining Oty Core Irred.lclble Sw a 22.9 , p.¡ - Stress ø bOle) Beta b(lle) Beta Psig -L ~ ~ ~ ~ SOD 17.4 4.90 2.84xl08 4.11 2_81x108 800 17.2 5.03 2.81xl08 4.10 2. 89x108 1000 17.2 5.06 2.83xl08 4.13 2.9Ox108 2000 16.8 5.05 2.99xl08 4.16 2.99xl08 4000 16.6 5.11 3.04x108 4.27 3.06xl08 6000 16.5 5.10 3. 19x108 4.30 3.15xl08 ',~ ?ç::::<:::.}.,. '. '..' , :~, t;, t~~t~i~:f§:.tf·~·t::·i\ ,', - ..:~ .;,:.i; .;¡;t· ':\ :t::;. ,",:..".- I I -"",,' SURFACE T OVERBURDEN PRE SSURE 0.5 ~ { 2::::J - . NET OVERBURDEN = (OVERBURDEN PRESSURE) - (RESERVOIR PRESSURE NOB ~ DEPTH (1.0 ~s/ -0.5 ~s/ ) ~ DE PTH (0.5 ~ITi ) Fig. 2-Net overburden pressure \I'~. depth. ~' WI ' FLOW /.// !;;t 0: :I: 0 -J u.. 1- :~ :: V f- + ß p V 2J 00 PRESSURE DIFFERENTIAL .. Fig. "-Etlect. o' lurbulence on flow. ..:--< 1 KA:: KCI) ,;'~ " ,,' ~~" NON-REACTIVE LIQUID ,~~......... ................. ........ SLIPPAGE CORRECTED KLlNKENBERG PERMEABILITY Fig. 1-Permeablllty I. . 'unction of mean pressure. ------@- ~ I ----- '<A>- ~ .. I 1 ~ ~S. 100 PSI STRESS f IQ/NI(EN8EAG 6 ill!D. ~ œmJ I $""..::: 3UIIO IU't, ~ .071 110 'U't, i .S - - .. ~ I , 3 - 0 1 1 3 . S 6 1 6 10 CONFINING STRESS: lHOuSANDS Of PSI Fig. 3-Po,o.lty and p.rm.abIllTy v., confining .1'.... --L- Pmean - >- .... ¿. CD ~ I.&J ::IE 0: I.&J 0.. °0 - n.e 22.6 22.' ~ 22.2 ~ ~ :;;no ~ 2U! 2'. - COHf~tHG STfltSS' PSIG fig. B-Comparat ye porosities va. confining stress. ti :r 3.50 ~ > ~ J.4~ 1.65 3.0 335 3.30 o 1000 2000 3000 ~n COHftNlNG STRESS: PSI(; 4000 ~ooo Fig. 9-ComparaUve pore volumes va. net confining .tress. ':' 28 ~ >< 2' I 20 ~ :0 ,. m ~ " 11 8 ~ " " g ~ 0 ~ 0 '000 5000 230 n8 226 ~ >- 0 I STANDARD ~D,"T7""'"" I I . ~ ',I A11EROSTRESS'~ I ~-'" r ~ ". ...... JACKH£D 8R1NE. SATURA.TEO CORE fN ....... roMPR(SSIØIUTY APPARA 1US .,.... . ............... z W 22" ~ ~ § 221 ~ no 218 21.. D 3000 2000 '000 1000 N£T toHf"'ltOG STlltSS : I'SIG Fig. 10--Comparatlva poro.ttles .... net confining stress. - - 1.0 - >- ..... -....J ....J<{ OOz ~~1 ::lEa: a:O W Q...lL- o <Oz >-2 .......... -<.> <nod: 0a: ~lL- 0... ® 00 Fig. 11-compa_ poIa volume com¡>1euItMlltles vs. net conflnll\1 stress. N(T OOHAIIIOG STRfSS : I'SIG POROSITY ADJUSTED TO UNIAXIAL STRAIN ~ Fig. f2_OIoslty _ _ability &dlu.t....,,1 10 un!.."'1 .Iraln, I I I I I I I I® NET OVERBURDEN PRESSURE ~ September 23, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O..Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3K-9 ARCO Alaska, Inc. Permit No. 86-166 Sur. Loc. 1234'FSL, 317'FWL, Sec. 35, TI3N, R9E, UM. Btmhole Loc. 132]'FSL, 1902'FWL, Sec. 35, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so 'that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI~Rv%ISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L Lowery STATE OF ALASKA ALASKA ,- AND GAS CONSERVATION C,- ,4MISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~3,./ Redrill ~1 lb. Type of welI. Exploratory© StratigraphicTest [] Development Oil L"~ Re-Entry Deepen Service [] Developement Gas [] Single Zone I~L Multiple Zone El 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25519 ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 1234'FSL, 317'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1317'FSL, 1794'FWL, Sec.35, T13N, R9E, UM 3K-9 #8088-26-27 At total depth 9. Approximate spud date Amount 1323'FSL, 1902'FWL, Sec.35, T13N, R9E, UM 09/26/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pr0perbj 15. Proposed depth(MD and TVD) property line 7305 'MD feet 317' @ surface feet 3K-8 25'@ surface feet 2560 (6955'TVD) 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth2932 feet Maximum hole angle30 0 Maximum surface 2300 psig At total depth (TVD) 3470 psig 18, Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2a.'' !6" 62.5# H-".O Weld 20' 35' 35' !!5' !!5' ±200 cf 12-1/4"9-~/R " zF,.n~ .i-~,~ RTe ~Rq~,' '~, -~c,, ~,q?q' 3~8~' 1100 s× AS I!1 &. HF-ERW 300 sx Class G blend 8-1/2" 7" .26.0# J-55 BTC 7271 ' 34' 34' 7305' 6955' HF-ERW 200 sx C1 ass G(Min.) 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~'~0~t ~o285ve't~Do Ku ) Present well condition summary a p p Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Intermediate Production~< .:'iL; ~!. ~? ~.~J{3" '~" .... Liner Perforation depth: measured .... "~: '~ .... ' .... ,,;:,i~:;:..]ic..?~ true vertical "?" ~::!; ~:""~!'! ? 20. Attachments Filir~ fee~ Property plat [] BOP Sketch ,]~ Diverter Sketch~ Drilling program,~ Drilling fluid program ~l;~k,,Tim~ vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certif/~t the foregoing i/~and correct to the best of my knowledge Signed ! /~7'~,~ ,_~( L//~/x,?~~' Title Regional Drilling Engineer Dat ~.-~//" (¢/ ~/ ~""~' ~ ~- Commission Use Only (HRE) PD/007 ~'{G(¢ '1 50-- o~,-'~- ¢,-[ E, ,5~-(o Appr°~/d~!t~/86 for other requirements Conditions of approval Samples required [] Yes ~L. No Mud Icg required ~ Yes J~No Hydrogen sulfide measures , [] Yes [] No Directional survey required I~E--Yes [] No Required workin~ure~f~~Mj,~j~3M; I-I 5M; [] 10M; [] 15M Other: f' /,,_.~~ ~__~~~~ te~ by order of Approved by L ~' . Commissioner the commission Da Form 10-401 Rev. 1~ ~ / Su,I; ~ triplicate , $ I ' - . I..500" 1 i / 1605 ! ._.L4OQ: 700_ 57'1 _.t200~ ..... 700 O- 100 200 3;00 -- 400- - 500-'-- 600 KUPRRUK R I VER UN I T 20" D I VERTER SCHEMAT I C DESCRIPTION 1. lB" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI ORILLINQ SPOOL H/lO" OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION.~--~ 8. 20" 2000 PSI ANNULAR PREVENTER./ ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 03S (b) MA I NTENANCE & OPERAT I C~ Ill I Il 4 2 'L 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BlOW A I R THROU(~H D I VERTER L I NES EVERY 12 HEXJRS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROi:U~IATE VALVE TO ACHIEVE DONI~INO DIVERSION. DO NOT SHUT IN WELL II II UNOER ANY C I RCUMSTANCES . mm i mm ~j 00~4oo2, 7 DIAGRAM #l 13-5/8" 5000 PSI RSRRA BOP STACK i. 16" - 2000 PSI TAN<CO STARTING HEAD 2. I1" - 3000 PSI CASING IF_AD 3. I1" - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOCL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/CHOKE At~D KILL LI~ES G. 13-5/8= - 5000 PSI DOUBLE RAM W/PIPE RAMS ON TOP, BLITZ) RAMS ON BOTTCM. ?. 13-5/8' - 5000 PSI A~ ACCLIVIJLATOR CAPAC]'TY TEST I. CHECK A~ FILL ACCLI~TOR RESERVOIR TO PRCPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT AC~TOR PRESSL~ IS 5000 PSI WITH 1500 PSI D(~TREAM CF THE REGULATOR. 3. OBSERVE TINE, THEN CLOSE ALL UNITS SINIJLTA~EOUSLY A~D RECORD THE TINE ~ P~ REMAINING AFTER ALL UNITS ARE CLOSED WITH Q4ARGING PLI~P OFF. 4. RECORD ON NADC REPORT, THE ACCEPTAt~E LOA~R LIMIT IS 45 SE~ CLOSING TINE AI~ 1200 PSI RE]VlAINING PRE~, . 12. 15-5/8" BOP STACK TEST FILL-BOP STACK AI~ CHCKE MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL LOCK D(~ SC~ IN V~E1.U-EAD ARE FLE.LY RETRACTED. SEAT TEST PLUG IN WE]_I.~ WITH Rt~ING JT ~ RUN IN LO(~ SCREWS. LIHE VALVES ADJACENT TO BOP STACK,, ALL OTHER VALVES /~ CHCKES SHOULD BE OPEN. PRESSUI~ UP TO 250 PSI ~ HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI AAD HOLD FCR I0 MIN. BLEED PRESSURE TO 0 PSI. OPEN A~ PREVENTER AhD MA~AL KILL AhD CHCKE LIhE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON K;[LL AhD CHOKE LIhES. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LIt~ES, A~D CHCKES WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRE.~,SI.IRF' TEST ANY ~ OI~_Y NOT A F~I-L CLosING PosITIVE SEAL u-.,,.~c.,THAT IS FUNCTION TES]- CHCKES THAT DO NOT FULLY CLosE. OPEN TOP PIPE RAMS AI~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI ~ 3000 PSI. OPEN BOTTa~ PIPE RAMS, BACK OUT RUNNING JT AhD PULL OUT CF HOLE. CLosE BLIhD RAMS AhD TEST TO 250 PSI AhD 3000 PSI. OPEN BLIAD RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIhES ARE FULL CF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI AhD 3000 PSI. RECORD TEST Ih~rC~TICN ON BLOWOUT PREVENTER TEST FORM, SIGN, AND SEhD TO DRILLING SUPERVISCR. PERFC~ CCIVPLETE BOPE TEST AFTER NIPPLING UP AhD WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15,, 1985 GENERAL DRILLING PROCEDU~u~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8%" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8~" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. I0. Run and cement 7" casing. Pressure test to 3500 psig. II. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xm-s tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and rubies, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. . l CLEANER I }! $1..iAL. E i S;,~.~., ',STIR SHAKERS {- ~ ' CENTRIFUOE TYPICAL MUD SYSTEM SCHEMATIC LWK4/ih ; ' .... ' ; DRILLING FLUID PROGRAM Density PV YP Viscosity Initial Gel i0 Minute Gel Filtrate API pH % Solids Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 20 9-10 10_+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih ARCO Alaska, inc. Post Office BOx 100360 Anchorage, Alaska 99510.-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built LOCation Plat - 3K Pad {Wells I - 18) Dear r4r. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl osure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichheldCompany LOCATED IN PROTRACTED '" LOCATED IN PROTRACTED "~ SECTION ~5, T.i~N., R. 9E.,U.M. SECTION ~5, T.I~N., R. 9E.,U.M. X - 5~,G.11 L~. 149'45'~.9~7' X - S~,~.69 L~G. 149'45'~.~" 14~' KL, 318' ~ ~- ~.~ P~- ~.S IlK' r~, 315' ~ ~- ~.8 P~" ~.S X · 5~,~.19 L~G. 149045'~.93~ X - 5~,~S.73 L~. 149'45'~.9774' 1~' ~, 318' ~ ~- ~.4 P~- ~.S 1135' ~, 31S' ~ ~- ~.O P~" ~.S 3 - Y - 6,~,~8.~ ~T. 70'~'0Z.~79' lZ - Y "6,~,103.53 ~T. 7~'59.~" X - 5~,~.14 L~G. 149'45'~.9~" I - 5~,~S.72 L~G. 14~45'~.~" 1~' ~, 31~' ~ ~' ~.5 P~ · ~.S I1~' ~, 316' ~ ~' ~.0 P~" ~.S 4 - Y · 6,~,353.~ ~T. 7~"02.~14' 13 - Y "6.~,078.~ ~T. 7~'59.3~3' 1359' ~SL, 318' ~ ~" ~.7 P~" ~.S 1~' ~, 315' S - Y - 6,~,3~.~ ~T. 700~'01.795~ 14 - Y - S,~,~.75 ~T. 70'~'S~.~2~ X - S~,~.O7 L~G. 149045'~.~S" X - S~,~.~ L~. 14~45'~.~" 13~' ~, 317' ~ ~" ~.8 P~ ~.S 1~' ~, 315' ~ ~' ~.0 P~" ~.S 6 * Y - 6,~,~3.~ ~T. ~'~'01.S~I" 1S - Y ' 6,~,0~.53 ~T. 70'~'~.~51" I - 5~,~.05 L~. 149'45'~.~78' X - 5~,~S.75 L~. 149'45'~.~" I~' ~, 317' ~ ~- ~.9 P~' ~,S 10~' ~, 31S' ~ ~- ~.0 P~" ~.S 7 - Y - 6,~,~.~ ~T. 7~'01.~" 16 - Y - 6,~,~3.~ ~T. 7~'~.S~" X - 5~0~S.~ L~. 149045'~.95~ X - S~,~S.78 L~G. 149'45'~.~S" 1~' ~, 317' ~ ~ - ~.0 P~" ~.S l~' KSL, 315' ~ ~- ~.0 P~- 34.5 8 - Y - 6,~,2~.70 ~T. 700~'01.0~ 17 - y - 6,~7,978.81 ~T. X - 5~,~S.~ L~G. 149045'~.9~" X - 5~,~S.77 L~G. 1259' ~L, 317' ~ ~" ~.0 P~" ~.S ~S' KSL, 315' ~ ~' ~.0 P~- ~.S ~ - Y - 6,~,~.65 ~T. 70'26'~.8124' 18 - Y - 6.~7,953.69 ~T. 7~'~.1~ X - 5~,~S.9Z L~G. 149045'~.~" X - 5~,~5.73 L~G. 149'45'~.~77" 12~' FSL, 317' ~ ~" ~.1 P~" ~.S 959' KL, 315' ~ - _. . . : NOTES * ' . I. ALL COOrDINaTES A~E A.$.~,ZO~E~. · . _ ~L DISTANCES SHOWN ARE TRUE. ~.HO~IZONTAL POSITIONS BASED ON ~K CONTROL ~O~UMENTS PER [HD ~ ASSOC. 4. VERTICAL POSITIONS BASED 0~ ~K TBM ~o. 4 ~ TBM ~o. 5 PER ~HD ~ ~S~. 5.0.G. ELEVATION~ INTERPOLATED F~OM S/C DRAWING C[D-~IXX-~O70 rev.~ ~ CER~FICA~ OF SURVEYOR: I HEREBY C~TI~ THAT I AM PROPERLY REGISTERED AND LICENSED ~ PRACTICE LAND -:'* - ":~ ** .' :'~ ~RVEYINO IN ~E STATE OF ALASKA ~O THAT .~ - 'T. "', -~ -' THIS P~AT REPRESENTS A LOCATION SURVEY ~. .. , ',~ ~ I ~ M~ BY ME 0~ UN~; MY SUgERVISION, ~ND ~ -, . ~) ~ - ' IONS AND OTHER DET~ 12S ~ '~,' ' ~;ETH~T CO~E~.A2L DIMENSAs OF ~ MAY 1986. F. ~;~ , ,, ," SURVEYED FOR: ~ ARCO Alosko, Inc. ~ KUPARUK PROJECT ~,' ~ --'"'' . DATE 2 MAY 19,86 ::~ ~.~w.~ DRILL SITE 3K CONDUCTOR ~, '.~ 8SSO& ] ,,~ ~,~,.e.,,o~ AS-BUILT LOCATIONS I......... IIDWG' N°' NSK 86-'l ~3~ A~t~ ~u/eva~, Sure 201, ~flomge, Amska ~9503 ll$~cE NOT T0 SCALE II I I ii I I ii CHECK LIST FOR NEW WEIJ. PERMITS IT~ APPROVE DATE (1) Fee (2) Loc ,, , 1. Is the permit fee attached .......................... . . . Is well to be located in a defined pool '.' Is well located proper distance from property line . : · 41 Is well located proper distance from other w~lls .. . Lease & Well YES NO 0 . ., h . (3) Adndn ~// ¢-'¢7~f~ 9. (9, th 13) , i 10. ~ 12. 13. (4) Casg~~ ~ (14 t~ "22) (5) BOPE (23 thru 28) (6) OTHER /~/,A, (29 thru J'31)'' (6) Add: ~.~.~. ?-~-g~ Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ............... Is operator the only affected party ........................... ' Can permit be approved before fifteen-day wait ...................... ~'~/ ., Does operator have a bond in force .................. . e e e e e · · e · · · · · · · ,_ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ............. ....................... Does the well have a unique name and number ......................... 14. 15. 16.. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is conductor string provided ........................................ _~f_ ..... Will surface casing protect fresh water zones ....................... ~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ~ ,, Will cement cover all known productive horizons ..................... ~ ...... Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... Is the drilling fluid program schen~atic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached· Does BOPE have sufficient pressure rating - Test to ,-~Of)~ psig .. Does the choke mm]ifold comply w/AP1 RP-53 (May 84)..: ............... Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ' 20 eeeeeoeeoeeeeeeeeeeeeeeeeeeeoeeeeeeeeeeeeeeoo Gee logy: WVA 07/18/86 POOL INITIAL CLASS STATUS GEO.! UNIT I ON/OFF AREA NO. j,,sHor 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. :~: .... SCHLUMBERGER .... .VP 010.H02 VERIFICATION LISTING PAGE I :~: REEL H:ADER. ~,~ ;ERVICE NAME :EDIT )ATE :86/10/22 )RIGIN : 1EEL NAME :149469 'ONTINUATION ~ :01 )REVIOUS REEL : 'OMMENTS :LIBRARY TAPE x~ TAPE HEADER ;ERVICE NAME :EDIT )ATE :86/10/22 )RIGIN :FS1A FAPE NAME : ;ONTINUATION ~ )RE¥IOUS TAPE : ;OMMENTS :LIBRARY TAPE ,.~LFILE HEADER ~.~ : E NAME :EDIT .001 ;ERVICE NAME : ~ERSION m : )ATE : qAXIMUM LENGTH : 102~ :ILE TYPE : ~REVIOUS FILE : INFORMATION RECORDS ~NEM CONTENTS UNIT TYP,E CATE SIZE CODE SN : ARCO ALASKA, INC. ~N : 3K-9 mN : KUPARUK RANG: gE TOWN: 13N SECT: 35 COUN': NORTH SLOPE STAT: ALASKA MNEM CONTENTS' 000 000 018 055 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 0 06 065 UNIT TYPE CATE SIZE CODE .VP 010.H02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER ~DMP~NY = ARCO ALASKA INC iELL = 3K'-g :IELD : KUPARUK ;OUNTY = NORTH SLOPE BOROUGH ;TATE = ALASKA lOB NUMBER AT ACC: 72000 IUN ~TWO~ DATE LOGGED: ~5 OCT 86 .DP: T HALSTEAD ;ASING : 10.750" @ 3172' - BIT SIZE = 8.5" TO 7443' '¥PE FLUID = LSND POLYMER )ENSITY : ~0.10 LB/G RM : 3.190 @ 65 DF /ISCOSITY = ~3.0 S RMF = 3,010 @ 65 DF ~H = 9-5 RMC = 2.250 @ 70 DF =LUID LOSS = 4.2 C3 RM AT BHT = 1.5~1 @ 142 DF {ATRIX SANDSTONE ,,--.-~,-~ THIS DATA H~S NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ~ .VP OlO.H02 VERIFICATION LISTING PAGE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: '-Y- DUAL INDUCTION SPHERICALLY FOCUSED LOG (OIL) ~ DATA AVAILABLE: 7425' TO 3175' ~.' BOREHOLE COMPENSATED SONIC LOG (BHC) ~ DATA AVAILABLE: 7394' TO 3175' ~ FORMATION DENSITY COMPENSATED LOG (FDN) COMPENSATED NEUTRON LOG (FDN) -'--,. DATA AVAILABLE: 7399' TO 3175' -~ GAMMA RAY IN CASING (GR.CNL) -,.-~ DATA AVAILABLE: 3175' TO 1000' DATA FORMAT RECORD ~ ~NTRY BLOCKS 'TYPE' SIZE REPR CODE ENTRY 2 ! 66 0 4 ~ 66 1 8 ~ 73 60 9 4 65 .lin 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS ~NEM SERVICE SERVICE DNIT AP1 AP1 AP1 AP'I FiLE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 4 ~ 68 00000000000000 SFLU DZL CHMM O0 220 OI 0 0 4 t 68 00000000000000 .VP OlO.HO2 VERIFICATIgN LISTING `PAGE 4 iLO OIL OHMM O0 :LM OIL OHMM O0 ~P DIL MV O0 ;R DIL GAPI O0 )T BHC US/F O0 ;R BHC GAPI O0 ;R FDN GAPI O0 ~LI FDN IN O0 ~HOB FDN G/C3 O0 )RHO FON G/C3 O0 ~R/tT FDN O0 ',NRA FDN O0 tPHI FDN PU O0 )PHI FDN PU O0 4CNL FDN CPS O0 :CNL FDN CPS O0 ;R CNL GA.PI O0 120 120 010 310 52O 310 310 280 350 356 420 000 890 890 330 330 310 )EPT 7438.5000 SFLU ;~P -999.2500 GR ~R 108.8125 CALI ~RAT 3.2598 RNRA ~CNL 2029.0000 FCNL DEPT 7400.0000 SFLU ~P -53.4375 GR DR 108.8125 CAt! 4RAT 3.2598 RNRA ICN!L 2029.0000 FCNL~ )EPT 7300.0000 SFLU SP -18.5156 GR ;R 87.7500 CALI ~RAT 3.1172 RNRA ~CNL 2150.0000 FCNL DEPT 7200,0000 SFLU SP -21,0000 GR 3R 88,0625 C~LI ~RAT 3.6523 RNRA ~CNL 1708.0000 FCNL DEPT' 7100,0000 SFLU SP -50.5313 GR GR 42,9687 CALI NR~T 2,7598 RNRA NCNL 22~4,0000 FCNL DEPT 7000.00~00 SFLU SP -48,0938 GR GR 61,5625 =CALI' -999. -999. 8. 3. 574. . 106. 8. 3. 574. . 98. 8. 3. 625. . 89. 9. 3. 473. 27. 49. 8. 2. 797 · 8. 65. 8. 46 44 O1 01 80 O1 01 O1 O2 01 O1 O0 O0 00 31 3O O1 2500 2500 1797 5332 0000 8283 6250 6250 5332 0000 1362 7500 4609 4355 5000 0429 7500 2969 6035 7500 1181 5000 2656 8125 5000 8836 3125 8281 ILD DT RHOB NPMI GR ILD DY RHOB NPMI GR ILO DT RMOB NPHI GR ILO DT RMOB NPHI GR ILD DT RHOB NPHI GR ILO O 'T RHOB 4 ! 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 6 8 4 1 68 4 1 68 4 1 68 4 1 68 -999.2500 ILM -999.2500 GR 2.4258 DRHO 39.3066 DPHI -999.2500 1.6519 ILM 97.8125 GR 2.4453 DRHO 38.6230 DPHI -999.2500 2.70.11 ,ILM 92.4375 GR 2.4707 DRHO 36.2793 DPHI -999.2500 1,9177 ILM 110,4375 GR 2,3379 DRHO 44,8242 DPHI -999,2500 18.6950 ILM 92.8750 GR 2.2617 DRHO 30.5664 OPHI -999.2500 6,3272 ILM 92,3125 GR 2,4082 DRHO 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 -999.2500 -999.2500 0.0244 13.5977 1.7177 106.6250 0.0547 12.4140 2.7879 98.7500 0.0161 10.8754 1.9710 89.7500 0.0303 18.9238 20.1349 49.5000 .0.0117 23.5398 6.5924 65.3125 O. 0308 .VP OlO.H02 VERIFICATION LISTING PAGE 5 iRAT 2.9531 RNRA ICNL 2184.0000 FCNL )EPT 6900.0000 SFLU ;P -69.6250 GR ;R 93.1875 CALI IRAT 2.9395 RNRA tCNL 1870.0000 FCNL )EPT 6800.0000 SFLU ;P -51.0000 GR ;R 103.9375 CALI IRAT 3.9707 RNRA 4CNL 1630.0000 FCNL )EPT 6700.0000 SFLU ½P -50.0000 GR ~R 159.0000 CALI ~RAT 3.9043 RNRA ~CNL 1564.0000 FCNL )EPT 6600.0000 SFLU SP -57.5000 GR DR 119.2500 CALI ~RAT 3.8906 RNRA qCNL 1627.0000 FCNL ]EPT 6500.0000 SFLU SP -47.5000 GR SR 330.7,500 CALI ~)RAT 3.3223 RNRA ~CNL 1668.0000 FCNL DEPT 6400.0000 SFLU SP -57.50,00 GR ~R -999.250'0 CALI ~RAT -999.2500 RNRA NCNL -999.2500 FCNL DEPT 6300.0000 SFLU SP -47.5000 GR GR -999.2500 CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL DEPT 6200.0000 SFLU SP -40.0000 GR GR -999.2500 CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL DEPT 6100.0000 SFLU SP -42.5000 GR GR -999.2500 CALi 3.4160 NPHI 639.0000 GR 3.5671 ILD 108.8125 DT 9.9219 RHOB 3.3027 NPHI 566.0000 GR 1.5690 ILO 119.5625 DT 10.9219 RHOB 4.2891 N'PHI 379.7500 GR 2.4195 ILD 161.3750 DT 9.8828 RHOB 4.0000 NPHI 391.0000 GR 2.4824 ILD 130.5000 DT 10.7969 RHOB 4.1602 NPHI 390.7500 GR 2.7437 ILD 399.0000 DT 8.8828 RHOB 3.5586 NPHI 468.5000 GR 2.1046 ILD 115.9375 DT -999.2500 RHOB -999.2500 NPHI -ggg.2500 GR 2.4355 ILO 131 . 6250 D T -999. 2500 RHOB -999.2500 NPHI -999.2500 GR 2.1750 ILO 98. 8125 DT -999.2500 .RHOB -999. 2500 NPHI -999.2500 GR 2.3787 ILO 95.3750 DT -999.2500 RHOB 32.8125 DPHI -999.2500 2.6108 ILM 98.1250 GR 2.5449 DRHO 31.2500 DPHI -999.2500 1.4327 ILM 111.2500 GR 2.4063 DRHO 48.3887 DPHI -999.2500 2.2177 ILM 115.1250 GR 2.3833 DRHO 48.5352 DPHI -999.2500 1.9949 ILM 113.1250 GR 2.4160 DRHO 47.0215 DPHI -999.2500 '1.3750 ILM 110.3750 GR 2.4629 DRHO 39.4043 DPHI -999.2500 1.6874 ILM 102.2500 GR -999.2500 DRHO -999.2500 DPHI -999-2500 1.7100 ILM 108.1875 GR -999.2500 DRHO -999.2500 DPHI -999'2500 2.1769 !LM 94.1250 GR -999.2500 DRHO -999.2500 DPHI -999.2500 2.9083 ILM 89.1875 GR -999.2500 DRHO 14.6629 2.9468 108.8125 0.1089 6.3777 1.5309 119.5625 0.0215 14.7812 2.2'380 161.3750 0.0317 17.3851 2.0568 130.5000 0.0503 14.1894 1.6399 399.0000 0.0483 i1.3488 1.8417 115.9375 -999,.2500 -999.2500 1.8381 131.6250 -999.2500 -999.2500 2.2601 98.8125 -999.2500 -999.2500 2.9558 95. 3750 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 6 ~R&T -999.2500 RNRA -999. tCNL -999.2500 FCNL -999. )EPT 6000.0000 SFLU 1. ;P -39.5000 GR 38. ;R -999.2500 CALI -999. ~RAT -999.2500 RNRA -999. ~CNL -999.2500 FCNL -999, )EPT 5900.0000 SFLU ;P -47.0000 GR 61. ;R -999.2500 CALI -999. ~RAT -999.2500 RNR~ -999. ~CNL -999.2500 FCNL -999. )EPT 5800.0000 SFLU 2. ~P -48.5000 GR 99. iR -999.2500 CALI -999. ~RAT -999.2500 RNRA -999. ~CNL -999.2500 FCNL -999. ]EPT 5700.0000 SFLU 2, ~P -52.0000 GR 93. ;R -999.2500 CAll -999. ~RAT -999.2500 RNRA -999. qCNL -999. 2500 FCNL -999. ]EPT 5600.0000 SFLU 3. SP -49.0000 GR 99. SR -999.2500 CALI -999. ~RAT -999.2500 RNRA -999. gCNL -999.2500 FCNt -999. DEPT 5500.0000 SFLU 2. SP -53.5000 GR 106. ~R -999.2500 CAL[ '999. NRAT -999.2500 RNRA -999. NCNL -999.2500 FCNL -999. DEPT 5400.0000 SFLU 1. SP -52.5313 GR 102. GE -999.2500 CALI -999. NRAT -999. 2500 RNRA -999. NCNL -999.2500 FCNL -999. DEPT 5300.0000 SFLU SP -52.5000 GR 104. GR -999.2500 CALl -999. NRAT -999.2500 RNR~ -999. NCNL -999.2500 FCNL -999. DEPT 5200.0000 SFLU 3. SP -55.0000 GR 92. GR -999.2500 CALI -999. 2500 2500 8149 1875 2500 25O0 2500 9727 6563 2500 2500 2500 1212 1875 2500 2500 2500 6658 5625 2500 250O 2500 1180 0625 2500 2500 2500 8590 1875 2500 2500 2500 9385 0000 2500 2500 2500 0855 3750 2500 2500 2500 3605 9375 2500 NPHI GR tLD DT RHOB NPHI GR ILD DT RHOB NPHI GR ILO DT RHOB NPHI GR ILO DT RHOB NPHI GR ILO DT RHOB NPHI GR DT RHOB NPHI GR DT RHOB NPHI GR ILD DT RHOB NPHi GR ILO OT RHOB -999.2500 DPHI -999.2500 1.6300 ILM 100.3750 GR -999.2500 DRHD -999.2500 DPHI -999.2500 4.4774 ILM 79.9375 GR -999.2500 ORHO -999.2500 DPHI -999.2500 2.1914 ILM 102.3125 GR -999.2500 DRHO -999.2500 OPHI -999.2500 2.5628 ILM 99.7500 GR -999.2~00 DRHO -999.2500 DPHI -999.2500 3.0965 ILM 97.3125 GR -999.2500 DRHO -999.2500. DPHI -9'99.2500 3.0318 ILM 95.0000 GR -999.2500 DRHO -999.2500 DPHI -999.2500 102.3125 GR -999'250'0 DRHO -999.2500 DPHI -999.2500 3.1441 ILM 101.0000 GR -999.2500 DRHO -999.2500, DPHI -999.2500 3.3161 ILM 98.3125 GR -999.2500 DRHO -999.2500 1.7137 88.1875 -999.2500 -999.2500 5.0804 61.6563 -999.2500 -999.2500 2.2534 99.1875 -999.2500 -999o25~00 2.6389 93.5625 -999.2500 -999.2500 3.1878 99.0625 -999.2500 -999.2500 3.0991 106.1875 -999.2500 -999.2500 2.5125 102,0000 -999.2500 -999.2500 3.1859 104.3750 -999.2500 -999.2500 3.3472 92.9375 -999.2500 ,VP OIO.H02 VERIFICATION LISTING PAGE 7 JRAT -999,2500 RNRA ICNL -999,2.500 FCNL -999.2500 NPHI -999.2500 GR ~EPT 5100,0000 SFLU iP -116,5000 GR ;R -999,2500 CALI ~RAT -999,2500 RNRA ~CNL -999,2500 FCNL 3,1049 ILD 93,3750 DT -999,2500 RHOB -999,2500 NPHI -999.2500 GR )EPT 5000.0000 SFLU ;P -5.5156 GR ;R -999.2500 CALI ~RAT -999.2500 RNRA ~CNL -999.2500 FCNL 4,6632 ltd 81,0625 DT -999,2500 RHOB -999,2500 NPHI -999,2500 GR )EPT 4900,0000 SFLU ~P -2,0801 GR )R -999,2500 CALI ~RAT -999.2500 RNRA UCNL -999.2500 FCNL 2.4845 ILO 97.3125 OT -999.2500 RHOB -999.2500 NPHI -999.2500 GR ]EPT 4800.0000 SFLU SP -4.0000 GR DR -999.2500 CALI qRAT -999.2500 RNRA gCNL -999.2500 FCNL 2,8701 ILD 92, 3125 DT -999,2500 RHOB -999,2500 NPHI -999.2500 GR 2EPT 4700.0000 SFLU SP -5.2734 GR SR -999.2500 CALI NEAT -999.2500 RNRA ~CNL -999.2500 FCNL 2.5979 ILD 91.3125 DT -999.2500 RMDB -999.2500 NPHI -999.2500 GE DEPT 4600.0000 SFLU SP -iB,O000 GR GR -999,2500 CALI NRAT -999,2500 RNRA NCNL -999,2500 FCNL 2.7693 ILD 93,812S DT -999°2500 RHOB -999,2500 NPMI -999,2500 GR DEPT 4500,01000 SFLU SP -13,0000 GR GR -999,2500 CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL 2.4009 ILD 96.9375 DT ,-999.2500 RHOB -999.2500 .NPHi -999,2500 GR DEPT 4400,0000 SFLU SP -14,5000 GR GR -999,2500 CALI NEAT -999,2500 RNRA NCNL -999,2500 FCNL 2.9384 ILD 77.6875 OT -999.2500 RHOB -999.2500 NPHI -999.2500 GE DEPT ~300.:0000 SFLU SP -16.0000 GR GR -999.2500 CALl 3,2823 ILO 77,1875 DT -999,2500 RHOB -999.2500 DPHI -999.2500 3,2230 ILM 97,5625 GR -999,2500 DRHO -999.2500 DPHI -999.2500 3.7939 ILM 97.6875 GR -999.2500 DRHO -999.2500 DPHI -999.2500 2.7064 ILM 103.1875 GR -999.2500 DRHO -999.2500 DPHI -999.2500 3.0743 ILM 105,0625 GR -999,2500 DRHO -999,2500 DPHI -999.2500 2.8053 ILM 104,5625 GR -999,2500 DRHO -:999.2500 DPHI -999.2500 2.9163 109,2500 -999.2500 -999.2500 -999-2500 ILM GR DRHO DPHI 2'6242 ILM 112.5625 GR -999.2500 DRHO -999.2500 DPHI -999.2500 2. 9920 ILM 107.6250 GE -999.2:500 DRHO -999. 2500 DPHI -999. 2500 3.4067 110,2500 -999.2500 ILM GR DRHO -999.2500 3.3368 93.3750 -999.2500 -999.2500 3.9067 81,0625 -999.2500 -999.2500 2.7069 97.3125 -999.2500 -999.2500 3.0847 92.3125 -999.2500 -999.2500 2.'7989 9!.3125 -999.2500 -999.2500 2.9217 93.8125 -999.250~0 -999.2500 2.6311 96.9375 -999.2500 -999.2500 2,9814 77.6875 ,-999.2500 -999.2500 3.3863 77.1875 -999.2500 ,VP OlO.H02 VERIFICATION LISTING PAGE 8 IR~T -999.2500 RNRA ICNL -999.2500 FCNL )EPT 4200.0000 SFLU ;P -18.5000 GR ;R -999.2500 CALI iR~T -999.2500 RNRA ICNL -999.2500 FCNL }EPT 4100.0000 SFLU ;P -21.0000 GR ;R -999.2500 CALI tROT -999.2500 RNRA }CNL -999.2500 FCNL )EPT 4000.0000 SFLU ;P -20.0000 GR ;R -999.2500 CALI 4RAT -999.2500 RNR~ dCNL -999.2500 FCNL )EPT 3900.0000 SFLU ;P -25.5000 GR ;R 69.1875 CALI 4RAT 3.9785 RNRA dCNL 1585.0000 FCN'L )EPT 3800.0000 SFLU ~P -24.5000 GR ;R 72.9375 CALI ~R~T 3.8242 RNRA ~CNL 1564.0000 FCNL )EPT 3700.0000 SFLU 3P -26.5000 GE ;R 71.4375 CALI qRAT 3.6621 RNRA 4CNL ~761.0000 FCNL DEPT 3600.0000 SFLU SP -32.0000 GR ~R 81.0000 CALI ~RAT 3.7441 RNRA ~CNL 1604.0000 FCNL DEPT 3500.0000 SFLU 3P -34.01000 GR ;R 62.Z813 CALl qRAT 3.6543 RNRA ~CNL 1520.0000 FCNL ]EPT 3400.0000 SFLU 5P -46.0000 GR ~R 65.5000 CALI -999.2500 NPHI -999.2500 GR 3.4307 !LD 83.0000 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR 3.8907 ILD 84.5000 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR 2.6210 ltd 72.4375 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR 5.1367 ILD 67.8750 DT 12.3516 RHOB 3.9277 NPHI 403.5000 GR 4.1910 ILO 81. 6250 {DT 1~.3438 RHOB 3.9414 NPHI 396.7500 GR 4.4763 ILO 77.875:0 DT 11.4375 RMOB 4.0508 NPHI 434.5000 GR 4.2820 ILD 89.3750 DT 11.5078 RHOB 3.9785 NPHI 403.0000 GR 4.8704 ILD 70.9375 DT 11.2422 RH05 3.5840 NPHI 424.0000 GR 14.3919 ILD 67.5625 DT 9.7578 RHOB -999.2500 DPHI -999.2500 3.4735 ILM 108.0000 GR -999.2500 DRHO -999.2500 DPHI -999.2500 3.2509 ILM 113.0525 GR -999.2500 DRHO -999.2500 DPHI -999.2500 2.7040 ILM 116.7500 GR -999.2500 DRHO -999.2500 DPHI -999.2500 3.9886 ILM 117.8750 GR 2.2090 DRHD 47.9004 DPHI -999.2500 4.0390 ILM 111.8750 GR 2.2520 DRHO 45.0684 DPHI -999,2500 5.4783 ILM 116.4375 GR 2.1738 DRHO 42.5293 DPHI -999.2500 4.7065 tLM 119.6250 GR 2.1816 DRHD 43.9941 DPHI -999.2500 5.3515 ILM 119.8750 GR 2.1:875 DRHO 42.4805 DPHI -999.2500 10.6080 tLM 125.8750 GR 2.1992 DRHO -999.2500 3.4285 83.0000 -999.2500 -999.2500 3.3420 84.5000 -999.2500 -999.2500 2.7222 72.4375 -999.2500 -999.2500 3.8619 67.8750 0.0137 26.7355 4'0459 81.6250 0.'0825 14.1316 5.0615 77.8750 0..0171 28.8660 4.4989 89.3750 O. 0327 28.3926 5.3087 70.9375 0.0137 28.0375 10.5660 67.5625 0.0103 ,VP OlO.HO2 VERIFICATION LISTING PAGE tRAT 3.8~37 RNRA ICNL 1579.0000 FCNL IEPT 3300.0000 SFLU ;P -46.5000 GR ;R 54.6875 CALI IRAT 3.7773 RNRA ICNL [553.0000 FCNL )EPT 3200.0000 SFLU iP -41.0000 GR ;R 56.8437 CALI 4RAT 3.8887 RNRA 4CNL 1512.0000 FCNL )EPT 3100.0000 SFLU ~P -999.Z500 GR ~R -999.2500 CALI ~RAT -999.2500 RNRA ~CNL -999.2500 FCNL DEPT 30'00.0000 SFLU SP -999.2500 GR DR -999.2500 CALI ~RAT -999.2500 RNRA ~CNL -999.2500 FCNL ]EPT 2900.0000 SFLU SP -999.2500 GR ~R -999.2500 CALI ~RAT -999.2500 RNRA ~CNL -999.2500 FCNL DEPT 2800.0000 SFLU SP -999.2500 GR ;R -999.2500 CALI NRAT -999.2500 RNRA NCNL -9'99.2500 FCNL DEPT 2700.0000 SFLU SP -999.2500 GR GR -999.2500 CALI NR&T -999.21500 RNRA NCNL -999.2500 FCNL DEPT 2600.0000 SFLU' SP -999.2500 GR GR -999.2500 CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL DEPT 2500.0000 SFLU SP -999.2500 GR GR '-999.2500 CALI 4.0000 NPHI 394.7500 GR 7.6742 ILO 50.9375 DT 10.7266 RHOB 4.3086 NPHI 360.2500 GR 5.3262 ILO 60.9687 DT 15.4688 RHOB 4.2422 NPHI 356.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -'999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999. 2500 ILD -999.2500 DT -999. 2500 RHOB -999. 2500 NPHI -999. 2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999.2500 -999.2500 DT -999.2500' RH08 -999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -'999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RH08 47. -999. . 132. 2. 44. -999. 6074 250O 6556 2500 1523 9219 2500 5.9136 131.7500 2.1836 44.7266 58.8750 -999.2500 -999.2500 -999.2500 -999.2500 37.7188 -999.2500 -999.2500 -999.2500 -999.2500 25.7031 -999.2500 -9'99.2~00 -999.2500 -999.2500 32.0938 -999.2500 -999.2500 -999.2500 -999.2500 .48.5313 -999.2500 --999.2500 -999.2500 -999.2500 39.8125 -999.2500 -999.2500 -999.2500 -999.2500 24.6563 -999.2500 -999.2500 -999.2500 DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI ILM GR DRHO DPHI I L M GR DRHO DPHI ILM GR DRHO 27. 3273 7.5993 50.9375 0.0205 30.1680 5.4633 60.9687 0.0229 28.2742 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,VP OlO.H02 VERIFICATION LISTING PAGE t0 iRAT ICNL )EPT ;P ;R IRAT ICNL )EPT ;R ,IRAT ~CNL )EPT ~P .;R ',lC NL DEPT SP .;R qRAT ~CNL DEPT .~R ~IRAT NCNL DEPT SP SR NRAT NCNL DEPT SP SR NR AT NCNL DE PT SP GR NRAT NCNL DEPT SP GR -999.2500 RNRA -999.2500 FCNL 2400.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 2300.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 RNRA -999.2500 FCNL 2200.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 RNRA -999.2500 FCNL 2100.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 RNRA -999.2500 FCNL 2000.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 1900.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 1800.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 RNRA -999.2500 FCNL 1700.0000 SFLU -999.2500 GR -999.250'0 CALI -999.2500 RNRA -999.2500 FCNL 1600.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPMI -999.2500 GR -999.2500 ILO -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999.2500 iLD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999.2500 ILO -999.2500 DT -999.2500 RM'OB -999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999-2500 ILO -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NPHI -999.2500 GR -999-2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 DPHI 37.4688 -999.2500 iLM -999.2500 GR -999.2500 ORHO -999.2500 DPMI 25.7188 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 25.6250 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 26.4063 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 24.8906 -999.2500 ILM -999.2500 GR · -999.2500 ORHO -999.2500 DPHI 24.0313 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 30.2969 -999.2500 ILM -999.2500 GR -999.2500 DRMO -999.2500 DPHI 28.4375 -999.2500 -999.2500 GR -999.2500 DRHO -999.2500 DPHI 34.0938 -999.2500 ILM -999.2500 GR -999.2<500 DRHO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999'2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP OlO.H02 VERIFICATION LISTING PAGE 11 tROT -999.2500 RNRA ICNL -999.2500 FCNL !EPT 1500.0000 SFLU ;P -999.2500 GR ;R -999.2500 CALI IRAT -999.2500 RNRA ICNL -999.2500 FCNL )EPT 1400.0000 SFLU ;P -999.2500 GR ;R -999.2500 CALI 4RAT -999.2500 RNRA 4CNL -999.2500 FCNL )EFT 1300.0000 SFLU ~P -999.2500 GR ;R -999.2500 CALI ~RAT -999.2500 RNRA gCNL -999.2500 FCNL DEFT 1200.0000 SFLU SP -999.2500 GR DR -999.2500 CALI ~RAT -999.2500 RNRA gCNL -999.2500 FCNL 3EPT llO0.O000 SFLU SP -999.2500 GR )R -999.2500 CALI q~RAT -999. 2500 RNRA NCNL -999.2500 FCNL 3EPT lO00.O000 SFLU SP -999.2500 GR ER -999.2500 CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL DEFT 995.0000 SF!LU SP -999.2500 GR GR -999.2500 ~CALI NRAT -999.2500 RNRA NCNL -999.2500 FCNL ~ FILE TRAILER FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH :1024 FILE TYPE NEXT FILE NAME -999 -999 -999. -999. -999. -999. -999. -999. -999. -999. -ggg. -999. -999. -999. -999. -999. -999. -999. -999. -999- -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -9gg. -999. -999. '-999. -999. -999. '-999. 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 25O0 2500 2500 2500 2500 250=0 2500 25 O0 250:0 250~0 2500 2500 2500 2500 2500 2500 2500 2500 250O 2500 2500 2500 2500 NPHI GR ILD DT RHOB NPHI GR ILD DT RHOB NPHI GR iLD DT RHO6 NPHI GR ILO DT RHOB NPHI GR ILD DT RHOB NP HI GR DT RHOB NPHI GR ILO DT RHO8 NPHI GR -999.2500 DPHI 13.0781 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 33.9687 -999.2500 ILM -999.2500 GR -999.2500 DRMD -999.2500 DPHI 21.3T50 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 34.9375 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 29.5938 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 41.3125 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 48.0625 -999.2500 ILM -999.2500 GR -999.2500 DRHO -999.2500 DPHI 49.0625 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.HO2 VERIFICATION LISTING PAGE tZ ~ FILE HEADER ~ :ILE NAME :EDIT .002 SERVICE NAME : ~ERSION ~ : )ATE : qAXIMUM LENGTH : 102z+ :ILE TYPE : ~REVIOUS FILE : '~* COMMENTS ~.'~ ,,..~..~.~.o,..~..~.~.~.:~..~-'o-'--'o-~-~.-'--~--'o ~:~`~`~xk`~°`~`~`~`~`~`~``~``,`~`~`~`~`~`~``~`~`~~`~`~`~. ~-~-~o~~.~.,~.~-~.~..~.~-~.~.~ .... .~.~.~., SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY = ARCO ALASKA INC NELL = ~K-g FIELD = KUPARUK SOUNTY = NORTH SLOPE BOROUGH STATE = ALASK~ JOB NUMBER AT ACC: 72000 RUN #TWO, DATE LOGGED: 15 OCT 86 LOP: T HALSTEAD CASING TYPE FLUID DENSITY VISCOSITY = 10.750" @ 3172' - BIT SIZE =- 8.5:" TO 7443' = LSND POLYMER = 10.10 LB/G RM = 3.190 ;9 65 DF = 43.0 S R MF = 3.010 ;9 65 DF ,VP OlO.H02 VERIFICATION LISTING ~ PAGE 13 \ ~H = 9.5 '!, RMC = 2.250 @ 70 DF :LUID LOSS = 4.2 C3 \ RM AT 5HT = 1.5~1 @ 142 DF IATRIX SANDSTONE :;~:',:~ THIS DATA HAS NOT BEEN DE H SHIFTED - OVERLAYS FIELD PRINTS :~k~:~ THIS FILE CONTAINS ALL 1.2" 5AMRLED. DATA ~. ~: ~ ~: ~ .~. ~ ;~ ~ ~ ~ .-~ ~ , ~ ~ ~ ~ ~ ~ ~: ~ ~k ~ ~ ~. ~ ~ ~. ~ ~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: ~ · FORMATION DENSITY COMPENSATED LOG (SAM) ~- · COMPENSATED NEUTRON LOG (SAM) · .,--'- DAT/~ /~VAILABLE: 7399' TO 3175' ~',: ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ 1 66 1 9 4 65 .lIN 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP.i API API ~PI FILE SIZE SPL REPR ID ORDER # LOG TYPE CLASS MOD NO. CODE PROCESS (OCTAL) .¥P 010.H02 VERIFICATION LISTING PAGE 14 )EPT FT O0 ;R SAM GAPI O0 iALI SAM IN O0 ~HOB SAM G/C3 O0 )RHO SAM G/C3 O0 ~RAT SAM O0 ~NRA SAM O0 JPHI SAM PU O0 )PHI SAM PU O0 ~CNL SAM CPS O0 :CNL SAM CPS O0 000 310 280 35O 356 42O 000 890 890 330 330 O0 O1 O1 02 O1 O1 O0 O0 O0 31 30 }EPT )RHO )PHI 7404,8994 0,0513 6.7328 7400,2998 0,0513 6,7328 7300.2998 0.0112 10.4019 7200'2998 0.0483 17,6219 7100.2998 -0.0039 25.3152 7000-.2998 0.0254 13.3609 6900.2995 -999.2500 -999,2500 6800.2998 -999,2500 -999,2500 6700,2998 -999.2500 -999,2500 6600,2998 -999,2500 -999,2500 ]EPT )RHO )PHI ]EPT )RHO 3PHi ]EPT 3RHO 3EPT 2RHO DPHI 3EPT DRHD DPHI OEPT DRHO DPHI DEPT DRHO OPHI OEPT DRHD DPHi DEPT ORHO DPHI GR NEAT NCNL GR NEAT NCNL GE NRAT NC NL GR NEAT NCNL GR NEAT NC NL GR NEAT NCNL GR NEAT NCNL GR NRAT N C N L GR NE.AT NCNL GR NEAT NCNL 93.1250 3,1309 1885,0000 93,1250 3,1309 1885.0000 86.4375 3.0684 2068. 0000 82.8125 3. 8340 1659.000'0 45.3438 2.6563 2354, O000 61,5000 2. 9023 2150.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2.500 -999.2500 -999. 2500 -999,2500 CALI RNRA FCNL CALl RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CAL~ RNRA FCNL CALI RNRA FCNL 8.3828 3,3926 555.5000 8.3828 3,3926 555,5000 8.5078 3.2930 628.0000 9.3984 4.0000 414.7500 8.2500 3.0996 759.0000 8.9375 3.1719 677,5000 -999.2500 -999.250,0 -999.2500 -999.2500 -999,2500 -999,2500 -999,2~00 -999,2500 -999,2500 -999,2500 -999.250.0 -999.2500 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 RHOB 2.5391 NPHI 36.6211 EHOB 2.5391 NPHI 36.6211 RHOB 2.4785 NPHI 35.3027 RHOB 2.3594 NPHI 47.9.492 RHDB 2.2324 NPHI 29.0527 RHOB 2.4297 NPHI 31,8848 RHOB -999.2500 NPHI -999.2500 RMOB -9~99.2500 NPHI -999.2500 RHOB -999.2500 NPHI -999,2500 EHOB -999,2500 NPHI -999,2500 ,VP 010.H02 VERIFICATION LISTING PAGE 15 }EPT }RHO )PHI )EPT )RHO )PHI )EPT )RHO )PHI )EPT )RHO )PHI )EPT )RHO )PHI )EPT }RHO )PHI )EPT )RHO )PHI )EPT 3RHO )PHI 3EPT 3RHO 3PHI 2EPT DRHO DPHI DE P'T DRHO DPHI DEPT ORHO DPHI DEPT ORHO DPHI 6500.2998 GR -999.2500 NRAT -999.2500 NCNL 6~00.2998 GR -999.2500 NRAT -999.2500 NCNL 6300.2998 GR · -999.2500 NRAT -999.2500 NCNL 6200.2998 GR -999.2500 NRAT -999.2500 NCNL 6100.2998 GR -999.2500 NRAT -999.2500 NCNL 6000.2998 GR -999.2500 NRAT -999.2500 NCNL 5900.2998 GR -999.2500 NRAT -999.2500 NCNL 5800.2998 GR -999.2500 NRAT -999.2500 NCNL 5700.2998 GR -999.2500 NRAT -999.2500 NCNL 5600.2998 GR -999.2500 NR4T -999.2500 NCNL 5500.2998 GR -999.2500 NRAT -999.2500 NCNL 5400.2998 GR -999.2500 NR4T -999.2500 NCNL 5300.2998 GR -999.2500 NRAT -999.2500 NCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999. 2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 ~CNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999-2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL ,-999. 2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB ~NPH I RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 DEPT 5200.2998 GR -999.2500 CAiLI -999.2500 RHOB -999.2500 VP OlO.H02 VERIFICATION LISTING PAGE 16 IRH3 -999.2500 NRAT IPHI -999.2500 NCNL )EPT 5100.2998 GR )RHO -999.2500 NRAT )PHI -999.2500 NCNL )EPT 5000.2998 GR )RHO -999.2500 NRAT )PHI -999.2500 NCNL )EPT 4900.2998 GR )RHO -999.2500 NRAT )PHI -999.2500 NCNL )EPT .4800.2998 GR )RHO -999.2500 NRAT )PHI -999.2500 NCNL )EPT 4700.2998 GR )RHO -999.2500 NRA'T ]PHI -999.2500 N:CNL ]EPT 4600.2998 GE )RHD -999.2500 NRAT )PHI -999.2500 NCNL ]EPT 4500.2998 GR DRHO -999,2500 NRAT 2PHI -999,2500 NCNL DEPT 4400,2998 GR DRHO -999,2500 NRAT DPHI -999,2500 NCNL DEPT 4300.2998 GR DRHO -999,2500 NRAT DPHI -999,2500 NCNL DEPT 4200.2998 GR DRHO -'999.2500 NRAT O:PHI -999,2500 NCNL DEPT 4100,2998 GR DRHO -999.2500 NRAT DPHI -999,2500 NCNL DEPT 4000,2998 GR DRHD -999.2500 NRAT DPHI -999. 2500 NCNL DEPT 3900.2998 GR ORHO 0.0488 NRAT DPHI 23.6582 NCNL -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999,2500 RNRA -999.2500 FCNL -999,2500 CALi -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999. 2500 CALI -999,2500 RNRA -999.2500 FCNL -999.2500 C4LI -999.2500 RNRA -999.2500 FCNL -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 CALl -999.2500 RNRA -999.2500 FCNL -999,2500 CALl -999,2500 RNRA -999,250.0 FCNL -999.2500 CALI -999.2500 RNRA -999,2500 F~C!NL -999,2500 CALl .-999.2500 RNRA -999.2500 FCNL 67,1250 CALI 4,0742 RNRA 1496.0000 FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.250:0 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12,4063 4.4531 335.7500 NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI R H 0 B NPHI RHOB NPHI RHOB NPHI RHOB NPHI RHOB NPHI --999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.2598 49.6582 .VP OiO.H02 VERIFICATION LISTING PAGE 17 )EPT 3800.2998 GR )RHD 0.0566 NRAT )PHI 25.3152 NCNL )EPT 3700.2998 GR )RHD 0.0000 NRAT )PHI 29.1027 NCNL )EPT 3500.2998 GR )RMO 0.0508 NRAT )PHI 26.8539 NCNL )EPT 3500.2998 GR ]RHO 0.0005 NRAT )PHI 28.2593 NCNL )EPT 3400.2998 GR ]RHO 0.0405 NRAT DPHI 25.0790 NCNL ]EPT 3300.2998 GR ]RHO 0.0371 NRAT DPHI 28.3905 NCNL DEPT 3299.5000 GR DRHO 0.0005 NRAT DPHI 31.4667 NCNL 81.2500 3.7168 1652.0000 78.5625 3.6309 1715.0000 81.5000 3.7773 1471.0000 62.8594 3.8384 1604.2500 75.6875 4.2539 1701.9844 62.7539 3.7422 1567.1250 '56.4180 3.2354 1471.0000 C~LI RNRA FCNL CALl RNRA FCNL CALI RNRA FCNL CALI RNRA FCNL CALl RNRA FCNL CALI RNRA FCNL ,CALI R.NRA FCNL ~-~"°,- FILE TRAILER FiLE NAME :EDIT .002 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME : EOF =~=~=~ ~ TAPE TRAILER ~ SERVICE NAME :EDIT DATE :86/10/22 ORIGIN :FSI& 'TAPE NAME : CONTIN~U~TION ~ :01 NEXT TAPE NAME : COMMENTS :LIBRARY TAPE ~ REEL TRAILER ~ SERVICE NAME :EDIT 13.4453 4.3125 382.7500 11.5391 4.0938 418.7500 11.6094 3.3184 443.2500 11.9062 4.5254 354.2500 10.0469 4.6093 369.0078 10.7580 4.0004 391.6875 10.7578 2.9609 496.8750 RHOB NPHI RHDB NPHI RHDB NPHI RHO8 NPHI RHO8 NPH I R H 0 B NPHI RHOB NP H I 2.2324 42.5781 2.1699 41.8945 2.2070 44.5801 2.1837 45.5139 2.2363 54.6753 2.1816 44.3298 2.1309 3.5.0220 ,VP OlO.H02 VERIFICATION LISTING P~GE 18 lATE :86/10/22 IRIGIN : :EEL NAHE :149469 :ONTINUATiON ~ :01 IEXT REEL NAME : :OMMENTS :LIBRARY TAPE
