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
194-161
94 .... i 6 i 94 - i 6 i 94 "- I 6 '1 94 - 16 i 94 ...... i 61 94-' 16 / 9 Lt. ,* 161 9 4 "-' '1 6 / 9 4 -" 1 6 1 94 .... I 61 94'- 94 ~ 161 94 - 161 94-161 9 4 - I 6 1 9 4 - I 6 I 94, -'" I 6 ii 94 ...... 161 ~[ ~I l ...... j 6 ~i 94 .... J 61 94 ~I J J 61 ,S :a o J o g ~1' C a '[ ix,'[ a 't: :a r" "f a 'J s I i'i v :e Fi 't o r" y T L'; A T ':-I F'L IJ ',El Ds-ke: ii.,.> 0 i,/',96 0,5/" 0 4./" 9 5 04/1 0/'95 0 a./' '10//95 DPR/GR "'J" f,//..,.B O P F:..:/,'"' '3 R ,/W E:,..,c :]:/' I E Iq G/' L 0 G E N G/' L 0,2 E P L. L. DS//'LDT /,AO ,.E-'"'6 '100 - 1 0500 ~ a-490-'95%.3 Il )A~ H D F' T' ~ 9500 - 1 'i 500/t'1/..~ "1 04/' I 0/" 95 0/.i. / I '10 //l 95 0 4 ,/ 1 0 ,/ 9 5 04'/' '10/'95 04/' '10/' 9 S 04/1 0/95 /' i (] /9 !5 04 / / 04/' '10/95 0,4 ,,/1 O/9 5 0 4 / '10,/ 9 5 0 ~'l' // 1 0 ¢'/ 9 5 04/'10 / 95 04./1 0//' g 5 ivi S D I 9600 ..... 11350 i 0 4 ,/' t 0/" 9 S ,~, . E U N C, A T E ._.R E ,$ VD 9 a. --, i 6 1 9 .q - '1 6 'i 9 a..,.. I 6 1 9 a, .,, '1 6 1 N F'BD/D F' RG R P D :[ F:'./" ~.~/TE P 0/R/" A E T S TVD TVD F'D/"R 04../' I 0/' 9 5 0 z.~../i O / 95, 0-q./' '1 [."),/"9 5 0 .q./'i 0/95 0~./I 0/95 0 -q./'10 / 95 0 a. ,/'1 0 / 9 5 94 ..... i61 9/+'~ i 6 'i 9/+-~ 16 I 9/+-~ i6i 9L~ ..~ '161 94--161 9/+-.'--16i 94.-- i61 94-161 9a---' 161 94-161 9/+----'16I 9/+''~ 161 9~.~- 161 9/+~ 16 t 9~-i61 94-- 16 I 94-161 94--161 9~-i6i 9a-i61 9a-- i61 9/+--161 9 a----161 9a..Y t61 9a.~-16 I DATA -. .... , T DATA_PLUS R UN E,A I-'E .... F,'EC\ TVD M,'~¢~ k,.r ~-/~500-'i 0500 TVD/LDS,LDT. , d.,-"~00--10500 NGRS; ~9570-11307 0a/ 10/95 04 / i 0/' 95 0a/ I 0/95 04/ 10/95 0a./ I 0/95 PDIR/~R TVD/LS$/OA[ LDS/LDT (7) a/ I 0I 95 04/ -10/95 04/ 10/95 MDFT TVO LSS/DSZ LSS/DSZ DPR/~R DPR/GR ENG/LOG COMB/k~VD ENG/LOG COklB/l'4G AD NF'BD/DPRGR MSD LDS/LDT k~ZCRO/L. AIT D,H.WATER Sk~F'L 976/+~112/+8 ~'f~t~- 1 0~/ 10/95 100~-10/+00 ~ A" o~Y~,,.,,,,,-,.-~ 1 0a/'10/95 1 (')/+/ 10/95 " 9560-i i5/+¢ F 1 0a/ 10/95 5o--~ lsso~ 9" 'l oa-/'lo/gs 50-1i550~X ~ I 0/+//0/95 cE 9560~-~ 15acA,c ,i o;.,./.10/95 FMI ..-E~9589~ I0/.79 ~,.:~,~!,¢$l. ~.~1~ b.O,& I ~* ¢'i / 10/95 ~9600~11350 E~*~ N~¢_~,f~&.,_,.'b!-~ ~,.~¢~ 1 0~-/ ~0/'95 - ' · ~ oa./1 o/ 5 ~ z~90--11326 2 ~/ ~ ' a 0l~/ 10/95 ~ 9570---il/+52 P~,- /~ 0/~/10/95 ,¢~¢ ~ ~/ 04/ '10/95 . ~ , 05/0~,/95 . ~---' i6 'i 94-16! 94--161 9 tv-- 161 94-161 94-161 9t~-161 DATA T DATA.._P L U'3 FM TOPE; CORE DESCRZPTZC, N F~. VEL. OCZTY SURVEY CORE ANAL. YSZS DST ~2 PTS WELL TST RPT~. R LIN DATE REC'v 05/0,'.~ / 95 05/04/95 O5/O6/95 o5/o~/9s osfo~l'OS 05/0~/9.5 Ar'e dr'y ditch Was the Ar'e well We ii i s samples r'equir'¢d° ~ . ~ .~ ~. And r'eceived? no well cor'ed? ~ no Anaiysi's &. descr'~'pti'on r'eceived?~ i'n compliance I~{i' ti'a i COMMENTS I'10 PLUGGING & LOCATION CLEARANCE REPORT State of Alaska .ALASKA OiL & GAS CONSERVATION COMH!SSiON Memcrand%um To File: APi No. Well Name 0uerator Location Note casing size, wi, Perf in=e~als - tops: Abnd Data depth, cmt vol, & procedure. ~'~o , ~ q &5 . ~7~~ ~x ~ t o ,70?~ fl, (go q~5 Well head cut off: Marker post or plate: Location Clearance: Review the well file, and' comment on' plugging, well head - I ~ Conclusions Code f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP ! I=TION RFPORT A LO.C' 1. Status of Well Classification of Service OIL ~ GAS ~ ~~D D ~~ED ~ SERVICE 2. Name of Operator ~ 7. Permit Number BP Exploration / ~, ~ , 94-161 3. Address ' I ,I ~//~/~ ~.APINumber P. 0. Box 196612, Anchorage, Alaska 9951~]~, 50-629-22533 4. Location of well at surface ~ C~;V.?~.~T~[~ 9. Unit or Lease Name 33~' SNL, 4878' WEL, SEC. 5, T9N, R2~ ·, P,'~T~ ~ Badami At Top Producing Interval ~/~_. ~ ~ ~ 10. Well Number 950' SNL, 3430' WEL, SEC. 5, T9N, R20E ~ ~ Badami ~5 At Total Depth ;~.;L~ .... Z_ '--~- ~~~ 11. Field and Pool 543' SNL, 3137' WEL, SEC. 5, T9N, R20E Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 33' AMSL ADL 367011 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1/21/95 3/2/95 4~/95 6'feet MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ]20. Depth where SSSV set 21. Thickness of Permafrost 11549' MD/10554' TVD Sudace ~S ~ ~ DJ N/A feet MD 1900' 22. Type Electric or Other Logs Run Please see a~achment 23. CASING, LINER AND CEMENTING RE,RD S~ ~ ~ ~NG DEP~ MD CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~NG RECORD AMOUNT PUl I 30' 310~ 30' 11 O' Ddven 80' 13-3/8" 68~ NT80-CYHE 30' 4465' 16" 8755 sx CS 11/305 sx "G" 30' 9-5/8" 47~ P- 110 30' 9578' 12-1/4" 800 sx 'G" Neat 195' 7" 29~ NT95HS 9279' 11549' 8-1/2" 680 sx 'G" Neat None 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH S~(MD) PACKER S~ All pedorations abandoned None None 26. ACID, F~CTURE, CEME~ SQUE~E, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See a~ached diagram for abandonment cement plu~s 27. PRODU~ION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) See a~achment N/A Date of Test Hours Tested PRODU~ION FOR OIL-BBL GAS-MCF WATER-BBL CHO~SIZE ]GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. See a~achment RECEIVED I¥~AY 1 0 t9~5 Alas~ 0il.& Gas Cons. Commi~sion Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverecl~iil~t~gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Sagavanirktok Fm. (at or near seabottom) Base Permafrost 1900' 1900' Top Canning Fm. 5154' 5154' (Mikkelsen Tongue) Top Staines Tongue of 7120' 6892' Sagavanirktok Fm. Base Staines Tongue 8799' 8295' or Top Lower Canning Fm. RECEIVE[; k, AY 1 0 19 5 Alaska Oil & Gas Cons. Commission Anchors 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~C~/~ TitleDrillingEn_clineerSuporvi$or Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) Or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 BP Exploration (Alaska), Inc. CONFIDENTIAI~',e~O' Badami #5 APl Number: 50-629-22533-00 ~.,~ all core footage are driller's depth; core diameter approximately 4" Core #1: cut 10,489' to 10,498', recovered 8.3 feet (in Aluminum liner) 11,489' - 11,497.3' gray muddy siltstone with minor amounts of cemented very fine grained sandstone as laminae and streaks. No oil stain, cut or fluorescence. Apparent dips variable, ranging from 25° to 60°. Core #2: cut 10,550' to 10,553', recovered 0.4 feet (in Aluminum liner) 10,550.0' - 11,550.4' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 50°. Core #3: cut 10,553' to 10,573', recovered 20 feet (in Aluminum liner) 10,553.0' - 10,573.0' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip ranges from 48° to 55°. Core #4: cut 11,01 11,016.0' - 11,021.7' sandstone. Sandstone to orange fluorescence 6' to 11,024', recovered 5.7 feet (in Aluminum liner) gray siltstone interlaminated with minor amounts of very fine grained is oil stained medium brown to light brown. Stained sandstone has dull yellow and bright yellow streaming cut fluorescence. Apparent dip is 28°. Core #5: cut 11,113' to 11,143', recovered 25 feet (in Aluminum liner) 11,113.0' - 11,1120.0' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained medium brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 30°. 11,120.0' - 11,138.0' gray siltstone (interlaminated with very fine grained sandstone) interbedded with thin bedded sandstone. Sandstone (as beds and in laminae) is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 320. Core #6: cut 1 1,143' to 11,203', recovered 59.5 feet (in Aluminum liner) 11,143.0' - 11,160.0' gray siltstone interlaminated and interbedded with fine grained sandstone. Sandstone (as beds to 8' thick and in laminae) is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 35°. 11,160.0' - 11,166.0' Sandstone with rare thin interbeds of siltstone. Sandstone is fine to medium and contains carbonaceous and coaly debris. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 35°. 11,166.0' - 11,175.5' gray siltstone interlaminated and interbedded with very fine to fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 41° 11,175.5' - 11,196.7' Sandstone with rare thin interbeds of siltstone. Sandstone is very fine to fine grained and contains carbonaceous and coaly debris. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. 11,196.7' - 11,202.5' Sandstone with rare thin interbeds of carbonaceous sandstone. Sandstone is fine to medium grained and is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. RECEIVED Gas Cons. Commission Anchor;. ', Core #7: cut 11,203' to 11,263', recovered 60'+ feet (in Aluminum liner) -'"~.,,~ 11,203.0' - 11,213.4' Sandstone with rare thin interbeds of carbonaceous sandstone. Sandstone fine to medium grained and is oil stained dark brown to medium brown. Stained sandstone has dull '~',~,~ yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. "~ 11,213.4' - 11,247.3' Sandstone with thin interbeds of carbonaceous sandstone and gray siltstone. Sandstone is fine to medium grained with some beds containing siltstone clasts. Sandstone is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is approximately 40°. 11,247.3' - 11,252.8' gray to tan siltstone and silty mudstone. No stain, cut or fluorescence. Highly variable dips ranging from 10° to 60°. 11,252.8' - 11,257.8' Sandstone with thin interbeds of carbonaceous sandstone and gray siltstone. Sandstone is fine to medium grained with some beds containing siltstone clasts. Sandstone is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is approximately 40°. 11,27.8' - 11,263.0' + 8" gray to tan silty mudstone and siltstone. No stain, cut or fluorescence. Highly variable dips ranging from 5° to 70°. Core #8: cut 11,263.0' to 11,270', recovered feet (in Aluminum liner) 11,263.0' - 11,268.6' gray to tan silty mudstone and siltstone. No stain, cut or fluorescence. Highly variable dips ranging from 0° to 40°. CONFIDENTIAL CONFIDENTIAL ,,IAY 0 Alaska Oil & Gas Cons. Commission Anchor~ , Wireline Logs: BADAMI #5 LOGGING RUNS °0. 1/25/95 Run #1 Descent 1 DI::T-E-SDT~-~AMS (110'-4499') 2/1/95 Run #2 Descent 1 M ~~¢'-A'Ms~4580'-5083') 2/9/95 Run #3 Descent 1 Descent 2 DIT/E-DSI~L-GCI-AMS (4490'-9554') ~;:O~-i3~AMS (4490'-9533') 3/8/95 Run #4 Descent 1 Descent 2 Descent 3 Descent 4 AI~rC-D,evFM~'~GR-AMS (9570'-11524') IP.,I::..EP-T..-HNGS (9570'-11326') Drill Pipe Conveyed FMNGR"(9570'-11370') Drill Pipe Conveyed Mg--T-GR-A~S (9764.5'-11248') Drill Pipe Conveyed 3/12/95 Run #5 VSP (3000-11420') CET-CBT-GR (over 7" liner interval) Meaurement-While-Drilling Logs: Directional only: Surface to 6220' MD- Directional plus Resistivity/Gamma. Ray: 6220'- 9578' and 10489'- 11459' Directional plus Resist-ivfC¢/GR pq'~uu~ Neutron Porosity/Density: 9578'- 10489' MAY 1 0 ?o,c,,~ Oil & Gas Cons. Commission Anchors" Badami #5 Production Test Data DST #1 Perforation Interval: 11,140'- 11,260' MD Date of test: 3/16-19/95 Hours Tested: 25 (flowing) Production for test period: Oil- 1169bbls Gas - 464mscf Water - 0 bbls Choke Size - 30/64" Gas-Oil Ratio - 380 Flow Tubing Pressure - 690psi Casing Pressure - 2200psi Calculated 24-hour rate (based on stabilized flow period): Oil- 1660bbls/day Gas - 630 mscf/d Water - 0 bbls/day Oil Gravity - APl (Corr): 26° CONFIDENTIAL DST #2 Perforation Interval: 10,700' - 10,810' Date of test:2/23-26/95 Hours Tested: 33 (flowing) Production for test period: Oil - 480 bbls Gas - 126 mscf Water - 0 bbls Choke Size - 30/64" Gas-Oil Ratio - 240 Flow Tubing Pressure- 180psi Casing Pressure- 2300psi Calculated 24-hour rate (based on stabilized flow period): Oil - 380 bbls/day Gas - 90 mscf/d Water - 0 bbls/day Oil Gravity - APl (Corr): 20° Perforations were shot at 4975' - 4989' (DST #3) in order to obtain a representative clean sample of formation water from this zone. The form. fluid was successfully gas lifted, obtaining a P-V-T sample in a bottomhole sampler but no flow rate information was required or obtained. RECEiVJ D Alaska 0il & (~as Cons. Commission Anch0r~- Badami #5 Daily Operations Diary4 Report Days MD/ MW Daily Summary Date since TVD (ft) PPg spud 1/12 -1 -/- - Suspended PBU well P-7. Continued to prepare Badami #5 location. 1/13 -2 -/- - Upgraded rig PVT system (Non-Badami AFE work). Ice pad and road ready for move. Alaska Telecom and Veco moved in to start on tower and well cellar/conductor installation 1/14 -3 -/- - Cont. on rig with PVT system installation. Dig hole for cellar, free water encountered at mudline. 1/15 -4 -/- - Completed PVT system installation. Attached vent piping to exterior of Badami cellar and fabricated 48" drive pup for piling hammer. 1/16 -5 -/- - Drove 48" joint to 15' below mudline. Set well cellar and pumped 86bbls of cement into base of cellar to attempt to seal floor. Cleaned out 48" joint and new hole to 30', encountering more free-water. Rigged up to drive conductor, set 40" insulated sleeve joint to 20' below mudline. Rigged down on P-pad and began moving modules to Badami #5. 1/17 -6 -/- - Drove 30" conductor to 100' below mudline. Backfilled cellar box with ice chips and freezed in, vent pipes operating. Moved rig camp to Badami location. Substructure, boiler and motor complexes on ice road. 1/18 -7 -/- - Cemented 30" x 48" annulus and cellar floor w/34 bbls cement. Tidied up cellar area and graded for substructure. Moved subbase onto location, pinned and raised derrick. 1/19 -8 -/- - Spotted substructure and all complexes. Hooked up lines, mud-logging equipment and rig floor. Accepted rig for Badami operations at 1500hrs 1/19/95. 1/20 -9 -/- - Welded on 30"x 20" landing ring housing and baseplate to conductor, cleaned out cellar of ice/water. Nippled up diverter. Rigged up mudlogging unit and equipment. Continued general rigup. Completed installing communications in camp. i/21 -10 -/- - Nippled up diverter line, continued with mud logging equip. ri§up. Loaded and strapped BHA in shed. 1/22 1 1215' 9.1 M/U and tighten kelly, P/U BHA, Perform pre-spud 1215' environmental checklist and pre'spud/tight hole meetings. Cleaned out 30" conductor w/16" bit. Spudded at 1200 hrs 1/21. Drilled and surveyed to 1215'. :1/23 2 2607' 9.0 Drilled to 1500'. Short tripped and POOH to inspect/adjust 2607' drawworks couplers. Bit not worn, rerun, RIH to 1385'. Drilled to 2607. ROP ~ 100 fph. A!~,ska Oil & Gas Cons. Commission Anchor~' *'fi,,. 1/24 3 4502' 9.4 Drilled to 2792'. Changed out swivel packing. Drilled 4502' 3005'. Short tripped, hole condition good. Drilled to 3950'. Torque increased at 3300'. ROP reduced to --40 fph at 3300'. Offset info. indicated that reduced ROP was formation related (increased clays). First shelf sand came in at 4100'-- ROP - 125 fph from 4100' to 4350. Casing point picked at 4502' based on offset log (shaley area 300' above second shelf sand.). Cuttings indicated presence of clays around 4500' for a competent shoe. Short tripped to 3000'. RIH. 1/25 4 4502' 9.4 CBU. POH. Rigged up Schlumberger and ran open hole 4502' logs -- SP/GR/DIL/LSS. No problems logging. Phase 3 weather conditions -- 6 hours WOW and for road to be cleared for BJ cementers and vac trucks. Performed wiper trip due to weather delay, hole condition good. Circulated and POH to run casing. 1/26 5 4502' 9.3 Ran 13-3/8, 68#, NT80-CYHE, BTC casing. Hit bridge at 4502' 2010, base of permafrost. Broke circulation. Casing ran in slowly from 2015' - 4412', landed successfully at 4495'. Cemented with 75 bbls water pre-flush, 300 bbls lead slurry, 87 bbls tail cement. Bumped plug, full returns, no cement to surface Performed top job from 80' with cement to surface. 1/27 6 4502' 9.0 Nippled down 20" diverter. Installed 10M wellhead. Nippled 4502' up 10M BOPE. Rig up slow due to size of equipment, need to assemble stack from individual pieces, de-freezing stack. 1/28 7 4502' 8.6 N/U choke line. Many problems due to lack of planning (of 4502' contractor) including: 10M choke line was not long enough and lost in snow drift, had to remove wheels and gooseneck on sub to get choke house close enough, had to construct and weld 2 flange to gray lock spools, XO spool, 5000# downstream choke line, panic line tee and flange , 1/29 8 4502' 8.6 Tested BOP stack. Completed rigging up choke manifold and 4502' tested. Blew down choke lines and freeze protected. RIH w/ 12-1/4" MSDSSHODG on pendulum BHA. 1/30 9 5001 9.1 Pressure tested 13-3/8" casing to 3000# for 30 minutes with cmt. unit. Drilled out cement, plugs, 10' new hole to 4512'. Performed 12-1/4" leak-off test: leak off @ 650 psi surface pressure, LOT = 11.8 ppgEMW. Conditioned mud to lower water loss. Drilled to 5001'. Short tripped to shoe" noticed 25-50K drag (lots of clay). 1/31 10 5100' 9.1 POOH & R/U Schlumberger. Ran MDT tool, but unable t° get 5099' past 4710'. Goal was to test sands @ 4850'. Set MDT tool at 4588', 4665', 4462', 4593' 4708' & 4716', but probes plugged up. POOH w/tool. Decided to perform wiper trip and drill to 5100' in hope of reaching cleaner sands. RIH. At 4608', drag increased and took 20K weight. Washed and reamed from . 4608' to 5001' Drilled 12 1/4" hole to 5100'. ~AY 10 A~ska 0il & Gas Cons. C0mmis$i0r~ 2/1 1 1 5948' 9.2 POOH & R/U Schlumberger. Ran MDT tool to bottom -- 5920' clean. Pressure sets obtained at 4982', 4825', 5084'. Tool pretest indicated good sample area, but probes plugged off repeatedly when attempting to take sample. All attempts unsuccessful. POOH w/tool. PU mud motor with same bit (mill tooth) and began kick-off. Drilled to 5920'. 2/2 12 6220' 9.7 Drilled 12 1/4" hole to 6113'. Short tripped 11 stands -- some 6153' tight hole, swabbing. Drilled to 6220'. POOH and changed bit (worn teeth) to insert bit. Hole in good shape. 2/3 1 3 7222' 9.7 Drilled 12 1/4" hole to 7222'. 6979' , 2/4 14 7820' 9.8 Drilled 12 1/4" hole to 7820'. Circulated lo-hi vis sweep, 7475' POOH for bit change to PDC bit, PU tandem motor. 2/5 15 8638' 9.8 Drilled 12 1/4" hole to 8355'. MBK 90 marker @ 8331'. 8151' Building angle while rotating. Drilled to 8638'. Good ROP w/ PDC -- 80 fhp, 20 fph sliding. 2/6 16 9145' 9.9 Drilled 12 1/4" hole to 8737'. Short tripped to 7700', tight hole 8601' from 8250' to 7800', but no swabbing. No problems while RIH. Drilled to 9145' 2/7 17 9193' 9.9 Drilled 12 1/4" hole to 9193'. Lost 500 psi standpipe 8632' pressure. Found washout in box of 4th joint of 5" HWDP. POOH and changed bit (worn teeth, broken cutters). Test BOPE. PU insert bit and RIH w/same BHA. Inspected 5" HWDP, found 5 bad joints. 2/8 18 9578' 10.1 Drilled 12 1/4" hole to 9578' TD per geologist, 100' above 8910' shallowest possible depth of Badami reservoir sands, still in good shale for shoe. Raised MW to 10.1ppg in response to ... possible increasing pore pressure trend during last 200'. 2/9 19 9578' 10.1 CBU, short trip, CBU, POOH. Hole in good condition. Ran 8910' open hole logs: 1st-- DIL/DSI/GR.MLT 2nd: -- AMS/TCC/GR/CNL/LDT. Hole in good condition. 2/10 20 9578' 10.1 RIH for wiper trip. CBU. Shorttrip 10stands. cBu. POOH. 8910' Good, clean wellbore. Began to run 9 5/8" 47# Pl10, BTC- MOD casing. 2/11 21 9578' 10.1 RIH w/9 5/8" casing. Casing went straight to bottom -- very 8910' slick hole. ReCiprocated w/P/U wt: 395K, S/O wt: 325K lbs. Lost traction motor prior to cementing, unable to reciprocate. Cemented with 50 bbls spacer, 164 bbls Class G Neat cement. Bumped plug w/3000 Fsi. WOC. 2/12 . 22 9875' 12.0 WOC before picking up on casing. Work on choke manifold. 8910' P/U casing to 425KIbs. Set casing slips. Cut and smooth grind 9-5/8" casing stub. Weight up mud system to 12.2 ppg. 2/13 23 9578' 12.2 Install 9 5/8" packoff. Test to 4000 psi. NU BOPE. X-ray, test 8910' new weld on choke line. Test choke manifold and BOPE to 7500/250 psi. Test Hydril to 3500/250. Blow down and ? ~. (~-- ~..., ..,.~i '~ freeze protect choke. P/U new BHA: 8 1/2" M15 bit ,, t~ ~ ~ on 1.25° motor. Circulate and condition mud to 12.2 ppg. 2/14 24 9607' 12.2 Pressure test casing to 4000 psi. Drilled cement, float 8972' equipment, and 8 1/2" hole to 9589'. Performed leak-off test: LOT: 18.0 ppgEMW. Drilled 8 1/2" hole to 9607', average ROP: 6 fph. 2/15 25 9795' 12.2 Drill 81/2'' hole to 9623'. POOH for LWD failure. P/U 8 1/2" 9139' M85P PDC bit and 1.25° mud motor. RIH. Drill 8 1/2" hole to 9795'. 2/16 26 9795' 12.2 Drill 8 1/2" hole to 10,009'. 400 psi pressure loss, POOH 9475' looking for washout. Locate washout in 55th joint of drillpipe. RIH, drill to 10204'. Hole in good condition. Background gas ..... increase noted below 9990' with formation change. Average ROP w/PDC: 24 fph. 2/17 27 10489' 12.2 Drill 8 1/2" hole to 10,489, core point picked by geologist. 9711' LWD failure at 9675'. CBU. Short trip to shoe. WOW to open road for vac. trucks containing bland coring fluid. 2/18 28 10489' 12.2 Cleaned pits and injected old mud down 9-5/8" x 13-3/8" 9711' annulus. RIH to btm. Pumped 100bbls spacer followed by coring fluid. Circ. & cond. coring fluid, barite had dropped out " somewhat during transportation' 2/19 29 10498' 12.2 C&C mud. Added Xanvis polymer to coring fluid to obtain 9720' required gel strengths. POH, L/D bit and picked up core barrel. RIH, hole good. Cut core #1' 10,489'- 10498' P. rate +/- 2ft/hr. 2/20 30 10550' 12.2 Core barrel jammed off. POH, laid out 9' of core. RIH with 9760' drilling assembly. Drilled to core point at 10,550', POH. 2/21 31 10553' 12.2 POH. Tested BOPE. RIH with core barrel. Cut core #2 9763' 10,550'-10,553'. P. rate 2ft/hr, slowed and then quit coring. Jammed off? POH. 2/22 32 10573' 12.2 POH. Recovered 1' of core. RIH wit'h coring assy. Cut core #3 9780' 10,553'-10,573'. P.rate 2ft/hr. Stopped coring on geol. orders. POH. 2/23 33 11005' 12.3 POH with core #3. Recovered 20ft core. M/U drilling assembly 10111' & RIH. Drilled to 10644'. CBU for sample, high gas. Drilled to 10778'. CBU for sample, high gas. Drilled to 10895. CBU for sample, high gas. Drilled to 10912', CBU for sample, high gas. Drilled to 11005'. 2/24 34 11024' 1.2.5 Drilled to 11016'. CBU for sample, high gas reading but lower 10125' than previous 200'. Short tripped to shoe, hole good. POH. P/U 60' core barrel. RIH, cut core #4 11016'- 11024'. Core barrel jammed. CBU. POH. 2/25 35 11113' 12.5 POH with core #4. Recovered 6' of core. RIH with drilling 10197' assembly. Drilled to 11113'. CBU for sample. POH for core barrel. 2/26 36 11143' 12.5 RIH with 30' core barrel. Cut core #5 11113' - 11143'. CBU. 10219' 2/27 37 11188' 12.5 POH w/core #5. Recovered 25.2' of core. RIH w/60' co're 10254' barrel and SC-712 core bit to 11105'. Wash to bottom 11143'. Core to 11188'. 2/28 38 11203' 12.6 Core to 11203' at 60' in 16.2 hrs. CBU. POH w/core #6, "'-/I/;~ 10267' recovered 60' core. Test BOPE. Pick up core bit and RIH to11164'. Wash and ream to 11203'. CBU. 3/1 39 11263' 12.5 Core to 11263'-- 60' in 17.7 hrs. CBU. POH w/core #7. 10314' Recovered 60' core. RIH w/same core bit. 3/2 40 11270' 12.5 RIHto 11225'. Wash to bottom 11263'. Coreto 11270'i 10320' Unable to get core bit to drill off in last hour. Core jammed off. -- cut 7' in 5.5 hrs. CBU. POH w/core #8. Recovered 5.5' core. PU 8.5" PDC bit and BHA. RIH to 11072'. wash, ream and MAD pass w/LWD f/11072' to 11270' bottom. 3/3 41 11549' 12.5 Drill 8 1/2" hole to 11518'. CBU, wait on geol. orders. Drillto 10552' 11549' TD. CBU. Short trip to 9 5/8" shoe. Hole tight and swabbing from 11360' to 11040'. CBU. POH for logs. Hole in good shape. Rig up wireline. RIH w/AlT/Dipole/MIL/GR. Logged from WLTD 11526'-10290'. Hole tight at 10585', 10526', and stuck tool at 10280'. Pulled 5K on tool, freed in 45 min. POH w/logging tools to make wiper trip. 3/4 42 11549' 12.6 PU 8 1/2" bit and BHA. TIH to 9954'. Wash and ream to 10552' 10720'. CBU. RIH to 11549'. Circ. Short trip to shoe. RIH to bottom. Had 15K drag @ 10000' & 10155'. Circ. lo-hi vis sweep. POH for logs. RIH w/EPT/IPLT/HNGS logs. Tools set down at 9655' and became stuck. Held 5KIbs tension for 30 minutes and tool pulled free. POH w/tools. Removed bowspring centralizer and reran tools. Logging tool set down at 9630', pulled free in 15 min. POH w/tools. 3/5 43 11549' 12.6 PU 8 1/2" bit and RIH for wiper trip. Hit bridge at 11395'. 10552' Wash and ream to bottom @ 11549'. Pump lo-hi vis sweep. Short trip to shoe - hole in good shape. CBU. POH to run DP conveyed logs. RIH w/logging tool on 5" DP. RIH to 9318'. RIH pumping down wireline probe, and latch up. RIH w/ logging tools. 3/6 44 11549' 12.6 RIHw/Ioggingtool, would not go past 11377'. POOHw/DP 10552' logging open hole from 11355'-9570' w/EPT/IPLT tools. Wiper trip. Hole tight f/11385'-11449'. POOH. 3/7 45 11549' 12.6 RIH and log from 11392'-9570 w/DP conveyed 10552' Schlumberger FMI tool. Wiper Trip, no problems. POOH. RIH w/Schlumberger MDT tool. 3/8 46. 11549' 12.6 Repair MDT tool. RIH w/MDT on drill pipe. Log up w/DP and 10552' MDT tool, making 26 sets w/tool from 11340'-9790'. 3/9 47 11549' 12.6 POOH w/MDT. Test BOPE. Wiper trip, no problems. Circ 10552' and cond mud for 7" liner A~ska Oil & Gas Cons. Commi~si0n Anchor~ 3/10 48 11430' 12.6 RIH w/56 jnts of 7" 29# NT110HS NSCC casing on 5" PBTD drillpipe to 11549', circulating at the shoe. Reciprocate pipe while mixing/pumping cement. Pump 20 bbls water, 70 bbis 14.0 ppg MSC spacer, 144 bbls 15.7 Type "G" cement. Drop plug. Displace mud to landing collar with 235 bbls. Bump plug, and set hanger at 3500 psi, liner top packer at 4500 psi. Held pressure for 2 min., lost 2000 psi. Appeared landing collar sheared out insert. Had 30 bbls cement return to surface while rotating off top of liner. POOH w/running tool. 3/11 49 11430' 12.6 Clean out 7" liner to 11430'. Test liner and liner lap to 4000 PBTD psi. POOH. 3/12 50 11430' 12.6 Run VSP log. POOH. R~nCBT/CETIog. POOH. Change PBTD BOPE rams. 3/13 51 11430' 12.6 Continue to change BOPE rams. RIH w/3 1/2" tubing. PBTD 3/14 52 11430' 12.5 Thaw out frozen mud line. Circulate and condition mud for PBTD DST #1. Pressure test 3 1/2" tubing. M/U 4 1/2" perf guns and DST tools. 3/15 53 11430'' 12.6 RIH w/3 1/2" test string, perf guns, and DST tools. Run PBTD GR/CCL log to position guns on depth. Space out DST string. Pressure test lines, tubing. 3/16 54 11430' 12.6 Pressure test tubing to 6,500 psi. Set packer. Pressure test PBTD all DST surface equipment. Displaced tubing to diesel. Fired perf guns. Flow well. 3/17 55 11430' 12.6 Flow well. Shut-in for initial PBU. Open-up well for main flow PBTD period. , 3/18 56 11430' 12.6 Flow well. Shut-in for main PBU.. PBTD 3/19 57 11430' 12.6 Well shut-in. Fow well to obtain bottom-hole PVT samples on PBTD wireline. End test, kill well. 3/20 58 11430' 12.6 Circ. kill weight mud around hole. POH with test tubing and PBTD tools. Lay down tools and guns. 3/21 59 11,090' 12.6 RIH with tubing & set 7" bridge plug at 11,090'. Circ. & cond. PBTD mud. POH. Pressure test BOPE. 3/22 60 11,090' 12.6 Test BOPE, repair HCR valve. RIH w/test string and pert= PBTD guns for DST #2. 3/23. 61 11,090' 12.6 RIH with test string. Run GR/CCL to position guns on depth. PBTD Space out DST string. Pressure test tubing and all surface equipment. Circ. tubing to diesel. Fired guns. 3/24 62 11,090' 12.6 Flow well. Shut-in for initial PBU. Open up well for main flow PBTD period. 3/25 63 11,090' 12.6 Continue main flow period. Shut-in well for main PBU. ' PBTD 3/26 64 11,090' 12.6 Complete main PBU. Flow well to obtain bottomhole pVT PBTD samples on wireline. 3/27 65 11,090' 12.6 Recover PVT samples. End test. Kill well. POH with DST PBTD tools. RIH with tubing and mule shoe sub. , t985 Aiaska .Oil .& Gas Cons. Commission , Anch0rr ,,~ 3/28 66 11,090' 12.6 RIH with tubing to 11,090'. Lay 600' balanced cement plug PBTD (109sx G Neat) above bridge plug at 11,090'. Pulled above plug, circ. tubing clean. WOC. 3/29 67 11,090' 12.6 RIH to tag cement top. Tagged top of cement at 10,722', too PBTD deep (in perf. interval). Pump second 600' balanced plug (Plug #lA- 109sx G Neat). Pulled above plug, circ. tubing clean. WOC. 3/30 68 10,397' 12.6 RIH to tag cement top. Tagged top of cement at 10,397'. POH PBTD to 9,380' for plug across liner top. Pumped Plug #2, 87sx G Neat. Pulled above cement top and circ. tubing clean. POH with tubing. Pressure tested Plug..~2 to 1,000psi. Rig up wireline. Perforate 9-5/8" casing 5050'- 5056'. 13-3/8" x 9- 5/8" annulus pressure increased to 850psi confirming communication. 3/31 69 5040' 9.2 Run 9-5/8" cement retainer on wireline and set at 5040'. R/D PBTD wireline. P/U stinger and 5" drillpipe, RIH to cmt. retainer. Circ.well to 9.2ppg brine. Sting into cement retainer, circ. 9.2ppg brine around 9-5/8" annulus, pumped 476sx G Neat slurry through retainer into 9-5/8" x 13-3/8" annulus. Unsting from retainer, POH. Change out bottom rams to 5". Test BOPE. 4/1 70 5040' 9.2 WOC before perforating. R/U wireline. Perforate 9-5/8" casing PBTD 4975'- 4989'. R/D wireline. Run tools and drillpipe for DST #3 (water zone test). Set packer at 4880'. Rig up nitrogen line to wellhead and pressure test. Pump nitrogen down annulus to unload well and gas lift formation fluids. 4/2 71 5040' 9.2 Continue gas lift operation. R/U slickline unit, run bottomhole PBTD samplers to obtain PVT samples, continue to gas lift well. Recover samplers 4/3 72 4925' 9.2 Change out orifaoe valve in GLM for dummy valve. Close PBTD tester valve, unseat packer, kill well. POH with test tools. RIH with cement retainer on DP. Set retainer at 4925'. Inject fluids downhole, pumped plug #4, 65sx G Neat. Unsting from retainer, circ. tubing clean, POH laying down 5" DP. Pressure test retainer to 1,000psi. P/U 9-5/8" casing cutter. Cut 9-5/8" casing at 255'. 4/4 73 65' 9.2 Recovered 9-5/8" casing. Pushed 13-3/8" wiper plug to 255'. ' POH. Pumped Plug #5, 151sx Coldset II slurry. Washed out cement to 65'BRT. POH. P/U 13-3/8" cutter. WOC. '~t/5 74 65' 9.2 Cut 13 3/8" casing at 60'BRT. Cut 30" casing at 60'. Broke down BOP and removed from cellar. Cut off wellhead.. Recovered 13-3/8" casing, 30" remained in ground. Dig out cellar to cut 20" x 30" adaptor. 4/6 75 65 NA Completed cleaning out cellar. Pulled 30" conductor to surface. 4/7 76 65' N/A Recovered 60' 30" conductor. Pulled 34" insulated pipe and 65' 48" pipe free and lay down. Oil & Gas Cons. Commission Anchors 4/8 77 N/A N/A Clear cellar area, empty fuel tanks, pump off all excess from rig. Remove beams from around rig. Moved pipe shed 'oft location. Moved all complexes off well. Rig released at 24:00hr$ 4/'//95, 4/9 78 N/A N/A Lower derrick and remove from sub-base. Move rig complexes down ice road. Commence pad clear-up operations. A!as 'ks Oil & 6as Cons. Commission ~ ICE PAD LIMITS (500' X 500')VICINITY MAP __ ~Jjj~ __ N.T.S. RECEIVED MAY i 0 1~55 Alaska 0il & Gas Cons. Commi~8ion gnchor~ NOTES LEGEND 2. REFERENCE FIELD BOOK BAD95-01 (pgs. 7 THRU 9). 4. HORIZONTAL CONTROL IS BASED ON 1993 GPS SURVEY POSITIONS OF CONTROL POINTS "BADAMI-E" AND "BADAMI-D". (YUKON GOLD SURVEY) SURV[YOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM LOCATED WITHIN PROTRACTED SEC. 5, T. 9 N., R. 20 E., U.M., AK. PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING WELL A.S.P. PLANT GEODETIC GEODETIC , SECTION CELLAR THE STATE OF ALASKA AND THAT NO. COORDINATES COORDINATES POSITION(DMg)~POSITION(D.DD)~OFFSETS BOX ELEV. THIS PLAT REPRESENTS A SURVEY ' MADE BY ME OR UNDER MY DIRECT Y= 5,909,872.41 N. N/A ~ 70'09'41,073" 70.1614092' 1936'FSL N/A SUPERVISION AND THAT ALL 5 X= 359,186.17 E. N/A J147'07'58.242" 147.1328450' 4878'FEL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF dANUARY 19, 1995 , P' ~q~e~ DRAWN: SiNNETT DRAWINg: BADSAB B A D A M I ~ o CONDUCTOR AS-BUILT 0 /24/95 ORI~NAL AS-BULT ISlE "S ~"~ ........~ WELL ~5 NO, DA~ , RE.SION BY CHK ~o~ ~L~ ~J~ 1"=200' WELL A.S.P. PLANT GEODETIC GEODETIC SECTION CELLAR NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) OFFSETS BOX ELEV. Y= 5,909,872.41 N. N/A 70'09'41.073" 70.1614092" 1936'FSL N/A .5 X= 359,186.17 E. N/A 147'07'58.242" 14-7.1328450' 4.878'FEL BADAMI #5: PLUG AND ABANDONMENT MUD LINE @ 37.7' MD Cement Plug #5: (255' - 65' MD) 13-3/8" 68# NT-80CHYHE BTC Casing @ 4495' MD Cement Retainer @ 4925' Perforations 4975'- 4989' Cement Retainer @ 5040' Perforations 5050' - 5056' 9.2PPG BRINE Cement Plug #4: (Squeeze 4925'- 4989' MD) Cement Plug #3: (In Csg: 5056' - 5040' MD) (In Annulus: (5056' - 3495') 12.6PPG MUD All cement plugs G Neat formulation, except surface plug, Coldset II 7" Hanger @ 9279' 9-5/8" 47# P110 BTC-Mod Casing @ 9578' MD Perforations 10,700' - 10,810' Bridge Plug @ 11,090' Perforations 11,140'- 11,260' 12.6PPG MUD Tagged w/20KIbs J_._BBTD 11430'MD I _ _ 7" 29# NT-110HS, NSCC Casing @ 11,549' MD Cement Plug #2' (9380' - 9080' MD) RECEIVED fvlAY "t 0 A!~s[~a 0ii & Gas Cons. C2m,,nission ,Anchor: ,: Cement Plug #1 & #lA: (11,090' - 10,397'MD) ALL OBSTRUCTIONS CLEARED TO A DEPTH AT LEAST 15' BELOW MUD LINE. 9 5/8" CASING . CUT AND PULLED FROM 255' MD. 13 3/8" CASING. CUT AND PULLED FROM 60' MD. 30" CASING. RECOVERED. 34" INSULATED SLEEVE. RECOVERED. 48" CASING. RECOVERED. TRS 4/7/95 ANNULAR INJECTION DATA ENTRY SCREEN Asset .Ey4~lo~[aQo~ ........................... Legal Desc .193.6.:ESL...4~7.8:EEL,..SP.c...5,T.9~,..B2D~_ ........................... Research Rig Name ~lab~3r.s...l~SE .......................... · ..................................................................................................................... CD-BB. EG]'F_D..CQE.Y..SLIBMI.]TJ:ED..T.O.,~:~GCC. Q~ ...... 2.~.2J~.=9.Z. .................................................................................... Inj Well Name~'~r~-~.~--~ ..................... Permit Start ..... 2_/..1..7../.9..5 .... Permit End....1.2~/~3..1._/~9.5.,.. Sur Csg Dep ..4.4.9.5. ............. · ............................................................. Cumulative Data :: ~ : Rig ::i::~:ii::iCompietion :: :Formation ::Well :Total :' ' Mud/Ctg :: : Wash:;!:; Fi~idS::i:: ::: :: :: FlUids: :; Source i Date of Well i injectiOn BADAMI 5 102/13/95 i Annulus Closed - Don't Use Well Daily Data iMud, Ctgs~ Cm~ i ~ ' Inlermiltant i i C°ntaminated i i RigWash i: Completion!'' F°rmation i Freeze: i DrlgMud. i FlUids: i Fluids i Fluids i prOteclion Freeze i:::: :D,~ilY: i: : :: · .i AnnUus : : !::Pr°tection !: ::TOtal : i: ::Rate i Pressurei slatus Jc0rm~n~sCorr~licalJons 1125 i Closed i lnitial Freeze Protection __i140 i -- __!1,26~I ---i4. bpm, 700 25 j250 j ~Freeze protect after annulus cmt job for DST Outer annulus closed w/cement plug across i ~~i~i ~the top (66'-255') and lO00'~ement R~ug _ i ~ ~from i 3495'-4495' ~ I i ~ i --I ! . I . BADAMI 5 102/17/95 BADAMI 5 102/18/95 BADAMI 5 102/22/95 BADAMI 5 103/31/95 --i --i 140 i 1,269 [100 -- i i125 125 rod u cti o nTe sti n g $ e rvi c e s WELL TEST REPORT ,,,, · ,, ~ · m --ii i ,ill ~11~ iiiilll, III III I I I ~J' I I II I lip II II III i ~ ~ ii i ,~1 iii ii i ~ II ......... I II I I Illl I I . ~ '~? - IIIII II III1' .......... ........... 11111111 III II I I IIII Well Name: Well Location: Company: Test Date: Badami 5 Badami BP Exploration (Alaska) March 15- March 19 1995 April 1995 MICROFILMED ~,. I/~,,~.l ...... 100TH AVE. ANCHORAGE. ALASKA 99515 (907) 344-2024 FAX (907) 344-2022 rod u cti o nTe sti n g S e rvi c e s CON i Test Summary COMPANY: DP EXPLORATION WELL NO. · ~i ,, LOCATION : BADAMI TEST NO. ' I , , ZONE NO. : LOWER ZONE TUBING : 3.5 CASING SIZE : PACKER TYPE : CUSHION COMP.: DIESEL TOTAL DEP'FH PERF INTERVAL ; TOTAL FI.OW TIME: 19:25 AVERAGE i-120 : AVERAGE Q GAS : 1405 AVERAGE GOR : 382 AVERAGE Q OIL :625 AVERAGE GLR : TOTAL PROD. OIL : 1169.13 TOTAL PROD. GAS: OIL GRAVITY : 26 GAS GRAVITY : ~.820 TOTAL PROD. LIQ.: ! 169.47 FLOW RATE INITIAL FROM: 0448 .... TO; 1035 TOTAL TIME : 5.87 HRS AVERAGE FTP : 1232 AVERAGE VIT : 44,:i AVERAGE Q OIL : 825 AVERAGE Q GAS : 403.6 AVERAGE Q 1-120 : 0 AVERAGE GOR :489.1 AVERAGE GLR : AVERAGE BS&W : OIL GRAVITY : GAS GRAVITY : CHLORIDE : .800 pH : % H2S : 0 % C02 : 0 RESITIVITY : PRODUCED Q GAS : 44 MMLF PRODUCED Q OIL : 199.79 . PRODUCED Q 1-120 : TOTAL PROD. LIQ : 199.79 DATE: 3/16-17/95 PACKER DEPTH : 11073 TUBING CUSHION FT. : AVERAGE WELLHEAD PS! : 935 FTP INITIAl. WELUIEAD PS! : 1800 SHUT-IN WELLHEAD PSI : 2500 TOTAL PROD. H20 : .34 CHLORIDE :~ FI.OW RATE #FINAL FROM: 1935 TO: 1500 TOTAL TIME : 19:2~ HRS AVERAGE FTP ; AVERAGE FTT : AVERAGE Q OIL : AVERAGE Q GAS : 625 AVERAGE Q I-[20 : .... AVERAGE GOR : 382 AVERAGE GLR AVERAGE BS&W : OIL GRAVITY : 26.0 GAS GRAVITY : .820 CHLORIDE : PH :. % H2S : % CO2 : O RESITIVITY PRODUCED Q GAS : 464,14 MMLF PRODUCED Q OIL : ! ! 69.13 PRODUCED Q H20 : TOTAL PROD. LIQ : 1169.47 COMMENTS: Pressured up on tbg ~ 04:28 to fire guns. Guns fired at 04:41 tbg climbed from 1100 to 1800 psi in about 30 seconds. At 04:43 tbg ~ 20:50, ~)4:44 opened adj. choke on 10/64, to separator, 05:00 increased choke to 15/16, 05:l0 opened manitbld on full bypass using heater choke, 10:35 hr shut in tool tbr initial build-up, 19:30 hr pressure up csg to open test tool, 19:31 hfs tool open, 19:34 opened choke slowly to 15/16 on manitbld, 19:55 safety system shut in, 21:02 reopened surface valve, 23:00 installed positive 30/64 choke in manifold. 3/I 7/95 05:41 ESO shut in, 06:35 reopened well, 08:27 stopped Chemical injection of defoamer, 15:00 closed down hole test tool shut in for final buildup. I OOTH AVE. ANCHORAGE, ALASKA 9951 5 (907} 344-2024 FAX (907) 344-2022 rod u cti o nTe sti n g $ e rvi c e s CONFiD OPERATIONS LOG tstomer: BP Exploration ell No. 5 Tests: PTS SUPERVISORS: Dst #1, Lower, Dst #2, Upper, Dst #3, Water M. Hewston C. Garrett Schlumberger start in the hole with the guns. test tools and packer Schlumberger on bottom with the test tools PTS open by-pass on choke manifold so BJ can pump glycol for pressure testing BJ start pumping BJ shut down BJ fix leak in their flow line PTS has glycol to the heater, and test to 5000 psi PTS flow line tested PTS close manifold to test the manifold and the flow lines to 6500 psi, upstream side of manifold Manifold at 6500 psi Test BJ check valve on the kill line iCheck valve complete pressure test Start the function test of the safety system and all of the ESD stations All of the PTS ESD boards tested with a average shut down time of 4 seconds Install Flow head cap on the flow head so the diesel cushion can be displaced Cap didn't test being pulled off and repaired Schlumberger cycle tool so the diesel can be displaced BJ start pumping diesel 45 bbls of diesel displaced the pressure at 2130 psi 67 bbls of diesel displaced tbj pressure at 3000 psi 68.18 total bbls of diesel displaced tbg pressure 3018 psi Schlumberger close MIRV tool PTS open manifold to bleed pressure down to 2500 psi PTS bleed tbg down to 2000 psi Shut in tbg at 2500 Schlumberger close PCT Pressure up scg to cycle tool, csg pressure to 2000 psi Bleed off csg to close tool Schlumberger up csg to open PCT at 2300 psi, tbg at 2050 BP Exploration will conduct a safety meeting with all of the service companies and rig hand that will involved in the test Safety meeting is over prepare to perforate the guns Pressure up on the ttxj to fire the guns 6200 psi for the initial flow period of test #1 PTS open choke manifold on the adjustable choke to bleed the tbg pressure down to 1100 psi Schlumberger guns fired pressure on the tbg rose to 1800 psi in 20 seconds tbg at 2000 psi tbg at 2050 psi PTS open choke manifold on the adjustable to 10~64 5.61 total bbls recovered at this point PTS has recovered 3.36 bbls at this point of the initial flow period flowing direct to test tanks PTS increase adjustable choke on the manifold to a 15164 5.61 total recovered at this point PTS close manifold to fix a leak on the down stream side of the manifold PTS reopen the manifold and continue to flow the well on a 15164 choke setting tbg at 1600 psi PtS open choke manifold on bypass and do the well control at the adjustable choke on the heater 38.43 bi)Is recovered at this point of the test still flowing back the diesel cushion PTS is registering gas at surface, preparing to put well into the surge tank 100TH AVE. ANCHORAGE. ALASKA 99515 (907) 344-2024 FAX (907} 344-2022 rod u cti o nTe sti n g $ e rvi c e s OPERATIONS LOG ~stomer: BP Exploration ell No. 5 PTS SUPERVISORS: M. Hewston C. Garrett PTS start flowing well into the surge tank so we can flare off the gas in a safe manner !Diesel cushion appears to be over and we are seeing mud returns that is 68 bbls of diesel cushion PTS is encountering heavy choke plugging at the heater going to switch back to the rig floor on our choke manifold. PTS will set the choke on a 20164 PTS bypass heater choke is plugged off PTS switch from the surge tank to the separator gas and fluid volumes are getting strong enough for the separator tbg at 1200 psi Schlumberger bleed off csg to close the tool for the INITIAL shut in period. PTS has also shut in the choke manifold to retain pressure on the tbg to verify that the tool is closed. PTS repaired choke on the heater it was plugged off with perforating debris PTS put choke Pressure test of the heater choke was successful, witnessed by BP ENG. and Drilling Foreman PTS cleaning up from the initial and preferring for the final flow period Schlumberger pressure up on the csg to open the PCT to start the final flow period of test #1 Csg at 2200 psi and the tool has opened PTS creep open the adjustable choke to a 15/64 ESD shut in well. at the surface PTS pull pilot and check out the calibration Everything was correct Schlumberger reopen surface safety valve PTS open choke manifold on a 20164 PTS increase choke setting to 25164 PTS open choke bypass to control the well at the heater see well test date for further information on flow rates ESD trip and shut in surface safety valve Schlumberger reopen safety valve and resume the final flow period PTS open choke manifold on the positive 30/64 PTS shut off chemical injection so Westport Lab couldn't chemical free samples, see well test date report for further information on flow rates Schlumberger bleed off csg to close PCT for the final build up PTS close choke manifold PTS is bleeding down the tbg pressure with the PCT closed to verify that the tool is closed PTS close choke manifold 7.75 bbls of fluid recovered after the tool is closed PTS off loaded the first load of oil 309.9 bbls The vapor pressure is to high to ship the rest of the oil. it will sit and let the gas escape out the vapor pressure has to be less 4psi Pressure up Atlas Wireline lubricator to 5500 psi Start pressuring up Atlas lubricator tested and held 5500 psi Schlumberger up csg to open PCT to flow the well for Expro to get bottom hole samples PCT open PTS open choke manifold tbg at 2150 psi, on 10164 Fluid at surface tbg at 1600 psi Increase choke tO 16164 Increase choke to 20164 tbg at 800 psi Increase choke to 24~64 tbg at 600 psi Open on positive choke, 30164 at 650 psi Shut in well at the manifold. Atlas Wireline begin to RIG up tools for bottom hole PTS choke manifold on a 5164 choke on the adjustable 100TH AVE. ANCHORAGE. ALASKA 99515 (907) 344-2024 FAX (907] 344-2022 rod u cti o nTe sti n g $ e rvi c e s OPERATIONS LOG , (0 NFiDENTiAL ustomer: BP Exploration ~ell No. 5 PTS SUPERVISORS: M. Hewston C. Garrett PTS recovered bbls from the flow pedod PTS shut in manifold so Atlas can come out of the hole, Expro has received the samples PTS bleed off lubricator to the choke manifold, and then to the surge tank Atlas pull lubricator and break out Expro sample tools PTS open to separator to bleed down the tbg before reversing out (R/O) Nabors stop pumping PTS light flare pilot PTS open to separate Shut in at heater Open well to Close at heater Open well at heater Shut in at Schlumberger flow head PTS bleed off Add 10' of chicksan to flow head to release tool BJ pumping PTS open to the stock tank 1 and 2 BJ stop pumping PTS close manifold at floor BJ pumping down the tbg PTS rig down surface flow line on the rig floor PTS hook up Peak vacuum truck to the surge tank and sucked it dry. PTS on standby waiting on the next est. crews doing general maintenance preparing for the next test PTS on standby waiting on the next est, crews doing general maintenance preparing for the next test Atlas Wireline complete correlating guns Schlumberger dg up flow head Nabors pull mouse hole out for PTS to run main flow line from the cellar PTS rig up surface flow lines and the choke manifold BJ pressure test surface flow lines to 5.000 psi Pressure test choke manifold to 5.000 psi Pressure test complete blow down lines to the surge tank with the test fluid Pressure test Schlumberger flow line to PTS manifold to 6500 psi BJ start to displace the tbg with diesel Schlumberger cycle the MERV valve PTS bleed off the pressure. BJ continue to displace tbg displaced with diesel BJ stop pumping BP hold a safety meeting will all of the people involved with the test on the dg floor Safety meeting over BJ pressure up on the tbg to fire the guns ttxj at 6500 psi PTS bleed tbg down to 1350 psi Schlumberger has indicated that the guns have fired. PTS DAU is monitoring the pressure build-up start of test #2 tbg at 2325 psi tbg at 2395 psi tbg at 2446 psi tbg at 2450 psi PTS open well on a 10164 adjustable choke, for initial flow period tbg at 275 psi Increase choke to 14164 Increase choke to 16164 tbg at 235 Increase choke to 20164 at 240 100TH AVE. ANCHORAGE. ALASKA 99515 (907) :344-2024 FAX' (907) 344-2022 rod u cti o nTe sti n g $ e rvi c e s ' OPERATIONS LOG Jstomer: BP Exploration ~ell No. 5 PTS SUPERVISORS: M. Hewston C. Garrett csg at 825 psi csg at 850 psi See Well test data sheet for further pressures and fluid recovery Csg bleed to 0 psi Nabors rigged up to give us 10 bbls of diesel Start off loading brine water into Peak from tank #10 265 bbls of water pulled of #10 :Start to off load 87 bbls of diesel from tank ~4 to Peak All fluid transferred to Peak Haliburton begin to r~g up test tools BJ pressure test flow string TIW Valve leaking pull off for repairs PTS rigged up surface flow lines and the choke manifold BJ pressure test flow line and manifold to 2500 psi Blow down lines to tanks Starting tank straps obtained on all tanks Safety meeting with BP to discuss the test BJ pressure up on the csg to displace the fluid up the tbg Nabors getting returns to the pits 14 bbls returned See well test data sheet for further information N2 rate at 860 scfrn BJ has leveled the N2 rate at 922 scfm fluid at surface PTS is getting sand returns BJ stop N2 BJ stop N2 BJ stop N2 BJ stop N2 BJ lost air pressure on N2 unit stop pumping BJ start pumping N2 rate at 930-40 scfm Fluid at surface Rig up wireline Pressure test Camco lubricator Camco make a feeler run Camco rig up Expro sample gauges Camco on bottom with tools BJ start N2 at rate of 930 scfm BJ stop Dumping. DST #3 water test complete PTS blow down lines waiting to rio PTS rio start the rig down procedure PTS continue to rig down PTS continue to rig down Badami #5 rigged down all of PTS equipment off the location and the crew is leaving. IOOTH AVE. ANCHORAGE. ALASKA 99515 (907) 344-2024 FAX (907) 344-2022 rod u cti o nTe sti n g $ e rvi c e s OPERATIONS LOG :ustomer: BP Exploration Yell No. 5 PTS SUPERVISORS: M. Hewston C. Garrett Pump down surge tank Increase choke to 25/64 Bleed down csg to 2100 psi Schlumbercjer close PCT and shut in surface manifold tlxj at 153 psi Schlumberger open PCT for the final flow period for test #2 See PTS well test data sheet for further flow information PTS open choke manifold on a 5/64 adj. choke setting Cut anti-foam to 1.5 strokes per minute Schlumberger close PCT for final build-up Blow down flow lines with air and methanol PTS pump down Gauge tanks 1 and 2 to storage tank 6 Gauge tanks pumped down Schlumbe~er open PCT to flow the well to bottom hole samples PTS open manifold on a 10/64 Increase choke to 20164 Shut in well to run in bottom hole sampler PTS bleed off flow line Atlas rigged up and start in the hole with Expro sampler Atlas at perforations PTS open choke to a 5/64 choke to tank #1 Shut in manifold Atlas start out of the hole with Expro sample containers Atlas at surface with Expro samples PTS bleed off the pressure Atlas rigging down samples are good Atlas off the dg floor BJ rigging up to reverse out Schlumberger has the PCT closed ready to start the reverse out Pressure u,p the csg to 2250 Bleed off Pressure up csg to 2250 Bleed off. now the tool is in the proper position Open the manifold has 1800 psi Nabors pull up on tbg string to release rio port PTS open choke manifold to take fluid tbg at 300 psi, 64 bbls to equalize the ~g and csg Close flow head to PTS and circulate the long way nabors blow PTS down with diesel then air Lines all clear and dry PTS rigged down off the floor Standby waiting on DST #3. cleaning and doing general maintain Standby waiting on OST #3, cleaning and doing general maintain PTS rig up to the csg to flow back the diesel in the csg PTS rigged up and waiting to perforate Open to the surge tank to measure back the fluid Still flowing diesel Atlas in the hole with the guns correlating location of zone Atlas perforate ' IOOTH AVE. ANCHORAGE, ALASKA 99515 (907] 344-2024 FAX (907] 344-2022 rod u cti o nTe sti n g $ e rvi c e s Test Sum.mary WELl, N'(.J, J. ............. '['EST NC). :Z ................ TIrBING ,3..:~ ............... PACKER TYPE : ....................... TOTAL DEF[t{ ' ......................... TO'FAI', FLOW TIME: :}.:J=~ .............. A V~S.,C;E q GAS '!~5:~i~.7.~.~'.~ AVERAGE (~ OIL : ({~,] ............... TOTAL PROD. Off.. · :iaT~. ................ ()fl, C;RAVITY ' ~.0_ ............. I',OCAT[ON ZONE 'NC), DATE: 3/26/95 · ,.:-kSING 8117..'5E ' ~'.. ............... PACKER DEPTH : 1.0638 CUSHION COMP.: ..D..i~_,~I~J.< ............................... 'II')I~;[NG CUgHION lelY. : ..................... PERF INrD?,RVAL ' AVERA(iE H20 ' ......................... AVERAGE WELLHEAD P,.qI - ..2_2_$....b.~i..P_. AVERAGE, GOR ' ..t_~!.L). .......... INYflAL WF.,LI,IqE~.~)PSI A~.':RAGE GLR. : ...................... S}{UT-IN WELLHI,,'AD PSI : ~_4_4_6. ........... TOTAL PROD. GAS: .l'~(}t!J?.~.'..'E TOTAL PROD. }120 :.=..0. ..................... GAS GRAvr]sY .._8_1_O ......... C[{L .)RIDE. : TOTAL PROD. I,[Q., :.]:_7.? ............... l~,OW RA'fl!: tN!~_ '!~ ................................ iq,OW ~)M: ~).,~.EL ...................."r~Z.Ll~g .......................... ~oM: ooo~ L'O' t,,~ '1".~ : ~J~_t~:~. .............................. 'I'C)T~U:, TIME AVERA(JE FYP : '}6~ .................................. A~.RAO~: .[z ['p AVERAGE ~'['1' : ~. ............................................. AVL&RAGE I~TI' AVI~bk(.;E Q GAS , !~,~.[~}~ ................. AVEraGE Q ,-k~,~tRAGE Q 1t20 . ~ ......................................... AVENGE Q A~RAGE GOR :. 2~. ..................................... AVERAGE GOR AVERAGE GLR ' ........................................... A~2R.AGE GLR AVERAGE BS&W '. .............................................. AVEP~GE BS&W OU., G~V1TY : 2_~ ...................................... OIL GRAf'S' GAS (~AXfflW ' .~l ~=~ .................................... GAS GRA%qTY p H : p H % CO2 ' ~ ................................................. % CO2 PRODUCED Q GAS : ~.gj~.~[ffI~ .......................... PRODUCED Q GAS PRODUCED Q (')~., : ).~:.[~ ................................... PRODUCED Q OIL PRODI.IC~ Q H20 : ~ .................................................. PRODU~D Q TO'I'~ PROD. I.,[Q : ]..~[~._~J.~ ................................ TOTAL PROD. LIQ (.-'..QM'..N._[!.'i!~.N..:!~.~..3/23/95 05:24 ,~,,hlumburger pert orated 'the well at 06:10 open choke fluid ~'~ ..q ' · ~, ~ al' surface. ,.~hut in pre.., sm c 2446 psi t0:1. > oil at: suffa.c,e A'P'I gravity 21.4. Flowing well into the surge tank. At 15:00 shut in test tool tbr the initial build up. March 24, 1995 a.t 00:06 open well for the final tlow period at 00:33 fluid at separator, at I)2:30 open well into th.¢ separator and be~ojn, toflow. Al: 0941) stop chemical injectkm. West Port [.,ab taking all. o1" Ihe fluid samples. Al: 16:42 start, chemical injection. March '25,1995 %blumber :,'er close test tool. at 00:02 ~ ~. ..... g ) F. IOOTH AVE. ANCHORAGE, ALASKA 99515 (907) 344-2024 FAX (907) 344-2022 PTS WELL TEST SUMMARY BADAMI//5, INITIAL FLOW, LOWER ZONE 3/16/95 WELLHEAD HEATER SEPARATOR TANK DATE CHOKE TEMP TI~ CSG CHOK~ STATIC GAS DI]~F ORIFICE GAS CUM ]]qCR. OIL CUM Bs&w OIL GRAV. GAS H~S COz ]NCR. On'- CUM GOR KEMARKS TIME SIZE PRESS PRESS SIZE PRESS TEMP PI~SS SIZE RATE GAS On'- RATE On'- @ 60 °F GRAV. OIL RA~E on_ 64THIN OF PSIG PSIG 6~,THIN PSIG °F INH~O IN M$CP/D MSC~ BBL BPI) BBL ~, °API PPM PPM BBL BPD BBL SCF/BBL 16-Mar-95 4:28 0 2300 0 Press t~ to fire I~un. 4:40 0 1500 2300 0 Waitin~ for ~uas fire. 4:46 0 2050 2300 0 Guns 4:48 10 2100 2300 20 Open we[[ to tank. 4:53 10 1440 2200 5:00 15 1250 2200 Ope~ to .[ 5/64' adi. choke. 5:02 0 1475 2200 Sb~ b wet[ @ s-dace. 5:03 15 1475 2200 O~en we[] to tank. [ 5:10 0 37 850 2200 15 F[ow to stodl tank. [ 5:15 0 36 890 2200 15 [:k~v thro~b beater 5:20 0 3~ 1050 2200 15 20.15 20.15 88LS back. 5:25 0 36 1270 2250 .[ 5 5:30 0 36 11 50 2250 15 4.20 4.[ 1.64 24.44 24.~, 88LS back. 5:40 0 37 1210 2250 15 5.78 166~.64 30.22 30.22 88LS back. 5:50 0 38 1.[.[0 2265 15 4.85 698.40 35.07 35.07 88LS ba~c 6:00 0 39 1.[00 2270 15 3.38 483.64 38.43 38A3 88LS back. 6:'[0 0 39 1125 2290 15 4.10 590.40 42.53 42.53 BSLS back. 6:20 0 40 1185 2290 15 4.10 590.40 46.63 46.63 88[_$ back. 6:30 0 44 1200 2278 15 2.99 430.56 49.62 49.62 8BLS back. 6:40 0 46 1.[40 2278 15 4.47 643.63 54.09 54.09 88L8 back 6:50 0 45 1100 2278 .[5 2.97 427.68 57.06 57.06 88[$ back. 7:00 0 43 1180 2278 .[5 4.47 643.63 61.53 Switch tanks. 7:10 0 41 .[060 2278 15 8.21 1182.24 69.74 ~)7:12 ~as ~ s~rface 7:20 0 42 1150 2278 15 4.50 648.00 ?4.24 7:30 0 44 1050 2278 20 5.00 720.00 79.24 7:40 0 47 900 2278 20 2.00 288.00 81.24 7:50 0 51 1000 2278 20 2.00 288.00 83.24 8:00 0 53 1150 2278 20 5 74 9.0 1.000 77.000 0.550 0.810 6.00 8~4.00 89.24 89 8:10 0 52 1400 2'300 20 4.00 576.00 93.24 8:20 0 53 1650 2'300 20 5 78 15.0 1.030 98.000 1.911 0.810 3.25 468.00 96.49 209 8:30 0 54 1700 2300 25 2 80 7.5 1.030 54.200 2.370 0.810 1.75 252.00 98.24 255 Sw~tch to c~oke rrgk[. 8:40 0 54 1575 2'300 25 15 80 5.0 1.000 70.000 2.870 0.810 0.03 0.00 98.24 8:50 0 53 13~0 2300 25 20 72 .[0.0 1.000 109.300 3.650 0.810 Pumpin[~ tank. 9:00 0 53 1370 2'300 25 40 68 35.0 1.125 335.400 6.040 0.810 5.00 360.00 103.24 932 9:10 0 44 1300 2'300 25 100 38 38.0 1..[25 597.880 10.300 0.740 15.00 2150.00 118.24 277 9:20 0 44 1040 2300 25 90 42 60.0 1.125 '/1.[.000 15.400 0.740 6.00 864.00 124.24 823 RPT16.XLS PTS WELL TEST SUMMARY BADAMI ~ DST #1, INITIAL FLOW LOWER ZONE 3/16/95 WELLH~D H~TER SEPARA~R TANK DA~ ~O~ ~ ~ ~G ~O~ S~C ~ D~ O~ ~ ~ ~. O~ ~ B~ O~ G~V. ~ H~ ~ ~, O~ ~ ~R ~ ~ S~ P~S P~ S~ P~S ~ P~S S~ ~ ~ O~ ~ O~ ~ ~ ~ G~V. O~ ~ O~ ~ ~ ~IG ~IG ~ ~IG ~ ~H~ ~ M~ MS~ BBL B~ B~ ~ o~ PPM PPM BBL B~ BBL S~BL 9:~ 0 ~ 1070 ~ ~ 1~ ~ ~.0 1,125 ~.~ 19.7~ 0.7~ 8.~ 11~.~ 1~.~ 516 9:~ 0 ~ 1~ ~ 25 1~ ~ 4Z0 1.125 ~4.~ 24.~ 0.7~ 7.~ 1074.24 1~.~ ~1 9:~ 0 45 1~ 2~ 25 1~ ~ ~.0 1,125 ~.~ 28.~ 0.7~ 10.49 1510.~ 1~.~ ~ 10:~ 0 47 1~ ~ 25 ~ ~ ~.0 1,125 411.~ 31.~ 0.7~ 11.19 1611.~ 161.~ 2~ 10:10 0 47 1~ ~ 25 ~ ~ ~.0 1.1~ ~.~ ~.570 0.7~ 12.~ 1825.~ 174.~ 318 10:~ 0 47 1~5 ~ 25 ~ 45 ~.0 1.125 ~.~ ~.710 0.7~ 11.19 1611.~ 1~.45 ~ 10:~ 0 47 1~ ~ 25 ~ ~ ~.0 1.125 579.~ ~.~ 0.7~ 8.~ 1~.24 1~.41 ~9 10:~ 0 1~.19 Sh~ in ~11 ~ t~l. RPT16.XLS -2of2 WHP/CSG_P/WHT/CHOKE BADAMI #5, DST#l, INITIAL FLOW 3000 6O 2500 5O 2OOO 1500 1000 5OO ~WHP ---~.- CASING PRESS · -~ WHT(DEGF) -,-4,~ CHOK E(64th IN) 4O 30 o O 2O t0 0 3/18/95 4:00 3/16/95 5:30 3/16/95 7:00 DATE/TIME 3/t 6/95 8:30 3/16/95 10:00 RPT16PLT.XLS/CHARTI CUM GAS/CUM O~L 2OO t60 120 BADAMt #5, DST#l, INITIAL FLOW 4O 3O 2O 8O 4O 0 3/16/95 4:00 ~F~, CUM OIL 3/18/95 5:30 3/t 6/95 7:00 3/16/95 8:30 DATE/TiME 3/1,6/95 10:00 10 RPT16PLT.XLS/CHART2 WHP/OIL RATE/GOR 250O 2O0O 15OO 1000 500 BADAMt #5, DST#l, INITIAL FLOW ATE(BPD) SGF/BBL) 0 3/16/95 4:00 3/t 6/95 5:30 3/16/95 7:00 DATE/TIME 3/16/95 8:30 3/16/95 10:00 25OO 2000 1500 1000 500 RPT16PLT.XLS/CHART3 PTS WELL TEST SUMMARY BADAMI ~5, DST #1, MAIN FLOW, LOWER ZONE 3/16/95-3/17/95 WELLHEAD HEATER SEPARATOR TANK DATE CHOKE TEMP TBG CSG CHOKE STATIC GAS DIE~ OR]I~CE GAS CUM INCR. OIL CUM Bs&w OK, GRAV. GAS H~S CO~ INC~. OIL CUM C-OR REMARKS T/ME SIZE PRESS PRESS SIZE PRESS TEMP PRESS SIZE RATE GAS OK. RATE OIL @ ~0 ~F GRAV. OIL RATE OIL 64THIN °F PSIG PSIG 64THIN PSIG °F INHfi) IN MSCF/D MSCF BBL BPI) I~R~. · °API PPM PPM BBL BPI) BBL SCF/BBL 16-Mar-95 19:30 10 2200 Open well on 10/64. 19."35 15 2260 Open to sep., 15/64. 19:37 20 48 1235 2280 FULL Open to 20/64. 19:40 25 48 975 2200 FULL 4.50 2040.00 14.17 Open to 25/64. 19:45 30 45 900 2200 FULL Trace 25.20 11.23 1611.00 25.40 Open to 30/64. 19:45 25 45 870 2200 FULL Open to 25/64. 19:50 25 45 FULL 15o 70 50.0 1.25o 798.820 8.320 0.820 Well shut in. 20.t30 25 45 905 2200 FULL Dpen well to 10/64 21:03 10 44 2500 2255 FULL Cpe,'~ to 25/64 21:15 25 42 1130 2300 FULL 5.97 716.00 31.33 heater @ 21:08. 21.~0 0 42 1162 2250 25 Trace 25.80 0.840 5.22 501.00 36.55 21:45 0 42 1260 2300 25 175 79 96.0 0.875 547.150 14.020 Trace 0.840 26.11 2506.00 62.66 218 22:00 0 42 1299 2300 25 175 80 85.0 0.875 514.650 19.380 Trace 0.840 18.66 1791.00 81.32 287 22:15 0 44 1341 2'300 25 175 82 60.0 0.875 432.140 23.881 Trace 0.840 2.23 214.00 83.55 2019 Rocked 22:30 0 44 1355 2300 30 175 80 97.0 0.875 549.380 29.604 Trace 0.840 11.94 1148.00 95.49 479 Rocked choke. 23.t30 30 43 710 2400 48 180 80 97.0 0.875 550.240 41.068 1% 26.00 0.840 33.21 1593.00 128.70 345 0.34 BBL H20. 23:30 30 45 990 2300 78 180 76 98.0 0.875 533.040 52.173 Trace 0.840 26.50 1271.00 155.20 419 Rod(ed choke. 17-Mar-95 0:00 30 45 797 2300 78 180 74 118.0 0.875 617.480 65.037 Trace 0.840 33.40 1603.00 188.50 385 0:30 30 48 835 2300 62 180 71 116.0 0.875 614.270 77.834 Trace 26.00 0.840 42.70 2051.00 231.30 299 1:00 30 49 820 2440 62 180 71 113.0 0.875 606.380 90.467 Trace 0.780 23.87 1145.00 255.17 530 1:30 0 49 945 2293 30 180 69 86.0 0.875 530.990 101.529 Trace 0.780 30.06 1486.00 286.13 357 2.130 30 49 685 2312 78 180 69 172.0 0.875 755.730 117.274 Trace 0.800 26.27 1262.03 312.40 599 2:30 30 50 725 2357 180 74 148.0 0.875 698.260 131.821 0.800 0 0 41.00 1969.0~ 3,53.40 355 3:00 30 50 715 2360 180 78 144.0 0.875 686.010 146.113 Traoe 25.50 0.800 31.90 1531.00 385.30 448 3:30 30 51 710 2400 180 79 134.0 0.875 681.460 159.893 Trace 0.800 0 0 38.80 1861.00 424.10 355 4:00 30 53 700 2400 180 79 135.0 0.875 663.880 173.724 0.800 33.20 1593.00 457.30 417 4:30 30 51 700 2300 180 78 132.0 0.875 557.270 187.417 Trace 26.00 0.800 0 0 35.10 1685.00 492.40 390 5:00 30 52 694 2367 180 78 134.0 0.875 662.150 201.212 Trace 0.800 43.30 1781.00 535.70 372 5:30 30 52 690 2367 180 79 132.0 0.875 656.580 214.890 0.800 25.10 1504.00 561,80 437 5:40 30 14.00 1831.00 575.80 (~5:41 well shut in. 6:35 0 2000 2200 Trace 26.50 Open well on 30/64. 7:00 30 47 720 2175 50 175 76 120.0 0.875 619.880 225.652 0.800 39.98 2245.03 614.78 276 7:30 30 49 690 2290 50 180 80 140.0 0.875 675.160 239.718 0.800 36.56 1755.00 651.34 385 8:00 30 50 693 2400 50 180 80 136.0 0.875 665.600 253.584 T.=__,~,_ 26.50 0.800 0 0 35.81 1719.00 687.15 387 9:00 30 49 690 2400 50 180 78 120.0 0.875 627.130 279.715 Trace 26.00 0,800 66.03 1584,00 753,18 396 RPT17.XLS I of 2 PTS WELL TEST SUMMARY BADAMI #5, DST #1, MAIN LOWER ZONE 3/16/95-3/17/95 WELLHEAD HEATER SEPARATOR TANK DATE CI-[OKt[ TE_MP '['BG CSG CHOK~ STATIC GAS D]]=F ORIFICE GAS CUM INCR. OIL CUM Bs8cw OIL GRAV. GAS H~S CO~ ]]qCR. OIL CUM GOR REMARKS TIME SIZE PRESS PRESS SIZE PR.ESS TEMP PRESS SIZE RATE GAS OR, RATE OIL @ ~O"F GRAV. OD., RATE orr_ 64THIN °F PSIG PSIG 64THIN PSIG °F IN H:,O IN MSCF/D MSC~ RRT. BPD BBL ~ °API PPM PPM BBL BPI) BBL SCF/BBL 10:00 30 50 695 2400 50 180 76 124.0 0.875 625.650 305.783 Trace 26.00 0.800 0 0 70.13 1683.00 823.31 372 11:00 30 55 670 2370 50 180 76 122.0 0.875 633.6(10 332.183 Trace 26.10 0.800 70.88 1701.00 894.19 372 12:00 30 53 668 2370 50 180 78 120.0 0.875 627.130 358.314 Trace 25.90 0.800 0 0 69.38 1665.00 963.57 377 13:00 30 57 686 2200 50 180 80 118.0 0.875 629.020 384.523 Trace 26.10 0.800 69.38 1665.00 1032.95 378 14:00 30 59 661 2200 50 180 80 118.0 0.875 629.020 410.732 Trace 26.00 0.800 0 0 67.89 1630.00 1100.84 386 15:00 30 60 660 2210 50 150 80 117.0 0.875 626.380 436.831 Trace 26.10 0.800 68.32 1640.00 1169.16 382 W®[I shut in @ tool. 15:50 0 150 Shut in @ manifold. RPT17.XLS 2 of 2 3000 2500 2000 1500 1000 500 BADAMI #5, DST#l, MAINFLOW 0 3/16/95 19:00 3/16/95 22:00 3/17/95 1:00 WHP/CSG P/WHT/CHOKE -~ WHP -4~ CASING PRESS ---~-- WHT(DEGF) ~ CHOKE(64th IN) 3/17/95 4:00 3/17/95 7:00 3/17/95 10:00 3/17/95 13:00 DATE/T~ME 6O 5O 4O 2O 10 RPT17PL%XLS/CHART1 CUM GAS/CUM O~L BADAMI #5, DST#l, MAINFLOW 1500 - - -- 500.000 1200 900 600 30O 3/16/95 19:00 3/16/95 22:00 3/t7/95 1:00 ~ CUM OIL ~-- ,,., UM GAS 3/17/95 4:00 3/17/95 7:00 3/t7/95 t0:00 3/17/95 13:00 DATE/T~ME ,400~000 300.000 200.000 100.000 0,000 RPTt 7PLT,XLS/CHART2 30O0 BADAMI #5, DST#l, MAINFLOW WHP/OIL RATE/GOR 3OO0 2500 2OOO 1500 1000 5oo 0 3/16/95 19:00 OIL RATE(BPD) I GOR(SCF/B,~ 3/16/95 22:00 3/17/95 1:00 3/17/95 4:00 3/17/95 7:00 3/17/95 t0:00 3/17/95 13:00 DATE/TIME 25OO 2OOO 1500 1000 5O0 RPT17PLT,XLS/CHART3 30.00 28.00 26.00 24.00 OIL GRAVITY(APl DEGREE) BADAMI #5, DST#l, MAINFLOW 22.00 20.00 3/16/95 19:00 3/16/95 22:00 3/17/95 1:00 3/17/95 4:00 3/17/95 7:00 3/17/95 10:00 3/17/95 13:00 DATE/TIME RPT17PLT.XLS/CHART4 PTS WELL TEST SUMMARY BADAMI ~5, DST #2, INITIAL FI UPPER ZONE · - ........ 3123/95 WELLHEAD HEATER SEPARATOR TANK DATE CHo~ TEMP TBG CSG CHo~. STATIC GAS Dn~ OP,~i~ GAS (HJM INCR. OH, CUM Bs&-w OIL GRAY. GAS H~S CO~ INCR. OIL CUM GO; i~EMARKS TIME SIZE PRESS PRESS SIZE PKESS TEMP PRESS SIZ~ RATE GAS OIL RATE OH. ~ ~0 op GRAV. OIL RATE OIL 64THIN °F PSIG PSIG 64THIN PSIG °F INH~O IN MSCP/D MSCF BBL BPD BBL ~ °API PPM PPM llRT. BPD BBL SCF/BBL 23-Mar-95 5:24 0 6500 2200 5:42 0 60 2120 Pr-~,~sure up tt~. 5:58 0 2395 2117 Guns fired. 6:00 0 2446 2115 6:05 Open well on 10/64'. 6:10 10 57 275 2100 5.22 1503.00 5.22 "- 6.'20 10 52 200 2100 2.99 431.00 8.21 6:30 10 50 195 2100 2.24 322.00 10.45 6:40 10 49 206 2100 2.98 429.00 13.43 6:58 10 50 215 2200 2.98 429.00 16.41 7:00 10 49 220 2100 2.99 431.00 19.40 7:10 10 52 225 2100 2.61 376.00 22.01 7:15 12 52 2100 7~13 12 52 102 2100 Incr. chok® to 12/64'. 2.98 429.00 24.98 7:30 12 52 101 2100 3.36 484.00 28.35 7:45 12 52 107 2100 3.73 358.68 32.08 8:00 12 53 125 2100 4.10 304.00 36.18 8:15 12 54 130 2100 3.73 358.00 39.91 8:30 12 64 135 2100 4.11 395.00 44.02 8:45 12 54 150 2100 5.22 501.00 49.24 9:00 12 53 165 2020 3.36 323.00 52.60 No sign of gas, solid 9:15 12 54 195 2240 3.73 358.00 56.33 di~'~=l flowin~ out. 9:30 12 52 235 2200 4.65 466.00 61.18 Incr. choke to 20/64'. 9.00 584.0~ 70.18 9:50 I 64 45.0 1.125 196.000 0.680 0.800 10:00 20 55 85 2243 I 64 15.0 1.125 112.000 1.460 0.800 3.00 298.00 73.18 389 10:15 20 57 60 2183 1 64 5.0 1.125 65.000 2.137 0.800 10.~30 20 57 90 2200 1 64 4.0 1.125 58.000 2.741 3.0 21.40 0.800 10:45 20 58 145 2200 I 64 3.0 1.125 50.600 3.268 0.800 All Bs&w is mud. 11:00 20 57 160 2240 I 64 3.5 1.125 54.700 3.838 0.800 11:15 20 57 180 2200 1 64 6.0 1.125 71.000 4.578 0.800 Incr. choke 1o 25/64'. 11:30 25 54 130 2272 1 64 13.0 1.125 104.000 5.661 19.80 0.800 17.00 272.00 g0.18 382 11:45 25 54 140 2270 3 64 12.0 1.125 71.500 6.406 0.800 2.00 192.00 92.18 372 12:00 25 51 125 2258 3 64 15.0 1.125 119.300 7.649 3.5 0.800 4.50 432.0~ 98.68 276 12:15 25 50 120 2220 2 64 14.0 1.125 112.000 8.815 0.800 4.50 432.00 101.18 259 ~2.~o ;5 49 1~ L~01 1 64 13.0 1.125 164.600 9.905 3.5 0.800 3.00 288,00 104,18 363 RPT23.XLS 1 of 2 PTS WELL TEST SUMMARY BADAMI #5, INITIAL FLOW, UPPER ZONE 3/23/95 WELLHEAD HEATER SEPARATOR TANK DATE CHOK~ TRIMP TBG CSG CHOKE STATIC GAS DI~ ORIHCR GAS CUM INCR.. OIL CUM Bs&w OIL GRAV. GAS H~ CO~ INCR. OIL CUM GOR REMARKS TIME SIZE PRF_.SS PRP.~ SIZE PKESS TP_.MP PRESS SIZE RATE GAS OIL RATE OIL @ 60 OF GRAV. OIL RATE OIL 64THIN °F PSIG PSIG 64THIN PSIG OF INH~O IN MSC'P/D MSC~ BBL BPD BBL % °API PPM PPM BBL BPD BBL $(~/BBL 12:45 25 48 134 2321 1 64 15.0 1.125 112.000 11.071 0.800 4.50 ~,',~.00 108.68 259 13:00 25 48 1~0 2340 1 64 17.0 1.125 119.300 12.314 1.8 18.80 0.800 4.50 432.00 113.18 276 13:15 25 47 143 2300 1 64 18.0 1.125 122.600 13.591 0.800 4.75 468.00 117.93 259 13:30 25 47 152 2300 1 64 19.0 1.125 125.900 14.903 1.0 19.80 0.800 4.25 408.00 122.18 309 13:45 25 47 153 2100 1 64 19.0 1.125 125.900 16.214 0.800 5.00 480.00 127.18 262 14:00 25 47 155 2'300 1 64 19.0 1.125 125.900 17.526 1.2 19.80 0.800 4.00 31M.00 131.18 328 14:15 25 47 151 2487 1 64 18.0 1.195 122.600 18.803 0.800 5.00 480.00 136.10 255 14:30 25 47 153 2480 1 64 18.0 1.125 122.600 20.080 0.5 19.80 0.8(10 3.00 288.00 138.18 426 14:45 25 45 152 2400 1 64 18.0 1.125 122.600 21.357 0.800 5.00 480.00 144.18 255 15:00 25 153 24OO 1 64 18.0 1.125 122.600 22.634 0.3 20.00 0.800 4.00 3tM.00 148.18 319 C~o6e, d PCT & maaifok[.[ 2of 2 RPT23.XLS 2500 BADAMI #5~ DST#2, INITIAL FLOW WHP/CSG P,~HT/CHOKE 2OO0 1500 1000 5OO I~WHP + CSG P ~ WH T-~D EG F) + Choke(64th IN) 0 I 3/23/95 5:00 3/23/95 8:30 3/23/95 8:00 3/23/95 9:30 3/23/95 11:00 3/23/95 12:30 3/23/95 14:00 DATE/TiME 100 8O 6O 4O 2O RPT23PLT.XLS/CHART1 CtJ~ GAS/CU~ OIL 2OO 180 160 t40 t20 100 8O 6O 4O 2O BADAMI #5, DST#2, INITIAL FLOW 0 3/23/95 5:00 3/23/95 6:30 CUM OIL ~CUM GAS 3/23/95 8:00 3/23/95 9:30 3/23/95 11:00 3/23/95 12:30 3/23/95 14:00 DATE/TIME 3O 27 24 21 9 RPT23PLT.XLS/CHART2 WHP/OIL RATE/GOR BADAMI #5, DST#2, INITIAL FLOW 2500 2000 2000 1500 1000 5OO ~P PSIG) ~OIL RATE(BPD) ~ GOR, SCF/BBL) 1600 1200 8OO 400 0 c~ 0 0 3/23/95 5:00 3/23/95 6:30 3/23/95 8:00 3/23/95 9:30 3/23/95 11:00 DATF.,rf~MF_. 3/23/95 12:30 3/23/95 14:00 RPT23PLT,XLS/CHART3 25.00 24.00 23.00 22.00 21.00 20.00 OIL GRAVITY(APl DEGREE) BADAMI #5, DST~2, INITIAL FLOW i · , 19.00 18.00 i7.00 16.00 15.00 3/23/95 5:00 3/23/95 6:30 3/23/95 8:00 3/23/95 9:30 3/23/95 11:00 3/23/95 12:30 3/23/95 14:00 DATE/TIME R PT23 PLT.XLS/CHART4 PTS WELL TEST SUMMARY BADAMI ~5, DST #2, MAIN FLOW, UPPER ZONE 3/24/95 WELLHEAD HEATER SEPARATOR TANK DATE CHOK~ TEMP TBG CSG CHOK~ STATIC GAS DIFF ORIFICE GAS OJM INCR. OIL CUM Bs&w OIL GRAV. GAS H~S CO~ I~fCR, OIL CUM GOR P.P-MARK$ ~ SIZE PRF. SS PRESS SIZE PRESS TEMP PRESS SIZE RATE GAS OR. RATE OIL @ 60 °F GRAV. OIL RATE OIL 64THlN °F PSIG PSIG 64THIN PSIG oF INH~O IN MSCP/D MS(X~ BBL BPD BBL % oAPI PPM PPM BBL Bl~ BBL SC~/BBL 24-Mar-95 0:06 5 66 406 2400 0 0 Open well on 5/64". 0:08 10 64 400 2400 0 0 Open well on 10/64'. 0:15 10 61 280 2400 7 72 22.0 1.125 158.470 1.650 0.81 0 0 No fluid. 0.~-30 10 57 290 2400 2 73 12.0 1.125 102.930 2.722 0.81 0 0 Incr. choke to 1~46'. 0:45 15 53 288 2400 5 96 8.0 1.125 89.721 3.657 0.81 0 0 3.50 336 3.50 267 Fluid @ sep. @ 0:33. 1.t30 20 47 232 2400 13 113 26.0 1.125 186.550 5.600 20.80 0.81 0 0 5.50 528 9.00 353 Incr. choke to 20/64'. 1:15 20 46 198 2407 12 124 22.0 1.125 167.090 7.341 19.30 0.81 0 0 3.50 336 12.50 497 Chemical inj. @ 4 SPM. 1:30 20 44 190 2407 12 140 21.5 1.125 139.590 8.795 0.81 0 0 4.03 384 16.50 364 1:45 20 43 203 2400 10 140 17.0 1.125 146.500 10.321 0.81 0 0 3.00 288 19.50 509 2:00 20 43 213 2433 1 140 18.0 1.125 149.310 11.876 0.81 0 0 4.25 408 23.75 366 2:30 20 43 212 2474 10 140 19.5 1.125 99.394 13.947 0.81 0 0 7.75 372 31.50 267 Put into seperator. 3:00 20 45 205 2500 90 95 55.0 0.500 99.394 16.017 20.70 0.81 0 0 5.03 241 36.53 412 3:30 20 45 201 2500 89 105 53.0 0.500 90.674 17.906 0.81 0 0 7.46 358 43.99 253 4:00 20 45 206 2500 75 108 55.0 0.500 80.130 19.576 20.00 0.81 0 0 8.21 394 52.20 203 5:00 20 45 215 2400 78 116 42.0 0.500 75.361 22.716 0.81 0 0 13.80 331 66.00 228 6:00 20 46 210 2600 78 130 38.0 0.500 75.550 25.864 0.81 0 0 14.22 341 80.22 221 7:00 20 46 210 2600 75 136 40.0 0.500 91.630 26.682 20.10 0.81 0 0 14.92 358 95.14 256 8:00 20 48 206 2627 70 138 63.0 0.500 91.470 33.493 19.90 0.81 0 0 10.86 261 106.03 351 9:00 20 43 205 2630 70 140 63.0 0.500 91.470 37.304 19.70 0.81 0 0 14.10 338 120.10 270 Stop chemical inj. 10:00 20 50 210 2646 75 136 40.0 0.500 75.550 40.452 20.03 0.81 0 0 13.00 312 133.10 242 ~ 9:43. 11:00 20 51 213 2650 80 128 37.0 0.500 75.266 43.588 Trace 20.2 0.81 0 0 14.17 340 147.27 221 12:00 20 51 210 2652 80 120 37.0 0.500 75.807 46.747 Trace 20.08 0.81 0 0 14.18 34~ 161.45 223 Oil meter frozen, 13:00 20 51 212 2644 80 114 37.0 0.500 76.222 49.923 Trace 20.10 0.81 0 0 14.00 33E 175.45 227 meter factor off, using 14:00 20 52 210 2652 80 112 40.0 0.500 79.367 53.230 Trace 20.20 0.81 0 0 14.17 340 189.62 233 tank strap. 15:00 20 50 208 2660 75 114 38.0 0.500 75.119 58.360 Trace 20.20 0.91 0 0 15.30 367 204.92 205 16:00 20 50 209 2661 75 114 38.0 0.500 75.119 58.490 Trace 20.30 0.81 0 0 7.22 173 212.14 434 @ 16:42 startchernical 17:00 20 52 210 2632 80 114 39.0 0.500 78.235 62.749 Trace 20.00 0.81 0 0 19.26 463 231.42 169 inj., samplin~l done, 18:00 20 51 204 2612 80 122 39.0 0.500 77.670 55.986 Trace 20.80 0.81 0 0 11.75 282 243.17 275 4 SPM, 4 Gal/Day. 19:00 26 51 199 2550 80 135 50.0 0.500 86.820 69.603 I Trace 20.00 0.81 0 0 15.53 373 258.70 233 20:00 20 51 198 2540 80 140 57.0 0.500 92.216 73.445 Trace 20.10 0.81 0 0 13.20 317 271.90 291 21:00 20 52 200 2500 80 143 49.0 0.500 85.362 77.002 Trace 19.90 0.81 0 0 13.20 317 285.10 269 22:00 20 49 200 2500 77 141 44.0 0.500 79.754 80.325 Trace 20.03 0.81 0 0 17.00 408 302.10 195 23:00 20 49 201 2500 78 131 38.0 0.500 75.2'39 33.460 Trace 20.00 0.81 0 0 12.50 300 314.50 251 0:08 20 49 202 2500 80 124 33.0 0.500 71.370 86.434 20.03 0.81 0 0 14.20 341 328.80 209 Closed PCT @ 0:02. IClose maniiold 0:04. RPT24,XLS I of I WHP/CSG P/WHT/CHO~E BADAMI #5, DST#2, MAINFLOW 3000 7O 2500 6O 20OO 1500 1000 500 5O 0 3/24/95 0:00 · ~CASiNG PRESS ~ +CHOKE(64th iN) , i 30 4~ - t0 3/24/95 3/24/95 3/24/95 3/24/95 3/24/95 3/24/95 3/24/95 3/25/95 3:00 8:00 9:00 12:00 15:00 18:00 21:00 0:00 BATE/TiME 0 CUM GAS/CUM O~L 500,o0 BADAMI #5, DST#2, MAINFLOW 100,000 450,00 90,000 400.00 80~000 350.00 70,000 300.00 60.000 50,000 40.0O0 250.00 200.00 150.00 100.00 50.00 0.00 3/24/95 0:00 3/24/95 3:00 3/24/95 6:00 3/24/95 9:00 3/24/95 12:00 DATE/TiME CUM OIL 1 CUM GASl 30,000 20.000 10.000 3/24/95 15:00 3/24/95 18:00 3/24/95 21:00 0.000 3/25/95 0:00 RPT24PLT.XLS/CHART2 600 5OO 400 300 2OO 100 BADAMI #5, DST#2, MAINFLOW WHP/OIL RATE/GOR -4~-~ WHP(PSIG) OIL RATE(BPD) GOR(SCF/BBL) 800 500 400 30O 2OO 100 0 3/24/95 0:00 3/24/95 3:00 3/24/95 8:00 3/24/95 9:00 3/24/95 i2:00 DATE/T~ME 3/24/95 15:00 3/24/95 18:00 3/24/95 21:00 0 3/25/95 0:00 RPT24PLT,XLS/CHART3 OIL GRAVITY(APl DEGREE) 25.00 24.00 23.00 22.00 BADAMI #5, DST82, MAINFLOW I = ,1-- = J -= __-~-__~_= ~ = ,~ ' ii I I , 21.00 20.00 19.00 18.00 17.00 16.00 15.00 3/24/95 0:00 3/24/95 3:00 3/24/95 6:00 3/24/95 9:00 3/24/95 12:00 3/24/95 15:00 3/24/95 18:00 3/24/95 21:00 3/25/95 0:00 DATE/TIME RPT24PLT.XLS/CHART4 PTS WELL TEST SUMMARY BADAMI #5, DST #2, SAMPLING, UPPER ZONE 3/26/95 WELLHEAD HEATER SEPARATOR TANK DATE CHOKE TEMP TI~ CSO CHOKE STATIC VESSEL GAS DIFF OItIFICE GAS CUM Bs&,w OIL GRAV. GAS H~ CO~ INCR. OIL CUM GOR RF_,MARKS TIME SIZE PltP, SS PKESS SIZE PRESS TEMP TEMP PItP, SS SIZE RATE GAS @ ~ °F GRAV. OIL RATE OIL 64THIN °F PSIG PSIG 64THIN PSIG OF OF INH:~O ! IN MSCF/D MS(~ ~, °API PPM PPM BBL BPD BBL SC~/BBL 25-Mar-95 0:04 10 461 , Open well to sap. on 10/64. 0:08 20 85 'Incr. choke to 20/64, 0:30 20 42 166 2140 ,50 84 99 78.0 0.500 91.653 1.909 0.81 0 0 1.50 72 1.50 1273 start chemicaJ injection. 1:00 20 42 177 2150 50 86 104 89.0 0.500 96.197 3.914 Trace 20.10 0.81 0 0 6.15 295 7.65 326 Trace of mud. 1:30 20 37 170 2160 50 100 107 87.0 0.500 95.933 5.912 0.81 0 0 6.34 304 13.99 315 2:00 20 44 194 2180 50 100 108 89.0 0.500 96.907 7.931 Trace 20.00 0.81 0 0 8.02 385 22.01 252 Shut in ~ mainfold to RI hole w/wireline. 5:00 5 37 2150 2201 Open well on 5/64. 5:30 ,5 36 2010 2210 0.18 9 22.19 No ~as observed @ ta~k. 6:00 5 35 2000 2230 0.00 22.19 6:30 5 33 2060 2260 0.00 22.19 7:00 5 32 2010 2210 0.00 22.19 7:29 5 38 2020 2220 0.18 2 22.35 Shut in @ mainfold, 7:30 Atlas pull sample chamber out of hole. RPT26.XLS I of I WELL TEST DATA BY DAU BAI #5 MAIN FLOW ZONE 3/17/95 DATE TIME TBG CSG WHT STATIC SEP DIFF GAS GAS REMARK PRESS PRESS PRESS TEMP PRESS TEMP RATE PSIG PSIG ~F PSIG ~F IN H~O ~F MSCF/D , 3/16/95 19:30.130 1033.0~ 452.7 48.5 118.5 62.6 Open well. 3/16/95 19:45.130 865.9= 2170.0 45.7 97.0 62.9 Shutwell in @ 19:50. 3/16,95 20:00.130 101.1 2221.2 43.0 50.4 63.0 Open well. 3/16/95 20:15.'00 101.1 2246.2 43.0 22.4 63.0 3/16/95 20:30.130 0.0 2254.9 41.9 12.3 63.0 3/16,95 20:45.00 14.7 2254.9 41.4 7.7 62.5 3/16/95 21:00.'00 8.8 2254.9 44.3 96.3 64.7 3/16/95 21:15.00 1610.3 2238.8 42.9 134.7 68.4 16.1 81.0 64.6 3/16/95 21:30.1:)0 1227.8 2240.3 41.8 179.2 71.1 113.5 82.0 611.8 , 3/16/95 21:45.130 1100.4 2281.3 41.8 179.3 72.9 69.3 82.0 480.5 3/16/95 22:00.00 1213.2 2317.9 42.3 177.2 74.7 53.4 84.0 419.3 3/16/95 22:15.130 1353.8 2345.8 42.9 177.6 77.8 44.5 85.0 360.5 3/16/95 22:30.~0 1352.4 2363.4 43.5 183.5 79.5 58.3 85.0 385.9 3/16/95 22:45.130 1178.0 2379.5 44.0 189.1 79.3 66.0 80.0 359.5 3/16/95 23:00.O0 722.3 2404.4 43.6 188.4 78.0 107.7 76.0 568.7 3/16/95 23:15.130 923.1 2460.1 44.7 187.9 76.8 76.7 78.0 500.2 ,,, 3/16/95 23:30.'~ 974.4 2268.1 45.3 188.1 76.1 102.9 78.0 590.3 3/16/95 23:45.130 814.7 2294.5 45.2 191.8 75.2 137.7 74.0 721.2 3/17/95 0:00.O0 789.7 2326.7 45.8 168.2 74.8 113;7 73.0 650.5 3/17/95 0:15m 822.0 2260.4 45.8 185.8 76.5 119.8 71.0 667.0 3/i7/95 0:30~ 822.0 2391.2 48.1 lS4.1 77.8 112.5 70.0 843.7 , 3/17/95 0:45:~ 823.4 2419.0 48.1 189.6 78.4 110.9 71.0 648.2 3/17/95 1:00.130 822.0 2444.0 48.5 191.7 76.9 108.5 72.0 644.5 3/17/95 1:15:00 826.4 2266.7 49.1 189.7 75.3 71.5 71.0 515.1 3/17/95 1:30.1:)0 984.6 2284.; 49.6 168.7 73.7 32.5 70.0 269.9 ,, 3/17/95 1:45.130 934.8 2298.9 47.8 194.0 72.4 114.3 69.0 592.4 ~ ,, 3/17/95 2:00:00 715.0 2306.2 48.9 195.3 71.6 152.2 73.0 765.4 3/17/95 2:15.O0 666.7 2323.8 49.6 194.7 71.3 140.1 76.0 731.1 , 3/17/95 2:30.130 682.8 2350.2 49.5 193.6 71.8 119.4 78.0 668.1 ,,, ,, , 3/17/95 2:45.130 748.7 2373.6 50.7 194.6 72.8 145.1 79.0 742.2 , , 3/17/95 3:00.130 706.2 2391.; 50.7 195.1 73.5 140.0 80.0 730.8 3/17/95 3:15.130! 697.4 2411.7 50.7 194.9 74.0 136.7 80.0 721.5 .., 3/17/95 3:30.130 698.9 2427.8 51.2 195.1 74.6 136.5 80.0 721.0 i,,, , ,, , , ,, , 3/17/95 3:45.130! 697.4 2244.7 51.0 195.6 74.6 135.2 79.0 720.2 3/17/95 4:00.130! 697.4 2259.3 51.0 194.4 74.6 135.6 79.0 718.6 i , 3/17/95 4:15:00: 694.5 2271.1 51.6 190.0 75.4 140.0 78.0 722.6 3/17/95 4:30:00 694.5 2278.4 51.6 187.8 77.2 139.3 78.0 715.5 ,,, 3/17/95 4:45:00= 693.0 2287.2 51.6 186.3 79.7 139.3 77.0 714.5 3/17/95 5:00:00 690.1 2300.4 50.5 187.7 81.4 136.3 78.0 711.7 3/17/95 5:15:~i 688.6 2309.2 50.9 192.7 81.1 133.4 79.0 709.6 , 3/17/95 5:30.130 688.6 2320.9= 51.5 181.7 79.6 81.5 79.0 453.8 , , 3/17/95 5:45.130 165.6 2334.1 50.4 158.8 78.2 Well shut in @ 5:41. 3/17/95 6:00.1:)0i 162.6 2339.9 48.4 154.7' 77.6 , 3/17/95 6:15:001 2060.1 2227.1 49.0 150.5 77.0 i 3/17/95 6:30:00 2060.1 2227.1 49.0 143.1 75.3 Open well @ 6:35. 3/17/95 6:45.130 709.2 2227.1 49.0 201.1 74.7 113.7 79.0 670.7 3/17/95 7:00.130 709.2 2177.3 47.6 200.7 74.7 140.4 82.0 740.4 ,,,, , 3/17/95 7:15:~ 700.4 '2189.0 48.1 200.0 75.8 140.8 83.0 73719 " 3/17/95 7:30'.~X3 693'.0 2203.7 48.1 203.8 76.0 134.0 84.0 727.5 ' ,, , 3/17/95 7:45.130 690.1 2222.7 48.6 201.5 76.3 133.7 83.0 723.2 , 3/17/95 8:00.'~ 688.6 2243.2 49.1 200.7 76.8 133.6 83.0 699.4 , , , 3/17/95 8:15.1X) 684.2 2259.3 47.9 201.5 77;1 131.0 83.0 691.6 i 3/17/95 8:30.130 681.3 2276.9 49.6 200;7 77.6 126.1 79.0 680.1 .. 3/17/95 8:45.00 682.8 2293.0 49.1 201.1 79.5 126.0 79.0 680.7 , Page 1 of 2 WELL TEST DATA BY DAU BADAMI #5 MAIN ZONE 3/17/95 DATE TI]VIE TBG CSG WI-IT STATIC SEP DIFF GAS GAS REM PRESS PRESS PRESS TEMP PRESS TEMP RATE PSIG PSIG ~F PSIG "F IN H20 ~F MSCF/D -- 3/17/95 9:00.'00 681.3 2309.2 48.5 199.2! 80.2 125.4 77.0 677.6 -- 3/17/95 9:15.'00 678.4 2320.9 48.5 198.3 80.6 125.1 76.0 675.7 3/17/95 9:30.00 676.9 2334.1 49.1 197.8 80.6 124.9 76.0 674.3 3/17/95 9:45.'00 675.5 2344.3 50.8, 203.2 80.5[ 120.3 77.0 669.6 -- _ 3/17/95 10:00:00 672.5 2354.6 53.1 199.3 80.1' 125.4 78.0 676.8 __ 3/17/95 10:15:00 672.5 2367.8 54.3 198.2 81.2~ 123.9 78.0 671.0 3/17/95 10:30.130 671.1 2366.3 55.9 201.9 81.5 120.9 78.0 668.3 __ 3/17/95 10:45:00 671.1 2367.8 56.5 202.4 80.6 119.4 79.0 664.8 3/17/95 11:00.'00 669.6 2367.8 55.4 199.5 80.8 124.3 79.0 673.4 3/17/95 11:15.'00 672.5 2376.6 53.1 203.7 81.7 118.8 80.0 664.4 3/17/95 11:30:00 666.7 2379.5 53.6 206.0 81.7 118.1 81.0 665.8 3/17/95 11:45.'00 666.7 2385.3 53.7 204.0 81.2 120.6 81.0 665.4 3/17/95 12:98.130 665.2 2165.6 53.7 199.1 82.6 122.3 81.0 666.3 3/17/95 12:15.00 665.2 2165.6 54.8 198.0 83.9 122.1 80.0 663.8 3/1'7/95 12:30.'00 663.7 2170.0 55.3 203.9 83.8 118.4 81.0 662.9 3/17/95 12:45.'00 663.7 2172.9 55.3 206.0 82.3 117.3 82.0 662.9 , 3/17/95 13:00.'00 660.8 2177.3 57.0 204.8 80.8 119.1 82.0 666.1 3/17/95 13:15.'00 660.8 2181.7 56.5 199.2 80.6 121.6 82,01 663.5 , ~ , 3/17/95 13:30:00 660.8 2187.5 58.2 198.8 82.2 120.7 82.0! 661.0 '3/1'7/95 13:45.00 659.3 2190.5 59.4 201.1 83.2 i18.0 81.0 657.2 , r 3/17/95 14:00:00 659.3 2194.9 59.4 203.783.4 117.5 82.0, 659.1 , 3/17/95 14:15.'00 659.3 2200.7 59.4 205.5 82.9 116.4 83.0 658.5 3/17/95 14:30.00 659.3 2206.6 59.4 206.3 82.4 116.5 84.0 659.7 ~ , 3/17/95 14:45.00 656.4 2209.5 60.0 203.8 82.4 108.2 85.0 604.8 , , 3/17/95 15:00.00 656.4 2215.4 61.2 195.2 83.1 34.2 85.0 289,5 Close PCT. , ~ , , Page 2 of 2 WELL TEST DATA BY DAU BADAMI #5 INITIAL :)W UPPER 3/23/95 -- DATE TIME TBG CSG WHT STATIC SEP DIFF GAS GAS REMARK PSIG PSIG ~F PSIG ~F IN H~O ~F MSCF/D 3/23/95 5.00.'00 2909.9 1219.0 61.1 3/23/95 5:15.1:)O 3053.5 2139.2 61.6 Pressure up tb~ @ 5:24. 3/23/95 5:30.00 1412.5 2121.6 59.8 3/23/95 5:45.00 2082.1 2121.6 59.8 Guns fired @ 5:42. 3/23/95 6:00.'00 2427.81 2115.8 61.5 , open well @ 6:05. 3/23/95 6:15.00 225.6 2087.9 55.0 3/23/95 6:30.'00 199.3! 2095.2 50.4 3/23/95 6:45.00 208.1 2095.2 48.7 3/23/95 7:00.00 221.2, 2098.2 49.2 3/23/95 7:15.1)0 231.5 2108.4 51.5 3/23/95 7:30:00 101.1 2111.4 52.1 3/23/95 7:45:00 109.9 2123.1 51.5, 3/23/95 8:00:00 11,7.2 2133.3 52.6 3/23/95 8:15.'00 134.8'2153.8 53.7 3/23/95 8:30.'00 140.7 2149.5 55.4 3/23/95 8:45.1:)0 152.4 2149.5 56.0 ,, 3/23/95 9:00:00 164.1 2167.0 52.8 , ,, 3/23~5 9:15.00 193.4 2190.5 52.3 , ,,, , 3/23/95 9:30:00 243.2 2181.7 51.5 3/23/95 9:45.'00 332.6 2177.3 52.4 3/23/95 10:00.00 90.8 2197.8 55.3 ,, 3/23/95 10:15.O0 67.4 2175.8 56.0 3/23/95 10:30.1:)0 98.2 2194.9 56.8 3/23/95 10:45.00 131.9 2190.5 57.9 3/23~5 11:00.'00 168.5 2225.6 55.7 3/23/95 11:15.1:)0 180.2 2200.7 56.7 3/23/95 11:30.'~ 130.4 2197.8 53.7 , , 3/23/95 11:45.00 145.1 2249.1 52.6 3/23/95 12:00:00 126.0 2250.5 51.5 3/23/95 12:15:00 120.1 2276.9 51.0 , , , 3/23/95 12:30:00 130.4; 2304.8 49.9 3/23/95 12:45:00 140.7 2309.2 48.7 ' 3/23/95 13:00.00 145.1 '2342.9 48.2 3/23/95 13:15:00 148.0 2361.9 47.7 ,, , 3/23/95l 13:30:00 152.4 2385.3 47.2 , , 3/23/95! 13:45.O0 153.8 . 2360.4 46.7' 3/23/95; 14:00:00 152.4 2276.9 46.7 , , 3/23/95i 14:15.00 153.8 2293.0 46.7 3/23/95! 14:30:00 156.8 2419.0 46.2 3/23/951 14:45:00 153.8 2410.3 46.2 3/23/951 15:00:00 153.8 1071.1 ' 46.2 Close PCT & manifold. REPORT23.XLS Page I of I WELL TEST DATA BY DAU BADAMI #5 MAIN FLOW, UPPER ZONE 3/24/95 DATE TIME-- TBG- CSG ~HT STATIC S~P DIFF GAS GAS P~MARK PRESS PRESS PRESS TEMP PRESS TEMP RATE PSIG PSIG "F PSIG ~F IN H~O ~F MSCF/D 3/24/95 0:00.'O0 369.2 291.6[ 67.0 Open well @ 0:06. 3/24/95 O: 15.'00 320.9 2426.4 62.1 3/24,95 0:30.1::)0' 317.9 2427.8 58.0 3/24/95 0:45.1:)O 290.1 2417.6 52.7 3/24/95 1:00:00 227.1 2407.3 48.7 3/24/95 1:15.00 197.8 2404.4 46.2 3/24/95 1:30.'00 191.9 2410.3 44.4 , ,,, 3/24/95 1:45.O0 197.8 2416.1 43.3 3/24/95 2:00.1:)0 213.9 2438.1 42.7 3/24/95 2:15.'00 213.9 2441.0 42.1 3/24/95 2:30.'00 212.5 2474.7 42.7 Put into seperator. 3/24/95 2:45:00 230.0~ 2479.1 43.3 83.8 102.0 47.8 100.0 89.79 3/24/95 3:00:00 237.4 2483.5 43.8 86.5 95.0 74.0 93.0 114.18 3/24/95 3:15.'00 219.8 2489.4 44.3 86.8 102.0 52.0 100.0 95.10 3/24/95 3:30.'00 203.7 2507.0 44.9 81.7 107.0 47.4 105.0 87.23 , 3/24/95 3:45:00 199.3 2508.4 45.4 · 75.1 108.0 38.3 106.0 76.53 , , 3/24/95 4:00.'1:)0206.6 2508.4 45.4 74.9 110.0 35.9 108.0 73.54 3/24/95 4:15.1:)0 213.9 2512.8. 44.9 73.9 112.0 44.1 110.0 81.78 3/24/95 4:30:00 213.9 2523.1 44.9 78.5 114.0 41.1 112.0 80.95 3/24/95 4:45.'00 215.4 2530.4 45.4 81.1 115.0 41.7 113.0 82.46 3/24/95 5:00:00 215.4 2528.9 45.9 81.2 117.0 49.1i 115.0! 88.47 ,, , , , 3/24/95 5:15:00 215.4 2524.5 45.9 77.9 122.0 54.3 120.0 91.40 3/24/95 5:30:00 218.3 2533.3 45.9 75.9 126.0 64.6 124.0 97.80 3/24/95 5:45:00 215.4 2545.1 45.9 76.3 127.0 64.2 125.0 97.25 3/24/95 6:00:00 208.1 2555.3 46.5 81.6 131.0 45.9 129.0 83~40 3/24/95 6:15.'00 206.6 2577.3 46.5 78.3 132.0 47.9 '130.0 85.12' ' ..... 3/24/95 6:30.1:)0 209.5 2572.9 47.1 78.3~ 134.0 47.7 132.0 84.68 3/24/95 6:45:00 213.9 2578.8 47.7 76.3 135.0 60.4 133.0 93.28 , 3/24/95 7:00.1:X) 213~9 2577.3 48.2 73.3 137.0 62.7 135.0 93.91 , , 3/24/95 7:15:00 212.5 2594.9 48.2 73.6 137.0 62.8 135.0 94.07 3/24/95 7:30.'00 212.5 2618.3 48.2 73.3 137,0 62.5 135.0 93.63 , 3/24/95 7:45:00 208.11 2622.7 48.2 72.8 137.0 62.1 135.0 93.09 , , , 3/24/95 8:00.1::)0208.1 2624.2 48.21 72.5 139.O 61.9 137.0 92.83 , 3/24/95 8:15:00 206.6 2627.1 48.2 72.5 139.0 62.1 137.0 92.71 , , 3/24/95 8:30:00 206.6 2628.6 48.2 72.6 139.0 62.4 137.0 93.00 3/24/95 8:45.O0 . 206.6 1 2624.2 48.2 72.6 139:.0 61.5 137.0 92.14 3/24/95 9:00:00 206.6 2634.4 48.2 '79.6 141.0 44.6 139.0 82.06 3/24/95 9:15.1:)0 208.1 2624.2 48.7 81.7 140.0 45.4 138.0 83.97 , 3/24/95 9:30.00 208.1 2628.6 48.7 81.9 139.0 42.0 137.0 80.73 , 3/24/95 9:45:00 212.5 2624.2 49~3 86.5 138.0 34.2 136.0 74.74 , 3/24/951 10:00:00 212.5 2634.4 49.8 85.9 137.0 33.9 135.0 74.39 3/24/95 10:15.O0 213.9 2628.6 50.4 85.7 132.0 33.9 130.0 74.46 , ,, 3/24/95 10:30:00 213.9 2650.5 50.4 85.7 132.0 33.7 130.0 74.33 3/24/95 10:45:00 213.9 2635.9, 50.4 85.7 132.0 33.7 130.0 74.33 , 3/24/95 ~. 11:00.'00: 212.5 2641.8 50.4 85.1 129.0 33.4 127.0 74.09 , , , ,~ , 3/24/951 11:15:00 213.9 ' 2656.4 50.4 84.4 128.0 33.2 126.0 73.51 , 3/24/95 11:30:00 213:9 2654.9 50.9 83.8 128.0 33.2 126.0 73.43 , , , 3/24/95 11:45:00 2'12:5 2641.8 50.9 84.2 126.0 33.1 124.0 73.82 3/24/95 12:00.1:)0.: 212.5 2640.3 50.9 84.; 123.0 33.21 '121.01 73.81 , 3/24/95 12:15.'00 212.5 2652:0' 50.9 84.2 120.0 33.2 118.0 73.83 ,, 3/24/95 12:30.'00 212.5 r 2634.4 51.5 83.2 118'0 33.0 116'0 73.37 , REPORT24.XLS Page 1 of 2 WELL TEST DATA BY DAU BADAMI #5, MAIN FLOW UPPER ZONE 3/24/95 ,, ,, ,~ r r DATE TI TBG CSG ~,~'IT STATIC SEP DIFF GAS GAS RE~ PRESS PRESS PRESS TElVIP PRESS TElVlP RATE PSIG PSIG OF PSIG OF IN H20 °F MSCF/I) 3/24595 12:45.1)0 212.5 2634.4 51.5 82.9 118.0 32.2 116.0 72.62 3/24/95 13:00.120 212.5 2640.3 51.5 85.5 116.0 28.9 114.0 69.61 3/24/95 13:15.~20 212.5 2647.6 51.5 86.4 115.0 29.1 113.0 70.24 3/24/95 13:30.1)0 212.5 2647.6 51.5 85.0 115.0 31.9 113.0 73.18 3/24/95 13:45.1)0 213.9 2660.8 51.5 78.4 115.0 40.4 113.0 79.39 3/24/95 14:00.1)0 209.5 2647.6 51.5 76.5 115.0 39.5 113.0 77.61 3/24/95 14:15.1)0 209.5 2656.4 51.5 76.2 115.0 39.3 113.0 77.29 3/24,95 14:30.1)0 209.5 2660.8 51.0 76.7 115.0 36.9 113.0 74.89 , 3/24/95 14:45.1)0 208.1 2672.5 50.5 77.3 115.0 36.3 113.0 74.81 3/24/95 15:00.1X) 208.1 2857.9, 50.5 78.6 115.0 33.8. 113.0 72.49 3/24/95 15:15.1)0 209.5 2656.4 50.0 79.3 116.0 33.5 114.0 72.46 3/24/95 15:30.1)0 209.5 2646.2 50.0 79.5 116.0 32.9 114.0 72.09 3/24/95 15:45.O0 209.5 2652.0l 50.5 81.9 116.0 32.3~ 114.0 72.20. 3/24/95 16:00.1)0 209.5 2662.3 51.5 79.4 116.0 ' 38.1{ 114.0 77.231 ' 3/24/95 16:15.1)01 208.1 2656.4 51.5 78.8 116.0 37.7 114.0 76.54 3/24/95 16i30.O0: 208.1 2641.8 52.1: 77.7 116.0 37.4 114.0 75.78! 3/24/95 16:45.O0{ 206.6 2650.5 52.1 78.4 116.0 37.7 114.0 76.49i ,,,,,, , , 3/24/95 17:00.1)0 206.6 2647.6 51.6 77.4 116.0 37.3 114.0 75.65 3/24/95 17:15.1)0 206.2 2634.~ 51.7! 78.4 120.0 37.5 118.0 75.65 , 3/24/95 1'7:30.1)0 205.7 2638.8 51.7 78.4 120.0 37.7 118.0 76.00 3/24/95 17:45.120 205.7 2624.2 51.2 78.4 121.0 37.7 119.0 76.201 3/24/95 18:00.1)0 205.0 2616.8 51.2 77.5 123.0 37.8 121'.0i 76.13 3/24/95 18:15.1)0 204.2 2630.8 51.5 78.4 127.0 37.7 125.0 75.7; ' , 3/24/95 18:30.O0 203.3 2627.1 51.5 78.1 129.0 37.0 127.0 75.73 ,, 3/24~95 18:45.120 203.3 2628.6 51.4 78.3 137.0; 37.4 135.0 74.76 3/24~95 19:00.O0 203.3 2630.0 51.6 78.4. 137.O 48.5 135.0 74.73 , , , 3/24/95 19:15.'~ 201.3 2628.6 51.5 78.0 139.0{ 46.5 137.0 85.20 3/24/95 19:30.120 200.5 2634.4 51.4 77.4' 139.0 47.5 '137.0 83.09 ' 3/24/95 19:45.1)0 199.3 2634.4 51.6 78.2 141.0 48.0 139.0 83.71 ,, 3/24/95 20:00:~ 199.3 2638.8 51.6 78.4 141.0 48.5 139.0 84.37 , 3/24/95{ 20:15.1)0 199.3 2660.8 51.6 76.9 144.0 48.5 142.0 84.15 3/24/95{ 20:30.1)0 199.3 2493.8 51.6 76.8 144.0 48.7 142.0 84.23 3/24/95 20:45.00 199~3 2499.6 51.6 76.8 144.0 48.9 142.0 84.35 , , 3/24/95 21:00.'~ 199.3 2499.6 51.5 76.3 144.0 48.5 142.0 83.B0 , , 3/24/95 21:15.120 199.3 2502.6 51.5 76.6 143.0 45.5 141.0 81.18 3/24/95 21:30.120 202.2 2508.4 51.5 78.8 143.0 40.4 141.0 77.46 3/24/95 21:45.X)0 202.2 . 2508.4 50.4 77.6 143.0 39.6 141.0 76.54 3/24/95 22:00.00 202.2 2512.8 49.2 79.0 143.0 39.4 141.0 74.79 , , 3/24/95 22:15:00 203.7 2511.4 49.2 76.0 137.0 38.1 135.0 74.47 ,, , , 3/24/95 22:30.130 203.7 2508.4 49.2 77.5 134.0 34.7 132.0 71.69 3/24/95 22:45.1)0 206.6 2512.8 49.2 81.3 134.0 31.4 132.0 70.08 3/24/95 23:00.120 208.1 2512.8 49.2 82.B 134.0 32.2 132.0 71.36 3/24/95 23:15:00 206.6 2508.4. 49.2 84.3 132.0 33.1 130.0 73.28 , ,, 3/24/95 23:30:00 206.6 2502.61 49.2 83.4 126.0 34.4 124.0 74.50 3/24/95 23:45.00 208.1 2512.8 49.2 83.0 126.0 34.1 124.0 74.31 3/25/95 0:00.~30 208.1 2511.4 49.2 67.7 126.0 11.6 124.0 32.59 Closed PCT @ 0:02. , 3/25/95 0:00.'04 , Close manifold 0:04. REPORT24.XLS Page 2 of 2 WELL TEST DATA BY DAU BADAMI #5 INITIAL 3/16/95 DATE Tlk~. TBO' CSO WHT ~TATIC SEP DIFF OAS OAS REIVtAYJ( PRESS PRESS PRESS 'TEIVIP PRESS TEIVlP RATE PSIG PSIG ~F PSIG ~F IN H~O ~F MSCF/D 3/16/95 4:00.130 2143.6 2301.8 43.0 0.0 71.2 3/16/95 4:05.130 2155.3 2284.2 44.2 0.0 70.3 3/16/95 4:10.1:)0 2165.6 2272.5 44.9 0.0 69.5 3/16/95 4:15.130 2172.9 2265.2 44.9 0.0 68.7 3/16/95 4:20.130 2181.7 2259.3 44.3 0.0 68.1 3/16/95 4:25.00 2184.6 2250.5 44.3 0.0 68.1 3/16/95 4:30.130 3235.2 2260.8 43.7 0.0 68.1 Press tt~ to fire ~lun @ 4:28. 3/16/95 4:35.130 3098.9 2310.6 44.3 0.0' 68.0 3/16/95 4:40.~31 1172.2 2240.3 42.4~ 0.0 67.4 3/16/95 4:45.130 1490.1 2231.5 41.3 0.0 67.0 Guns fired @ 4:46. 3/16/95 4:50.1:)0 1542.9 2221.2 39.6 0.0 66.3: Open well to tank @ 4:48. 3/16/95 4:55.~)0 1336.3 2211.0 37.1 0.0 65.8 3/16/95 5:00.~X) 1219.0 2215.4 36.6 0.0 65.8 3/16/95 5:05.1)0 1049.1 2221.2 37.7 0.0 66.5 3/'16/95 5:10.130 773.6 2221.2 36.6 0.0 67.2 , 3/16/95 5:15:00 816.1 2231.5~ 36.6 0.0 67.5 "3/16/95 5:20:00 1084.2 2243.2 36.6 0.0 67.5 3/16/95 5:25.1:)0 1252.7 2250.5 36.1 0.0 67.5 ,, 3/16/95 5:30:00 1082.8 2253.5 36.1 0.0 67.0 3/16/95i 5:35:00 1119.4 2256.4 37.3 0.0 66.4 ,, , , 3/16/95: 5:40.1:)O 1027.1 2259.3 37.3 0.0 66.1 3/16/95 5:45.1:)0 1071.1 2260.8, 37.9 0.0 65.5 3/16/95 5:50:00 1079.9 2265.2 39.1 0.0 65.0 ,,, , 3/16/95 5:55:00 1096.0 2268.1 39.6 0.0 64.6 , 3/16/95 6:00.1:)0 1157.5 2272.5 39.1 0.0 64.6 , 3/16/95 6:05.130 1179.5 2274.0 39.1 0.0 65.3 , 3/16/95 6:10.130 1207.3! 2274.0 39.1 0.0 66.1 ,,, 3/16/95 6:15:00 1100.4~ 2276.9 40.8 0.0 67.0 , , 3/16/95 6:20:00 1112.1 2276.9 40.2 0~0 67.8 3)16/95 6:25:00 1244.0 2281.3 42.0 0.0 68.3 ' ' ,,, 3/16/95 6:30.~0 1098.9 2278.4 43:7 0.0 69.0 , , 3/16/95 6:35:00 1188.3 2281.3 44.9 0.0 69.2 3/16/95 6:40.00 1147.3 2282.8 46.3 0.0 69.5 , 3/16/95 6:45.130 1119.4 2278.4 46.3 0.0 68.9 3/16/95 6:50:00 1138.5 2282.8 45.1 0.0 68.2 , 3/16/95 6:55:00 1147.3 2284.2 44.0 0.0 67.5 3/16/95 7:00.1:)0 1112.1 2287.2 42.9 0.0 66.8 3/16/95 7:05.1:)0 1169.2 2288.6 42.3 0.0 66.6 3/16/95 7:10.~X) 1128.2 2288.6 41.2 0.0 66.7 3/16/95 7:15.O0 1052.0 2290.1 40.6 0.0 67.2 , , 3/16/95 7:20.130 1223.4 2290.1 40.6 0.0 66.9 3/16/95 7:25.00 1060.8 2290.1 41.7 0.0 66.3 3/16/95 7:30.00 912.8 2284.2 43.5 0.0 65.7 , 3/16/95 7:35:00 901.1 2282.8 44.2 0.0 64.5 , , , , 3/16/95 7:40:00 934.8 2284.2 47.1 0.0 63.6 , 3/16/95 7:45:00 983.2 2288.6 49.5 0.0 62.8 3/16/95 7:50.1:)0 i046.2 2290.1 50.7 0.0 62.2 , 3/16/95 7:55.~:)0i 1066.7 2293.0 51.2 0.0 61.5 ~, , 3/16/95 8:00.'~ 1126.7 2296.0 51.8 0.0 60.7 , 3/16/95 8:05:00!, 1173.6 2301.8 53.0 0.0! 60.0! , 3/16/95 8:10.1:)0 1314.3 2309.2 52~5' 0.0 60.7 REPORT16.XLS Page I of 2 WELL TEST DATA BY DAU BADAMI #5 INITIAL FLOW ZONE 3/16/95 DATE TIME TBG CSG WHT STATIC SEP DIFF GAS GAS REMAYJ( PRESS PRESS PRESS TElVIP PRESS TEl'viP RATE PSIG PSIG ~F PSIG ~F IN H~O ~F MSCF/D 3/16/95 8:15.130 1591.2 2564.1 52.0 0.0 63.2 3/16,95 8:20.130 1607.3 2316.5 53.2 0.0' 65.0 3/16/95 8:25.130 1645.4 2317.9 53.4 0.0 65.0~ 3/16/95 8:30.1:)0 1726.0 2320.9 53.4 0.0 65.0 3/16/95 8:35.1:)0 1780.2 2323.8 54.0 0.0 64.9 3/16/95 8:40.1:)0 1619.0 2323.8 53.8 0.0 64.4 3/16/95 8:45.1~0 1575.1 2322.3 53.2 0.0 63.5 3/16/95 8:50:00 1517.9 2322.3 53.2 0.0 61.9 3/16/95 8:55:00 1386.1 2317.9 53.21 0.0 60.5 3/16/95 9:00:~ 1361.2 2317.9 53.2 0.0 59.7 3/16/95 9:05:00 1323.1~ 2320.9 53.2 23.8 59.0 '3/16/95 9:10.1X) 1173.6 2317.9 53.2 77.5 58.7 3/16/95 9:15.~0 1090.1 2322.3 53.8 76.6 57.9 3/16/95 9:20.1:)0 1035.9 2332.6 53.9 74.3 57.8 3/16/95 9:25:00 1015.4 2345.8 52.8 74.1 58.0 46.1 44.0 26.2 , 3/16/95 9:30.1:)0 1011.0 2360.4 51.2 78.1 58.0 44.6 44.0 540.9 , 3/16/95 9:35.130 1002.2 2372.2 48.7 78.6 58.0 46.5 45.0 652.7 , , 3/16/95 9:40.130 990.5 2383.9 47.6 78.3 58.0 45.0 45.0 641.5 3/16/95 9:45:00 981.7 2395.6 47.0 80.9 58.0 38.2 45.0 595.6 3/16/95 9:50:00!' 972.9 2410.3 46.4 80.1 '58.0 33.2 45.0 554.8 3/16/95 9:55.130: 989.0 2332.6 "46.9 78.2 58.4 36.5 45.0 522.6 3/16/95 10:00:00 978.8 2271.1 46.9 84.1 58.2 33.9 46.0 485.3 , , , , ,,,, , ,,, ,, 3/16/95 10:05:00 977.3 2282.8 46.9 79.9 57.9 31.7 46.0 466.7 3/16/95 10:10:00 1008.1 2284.2 46.9 78.1 57.7 36.4 46.0 497.6 , 3/16/95 10:15:00 1016.8 2293.0 46.9 78.2 57.7 41.2 47.0 532.3 , ,, 3/16/95 10:20:~ 1018.3 2301.8 47.5 81.1 57.7 37.2 47.0 509.7 3/16/95 10:25:00 1022.7 2310.6 48.2 82.3 57.7 43.1 47.0 556.6 , , 3/16/95 10:30.'~ 1028.6 2317.9 48.8 77.7 57.2 40.6 47.0 518.0 3/16/95 10:35:00 1033.0 20.5 48.8 61.9 57.1 1.4 45.0 88.0 Close PCT. REPORT16.XLS Page 2 of 2 Production Testing Services WELLTEST FIELD READING .CUSOMER B.P. EXPLORATION WELL: #5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-16-95: PAGE: I of 3 ,TOMER REP: N. Scales FIELD: DS# Badami Lease: HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WA i E.~< CUM .~LOCK CASING CHOKE CHOKE VF_.SSEL OIL OIL MEAS. OIL GRAY. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT, WAT I'IME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAY. ~EMP. BS&W AT60F' FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwlt Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F eeL APl DEC F % APl FRAC BBL STB/D BBL eeL BaL/O BBL COMMENTS Pressure tbg. to tim funs 0428 2300 0 0440 2300 0 1 500 Waiting for guns to tim Guns fired 0446 2300 0 205O Open well to tank 0448 t0 2100 201 0453 2200 10 t 440 Open to 15/64 adj. 0500 2200 15 1250 Shut in well ~ surface 0502 2200 0 1475 0503 15 1475'Open well, to tank 0510 ~ 2200 O* 37 850 15 Flow to stock tank 0515 2200 0 36 890 15 "Flow through heater choke 0520 2200 0 36 1050 15 1415 20.15 bbl back 0525 2250 0 36 1270 15 0530 2250 0 36 1150 15 515 24.44 bbls back , 0540 2250 0 1210 15 832 30.22 bbls back 0550 2265 0 38 1110 15 698 35.07 bbls back 0600 2270 0 39 1110 15 484 38.43 bbls back 0610 2290 0 39 1125 15 172 590 42.53 bbls back 0620 2290 0 40 1185 15 174 590 ~,6.63 bt)Is back 0630 2278 0 44 1200 15 174 431 49.62 ht)l back 0640i 2278 0 46 1140 15 164 644 54.09 bbls back 0650 2278 0 45 1100 15 178 428 57.06 bbls back GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFIC ORIFICE GAS MEAS, SEP CONV. ORIFICE TEMP. GRAVIT COMPR. XPANS 'PRESS. FLOW TOTAL GASIOI GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTO XTENS RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y ~wPsep Gg CDR1 CDR2 GORT TGLR TLGR WOR _ PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFIST SCFISTB SCFISTB SCFIBBL BBL/MMCF BBL/STB COMMENTS , _ _ _ _ ,,, _ -- "1 _ MUD WT. l~.61bsln SHOT/F 1_~2 TUB/DP 3.5~" ACKER DT (F'r) 11073ft SEPARATOR H20 METER SIZE 1_ METERRUN 5.761/1.939 URGE TANK STATIC PRESS RNG 0-200, WELLTEST.XLS I DISP. FLUID BRIN Diesel ST DIA PIPE VOL 82bt)l TOTAL DT (FT) OIL METER SIZE 1_ METER RNG 137-2570 DIFF PRESS 0-200 METER TYPE I~,n~eI ~', PERF INT CASING 7: DEPTH REF K...~B OIL METER RNG 137-257 METER TYPE Daniel Sr. STATIC PRESS 0-1500 TER RUN SIZE 1.939 STOCK TANK Storage Total: 506____.~0 BBL/in: Various # TANKS: 1:3 ARD CONDITIONS Psc 14,73 P,~l TSC 6ooF DIFF PRESS RNG 0-50"VV.C Production Testing Services CUSTOMER: BP EXPLORATION. WELL: #5 WELLTEST FIELD READING FORMATION: PTS REP: M. Hewston DATE:03-16-95 PAGE: 2 OF 3 CUSTOMER REP: Nick Scales FIELD: DS # Badami LEASE: ' WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK " I I OIL TEMP. CHANGE OIL CUM. CHANG WATE CUM CLOC CASING CHOKE CHOKE VESSEL 'OIL OIL MEAS. OIL GRAV. SHRINK. CORR. INOIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRES SIZE TEMP H2S CO2 .SALINITY P.H. TEMP. COUN. GRAY. TEMP. BS&W AT60 FACTOR FACTOR COUNTER RATE OIL COUN COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw PSIG IN DEG F PSIG IN DEG F PPM DEG F BBL APl DEG F % APl FRAC BBL STB/D aBL BBL BBIJD BBL COMMENTS 0700 2278 0.00 43 1180 15 188 635 61.53 bbls back, switch tanks , 0710 2278 0.00 41 1060, 15 192 , 1182 69.74 ~712 Gas ~ surface 0720 2278 0.00 42 1150 15 180 648 74.24 bbls back, 0730 2278 0.00 44 1050 20 162 720 ,_,___~ 79.24 074'"'--'~ 2278 0.-""~ 4~'--'~ 90-'----~ 2'"--""~ - 163 288 81.24 07-----~ 78 0.00 51 1000 2--'~ 1-~'='--~' .......... 288 83.24 ' 864 89,24 0800 2278 0.00 53 1150 20 177 -------- 081'--"~' 2300 0.0"---'~ 5m"--"~ 140----'"~ ~ ~ .......... 576 93.24, 2300 csg 082--"~ 2300 0.0~' 53 1650 20 176 468 96.49 0830 2300 0.00 54 1700 20 180 252 98.24 0840 2300 0.00 54 1575 25 0 98.24 , 0850 2300 0.00 53 1390 25Pumping Tank ,, 0900 2300 0.00 53 1370 25 720 103.24 0910 2300 0.00 44 1300 25 ...., 2160 118.24 092-'--~ 2300 0.00 44 1060 25______ __ __ ----.---- . . ---,-,--,, 86~4 ~ 124.24 ~ 2300 0.0~"-~ 4~ 107'""--~ ~ ....... i 1181 132.44 , , 1074 139.9 0940 2300 0.00 45 1000 25 , 1510 150.39 0950 2400 0.00 45 1000 25 i' , 1611 161.58 1000 2300 0.00 47 1000 25 " 1825 174.26 1010 1300 0.00 47 1030 25 ' ' 1611 185.45 1020 2300 0.00 47 1025 25 , ABS UNIT BASIC FLOWIN GAS SUPER GAS GAS CUM. SEP, SEP. OIL TOTAL':i GAS LIQUID WATER " CLOC ORIFI ORIFIC GAS MEAS. SEP CONV. ORIFIC TEMP. GRAVl COMPR. EXPAN PRES FLOW TOTAL GASIO GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS, SIZE DIFF. GRAV, TEMP. PRESS. FACTO FACTO FACTOR FACTO FACTOR FACTO EXTE RATE GAS RATIO SOLUTIO RATIO,:" RATIO RATIO RATIO Psep d hw T~ Psepa Fu Fb Fff Fg Fpv Y hwPse G~ GOR1 GOR2 GORT TGLR TLGR WOR :PSlG IN IN H20 DEG F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFI MMCF SCFIS SCFISTB SCFISTB SCFIBBL BBL/MM£ BBLISTB , 0800 5 1.00 9 0.81 74 19.73 0.024 212.47 0.9868 1.118 1,0016 9943 13.08 77 0.55' flowin~l~a~ from sur~letank 0820 5 1.00 15 0.81 48 19.73 0.024 212,47 0.9831 1.118 1,0016 9905 16,88 98 1.911 0830 2 1.00 7.5 0.81 80 16.73 0.024 212.47 0,9813 1.118 1.t3013 9943 10,95 64.2 ,2.37 , , , 0840 15 1,00 5 0,81 80 29.73 0.024 212,47 0,9813 1.118 1.0024 9979 12.04 70 2.87 , 0850 20 1,00 10 0.81' 72 34.73 0,024 212.47 0,9887 1.118 1.003 9964 18.44 109,.3 3.65 , 0900 40 1.13 35 0.81 68 54.73 0.024 276.2 0,9924 1.118 1,0051 9819 43.47 335.4 6.04 , 0910 100 1.25 38 0.74 38 114.73 0.024 314.95 1.0219 1.16251 1.0123 9962 66.02 597.88 10.3 Gas now flowin~l fo~m Separator 0920 90 1.25 60 0.74 42 104.73 0.024 314.95 1.0178 1.1625 1.0108 9935 79.27 711 15.4 , 0930 100 1.25 40 0.74 44 114.73 0.024 314.95 1.0158 1.1625 1.0118 9960 67.74 609 19.75 0940 100 1.25 42 0.74 44 114.73 0.024! 314.95 1.0158 1.1625 1.0118 9958 69.42 624 24.2 0950 100 1.25 40 0,74 45 114.73 0.024 314.95 1.0148 1.1625 1.0117 9960 67.74 608 28.5 , 1000 90 1.25 20 0.74 45 104.73 0.024 314.95 1.0148 1.1625 1.0106' 9978 45.77 411 31.43 1010 90 1.25 40 0.74 45 104.73 0.024 314.95 1.0148 1.1625 1.0106 9956 64.72 580 35,57 1020 90 1.25 40 0.74 45 104.73 0.024 314.95 1.0148 1.1625 1.0106 9956 64.72 580 39.71 , , , , · ~l ,n~^n- 4') ~,h~ ~r~T~ ~'~ TIIRII3P 3 5" PACKER DT ~FTI 11073ft SEPARATOR H20 METER SI 1 METER .76111.939 SURGE TANK STATIC PRESS 0-200 DISP. FLUID 8RIN Diesel ST DIA PIPE VOL 82bbl TOTAL DT (FT) OIL METER SIZE 1 H20 METER RN 137-2570 DIFF PR 0-200 GAS METER TYPE Daniel Sr. PERF INT CASIN 7" DEPTH REF KB OIL METER RNG 137-25 GAS METER TY Daniel Sr. STATIC 0-1500 METER RUN SIZE 1.939~ STOCK TANK Storage Total: 5060 BBLli Variou # TANKS: 13 STANDARD CONDITIONS Psc 14.73 P TSC 00oF DIFF PRESS RNG 0-50"W.C WELLTEST. XLS Production Testing Services WELLTEST FIELD READING CUSTOMER: BP EXPLORATION. WELL: #5 FORMATION: PTS REP: M. Hewston DATE:03-16-95 PAGE: 3 OF 3 CUSTOMER REP: Nick Scales FIELD: DS # Badami LEASE: WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE'WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAY. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME pR~_$$. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAY. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN COUN. RATE BBL Pbh Cwh Twfl Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO ew qw PSIG IN DEC F PSlG IN DEC F PPM DEC F BBL APl DES F % APl FRAC I~L STB/D BBL BBL BBL/D BBL COMMENTS · 1030 2300 25 47 1030 0 194.41 bbls recovered 1055 0 0 0Sl~u! in ,~.,hlumt~ler tool 199.79 recovered after , all blown down. , ABS UNIT BASIC FLOINING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM OOIM ODIM ODIM ODIM MSCF/D MMCF SCFISTB SCF/S¥~ SCF/~¥~ SCF/BBL BBL/MMCF BBI./STB COMMENTS 1030 90 1.251 40 0.74 I 4.7 104.73 0.024 314.95 1.0127 1.1625 1.0105 9956 64.724 579 44 , , , , , , , i , , , ,, .,. MUD WI'. 12.6 SHOTIFT 12 TUB/DP 3.5in PACKER DT (FT) 11073 SEPARATOR H20 METER SIZE 1" Ml=.i t-R RUN SIZE 5.761 SURGE TANK STATIC PRESS RNG 2 DISP. FLUID BRIN Diesel ST DIA PIPE VOL 82bbl TOTAL DT (F'I') OIL METER SIZE 1" H20 METER RNG 137-2570 DIFF PRESS RNG 200._..~" GAS METER TYPE Daniel Sr. STD COND: Psc 14.73 Tsc 60 PERF INT CASING 7 DEPTH REF KB OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500~ METER RUN S~ZE 1.939 WELLTEST.XLS STOCK TANK TOT STOR (BBL) 5060 # TANKS 13 BBI_/IN: VARIOUS DIFF PRESS RNG 50" Production Testing Services WELLTEST FIELD READING CUSTOMER: BP EXPLORATION. WELL: #5 FORMATION' PTS REP: M. Hewston DATE:03-16-95 PAGE: I OF 2 CUSTOMER REP: Nick Scales FIELD: DS # Badami LEASE: ~t,,.J~,l I ~.,/IVll,--I'~, I'qkL.,.I · IllVI~ i,./,iv~,..41~.~I,.; · WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM I CLOCK C~S~NG CHOKE CHOKE VESSEL O~L O~L ME~S. O~L GRAY. SHR~NK. CORR. ~N mL FLOW TOT~ H20 IN H20 FLOW OT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT60 F FACTOR FACTOR COUNTER RA~E O~L COUN COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC eeL STBK) BBL BBL BBL/D BBL COMMENTS OPEN ON 10148. START TANK #1 1930 2200 OPEN TO SEPARATOR 15/64 1935 2260 15 OPEN TO 20/64 1937 2280 20 48 1235 FULL 1940 2200 25 46 975 OPEN 4.25 2040 14.17 OPEN TO 25/64 1945 2200 30 45 900 Trace 25.2 11.23 1611 25.4 OPEN TO 30/64 ,CLOSE TO 25/64 1946 2200 25 45 870 WELL SHUT IN 2000 2200 25 44 905 OPEN WELL 10148 2103 2255 10 42 2500 2115 2300 25 42 1130 5.97 716.4 31.33 OPEN TO 25/64 (~2108HRS ~ HEATER 2130 2250 0 42 1162 25 Trace 25.8 5.22 501 36.55 2145 2300 0 44 1260 25 Trace 26.11 2506 62.66 _P_~_n0 2300 0 44 1299 25 Trace m 18.66 1791 81.32 2215 2300 0 43 1341 25 Trace 2.23 214 83.55 Rocked Choke 2230 2300 0 45 1355 30 Trace 11.94 1146 95.49 Rocked Choke 2300 2400 30 45 710 48 1% 26 , , 33.21 1593 128.7 16.32 0.34 2330 2300 30 48 990 78 Trace 26.5 1271 155.2 0.34 Rocked Choke 2400 2300 30 49 797 78 Trace , ~ 33.4 1603 188.6 0.34 0030 2300 30 49 835 62 Trace 26 42.7 2051 231.3 0.34 0100 2440 30 49 820 62 Trace 23.87 1145 255.17 0.34 0130 2293 0 49 945 30 Trace 30.96 1486 286.13 0.34 0200 2312 30 49 685 78 Trace 26.27 1262 312.4 , 0.34 ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu FI3 Ftf Fg Fpv Y hwPsepa Gg CDR1 GOR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEG F PS'IA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCF/D MMCF SCFISTB SCFISTB SCFISTB SCFIBBL SBIJ;,'.,¥.CF BBL/STB COMMENTS i 1950 150 1.25 50 0.82 70 164.73 0.024 314.95 9905 1.1625 1.0148 0.9965 90.755 798.82 8.32 495.8 , 2130 0.875 0.84 0.9822 , 2145 175 0.875 96 0.84 79 189.73 0.024 153.63 0.9813 1.1 043 1.0196 0.9942 134.959 547.15 14.02 218.29 , 2200 175 0.875 85 0.84 80 189.73 0.024 153.63 0.9795 1.1043 1.0195 0.9949 126.992 514.65 67.62 287.3 , , 2215 175 0.875 60 0.84 82 189.73 0.024 153.63 0.9813 1.1043 1.0192 0.9964 106.694 432.14 112.62 261~8 . , 2230 175 0.875 97 0.84 80 189.73 0.024 153.63 0.9813 1.1043 1.0195 0.9942 135.66 549.38 118.35 479.3 , 2300 180 0.875 97 0.84 80 194.73 0.024 153.63 0.9813 1.1043 1.0195 0.9942 135.66 550.24 129.81 345 0.341 187082 0.01 2330 180 0.875 88 0.84 76 194.73 0.024 153.63 0.985 1,1043 1.0206 0.9949 130.905 533.04 140.91 419 2400 180 0.875 118 0.84 74 194.73 0.024 153.63 0.9896 1.1043 1.0209 0.9931 151.58 617.48 153.77 385.15 ,, 0030 180 0.875 116 0.84 71 194.73 0.024 153.63 0.9896 1.1043 1.0213 0.9932 150.29 614.27 166.56 300 0100 180 0.875 113 0.78 71 194.73 0.024 153.63 0.9896 1.1043 1.0213 0.9934 148.33 606.38 179.19 529 , 0130 180 0.875 86 0.78 69 194.73 0.024 153.63 0.9915 1.1043 1.0216 0.995 129.4 530.99 190.25 357 0200 180 0.875 172 0.8 69 194.73 0.024 153.63 0.9915 1.118 1.0206 0.9899 183.012 755.73 205.99 599 , , , , , MUD WT. 12....._~6SHOT/FT 12 TUB/DP 3.5in PACKER DT (FT) 11073 SEPARATOR H20 MI= I I=R SIZE 1" METER RUN SIZE 5.76_.._._~1 __ DISP. FLUID BRIN Diesel ST DIA PIPE VOL 82bbl TOTAL DT (F'r) OIL METER SIZE 1" H20 METER RNG 137-2570 DIFF PRESS RNG 200" GAS METER TYPE Daniel Sr. STD COND: Psc 14.73 Tsc 60 WELLTEST.XLS PERF INT CASING 7 DEPTH REF KB OIL METER RNG 137.2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500~. METER RUN SIZE 1.939 STOCK TANK TOT STOR (BBL) 5060 # TANKS 13 BBL/IN: VARIOUS DIFF PRESS RNG 50" ., Production Testing Services WELLTEST FIELD READING USTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-17-95: PAGE: 2 of 2 USTOMER REP: N. Scales FIELD Badami LEASE: '" WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK O~L TEMP. CHANGE O]1. CUM. CHANGE WATER CUM LOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAY. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COLIN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC BBL STIND BBL BBL BBL/D BBL COMMENTS ~ 2357 30 50 725 0 0 74 41 1~69 3534 0.034 3oo 2~0 30 50 715 74 TRACE 26.5 31.9 1531 ~5.3 0.034 330: 2400 30 51 710 0 0 77 TRACE 38.8 1861 424.1 0.034 400 2400 30 53 700 77 33.2 1593 457.3 0.034 '' 430 2300 30 51 700 0 0 77 TRACE 26 35.1 1685 492.4 0.034 500 2367 30 52 694 79 TRACE 43.3 1781 535.7 0.034 "530 2367 30 52 690 26.1 1504 561.8 0.034 540 30 14 1831 575.8 0.034 0541 Well Shut in "635 2200 0 2000 TRACE 26.5 Reopen well on 30144 positive choke 700 2175 30 47 720 50 190 74 39.98 2245 614.78 0.034 , 730, 2290 30 49 690 50 192 80 36.56 1755 651.34 0.034 800 2400 30 50 693 50 198 80 TRACE 26.5 35.81 1719 687.15 0.034 ..... 900 2400 30 49 690 50 200 80 TRACE 26 [ 66.03 1584 753.18 0.034 1000 2400 30 50 695 50 210 0 0 80 TRACE 26 70.13 1683 823.31 0.034 1100 2370 30 55 670 50 206 80 TRACE 26.1 70.88 1701 894.16 0.034 1200 2370 30' 53 668 50 294 0 0 80 TRACE 25.9 69.38 1665 963.54 0.034 1300 2200 30 57 666 50 206 ~ 82. TRACE 26.1 6938 1665 1032.92 0.034 , 1400 2200 30 59 661 50 206 0 0 83 TRACE 26 67,89 1630 1100.81 0.034, 1500 2210 30 60 660 50, 208 83 ,TRACE 26.1 68,32 1640 1169.13 0,034 Close Bottom Hole Test Tool 1550 0 0 150 Shut in surface Manifold GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID .WATER , .OCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL ME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR ;ACTOR FACTOR FACTOR EXTENS. RATE , GAS RATIO SOLUTION RATIO RATIO RATIO :~,ATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2. GORT TGLR TLGR NOR )SIC IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCF/D MMCF SCF/STB SCFISTB SCF/STB SCFIBaL BBL/MMCF BBI./STB COMMENTS 230 180 0.875 148 0.8 74 194.73 0.024 153.63 0.9868 1.118 1.0199 0.9913 169.76 698.26 220.53 354.6 , 300 180 0.875 144 0.8 78 194.73 0.024 153.63 0.9831 1.118 1.0194 0.9916 167.45 686.01 234.82 448 330 1802 0.875 134 0.8 791 194.73 0.024 153.63 0.9822 1.118 1.0193 0.9922 161.53 661.46 248.6 355.4 , 400 180 0.875 135 0.8 79 194.73 0.024 153.63 0.9822 1.118 1.0193 0.9921 162.13 663.88 262.43 416.7 i 430 180 0.875 132 0.8 78 194.73 0.024 153.63 0.9831 1.118 1.0194 0.9923 160.32 657.27 276.12 390 ..... i 500 180 0.875 134 0.8 78 194.73 0.024 153.63 0.9831 1.118 1.0194 0.9922 161.53 662.15 289.91 371.7 ..... 530! 180 0.875 132 0.8 0.79 194.73 0.024 153.63 0.9822 1.118 1.0193 0.9923 160.32 656.58 303.58 436.5 ,, 700 175 0.875 120 0,8 76 188.73 0,024 153.63 0,985 1.118 1.0191 0.9928 150.89 619.88 314.34 276.15 ..... 730 180 0.875 140 0.8 80 194.73 0.024 153.63 0.9813 1.118 1.0192 0.9918 165.11 675.16 328.41, 384.7 -- 800 180 0.875 136 0.8 80 194.73 0.024 153.63 0.9813 1.118 1.0192 0.9918 162.73 665.6 342.28 387.2 __ 900 180 0.875 120 0.8 78 194.73 0.024 153.63 0.9831 1.118 1.0194 0.993 152.86 627.13 355.34 395.7 -- 1000 180 0.875 124 0.8 76 194.73 0,024 153.63 0.9671 1.118 1.0173 0.9927 155.39 625.65 381.41 371.7 -- 1100 180 0.875 122 0.8 76 194.73 0.024 153.63 0.985 1.118 1.0197 0.9929 154.133 633.6 407.81 372.5 , ,, 1200 180: 0.875 120 0.8 78 194.73 0.024 153.63 0.9831 1.118 1.0194 0.993 152.86 627.13 433.94 376.6 .__ 1300 185 0.875 118 0.8 80. 199.73 0.024 153.63 0.9813 1.118 1.0197 0.9933 153.519 629,02 460.15 377.7 , - 1400 185 0.875 118 0.8 80 199.73 0.024 153.63 0.9813 1.118 1.0197 0.9933 153.519 629.02 486.36 386.05 _ 1500 185 0.875 117 0.8 80 199.73 0.024 153,63 0.9813 1.118 1.0197 0.9933 152.87 626.38 512.46 382.01 ,,, ,, ~lUO WT'. 12.6 SHOT/FT 12 T 3.5" PACKER DT (FT) 11073lt SEPARATOR H20 MP_~I=R SIZE 1 M~_iI=R R 5.761 SURGE TANK STATIC :)ISP. FLUID BRIN Diesel ST DIA PI 82bbl TOTAL DT (ET) OIL METER SIZE 1 H20 METER EEC 137-2570 DIFF PRE 200 GAS METER TYPE Daniel S,. WELLTEST.XLS :~ERF INT CASING 7" DEPTH REF OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC P 1500 METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBL/in: Various # TANK 13 STANDARD CONDITIONS Psc 14.73 PSi TSC 60 oF DIFF PRESS RNG 50 Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-18-95: PAGE: 1 of 1 CUSTOMER REP: N. Scales FIELD Badami LEASE: ~1,,,~1,1~ i ~k~,dllll, l,l~ I~L--I ' I~l VyUI~'~,I' I I ......... WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OiL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAY. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL -- PI~ Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC aBE STB/D BBL _rU3_L BBI../D BeE COMMENTS _ Pressure up csg Tod open 0910 2200 Open choke manifold o936 22oo 10 2150 Fluid (~ surface 0945 2210 16 1600 O946 2200 16 1000 Increase ~'~oke 0951 2200 20 800 Increase choke 0953 2210 24 600 0955 2220 28 550 Increase choke Increase choke 0958 2220 30 650 , 1 ooo 2211 30 49 650 full 204 28.72 2757 28.72 Rocking Choke 1015 2260 30 48 840 full 206 22.39 2149 51,11 Rocking Choke 1030 2296 30 50 1000 full 206 11.93 1145 63.94 Rocking Choke 1045 2116 30 51 1100 full 206 11,19 1074 74.23 Rocking Choke 1148 30Open to positive choke on manifold 11 oo 2154 30 52 750 14.42 1384 88.65 1115 2188 30 52 780 full 207 18,65 1790 107.3 1130 2200 30 52 750 full 206 19.77 1898 127.07 1145 2200 30 52 760 full 208 , 19.27 1898 146,84 1146 0 GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. 'SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV, ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg GORI GOR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFiD MMCF SCF/~¥~ SCFISTB SCFISTB SCFIBBL BBUMMCF BBL/STB COMMENTS 1130 200 1.25 76 0.72 64 214.73 0.024 314.95 0.9962 1.1785 1.0197 9960 127.74 1151.3 8.2 514.43 Start through gas meter ~}1120 1145 215 1.25 74 0.72 63 229.73 0.024 314,95 0.9971 1.1785 1.0214 9963 130.38 1178,6, 20,48 621 , ... , ,, MUD WT. 12.6 SHOTIFT 12 TUB/DP 3 112 PACKER DT (FT~ SEPARATOR H20 METER SIZE 1" METER RUN SIZE 5.761 STATICPRESS RNG DISP. FLUID BRIN Diesel ST DIA PIPE VOL 82 TOTAL DT (FT) OIL METER SIZE 1' H20 METER RNG 137-2570 DIFF PRESS RNG ~ GAS METER TYPE Daniel Sr, WELLTEST.XLS PERF INT CASING 7 DEPTH REF 11073 OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500~ METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBI.Jin: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSlA Tsc 60 oF DIFF PRESS RNG #5 TANK SHEET FOR STORAGE ' DATE: 03116195 TIME 11:30 17:30 PUMPED OR INJECTED COMMENTS TANK Inch BBL Inch BBL Inch BBL Inch BBL Inch 3BL Inch BBL 27.5 STARTING FLUID 1 120" '89.53 6" 4.48 199.79 FLUID RECOVERED 2 11" 8.21 10" 7.46 AFTER PUMPING 3 26" 61.73 13.5" 26.00 DOWN LINE 4 28" 67.82 10" 17.52 194.41=5.38 DIFFERENCE 5 3" 16.03 FROM LINES 6 22.5 APl @60 7 8 9 Vol. 227.29 71.49 155.8 PUMPED OFF TIME PUMPED OR INJECTED TANK Inch BBL :Inch BBL Inch BBL Inch BBL Inch BBL Inch BBL 1 2 3 4 -- 5 _ 6 7 8 9 Vol.__.__~. · #s TANK SH]~I~,T DATE: 03116195 FOR STORAGE Tank 1 I 2 I 5 Remarks 'Time Inch BBLI Gain Inch BBL Gain Inch BBL 1730 4.48 6 1950; 18.65 14.17 25 2000 29.84 11.19 40! 2103 29.84 0 40 Open well to Sep 2115 35.81 5.97 48 27.5 @88c observed 2130 41.03 5.22 55 2145 67.14 26.11 '90 2200 85.8 18.66 115 2215 88.03 2.23 118 10 3 16.03 Switch to #2 2215 7.46 0 0 101 19.75 105.53 Pump #1 to #5 2230 19.4 11.94 26 36.5 195 2300 52.6 33.2 70.5 26.0 2330 79.08 26.48 106 2400 112.47 33.39 150.75 I 0030 49.43 42.72 66.25 20 Switch to #1 03/17195 0100 73.3 23.87 98.25 Pump #2 to #5 0130 104.26 30.96 139.75 Switch to #2 0200 41.22 26.3 55.25 Pump #1 to #5 0230 82.25 41.03 18.25 110.25 Switch to #1-Pump #2 0230 114.15 31.9 18.25 153I 301.1 @116 0300 37.3 23.68 50 281 .85! 52.75 0330 52.41 38.79 70.25 #$ TANK SHEET FOR STORAGE DATE : 03116195 Tank I I 2 I IRemarks Time Inch BBL Gain Inch BBL Gain I 0800 30 6 Surge Tank 0810 34 4, 0820 37.5 3.25! 0830 39 1.75 0840 39 0 0850 10 - 0900 15 0.5 0910 30 15 0920 36 6 to tank #1 0920 4.48 - 0930 · 12.68 8.2 0940 20.14 7.46 0950 30.59 10.45 1000 41.78 11.19 1566.7 1010 54.46 12.68 1020 65.65 11.19 1030 74.61 8.96 i #5 TANK SHEET FOR STORAGE DATE: 03/16/95 Tank I 2 Remarks Time Inch BBL Gain Inch BBL Gain 445 5.5 4.103 448 5.5 4.103 0 'Open to Tank #1 453 10 7.46 3.357 ~ 458 13 9.698 2.238 503 16 11.936 2.238 510 23 17.158 5.222 515 28 20.888 3.73 520 32.5 24.245 3.357 525 35 26.11 1.865 530 38.5 28.721 2.611 540 46 34.316 5.595 550 52.5 39.165 4.849 600 -57 42.522 3.357 610 62.5 46.625 4.103 620 68 50.728 4.103 630 72 53.712 2.984 640 78 58.188 4.476 650 82 61.172 2.984 700 88 65.648 4.476 710 11 8.206 Switch to Tank #2 740 26.8 20 5 10bbl 0715 to surge tank 750 32.171 24 4 I I #5 TANK SI-IEET FOR STORAGE DATE: 3117/95 TIME 1700 I 2300 1000 I 1030 I ;1045 I I PUMPED OR INJECTED COMMENTS TANK Inch 'IBBL Inch BBL Inch BBL InchIBBL Inch* BBL Inch BBL VOL IN OUT 1 6 4.48 8.5 6.34 3.11 35.06 .-, 2 120 89.50 41.75 31.15 3 11 2,242.00 to I to 8 4 88 19.97 5 61 470.20 3 16.03 309.91 61 3 Truckload 309.91 6 48 325.94 7 256.47 8 9 Vol. 188.98 1.8% shrinkage ~ 1,146.59 produce 3/17/95 TIME 1100 1115 1130 1145 1334 1334 PUMPED OR INJECTED TANK Inch BBL Inch BBL Inch BBL Inch BBL Inch BBL Inch !BBL I 61 45.51 86 64.16 7'10.5" 2'8.5" 24.25 2 6" 94.5 70.5 7'10.5" 3 4 ~-~ 5 6 7 8 1'8.5" 20- 106.86 _ 9 Vol. #s TANK SHEET DATE: 03117195 FOR STORAGE Tank I1 [21 5 6 Remarks Time Inch BBL Gain Inch BBL IGain Inch BBL 0400 85.61 33.2 114.75~ 50.75 281.85 0430 120.67 35.1 120.67 19.75 14.73 Switch to #2 0500 58.01 43.28!18(INITIAL 77.75 88.75 747.21 Pump#1 I 0530 84.121 26.11 ' 13.43 112.8 Switch to #1 0540 27.42' 13.99 36.75 I 0700 66.4 38.98 89 I 0730 41 5.5 1'3.5" Pumped 80.5 -- Page 1 #5 TANK SHEET FOR STOI~,GE DATE: 03118-0311911995 TIME ~1500 1738: D200 500.01 06151 07271 PUMPED OR INJECTED COMMENTS ~-~_ TANK Inch BBL Inch BBL Inch BBL InCh BBL Inch BBL linchIBBL __ 1 12.50 9.33 12.50 9.33 75" 55.95 2 29 21.64 6.00 4.48 38" 28.35 3 12" 22.42 4 11" 19.97 5 88" 470.20 86.75 463.52 35.5 189.68 5" 26.72 6" 0500-Ship 273.84 BBIs 6 3" 16.03 7 55" 293.88 35" 187.10 8 20" 106.86 *Coil-Do not use 9 14" 74.80 Vol. 1,035.10 TIME 0900 1100 PUMPED OR INJECTi=D TANK Inch BBL Inch BBL Inch BBL ;inch BBL Inch IBBL Inch BBL 1 2 3 4 11" 19.97 5 6" 3,206 6 3" 16.03 3" 16.03 7 3" 16.03 10.5" 56.10 8 20" 106.86 13" 69.46 9 Vol__._._:__. ~ · NOON 5 {5 · d'40 N3)I¥~. /.. NO II"ld ......... ~3.L O00C~-dN 'ON o ., .,o "~'16OO.eo0 ...... · ! ~l¢ . Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-23-95: PAGE: lof3 CUSTOMER REP: M Whitel~ FIELD Badami LEASE: 2 -, ,. WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM choke manifold has 30 pos - 3/4" adj. CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pt~ Cwll Twll Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw PSIG IN DEC F PSlG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC BSL STB/O BBL BBL BBL/D BBL COMMENTS 0524 2200 0 6500 Pressure up TBG to fire guns 0542 2120 0 60 Guns Fired 0556 2117 0 2395Open well on/64 to Tank #2 0600 2115 0 2446 0610 2100 10/64 57 275 5.22 1503 5.22 0620 2100 10/64 52 200 2.99 431 8.21 0630 2100 10/64 50 195 2.24 322 10.45 0640 2100 10/64 49 206 2.98 429 13.43 0650 2100 10/64 50 215 2.98 429 16.41 0700 21 oo 10/64 49 220 2.99 431 19.4 0710 2100 10/64 52 225 2.61 375.8 22.01 0715 2100 12/64 52 Increase to 12/64 choke 0720 2100 12/64 52 102 ,~ 2.98 429 24,99 0730 2100 12 52 101 3.36 484 28,35 0745 2100 12 52 107 3.73 358 32,08 0800 2100 12 53 125 4.1 393.8 36.18 , 0815 2100 12 54 130 ~' 3,73 358 39.91 0830 21 oo 12 54 135 4.11 394.56 44.02 0845 2100 12 54 150 5.22 501 49.24 , 0900 2020 12 53, 165 , 3.36 322.56 52.6 no sign of gas solid diesel flowing 0915 2240 12 54 195 3.73 358 56.33 out GAS METERING RATtO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP, GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL :, GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS, FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2 GORT TGLR TLGR WOR DEC F PSIA OOIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB SCFISTB SCFISTB SCF/BBL BBI./MMCF BBL/STB COMMENTS PSlG IN IN H20 , , ,, ,, , , ,.,, , , MUD WT. 12.6 SHOT/FT 12 TUB/DP 3 112 PACKER DT (F'I) 10,638 SEPARATOR H20 METER SIZE 1" METER RUN SIZE 5.761 .... SURGE TANK STATIC PRESS RNG 200~ DISP. FLUID DIESEL ST DIA PIPE VOL 75-77 TOTAL DT (F'I') OIL METER SIZE 1' H20 METER RNG 137-2570 DIFF PRESS RNG 200_..._~" GAS METER TYPE Daniel Sr. PERF INT CASING 7 DEPTH REF OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. .~TATIC PRESS RNG 1500~. METER RUN SIZE 1.939 STOCK TANK Slorage Total; 5060,. BBL/In: Various # TANKS: 13 STANDARD CONDITIONS Psc:t4.73 PSIA Tsc 60 oF DIFF PRESS RNG 50' Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION' PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-23-95: PAGE: 2of3 FIELD Badami LEASE: 2 I~UO I UMr-r~ ~r-I"; Wi VVlllLUly , ,.---,.,..~,.u,,,,u,?,, - '1 WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM choke manifold has 30 pos - 3/4" adj. CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR CO{INTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PPM DEC F BBL AP, DEC F ~ AP, FRAC BBL ~O B~L --, BBUO nn, COMMENTS PSlG IN DEC F PSlG IN DEC F 0930 2200 12 52 235 4.85 465.8 61.18 Increase choke to 20/64 0945 2200 20 53 330 9 884 70.18 3 288 73.18 1000 2243 20 55 85 1015 2183 20 57 60 1030 2200 20 57 90 200 21.5 62 3 21.4 All BS&W % were MUD E$~ate 2.8 bbls per 15 rain 1045 2200 20 56 145 204 .~-ate of 269 a day sight glass plugged 11 oo 2240 20 57 160 202 ~na-e~__~e choke to 25/64 1115 2200 20 57 180 206' 1130 2272 25 54 130 204 21.1 82 19.8 17 272 00.18 with mud> Holding higher ~ev~ to 1145 2270 25 54 140 204 2 192 92.18 maintain accurate readings 1200 2256 25 51 125 208 3.5 4.5 432 96.68 1215 2220 25 50 120 212 4.5 432 101.18 1230 2301 25 49 130 216 3.5 3 288 104.18 1245 2321 25 48 134 216 4.5 432 108.68 1300 2340 25 48 140 217 20.2 1.8 18.8 4.5 432 113.18 1315 2300 25 47 143 218 4.75 456 117.93 1330 2300 25 47 152 217 21 , 1 19.8 4.25 4o8 122.18 1345 2100 25 47 153 216 5 480 127.18 1400 2300 25 47 155 218 20.8 78 1.2 19.8 4 384 131.18 1415 2487 25 47 I 151 217 5 480 136.18 1430 2480 25 47 153 218 20.6 74 0.5 19.8 3 288 139.18 GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. ~EP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR :ACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO, Psep d Ilw Tg Psepa Fu Fb Ftf FO Fpv Y hwPsepa Gg GOR1 GOR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFg:) MMCF SCF/STB SCFISTB SCF/S¥8 SCF/BBL BBL/;.',;.',CF _~_~L/STS COMMENTS ~ 0.68 280 0950 I 1.25 45 0.8 64 15.73 0.024 276.2 0.g~,2 1.118 1.0015 9964 27.43 106 ,i , 1000 1 1.25 15 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9881 15.36 112 1.46 130 , , 1015 1 1.25 5 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9960 8.87 65 1.84 226 1030 1 1.25 4 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9968 7.93 58 2.44 1045 1 1.25 3 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9976 6.87 50.6 2.97 1100 1 1.25 3.5 0.8 84 15.73 0.024 276.2 0.9962 1.118 1.0014 9972 7.42 54.7 3.54 , 1115 1 1.25 6 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9952 9.72 71 4.28 1130 1 1.25 13 0.8 64 15.73 ' . 0.024 276.2 0.9962 1.118 1.0014 9897 14.3 104 5.36 382, 1145 3 1.25 12 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9897 9.72 71.5 6.1 372 1200 3 1.25 15 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9894 16.31 119.9 7.34 276 , , 1215 2 1.25 14 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9896 15.3 112 8.5 259 , 1230 1 1.25 13 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9897 14.3 104.6 9.39 363 1245 1 1.25 15 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9981 15.36 112 10.56 259 1300 1 1.25 17 0.8 '64 15.73 0.024 276.2 0.9962 1,118 1.0014 9865 16.35 119.3 11.76 276 1315 1 1.25 18 0.8 64 15.73 0.024 276,2 0.9962 1,118 1.0014 9857 16.82 122.6 12.96 269 , 1330 1 1.25 .19 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9849 17.29 125.9 14.27 308.5 1345 1 1.25 19 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9849 17.29 125.9 15.58 262 1400 1 1.25 19 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9849 17.29 125.9, 16.88 328 1415 1 1.25 18 0.8 64 15.73 0.024 276.2 0.9962 1,118 1.0014 9857 16.83 122.6 18.18 255 1430 1 1.25 18 0.8 64 15.73 0.024 276.2 0.9962 1.118 1.0014 9857 16.83 122.6 19.48 426 .............. ~,, ~.~,n u,~ ~,,~,-~co ~171= t" M~TF.I~ I~111~l ~I7F R 761 SIIRGI~ TANK STATIC PRESS RNG 200~ MUD WT. 12.6 SHOTIFT 12 TUB/DP 3 112 PACKER DT (FT) 10,838 SEPARATOR ~ . DISP. FLUID DIESEL ST DIA PIPE VOL 77 TOTAL OT (FT) --.--,-------- OIL METER SIZE 1" H20 METER RNG 137-2570__ DIFF PRESS RNG ~200--" GAS METER TYPE Daniel Sr. PERF INT .CASING 7 DEPTH REF OIL METER RNG .. 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500# METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060. BBL/in: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSlA Tsc 60 oF DIFF PRESS RNG 50" CUSTOMER B.P Exploration CUSTOMER REP: M WELLHEAD Production Testing Services WELL 5 FIELD Badami HEATER WELLTEST FIELD READING FORMATION' PTS REP: C. Garrett LEASE: 2 OIL OR CONDENSATE METERING PTS REP: M. Hewston OIL FLOW RATE QO STB/D 48O 384 DATE 03-23-95: SURGE TANK PAGE: 3of3 COMMENTS ;Iosed test tool and manifold GAS METERING LIQUID GAS RATIO TLGR BBL/MMCF COMMENTS MUD WT. 12.6 SHOTIFT DISP. FLUID ST DIA ,. CASING PERF INT STOCK TANK Storage Total: 506._~0 12 7 BBL/in: Vadous TUB/DP 3 112 PACKER DT (FT) PIPE VOL 77 TOTAL DT (FT) DEPTH REF # TANKS: 13 STANDARD CONDITIONS 10,638 SEPARATOR H20 METER SIZE OIL METER SIZE 1" H20 METER RNG OIL METER RNG 137-2570 GAS METER TYPE Psc:14.73 PSIA Tsc 60 oF 1" METER RUN SIZE 137-2570 DIFF PRESS RNG 200__._~' Daniel Sr. STATIC PRESS RNG 1500~ __ 5.761 SURGE TANK GAS METER TYPE METER RUN SIZE DIFF PRESS RNG Daniel Sr. 1.939 50" STATIC PRESS RNG 200~ Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-24-95: PAGE: 1of 2 CUSTOMER REP: M Whiter FIELD Badami LEASE: 2 WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAY. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwh CI~ Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC BBL STB/D eel BBL BBUD BBL COMMENTS 0006 2910 5 66 406 Open well for final flow on 5/64 0008 2400 10 64 400 Ina-ease choke to 10/64 0015 2400 10 61 280 No fluid 0030 2400 10 51 290 Ir,~-ease c~,~ke to 15/64 (~0031 hrs 0045 2400 15 53 288 20.8 336 3.5 Fluid Q separator Q0033 hrs 0100 2400 20 47 232 19.3 528 9 Increase choke to 20/64 0115 2407 20 46 198 19.3 336 12.5 Chemical injection ~ 4 SpT= 4 gal/day 0130 2407 20 44 190 21.3 95 364 16.5 0145 2400 20 43 203 288 19.5 0200 2433 20 43 213 408 23.75 02~0 2474 20 43 212 20.7 372 31.5 Start flow into separator (~0230 0300 2500 20 45 205 23.2 102 241.4 36.53 0330 2500 20 45 201 I 358 43.99 0400 2500 20 45 206 20 6.6 394 52.2 0500 2400 20 45 215 21.3 83 19.8 331 86 0600 2600 20 48 210 222 20.1 33.4 341 80.22 0700 2600 20 48 210 223 19.9 46.1 358 95.14 , 0800 2627 20 48 206 227 21.6 90 19.7 , 55.7 260 106 0900 2630 20 48 205 228 21.8 97 20 69.8 338.4 120.1 0934 stop chemical injection 1000 2646 20 50 210 224 21.2 81 82.8 312 133.1 so chemical free samples can be taken GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS, SEP CONY. ORIFICE TEMP. GRAVI'P( COMPR. EXPANS. PRESS. FLOW TOTAL GAB/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS, SIZE DIFF, GRAV. TEMP. PRESS, FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO , Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM DOlE ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB SCFISTB SCFISTB SCFIBBL BBL/MMCF BBL/STa COMMENTS 0015 7 1.125 22 0.8. 72 21.73 0.024 276.2 0.9887 1.118 1.0019 0.9874 21.864 158.47 1850 0030 2 1.125 12 0.8 73 16.73 0.024 276.2 0.9877 1.118 1.0014 0.991 14.169 102.93 2722 0045 5 1.125 8 0.8 96 19.73 0.024 276.2 0.9671 1.118 1.0015 0.9949 12563 89,721 3656 267 0100 13 1.125 26 0.81 113 27.73 0.024 276.2 0.9526 1.111 1.002 0.9883 26.851 186.55 5599 353 0115 12 1.125 22 0.81 124 26.73 0.024 276.2 0.9436 1.111 1.0018 0.9897 24.249 167.1 7339 497 , I 0130 12 1.125 21.5 0.81 140 26.73 0.024 276.2 0.9309 1.111 1.0016 0.99 23.972 162.99 8793 424 , 0145 10 1.125 17 0.81 140 24.73 0.024 276.2 0.9309 1.111 1.0015 0.9914 20.503 139.59 10319 484 0200 11 1.125 18 0.81 140 25.73 0.024 276.2 0.9309 1.111 1.0016 0.9913 21.52 146.5 11874 359 0230 10 1.125 19.5 0.81 140 24.73 0.024 276.2 0.9309 1.111 1.0015 0.9902 21.959 149.31 13945 401 0300 90 0.5 55 0.81 95 104.73 0.024 50.587 0.9679 1.111 1.009 0.994 75.895 99.394 16016 412 0330 89 0.5 53 0.81 105 103.73 0.024 50.587 0.9593 1.111 1.009 0.994 75.895 99.394 17905 258 , 0400 75 0.5 55 0.81 108 89.73 0.024 50.587 0.9568 1.111 1.0071 0.993 70.25 90.674 19574 230 0500 78 0.5 42 0.81 116 92.73 0.024 50.587 0.9501 1.111 1.007 0.9948 62.407 80.13 22714 242 , 0600 78 0.5 38 0.81 130 92.73 0.024 50.587 0.9388 1.111 1.0064 0.9953 59.361 75.361 25862 221 0700 75 0.5 40 0.81 136 89.73 0.024 50.587 0.934 1.111 1.006 0.9949 59.91 75.55 29680 211 , 0800 470 0.5 63 0.81 138 84.73 0.024 50.587 0.9325 1.111 1.0056 0.9915 73.06 91.63 33491 352 ,, 0900 70 0.5 63 0.81 140 84.73 0.024 50.587 0.9309 1.111 1.0055 0.9915 73.06 91.47 37302 270 1000 75 0.5 40 0.81 1'36 89.73 0.024 50.587 0.934 1.111 1.006 9949 59.91 75.55 40450 242 , ,, , .................................................. MUD W'I'. 12.6 SHOTIFT 12 TUB/DP 3 112 PACKER DT (F'I') 10638 SEPARATOR H20 METER SIZE 1' METER RUN SIZE 5.76111.93 SURGE TANK STATIC PRESS RNG 200~ DISP. FLUID DIESEL ST OIA PIPE VOL 77 TOTAL DT (FT) OIL METER SIZE I" H20 METER RNG 137-2570 DIFF PRESS RNG ~200--~" GAS METER TYPE Daniel Sr. PERF INT CASING 7 DEPTH REF OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500~ METER RUN SIZE 1.939 # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSIA Tsc 60 oF DIFF PRESS RNG 50" STOCK TANK Storage Total: 5060.. . BBL/in: Various Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-24-95: PAGE: 2of 2 CUSTOMER REP: M Whitel~ FIELD Badami LEASE: 2 · . · ~l. dl~,,~ I Villi-it I~B . iWl ~W I I·~.~.. T , .., .... WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAY. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Qo Go To BSW GO60 SHRL K QO QO Qw qw RBL COMMENTS PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC BBL STB/D BBL BBL BBL/D 1100 2650 20 51 213 228 0 0 134 21.4 80 TRACE 20.2 93.1 340 147.27 -- 1200 2652 20 51 210 228 0 0 125 21 77 TRACE 20 96.3 340 161.45 1300 2644 20 51 212 230 0 0 118 21 76 TRACE 20.1 106.5 336 175.45 Foamy oil meter, meter factor off 1400 2652 20 52 210 227 0 0 114 21.2 78 TRACE 20.2 116.7 340 189.62 Using tank st£aps for accurate 1500 2660 20 50 208 234 0 0 114 21.6 84 TRACE 2O.2 15.3 367.2 204.92 rates. Meter not tuming 1600 2661 20 50 209 236 0 0 114 21.4 79 TRACE 20.3 7.6 173 212.14 Switch to s;~-aps 1700 2632 20 52 210 236 0 0 114 22.4 101 TRACE 20 19.28 463 231.42 16:42 start chemical injection, sampling 1800 2612 20 51 204 220 0 0 116 22.2 95 TRACE 20.8 11.75 282 243.17 done 4 spin 4 gal/day 1900 2550 20 51 lgg 220 0 0 135 21.4 84 TRACE 20 15.53 371.5 258.7 2000 2540 20 51 198 220 0 0 140 21.6 88 TRACE 20.1 13.2 318 271.9 2100 2500 20 52 200 228 0 0 145 21.3 85 TRACE lg.g 13.2 317.7 285.1 2200 2500 20 49 200 236 0 0 146 21.2 81 TRACE 20 17 407.5 302.1 ,Shut - off cl~emical 2300 2500 20 49 201 239 0 0 147 21.2 81 TRACE 20 12.5 300 314.6 2400 2500 20 49 202 243 0 0 134 21.2 81 TRACE 20 14.2 340 328.8 Close F'CT @ 0002 Close Manifold @0004 GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAs GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR -'ACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2 GORT TGLR TLGR VVOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCF/~B SCF/STB SCFISTB SCF/BBL BRL/MMCF BBL/ST8 COMMENTS ~ 1100 80 0.5 37 0.81 ' 12a 94.73 0.024 50.587 0.9404 1.111 1.0067 0.9955 59.2031 75.266 43586 221 1200 80 0.5 37 0.81 120 94.73 0.024 50.587 0.9468 1.111 1.007 0.9955 59.2031 75.807 46745 223 , 1300 80 0.5 37 0.81 114 94.73 0.024 50.587 0.9518 1.111 1.0072 0.9955 59.2031 76.222 49921 227 , 1400 80 0.5 40 0.81 112 94.73 0.024 50.587 0.9534 1.111 1.0073 0.9952 61.5565 79.367 53228 233 1500 75 0.5 38 0.81 114 94.73 0.024 50.587 0.9518 1.111 1.0068 0.9952 58.393 75.1195 56358 294 , , , 1600 75 0.5 38 0.81 114 94.73 0.024 50.587 0.9518 1.111 1.0068 0.9952 58.393 75.119 59488 434 , , i 1700 80 0.5 39 0.81 114 94.73 0.024 50.587 0.9518 1.111 1.0072 0.9953 60.782 78.235 62748 169 , 1800 80 0.5 39 0.81 122 94.73 0.024 50.5879 0.9452 1.111 1.0069 0.9953 60.782 77.67 65984 27.54 1900 80 0.5 50 0.81 135 94.73 0.024 50.5879 0.9348 1.111 1.0064 0.994 68.822 86.82 69601 233.7 2000 80 0.5 57 0.81 140 94.73 0.024 50.5879 0.9309 1.111 1.0062 0.9931 73.482 92.216 73443 289.9 2100 80 0.5 49 0,81 143 94.73 0.024 50,5879 0.9286 1.111 1.0061 0.9941 68.1305 85.362 76999 269.2 2200 77 0.5 44 0.81 141 94.73 0,024 50.5879 0.9301 1.111 1,006 0,9945 63.5305 79,754 80322 195.7 2300 78 0.5 38 0,81 131 94.73 0.024 50.5879 0.938 1.111 1.0064 0.9953 59.3611 75.239 83456 250,7 2400 80 0.5 33 0.81 124 94.73 0.024 50.5879 0.9436 1.111 1.0068 0.996 55.9114 71.37 86429 254.2 , ........ -,,.- 4- &a ,'~ =i Ikl Ct?r' t O'~''~ ~11D/'~.G: TAMK ~TATIO. P~FRR F~N["~ MUD WT. 12.6 SHOTIFT 12 TUB/DP 3 112 PACKER DT (F'I') 10638 SEPARATOR H20 METER SIZE DISP. FLUID DIESEL ST DIA PIPE VOL 77 TOTAL CT (F'I') OIL METER SIZE 1" H20 METER RNG 137-2570 DIFF PRESS RNG ~200'---:" GAS METER TYPE Daniel Sr. PERF INT CASING 7 DEPTH REF OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500# METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBL/in: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSIA Tsc 60 oF DIFF PRESS RNG 50" Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-26-95: PAGE: 1 of 2 P: M Whitel' .FIELD Badami LEASE: 2 ~,,U~,~l~JIVIr'r~ R,-r, i11 IIiiil. Gly ,~ ~,,k,? ~,,~4~,,,,~ .... , , ...... WELLHEAD HEATER OIL OR CONDENSATE IVIETER[NG SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASINC, CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twfl Pwh Ch Th Tsep Qo Go To BSW GO60 SHP~L K QO QO Qw qw PSIG IN DEC F PSIG IN DEC F PPM DEC F BBL APl DEC, F % APl FRAC BBL STB/D BBL BBL BBI./D BBL COMMENTS Open well to separator on 10/64 00o4 10 461 Increase choke to 20/64, ~f_art 0008 20 85 0030 2140 20 42 186 235 0 0 84 72 1.5 =hemice! injection. 0100 2150 20 42 177 235 0 0 86 21.4 83 Trace 20.1 295.2 7.65 Tm__ce of mud 0130 2160 20 37 170 238 0 0 100 304 13.99 0200 2180 20 44 194 240 0 0 100 21.3 63 Trace 20 384 22.01 Shut in (~ manifold to R/I hole, WI_ Open well on 5/64 0500 2201 5 37 2150 0530 2210 5 36 2010 8.64 22.19 No gas oabserved (~ Tank 0 22.19 0600 2230 5 35 2000 0630 2260 5 33 2060 0 22.19 0700 2210 5 32 2010 0 22.19 9.12 22.8 Shut in manifold (~ surface, Atlas 0729 2220 5 38 2020 pull sa~e chamber out of hole 0730 1200 14 , 2880 20 :Begin RIO 1210 16 6264 41.75 1215 18 3888 68.75 1225 20 216 69.5 1260 24 648 74.75 1240 28 , 144 76.625 1250 30 234 1300 48 G.~.$ METERINC' RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS C,AS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WA Ir.t< CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONY. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. .ql 7;: DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. , RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1' CDR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB SCFISTB SCFISTB SCFIBBL BBL/MMCF BBL/STB COMMENTS i ~ 0030 50 0.5 78 0.81 99 64.73 0.024 50.587 9645 1.111 1.0052 9862 71.056 91653 1729 1273 0100 50 0.5 89 0.81 104 64.73 0.024 50.587 9602 1.111 1.0051 9846 75043 96197 3733 326 , 0130 50 0.5 87 0.81 107 64.73 0.024 50.587 9576 1.111 1.0051 9846 75043 95933 5732 315 0200 50 0.5 89 0.81 lO8 64.73 0.024 50.587 9568 1.111 1.0051 9843 75.901 96907 7751 252 , 1215 140 I 70 0.81 87 154.73 0.024 212.47 9750 1.111 1.0145 9945 104.07 580000 13793 1230 140 1 30 0.81 88 154.73 0.024 212.47 9741 1.ill 1.0144 9977 68.135 380564 17757 In Surge Tank 1305 1315 2 0.25 8 0.81 34 16.73 0.024 12.708 1.026 1.111 1.0019 9946 11.569 4000 17882 1330 2 0.25 28 0.81 35 16.73 0.024 12.708 1.025 1.111 1.0019 9809 21.643 7388 17959 MUD WT. 12.6 SHOTIFT 12 TUB/DP 3 1/2 PACKER DT (FT) 10,638 SEPARATOR H20 M~- lh_.R SIZE 1" OISP. FLUID diesel ST DIA PIPE VOL 77 TOTAL DT (FT) OIL METER SIZE 1" H20 METER RNG 137-2570 DIFF PRESS RNG 200" GAS METER TYPE Daniel Sr. PERF INT CASINC, 7 DEPTH REF OIL METER RNG 137.2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNC, 1500~ METER RUN SIZE 1.939 STOCK TANK S(orage Total: 5060 BBL/irI: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSIA Tsc 60 oF DIFF PRESS RNG 50" Production Testing Services WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 03-26-95: PAGE: 2 of 2 EIELD Bad; ' LEASE: 2 WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK , O~L TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE V~SSEL OIL OIL MEAS. OIL GRAY. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W ATBOF FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pt)h Cwfl Twh Pwh Ch Th Tsep OD GO TO BSW GOBO SHRL K OO ~e° o~ ~ COMMENTS PSlG IN ~ PSlG IN ~ ~PM DEC F BBL APl DEC F % APl FRAC BBL STB/D BBL BBL BBI_/D BBL 324 77.75 Fluid from R/O, choke open 1305 ful ................. 1.25 1~0 79 on center by-pass valve 1315 full ...... 2 192 81 1330 full ...... 3.75 1350 84.75 Shut in flow head 1336 full84375 Total Fluid to Sep. 1340 full ...... ~M~~ ~ ~ ~-.,~,.~--m .~-,,, ~~~ .,.~...mm ,-,~-,---~.,,,~ GAS METERING RATIO .... ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV, ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d I~w Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg GOR1 GOR2 GORT TGLR TLGR VVOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB SCFISTB SCF/~s SCFIBBL BBL/MMCF BBL/STB COMMENTS · .... ~,;,~-,.~n ~ t~ ~ ~tTf:: t" ~_iJ-R RUN SIZE 1.939 SURGE TANK STATIC F=~,F-SS RNG 1500 .............. ..A ,-¥-- MUD WT. 12.6 SHOTIFT 12 TUS/DP 3 1/2 PACKER DT (FT) 10,638 SEPARAT DISP. FLUID diesel ST DIA PIPE VOL 77 TOTAL DT (F'I'} ~ OIL METER SIZE 1" H20 METER RNG 137-2540,, DIFF PRESS RNG 200" .GAS METER TYPE Daniel Sr. PERF INT CASING 7 DEPTH REF OIL METER RNG 137-2570 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500# METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBL/in: Vadous # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSIA Tsc 60 oF TANK SHEET FOR STORAGE DATE:03~4~5 Tank Surge Tank 1 ...... ~ 2 IKamm~ i I ' 'l"~e Inch ,, BBL. , ]Gain I.,m~,, , BBL Gain ,, Inch, !BBL Gain 0 _ 33.5 .. ~1 DST#2, nofl~d I .... . 15 33.5 ' .... 4537, · , i "1 pump ~ '1 ' '!' " ~45 , -'-37'" ' '230 ...... '. '-i ~ ! at O2:3~ pump to #1 ~' ! _._ 3~o " '~.',41 .. I I , I .j , 330 ' } i -.,! i ..... I" } I .. ..... 53;si 400 e2"~i" i '" ' " "eeo i j Swttcfl to ~2 1 ,1 I ~oo - .. i .... 4.4s ~ i .... 134~ --" ! ~ ........ i I at 14.tXI fl~to # 2 1600 .. I | , I I ..... 1,700 ' 1 ' 45.88j i' ' ' ' '" ~oo ,,, ; . I I 1go0 .... ' -- i -'i"' 5; , ~6 AM SINGER 0 0 0 0 NOoN o ! , ~0 Production Testing Services WELLTEST FIELD READING CUSTOMER 'B.P Exploration WELL 5 FORMATION' PTS REP: C. Garrett PTS REP: M. Hewston DATE 04-01-95: PAGE: 1 of 4 .D Badami LEASE: L;U5 1UMI:K KC.Y: Pi. bcales , .r-. ~,-~..u.?--u,--,,,, WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE aBE Pbh Cwh Twh ;=wh Ch Th Tsep Qo ~ To ~SW GO~0 S. RL K QO ~O Qw qw COMMENTS PSlG IN DEG F PSlG IN DEG F PPM ~ BBL APlDEG F % APl FRAC BBL STB/D BBL BBL BBI./D BBL ~ =~m=~l=~ ~ ~ m=~= ~ ~ ~ ~a~lmmm ~ 0230 2500 '""'"'---- 16 0300 2500 ........... 74 3552 90 Pumping N2 into csg 033~0 1255~0 ....... ~ ~ ~ 20 960 110 Pit sample 9.1 # .per gallaon 0400 1300 ~ 3O 1920 150 0430 1430 86000 ........ ~ 10 1440 160 Turned to PTS from pits 0440 1470 04000 ............ 48 3462 208 0500 128 82000 --------- --------- ~ ~ ~ --'"'--'-- ~ 12.02 576.9 220.02 05530 78 16.03 769 236.05 O6OO 600 3O5 78 1.34 64 237.39 ._.....~. ~ ~ ~ ~ .~.._...._ ...._.__. ~ ...._.__.._ ....._.__. ~ ~ ..._.__..._ ~ ~ ~ ~ ~m ~ ---....-.--.-.-- -0630 42O 29O 842.67 128.2 240.06 ,Recorder line plugged, purged 0700 42o ~ ..~......._..~___...._._..__ .__.._._. ~..._._ ._....___ ~..~_ _....._..._ ._....._.._.~ ~ _..~--.--. ----.--- .~--..~- ~ ~ ~ -10 842.67 128.2 242.73 N2 Pump rate 458 SCFM 0730 600 5 84 0 0 242.73 No fluid fo a CL- o3oo 67o 5 84 0 0 242.73 ~0822 N2 Rate 922 SCFM 0830 880 3 84 0845 200 84 80000 ..... "-'' 6 33.49 16.08 276.22 o6oo 82o 25o~-.---..---~~~84 400oo ~ ~'-'----"- ~'"-'""'- ~ 4 384 280.22 Sand 0915 760 250 84 32000 093'-'--~ 750 210 84 ~ o.5 0 0 280.22 sand, (~0938 N2 Rate 930scfm ........... 0 0 280.22 1000 480 225 84 ........... Start N2 pumping @940 SCFM 1 o42 47o 5 842.67 213,6 282.89 1100 ,5 84 ~ .......... RATIO GAS METERING ..... ABS ~ BASIC FLOWING GAS SUPER GAS GAS ~ SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR :ACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep cl hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg GOR1 GOR2 GORT TGLR TLGR WOR ~ ----------~"--'-------------PS~G ~N ~. H20 ~ --------"--"----~------'---------'----PS~A O0~M O0~M OD~M O0~M OD~M O0~M --'--'---'OD~M MSCF/D MMCF SCF/STB SCF~STB SCF/STB SCF~BBL BBUMMCF SBUSTB COMMENTS · ,------------ ~ ~ __ __ __'~--"~" ~ _ ......... ,,,-, ,,=~-=a ~?,-- u~Tr:R I~! IN ~l?P I cJ3cJ SURGE TANK STATIC PRESS RNG 200~ MUD WT. 9.1 water SHOTIFT TUB/DP 5 112 PACKER DT (FT) SEPARATOR H20 DISP. FLUID bdne ST DIA PIPE VOL TOTAL DT (F'r) ~ OIL METER SIZE .--.,--,-,--- H20 METER RNG DIFF PRESS RNG 200' GAS METER TYPE Daniel Sr. WELLTEST.XLS PERF INT CASING 7 DEPTH REF OIL METER RNG ~GAS METER TYPE Daniel Sr. STATICPRESS RNG 1500~ METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBL/in: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSIA Tsc 60 oF DIFF PRESS RNG 50" Production Testing Services WELLTESTFIELD READING CUSTOMER 'B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 04-01-95: PAGE: 2 of 4 ELD Bad; LEASE: l~u~51UMI:::I~ I~1=.1": I~1. ;~cales FI[-~-~ ~,aua,,,, , WELLHEAD HEATER OIL OR CONDENSATE METERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Tsep Qo Go To BSW GO60 SHRL K QO QO --~-Qw qw .... Ch Th P'~'~'~~ DEO~ BB~ AP---"-'~' OEG--'---'~' ~ AP--"--'T'-- FRAC 8BL STB/D BBL BBL BBIJD ~BBL COMMENTS Pbh Cwh Twh Pwh PSlG IN DEG F PSlG IN DEGF 1105 lDO s4 132 3oooo ~ o.5 ~------. 282.80~ R. UID @SEP BS&W is SAND ................. 8.01 768.96 290.9 1110 660 135 84 128 28000 7 1115 660 280 84 130 28000 ........ 10.69 1539 301.59 N2 RATE STAYED 9~0-040 SCFM 1120 650 245 84 120 28000 ....... 0 0 301.59 11:27 B.J. STOP N2 PUMPING 1125 650 200 84 120 28000 7 ........ 0 0 301.59 ~ ~ ~ ~ ~ _.__.._.._ ~ ..~.._..__ ~ ....._.....~.-~-...~ ..-~---. ---..---- ~ -.-..-----~- ~ ---'---- ---~----- '------'-~ ~ --~ ~"'-"'--'113o 175 84 12o 2.87 128.16 30~.26~ TATE BEING PUMPED 930-940 $CFM 1200 380 100 84 120 2.67 128.16 306.93 1234 BJ START PUMPING 1230 380 75 84 134 .......... 0 0 306.93 1251 BJ STOP PUMPING 1400 680 ___ __ _._..__ __ ..___._ _._._.__ ~ .______ __ ~ __ ~ ..------- ~ ------------- -----.------5 84 140 0 0 306.93 1309 BJ START PUMPING 1405 84 145 30000 7 1410 350 84 ' 150 29000 6.68 1923 313.61 1356 RATE OF N2 930-870 PSI ....... ~ ....... -- ~ 21.37 6154 335 1405 FLUID ~ SURFACE 1415 800 285 84 158 27000 ............... 2.65 763 337.65 BJ STOP PUMPING N2 1420 750 200 84 160 1.33 383 338.08 1425 710 188 84 156 2.68 129 341.66 1430 700 175 84 152 ........... 0 0 341.66 (~1520 BJ START N2 ~930.940 RATE 1500 38o 10o 84 130 2.67 128 344.33 1,530 390 50 84 145 0 1600 680 5 84 140 .... 5.34 1538 349.67 1605 660 ~ 156 84 130 26000 1610 650 180 84 126 ~ ~ 6'68 1934 356.35 , ........ 4.01 1155 ~0.:~ 161S 640 155 84 124 27000 GAS METERING RATIO WATER ..... ABS ~ BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAY. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Pse?- Fu Fb Ftf Fg Fpv Y hwPsepa Gg CDR1 CDR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB $CFISTB SCFISTB $CFIBBL BBL/MMCF BBI./STB COMMENTS ~=mm,~== ~1~1~ ~lll~l ~ I~lllllll ~lllll ~Illllll ~llllll I1~II ~ ~ II~ll~ IIl~llll II~l ~ ~ ~ ~ ~l~l I~l~l~l~ I~llll -- ~ ~ ...... . ........... u,3,--~ ~='r=¢3 ~=,~'~: MI=TFI~ RIJN ill?l; 1 .g39 SURGE TANK STATIC PRESS RNG 200~ MUD WT. 9.1 water SHOTIFT TUB/DP PACKER DT (FT) SEPARATOR DISP. FLUID brine ST DIA PIPE VOL TOTAL DT (FT) ~ OIL METER SIZE ~ H20 METER RNG OIFF PRESS RNG 200" GAS METER TYPE Daniel Sr. PERF INT CASING DEPTH REF OIL METER RNG --.---------- GAS METER TYPE Daniel Sr. STATICPRESS RNG 1500~ METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBLJin: Various # TANKS: 13 STANDARD CONDITIONS Psc:14.73 PSlA Tsc 60 oF DIFF PRESS RNG 50" Production Testing Services WELLTEST FIELD READING CUSTOMER 'B.P Exploration WELL 5 FORMATION' PTS REP: C. Garrett PTS REP: M. Hewston DATE 04-01-95: PAGE: 3 of 4 N, Scales FIELD Badami LEASE: TEST #3 l,.,.I, JO 1%./IVlr'l~ EEl--. I1. ~,.]t. alt;O · .......... WELLHEAD HEATER OIL OR CONDENSATE k{15'rl-:KrNG SURGE TANK OIL TEMP. CHANGE O~L CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PR:_E~$. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT 60 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twh Pwh Ch Th Tsep Oo Go To BSW GO60 SHRL K QO QO Qw qw PSIG IN :)EG F PSlG IN DEC F PPM DEC F BBL APl DEC F % APl FRAC BBL STB/D Rm Am BBL/D BBL COMMENTS 1820 610 166 84 120 1.33 383 381.69 BJ STOP N2 1625 600 150 84 118 1.34 386 363.03 1630 500 160 84 116 0 0 363.03 17o0 320 20 84 108 5.34 256 ~_368.37 ~1720 BJ START N2 ' 0 0 368.37 ;RATE @940 SCFM 1730 380 0 84 232 lSO0 625 0 84 215 0 0 368.37 1810 642 215 84 215 28000 14.7 1924 383.07 1815 660 210 84 210 28000 4 1152 387.07 1820 640 190 84 1770 29000 4.01 1154 391.08 1825 620 195 84 169 27000 267 769 393.75 1830 610 197 84 168 0 0 393.75 BJ STOP N2 1835 4O0 18O 84 157 0 0 393.75 1845 100 135 84 146 0 0 393.75 1900 97 35 84 140 2.67 153.7 396.42 GAS METERING RATIO , ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAY. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR FACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO , Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg GORt GOR2 GORT TGLR TLGR WOR COMMENTS PSIG IN IN H20 DEC F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCFISTB SCFISTB SCF/STB SCFIBBL BBL/MMCF _R_RLISTB I , , , , , , , , , , MUD WT. 9.1 water SHOTIFT TUB/DP 51/2 PACKER DT (FT) SEPARATOR H20 MI=] I=R SIZE DISP. FLUID bdne ST DIA PIPE VOL TOTAL DT (FT) ~ OIL METER SIZE 1" H20 METER RNG DIFF PRESS RNG 2r00" GAS METER TYPE Daniel Sr. PERF INT ~ CASING DEPTH REF OIL METER RNG 137-2540 GAS METER TYPE Daniel Sr. STATIC PRESS RNG 1500~ METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060. BBL/in: Various # TANKS: 13 STANDARD CONDITIONS Psc;14,73 PSlA Tsc 60 oF DIFF PRESS RNG 50" Production Testing Services' WELLTEST FIELD READING CUSTOMER B.P Exploration WELL 5 FORMATION: PTS REP: C. Garrett PTS REP: M. Hewston DATE 04-2-95: PAGE: 4 of 4 Whiteh FIELD Badami LEASE: t~UO I UlVlr-l~ I~t-r~ WI llllllll,~;;ly ~ ll-l.b. ~,.,~,~HH,,,~I .... WELLHEAD HEATER OIL OR CONDENSATE M~; IERING SURGE TANK OIL TEMP. CHANGE OIL CUM. CHANGE WATER CUM CLOCK CASING CHOKE CHOKE VESSEL OIL OIL MEAS. OIL GRAV. SHRINK. CORR. IN OIL FLOW TOTAL H20 IN H20 FLOW TOT. WAT TIME PRESS. SIZE TEMP PRESS. SIZE TEMP H2S CO2 SALINITY P.H. TEMP. COUN. GRAV. TEMP. BS&W AT S0 F FACTOR FACTOR COUNTER RATE OIL COUN. COUN. RATE BBL Pbh Cwh Twfl Pwh Cfi Th Tsep Qo Go To BSW GOSO SHRL K QO QO Qw qw PPM DEG F BBL APl OEG F % APl FRAC BBL STB/D _rJ_RL BBL BBL/D BBL COMMENTS PSlG IN DEG F PSIG IN DEG F "llm~l~l ~11"ll"~lml ~ ~ I~1 i~l~l ~ ~ ~ ~ ~ ~~1 ..l,~lllll i~1~1 m.lm~l. ~ ~ ~..~llll~ ~ ~m.l~lml ~ -mml~ml~ 0 0 396.42 fl_UID (~ SURFACE 0400 1300 0 110 0410 174 110 0415 1190 390 110 0420 338 1 ! 0 0425 325 110 2885 456.5 BJ STOP N2 0430 970 280 110 0445 720 195 110 27000 128,6 457.8 0500 600 125 0 27O00 769.9 465.8 sHUT IN ~ HEATER ~ 0500 (~0503 OPEN ~ SEPARATOR SHUT 0515 520 265 128 27000 ' HEATER (~ 0509 GAS METERING RATIO ABS UNIT BASIC FLOWING GAS SUPER GAS GAS CUM. SEP. SEP. OIL TOTAL GAS LIQUID WATER CLOCK ORIFICE ORIFICE GAS MEAS. SEP CONV. ORIFICE TEMP. GRAVITY COMPR. EXPANS. PRESS. FLOW TOTAL GAS/OIL GAS IN GAS/OIL LIQUID GAS OIL TIME PRESS. SIZE DIFF. GRAV. TEMP. PRESS. FACTOR FACTOR FACTOR FACTOR -'ACTOR FACTOR EXTENS. RATE GAS RATIO SOLUTION RATIO RATIO RATIO RATIO Psep d hw Tg Psepa Fu Fb Ftf Fg Fpv Y hwPsepa Gg GOR1 GOR2 GORT TGLR TLGR WOR PSIG IN IN H20 DEG F PSIA ODIM ODIM ODIM ODIM ODIM ODIM ODIM MSCFID MMCF SCF/~B scF/STB SCFISTB SCFIBBL BBL/MMCF BBL/;5~. CO M M E NTS ~ m m mmm m mm m mmm,mmmmm~m mmm, ~ m mmm m mmmmmmmmmm m mmmmmmmm ~mmmm mmmmmmmm mmmmm mmmmmmmmm i i i ,, i , i , · , , i .............. u,~ ~.~ =m?c ~" U~-[~-R RIIN ~IXF 1 c~g SURGE[ TANK STATIC PRESS RNG 200# MUD WT. 9.1 SHOTIFT TUB/DP $112 PACKER DT (FT) SEPARATOR H20 DISP. FLUID brine ST DIA PiPE VOL TOTAL DT (F'r) ~ OIL METER SIZE 1" H20 METER RNG 137-2540 DIFF PRESS RNG 200" GAS METER TYPE Daniel Sr. PERF INT CASING DEPTH REF OIL METER RNG 137-2540 GAS METER TYPE Daniel Sr. .~;TATIC PRESS RNG 1500~ METER RUN SIZE 1.939 STOCK TANK Storage Total: 5060 BBL./in: Various # TANKS: 13 STANDARD CONDITIONS Psc:14,73 PSIA Tsc 60 oF DIFF PRESS RNG 50" TANK SHEET FOR STORAGE DATE.: 03/31/95 440 0.5 2 671 01 i I I I Open to Tank l~12 ~ 16 ~.4 ~.~ 1~ 28.5~ '15228 2.67 ~ ~ ~ I ~410 30.5 1~.97 6.~ ~ ,., ~ ~ · ' .~BO .-e- .... --------__ .~ 'T' -~ ._././'/' . .~ ..... ~ / ' ~..~... .. . ., -./,~s., / '-.:. ', · ~ ~""~" i ,! ~' '~0.~:: ..,/ . '~x, ."' .'~ "%' ..4,, / /~ ~ / ...-~ . . . "'-. '.;~ '~X. · "., ~.. ' ,/. .~ ~ .,. -' ,,., ~ .. :?~;q.~ ........ ..,.. ,~'/. ,-' .,,~oo,... ,- ~,..:--- . !.~...'/' ...... .. ~..~,..,.,- / ."-~,' ,,,,., '.... 1M /' \ /' / ~..-/ ..... ,-' ~. . ~' ' "-/-.. ... \%-- il/' x/ .,.- ~.~., ,. __.,oo~- X, $,,~, ,, I ,,, ,' ,'~' .,~ /"" ~. .... . ;,. / --'-:--: ~ .. .. , //,"' / ",/ × .-,v';... ..-.'/'" ' -,,o,-~- ? .X,X..: ~' '" ,lY~ / / /"x ,/ ;'~"f'" "' "/~"'/"' / ' ,,-!/. / ,, x./ ....~...,,/ "':?'" "i :' i ,.'~'~ './ . / ,.X, ./ ',o~,<J.~ ......\ ' ' . ~ :- - IIX/../. / ~/...A "i?'' :. !!/ x/ / './'/.,. 'z:'.. ~o.'~' ,: 'i.' ~:. ' /, ~ ' ~ , ,. %, /'. , ~,- ',., ..,,- . II / ./ './ ....,' ''. .' x, II ." , ~ '- ,' ' ' :', ,"' -°:'" "" , ' .,~ · . '.' . '~.'./' · /. ". l/ i) ~'X' CHART NO.H-1500-200 Z ~ TAKEN OFF . M ........ 1'4 , ~OOAT'ON .~,[L.A~ ~ 'id.....). ,~. SINGER METER DIVlBION NOON HOINQIW~t ~OTMK i~roduction Testing Services BP ]~AZ)AMI No, 5 "~l~, CHR!STYI~IPROC, ESS FLOW DIAGRAM_ '~. ~no~l--I~l-"°' I'"o~-~o~ IS, ~TS STAFFI~.,,,I~-~o~-J J,.~8 ,,' 3 P ]D BDUND RY mi,m )~1 !~ I~ M ~00 ]I:~L. L. XOUXD STORAGE TANK~ 500 BBL. LTOUID ~TI'II~AG£ TANKS 500 ]~]~L LIQUZD STORAr,£ TANKS 500 ]~]~k. LIQUI]) STORAGE TANKS 500 ~L STORAGE TANKS :500 ~L STORAGE TANKS 500 ~L STORAG£ TANKS I ~AU ! I==1E~ I=~ M ~ Mroduc ion Testing Services JOCX J: .010 J~G, CHRISTYI~I EQUZPMENT LAYOUT ~. LOGANI~, O I I 01-9501e7 1~ 1~0 psi 3O SURFACE .~_ SAFETY VALVE SEPARATOR 1000 ps~ H~ (UPSTREAM OIr INLET V&LVD = PSH ESD 120 ps~ LSH II100 psi INTERFACE PANEL 100 psi 250 psl H~ CJACK~T> 100 ps~ HI PSH SURGE ESD SCRUBBER 100 ps~ Hi HEATER 5000 ps~ H~ 50 p$~ Lo TANK SP LSH 120 psi ~ CRBBM PUMP TANKS Na ~OTI'L[:S RIG FLOOR 10,000 psi HI 50 psi Lo RIG FLOOR 120 psi ~.~---,,~ oduc n ng Services I~, CHmST, I~'I~ ~ETY SYSTEM DRAWING , I J C. GARRETTI J~NONEI J~ 3 ' 3 CONF DEf. AL BP Exploration (Alaska)Inc. Badami #5 Drill Stem Test #1 Location: State: Country: Drilling Company: Rig Number: BP Representatives: Petrafina Representative: Schlumberger Representatives: Sec, 5, - T9N - R20E Alaska USA Nabors Alaska Drilling 18E Nick Scales Mike Whiteley Mark Stanley Mark Hornbrook Charlie Michel Keith Barnard Tom Carlson Glen Carter ' I ICt OFILMED Date_~~;~.__,..__ , RECEIVED MAY 4. 199,,5 0il & Gas C°ns. C0mmissiort 11000 10000 9000 0000 ?000 -- Il I _ 8000 5000 4000 _ 3000 ! # · , i ?000 6000 4000 · iI · : .. · : ........ i ......... ! ......... ! ......... i ......... ! ......... i ......... i ......... ! ......... ! .... 40' 50 60 70 80 t' i m., ~nr" 100 110 120 130 BP EXPLORATION (ALASKA) Ine BADAMI #5 DST #1 CONNECTIONS 3 1/2 IF 3 1/2 PH6 3 1/2 PH6 3 1/2 PH-6 3 1/2 PH-6 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 tF 3 1/2 IF 3 1/2 IF 4.37 4thd SA 4.37 4thd SA 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF TOOL DESCRIPTION 1OK Surface Flowhead Valves = 2 Master, 1 Swab, 1 SS, 2 Wing OD ID LENGTH DEPTH 5.25 2.25 0 TIW Valve HOMCO 4.88 2.44 2.45 2.45 3 1/2 PH-6 Tubing to Surface 12.95 Ib/ft Cross Over Sub, HOMCO Top of XO to the bottom of BN = 781.36' 3.50 2.75 10476.98 10479.43 4.75 2.75 0.84 10480.27 5.0 2.25 28.22 10508.49 SLIP JOINT MODEL B 5' Stroke, SN 128912 Drill Collars, 50 3 Stands 4.75 2.25 280.02 10788.51 5.0 2.4 3.47 10791.98 SORTIE, Reversing Valve Annulus Pressure Activated, SN 1024 Drill Collars, 50 #/ft 1 Stand 4.75 2.25 93.63 10885.61 MIRV, Multi-Indexing Reversing Valve 9 cycle preset option, SN 123492 PTSV-FA, Pump Through Safety Valve SN 1003 RA SUB Actual RA PIP Tag to Top Shot = 237.74' Drill Collars, 50 #/ft 1 Stand MSRT, 3 Channel Recording Tool Electronics SN 107, HSG SN 007 PCTH-FCA, Fullbore 15K PCT, SN 1003 Operating pressure approx. 2300 psi PORT, Pressure Operated Reference Tool By-pass ports closed, SN 1026 DRAIN SUB RCAR-F, Shock Mounted Bundle Carrier RCAR-F-1023, LMR-9439, HPR-9037 TFTV-FCA, Tubing Fill Tester Valve By-pass ports open, SN 1013 5.0 2.25 9.53 10895.14 5.0 2.25 5.58 10900.72 5.0 2.50 1.16 10901.88 4.75 2.25 93.50 10995.38 5.0 2.25 8.02 11003.4 5.0 2.25 25.02 11028.42 5.0 2.25 4.75 11033.17 5.0 2.25 1.3 11034.47 5.3 2.25 15.75 11050.22 5.0 2.25 5.79 11056.01 5.0 2.25 7.32 11063.33 JAR (H2S) Length shown is extended, SN 177885 note' Depths are Measured Depths Updated' 15-MAR-95, final, kb CONNECTIONS 3 1/2 IF 3 1/2 IF 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 3 1/2 IF 3 1/2 IF 3 1/2 IF 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 1/2 GUN mod APl '1/2 GUN mod APl 4 1/2 GUN mod APl BP EXPLORATION (ALASKA) DST ~1 TOOL DESCRIPTION OD ID LENGTH DEPTH BOWEN SAFETY JOINT Cross Over Sub Tri-State SN TSA5359 5.0 2.25 1.69 11065.02 4.75 2.44 0.7 11065.72 7", 29# POSITRIEVE PACKER SN 49204 5.56 2.37 7.19 11072.91 Cross Over Sub Tri-State SN TSA4736 4.75 2.44 1.11 11074.02 RCAR-F, Shock Mounted Bundle Carrier RCAR-F-1029, LMR-9440, LMR-9443 5.3 2.25 15.75 11089.77 RADIAL SHOCK ABSORBER LONG SLOT PORTED DEBRIS SUB Ceramic Debris Cone 2 7/8 EUE Tubing, 6.5 #/ft 2, 10' pups - BP supplied HDF-B / BHF-C Redundant Firing Head HDF-B as Primary FH (Absolute Pressure) SAFETY SPACER 4 1/2 TCP HSD Gun 12 SPF, 135/45 deg Phased Gun TCP Gun Bull Nose 5.5 2.441 1.97 11091.74 3.68 2.375 1.77 11093.51 3.68 2.441 20.48 11113.99 3.68 - 8.92 11122.91 4.50 - 17.09 11140 4.50 - 120 11260 4.5 - 0.79 11260.79 note' Depths are Measured Depths Updated: 15-MAR-95, final, kb SEQUENCE OF EVENTS ~J I ! III Iil II~10 [~]1~ BP Exploration (Alaska) Inc. Badami #5 DST #1 12:00 13:00 14:15 08-MAR-95, Wednesday Depart Kenai Testing Shop. Depart Kenai for Anchorage via Mark Air. Depart Anchorage for Prudhoe Bay via Mark Air. Could not land in Prudhoe due to bad weather. Returned to Anchorage. 05:00 06:45 09:45 09-MAR-95, Thursday Depart Kenai for Anchorage. Depart Anchorage for Prudhoe Bay. Arrive in Prudhoe Bay. Begin preparing DST tools for job. 17:00 10-MAR-95, Friday Continue preparation of tools for job. BPX representative, M. Stanley, at SLB shop to witness pressure testing of tools. 11-MAR-95, Saturday 14:00 08:00 13:00 15:00 17:00 17:30 Continue preparing tools for job. BPX representative, M. Stanley, at SLB shop to witness pressure testing of tools. 12-MAR-95, Sunday Load out equipment to PEAK trucks. 2 doghouses. 2 tool skids. 1 pallet of guns. Personnel depart SLB camp for BPX, Badami #5. Personnel arrive at BPX, Badami #5. Equipment arrived at well. Begin trying to get units wired to the rig and the heat going. Wait on drill pipe to be removed from pipe shead to put in tools. 21:00 05:30 02:15 04:00 08:00 10:00 11:15 12:10 12:26 17:30 23:10 03:00 03:10 03:35 05:20 06:00 06:35 08:00 10:30 14:00 16:35 Put tools in the pipe shead. 13-MAR-95, Monday Start final tool preparations. 14-MAR-95, Tuesday Hold Safety Meeting at rig floor. Begin pick-up tools. Stop PU tools to steam out drill collars and drift drill collars. Resume picking up bottom hole assembly for DST. End PU BHA. RU and RIH with 1 STD of 3-1/2"PH-6 tubing. RU to pressure test BHA. Reverse 5 BBLS with mud pump to clear TFTV. Pressure test BHA with rigs test pump to 6500 psig. 10 min. test, good. Rig up to pressure test 1/2 way in the hole. Test to 6500, good. RU AWS for TCP WL Correlation. 15-MAR-95, Wednesday Complete TCP Correlation. Finish RD AWS. DP correlation = 45' deep. WL correlation showed us to be 46' deep. Space out guns. Dummy set packer with 4 rounds right. Determined that it requires 12' to get 20K on the packer, note: Slip Joint was completely collapsed. RU BJ to pressure test the test string. Complete pressure test to 6500, good. Set packer and rig up Flowhead. Begin pressure testing the flowhead. Had to steam head and regrease valves due to prolonged exposure to -55 degF. Pressure test of flowhead complete. Begin rigging up PTS lines. Complete pressure test to 6500 of PTS lines, good. Got a night cap from AWS to Pressure test the XO from SLB to AWS. 16:45 22:15 23:37 Pressure test failed at 5000 psig. Take to Doyon rig to torque up with their Iron Roughneck. Torqued to 10000 ft-lb. No Test. Torque to 13,500 fi-lbs. Tested at the Doyon rig, tested good. RU flowead again. Complete final test of flowhead to 6500, good. 00:38 01:15 03:07 03:20 03:25 03:30 03:49 03:55 04:00 04:28 04:38 04:45 04:48 05:02 05:10 10:32 10:39 11:00 19:16 19:30 19:32 21:00 16-MAR-g5, Thursday Begin cycling the MIRV open. Begin displacing mud with diesel at 1/2 bbl per min. 66 bbls of diesel pumped. Shut down to get reading before attempting to close. Close MIRV with approx. 3 bbl/min. Pressure annulus to 2000 lbs to fire PORT and the TFTV. Bleed tubing pressure to 2000 to confirm TFTV bypass ports are closed and test the packer seat. Bleed off casing. Pressure annulus to cycle PCT out of Hold-Open. Hold Safety Meeting on the Rig Floor. Begin pressuring up to 6500 activate Hydraulic delay firing head. Bleed tubing down to 1100 psig. Wait for guns to fire. Guns Fired. SI at surface. Surface pressure begins climbing. Open well to flow. Shut-in well at surface to repair leak on PTS line on the rig floor. Open well to choke. Bleed annulus pressure to close the PCT for the Initial Shut-In. Close lower master valve on flowhead and bleed down line to the seperator. Open lower master valve to the rig floor choke manifold. Choke manifold is shut-in. Vent a small amount of gas to flare burner to verify the lines are clear. Pressure annulus to open the PCT for the 2nd flow period. ESD tripped. Problem with PTS Iow pressure pilot. Open choke manifold and flow well. 05:41 06:25 06:35 15:02 17-MAR-95, Friday ESD system tripped. System air supply down to 20 psi. Wait to light flare. Open choke manifold to flow the well. Bleed annulus pressure to close the PCT for the final Build-Up. Bleed the tubing pressure to 0 psig. 09:07 09:48 11:44 13:16 17:34 19:00 22:27 23:15 18-MAR-95, Saturday Pressure annulus to open PCT for sampling flow period. Rig floor manifold closed. Liquid to surface. Shut in well at choke manifold. Close TIW valve and flowhead master valve. Bleed pressure off all surface lines to rig up AWS to run BH samplers. Complete pressure test of WL equipment. RIH with WL. Shut well in at surface and start out of the hole with WL. Rig down WL samples at surface. Begin cycling PCT to the Hold Open position. Add more chicksan to flow and kill lines and pressure test. 00:43 00:54 01:30 01:50 02:58 03:08 03:30 04:27 05:34 19-MAR-95, Sunday Pick up on tubing to open packer bypass. Verify that the PCT is in HO with increased surface pressure. Line up to reverse. Begin reversing to PTS. At approx 82 bbls the surface pressure began rising. Review of BHP data points to a flow restriction at surface. Most likely PTS's choke. Stop reversing, rig up to circulate. Begin circulating at ~900 psig. Circulating at 900 psig on the tubing OK. Kicked pressure/rate up and circulation stopped. Cycle MIRV open. MIRV not open. Realized that the check valve prevented tubing pressure bleed-off. Start cycling MIRV again. Pressure annulus to 4500 to fire SORTIE and PTSV. 05:50 21:00 Start getting returns. Pump at 52 strokes per minute. Start out of hole. 02:00 05:00 20-MAR-95, Monday Begin laying down DST tools & guns. End laying down DST tools & guns. BP Exploration (Alaska)Inc. Badami//5 Drill Stem Test #2 Location: State: Country: Drilling Company: Rig Number: BP RePresentatives: Petrafina Representative: Schlumberger Representatives: Sec. 5, - T9N - R20E Alaska USA Nabors Alaska Drilling 18E Nick Scales Mike Whiteley Mark Stanley Mark Hornbrook Charlie Michel Rhinehart Gros Keith Barnard Tom Carlson Glen Carter IC OFILHED Date RECEIVED MAY ,3 1995 Alsska 0il & Gas Cons. Commission Anchorage ORI61NAL 11000 10000 9000 8000 7000 G000 5000 4000 3000 ! · 7800 6000 - 5000 - 4000 - · ......... ! ......... 20 30 40 50 ! 8'0 9'. CONNECTIONS 3 1/2 IF 3 1/2 PH6 3 1/2 PH6 3 1/2 PH-6 3 1/2 PH-6 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 iF 3.1/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 3 1,/2 IF 3 1/2 IF 3 1/2 IF 3 1/2 IF 4,37 4thd SA ¢.37 4thd SA 3 .1/2 IF 3 1/2 IF 3 1/2 IF 3 1/:~ IF BP EXPLORATION (ALASKA) Inc. BADAMI #5 TOOL DESCRIPTION OD ID LENGTH DEPTH 1OK Surface Flowhead Valves = 2 Master, 1 Swab, 1 SS, 2 Wing 5.25 2.25 0 TIW Valve HOMCO 4.88 2.44 2.45 2.45 3 1/2 PH-6 Tubing to Surface 12.95 Ib/ft 3.50 2.75 10040.01 10042.46 Cross Over Sub, HOMCO Top of XO to the bottom of BN = 781.36' 4.75 2.75 0.84 10043.3 SLIP JOINT MODEL B 5' Stroke, SN 128912 5.0 2.25 28.22 10071.52 Drill Collars, 50 #/ft 3 Stands 4.75 2.25 280.02 10351.54 ,., SORTIE, Reversing Valve Annulus Pressure Activated, SN 1024 5.0 2.4 3.47 10355.01 Drill Collars, 50 #/ft 1 Stand 4.75 2.25 93.63 10448.64 MIRV, Multi-Indexing Reversing Valve 14 cycle preset option, SN 128577 PTSV-FA, Pump Through Safety Valve SN 1005 SORTIE, Reversing Valve Annulus Pressure Activated, SN 1023 RA SUB Actual RA PIP Tag to Top Shot = 237.74-' Drill Collars, 50 #/ft 1 Stand 5.0 2.25 9.53 10458.17 5.0 2.25 5.58 10463.75 5.0 2.4 3.47 10467.22 5.0 2.50 1.16 104-68.38 4.75 2.25 93.50 10561.88 MSRT, 3 Channel Recording Tool Electronics SN 107, HSG SN 007 5.0 2.25 8.02 10569.9 PCT'H-FCA, Fullbore 15K PCT, SN 1004 Operating pressure approx. 2300 psi 5.0 2.25 25.02 10594.92 PORT, Pressure Operated Reference Tool By-pass ports closed, SN 1025 5.0 2.25 4.75 10599.67 DRAIN SUB 5.0 2.25 1.3 10600.97 RCAR-F, Shock Mounted Bundle Carrier RCAR-F-1023, LMR-9439, LMR-9301 5.3 2.25 15.75 10616.72 TFTV-FCA, Tubing Fill Tester Valve By-pass ports open, SN 1014 5.0 2.25 5.79 10622.51 note' Depths are Measured Depths Updated:20-MAR-95, final, kb CONNECTIONS 3 1/2 IF 3 1/2 IF 3 1/2 IF 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 3 1/2 IF 3 1/2 IF 3 1/2 IF 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 2 7/8 EUE 4 1/2 GUN mod APl 4 1/2 GUN mod APl 4 1/2 GUN mod APl BP EXPLORATION (ALASKA) Inc. DST #2 TOOL DESCRIPTION OD ID LENGTH DEPTH JAR (H2S) Length shown is extended, SN 177885 5.0 2.25 7.32 10629.83 BOWEN SAFETY JOINT SN D73830-04 Cross Over Sub Tri-State SN TSA2441 5.0 4.75 2.25 1.69 10631.52 2.44 0.7 10632.22 7", 29# POSITRIEVE PACKER SN 49205 5.56 2.37 7.19 10639.41 Cross Over Sub Tri-State SN TSA8544 4.75 2.44 1.11 10640.52 RCAR-F, Shock Mounted Bundle Carrier RCAR-F-1029, LMR-9440, LMR-9443 5.3 2.25 15.75 10656.27 RADIAL SHOCK ABSORBER LONG SLOT PORTED DEBRIS SUB Ceramic Debris Cone 2 7/8 EUE Tubing, 6.5 #/ft 2, 10' pups - BP supplied HDF-B / BHF-C Redundant Firing Head HDF-B as Primary FH (Absolute Pressure) SAFETY SPACER 4 1/2 TCP HSD Gun 12 SPF, 135/45 deg Phased Gun TCP Gun Bull Nose 5.5 3.68 3.68 3.68 4.50 4.50 4.5 2.441 1.97 10658.24 2.375 . 1.77 10660.01 2.441 20.4-8 10680.49 8.92 10689.41 10.59 10700 110 ' 10810 0.79 10810.79 note: Depths are Measured Depths Updated:20-MAR-95, final, kb SEQUENCE OF EVENTS BP Exploration (Alaska) Inc. Badami #5 DST #2 20-MAR-95, Monday 12:30 Begin final tool preparation for DST #2. 22:00 22:30 21-MAR-95, Tuesday Safety meeting at rig floor. Begin picking up guns/DST tools. 02:05 02:45 03:45 12:00 15:30 17:00 17:27 19:02 20:51 22:05 23:48 23:57 22-MAR-95, Wednesday End picking up tools. Rig up to pressure test. High pressure, Iow volume pump will not seat flapper. Rig up mud pump & pressure up to 2500, close TIW valve and RU high pressure rig pump. Pressure test to 6500 psig complete. RIH. Pressure test string to 6500 psig on the way in the hole. Rig up AWS for TCP correlation. End rig doWn AWS for TCP correlation. Space out guns. Correlation shows the guns are 11' deep. Complete pressure test to 6500 psig. Set packer and rig up flowhead. Complete Pressure test of flowhead to 6500 psig. Rig up PTS and BJ. Begin pressure testing surface equipment. Begin cycling MIRV open. MIRV closed after pumping 5 bbls. Begin cycling open again. 00:38 23-MAR-95, Thursday Tubing pressured up again. MIRV closed (??) again after pumping 13 bbls. 00:57 01:02 01:09 01'11 01:45 01:55 02:03 02:14 02:15 02:22 04:03 04:08 04:12 04:30 04:38 04:47 04:53 04:57 05:00 . . 05:23 05:26 05:44 06:04 15:00 Pressure annulus to 2100 to fire PORT and the TFTV. Tubing pressure is noted at 2100 also. MIRV mu~ be open. Bleed annulus to 0. TW bleeding tubing. Pressure came right back up. MIRV must be open. Pump down tubing with diesel to vedfy MIRV is open. Stad getting returns right away. Dete~ine to pump down tubing at high rate to close MIRV. Close MIRV at the rate of -2 bbl/min. Tubing pressure up to 3000 psig. Bleed tubing pressure back to 0. Annulus and tubing are stable. Annulus & tubing remain stable. Pick up string and open packer bypass to circulate in diesel cushion. Packer bypass open. Stad pumping diesel with BJ. Complete displacing mud with diesel. Total displacement = 67 bbls. Reset packer. Pressure annulus to 2200 psig. Tubing pressure jumped up at ~1500 psig also. MIRV pushed open again. Attempt to close MIRV. BJ at .7 bbs/min, not enough rate. Attempt to close MIRV. BJ at 1.4 bbs/rain, not enough rate. Attempt to close MIRV. BJ at 2 bbs/min, tubing pressured up to 4500 psig. MIRV appears closed. Bleed tubing to 2400. Holding OK. Bleed tubing to 2100. Holding OK. Line up to fire guns. Verify that the rig floor choke manifold is shut-in. Pressure annulus to 2200 psig. Hold a safety meeting at the rig floor. Pressure tubing to 6300 to activate Hydraulic Delay Firing head. Hold for 3 minutes. Annulus pressure is stable. Bleed tubing back to 1330 psig. Close the Kill Line wing valve. Guns fired. Remain closed at rig floor choke manifold. Begin flowing well through the rig floor choke manifold. Bleed annulus pressure to close the PCT for the initial shut-in. 00:03 01:10 02:00 00:03 00:09 23:15 00:01 02:00 03:14 07:29 08:35 09:45 11:23 11:45 12:01 12:02 12:47 13:01 13:11 13:39 16:27 21:31 24-MAR-95, Friday Pressure annulus to 2200 to open the PCT. Open well at the dg floor choke manifold to begin flow. Note a 300 psig difference in the rig floor annulus pressure gauge and the PTS system gauge. Verified that PTS is 300 psi high by lining up a test gauge to the annulus. The test gauge and rig's gauge are close. 25-MAR-95, Saturday Bleed annulus pressure to close the PCT. Close the lower master valve. RU AWS for BH sample run. 26-MAR-95, Sunday Pressure annulus to open the PCT to flow the well. Close the flowhead master valve and bleed surface pressure to rig up AWS lubricator. RIH with BH samplers. Stop flowing the well. POOH with BH samples. BH samples to surface. Rig down AWS. Rig up to cycle PCT to the Hold Open. Cycle PCT to HO. PU on tubing and open the packer bypass. Verified open per an increase in tubing pressure. Begin U-tubing kill fluid. After 67 bbls the U-tubing stopped. Close rams and apply pressure to the annulus. Pressured up the annulus to 760. No returns. Set packer to fire SORTIE. Pressure annulus to 3200 to fire SORTIE. Begin circulating. Unseat packer and break out flowhead. Put on circulating head. Start out of hole. 01:30 05:00 06:00 27-MAR-95, Monday Begin laying down tools (slip joint). Safety Meeting. End Laying down tools/guns. ! CONFIDENT it L BADAMI #5 DOWNHOLE WATER SAMPLE ANALYSIS Shallow Sand- Potential Water Source by Corrosion, Inspection, and Chemical Group, Prudhoe Bay Unit April 20, 1995 INTRODUCTION - Badami field is in the early developmental stage and several downhole samples are being collected for reservoir fluid property characterization of a potential shallow water source zone. TEST PROCEDURES A downhole water sample collected in a PVT sampling tool and a surface water sample in a metal container were delivered to Prudhoe Bay Laboratory on April 2, 1995. The downhole sample was collected from Badami #5 well at a depth of 4750 feet (open perforations 4975' - 4989' tvd). The reservoir pressure is 2250 psi and the reservoir temperature is 60 °F (15.5 °C). The PVT tool was set vertically in the laboratory to separate oil and water. The water was carefully drained out from the bottom of the tool into a Hamilton 1000 cc gas syringe. Because of the lacking of a high pressure conversion fitting, this was not done under the single phase condition as recommended in the original plan. The volume of dissolved gas separated from the water was measured in the Hamilton gas syringe and the gas water ratio (GWR) and temperature were recorded. The water sample was then expelled from the gas syringe and the pH measured in a beaker. This was again deviated from the original plan that suggests to use an in-line pH probe connected directly to the gas syringe. The alkalinity of the water sample was measured by the potentiometric titration method. One half of the water sample was acidified with HNO3 acid for cation analyses by ICP or AA. The remaining half of the sample was not acidified for anion analyses including F, C1, Br, SO4, PO4, and organic acids by IC or titration methods. Dissolved sulfide was measured by the potentiometric titration method using a sulfide specific electrode. The Hamilton gas syringe was then inverted and the dry gas phase was transferred into a gas chromatography (GC) unit for complete gas analyses. The remaining gas was used for H2S gas analyses using the Ecolizer. No air was introduced into the system during the entire process. DISCUSSION Chemical compositions of two water samples are tabulated in Table 1. Because an in-line pH probe was not used this causes some uncertainty in the downhole sample pH measurement. The operator reported an initial pH of 5.2 and increased quickly to 7.1. The gas syringe data show there was 310 ml of dissolved gas liberated from 475 ml of water under ambient conditions. The gas composition analyzed by a GC is given in Table 2. The majority of the dissolved gas is methane with only 0.1 mole % of the dissolved gas is CO2. No H2S was detected in the gas phase. REC.EIV'ED Oil & ~ gons. C~mmission TABLE 1 Chemical Composition of Badami-~5 Bottomhole and Surface Water Samples Component ppm Bottomhole Surface Ca 1072 1032 Mg 954 944 Na 14200 14100 K 80 80 Fe 11.7 12.3 Mn 2.2 2.2 A1 1.4 0.2 Ba 52.3 50.4 Sr 14.2 14.4 Si 6.2 2.8 Cr <1 <1 B <1 <1 CI- 22700 22400 HCO3- 556 -- SO42- <1 <1 F- <1 <1 Br- 178 178 PO4 <10 13.2 Acetate 3.1 5.4 Propionate 7.2 5.7 Butyrate 1.2 3.0 TDS 39203 Spec. gravity 1.0340 pH (field)* 5.2- 7.1' pH (Lab) 6.9 pH (downhole)** 6.3 - 6.5** GWR 0.653 38749 1.0348 7.0 7.0 Operator reported the sample pH measured initially was at 5.2 and increased rapidly to 7.1. Based on model calculations, however, this pH value should be between 6.6 and 7.1 and probably very close to 6.9. Downhole pH calculated by adding liberated CO2 gas back in the solution under reservoir conditions. O llgiixlAL TABLE 2 Chemical Composition of Dissolved Gas in Badami-~5 Bottomhole Water Sample Component Mole % N2 3 CO2 0.1 C1 96.85 C2 0.05 C3 0 C4 0 C5 0 C6 0 Spc Gravity 0.569 Compress. 0.998 Btu 962.1 CONFIDENt"IAI_ Note: The chemical composition of dissolved gas in reservoir water is different from the composition of gas cap gas or dissolved gas in oil. O?,IGiNAL CONFIDENTIAL Badami g5 CONFIDENTIAL AP1 Number: 50-629-22533-00 all core footage are driller's depth; core diameter approximately 4" Core gl: cut 10,489' to 10,498', recovered 8.3 feet (in Aluminum liner) 11,489' - 11,497.3' gray muddy siltstone with minor amounts of cemented very fine grained sandstone as laminae and streaks. No oil stain, cut or fluorescence. Apparent dips variable, ranging from 25° to 60°. Core g2: cut 10,550' to 10,553', recovered 0.4 feet (in Aluminum liner) 10,550.0' - 11,550.4' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 50°. Core g3: cut 10,553' to 10,573', recovered 20 feet (in Aluminum liner) 10,553.0' - 10,573.0' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip ranges from 48° to 55°. Core g4: cut 11,016' to 11,024', recovered 5.7 feet (in Aluminum liner) 11,016.0' - 11,021.7' gray siltstone interlaminated with minor amounts of very fine grained sandstone. Sandstone is oil stained medium brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 28°. Core g5: cut 11,113' to 11,143', recovered 25 feet (in Aluminum liner) 11,113.0' - 11,1120.0' gray siltstone interlaminated with very fine grained sandstone. Sandstone is oil stained medium brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 30°. 11,120.0' - 11,138.0' gray siltstone (interlaminated with very fine grained sandstone) interbedded with thin bedded sandstone. Sandstone (as beds and in laminae) is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 32°. Core #6: cut 11,143' to 11,203', recovered 59.5 feet (in Aluminum liner) 11,143.0' - 11,160.0' gray siltstone interlaminated and interbedded with fine grained sandstone. Sandstone (as beds to 8' thick and in laminae) is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 35°. 11,160.0' - 11,166.0' Sandstone with rare thin interbeds of siltstone. Sandstone is fine to medium and contains carbonaceous and coaly debris. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 35°. MiCgOFiLi [ o i iN L Co,s. Co miss o, 11,166.0' - 11,175.5' gray siltstone interlaminated and interbedded with very fine to fine grained sandstone. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 41° 11,175.5' - 11,196.7' Sandstone with rare thin interbeds of siltstone. Sandstone is very fine to fine grained and contains carbonaceous and coa!y debris. Sandstone is oil stained dark brown to light brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. 11,196.7' - 11,202.5' Sandstone with rare thin interbeds of carbonaceous sandstone. Sandstone is fine to medium grained and is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. Core 4/7: cut 11,203' to 11,263', recovered 60'+ feet (in Aluminum liner) 11,203.0' - 11,213.4' Sandstone with rare thin interbeds of carbonaceous sandstone. Sandstone is fine to medium grained and is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is 40°. 11,213.4' - 11,247.3' Sandstone with thin interbeds of carbonaceous sandstone and gray siltstone. Sandstone is fine to medium grained with some beds containing siltstone clasts. Sandstone is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is approximately 40°. 11,247.3' - 11,252.8' gray to tan siltstone and silty mudstone. No stain, cut or fluorescence. Highly variable dips ranging from 10° to 60°. 11,252.8' - 11,257.8' Sandstone with thin interbeds of carbonaceous sandstone and gray siltstone. Sandstone is fine to medium grained with some beds containing siltstone clasts. Sandstone is oil stained dark brown to medium brown. Stained sandstone has dull yellow to orange fluorescence and bright yellow streaming cut fluorescence. Apparent dip is approximately 40°. 11,27.8' - 11,263.0' + 8" gray to tan silty mudstone and siltstone. No stain, cut or fluorescence. Highly variable dips ranging from 5° to 70°. Core 4/8: cut 11,263.0' to 11,270', recovered feet (in Aluminum liner) 11,263.0' - 11,268.6' gray to tan silty mudstone and siltstone. No stain, cut or fluorescence. Highly variable dips ranging from 0° to 40°. CONFIDENTIAL CONFIDENTIAL ORIG NAL PETROLEUM SERVICES BP EXPLORATION (ALASKA), INC. CORE ANALYSIS REPORT BADAMI #5 EXPLORATION NORTH SLOPE, ALASKA CL FILE NO. BP-3-1573 Performed by: Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented May 2, 1995 MAY q 1995 These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for hose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement f Core Laboratories (aLL errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oiL, gas or other mineral weLL or formation in connection with which such report is used or relied upon. ORIGINAL Core Laboratories, Inc. 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541, Fax (907) 344-2823 BP Exploration (Alaska), Inc. CONFIDENTIAL Badami #5 API Number: 50-629-22533-00 all core footage are driller's depth; core diameter approximately 4" Core gl' 11,489' - 11,497.3' No core analysis (all non pay muddy siltstone) Core g2: 10,550.0' - 11,550.4' Core g3: 10,553.0' - 10,573.0' Core g4: 11,016.0' - 11,021.7' Core g5: 11,113.0' - 11,138.0' Core g6: 11,143.0' - 11,202.5' Core g7:11,203.0' - 11,263.0' + 8" Core g8: 11,263.0'- 11,268.6' No core analysis (all non pay muddy siltstone) CONFIDENTIAL CONFIDENTIAL ORIGINAL Company Jell CORE : BP EXPLORATION (ALASKA), iNC. : BADAMI #5 ANAL YT I CAL PROC EDU R LABORATORIES Field : EXPLORATION Formation : ES AND QUALITY File No..- Date : 28-APR-95 A S S U R A N.~C E HANDLING & CLEANING Core Transportation Solvent Extraction Equipment 'Extraction Time Drying Equipment Drying Time Drying Temperature : AIR FREIGHT : TOLUENE : DEAN-STARK : TO STABLE READING : CONVECTION AND VACUUM OVENS : 48 HOURS : 180' F. C) ANALYSIS Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Permeabilities measured on ONE in. diameter drilled plugs Core Gamma Co~osite Dean Stark grain densities clean, dry solid mineral phase are measured CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA CO ,F DEN.TJAL .FILE: 1573 DATE: 28-APR-95 ANALYSTS:PB,D S,DA DEAN STARK ANALYSIS PLUG SAM PLES # # I:1' Kair/Md I Kair/Md (%) % PvI % Pv GM/CC DESCRIP11ON 2 1 10550.2 1.11 9.7 36.3 54.0 2.71 SS-bnd dk & Itgy,slt-vfsd,predvfsd,wsrtd,rnd,vwcrnt,qtz,brn cly,tr dol 3 1 10555.9 0.02 8.3 25.4 70.2 2.72 Sltst-mgy,slt-vfsd,pred slt,wsrtd,rnd,vwcmt,gy cly,qtz,bit,tr calc 3 2 10556.7 0.10 9.7 41.1 53.7 2.71 Sltst-mgy,slt-fsd,pred slt,wsrtd,rnd,vwcmt,gy cly,qtz,bit,tr calc 3 3 10559.4 7.08 13.1 53.2 28.1 2.70 SS-mltgy,slt-fsd,predvfsd,lam,rnd,vwcmt,qtz,gy cly,bit,tr calc,open jt 3 4 10560.7 BROKEN 12.3 52.5 38.6 2.71 SS-mltgy,slt-fsd,predvfsd,bnd,rnd,vwcrnt,qtz,gy cly,bit,tr calc,broken 3 5 10561.6 5.69 11.8 38.2 45.7 2.71 SS-mltgy,slt-fsd,predvfsd,bnd,rnd,vwcrnt,qtz,gy cly,bit,tr calc,frac 3 6 10562.0 9.64 12.6 44.8 -34.2 2.70 SS-mltgy,slt-fsd,predvfsd,bnd,rnd,vwcmt,qtz,gy cly,bit,tr calc,frac 3 7 10564.5 1.68 10.1 39.0 48.6 2,72 Sltst-mgy,slt-vfsd,pred slt, lam,rnd,vwcrnt,gy cly,qtz, bit,tr calc 3 8 10564.9 1.59 11.4 46.6 36.8 2.70 SS-mltgy,slt-fsd,predvfsd,p larn,rnd,vwcrnt,qtz,gy cly,bit,tr calc 3 9 10566.7 2.80 11.2 44.4 39.6 2.70 SS-mltgy,slt-msd,predvfsd,lam,rnd,vwcmt, qtz,gy cly,bit,tr calc 3 10 10571.9 0.21 10.4 44.0 43.4 2.71 SS-mgy,slt-msd, predvfsd,lam,rnd,vwcmt,qtz,gy cly,bit,tr calc 3 11 10563.8 0.17 10.4 41.5 44.3 2.72 SS-Itbrngy,slt--fsd,predvfsd,wsrtd,rnd,vwcrnt, qtz,brn cly,tr bit 4 1 11016.4 8.25. 13.8 52.8 17.4 2.66 SS-Itgy,vf-m gr, predvfgr,wsrtd,sbrnd,vwcmt,qtz,occ C lam,tr calc 4 2 11017.2 0.10 7.9 26.3 66.6 2.70 Sltst-mgy,slt-fsd,pred slt,wsrtd,rnd,vwcmt, gy cly,qtz,tr bit,occ dol 4 3 11018.3 0:86 10.0 45.6 41.1 2.69 SS-mdkgy,slt-msd,predfsd,p lam,mod srtd,sbrnd,vwcmt, qtz,brn cly,occ calc,bit 4 4 11019.3 0.09 8.5 26.5 61.9 2.73 Sltst-mgy,slt-fsd,pred slt,wsrtd,rnd,vwcrnt,gy cly,qtz,tr bit,occ dol 4 5 11019.9 3.37 8.7 28.8 60.4 2.71 SS-mgy,slt-fsd,predvfsd,wsrtd,rnd,vwcmt,qtz,gy cly,tr bit,tr dol,bdg jt 4 6 11020.8 0.02 7.5 27.4 67.2 2.72 Sltst-mgy,slt-fsd,pred slt,wsrtd,rnd,vwcrnt,gy cly,qtz,dol,tr glau & bit 4 7 11021.4 0.23 9.2 26.6 57.6 2.73 Sltst-mgy,slt-fsd,pred slt,wsrtd,rnd,vwcmt,gy cly,qtz,dol,tr glau & bit 5 1 11113.4 15.1 10.2 40.7 42.4 2.69 SS-mgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcrnt,qtz,gy cly,occ bit & calc,bdg jt 5 2 11114.7 0.13 9.6 45.0 43.9 2.68 SS-mgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcrnt,qtz,gy cly,occ bit & calc 5 3 11115.8 0.11 9.6 33.5 57.2 2.71 SS-mgy,slt-vfsd,predvfsd,wsrtd,rnd,vwcmt,qtz,dol,occ bit,broken 5 4 11117.1 3.09 11.1 42.5 38.5 2.69 SS-Itbmgy,vf-mgr, predfgr, bnd,wsrtd,sbrnd,vwcrnt, qtz,brn cly,dol,tr bit 5 5 11118.5 27.4 11.2 41.1 39.8 2.68 SS-mitgy,vf-mgr, predfgr, bnd,wsrtd,sbrnd,vwcrnt,qtz,brn cly,dol,tr bit, bdg jt 5 6 11120.3 ,50.4 15.4 50.6 29.9 2.68 SS-mltgy,vf-cgr, bnd,mod srtd,sbang,vwcmt, qtz, brn cl¥,dol,tr bit 5 7 11121.1 67.3 19.0 40.0 24.1 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,vwcrnt,qtz,brn lith gr, tr bit & calc 5 8 11121.5 6.77 11.6 41.9 38.7 2.67 SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,vwcmt,qtz,brn lith gr, dol,tr bit,bdg jr,broken 5 9 11122.5 200 20.3 42.4 20.5 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,vwcrnt, qtz,brn lith gr, dol,tr bit,frac ORIGINAl_ CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA CORE SP[ # # 5 10 11123.2 5 11 11125.3 5 12 11126 5 13 11123.7 5 14 11128.3 5 15 11129.2 5 16 11131.5 5 17 11130.1 5 18 11134.1 5 19 11136.6 5 2O- 11131.1 5 21 11134.7 5 22 11135.4 5 23 11132.3 5 24 11133.3 6 1 11143.8 6 2 11144.3 6 3 11146.4 6 4 - 11145.7 6 5 11148.4 6 6 11149.5 6 7 11146.7 6 8 11147.1 6 9 11149.0 6 10 11150.4 6 11 11151.2 6 12 11151.8 6 13 11152.5 ! I-u ~ PERMEABIUTY POROSITY SATURATIONS GRAIN DEPTH HOFIZONTALJVERTICAL (HEUUM) OIL IWATER DENSITY FT Kair/Md Kair/Md (%) % Pv % Pv GM/CC CO' FIDEF1TIAL' DEAN STARK ANALYSIS PLUG SAMPLES 30.9 12.1 1.14 3.02 5.63 2.89 8.36 0.24 4.15 1.21 6:56 67.2 15.2 0.19 22.0 59.0 53.5 13.1 30.2 DESC RI PTI ON 17.5 40.3 27.9 2.67 15.1 53.1 19.5 2.66 2.5 55.4 41.1 2.72 14.2 52.1 18.4 2.65 10.2 37.5 53.9 2.69 10.9 31.1 53.9 2.71 14.36 BROKEN 124 2.18 113 5.0 26.6 6.01 1.18 17.6 0.26 34.3 1.37 1,72 16.4 37.0 31.6 2.67 9.4 43.2 49.3 2.71 11.1 46.1 33.6 2.68 12.7 4516 29.6 2.71 13.9 39.1 33.4 2.65 18.3 42.3 28.4 2.66 14.0 44.9 22.8 2.66 9.2 42.0 47.1 2.71 10.6 41.1 45.2 2.71 18.4 38.2 26.4 2.63 18.4 33.8 27.7 2.62 16.3 40.2 28.7 2.62 17.4 46.6 20.2 2.62 15.0 50.7 -26.4 2.63 15.0 42.1 27.6 2.66 20.6 45.6 29.2 2.65 12.7 44.0 28.5 2.68 20.2 37.3 28.0 2.64 12.4 27.5 50.4 2.70 16.7 49.5 26.5 2.65 13.4 36.5 39.5 2.68 12.2 44.8 30.1 2.66 ORI ! AL FILE: 1573 DATE: 28-APR-95 ANALYSTS: PB ,D S,D A SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,brn lith gr, dol,tr bit SS-Itgy,slt-csd,bnd,mod srtd,sb ang,vwcmt,qtz,brn lith gr, blk cly,tr calc SS-Itgy,vf-m gr, predvfgr,wsrtd,sbrnd,vwcm t,qtz,calc cmt,tr bit & glau SS-ltgy,slt-msd, bnd,mod srtd,sbmd,vwcmt,qtz,occ dol & bit $1tst-mgy,bnd w/f-mgr SS,w srtd,vwcmt, qtz,gy cly,dol,tr bit,sml frac Sltst-mgy,bnd w/f-mgr SS,w srtd,vwcmt, qtz,gy cly,dol,tr bit SS-Itgy,vf-fgr, predvfgr, occ lam,wsrtd,sbrnd,vwcm t,qtz,occ bit,tr calc Sltst-ltbrngy,lam w/fgr SS,wsrtd,vwcmt, brn cly,qtz,dol,tr bit Sltst-mgy,bnd w/f-mgr SS,w srtd,vwcmt,qtz,gy cly,dol,tr bit SS-Itgy,slt-msd, bnd,mod srtd,sbrnd,vwcmt,qtz,occ dol & bit SS-m gy,vf-m gr, predfgr, wsrtd, bnd w/bm slt,rnd,wcm t,qtz, brn arg gr, C lam SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,vwcmt,qtz,brn lith gr, tr bit SS-Itgy,slt-msd, bnd,mod srtd,sbrnd,vwcmt,qtz,occ dol & bit SS-mgy,slt-msd, lam,mod srtd,sbrnd,vwcmt,qtz,dol,tr bit SS-mgy,slt-msd,lam,mod srtd,sbrnd,vwcmt, qtz,dol,tr bit,sml frac SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit SS-Itgy,f-mgr, predfgr,occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ C SS-ltgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit SS-mltgy,vf-mgr, predfgr, bnd,wsrtd,sbrnd,vwcmt,qtz,dk lith gr, wh cmt, broken SS-Itgy,vf-m gr, predfgr,wsrtd,rnd,vwcmt,qtz,brn arg gr, wh cmt,tr calc $S-mgy,slt-msd, lam,mod srtd,sbrnd,vwcmt, qtz,dol,tr bit SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit SS-Itgy bnd w/mgy Sltst, wsrtd,sbrnd,wcmt, qtz,gy cly,dol,tr bit, broken SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit, broken SS - Itgy bnd w/m gy Sltst,wsrtd,s brnd,wcm t, qtz, gy cly,dol,tr bit, broken SS-Itgy,f-m~r, lam,wsrtd,sbmd,wcm t,q._tz,brn lith ~r, occ bit CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA FI L.E: 1573 DATE: 20-APR-95 ANALYSTS:PB,D S,DA DEAN STARK ANALYSIS PLUG SAMPLES PERMEABIUTY POROSITY SATURATIONS GRAIN CORE SPI. DEPTH HORIZONTALI VERTICAL (HEUUM) OIL WATER DENSITY ..~,_ # FT' Kair/Md I Kair/Md (%) % Pv % Pv GM/CC DESCRIPTION 6 14 11153.5 12.6 0.33 16.2 54.7 25.6 2.62 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcrnt,qtz,brn lith gr, occ bit 6 15 11154.3 169 21.8 20.6 36.2 27.8 2.64 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt, qtz,brn lith gr, occ bit 6 16 11154.9 1.82 14.0 48.9 18.6 2.66 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,vwcmt, qtz,brn lith gr, occ bit 6 17 11155.7 38.5 16.9 35.5 30.8 2.66 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,vwcmt,qtz,brn lith gr, occ bit 6 18 11156.6 9.03 1.07 14.9 40.7 27.9 2.64 SS-Itgy,f-mgr, predfgr,occ lam,wsrtd,sbrnd,vwcmt,qtz,brn lith gr,occ bit,bdg jt 6 19 11157.2 3.64 0.14 14.3 43.6 28.8 2.65 SS-Itgy,f-mgr, predfgr, lam,wsrtd,sbrnd,vwcmt,qtz,brn lith gr,occ bit 6 20 11158.5 202 0.01 20.3 39.9 25.2 2.65 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,vwcrnt,qtz,brn lith gr,occ bit 6 21 11159.2 50.9 18.9 37.0 28.0 2.63 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr,occ bit 6 22 11159.7 34.1 18.5 35.8 31.2 2.66 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr,occ bit 6 23 11160.0 110 1.94 20.4 42.6 21.7 2.60 SS-Itgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, occ bit 6 24 A 11161.1 112 85.1 21.2 40.4 26.8 2.66 SS-Itgy,vf-mgr, predmgr, wsrtd,sbrnd,vwcmt,qtz, brn arg gr, wh cmt 6 24 B 11161.5 121 21.0 41.9 27.6 2.67 SS-Itgy,vf-mgr, predmgr, wsrtd,sbrnd,vwcmt, qtz, brn arg gr,wh cmt,tr pyr 6 24 C 11161.9 38.4 18.7 37.9 28.2 2.66 SS-Itgy,vf-mgr, predrngr, wsrtd,sbrnd,vwcrnt,qtz, brn arg gr,wh cmt,occ pyr & bit 6 25 11162.4 110 19.2 21.0 40.4 27.3 2.67 SS-Itgy,f-cgr, predfgr, wsrtd,sbrnd,wcrnt,qtz,brn lith gr, wh crnt,occ bit 6 26 11163.5 105 60.2 20.6 38.0 27.8 2.66 SS-Itgy,f-cgr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn lith gr, wh crnt,occ bit 6 27 11164.0 81.7 20.2 37.6 28.0 2.66 SS-Itgy,f-cgr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn lith gr, wh cmt,occ bit 6 28 11164.8 110 11.7 20.1 41.0 27.8 2.64 SS-Itgy,f-cgr, predfgr,wsrtd,sbrnd,wcmt,qtz,brn lith gr, wh cm t,Sltst pbl 6 29 11165.6 163 188 21.6 41.5 24.7 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbmd,wcrnt,qtz, brn lith gr,wh cmt,occ bit 6 30 A 11166.1 BROKEN 0.36 ~ 16.4 95.1 22.8 2.59 SS-Itgy,vf-fgr, predvfgr, occ lam,wsrtd,sbrnd,wcmt,qtz,occ bit, broken 6 30 B 11166.6 0.01 4.7 28.2 62.6 2.75 SS-mgy,vf-fgr, bnd,wsrtd,sbrnd,vwcmt,qtz,calc cmt,tr bit & pyr 6 31 11167.7 66.6 19.0 35.9 27.8 2.66 SS-ltgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt,qtz,brn lith gr, tr bit 6 32 11168.3 59.6 19.1 37.8 27.9 2.66 SS-ltgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn lith gr,tr bit 6 33 11169.4 22.3 0.85 17.7 49.6 20.5 2.66 SS-ltgy,f-mgr, predfgr, occ lam,wsrtd,sbrnd,wcmt, qtz,brn lith gr, occ bit 6 34 11170.1 65.6 41.0 19.5 40.2 27.3 2.67 SS-ltgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt,qtz,brn lith gr,tr bit 6 35 11171.1 38.7 18.7 39.2 28.6 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcrnt,qtz,brn lith gr, tr bit 6 36 11172.3 233 21.0 36.7 32.0 2.66 SS-ltgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt,qtz,brn lith gr 6 37 11172.5 161 20.4 40.1 30.3 2.68 SS-Itgy,f-mgr, predfgr, wsrtd,sbmd,wcmt, qtz,brn lith gr, Sltst lam 6 38 11173.7 105 20.3 38.3 26.4 2.66 SS-ltgy',f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn lith gr, tr glau ORIGI , AL CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA CORE # 6 39 11175.5 83.3 6 40 11176.7 388 6 41 11177.2 33.9 6 42 11177.7 68.7 6 43 11178.7 97.1 6 44 11174.7 147 6 45 11179.3 331 6 46 11180.0 301 6 47 11180.8 2.17 6 48 11181.4 115 6 49 11182.3 144 6 50 11183.1 422 6 51 11184.8 55.4 6 52 11185.4 41.5 6 53 11187.0 201 6 54A 11187.5 110 6 54B 11187.9 25.9 6 55 11188.9 8.76 6 56 11189.3 97.1 6 57 11189.6 90.0 6 58 11190.2 67.6 6 59 11191.3 0.70 6 60A 11192.5 106 6 60B 11192.6 6.75 6 61 11193.3 10.1 6 62 11194.6 46.4 6 63 11195.9 BROKEN 6 64 11196.1 11.3 DEAN STARK ANALYSIS PLUG SAMPLES PERMEABIUTY I POROSITYI SATURATIONS I GRAIN Kair/Md ~ (%) % Pv % Pv GM/CC DESCRIPTION 10.2 20.1 38.7 25.8 2.66 23.3 40.7 25.2 2.64 18.8 38.8 28.4 2.66 8.46 19.6 37.5 27.0 2.66 20.7 38.9 28.2 2.66 54.0 20.9 35.7 27.8 2.66 205 23.3 40.8 25.1 2.65 21.0 34.5 27.9 2.66 9.1 36.6 45.2 2.70 20.2 37.6 26.1 2.66 " 21.7 41.7 24.5 -' 2.66 134 22.2 36.1 28.5 2.65 9.50 19.7 37.0 28.5 2.66 17.3 42.2 27.3 2.65 21.5 36.5 26.8 2.66 21.3 41.4 28.9 2.66 1.61 17.9 43.9 28.8 2.66 0.23 14.9 41.0 30.1 2.67 20.6 40.8 28.3 2.65 35.7 20.4 39.6 31.8 2.66 ! 9.7 52.1 29.5 2.64 0.40 13.5 50.9 19.7 2.67 16.3 39.8 28.9 2.61 16.6 33.8 41.0 2.67 16.6 43.0 22.2 2.63 6.71 18.3 35.8 33.8 2.65 2.21 18.1 46.5 17.9 2.55 16.9 47.0 21.9 2.54 FILE: 1573 DATE: 28-APR-95 A NA LYSTS: PB ,D S,D A SS-ltgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn lith gr,tr bit SS-Itgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,wcmt,qtz,brn lith gr, tr bit SS-Itgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,vwcmt,qtz,brn lith gr, tr bit SS-Itgy,vf-m gr, predfgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr SS-Itgy,vf-m gr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr SS-Itgy,vf-m gr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr SS-Itgy,vf-m gr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr SS-Itgy,vf-m gr, predfgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr SS-m gy,slt- fsd,predvfsd,bn d,wsrtd, rn d,vwcm t, qtz, dol,occ bit, bdg jt SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr, SS-vltgy,f-m gr, predfgr, wsrtd,sbrnd,wcmt,qtz,brn arg gr, wh cmt SS-vltgy,f-cgr, predm gr, wsrtd,sbrnd,wcm t, qtz, brn arg gr,wh cmt SS-vltgy,f-m gr, predfgr, wsrtd,sbrnd,wcmt, qtz,brn arg gr, wh cmt SS-Itgy,vf-m gr, predfgr, wsrtd,rnd,vwcmt,qtz,brn lith gr,f C lam ,wh cmt SS-vltgy,f-m gr, predfgr, wsrtd,sbrnd,wcmt, qtz,brn arg gr, wh cmt SS-Itgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,wcmt, qtz,dk lith gr, occ bit SS-Itgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,wcmt,qtz,dk lith gr, occ bit SS-Itgy,vf-m gr, predfgr, lam,wsrtd, sbrnd,vwcmt,qtz,dk lith gr, occ calc SS-Itgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,wcmt,qtz,dk lith gr, occ bit SS-ltgy,vf-m gr, predfgr,wsrtd,rnd,vwcmt,qtz, bm lith gr, f C lam ,wh cmt SS-ltgy,f-mgr, predfgr, r lam,wsrtd,sbrnd,wcmt,qtz,dk lith gr, occ bit,frac SS-Itgy,vf-m gr, predfgr, wsrtd,rnd,vwcmt,qtz, brn lith gr, wh cmt SS-Itgy,vf-m gr, predfgr, wsrtd,rnd,vwcmt,qtz,brn lith gr,f C lam ,wh cmt,frac SS-Itgy,vf-m gr, predfgr, wsrtd;rnd,vwcmt,qtz,brn lith gr,wh cmt SS-Itgy,vr-m gr, predtgr, f-m Sltst pbl,wsrtd,md,vwcmt, qtz,bm Iilh gr, wh cmt SS-Itgy,vf-mgr, predfgr, r lam,wsrtd,rnd,vwcmt, qtz,brn lith gr, occ bit SS-Itgy,vf-m gr, predfgr, occ lam,wsrtd, rnd,vwcmt,qtz,brn lith gr, occ bit, broken SS-Itgy,vf-m~dfgr,f lam ,wsrtd,sbrnd,vwcm t, qtz,dk lith gr, bil CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA DEAN STARK ANALYSIS FILE: 1573 DATE: 28-APR- 95 ANALYSTS:PB,D S,DA PLUG SAMPLES PERMEABIUTY POROSITY SATURATIONS GRAIN CORE SPI DEPTH HORZONTALI VERTICAL (HEUUIV0 OIL I WATER DENSITY # # FT Kair/Md I Kair/Md (%) % Pv % Pv GM/CC DESCRIPTION 6 65 11197.5 34.6 0.75 18.2 34.8 31.5 2.66 SS-Itgy,vf-mgr, predfgr,wsrtd,sbrnd,vwcmt,qtz,dk lith gr,tr bit 6 66 11197.6 21.6 17.0 35.5 35.3 2.68 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,dk lith gr,occ calc 6 67 11198.8 66.1 27.4 19.9 45.8 25.5 2.63 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcrnt,qtz,dk lith gr, occ bit 6 68 11199.3 48.1 21.6 19.1 40.4 28.6 2.66 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,dk lith gr, tr bit 6 69 11200.1 55.8 18.8 37.6 27.6 2.60 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,dk lith gr, occ bit 6 70 11201.2 46.0 13.8 19.9 42.4 25.7 2.60 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,dk lith gr, occ bit 6 71 11201.6 244 e 22.5 41.2 26.8 2.65 $S-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,dk lith gr 6 72 11202.1 280 199 22.8 42.2 28.9 2.65 SS-Itgy,vf-mgr, predfgr,wsrtd,sbrnd,vwcmt, qtz,dk lith gr 7 I 11203.1 298 204 22.6 39.7 26.8 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr,tr bit 7 2 A 11204.0 173 94.6 20.7 42.0 22.6 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, tr bit 7 2 B 11204.4 208 159 21.6 40.9 24.3 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, tr pyr 7 3 A 11205.0 FRAC 23.7 41.5 19.1 2.61 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, C lam,frac 7 3 B 11205.3 98.1 91.1 20.4 43.3 25.6 2.64 SS-vltgy,vf-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,occ C,wh cmt 7 3 C 11205.9 128 122 20.5 39.1 25.7 2.65 SS-Itgy,f-cgr, predfgr,wsrtd,sbrnd,wcmt,qtz,dk lith gr,tr bit 7 4 11206.5 70.4 19.4 13.8 24.0 2.60 SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt,qtz,dk lith gr,occ C 7 5 A 11207.4 127 33.1 20.9 39.3 25.6 2.65 SS-Itgy,vf-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,wh cmt 7 5 B 11207.9 46.9 18.7 41.7 24.2 2.60 SS-Itgy,vf-mgr, predfgr,wsrtd,sbrnd,wcmt,qtz,wh cmt,occ bit lam 7 6 A 11208.6 76.7 19.0 37.7 26.7 2.63 SS-Itgy,vf-mgr, predfgr,wsrtd,rnd,wcmt, qtz,wh cmt,occ bit lam 7 6 B 11208.8 180 35.2 21.3 39.7 25.8 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt 7 7 A 11209.2 50.4 18.3 39.8 28.5 2.64 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt, qtz,dk Iith gr,occ bit lam 7 7 B 11209.6 21.9 8.21 16.9 41.1 26.5 2.54 SS-ltgy,f-mgr, predfgr,wsrtd,f C lam.sbrnd,wcmt,qtz,C,wh cmt 7 7 C 11209.9 232 22.1 39.4 27.6 2.66 SS-Itgy,f-cgr, predmgr,wsrtd,sbrnd,wcmt,qtz,dkgy lith gr,wh cmt 7 8 A 11210.9 184 16.5 21.1 40.3 24.7 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr, wh cmt 7 8 B 11210.4 237 21.9 38.7 27.4 2.65 SS-Itgy,f-mgr, predmgr,wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh crnt 7 9 11211.6 271 12.2 21.8 36.6 27.0 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmtlqtz, dk lith gr, wh cmt 7 10 A 11212.2 58.1 19.3 37.3 27.4 2.65 SS-Itgy,f-cgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dklith gr, wh cmt,occ bit 7 10 B 11212.9 112 20.4 38.3 28.6 2.66 SS-Itgy,f-mgr, predmgr,wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh crnt,tr bit 7 11 11213.3 26.1 17.1 38.9 30.7 2.66 SS-Itcjy,f-c~r, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith ~r, wh cmt,tr bit & BP EXPLORATION (ALASKA). INC. BADAMI #5 EXPLORAITON NORTH SLOPE. ALASKA CORE LABORATORIES FI LE: 1573 DATE: 28-APR-95 ANALYSTS: PB ,D S,D A DEAN STARK ANALYSIS PLUG SAMPLES PERMEABIUTY POROSITY SATURATIONS GRAIN CORE SPI DEPTH HORIZONTALI VERTICAL (HEUUM) OIL J WATER DENSITY # # FT Kair/Md I Kair/Md (%) % Pv[ % Pv GM/CC DESCRIPTION 7 12 A 11214.0 73.0 13.7 20.0 37.8 27.0 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt 7 12 B 11214.6 BROKEN 77.0 18.3 39.3 27.7 2.45 SS-ltgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt, C bnd,broken 7 13 A 11215.1 43.8 28.8 18.7 39.1 27.2 2.61 SS-Itgy,f-mgr, predfgr,wsrtd,rnd,wcmt, qtz,dk lith gr, wh cmt,occ bit 7 13 B 11215.8 13.9 16.7 43.1 21.9 2.56 SS-Itgy,f-mgr, predfgr,wsrtd,f C lam.sbrnd,wcmt,qtz,C,wh cmt 7 14 11216.5 41.7 23.4 19.2 38.7 27.6 2.66 SS-vltgy,vf-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,tr C,wh crnt 7 15 A 11217.2 28.3 17.9 40.4 29.2 2.67 SS-vltgy,vf-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,trC,wh cmt 7 15 B 11217.5 95.4 84.7 20.4 37.6 28.6 2.66 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt 7 16 A 11218.1 63.3 34.1 18.9 42.5 24.9 2.52 SS-Itgy,f-mgr, predmgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt,C lam 7 16 B 11218.8 49.7 18.5 41.0 26.3 2.59 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt, C lam 7 17 A 11219.4 110 0.80 19.2 41.5 27.6 2.64 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt, qtz,dk Iith gr, wh cmt, tr C 7 17 B 11219.7 -- FRAC 20.0 43.4 23.2 -2.51 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz;dk lith gr, wh cmt,C lam,frac 7 18 A 11220.4 89.3 4.12 18.5 39.5 29.0 2.66 SS-Itgy,f-mgr, predfgr, sltst bnd,wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh cmt,C lam 7 18 B 11220.6 166 20.4 41.1 22.9 2.57 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh crnt,C lam,tr pyr,frac 7 18 C 11220.8 94 21.1 45.6 22.1 2.62 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr,wh cmt,C lam,tr pyr 7 19 A 11221.5 195 41.9 22.7 42.5 25.0 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcrnt, qtz, dk lith gr, wh cmt 7 19 B 11221.9 226 22.3 37.8 27.2 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz, dk lith gr, wh crnt,tr C 7 20 A 11222.3 132 29.1 21.8 39.8 26.3 2.64 SS-Itgy,f-cgr, predfgr, wsrtd,sbmd,wcmt,qtz,dk lith gr,wh crnt,tr bit & pyr 7 20 B 11222.7 198 21.9 37.0 29.1 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt, qtz,dk lith gr, wh crnt 7 21 A 11223.3 151 21.2 39.7 27.3 2.65 SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,wcrnt, qtz,dk lith gr, wh cmt 7 21 B 11223.8 328 1.92 22.4 42.1 29.8 2.56 SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt, qtz,dk lith gr,wh cmt, occ Clam 7 22 A 11224.2 204 14.1 21.5 38.8 27.1 2.64 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcrnt,qtz,dk lith gr,wh cmt, occ Clam 7 22 B 11224.5 0.02 ~_ 4.4 48.5 37.8 2.75 SS-mltgy,vf-mgr, predfgr, wsrtd,sbrnd,vwcmt, qtz,dk lith gr, calc cmt 7 23 A 11225.2 76.6 19.8 39.4 26.2 2.62 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr, wh crnt, r C lam 7 23 B 11225.7 38.1 18.5 38.8 29.3 2.64 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,dk lith gr,wh cmt, r brn sh lam 7 24 A 11226.2 76.2 20.1 41.3 25.1 2.65 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcmt, qtz, dk lith gr, wh cmt, trC 7 24 B 11226.7 30.8 17.9 42.3 26.6 2.64 SS-Itgy,f-mgr, predfgr,wsrld,sbrnd,wcrnt,qtz,dk lith gr, wh crnt, tr C 7 25 A 11227.4 60.6 18.3 40.6 25.5 2.65 SS-Itgy,f-cgr, predfgr, wsrtd,rnd,wcrnt,qtz,dk lith gr, wh cmt 7 25 B 11227.8 193 72.5 21.2 39.8 29.4 2.65 SS-Itgy,f-cgr, predfgr, wsrtd,rnd,wcrnt,qtz,dk lith gr, wh cmt CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA CONr .,DENTIAL DEAN STARK ANALYSIS PLUG FI LE' 1573 DATE: 20-APR- 95 ANALYSTS:PB,D S,DA , LU ~ ,.~/~n~ r LEO PERMEABIUTY POROSITY SATURATIONS GRAIN ,. CORE SPI DEPTH HORIZONTALI VERTICAL (HEUUM) OIL I WATER DENSITY # # FT Kair/Md I Kair/Md (%) % Pv % Pv GM/CC DESCRIPTION 7 26 11228.3 202 22.4 41.5 26.7 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,sbrnd,wcrnt,qtz,dk lith gr, wh cmt 7 27 A 11229.2 230 21.4 40.1 29.1 2.66 SS-Itgy,f-cgr, predfgr, wsrtd,rnd,wcmt, qtz,dk lith gr, wh cmt 7 27 B 11229.7 243 185 21.6 39.7 28.5 2.65 SS-Itgy,f-mgr, predrngr, wsrtd,rnd,wcrnt,qtz, dk lith gr, wh cmt 7 28 11230.6 229 21.3 39.3 27.4 2.63 SS-Itgy,f-mgr, predmgr, wsrtd,rnd,wcrnt, qtz, dk lith gr, wh cmt,tr C 7 29 11231.3 284 178 21.7 42.6 27.9 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,rnd,wcmt,qtz, dk lith gr, wh crnt,tr C 7 30 11232.7 220 21.2 37.5 28.8 2.65 SS-Itgy,f-mgr, predmgr, wsrtd,rnd,wcrnt,qtz,dk lith gr, wh cmt 7 31 11233.5 293 174 22.2 41.2 27.6 2.63 SS-Itgy,f-mgr, predrngr, wsrtd,rnd,wcrnt, qtz,dk lith gr, wh cmt,tr C 7 33 11235.3 2.88 2.70 14.0 54.4 18.4 2.61 SS-Itgy,vf-mgr, predfgr, wsrtd,rnd,vwcmt, qtz,dk lith gr,wh cmt,occ C 7 34 A 11236.0 29.7 17.9 51.5 33.6 2.59 SS-Itgy,f-mgr, predmgr, wsrtd,rnd,wcmt, qtz, dk lith gr, wh cmt,occ C 7 34 B 11236.8 316 22.8 41.3 27.1 2.66 SS-Itgy,f-mgr, predrngr, wsrtd,rnd,wcmt, qtz, dk lith gr, wh crnt 7 35 A 11237.1 487 27.9 23.0 37.0 32.8 2.66 SS-Itgy,f-cgr, predrngr, wsrtd,rnd,vwcrnt,qtz,wh cmt,trcalc 7 35 B 11237.5 31.8 17.7 42.8 26.6 2.65 SS-Itgy vf-mgr, predfgr, wsrtd,rnd,wcmt,qtz,dk lith gr, wh cmt,tr C,tr fuchsite 7 36 A 11238.2 26.0 18.9 44.4 26.2 2.65 SS-Itgy,f-mgr, predfgr,wsrtd,sbrnd,wcmt, qtz,dk lith gr, wh cmt, occ C 7 36 B 11238.9 68.1 0.55 19.9 40.9 26.2 2.66 SS-Itgy,vf-mgr, predfgr, rlam,wsrtd,rnd,wcmt,qtz,dk lith gr,tr C 7 37 11239.8 176 20.9 38.5 27.7 2.64 SS-Itgy,vf-mgr, predfgr, r lam ,wsrtd,rnd,wcrn t, qtz,dk lith gr, wh cmt,tr C 7 38 A 11240.1 52.9 4.50 18.9 41.2 27.6 2.63 SS-Itgy,f-cgr, predfgr, occ lam,wsrtd,rnd,wcmt,qtz,dk lith gr, wh cmt,occ C 7 38 B 11240.6 111 19.9 33.0 32.8 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,rnd,wcmt,qtz,dk lith gr, wh cmt 7 39 11241.3 5.43 0.18 13.9 42.4 27.0 2.63 SS-Itgy,vf-mgr, bd,wsrtd,rnd,wcrnt,qtz,dk lith gr, tr C & calc 7 40 A 11242.0 6.71 12.6 44.4 33.4 2.67 SS-Itgy,vf-mgr, bnd,wsrtd,rnd,wcmt,qtz,dk lith gr, tr C & calc 7 40 B 11242.6 BROKEN 16.8 59.0 15.8 2.53 SS-Itgy,vf-mgr, lam,wsrtd,rnd,wcmt,qtz,dk lith gr, occ C,tr calc,broken 7 41 11243.2 12.5 1.13 15.6 43.1 26.9 2.67 SS-Itgy,vf-mgr, bnd,wsrtd,rnd,wcmt,qtz,dk lith gr, tr C & calc 7 42 11244.3 85.0 0.53 19.6 40.0 29.3 2.67 SS-Itgy,vf-mgr, predfgr, wsrtd,rnd,wcmt,qtz,dk lith gr, wh cmt,tr calc 7 43 A 11245.2 126 15.5 21.3 41.9 24.9 2.67 SS-Itgy,vf-mgr, predfgr,wsrtd,rnd,wcmt, qtz,dk lith gr, wh cmt,tr calc 7 43 B 11245.9 114 20.7 42.7 27.2 2.65 SS-Itgy',vf-mgr, predfgr, wsrtd,sbrnd,wcmt,qtz,wh cmt,r C lam 7 44 A 11246.4 196 21.2 39.1 26.0 2.66 SS-Itgy,vf-mgr, predlgr, wsrtd, rnd,wcmt, qtz, dk Iith gr, wh cmt, tr calc 7 44 B 11246.9 BROKEN 18.6 14.5 31.6 42.2 2.66 SS-Itgy,f-mgr, bnd w/gy Sltst,wsrtd,rnd,wcmt,qtz,dk lith gr, dol,tr C, broken 7 47 11249.4 0.11 8.1 8.8 89.6 2.71 Sltst- mgy,slt-vfsd, pred slt,wsrtd,rnd,vwcrnt, brn cly,qtz 7 49 11251.2 1.33 8.2 4.5 94.5 2.76 SS-mdkgy,vf-cgr, cly mtrx,mod srtd,vwcmt,cly,qtz, dol,tr, pyr mm m.m., CORE LABORATORIES BP EXPLORATION (ALASKA), INC. BADAMI #5 EXPLORAITON NORTH SLOPE, ALASKA CO D iA[ -'FILE: 1573 DATE: 28-APR-95 ANALYSTS: PB ,D S,DA DEAN STARK ANALYSIS PLUG SAMPLES PERMEABIUTY POROSITY SATURATIONS GRAIN CORE SPL DEPTH HOFIZONTALI VERTICAL (HEUUM) O~L WATER DENSITY # # FT Kair/Md I Kair/Md (%) % Pv % Pv GM/CC DESCRIPTION 7 51 11253.4 456 21.4 34.6 30.0 2.65 SS-Itgy,vf-cgr, predfgr, wsrtd,sbrnd,vwcmt,qtz,wh cmt,tr dol,dk lith gr 7 52 11254.2 669 523 24.2 38.5 30.5 2.66 SS-Itgy,f-mgr, predfgr, wsrtd,rnd,wcmt,qtz,dk lith gr, wh cmt,tr C 7 53 11255.1 BROKEN 26.3 24.7 43.2 18.8 2.49 SS-mgy,f-mgr, predfgr, lam,wsrtd,sbrnd,mod cmt,qtz,dk lith gr, C,broken 7 54 A 11256.2 38.6 21.7 36.0 17.0 2.55 SS-mgy,f-mgr, predfgr, lam,wsrtd,sbrnd,mod cmt,qtz,dk lith gr, C 7 54 B 11256.7 48.0 3.78 18.9 62.6 22.9 2.60 SS-mgy,f-mgr, predfgr, lam,wsrtd,sbrnd,mod cmt,qtz,dk lith gr, C 7 55 11257.8 10.6 7.5 8.2 84.5 2.70 SS-mgy,slt-vfsd,predvfsd,wsrtd,rnd,vwcmt,qtz,dk lith gr,occ calc 7 58 11260.5 0.20 8.4 5.1 95.6 2.69 SS-mgy,slt-msd,mod srtd,rnd,vwcmt,dol BP EXPLORATION (Ataska) Inc. Badami #5 Badami~ Stot #Badami ~5 Exploration North S[ope, Ataska SURVEY LISTING by . Baker Hughes INTEQ Your ref : PHSS <0.00 - 11549> Our ref : svy4576 License : Date printed : 30-Mar-95 Date created : 17-Mar-95 Last revised : 1?-Mar-95 Field is centred on n70 28 24.450,w148 49 2.487 Structure is centred on 359186.220,5909872.640,999.00000,N Stot location is nTO 9 41.076,w147 7 58.241 Slot Grid coordinates are N 5909872.640, E 359186.220 Stot local coordinates are 0.00 N 0.00 E Reference North is True North ORIGINAL RECEIVED k iAY tO Oil & Gas Cons. Commission Anchor~- ' BP EXPLORATION (ALaska) Inc. Badami #50Badami#5 ExpLoration,North SLope, ALaska SURVEY LISTING Page 1 Your ref : PMSS <0.00 - 11549> Last revised : 17-Mar-95 Measured ]nc[in. Azimuth True Vert. R E C T A N G U L A R DogLeg Vert Depth Degrees Degrees Depth C 0 0 R D ] N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 229.00 0.10 179.30 229.00 0.20 S 0.00 E 0.04 -0.17 316.00 0.30 130.00 316.00 0.42 S 0.18 E 0.28 -0.28 412.00 0.20 137.00 412.00 0.71 S 0.48 E 0.11 -0.38 504.00 0.30 94.20 504.00 0.84 S 0.83 E 0.22 -0.33 596.00 0.40 99.50 596.00 0.91 S 1.39 E 0.11 -0.12 688.00 0.50 53.20 687.99 0.72 S 2.03 E 0.40 0.35 780.00 0.30 39.80 ~79.99 0.30 S 2.50 E 0.24 0.96 871.00 0.40 58.10 870.99 0.05 N 2.93 E 0.16 1.47 964.00 0.30 69.70 963.99 0.31 N 3.43 E 0.13 1.94 1055.00 0.40 80.40 1054.98 0.44 N 3.97 E 0.13 2.32 1148.00 0.40 126.70 1147.98 0.30 N 4.55 E 0.34 2.48 1241.00 0.20 124.60 1240.98 0.02 N 4.94 E 0.22 2.42 1334.00 0.40 149.90 1333.98 0.36 S 5.24 E 0.25 2.24 1424.00 0.50 127.50 1423.98 0.87 S 5.71 E 0.22 2.02 1517.00 0.30 146.00 1516.98 1.32 S 6.16 E 0.25 1.85 1610.00 0.50' 146.60 1609.97 1.86 S 6.52 E 0.22 1.55 1702.00 0:50 160.60 1701.97 2.57 S 6.88 E 0.13 1.10 1793.00 0.60 156.40 1792.97 3.38 S 7.20 E 0.12 0.55 1886.00 0.60 193.00 1885.96 4.30 S 7.29 E 0.40 -0.21 1977.00 0.30 317.40 1976.96 4.59 S 7.02 E 0.89 -0.60 2070.00 0.30 239.00 2069.96 4.54 $ 6.64 E 0.41 -0.73 2161.00 0.40 118.10 2160.96 4.81 S 6.72 E 0.67 -0.93 2254.00 0.40 77.00 2253.96 4.89 $ 7.32 E 0.30 -0.71 2346.00 0.50 90.30 2345.95 4.82 S 8.04 E 0.16 -0.30 2438.00 0.60 70.60 2437.95 4.66 S 8.89 E 0.23 0.26 2532.00 0.80 98.80 2531.94 4.60 S 10.01 E 0.42 0.85 2624.00 0.60 125.10 2623.94 4.97 $ 11.04 E 0.40 1.02 2716.00 0.80 124.10 2715.93 5.61 $ 11.96 E 0.22 0.92 2809.00 0.90 126.20 2808.92 6.40 $ 13.09 E 0.11 0.77 2899.00 0.50 148.30 2898.91 7.16 S 13.86 E 0.53 0.49 2991.00 0.60 134.30 2990.91 7.83 S 14.42 E 0.18 0.17 3083.00 0.40 154.30 3082.90 8.46 S 14.90 E 0.28 -0.14 3175.00 0.40 157.30 3174.90 9.05 S 15.17 E 0.02 -0.52 3268.00 1.00 103.30 3267.90 9.53 S 16.08 E 0.89 -0.50 3360.00 0.70 108.30 3359.88 9.89 S 17.40 E 0.34 -0.18 3452.00 0.50 101.60 3451.88 10.15 S 18.32 E 0.23 0.05 3544.00 0.40 123.70 3543.88 10.41 S 18.98 E 0.22 0.14 3638.00 0.30 133.60 3637.88 ~ 10.76 S 19.44 E 0.12 0.05 3730.00 0.20 168.00 3729.87 11.08 S 19.64 E 0.19 -0.13 3821.00 0.20 196.50 3820.87 11.39 S 19.63 E 0.11 -0.40 3914.00 0.40 190.90 3913.87 11.87 S 19.52 E 0.22 -0.87 f~"l~Y 1 0 4008.00 0.40 196.90 4007.87 12.50 S 19.37 E 0.04 -1.50 4100.00 o.4o 178.20 40m.87 13.13 s 19.28 E 0.14 -2.O9 ~!~skaOil&GasCo~s. 4194.00 0.40 187.00 4193.86 13.78 S 19.25 E 0.06 -2.68 Anchor; 4285.00 0.50 154.00 4284.86 14.46 S 19.39 E 0.30 -3.20 4377.00 0.60 159.60 4376.56 15.27 s 19.73 E 0.12 -3.74 4457.00 0.60 178.60 4456.85 16.08 $ 19.89 E 0.25 -4.37 4567.00 0.60 177.90 4566.85 17.23 S 19.92 E 0.01 -5.36 4661.00 0.90 168.00 4660.~4 18.44 s 20.10 E 0.35 -6.34 Att data is in feet un[ess otherwise stated . Coordinates from S[ot #Badami ~ and TVD from RKB (Nabors 18E) (35.65 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 29.11 degrees. Declination is 0.00 degrees, Convergence is -1.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (ALaska) ]nc. Badami #5,Badami#5 Exploration,North SLope, ALaska SURVEY LISTING Page 2 Your ref : PMSS <0.00 - 11549> Last revised : 17-Mar-95 Measured ]ncLin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Oeg/lOOFt Sect 4754.00 0.80 152.69 4753.83 19.74 S 20.55 'E 0.26 -7.25 4846.00 1.30 169.80 4845.81 21.33 S 21.03 E 0.64 -8.41 4940.00 1.30 173.00 4939.79 23.44 S 21.34 E 0.08 -10.10 5034.00 1.30 173.00 5033.77 25.56 S 21.60 E 0.00 -11.82 5094.00 1.50 179.30 5093.75 27.02 S 21.70 E 0.42 -13.05 5186.00 1.80 68.50 5185.73 2?.69 S 2~.06 E 2.96 -12.98 5279.00 4.90 46.00 5278.56 24.40 S 27.27 E 3.56 -8.05 5371.00 8.20 41.10 5369.95 16.72 S 34.42 E 3.63 2.13 5462.00 10.50 39.40 5459.73 5.42 S 43.94 E 2.54 16.64 5554.00 13.30 36.20 5549.75 9.60 N 55.52 E 3.12 35.39 5646.00 16.30 33.40 5638.69 28.92 N 68.88 E 3.35 58.77 5738.00 19.20 28.10 5726.30 53.05 N 83.12 E 3.60 86.78 5832.00 22.40 25.60 5814.17 82.84 N 98.14 E 3.53 120.12 5927.00 25.80 25.60 5900.87 117.82 N 114.90 E 3.58 158.84 6022.00 28.80 24.90 5985.28 157.23 N 133.47 E 3.18 202.30 6117.00 32.00 2?.40 6067.21 200.35 N 154.69 E 3.62 250.30 6213.00 33.20 2?.40 6148.09 246.2? N 178.50 E 1.25 302.00 6310.00 33.80 28.80 6228.98 293.49 N 203.72 E 1.01 355.52 6402.00 34.50 28.50 6305.11 338.81N 228.48 E 0.?8 407.16 6496.00 35.50 27.80 6382.11 386.35 N 253.91E 1.15 461.07 6591.00 36.10 27.10 6459.16 435.66 N 279.52 E 0.76 516.62 6686.00 35.00 26.40 6536.46 484.98 N 304.39 E 1.23 571.80 6781.00 35.80 27.80 6613.89 533.97 N 329.46 E 1.20 626.80 6870.00 35.80 26.70 6686.08 580.25 N 353.30 E 0.72 678.83 6970.00 33.40 24.90 6768.39 631.35 N 378.03E 2.61 735.51 7063.00 34.60 24.60 6845.49 678.58 N 399.80 E 1.30 787.36 7156.00 35.30 24.90 6921.71 726.96 N 422.11E 0.78 840.49 7251.00 34.80 24.60 6999.49 776.51N 444.95 E 0.56 894.89 7541.00 33.00 22.50 7074.19 822.51N 465.02 E 2.38 944.84 7439.00 33.80 22.50 7156.00 872.35 N 485.67 E 0.82 998.43 7535.00 33.30 22.80 7236.01 921.31 N 506.10 E 0.55 1051.15 7628.00 32.50 25.60 7314.10 967.38 N 526.79 E 1.85 1101.46 7723.00 32.60 27.10 7394.18 1013.18 N 549.47 E 0.86 1152.51 7816.00 33.20 27.80 ?472.26 1058.01 N 572.?6 E 0.76 1203.01 7911.00 34.10 27.80 7551.34 1104.57 N 597.31 E 0.95 1255.63 8004.00 34.80 27.40 7628.03 1151.19 N 621.68 E 0.79 1308.22 8098.00 33.80 28.80 7705.68 1197.92 N 646.62 E 1.35 1361.18 8192.00 34.70 28.50 7783.38 1244.35 N 671.99 E 0.97 1414.08 8287.00 35.40 29.20 7861.15 1292.13 N 698.32 E 0.85 1468.64 8381.00 33.40 29.90 7938.71 1338.33 N 724.50 E 2.17 1521.74 8476.00 32.00 30.90 8018.65 1382.60 8570.00 30.80 30.60 8098.88 1424.69 8664.00 30.80 30.60 8179.63 1466.12 8758.00 31.30 30.90 8260.16 1507.78 8853.00 31.20 29.90 8341.38 1550.29 8946.00 31.10 29.90 8420.9? 1591.99 N 873.71 E 0.11 1815.96 9040.00 30.70 30.20 8501.62 1633.78 N 897.88 E 0.46 1864.22 9133.00 30.80 29.50 8581.55 1675.02 N 921.55 E 0.40 1911.77 9228.00 30.80 30.90 8663.15 1717.06 N 946.02 E 0.75 1960.40 9322.00 30.80 32.70 8743.90 1757.96 N 971.38 E 0.98 2008.47 RECE, IVED 750.46 E 1.58 1573.05 775.50 E 1.29 1622.00 800.00 E 0.00 1670.12 ~,~Y ~ 0 ~9~5 824.79 E 0.56 1718.58 ~49.73 E 0.56 1767.85 AIsska Oil & Gas Cons. Commission AnChors ALL data is in feet unless otherwise stated Coordinates from SLot #Badami #5 and TVD from RKB (Nabors 18E) (35.65 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 29.11 degrees. Declination is 0.00 degrees, Convergence is -1.06 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes [NTEQ BP EXPLORATION (Alaska) ]nc. Badami #5,Badami#5 Exploration,North Slope, Alaska Measured Inc[in. Azimuth True Vert. Depth Degrees Degrees Depth 9417.00 31.10 34.10 8825.37 9511.00 31.20 36.90 8905.82 9596.00 30.80 38.70 8978.68 9693.00 30.80 40.40 9062.00 9789.00 32.10 38.00 9143.90 9884.00 33.20 39.40 9223.89 9978.00 33.90 38.00 9302.23 10072.00 34.90 38.30 9379.79 10167.00 36.10 38.00 9457.13 10261.00 37.20 36.90 9532.54 10355.00 38.10 36.90 9606.97 10451.00 39.00 38.00 9682.05 10543.00 39.20 36.50 9753.45 10638.00 39.00 37.30 9827.17 107'54.00 39.00 35.50 9901.78 10830.00 38.80 35.50 9976.49 10924.00 38.80 35.10 10049.75 11015.00 38.70 32.80 10120.72 11110.00 36.30 33.70 10196.08 11202.00 36.20 32.30 10270.28 SURVEY LISTING Page 3 Your ref : PMSS <0.00 - 11549> Last revised : 17-Mar-95 R E C T A N G U L A R Dogleg Vert C 0 0 R D ! # A T E S Deg/lOOFt Sect 1798.75 N 998.28 1838.32 N 1026.51 1872.91 N 5053.33 1911.21 N 1084.96 1950.03 N 1116.59 1990.02 N 1148.64 2030.56 N 1181.12 2072.32 N 1213.92 2115.71 N 1248.00 2160.25 N 1282.11 'E 0.82 2057.19 E 1.54 2105.50 E 1.19 2148.77 E 0.90 2197.61 E 1.88 2246.92 2206.17 N 1316.58 2253.6~ N 1352.97 2299.84 N 1388.08 2347.76 N 1424.06 2396.38 N 1459.90 E 1.40 2297.45 E 1.11 2348.68 E 1.08 2401.12 E 1.28 2455.60 E 1.36 2511.12 2445.46 N 1494.91 2493.53 N 1528.95 2540.77 N 1560.75 2589.14 N 1592.45 2634.76 N 1622.08 E 0.96 2568.00 E 1.18 2627.20 E 1.05 2684.63 E 0.57 2743.99 E 1.18 2803.91 11295.00 35.70 33.00 10345.56 2680.73 N 1651.53 11388.00 35.20 34.10 10421.33 2725.68 N 1681.34 11483.00 34.00 32.30 10499.52 2770.81 N 1710.88 11514.00 33.70 33.00 10525.27 2785.35 N 1720.20 11549.00 33.70 33.00 10554.39 2801.63 N 1730.78 E 0.21 2863.82 E 0.27 2922.38 E 1.58 2979.13 E 2.59 3036.80 E 0.91 3091.08 E 0.70 E 0.87 E 1.66 E 1.59 E 0.00 3145.57 3199.34 3253.14 3270.38 3289.75 Projected Data - No Survey RECEIVED f' ,qY i 0 t,9 5 A!~ska Oil & Gas Cons. C~mmi~s]on Anchor~ ~ Att data is in feet unless otherwise stated Coordinates from Slot #Badami ~5 and TVD from RKB (Nabors 18E) (35.65 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 29.11 degrees. Declination is 0.00 degrees, Convergence is -1.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ BP EXPLORAT%ON (ALaska) Inc. Badami ~,Bedami#5 Exploration. North SLope, ALaska SURVEY LISTING Page 4 Your ref : PMSS <0.00 - 11549> Last revised : 17-Mar-95 Co~nts in weLlpath MO TVO Rectangular Coords. Comnent 11549.00 10554.39 2801.63 N 1730.78 E Projected Data - No Survey RECEIVED A~ska Oil & Gas Cons. Co~mission Anchor; · AL[ data is in feet unless otherwise stated Coordinates from Slot #Badami #5 and TVD from RKB (Nabors 18E) (35.65 Ft above Mean Sea Level). Bottom hole distance is 3293.14 on azimuth 31.71 degrees from wet[head. Vertical section is from wellhead on azimuth 29.11 degrees. Declination is 0.00 degrees, Convergence is -1.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ANALYST: SINES 20-MAR-95 12: 18: 23 PROGRAM: GSHOT 007.E09 * SCHLUMBERGER * VELOCITY SURVEY SUMMARY COMPANY : BP EXPLORATION WELL : BADAMI #5 FIELD : WILDCAT COUNTY : NORTH SLOPE STATE : ALASKA COUNTRY : USA REFERENCE: 95098 LOGGED : 11-MAR-1995 Date.~./Q ( _ RE¢£1V£D ~A¥ 4 1995 Alaska Oil & Gas Cons. Commission ~choraDe ****************************** SURFACE GEOMETRY TABLE ******************************* ******************************************************************************************* ******************************************************************************************** ELEVATION OF KELLY BUSHING (KB) ABOVE MEAN SEA LEVEL ELEVATION OF SEISMIC REFERENCE DATUM (SRD) ABOVE MSL ELEVATION OF GROUND LEVEL ABOVE SRD VELOCITY OF MEDIUM FROM SOURCE TO SURFACE SENSOR VELOCITY OF MEDIUM FROM SOURCE TO SRD 38.00 FT 0.00 FT 4.10 FT 10000.00 FT/SEC 10000.00 FT/SEC ******************************************************************************************** ******************************************************************************************* ******************************* SOURCE POSITION TABLE ******************************** ******************************************************************************************* ******************************************************************************************** SOURCE ELEVATION ABOVE SRD 0.0 FT 0.0 FT SOURCE DISTANCE FROM WELLHEAD 1000.0 FT 400.0 FT SOURCE AZIMUTH FROM NORTH 29.0 DEC 29.0 DEC DEPTH RANGE FROM TO 11320.2 4900.0 FT 4800.0 0.0 FT SURFACE SENSOR TABLE ********************************* SURFACE SENSOE SURFACE SENSOR ELEVATION ABO~E DISTANCE FROM SRD WELLHEAD 0.0 FT 1000.0 FT 0.0 FT 400.0 FT SURFACE SENSOR AZIMUTH FROM NORTH 29.0 DEG 29.0 DEG DEPTH RANGE' FROM TO 11320.2 4900.0 FT 4800.0 0.0 FT ******************************* SOURCE ELEVATION TABLE ******************************* ******************************************************************************************** TIME FROM SURFACE SENSOR TO SOURCE 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0o00 ~nS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 InS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS 0.00 mS O. O0 mS 0.00 mS O. O0 mS 0.00 mS 0.00 mS 0~00 mS 0.00 mS TIME FROM SOURCE TO SRD O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 ~nS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0~00 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 !11S O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 ~nS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS INAL 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 ,nS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 inS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 inS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 inS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS 0.00 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O o O0 mS O o O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 inS 0.00 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0;00 mS O. O0 mS O. O0 mS O. O0 inS O. O0 mS O. O0 InS O. O0 mS 0.00 mS , O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS O. O0 mS 0.00 mS O. O0 ,nS O. O0 mS ORIGINAL *************************** DEVIATED WELL RECEIVER GEOMETRY TABLE ****************************** MEASURED DEPTH FROM KB 851,3 FT 950,5 FT 1801,6 FT 1900,8 FT 2000.0 FT 2801,5 FT 2900,7 FT 2999,9 FT 3801,8 FT 3901,0 FT 4000.2 FT 4900,7 FT 4950,3 FT 4999,9 FT 5801.7 FT 5851,3 FT 5900,9 FT 5950,5 FT 6000.1 FT 6382,7 FT 6432,3 FT 6481,9 FT 6531,5 FT 6581,1 FT 6630,8 FT 6680,4 FT 6730.0 FT 6779,7 FT 6829,3 FT 6878,6 FT 6928,2 FT 6977,8 FT 7027,5 FT 7077,1 FT 7126,6 FT 7176,2 FT 7225,8 FT 7275,4 FT 7325,0 FT 7374,8 FT 7424.4 FT 7474,0 FT 7523,6 FT 7573,2 FT 7622,7 FT 7672,3 FT 7721,9 FT 7771.5 FT 7821,1 FT 7897,6 FT 7947,2 FT 7996.8 FT 8046.4 FT 8096,0 FT 8145.7 FT 8195,3 FT 8245,0 FT 8294,6 FT 8344,2 FT 8393,7 FT 8443,3 FT 8492,9 FT 8542,5 FT 8592,1 FT 8641,6 FT 8691,2 FT 8740,9 FT 8790,5 FT VERTICAL DEPTH FROM KB 851,3 FT 950,5 FT 1801,6 FT 1900.8 FT 2000.0 FT 2801,4 FT 2900,6 FT 2999.8 FT 3801,7 FT 3900,9 FT 4000.1 FT 4900.5 FT 4950,1 FT 4999,7 Fl' 5783,5 FT 5829,6 FT 5875,7 FT 5920,4 FT 5963,4 FT 6288,3 FT 6329,3 FT 6370,3 FT 6410,9 FT 6451,2 FT 6491,7 FT 6532,0 FT 6572,4 FT 6612,8 FT 6653,6 FT 6694,1 FT 6734,8 FT 6775,5 FT 6816,3 FT 6857,1 FT 6898,0 FT 6939,0 FT 6979.9 FT 7020,9 FT 7061,9 FT 7103,0 FT 7143,9 FT 7185,3 Fl' 7226,7 FT 7268,2 FT 7309,6 FT 7351,2 FT 7392,7 FT 7434,3 FT 7475,9 FT 7540,1 FT 7581,2 FT 7622.1 FT 7663,0 FT 7703,9 FT 7744,8 FT 7785,7 FT 7827,0 FT 7868,1 FT 7909,3 FT 7950,4 FT 7991,5 FT 8033,1 FT 2075.6 FT 5118,0 FT 8160,4 FT $202,8 FT 8245,4 FT 8287,8 FT VERTICAL DEPTH FROM SRD 813.3 FT 912,5 FT 1763,6 FT 1862,8 FT 1962.0 FT 2763.4 FT 2862,6 FT 2961.8 FT 3763,7 FT 3862,9 FT 3962,1 FT 4862,5 FT 4912,1 FT 4961.7 FT 5745,5 FT 5791,6 FT 5837,7 FT 5882,4 FT 5925.4 FT 6250,3 FT 6291,3 FT 6332,3 FT 6372,9 FT 6413,2 FT 6453,7 FT 6494,0 FT 6534.4 FT 6574,8 FT 6615,6 FT 6656,1FT 6696,8 FT 6737,5 FT 6778,3 FT 6819,1 FT 6860,0 FT 6901,0 FT 6941,9 FT 6982,9 FT 7023,9 FT 7065,0 FT 7105,9 FT 7147,3 FT 7188,7 FT 7230,2 FT 7271.6 FT 7313,2 FT 7354,7 FT 7396,3 FT 7437,9 FT 7502,1 FT 7543.2 FT 7584.1 FT 7625,0 FT 7665,9 FT 7706.8 FT 7747.7 FT 7789,0 FT 7830.1 FT 7871,3 FT 7912.4 FT 7953.5 FT 7995,1FT 8037,6 FT 8080,0 FT 8122,4 FT 8164,8 FT 8207,4 FT 8249,8 FT EAST WEST COORDINATES 2,8 FT 3,4 FT 6.4 FT 6,5 FT 6.6 FT 12,8 FT 13,9 FT 14.6 FT 19.5 FT 19.6 FT 19.5 FT 21,0 FT 21,2 FT 21.4 FT 94.4 FT 102.5 FT 110,6 FT 120, 1 FT 131.2 FT 223,7 FT 236,9 FT 250, 1 FT 263,3 FT 276,5 FT 289,6 FT 302,8 FT 315,9 FT 329,1 FT 341,5 FT 353,8 FT 366,2 FT 378,5 FT 390.9 FT 403,0 FT 414.3 FT 425,7 Fl' 437,0 FT 448,3 FT 459,6 FT 471,0 FT 482.3 FT 493,3 FT 504,1 FT 514,9 FT 525.6 FT 537,8 FT 550, 1 FT 562,4 FT 574,7 FT 593,7 FT 606,7 FT 619,9 FT 633, 1 FT 646.4 FT 659,6 FT 672,9 FT 686,6 FT 700,3 FT 71zi,O FT 727.7 FT 741,4 FT 754,9 FT 768,0 FT 781,1 FT 794,1 FT ' 807.2 FT 820,3 FT 833,2 FT NORTH SOUTH COORDINATES 0,0 FT 0.2 FT -3,0 FT -3,6 FT -4,1 FT -6,6 FT -7,2 FT -7,8 FT -11,3 FT -11,9 FT -12,6 FT -22,9 FT -23,9 FT -25.0 FT 78,2 FT 93,9 FT 109,6 FT 128,4 FT 150,7 FT 330,2 FT 354,8 FT 379,3 FT 404,7 FT 430,4 FT 456, 1 FT 481,8 FT 507,5 FT 533,3 FT 558,7 FT 584,0 FT 609,4 FT 634, 8 FT 660,3 FT 685,8 FT 711,3 FT 736,9 FT 762,4 FT 788,0 FT 813,6 FT 839,3 FT 864,8 FT 889.9 FT 914,9 FT 939,8 FT 964,7 FT 988,9 FT 1012,9 FT 1036,9 FT 1061,0 FT 1098, 1 FT 1122,6 FT 1147.2 FT 1171,9 FT 1196, 6 FT 1221,3 FT 1246,0 FT 1270,2 FT 1294.3 FT 1318,4 FT 1342,5 FT 1366,7 FT 1390, 1 FT 1412.1 FT 1434,1 FT 1456, 1 FT 1478, 1 FT 1500,2 FT 1522,3 FT GEOPHONE OFFSET 2,8 FT 3,4 FT 7,1 FT 7,4 FT 7,8 FT 14,4 FT 15,6 FT 16,6 FT 22,6 FT 22,9 FT 23,2 FT 31,1 FT 32,0 FT 32,9 FT 122,6 FT 139,0 FT 155,7 FT 175,8 FT 199,7 FT 398,9 FT 426,6 FT 454,4 FT 482,8 FT 511,5 FT 540,3 FT 569,1 FT 597,8 FT 626,7 FT 654,8 FT 682,8 FT 711,0 FT 739,1 FT 767,4 FT 795.4 FT 823,2 FT 851,0 FT 878,8 FT 906,6 FT 934,4 FT 962,4 FT 990,2 FT 1017,5 FT 1044,6 FT GEOPHONE AZIMUTH 9O. 7 DEG 86.7 DEG 114.9 DEG 118.7 DEG 122.1 DEG 117.4 DEG 117.3 DEG 117.9 DEG 120.1 DEG 121.3 DEG 122.8 DEG 137.4 DEG 138.5 DEG 139.5 DEG 50.4 DEG 47.5 DEG 45.3 DEG 43.1 DEG 41.0 DEG 34.1 DEG 33.7 DEG 33.4 DEG 33.0 DEG 32.7 DEG 32.4 DEG 32.1 DEG 31.9 DEG 31.7 DEG 31.4 DEG 31.2 DEG 31.0 DEG 30.8 DEG 30.6 DEG 30.4 DEG 30.2 DEG 30.0 DEG 29.8 DEG 29.6 DEG 29.5 DEG 29.3 DEG 29.1 DEG 29.0 DEG 28.9 DEG 1071.6 FT 28.7 DEG 1098,6 FT 28,6 J)6.~ 1125,6 FT ' .~:', ~ 1179:" 1206.6~,.T~,~ ~"1~8.4 BEG 1248,3 Fl' I 28,4 DEG 1276,0 FT 1304,0 FT 1332,0 FT 1360,0 FT 1388, 1 FT 1416, 1 FT 1443,9 FT 1471,6 FT 1499,4 FT 1527,1 FT 1554,8 FT 1581,9 FT 1607,4 FT 1633,0 FT 1658,6 FT 1684,2 FT 1709,8 FT 1735,5 FT 28,4 DEG 28.4 DEG 28,4 DEG 28,4 DEG 28,4 DEG 28.4 DEG 28,4 DEG 28,4 DEG 28,4 DEG 28,5 DEG 28.5 DEG 28,5 DEG 28.5 DEG 28,6 DEG 28,6 DEG 28,6 DEG 28,7 DEG 28,7 DEG 8840,1 8889.6 8939.2 8988.8 9038,4 9088.0 9137,7 9187,3 9236.9 9286,5 9336.1 9385.7 9435,3 9484,9 9534.5 9584,1 9633,7 9683,3 9732,9 9782,5 9832,1 9881,6 9931,2 9980,9 ]0030.5 10080.1 10129.7 10179.3 10228.9 10278.5 10328.1 10377.7 ]0427.3 10476.9 10526.5 10576.1 10625.7 10675,3 10724,9 10774,5 10824,1 10873,7 10923,3 10972,9 11022,5 11072,1 11121,8 11171,4 11221,0 11270,6 11320,2 FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT 5330,3 8372,7 8415,1 8457,7 8500,3 8542,9 8585,6 8628,2 8670,8 3713,4 8756~0 8798,5 8841,0 8883,5 8926,0 8968,5 9011,0 9053,4 9095,9 9138,3 9180,0 9221.5 9263,0 9304,6 9345,2 9385,8 9426,5 9466,8 9506,4 9546.0 9585,5 9622,3 9655,6 9689,0 9722,4 9762,6 9806,2 9849,8 9893,4 9933,0 9971,7 10010,5 10049,2 10088,5 1O127,8 10167,1 ]0206,5 ].0245,8 10285,4 10325,7 10366,0 FT FT Fl' FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT 8292,3 FT 8334,7 FT 8377,1FT 8419.7 FT 8462,3 FT 8504,9 FT 8547,6 FT 8590,2 FT 8632,8 FT 8675,4 FT 8718,0 FT 8760,5 FT 8803,0 FT 8845,5 FT 8888,0 FT 8930,5 FT 8973,0 FT 9015,4 FT 9057,9 FT 9100,3 FT 9142,0 FT 9183.5 FT 9225,0 FT 9266,6 FT 9307.2 FT 9347,8 FT 9388,5 FT 9428,8 FT 9468,4 FT 9508.0 FT 9547,5 FT 9584,3 FT 9617,6 FT 9651,0 FT 9684,4 FT 9724.6 FT 9768,2 FT 9811,8 FT 9855,4 FT 9895,0 FT 9933,7 FT 9972,5 FT 10011,2 FT 10050,5 FT 10089,8 FT 10129,1 FT 10168,5 FT 10207,8 FT 10247,4 FT 10287,7 FT 10328,0 FT 846.2 FT 859.0 FT 871,9 FT 884.7 FT 897,3 FT 910,0 FT 922,8 FT 935,9 FT 948.9 FT 962,0 FT 975.6 FT 990.4 FT 1005,3 FT 1020,1 FT 1034.9 FT 1049,8 FT 1065,7 FT 1081,9 FT 1098,2 FT 1114,5 FT 1131,3 FT 1148.2 FT 1165,1FT 1182,1FT 1199,7 FT 1217,2 FT 1234,8 FT 1252,5 FT 1270,6 FT 1288,7 FT 1306,8 FT 1325,2 FT 1344,1FT 1362,9 FT 1381,8 FT 1400,5 FT 1419,2 FT 1437,8 FT 1456,5 FT 1474,6 FT 1492.6 FT 1510,7 FT 1528,7 FT 1545,3 FT 1561,9 FT 1578,5 FT 1595,2 FT 1611,8 FT 1628.1 FT 1643,9 FT 1659,7 FT 1544,6 1566.7 1588,9 1611,0 1633,0 1655,0 1677,1 1698.8 1720,6 1742,4 1763.9 1784,7 1805,5 1826,3 1847,1 1867.9 1888.0 1907.8 1927.6 1947.4 1968.4 1989.5 2010.6 2031.9 2054,2 2076,6 2098,9 2121,6 2145,4 2169,3 2193,1 2217,3 2242,1 2266,8 2291,6 2316,6 2341,6 2366.7 2391,8 2417,1 2442,4 2467,8 2493,2 2518,4 2543,6 2568,8 2594,0 2619,2 2644,0 2668,3 2692,5 FT FT FT FT FT FT FT FT FT Fl' FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT FT 1761,1FT 1786.8 FT 1812,5 FT 1837.9 FT 1863,3 FT 1888,7 FT 1914,2 FT 1939.6 FT 1964,9 FT 1990,3 FT 2015,7 FT 2041,1 FT 2066,5 FT 2091.9 FT 2117,3 FT 2142,7 FT 2168,0 FT 2193,2 FT 2218,5 FT 2243,7 FT 2270,3 FT 2297,0 FT 2323,8 FT 2350,7 FT 2378,9 FT 2407,0 FT 2435,2 FT 2463,7 FT 2493,4 FT 2523.2 FT 2552,9 FT 2583,2 FT 2614,1 FT 2645,0 FT 2676,0 FT 2707,0 FT 2738,1 FT 2769.2 FT 2800,3 FT 2831,4 FT 2862.4 FT 2893,5 FT 2924,5 FT 2954,7 FT 2984,9 FT 3015,0 FT 3045,2 FT 3075,4 FT 3105,1 FT 3134,0 FT 3163,0 FT 28.7 DEG 28.7 DFG 28,8 DEG 28.8 DEG 28,8 DEG 28,8 DEG 28,8 DEG 28,8 DEG 28,9 DEG 28,9 DEG 28,9 DEG 29.0 DEG 29,1 DEG 29.2 DEG 29.3 DEG 29,3 DEG 29,4 DEG 29,6 DEG 29.7 DEG 29,8 DEG 29,9 DEG 30,0 DEG 30,1 DEG 30,2 DEG 30,3 DEG 30,4 DEG 30,5 DEG 30,6 DEG 30,6 DEG 30,7 DEG 30,8 DEG 30,9 DEG 30.9 DEG 31,0 DEG 31,1 DEG 31,2 DEG 31,2 DEG 31.3 DEG 31,3 DEG 31,4 DEG 31,4 DEG 31,5 DEG 31,5 DEG 31,5 DEG 31,6 DEG 31,6 DEG 31,6 DEG 31,6 DEG 31,6 DEG 31,6 DEG 31,7 DEG LEVEL NO 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 22 23 MEASURED DEPTH FROM KB FT 851.3 950.5 1801.6 1900.8 2000.0 2801.5 2900.7 2999.9 3801.8 3901.0 4000.2 4900.7 4950.3 4999.9 5801.7 5851.3 5900.9 5950.5 6000.1 6382.7 6432.3 6481.9 6531.5 COMPANY VERTICAL DEPTH FROM SRE, FT 813.3 912.5 1763.6 1862.8 1962.C 2763.~ 2862.5 2961.~ 3763.7 3862.9 3962.1 4862.5 4912.1 4961.7 5745.5 5791.6 5837.7 5882.4 5925.~ 6250.3 6291.3 6332.3 6372.? : BP EXPLORATION MEASURED TIME FROM SURFACE SENSOR TO GEO mS 99.0 104.0 168.0 176.0 188.0 304.0 319.0 331.3 433.0 444.0 452.4 570.0 576.0 583.0 666.0' 670.0 674.0 678.0 682.0 712.0 716.0 720.0 724.0 WELL : BADAMI #5 VERTICAL T1ME FROM SOURCE TO GEOPHONE mS 88.9 95.3 163.9 172.1 184.2 300.9 315.9 328.3 430.6 441.6 450.1 558.1 564.2 571.2 658.2 662.6 666.9 671.3 675.8 708.7 713.0 717.3 721.6 VERTICAL TIME FROM SRD/GEO. mS 88.9 95.3 163.9 172.1 184.2 300.9 315.9 328.3 430.6 441.6 450.1 558.1 564.2 571.2 658.2 662.6 666.9 671.3 675.8 708.7 713,0 717.3 721.6 AVERAGE VELOCITY SRD/GEO. FT/S 9149 9573 10763 10825 10651 9185 9061 9021 8741 8747 8803 8713 8707 8686 8729 8741 8753 8762 8768 8819 8824 8828 8832 INTERVAL VELOCITY FT/S 15439 12419 12054 8181 6870 6584 8007 7843 8971 11716 8338 8143 7016 9013 10543 10573 10146 9687 9870 9499 9539 9455 9446 LEVEL NO 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 4O 41 42 43 44 45 46 COMPANY : BP MEASURED DEPTIt FROM KB FT 6581.1 6630.8 6680.4 6730.0 6779.7 6829.3 6878.6 6928.2 6977.8 7027.5 7077.1 7126.6 7176.2 7225.8 7275.4 7325.0 7374.8 7424.4 7474.0 7523.6 7573.2 7622.7 7672.3 VERTICAL DEPTH FROM SRD FT 6413.2 6453.7 6494.0 6534.4 6574.8 6615.6 6656.1 6696.8 6737.5 6778.3 6819.1 6860.0 6901.0 6941.9 6982.9 7023.9 7065.0 7105.9 7147.3 7188.7 7230.2 7271.6 7313.2 EXPLORATION WELL : BADAMI #5 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 728.0 732.0 736.0 740.0 744.0 748.0 752.0 756.0 760.0 764.0 768.0 772.0 776.0 780.0 784.0 788.0 792.0 796.0 800.0 804.0 808.0 812.0 816.0 VERTICAL TIME FROM SOURCE TO GEOPHONE inS 725.9 730.1 734.4 738.6 742.8 747.0 751.1 755.3 759.4 763.5 767.7 771.7 775.8 779.9 783.9 788.0 792.0 796.0 800.0 804.0 808.0 811.9 815.9 VERTICAL TIME FROM SRD/GEO. mS 725.9 730.1 734.4 738.6 742.8 747.0 751.1 755.3 759.4 763.5 767.7 771.7 775.8 779.9 783.9 788.0 792.0 796.0 800.0 804.0 808.0 811.9 815.9 AVERAGE VELOCITY SRD/GEO. FT/S 8835 8839 8843 8847 8852 8856 8861 8867 8872 8877 8883 8889 8895 8901 8908 8914 8921 8927 8934 8941 8949 8956 8964 INTERVAL VELOCITY FT/S 9504 9526 9565 9623 9738 9722 9815 9851 9906 9939 9994 10048 10082 10115 10148 10222 10213 10333 10400 10430 10438 10516 10547 LEVEL NO 47 48 49 5o 51 52 53 54 55 56 57 58 59 6O 61 62 63 64 65 66 67 68 69 COMPANY : BP EXPLORATION WELL MEASURED DEPTH FROM KB FT 7721.9 7771.5 7821.1 7897.6 7947.2 7996.8 8046.4 8096.0 8145.7 8195.3 8245.0 8294.6 8344.2 8393.7 8443.3 8492.9 8542.5 8592.1 8641.6 8691.2 8740.9 8790.5 8840.1 VERTICAL DEPTH FROM SRD FT 7354.7 7396.3 7437.9 7502.1 7543.2 7584.1 7625.0 7665.9 7706.8 7747.7 7789.0 7830.1 7871.3 7912.4 7953.5 7995.1 8037.6 8080.0 8122.4 8164.8 8207.4 8249.8 8292.3 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 820.0 824.0 828.0 834.0 838.0 842.0 846.0 850.0 854.0 858.0 862.0 866.0 870.0 874.0 878.0 882.0 886.0 890.0 894.0 898.0 902.0 906.0 910.0 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 819.8 823.8 827.7 833.5 837.4 841.3 845.2 849.1 852.9 856.8 860.6 864.4 868.3 872.1 875.9 879.7 883.5 887.3 891.1 894.9 898.7 902.4 906.2 VERTICAL TIME FROM SRD/GEO. mS 819.8 823.8 827.7 833.5 837.4 841.3 845.2 849.1 852.9 856.8 860.6 864.4 868.3 872.1 875.9 879.7 883.5 887.3 891.1 894.9 898.7 902.4 906.2 BADAMI #5 AVERAGE VELOCITY SRD/GEO. FT/S 8971 8979 8987 9000 9007 9014 9022 9029 9036 9043 9051 9058 9066 9073 9081 9089 9098 9106 9115 9124 9133 9142 9151 INTERVAL VELOCITY FT/S 10575 10602 10943 10545 10526 10553 10580 10628 10636 10744 10746 10771 10772 10818 10940 11151 11169 11164 11206 11248 11246 11266 11260 LEVEL NO 7O 71 72 73 74 75 76 77 78 79 8O 81 82 ? 83 , , 84 85 86 87 88 89 90 91 92 MEASURED DEPTH FROM KB FT 8889.6 8939.2 8988.8 9038.4 9088.0 9137.7 9187.3 9236.9 9286.5 9336.1 9385.7 9435.3 9484.9 9534.5 9584.1 9633.7 9683.3 9732.9 9782.5 9832.1 9881.6 9931.2 9980.9 COMPANY : BP EXPLORATION WELL VERTICAL DEPTH FROM SRD FT 8334.7 8377.1 8419.7 8462.3 8504.9 8547.6 8590.2 8632.8 8675.4 8718.0 8760.5 8803.0 8845.5 8888.0 8930.5 8973.0 9015.4 9057.9 9100.3 9142.0 9183.5 9225.0 9266.6 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 914.0 918.0 922.0 926.0 930.0 934.0 938.0 942.0 946.0 950.0 954.0 958.0 962.0 966.0 970.0 974.0 978.0 982.0 986.0 990.0 994.0 998.0 1002.0 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 910.0 913.7 917.5 921.2 925.0 928.7 932.4 936.2 939.9 943.6 947.3 951.0 954.8 958.5 962.2 965.8 969.5 973.2 976.9 980.6 984.2 987.9 991.5 VERTICAL TIME FROM SRD/GEO. mS 910.0 913.7 917.5 921.2 925.0 928.7 932.4 936.2 939.9 943.6 947.3 951.0 954.8 958.5 962.2 965.8 969.5 973.2 976.9 980.6 984.2 987.9 991.5 BADAMI #5 AVERAGE VELOCITY SRD/GEO. FT/S 9159 9168 9177 9186 9195 9204 9213 9221 92~0 9239 9248 9256 9265 9273 9282 9290 9299 9307 9315 9323 9331 9338 9346 DELTA I INTERVAL TIME VELOCITY mS '~-8 11301 8 11337 8 11357 11372 11412 11406 11420 11434 11441 11435 11449 11464 11477 11490 11491 11500 11513 11525 11387 11353 11393 11421 11234 LEVEL NO 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 MEASURED DEPTH FROM KB FT 10030.5 10080.1 10129.7 10179.3 10228.9 10278.5 10328.1 10377.7 10427.3 10476.9 10526.5 10576.1 10625.7 10675.3 10724.9 10774.5 10824.1 10873.7 10923.3 10972.9 11022.5 11072.1 11121.8 COMPANY VERTICAL DEPTH FROM SRD FT 9307.2 9347.8 9388.5 9428.8 9468.4 9508.O 9547.5 9584.3 9617.6 9651.0 9684.4 9724.6 9768.2 9811.8 9855.4 9895.0 9933.7 9972.5 10011.2 10050.5 10089.8 10129.1 10168.5 : 9P EXPLORATION WELL MEASURED TIME FROM SURFACE SENSOR TO GEO mS 1006.0 1010.0 1014.0 1017.5 1022.0 1025.5 1028.7 1032.0 1036.0 1040.0 1044.0 1048.0 1051.2 1054.5 1058.0 1062.0 1066.0 1070.0 1074.0 1078.0 1081.7 1085.2 1088.5 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 995.1 998.7 1002.3 1005.5 1009.5 1012.6 1015.3 1018.2 1021.7 1025.2 1028.7 1032.2 1034.9 1037.7 1040.8 1044.2 1047.7 1051.2 1054.7 1058.1 1061.3 1064.3 1067.1 VERTICAL TIME FROM SRD/GEO. mS 995.1 998.7 1002.3 1005.5 1009.5 1012.6 1015.3 1018.2 1021.7 1025.2 1028.7 1032.2 1034.9 1037.7 1040.8 1044.2 1047.7 1051.2 1054.7 1058.1 1061.3 1064.3 1067.1 BADAMI #5 AVERAGE VELOCITY SRD/GEO. FT/S 9353 9360 9366 9378 9379 9390 9403 9413 9413 9414 9414 9421 9439 9455 9469 9476 9481 9487 9492 9498 9507 9517 9529 INTERVAL VELOCITY FT/S 11250 11266 13020 9744 12897 14301 12917 9511 9530 9548 11461 16007 15468 14481 11365 11134 11150 11167 11279 12337 13166 14142 13199 COMPANY LEVEL NO 116 117 118 119 MEASURED DEPTH FROM KB FT 11171.4 11221.0 11270.6 11320.2 VERTICAL DEPTH FROM SRD FT 10207.$ 10247.4 10287.7 10328.0 : BP EXPLORATION WELL : BADAMI #5 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 1092.0 1096.0 1100.1 1103.8 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 1070.1 1073.6 1077.1 1080.3 VERTICAL TIME FROM SRD/GEO. mS 1070.1 1073.6 1077.1 1080.3 AVERAGE VELOCITY SRD/GEO. FT/S 9539 9545 9551 9560 DEL DEP FT 39 4O 40 DEL1 TIME , INTERVAL VELOCITY FT/S 11417 11225 12614 SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska FINAL LOGS AND CONDENSED DIGITAL DATA BP EXPLORATION Badami No. 5 North Slope, Alaska Final Report Summary March 1995 F IC ()FILMED PREPARED FOR: BP Exploration PREPARED BY: John Patton Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska Ass~cjned Li(ho~ogy Pa(terns - 10'23 22-~4AR-95 P~ttern Tuff Chert 67 P~tiern 32 Pattern 29 Pattern 47 P~itern 44 Shale P~ttern ¢5 P~ttern 9 P~ilern 7 Pattern 5t P~iiern O L SEPIA FINAL SEPIA FINAL SEPIA FINAL SEPIA FINAL SEPIA FINAL SEPIA FINAL 5" & 10"- SEPIA t'fNAL DIPOLE SHEAR IMAGER IMAGE kO(~ SEPIA FINAL INTEGRATED POROSITY LOG. NATURAL GAMMA RAY LOG 5" SEPIA FINAL LONG SPACED SONIC AND DIPOLE SHE. AR IMAGER 5" SEPIA FINAL TVD PHASOR DUAL INDUCTION R.ESISTWITIES & ARRAY INDUCTION TOOL RESISTIVITIES SEPIA FINAL CEMENT EVALUATION LOG SEPIA FINAL MICROLOG 5" & 10" LDS BULK DENSITY AND APS EPITHERMAL POROSITY 5" TVD LDS BULK DENSITY & APS EPITHERMAL ELECTROMAGNETIC PROPAGATION TVD MICROLOG LONG SPACED SONIC AND DIPOLE SHEAR 12VIAGER 2" PHASOR DUAL INDUCTION RES. AND ARRAY INDUCTION TOOL RES. SEPIA FINAL CEMENT BOND l~OO (CBT) SEPIA FINAL LONG SPACED SONIC AND DIPOLE SHEAR IMAGER SEPIA FINAL LDS BULK DENSITY AND EPITHERMAL POROSITY 2" SEPIA FINAL PHASOR DUAL INDUCTION RES. AND ARRAY INDUCTION TOOL RES SEPIA FINAL INTEGRATED POROSITY LOG NATURAL GAMMA RAY LOG'2" '' SEPIA FINAL MODULAR DYNAMICS FORMATION TESTER SPERRY SUN Blueline 2"/100' & 5"/100'-MD.EWR4.DGR.ROP ! 2"/100' & 5"/100'-TVD.,EWR4,DGR,ROP 1 2"/100' & ,5"/100'-MD.EWR4.DGR.ROP.SLD 1 2"/100' & 5"/100'-TVD.EWR4.DGR.ROP.SLD 1 MWD End of Well Report Diskette~ 1 1 1 1 Roll Sepia 1 1 1 1 Blueline FF Sepia Roll Sepia. 2"/100'-Combination Mud Log 1 1 1 2"/100'-Engineering Log 1 1 1 5"/100'-Combinatioll Mud Log 1 1 1 5"/100'-Engineering Log 1 1 1 Di~kette~ 1 1 1 1 ,-'1Still Stem Test 'Report Badami #4 · ~'ormation Tops Badami 4/4 ~ore Discription Badami #4 '-'Velocity Survey Badami #4 (-~'ore Analysis Badami #4 ~'~ownhole Water' Sample Analysj~ Badami #5 ...... Formation Tops Badami #5 (.~Core Discriptior~ B~qt~mi #5 :"-"Velocity Survey Badami #5 ~-tCore Analysis Badami #5 ,--Drill Stem Test Report Badami #5 ~ t/, ~) t,ta~T Well Test Report Badami #5 Received by' Date received: ,, {, BP Exploration (Alaska), Inc. Badami #5 API Number: CONFIDENTIAL 50-629-22533-00 List of formation tops referenced to final log depth FORMATION BOUNDARY measured depth TVD brt Sagavanirktok Formation (at or near seabottom) Base Permafrost 1,900' 1,900' Top Canning Formation (Mikkelsen Tongue) 5,154' 5,154' Top Staines Tongue of Sagavanirktok Fm. 7,120' 6,892' Base Staines Tongue or Top Lower Canning Fm. 8,799' 8,295' (TD in Canning Formation @ 11,549' driller's depth) CONFIDENTIAL CONFIDENTIAL RECEIVED MAY 4 1995 Alaska Oil & Gas Cons. Commimsion Anchorage ORIGINAL 7¥-- BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 3, 1995 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501-3192 Dear David W. Johnson, Chairman' The attached is a listing of well information for Badami #4 & #5. The material is being transmitted in accordance with AAC 25.071 (Geologic Data And Logs). We transmit this data with the understanding it will be held confidential in accordance to AAC 82.810 (Confidentiality of Data). Please acknowledge receipt by signing the enclosed transmittal and returning a copy to us. Walter Tifenta¢" Technical Assistant Encl: TransmittaI TO: Core Laboratories TRANSMITTAL AND ACKNOWLEDGEMENT OF .RECEIPT ALASKA OIL AND GAS COMMISSION ANCHORAGE, AK MA TERIALS RECEIVED VIA: CORE LAB PERSONNEL ITEMS RECEIVED: · BOX 1 BOX 2 BOX 3 BADAM! #4 CORE1 11068-11097 CORE2 11185-11214 CORE2 11215-11239 BADAMI 5 BOX 1 CORE 1,2, 3 BOX2 CORE 4,5 BOX 3 CORE 6 BOX 4 CORE 6 BOX 5 CORE 7 BOX6 CORE 7,8 10489 - 10572 11016 - 11021 11113 - 11137 11143 - 11175 11176 - 11202 11203 - 11240 11241 - 1-I-2e8- 11263 -. 11268 REEEIVED Alaska Oil & Gas C0~ Shipped ~.' PERF~ BROWN for CORE LAB Date: 11-May-95 / Receivedk[;~: o for AOGC Date: Please note that th s listed above are inventoried, shipped and received in good faith, but due to errors, are subject to minor adjustments. In such case both shipper and receiver agree to make a timely and bona fide effort to correct any observed discrepancies. CORE LABORATORES 8005 SCHOON ST., ANCHORAGE, ALASKA 99518 (907) 349-3541 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~, DATE: April 15, 1995 Chairm~ T~RU: Blair Wondzell, ~ ~LE NO: G99LDNCD.doc P. I. Supervisor FROM: John Spauiding~,~;L~ SUBJECT: Location Inspections Petroleum Insp Badami 4 & 5 BPX Wildcat Wells' ~/- ,9~- I~,i Friday April 14,1995: I visited BPX's Badami 4 & 5 wildcat'Wells at the request ofthe cleanup contractor Peak Oiifield Services. ....... The cleanup effort after the ddiling rigs had been moved and was going quite well. Peaks foreman was under the understanding that i woui~l be able to grant a location clearance when all the dirty snow was removed. I informed the 'Peak foreman that although both sites appeared to be in excellent shape that a location clearance would not be granted unti~ the summer months when a visit by helicopter could be arranged. This information was also passed on to Nick Scales BPX..drilling foreman. Summary: I visited the Badami 4 & 5 locations to observe area cleanup operations after the drilling season and drilling rigs were moved. · 7' Memorandum To: Blair Wondzeli Date: 4/10/95 From: Tim Sohofield RECEIVED Subject: Badami #5 Abandonment Plugs APR 1 ! !~995 Alaska Oil & I~as Cons. Anchorage I hope that this will clear up the question of the Iow pH reported by your Slope representatives, I suspect that there was some confusion between figures for Pm and pH, The mud system did get contaminated by the cement, but the contamination caused the usual increase in pH and not a reduction. I have attached the Badami #5 mud reports for the four days just prior to and during the setting of abandonment plugs inside 7" liner, i think that the most informative parts of the reports are the pH and alkalinity mud (Pm) values, the 'Remarks' section and. the 'Materials Used' section, I have tried to indicate these, but I don't know how successfully it will fax. Day 66 - March 27th was the day before we pUmped the first cement plug. The report shows a pH of 6,9, which was typical for our bland core fluid, Day 67 - We set the first cement plug and circulated above it. We appear to have had some contamination and this is indicated by the increase in pH to 10.4, Note that the Pm is at 0,65, Aisc note that a product called PH6 was added to the system. This is a earboxylic acid buffer which is designed to reduce the pH level after cement contamination, Day 68 - After waiting on cement, we washed down to the top of the plug and tagged it at 10722', some 205' deeper than expected, We subsequently tested the open perforations and found that they held an 1100 psi test without leaking off. It is most unlikely that we would have had significant losses to such a competent zone, so the missing cement was probably washed out of the hole before it set up. A second plug was set to cover the perforations, The mud test for the day showed an increased pH level of 11,9 and a sharp increase in Pm at 3.9. Once again, PH6 was used to try and reduce the pH level, Day 69 - The second plug was tagged and once again, no hard cement was found within 200' of the expected top. Further treatment with PH6 was helping to reduce the pH and Pm levels to 11,6 and 3.0 respectively, I have no doubt that there was no drop in pH associated with the cement contamination, The mud reports show a high pH reading on the days when we cemented and this is supported by the high alkalinity (Pm) readings, I cannot offer a very good explanation for the missing cement, but it is possible that we over estimated the temperature at the plug depth and came up with an incorrect slurry design, This would delay the thickening time, but would not affect the quality of the cement, Please call me at 564-$242 if you would like more information. Tim Schofield Att. Mud Reports Adrian Clark Randy Thomas SSD SSD RECEIVED APR !I 1-995 Alaska Oil & Gas Cons. Anchora~ APR 10 '~5 8~:4~P{~J SHARED SERVICES DRILL!Hg ~ABO~$18~ ~L FAX ~: .~ero£a D~illin~ Flv£1~, D~LLXN~MUD ~A~ $0'~ P./I ll:z~G No.O15 P.04 NOI~T~ SLOPE IUG)[ 0.071 ,II , O' O.O ~t, II, APR 1 1 1.995, Alaska,Oil & Gas Cons. Anchorage MUD VO{:].fME 1~1 G;ad o.o Off Test 18,0 ~g. SI~ 0,0 Ntt, {)iff, I'~o;~ o We; 6.4 0,0 lbs/tO0 .......... i APl ~~R~..~f,t.:~_' ....... , Rli~o;eg¥ ^ .......... '{]~ ...... ~lis I ~L~O ~I~G t~Lu ~0 tp, '16 .................. . Ora4 0,0 [ ~1¢ 4,0~ Tn atorage ' w~i~ Bnne w~t~r o~ 6 tpm ~ ~D i~,l J N~IN~ O,O0 'ti.it ~lPR 10 '9~ 8~:44Pffl SHAPED SER¥ICES DRI~ING M~R 28~qS 7~0~ N~,O05 P,05 M~K~ ~IT~LZY ~ ~ [DON DuBOIS W~ ~ -~'"~'~ I Pz ~O 0~-~'~ ~,. ,..,-J~'~"o~"~) ~/~ :~ ~.,~' ~ ~'.'f~'_.i~ .... ~'~$~%,~,~,~,~ . _?='. ....... '. .... , '~ ~n~ ..............'rs ....t~ -' j i'-ZJ~'-~,z ...... ~',~'~- -- ,,~? '~,, ~ ,.~jiF':--'~-~-~.~ ' ~.,, ,. b~%~ '~ ....... :_L]]~i~ ...................... 7~ ' ~' ~,~ ....... ]-~' M~'/~; __ ~'~A ' ..... i ol~ ........................................................... ~n~th ~"_~_ '~-'- .... l'~'ij~ ..................... ' ........ ~'~'~ ..................... T ~t ~ '1 ~ l~lPi~ ....... ............... ~,~ ....... ~ ' .... ' MUD 9~OP~TIES ~CZFICATIONS .......... CakO Tb~ckn#~ 'll'i'~ I~rJtt~ Iff RI$~KS APR 1 1 !,995 ^~aska .0il &fias Ooas. ~chomg~ , Sh~ 13,3 any li~illt¥ by ~Ol~ imIL&~ PL~ID~, ~C, =r Jla s~e~:~ al~d at~ at~t.,.nt~ o! o~i~O~ o~ly, APR 10 '9S 03'45PH SHI;RED SERVICES ]DRILLING P.7 ,~IBORSlS~ DRL FAX 'D: {~AR 27'.~5. 6:.7 NO.O0~ P.05 .... ~ o~7/95 ~43o ~ae~ ~MD] . ~'R~N~ f~t J .... ~IN~ CIRCULATION DATA ,130 sat ~ h ,, ,4or ~ me 1]~ )me RECONMENDTM TOUR iii mlllll~ T~ ~ERVIC~ ~ I El, b~¥ I APR 1'1 !,995,, Alaska Oil & Gas L;ons. · , · -,}.,,l~ ,iiml~imi,,,, i em'~,, i, I 4'~"' "' ~IF.II%qI'IMI,i,,.IAiI,~k'I ii ,i{ ,. s m , ,, ~T- ] ~s '~ ~Ua~D~P ....... ]~ ~" '~ .................... = .6~s_ .{.. {~3.._~' _"_~UD ~IBHR~IOR'])OO rp: 53 ~ o~f Test ~}9 6fly, vol ~ 13,4 RIIN C$8 o.00 April 10, 1995 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501-3192 Dear David W. Johnson, Chairman: The attached is a listing of well information for Badami #5. The material is being transmitted in accordance with AAC 25.071 (Geologic Data And Logs). We transmit this data with the understanding it will be held confidential in accordance to AAC 82.810 (Confidentiality of Data). Please acknowledge receipt by signing the enclosed transmittal and returning a copy to us. Technical Assistant RECEIVED Encl: Transmittal APR 1 0 1995 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION (ALASKA) INC. I " ANCHORAGE, AK 99519-6612 ANCHORAGE OFFICE: 900 E. BENSON BLVD. · ANCHORAGE, AK 99508 · (907) 561-5111 TO: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501-3192 FROM: BP Exploration (Alaska)Inc. Alaska Exploration P.O. BOX 196612 Anchorage, AK 99519-6612 RECEIVED APR 1 0 1995 Alaska 0ii & Gas Cons. Commission A~ch0rag~ DATE: 04/10/95 The following material is being transmitted herewith. Please acknowledge receipt by signing below and returning a copy of this letter: BADAMI #5 One each B-line & Sepia: ,~latural Gamma Ray Spectroscopy Log 2"&5" ipole Shear Imager Image Log lectromagnetic propogation Log 2"&5" ong Spaced Sonic and Dipole Shear Imager cng Spaced Sonic and Dipole Shear Imager ~,,,TVD LDS/LDT Bulk Density And APS/CNTH Neutron Porosity ~Phasor Dual Induction Res. and Array Induction Tool Res. 5"&10" I~rVD Long Spaced Sonic and Dipole Shear Imager '~VD Phasor Dual Induction Res. and Array Induction Tool Res. ~'" ~Phasor Dual Induction Res. and Array Induction Tool Res. ,~ 1/2" &2" dular Dynamics Formation Tester /~0 ;~. -,EDS/LDT Bulk Density and APS/CNTH Neutron Porosity 5"&10" .~DS/LDT Bulk Density and APS?CNTH Neutron Porosity 2" · ,,,Microlog 2"&5" // ,~I'VD Microlog ~ ~,~,ne each B-line & Sepia & Mylar: ' Dual Propagation Res., Gamma Ray TVDSS ~v~"&5" Dual Propagation Res., Gamma Ray MD L/~"&5" Neutron Porosity, Bulk Density, Dual Propagation Res., Gamma Ray MD 2" Neutron Porosity, Bulk Density, Dual Propagation Res., Gamma Ray TVDSS · ~IT Dip Correction (Paper Copy) ~2 copies MSD Mean Square Dip logs ,,9588-10030 FMI 1" Dynamic Images (Paper Copy) ,.,10030-10480 FMI 1" Dynamic Images (Paper Copy) 2"/100' Blueline/Sepia/Mylar/Diskettes of each: ·,,Combination Mud L...o,g ~,Engineering Log ~Combination Mud Log t~Engineering Log 9-track Tap data with listing ~-~.~" t~ual Propagation Res. Gamma Ray, Neutron & Density Porosity Data G~-~'? ~'FMI Dip Results r~5' ~(~ "~vlSD Dip Results ~,j--~/ ~pen Hole Edit Tape Received by: Date Received' /~ ~/~ (~""'- v v ~ RECEIVED APR 1 0 1995 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation C(~mmission TO: David Joh~ Chairman DATE: April 6, 1995 THRU: FROM: Blair Wondzell,~.~. P. I. Supervisor 4/71,~,.~... FILE NO: Doug Amos, be ~ '~'~'-SUBJECT: Petroleum Inspector g9nhdfcd.doc Surface Cement Plug BPX Badami No. 5 Exploratory PTD 94-161 Tuesday, April 4, 1995: I was unable to witness the placetnent of the surface cement plug at BPX Exploratory Well Badami No 5, therefore I traveled to the site to visually inspect the location and collect data on the plug. I met with BPX representative Mile Whitely and collected the follow data: After setting cement plug #3 the 9 5/8" casing was cut at 250' BRT. After WOC for 8 hours the BOPE stack was nippled down the upper casing . spool was lifted and the cut off'9 518" casing was removed. .A 13 3/8" wiper plug was RIH to 250' BRT, 14.95 PPG Cold Set II cement was place from the wiper plug to 68' BRT. The top of this plug was verified by tagging it with a 13 3/8" Casing Spear on drill pipe. As per Blair's request, I questioned Mike about the radical mud ph change during the cementing operations for plug #2. Mike told me that the hole was drilled with a neutral (ph 7), high viscous mud at 12.5 PPG. VVhile placing this plug the 15.8 PPG cement was slow falling out of the drill pipe and Mike believes that most of the cement remained in the drill pipe, contaminating the mud, resulting in a mud ph of 3 after the job. This also explains why there was a large quantify of cement pumped but a small quaintly of cement across the perforations. The identical event occurred when the second batch of cement was pumped for plug #2. Enough cement was mixed and pumped to give a 600' plug across the upper perforations yet when tagged, there was only 300' of cement in the hole. Thursday, April 6, 1995: i traveled back to the Badami #5 location to update this report and inspect the cellar removal program. The 13 3/8", 30" and 34" casings had been removed and cement was being jack hammered from around the 48" drive pipe. BPX representative Nick Scales was doubtful if the rig would be able to pull this 48" section of pipe because of the hard cement encasing it. After the rig substructure is moved off of the well, arrangements have been made to bring a track mounted backhoe to the location. This excavator will be used to remove the remaining cement, the 48" drive pipe and the 12' diameter by 10' insulated cellar box. Lou Grimaldi will be notified when the excavation commences so that he can verify the removal of all remaining cement, piping and casings from the cellar. ...Friday, April 7, 1995: I contacted Nick Scales to get an update on the cellar boX, cement and 48" drive pipe removal. Nick told me that all casings had been removed and that the rig should be released some time later today. The backhoe should be on location Sunday April 9, 1995 to remove the remaining cement, cellar box and piping. i took our Magellan Nav 5000DX GPS to the location and recorded the Lat. and Long. coordinates for this location and Badami #4. We can use these coordinates to fiscally locate both well sites this summer, should we so desire. SUMMARY: I collected data on the surface cement plug and mud ph change at BPX Exploratory Well Badami #5 Attachments: G9NHDGCD.XLS, CASING SCHEMATIC Pmofmuds RATING ALKALINITY OF DRII,LING MUDS During the placement of cement plugs and during drilling them out, cement contamination of the mud system can occur. The addition of cement to the mud system rasises the pH of the mud system - the filtrate as well as the mud itself. - to a pH which is above the neutral point of pH - 7.0. Above 7, the fluid is said to be alkaline versus acid which is below 7. Alkalinity or acidity is indicated by pH which is the log base 10 of the hydrogen ion concentration (the power of minus 1 is pH = 1, minus 2 is pH = 2, etc.). However, the characteristics of a mud may fluctuate despite constant pH. This is due to the effect of the varying amounts and nature of the ions present. Moreover, the pH scale is logarithmic. The alkalinity of a high pH mud can vary considerably with no measurable change in pH. When using alkaline muds, analysis of the mud and/or the filtrate to determine the alkalinity is more significant than the pH measurement. A titration method is used to determine the alkalinity content of the mud or filtrate. The indicator is phenolphthalein. The alkalinity of the filtrate or mud is reported as the phenolphthalein alkalinity - the number of milliliter of 0.02 normal (N/50) acid required per milliliter of mud or filtrate. For the mud - Pm, for the filtrate - Pl.. Be careful when considering muds which may be cement contaminated; don't confuse pit with Pm. pH is acidity on a logarithmic scale; Pm is alkalinity based on a phenolphthalein indicator titration method. References: 1. APl RP 13B, Eleventh edition, May 1,1985, STANDARD PROCEDURE for FIELD TESTING DRILLING FLUIDS pg 21 &22. 2. MUD ENGINEERING, Dresser Magcobar, Houston, Texas, Revised August 1968, pg 14 & 15. 3. COMPOSITION AND PROPERTIES OF OIL WELL DRILLING FLUIDS, Walter F. Rogers, Gulf Oil Corp., Houston, Texas, 1953 pg 124-127. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plug And Abandonment Report Operator: Operator Rep.: Lease No.: BP Exploration Mike Whitely / Nick Scales Well No.: 5 Sec. T-R Total Depth: 11,549' Well Name: PTD No.: S5, T9N, R20E Elevation: Date: Badami 94-161 Meridian: Umiat Mud Wt.: 12.5 CASING DATA: 4/7/95 PPg. Drive Pipe: 48" Conductor: 30 Intermediate: 9 5/8 O.D." Set @: 25 ff. With O.D." Set @: 110 ff. Surface: 13 3/8 O.D." Set@: 9578 ft. Prodctn: 7 PLUGGING DATA: Penetration O.D." Set @: 4500 ft. O.D." Set @: 11,605 ff. 1. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: Perforation intervals located at 11,260' to 11,140' and 10,810' to 10,700' 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: 9 5/8 13 3/8 30 34 182' of 14.95 PPG Coldset II Cement from 250' BRT To 28' below the mud line. " Casing Cut @ 250 Feet BRT " Casing Cut @ 30 Feet BRT " Casing Cut @ 30 Feet BRT " Casing Cut @ 30 Feet BRT (Below Rotory Table) (Below Rotory Table) (Below Rotory Table) (Below Rotory Table) REMARKS: The cellar box and remaining cement in the cellar will be removed with a track mounted Backhoe. Lou Grimaldi will verify this portion of the abandonment operation. Distribution: odg - Well File c - Operator c- DNR/DOG c- Database c - Rpt File c - Inspector FI-000 (Rev. 3/93) Inspector (s): John H. Spaulding, Doug Amos GgNHDGCD.XLT BPXA Badami #5 As-Built of Conductor & Cellar Ice l~ad Surface Ice Chips X,x,X 10' x 12' Diameter x 10' High Insulated CMP Cellar ~v/0.3' Urcthane Insulation Cellar Excavation ....................... Mudline ~-9' , ...... 34" Conductor Sleeve w/3" Urethane Insulation 4.25' 4" Ambient Air Vent Pipe · 4'~ Casing Gravelly Soil Inside C,:sing /ncs/Badami #5 Cellar As. Built, Rcv, 1, 1/26/<)5 STATE OF ALASKA ALA~r~, OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well __ Alter casing __ Repair well Plugging x Time extension __ Stimulate __ Change approved program __ Pull tubing __ Vadance __ Perforate __ Other__ 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 3334' SNL, 4770' WEL, SEC. 5, T9N, R20E At top of productive interval 955 SNL, 3323' WEL, SEC. 5, T9N, R20E At effective depth NA At total depth 532' SNL, 3037' WEL, SEC. 5, T9N, R20E 12. Present well condition summary Total depth: measured true vertical RECEIVED MAR 199,5 Ataska 0il & Gas Cons. Commission 11549 feet Plugs (measured) 10544 feet 6. Datum elevation (DF or KB) 32. 7 feet Effective depth: measured NA feet Junk (measured) true vertical NA feet 7. Unit or Property name Exploratory 8. Well number Badami #5 9. Permit number 94-161 10. APl number 50- 629-22533 11. Field/Pool Prudhoe Bay Field~Oil Pool ORIGINAL Casing Length Size Cemented Measured depth Structural 110' 30" DRIVEN 140' Conductor Surface 4465" 13 3/8 875 SX COLDSET II 4495' Intermediate AND 30 SX CLASS G Production 9548' 9 5/8" 800 SX CLASS G 9578' Liner 2270' 7" 680 SX CLASS G 11549' Perforation depth: measured 1) 11,140- 11,260' 2/ 10,700'- 10,810' 3) 4975'-4989' True vertical depth 140' 4495' 8961' 10544' true vertical 1) 10,223'- 10,317' 2) 9875'- 9960' 3) 4975'- 4989' Tubing (size, grade, and measured depth) NONE Packers and SSSV (type and measured depth) NONE 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 3/27/95 16. If proposal was verbally approved Name of approver B. WONDZELL 3/24/95 Date approved 15. Status of well classification as: Oil X Gas__ Suspended __ Service Exploratory 17. I hereby certify that the fore_g.ojng is true and co/'re~ct to the best of my knowledge. Signed ~,~'~) ..... --'~" ~~'~ ' Title DrillingEiigineer ~" FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Date 3/30/95 '~,,ec~ CO~'J J?pproval No. Location clearance 'z./o ,., - mal Signed By SUBMIT IN TRIPLICATE BADAMI #5- FORWARD PROGRAM 3/29/95 Written By Approved By Tim Schofi~'ld y Thomas ABANDONMENT PROGRAM The following program will be carried out after drill stem testing operations on Badami #5. Final abandonment operations will not commence until the New Developments Manager has given approval to permanently abandon the well. Please contact AOGCC slope rep. prior to abandonment as they are likely want to witness at least some of the oPeration, including verification of the condition of the location after abandonment. 1. After testing the lower zone, set a bridge plug no more than 50' above the top perforation. Perforate and test the upper zone. Abandoning The Reservoir Interval. Plug #1. According to the AOGCC regs, the lower zone can be abandoned by placing a minimum of 75' of cement on top of the bridge plug. To abandon the uPper zone with a balanced plug requires cement from at least 100' below to 100' above the perforated interval. The abandonment requiremer~ts for both zones can be met by setting a 600' balanced plUg on top of the bridge plug. This would put cement 200' above the top perforation. The plug will consist of 15.8 ppg, Class G cement. 2. Kill the well POOH with the test string after DST#2. RIH with open ended tubing and set a balanced plug from the bridge plug at 11090' to 10490'. POOH to 10525' and reverse circulate. This should remove any contaminated mud and cement, leaving a clean top 175' above the top perforation. After waiting for plug #1 to set, verify the location of the plug by tagging it. POOH to 9379', laying down tubing. Abandoning The Liner Top. Plug #2. AOGCC regs state that cement stubs must be abandoned with a balanced plug from at least 100' below the stub to at least 100' above it. The 7" liner top will be abandoned with a 300' balanced plug of 15.8 ppg, Class G cement, giving 200' of cement above the hanger. . Set a balanced plug from 9380' to 9080'. Pick up above the plug and circulate to clean the tubing. POOH laying down tubing. At least 12 hours after setting plug #2 and before perforating the casing for plug #3, pressure test with 1000 psi to verify the integrity of the cement. Note - The pressure test of 1000 psi exceeds the formation strength at the top perforation, assuming that the fracture gradient of the reservoir i~eR~alrtq tCLaf- measured in Badami #1. K i~ I~ I" ~Vl' D MAR ~ 1 1995 Aiask~ 0il & Gas Cons. Commission Anchorage Water 4. Test Preparations Plug #3 RIH with casing guns on wireline and shoot 6' of perforations at 5050'. Monitor the annulus to see if communication can be verified by flow from U-tubing. , RIH with a cement retainer on wireline and set it at 5040'. RIH with 5" drillpipe and stab into the retainer. Circulate through the perforations to establish circulation up the annulus and remove the diesel used for freeze protection. 6. Pump plug #3 to get cement 1000' above the 13 3/8" shoe. Note If annulus communication can not be established, RIH with casing guns and shoot 6' of perforations at 4970'. RIH with a cement retainer and perform a 'suicide squeeze'. Following the water zone test, the surface annulus will have to be abandoned by downsqueezing cement into it, leaving a 500' plug just inside the 13 3/8" shoe. Abandoning The Aquifer. Plug #4 The preferred method of abandoning the water zone will be to squeeze cement' into the perforations. AOGCC regs require that a volume of cement equivalent to the volume of the casing from the retainer to 100' below the bottom perforation must be pumped. , RIH with a cement retainer, set it 50' above the top perforation and dispose of any excess mud not required during subsequent abandonment operations. Pump plug #4, consisting of 15.8 ppg, Class G cement. Release from the retainer and reverse circulate to clean the pipe. Pressure test with 1000 psi. POOH laying down drillpipe. Final Abandonment. Plug #5. 8. Squeeze cement into the surface annulus if it was not abandoned with plug #3. RIH with a 9-5/8" casing cutter to at least 250'BRT (check casing tallies that cut is not across coupling). Cut the 9-5/8" casing. . Nipple down BOP stack (ensure that 9-5/8" x 13-3/8" cement job has had adequate time to set up before commencing this operation.) and lift the upper casing spool. Spear into the 9-5/8" stub and recover the casing. 10. Push a 13-3/8" cement wiper plug to 250' BRT. Fill the 13 3/8" casing from 250'BRT to 70' BRT (approx 30' below the mud line) with plug #5, consisting of 14.95 ppg, COLDSET II cement, state Regs require the abandonment surface cement plug to be at least 15' below the mud line and be of at least 150' length. 11. Remove base plate and cement from cellar. Cut 13 3/8" and 30" casing just below the bottom of the 48" pipe. Retrieve all casing, wellhead and ither obstructions to a depth of at least 15' below the mudline. AOGCC rep should verify that the location has been satisfactorily cleared. RECEIVED Oil & Gas Cons. Com~issi~.n Anchorag~ CEMENT DETAILS PLUG #1 600' balanced plug set on top of the 7" bridge plug at 11,090'. Volume of 7" liner -- 0.0371 bbls/ft. Required slurry volume - 600 x 0.0371 - 22.3 bbls or 125 cuff. Slurry yield -- 1.153 cuft/sk No. sx = 125/1.153 = 108 Slurry - Class G + 0.35% FL-52 + 0.8% CD-32 + 0.03% R-1 + 0.5 ghs FP-12L Density = 15.8 ppg, Yield = 1.153 cf/sk, Mix Water = 4.94 gps Thickening Time = 3.30 - 4.00 hrs. Fluid Loss - <150 cc. BHCT = 145°F PLUG #2 300' balanced plug across 9 5/8" x 7" liner lap. Volume of 100' of 7" casing -- 3.7 bbls or 20.8 cuff. Volume of 200' of 9 5/8" casing - 200 x 0.0732 = 14.6 bbls or 82.2 cuff. Required slurry volume = 103 cuft. Slurry yield - 1.153 cuft/sk No sx - 103/1.153 = 89 Slurry - Class G + 0.3% FL-52 + 0.5% CD-32 + ?? A2 + 0.5 ghs FP-12L Density = 15.8 ppg, Yield - 1.153 cf/sk, Mix Water = 4.94 gps Thickening Time = 3.30 - 4.00 hrs. BHCT - 125°F '~"" PLUG #3 Circulation squeeze to isolate the water zone and plug the surface annulus Capacity of 12 1/4" x 9 5/8" annulus = 0.0558 bbls/ft Volume of open hole = 546 x 0.0558 = 30.5 bbls or 171 cuft Capacity of 13 3/8" x 9 5/8" annulus = 0.0597 bbls/ft Volume of surface casing annulus = 1000 x 0.0597 -- 59.7 bbls or 335 cuff Required slurry volume - 90.2 bbls or 506 cuft Slurry yield = 1.15 cuft/sk No sx -- 440 Slurry - Class G + 0.2% FL-52 +0.5% CD-32 +? A2 + 0.5% FP-9L Density = 15.8 ppg, Yield = 1.15 cf/sk, Mix water = 4.95 gps Thickening time = 3.30,4.00 hrs. BHCT = 60°F. Fluid loss = <175 Contingency- Suicide Squeeze Slurry - Same as plug #3 Contingency- Down Squeeze Surface Annulus w/500' Plug Volume required = 500 x 0.0597 -- 15.3 bbls or 136 cuft No sx- 136/1.15- 118 Slurry - As plug #3 if any left, or: Class G + 2% A-7 + 0.5 ghs FP-12L Density = 15.8 ppg, Yield = 1.15 cuft/sk RECEIVED MAR ,~1 1995 A~$k~ 0il & Gas Cons. Commission Anchorage PLUG #4 Abandon water zone perforations with squeeze through retainer. Capcity of 9 5/8" casing -- 0.0732 bbls/ft Volume required = 164 x 0.0732 -- 12 bbls or 67.4 cuft. Slurry yield - 1.15 No sx -- 67.4/1.15 - 59 Slurry - Class G + 2% A-7 + 0.5 ghs FP-12L Density = 15.8 ppg, Yield - 1.15 cuft/sk PLUG #5 Cut and pull 9 5/8" at 250'. Set a 180' balanced plug in 13 3/8" casing Capacity of 13 3/8"= 0.1497 bbls/ft Required slurry volume - 180 x 0.1497 -- 27 bbls or 151 cuft Slurry yield - 0.961 cuft/sk No sx = 151/0.961 -- 157 Slurry - COLD SET II at 14.95 ppg RECEIVED ~iAR 31 1995 Alaska Oil & Gas Cons. Commission Anchorage 30" 310# NT-60LE Conductor @ 110' MD BADAMI # ". ~-UG AND ABANDONMENi~ MUD LINE L Cement Plug #5: (250' - 70' MD) 157 sx (27 bbls) of 15.8 ppg Class G Slurry 13-3/8" 68# NT-80CHYHE BTC Casing @ 4500' MD Cement Retainer @ 4925' Perforations 4975' - 4989' Cement Retainer @ 5040' Perforations 5040'- 5046' Cement Plug #4: (Squeeze @ 4975' MD) 59 sx (12 bbls) of 15.8 ppg Class G Slurry Cement Plug #3' (5040'- 3500' MD) 440 sx (90 bbls) of 15.8 ppg Class G Slurry 7" Hanger @ 9279' , 9-5/8" 47# P110 BTC-Mod Casing @ 9578' MD TAG PLUG Perforations 10,700'- 10,810' Bridge Plug @ 11,090' Perfora{~ons 11,140' - 11,260' 7" 29# NT-110HS, NSCC Casing @ 11,549' MD Cement Plug #2: (9379'- 9079' MD) 90 sx (18 bbls) of 15.8 ppg Class G Slurry Cement Plug #1' (11,090'- 10,490'MD) 108 sx (22 bbls) of 15.8 ppg Class G Slurry RECEIVED MAR 3 I 1995 0il & Gas Cons. Commission Anchora~;:,? , ¢,~ ~,'~ 1 ~I F 13 ~ I ?: zi t-I I'4 n. FJ t'J 6 P. 0 '1 TI'I: MRR '~' I'f BADAMI #5- FORWARD PROGRAM The tollowi~',g p~ugrar¢, wilt be carried out after drill stem testing nparation~ on ~5. Finat abar~¢~;ment operations will nnt ~¢mm~nc~ until ~he New Developments Manager ha9 given ¢0prnvnl tn ~nrmanently abandurl t~u well, Please contact AOGOC ~tepa rep. prior 1o ~bQnd0nnlont RB they ~re likely w~nt to wiir~ess at leasl some ct the o~r~ti~n. 1, After ~esting the Lower ~onn, ~nt a bridgu plug r'~ f'~Of'e than 50' a~ve the perloratiun, Puffgrate ~nd test the up,er zone, Abandoning The Rn~nrvolr tnte~l. Plug ¢1, According to thn AOGCC ~'egs, the lower zone Can be a~a~doned by ¢lacJn~ a minimum ot 75' ct cement on tap of Jh~} bridge plug. To abandon with a balanced plug mqL~ire~ cemunt fru~n at least. 100' below to 100' above the pedorated info,al, The ~bandonmenl req~Jirnm~nt~ I~r bot~ zones can be met Dy s~ing a 600' b~lanced plug or~ top of ~l~e bridgn plug. Ttfi~; would put cement 200' abovu Ibc 1gp per'luralion. The plug will consist of 15,8 ppg, Clas~ G ~ment, 2. KiI[ the,weli POOH with tt~e test string attur DST¢2, RIH wi[i~ oper, ended tu~ing arm Set a balanced plug Item the bridge plug at 110~0' to 10490'. NO'IP - A[)HIAN T~IINKS TI tATWE MIGHT GET AWAY WITH ONLY VERIFYING ONE OF THE FIRST ~O PLU~8. $bb WHA'f TIlE AOGOC REP THINKS. (a) It the AO¢CC mp don.~ not require the integrity el the plug lg be verified, POOH to 9379' and reveme circulate to clean the pipe. (b) It verification is required. POOH tO 10549' ~nd rovorso oircut~e. This 8hodld remove say contaminated mud and cement, leaving e clean [o¢ !60' ~bove the top perforation. After waiting for plug ¢1 ~ ~at, v~rily tt~e integrity of tho plug by o~thor t~gging it or prn~lire tust~ng to 1000 p~. POOH tg g3?~', I~ying down N~te - Ti~e pre,sure te~t nf I~OQ p..i f.xa(.J.d.~ t.io formation st~e~Jgtl~ at Ihe top purturaligr~, ~ssuming tha~ tl'~e lracture gradient of the rose,git measured in Badami ~1. Aband?,[,ir',g The Liner 'lop, Plug #2. AOGOO rags state,,hthat O.f;~nt ~t[Jb~ taunt be abandoned wlthoa,, balanced plug from at Inapt 10D' h[.l(}w th~ ~;itJb to at lem;t I00' ~buve iL The li~er top witl be abandor~ed wi~h a 250' balanced plug ct 15.5 ppg, Ola~ O cement, giving t50' of cement above the t~nger. Set, a baCancecl plug from 9379' to 9129°, (a) If tho AOGCC rep du~u r~t r~quiru tt~u i~I~grlty ~1 I1,~ plug tU b~ verilied, POOH 10 stands and ruv~r~ ¢iruulu~e to clean It~e tubing, POOH laying d~wn tubin¢, (b) II verification i~ required, POOH io 9150' and reverse circulale, 'l I~is sl~ould remove any conlaminaled mud and cement, ie~vin~ a clean top 130' above tl~e liner top, After w~iting for RECEiVEb f ,!AR 2 8 1-995. 6laska 0il & Gas Cons. Co[~.~S,5~-~-~ ' nch ra§. . ....... ... . ~RS '1 tlr ?: 4':J N n . I-J t'J I.-~ P. t',l plug #2 to set, ver',ly mn intnority of Ihs ptug by either Tagging it ar pressure te~t!ncj to 1000 psi PO~ Inyin0 d~)wn t~:t:ing, WL~tur TuOI Preparalions Plug 4. t"tlI t with ¢.n~in<'j guns on wirolinc and shorn 6' uf ~rf~dl~ns ~t 5050', Monilor the annu!uS tO see If communication can bo vorifiud by fluw from U-tubin..q, Nme - P, tI-{ with ~! cemept l'et~iner nn w~r~l~n~ and ~ei it ~t 5040' PIIl t with 5" drilJpJpe m'd slab into U'm rP.t.qil~r. Circulate through the pu~fu~Lia~'~ to esLalnlish 0irrul~!i0n up the ann~liuG 3nd remove the diesel used for Ireeze proteclion, Pump plug #3 to got oomont 1000' above the 13 3/8" shoe, It ~nnulus communication can nd he edablished, HIH with cos,nO guns 8nd snoot 6' of perforations et 4f170'.. RIH with a oemur'~t re[~{{ner and perform a 'suicide s~um~zu', Followir~g II~e water zone test, th~ ~rfRne ~nnulu~ will l~ave to be abandoned by down~queezifl~ cement Into 11. Ah~ndonin. g The. Aquifer, Plug it,l , The preterred method of .."th~nrlnn~nO ihn wmor zono will be to squeeze rsement into the pedorations, AOG .0,C rngr~ rnquiru that ~ wlumu gl cement equivalent tO tile volume of the casin~ trom ~t~e retainer to 100' below tho hn.nm perloration must be pumped. RtH with a uemef~t retainer an:J dispo, se of any excess mud not required during sub~flu~m eb~nd~nm~.nt, opcmtlon~, Pump plug ~4, vunsit;li~g u115.8 ppg, pipe. Wait for the cemenl to s~t nnd th~n varify th~ Integrity of ttnc plug ~cording to the r~quirements of II~e AOG00 top, POON I~yin~ down drillpipu, Final Abandonment, Pk~g #5. 8, Squeeze cement into the surlace ~nrlulu~, if ii was not abandoned witt~ plug ~3, RIH with a g,~/8" casing cutler lo at least 250'BH 1 (cl~eok c~sing tallie~ th~l cut Nipple down LIOI~ sic, ok (ensure that g..~/R" ~ 1L~ R/P," ¢,nmnnt jr~h ha,,', had ~doqu~to time to set up before commencing this operation,) and lift tl~e upper ca~ing ~pool, Spear into the 9.5/0" s~ub and r~cover the c~ng. 10, Push a tn-3/B" cement wiper plug to 250' BF~T, Fill rhe t3 3/1~" casing from ~O'B~'t' to 70' BnT (~pprnx ~0' hMlow the M[Jd line) wifl~ Dlug ~5, ool~si3til~g of 14,fib ppg, ~OLD~ET II aemur~t. Statu,Ruy~; ruqu re t'e ~bmdonment surface cen'lenl plug to be at least t 5' below tine mud line and be of et least 150' length, '1'1, Remove base plate and cement from cellar. Cut i 3 3f8" and 30"casing just below the bdtom d the 48" pipe, '10 BP_ CON IlNUI:::D. Alaska Oil & Gas, Co~s. Go~,~,~ssV:?~ CEMENT DETAILS M Rf'g' ';'8 ' ':J.~ Pl..tiC #1 ¢,00' t'~lnn~d pltJg nI,,t r~r'~ top of lhu 7" b~idgt~ plug al 11 .ogo'. Volume of 7" liner= 0,03/1 bbJ~/~, Required ¢lur~ voJllme _ 600 x 0,037 i ,. 22,3 bbis or 125 curl, Sl~rry yield = 1.153 cutt/Sk No. ~x = 125/1,153= I08 Slurry Ctass G ~ 0,35% FL-52 + 0.8% CD-32 -.. 0.03% R-1 .~. 0.5 gl'm FP,121 Density - 15.8 ppg, Yield _ 1.15:3 ci/~r, Mix Wnmr = 4.94 Opt, 'I hickening limo = ~.',~0 - 4,00 hrs, Fluid Los~, = <150 cc, BHCT -.- 145~F ?: 4':l Nn. I"JL"JL5 F". L-J3 PI..LJO #2 250' balancec~ plug acro$~ 9.5/8"× ?" liner [ap. Volume ct 100' of 7" casing = 3,7 bbis or' 20,8 cult, Vululnu ol 150' of 9 5/8" casing .-. lbo x 0,0'/32 - 11 t~bls or 6'~ .6 cuff. I tequited slurry volJimn = ~2,4 Slurry yinJd = ,1, tS2 r-.uft/sk No sx - 82.4~1,153 = 72 Slurry Class f,~ + 0,3% PL-52. O,b% 0[3.32 + ?? A2 + 0.5 9hs FP-12L ben,~lty ,. 1~,8 ppg, Ylold = 1,153 r;f/sk0 Mix W~¢,u~ ,.- ,1.94 gps Thid~enlng Timo = 8,30 - 4,00 IJm, BHOT =, 125'~F TO BE CONTINUED, I NEED TO CHECK WHAT SLURRY WE NEED FOR THE SQUEEZE JOBS. ,~UFY~].~I- £1k':L 1'-14)4 BADAj' .30" :tl O# N I ,GOLL ~ C;0nd[mtor @ ~ !0' MD ,-,-3 8 68¢ N'I-BOCHYHL Cement Retainer 4975' - 4]89' ~m~m Retnln~r 5040'- 50'~6' Ii): :...P.L.U.~ AND ABANDONMENT MIJD_.L.~E ..................... ¢':UU No.OOb P.04 ¢~ 5/8" 4 7¢; P110 NSCC Casing ~ 9578' MD Cement Plug #2' (9379'. 9129' MD) 72 sx (15 bbJs) of 15,8 ppg Cia. ss G Slurry I'erf0rStion8 t 0.?00' - 10,810 .... ~ Porforat,Ol'm 112,60' Tn~ plu¢l with 10KIb5 ?" B2# NT.96H$, N,~CC Ce$ing ~ ' 1,805' MI.) Cemenl Plug #1' (11,090' - 10,490'MD) 108 sx (2.2 bbls) of 15,0 ppg Class MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~~ Chairman -->' DATE: March 28, 1995 THRU: Blair Wondzeil, ~,~ FILE NO: P. I. Supervisor ~/~t~' FROM: John Spauiding~ ~ SUBJECT: Petroleum Insp P9NLC1CD.doc Plug & Abandonment BPX / Badami #5 Exploration PTD 94-161 Tuesday March 28~ 1995: I witnessed the plug and abandonment, of the perforation interval at BPX's Badami #5 wildcat well. The AOGCC Plug And Abandonment Report is attached for reference. The perforation intervals are located at 11,260' md to 11,140' md and 10,810' md to 10,700' md. The plug and abandon program called for placing a cement retainer between the perforations at 11,090' md, and cementing over the top set of perforations to a depth of 10,600' md. No cement was to be placed below the cement retainer. Prior to placing the cement plug over the top set of perforations, the cement retainer was tagged with 25,000 lbs. of driilstring weight to verify depth and integrity. A cement plug of 22 bbls. sufficient to cover the perforations and up hole approximately 250' was pumped through 3.5" tubing. The cement was allowed to cure for 12 hours after pumping. After alloWing the cement to cure an attempt was made to tag the cement above the perforations, the solid cement was finally located at 10,722' md or 22' into the perforations. This led the BPX drilling engineer (Mark Stanley) to believe that the perforations took all the cement, a 1400psi test was performed, after 5 min. pressure bled to 1200psi and held for 30 min. This pressure test indicated that the bulk of the cement may have went into the formation. Another batch of cement was mixed, enough for a column of 900' above the perforations. Again this batch of cement was placed through 3.5" tubing and allowed to cure for a period of 12 hours. This batch of cement was located at 10,397' md and 25,000# was set on the plug twice to verify depth and integrity. The depth of 10,397' md allows for 303' of cement above the perforations to be consistent with AOGCC regulations. Between cement jobs I spoke to the rig mud engineer and he informed me that during and immediately following the first cement placement the pH of the drilling mud decreased from 7 to 3 ( very acidic ). Additives were placed in the drilling mud to bring the mud to a normal pH of 7 prior to the second cement placement. Following the the second cement plug no measurable change in pH was' noted. During the 2 day period that I was at the rig attempting to witness the perforation' P&A, Nabors Drilling performed two separate drills; 1 BOPE drill and 1 fire drill in the boiler room. I to spoke Don Dubois Nabors tool pusher to see if these drills were performed for my benefit or if this was company policy. He informed me that Nabors company policy requests that these types of drills be performed at least 2 times per week. Summary: I witnessed the successful P&A of the perforation interval on BPX's Badami #5. Attachments: P9NLC1CD.XLT STATE OF ALASK~I ALASKA OIL AND GAS CONSERVATION COMMISSION Plug And Abandonmsnt Report Operator: BP Exploration Well Name: Badami #5 Operator Rep.: Mike Whitely PTD No.: 94-161 Lease No.: Well No.: 5 Sec. T-R S5, T9N, R20E Total Depth: 11,549' Elevation: Date: 3/27/95 Meridian: Umiat Mud Wt.: ppg. CASING DATA: Drive Pipe: O.D." Set 6: Conductor: 30 O.D." Set 6: Intermediate: 9 5/8 O.D." Set 6: 1. Open Hole Plugs: ft. With 110 ft. Surface: 13 3/8 9578 ft. Prodctn: 7 PLUGGING DATA: Penetration O.D." Set 6: 4500 ft. O.D." Set 6: 11,605 ft. 2. Open Hole Isolation Plugs: 3. Perforation Plugs: Perforation intervals located at 11,260' to 11,140' and 10,810' to 10,700' 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: REMARKS: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet Distribution: odg - Well File c- Operator c - DNR/DOG c- Database c - Rpt File c- Inspector Inspector (s): John H. Spauldin~l FI-000 (Rev. 3/93) P9NLCICD.XLT To: State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Sflvemdo Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process Depth Start Process Date Start Process Depth Process Date End Total Number of Samples Included in this SMpment Shipment Number '~1~-- 5631 Silverado Way, Unit O, Anchorage AK 99518-1654 ® (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company To' State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Atto: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From' BP Exploration (Alaska) Inc. Badami #5 See. 5, T9N, R20E AP! #50-629-22533-00 Shipment Includes: Process Depth Start ~ ! 5'2.0] 115~ altc l.qS' Total Number of Samples Included in this Shipment Shipment Number ~ I~ Process Depth End ~15~I I~w'D~O'~D 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company ORII--L-I N G SERVICES To: State of Alaska (AOGCC) Arm: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 ~~//-~&. // From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silvemdo Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried Froml BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start / Process Date Start Total Number of Samples Included in this Shipment Shipment Number Process Depth End //0/0 ff~//~O ~o~ D~t~ ~.na >/~/b.~ 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company State of Alaska (AOGCC) Attn: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Att_n: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From; BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process Depth Start / & ~L O/~ O?]t_~ t3 ' Process Date Start ,[-~/~ /? ,5' Total Number of Samples Included in this Shipment ./ Shipment Number Process Depth End,, Process Date End 5631 $ilverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company To: State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Att_n: Steve Carroll 5631 Silvemdo Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start Process Date Start Process Depth End Process Date End Total Number of Samples Included in this Shipment Shipment Number 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company r'l I::! I I--I--I I~1 Oi SEI::I~,~ I C E S To~ State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Comact No. B5#6 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start ?~;~c~"~./~7~ 0 Process Date Start....c~ ~5/~5 Process Depth End .,f~/~.'f~./J~o Process Date End ,~ ~ Z/g~q' Total Number of Samples Included in this Shipment Shipment Number -~dt7 5631 Silvemdo Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company To: State of Alaska (AOGCC) Att_n: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process Depth Start Process Date Start Process Depth End ,..~9L~O ~ ~)~ Process Date End ~/~"][ ~'- Total Number of Samples Included in this Shipment Shipment Number 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company r'l R I I--I--I N Oi SERVICES To: State of Alaska (AOGCC) Attn: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Atto: Steve Carroll 5631 Silvemdo Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start '~ J' ~ 0 Process Depth End Process Date Start ~/~q?. t9 / 6] 7 Process Date End Total Number of Samples Included in this Shipment ~;~ ~ Shipment Number ~ 5631 $ilverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ~TATE PIPELINE COORDINATOR'S OFFICE · Department of Environmental Conservation [] Department of Natural Resources [] Department of Fish and Game February 13, 1995 411 WEST 4th AVENUE, SUITE 2C ANCHORAGE, ALASKA 99501 PHONE: (907) 278-8594 (907) 278-8595 FAX: (907) 272-0690 Letter No.: 95-013-RK File No.: 0900.45.010.7BL Mr. Peter T. Hanley BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 RE: Annular Injection Permit for Badami Appraisal Wells #4 and #5; Permit Authorization Number 9240-DB002-7BL; Receiving Zone Information; Review On February 10, 1995, this office received your submittal of information regarding the receiving zones of Badami appraisal wells #4, and #5, as required in the Department's injection authorization letter of November 9, 1994. According to your submittal, BP Exploration (Alaska) inc., has evaluated the proposed receiving zones and has determined the zones to be adequate to manage the injection fluids. Based on this information, the Department is authorizing the commencement of injection for these wells. Authorization for commencement of injection is constituted by this letter. The exact bottomhole location will not be determined until the wells reach the total depth drilled. This information can be provided in the report required in section IV of Permit, once the exact bottomhole location has been determined. If you have any questions, please do not hesitate to contact Mr. Ralph Kiehl of this office at 271-3649. Sincerely, C_~Tom ~/h~ppl~e <J~/.;~/.~ Regional Administrator Pipeline Corridor Regional Office TC: RK: (PCRO c:\rnlphk\work\95013.rk cc: Tuckerman Babcock, AOGCC Tim Law, PCRO/Anchorage Kalu Kalu, PCRO/Fairbanks Bit & Gas Cons. Gomm'~sgon Anchota ,e MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johnst~ Chairman' ~ Blair Wondzell, ~ P. I. Supervisor zle~ FROM: Bobby Fost~?'-~-~C SUBJECT: Petroleum Inspector DATE: February 20, 1995 FILE NO: A7NIBTCD.doc BOPE Test - Nabors 18E BPX - Badmi # 5 - Exploratory PTD # 94-161 Exploratory Location Monday, February 20, 1995: I traveled this date to BPX Badmi # 5 being drilled by Nabors rig 18E and witnessed the weekly BOPE te~t. As the attached AOGCC BOPE Test Report shows there were 3 failures. The choke line HCR valve leaked - the valve was greased, cycled and retested OK. The dart type floor safety valve leaked and the lower kelly valve leaked. Both valves are to be replaced / repaired before running the DP in past the 9.625" casing shoe. The rig was clean and all of the equipment seemed to be in good working order. The location was clean and all extra equipment was stored properly. Summary: I witnessed the weekly BOPE test on Nabors rig 18E drilling BPX's Badmi # 5 - test time 5 hours - 3 failures. Attachment: A7NIBTCD.XLS NOTE: i was notified by Don Dubois at 11:30 PM - 2/20/95 - that both valves had been repaired and tested OK. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPB Test Rcpor~ X OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial Workover: NABORS Rig No. 18E PTD # 94-161 BP Exploration Rep.: BADAM! # 5 Rig Rep.: Set @ 9657' Location: Sec. ~ Weekly X Other DATE: 2/20/95 Rig Ph.# 659-2819 NiCK SCALES DON DUBOIS 6 T. gN R. 20E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves 3 Check Valve ' 0 Test Pressure P/F 250~3500 P I 250~7500 P 1 250t7500 P I 250t7500 P 1 250~7500 F/P 2 250t7500 P 250~7500 N/A P N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK . Pit Level Indicators OK OK ,~ , Flow Indicator OK OK Methane Detectors OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250~7500 P I 250~7500 I 250t7500 I 250%7500 F/P CHOKE MANIFOLD: No. Valves 16 No. Flanges 42 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 250~7500 P 250~7500 tested tested ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 8 ~ 2'100 3,000 ] OK 1,300 'OK"' minutes 42 sec. minutes 14 sec. OK Remote: OK Psig. Number of Failures: 3 ,TestTime: 5°5 Hours. Number of valves tested 29 Repair or Replacement of Failed i Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 I=,pecto£Nortl~Slot~ePagerNo. 659-3(~7 er 3657 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: FAILURES: The choke line HCR valve leaked - greased, cycled and retested OK. The Dart type floor safe~ valve leaked and the lower kelly valve leaked - both are to be repaired, tested and the ^OGCC inspector notified w~th in 24 hours. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/93) A7NIBTCD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston. Chairma~ THRU: Blair Wondzell, ~ P. I. Supervisor FROM: Lou Grimaldi;/'':'-'-~ Petroleum Inspector DATE: FILE NO: SUBJECT: February 7, 1995 Q7NJBGCD.DOC Rig BOPE inspection Nabors 18-E BPX well Badami # 5 Exploratory PTD # 94-161 Tuesday, February 7, 1995: I traveled to BPX's exploratory well Badami #5 to make a Rig BOPE inspection on Nabors rig 18-E. The rig was just concluded their weekly BOP test when I arrived. Mike Whitely had given proper notification but as weather conditions were bad this day I had opted not to travel in the dark part of the morning. I found all BOPE equipment to be in place and in good condition as I had left it during my witness of the initial BOP test last week. Mike Whitely (Company Rep.) and Bill Bixby (Nabors Toolpusher) were on the rig floor during the BOP test and accompanied me on a short tour of the rig. I checked the insulation and heat trace on the choke lines running to the 10,000 psi choke manifold outside the rig and found them to be complete and operating quite well. Access to the rig was good and the location surrounding the rig was clean and orderly. SUMMARY: I made a Rig/BOPE inspection on Nabors 18-E with all equipment in compliance. Attachments: Q7NJBGCD.XLS. cc: Scott Sigurdsen / Steve Horton (Prudhoe Bay ,drilling) 56q0-5772 ~ c~ e~) QTNJBGCD.XL$ MPS State of Alaska (AOGCC) Attn: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, 'R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start ~ 100 [-Tl{O 0 Process Date Start Process Depth End ~ "/~)/S8¢ Pro°ess .nd Total Number of Samples Included in this Shipment Shipment Number 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Indusuies, Inc. Company C] ICl I I_1_! ~ [3 SEICl~I CEE S To: MPS State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Contact No. B5#6 ~835!1406856~ From: Sperry-Sun Drilling Services Atto: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process Depth Start 2 Process Date Start S-' Process Depth End Process Date End Total Number of Samples Included in this Shipment Shipment Number '~ ~;~ 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company per m -L n r'~ I::~ I I_li I N C3 S IE; R~J I C:: IE== To: State of Alaska (AOGCC) Attn: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Comact No. B5#6 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP..Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process DePth Start L~~ ~~ Process Date Start Total Number of Samples Included in this Shipment Shipment Number Process Depth End 5.~/~ ~ O Process Date End gq- t?£'CEiv£D FEB 0 '7 1995 Alasl~a oii & cas cons. comml~ion Anchorage 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company C! RI I_!_1 hi [~ S I= I::!~./I CIE S State of Alaska (AOGCC) Atto: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Comact No. B5#6 i 9q-.'zq ¢ 0'z ¢ From: Sperry-Sun Drilling Services Atto: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E AP1 #50-629-22533-00 Shipment Includes: Process Depth Start Process Date Start ~ Total Number of Samples Included in this Shipmem Shipmem Number Process Depth End 3~//-~0 oo ss at Zo Alaska Oil & Gas Cons. Commission Anchorage .. 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company To; MPS State of Alaska (AOGCC) Attn: Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Comact No. B5#6 I Sh~. ~1 From: Sperry-Sun Drilling Services Atto: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried F~om: BP Exploration (Alaska) Inc. Badami #5 Sec. 5, T9N, R20E API #50-629-22533-00 Shipment Includes: Process Depth Start P~oo~s~ ~at~ Start ~/q / ~ Total Number of Samples Included in this Shipment Shipmem Number Process Depth End 19 O0 200C) Process Date End 2{(O/SS RECEIVED FEB 0 7 1995 illaska 0il & 6as 8oss. CommiSsion Anchorage 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (90.7)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO: THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 30, 1995 FILE NO: A7NJA4CD. DOC FROM' Lou Grimaldi;~'(%",,, SUBJECT: Petroleum Inspector BOP test / Rig inspection Nabors #18-E BPX Badami # 5 PTD # 94-161 January 27/28,1995: I witnessed the rigup and testing of the 10,000 PSI BOPE on Nabors rig 18-E which was preparing to drill BPX exploratory well Badami # 5. The test was originally scheduled for Friday the 27th but the cement job on the 13 3/8 casing did not reach surface and a top job was required. A 390 bbl. cap was placed from the top side of the 13 3/8 annulus. The following day assembly of the 10,000 PSI BOPE was began and as the weather was still bad I opted to stay on location and observe this procedure. All equipment was inspected for worthiness before assembly, this included opening the doors on the BOP stack and checking the rams. A problem occurred during the rigup of the 10,000 PSI choke assembly, it seemed that there was a mismatch of flanges on the choke and return line components which consisted of 3 1/16 10,000 and 4 1/16 10,000. This was a major obstacle that was compounded by a inability to locate the proper equipment on the slope. The proper equipment was finally found buried in a snowbank and was rigged up. Sunday January 29, 1995: The test was started this morning while the choke system was still being rigged up. A Iow/high test of 350/7500 psi was put on all BOPE with the exception of the annular preventer which was tested to 350~3500 psi. The entire Kill system was tested from the mud pumps through the standpipe. There was a small leak from the doors on the bottom set of pipe rams which stopped after retightening the bolts. A full performance test was performed on the accumulator which consisted of a closure of the Annular preventer and opening of the HCR valve by pump only (1 min., 57 sec), a check of the accumulator bottles, and a recharge test that showed the accumulator was in satisfactory shape. The high pressure bypass was selected remotely from the rig floor and 3000 psi was admitted to the accumulator manifold and held successfully. The choke manifold, when ready, was tested with all valves operating smoothly and holding their pressure test of 350/7500 psi. cont. page 2 A7NJA4CD.DOC CONT. cont. from page 1 The 5,000 psi choke assembly downstream of the 10,000 assembly was shutin at its outside valves and was tested along with the lines to 5,000 psi with no leakage observed. Overall considering the test pressures and assembly of new equipment the test went very well. SUMMARY: I witnessed the initial BOP test on Nabors 18-E drilling BPX exploratory well Badami # 5. Test time 18 hours, 1 failure. Attachments: A7NJA4CD.XLS CC: Scott Sigurdson/Tom Horten , STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 13 3~8 Test: Initial X Workover: Nabors Rig No. 18E PTD# 94-161 BP Exploration Rep.: Badarni #5 Rig Rep.: Set @ 4,500 Location: Sec. Weekly Other DATE: 1/29/95 Rig Ph.# 564-5772~659-2819 Mike VVhitely Don Dubois 5 T. 9N R. 20E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Pressure 250~3500 250~7500 250~7500 250~7500 250~7500 2 250~7500 3 250~7500 0 N/A P/F P P P P P P P N/A Alarm OK OK OK OK MUD SYSTEM: Visual Trip Tank OK Pit Level Indicators OK Flow Indicator check Gas Detectors OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Ted Quan. Pressure P/F I 250t7500 P 1 250~7500 P 1 250~7500 P 1 250~7500 P CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes Hydraulic Chokes 2 Test Pressure P/F 250~7500 P 36 250t7500 P 1 P tested tested ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 8 Bottles 2050 3,000 1,300 OK minutes 47 sec. minutes 2 sec. OK Remote: OK Psig. Number of Failures: I ,Test Time: 18.0 Hours. Number of valves tested 31 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Drillers side door on bottom pipes leaked at high test tightened and retested "OK", if leaks at next test replace seal. Check heat trace on lines to choke house daily to insure they are operational. Flow meter was not installed at time of test. Good test considering all 10,000 psi equipment newly installed. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R Grimaldi FI-021 L (Rev. 7/93) A7NJA4CD.XLS inspinfo.frm Conductor size: Diverter line size~ Surface hole size: INSPECTION INFORMATION - EXPLORATORY WELLS This form is intended to supply some basic well information that will be useful to the inspectors when inspecting diverter and BOPE systems. Well Name: ~~; ~-- PTD No.: operator: .... Surface Casing size: l~ and weight & grade: Surface casing BOP size: /3~ , Pressures - WP/TP: Intermediate hole size: ~'¥~ ~ ~ Prod casing size: 9~//~}~ and weight & grade: Prod casing BOP size: ~ , Pressures - WP/TP: Liner hole size: "~' Liner/casing size: , ,~ Liner/casing BOP size: and weight & grade: ~= , Pressures - WP/TP: --- Hydrogen Sulfide Measures: _~ of Alaska MEMORANDUM ska and Gas Conservation Commission a Oil TO: David John~ DATE: January 20, 1995 Chairman - / TRRU: Blair Wondzell, ,/~[<~x FILE NO: P. I. Supervisor FROM: John Spaulding, ~'~ SUBJECT: Petroleum Inspedtor E9NLATCD.doc Diverter Function Test Nabors 18E / Badami 5 BP Exploration PTD# 94-161 January 20, 1994: I traveled to BP Exploration's Badami #5 an exploration well to inspect and witness the Diverter Function Test on Nabors 18E. As noted on the AOGCC Diverter Test Report all items were in compliance. The diverter vent line is 10" in diameter and 100' from the rig and ignition sources. The ice pad is well arranged and the rig is positioned to take good advantage of the prevailing wind directions. Summary: I inspected and witnessed the Diverter Function Test on Nabors 18E with no failures. Attachment: E9NLATCD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Operator: Well Name: Location: Sec. Nabors BP Exploration Badami #5 5 T. 9N R. Operation: Development Rig No. 18E PTD # Oper. Rep.: Rig Rep.: 20E Merdian Umiat Exploratory: 94-161 Rig Ph. # Nick Scales Don Dubois XXX 564-5779 MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: na Well Sign: ok (Gen.) Drlg. Rig: ok Flare Pit: na DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: )/es Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 10 in. Vent Line(s) Length: 100 ft. Line(s) Bifurcated: na Line(s) Down Wind: na Line(s) Anchored: yes Turns Targeted / Long Radius: na ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3000 psig 1500 psig min. 38 sec. 2 min. 5 sec. 8 ~ 2000 avg. psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: x x Mud Pits: x x Flow Monitor: x x GAS DETECTORS: Light Alarm Methane x x Hydrogen Sulfide: x x Wind direction 10"x 100' Vent Line S.W. ~~~i, · ~~20" Diverter North Camp Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - Inspector FI-022 AOGCC REP.: OPERATOR REP.: E9NLATCD.XLS John H. spaulding Nick Scales Nabors 18E Diverter System Rig Floor KSB 1/4/95 Hydril 2000# 10" 150# Actu~ ed Knife Gate Valve [ I I 'i 1.57' from GL, not mat~ GL=O' 20" Diverter Spool with 10" Outlet -F T 3.96' 8.34' 29.2' J~ ~ ,."5" from ~~ [set screw flange to .... s, '~" scr~ 8.3w 30" Conductor Bottom of cella -10.0' ' I! i'!",f' ,-.. z.. ,, , ' I .~' i ~SKA OIL ~ GAS ,,/ 'CONSERVATION CO~HSSION / January 4, 1995 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Adrian Clark, Drilling Engr Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Badami #5 BP Exploration (Alaska), Inc. Permit No: 94-161 Sur. Loc. 3334'SNL, 4770'WEL, Sec. 5, T9N. R20E, UM Btmhole Loc. 786'SNL, 3461'WEL, Sec. 5, T9N, R20E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Based on lack of shallow gas hazards, the Commission approves the variance to casing setting requirements of 20 AAC 25.030 b(2)(3) to allow setting 13 3/8" surface casing to 4500' TVD. Your request for exemption from the requirements in 20 AAC 25.065(c) relating to hydrogen sulfide is also approved. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field er at 659-3607. , David W~ Johnston ~ ~ BY ORDER OF }{MISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION To' Fro m: Robert P. Crandall Sr. Petroleum Geologist Alaska Oil & Gas Commission Adrian Clark Drilling Engineer Supervisor Shared Services Drilling Date' 12/16/94 Subject: Exploratory_ Wells B~dami #4 & #[; Point of contact for the exploratory wells Badami #4 and Badami #5 will be myself, Adrian Clark, Drilling Engineer Supervisor, Shared Services Department, 564-4720. In the event that I cannot be reached you may contact Tim Schofield, BPX Drilling Engineer, 564-5242. YoUrs Sincerely,,~ ,~'drian Clark CC. T. Schofield M. Stanley Well file RECEIVED DEC 1 9 1994 Alaska.Oil & Gas Cons, Commission Anchora,~'0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill~_[lb. Type of well. Exploratory[] Stratigraphic Test [] Re-Entry [] Deepen Service [] Development Oil [] 2. Name of Operator BP Exploration 3. Address P. 0. Box 196612. Anchorage. Alaska 99519-6612 4. Location of well at surface 3334' SNL, 4770' WEL, SEC. 5, T9N, R20E At top of productive interval 1114' SNL, 3629' WEL, SEC. 5, TgN, R20E At total depth 786' SNL, 3461' WEL, SEC. 5, TgN, R20E 12. Distance to nearest 113. Distance to nearest well property line , ADL 367006-786 feet No close approach feel 16. To be completed for deviated wells Kickoff depth 4soo feet 18. Casing program Maximum hole an~/le ~ o Development Gas [] Single Zone [] Multiple Zone [] 5. Datum Elevation (DF or KB) KBE=33.5' feet 6. Property Designation ADL 367011 7. Unit or property Name Badami 8. Well number Badami #5 9. Approximate spud date 1/15/95 14. Number of acres in property 2533 10. Field and Pool Wildcat 1 1. Type Bond(r~e 20 AAC 25.025) Number 2S100302630-277 Amount $200,000.00 15. Proposed depth (MD and TVD 11450' MD/lO600' TVD feet 17. Anticipated pressure (see 20 AAC 25,035 (e)(2)) Maximum surface 5~r~O psig At tOtal depth (TVD) 10600'/~)0 psig s~ze Specifications Hole Casing . Weight I Grade I Coupling 42" 30" 157# J ERW J Weld 16" 13-3/8" 68# J'vr~oc~I BTC 8-1/2" 7" 29# I ~r.,o~s I NSCC 19. To be completed for Redrill, Re-entry, and Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation depth:" measured true vertical J20. Attachments Filing fee [] Setting Top Length M D TVD 100' 30' 30' 4500~ 30' 30' 9670' 30' 30' 1900' 9550' 8970' . Deepen Operations. Depth Bottom MD I TVD 130'I 130' 4530' I 4500' 9700' I 9100' I o oo, Quantity of cement (include stage data) 230 sx PF "C" 800 sx PF "E"/370 sx "G"/250 sx PF "C" 820 sx Class "G" 230 sx Class "G" feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True Vertical depth RE£F. IVED DEC '~ 4 1994 Property plat [] BOP Sketch [] Gas Cons. Commission Anchor[ ~ , Diverter Sketch [] Drilling program[] IDrillin9 fluid pr°gr~m [] Time vs depth,plot [] Refraction analysis[] Seabed report l-'l cert.,J4¢¢ t,h'at the ,fgr,.,egoin.q,,/'s true and correct to the best of my knowledge t21. I hereby 20 AAC 25.050 requirementsl-1 ~ Signed ~, t/';' ~"'~ TitleDrillin~IEn~lineerSu. ervisor / I Commission Use Only iPermit Number IAPI n.J,J, mber IApproval date JSee cover letter ~'~'-/~/ J50-¢::~ 2_. ~.- .Z.~...._,A'..,~..~ J /.-"'~'~'-~,,..~.'"' Jfor other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey requ~rea J~ Yes [] No Required working pressure for BOPE []2M' r-13M; 1-15M; ,I~].1OM; 1-115M; /~ Other: Original Signed By by order of =Approved by David W, ;J0hilst0[I Commissioner zne commission Date -orm 10-401 Rev. 12-1-85 Submit i~ fri[ari~,at~ WELL PLAN WELL: Badami #5 LOOATION: Surface' Target: T.D.: 3334' FNL 4770' FEL Sec 05 T09N R20E 1114' FNL 3629' FEL Sec 05 T09N R20E 567' FNL 3348' FEL Sec 05 T09N R20E ESTIMATED START: Mid. January 1995 OPR. DAYS TO COMPLETE: CCAITRACTOR: 66 days (46 days drill, core and log; 20 days testing) Nabors #18E MAX ANGLE/AZIMUTH/KOP/BUILD/MAX DEP: 31°/27°/4650'/2°per100'/3107' Ice pad elevation will be approx. 4' AMSL. KB to ice pad elevation is 29.5'. EXPECTED PORE PRESSURES AND FRACTURE GRADIENTS: Moderate overpressures have been encountered in all wells drilled in the Mikkelsen Bay area. At the Badami #5 location the following pore pressures and frac. gradients are expected to be encountered. Depth ('TVDBRT) Strata/Casing Point Pore pressur~ (ppg EMW) 0' - 4500' Upper Brookian 8.5 4 5 0 0' 13-3/8" casing shoe 8.5 4 5 0 0' £91 0 0' Upper/Middle Brookian 8.5 --> 10.5 91 0 0' 9-5/8" casing shoe 1 0.5 9100'-10600' Middle Brookian 10.5 --> 12.0 Fracture Gradient (ppg EMW) 12.0-->14.0 15.5-->16.5 Top of overpressure is expected at 9000'TVDBRT although there is a potential for it to occur as high as.8,200'TVDBRT. Based on Badami #1 and #2 DST information, a reservoir pressure of 11.8ppgEMW is expected .in the Badami Sand interval. CASING PROGRAM: LC)C-~ING PFtOGRAM: O0en Hole- 16" Hole: 1 2-1/4" 8-1/2" Hole Hole' E-line: DIFL/GR/LSS/CAL MWD' Gamma Ray & Resistivity fm. 6200'TVD E-Line' D IFL/MAC/SPECTRA-G R ZDL/CNL/GR/CAL FMT/GR (optional) MWD: Gamma Ray, Resistivity & Density E-line: DIFL/MAC/SPECTRA-GR ZDL/CN L/DI EL/G R/CAL FMT/GR DIPMETER/CIBL/GR VSP (option of running in cased hole) Cased Hole CBL will be run if DST is to be performed RECEIVED DEC 1 4 1994 Alaska Oil & Gas Cons. Commission PROPOSED DRILLING PROGRAM WELL: Bedemi #5 A sea-ice road extending from the Endicott causeway to Mikkelsen Bay will be constructed in Dec '94/Jan '95. Badami #5 will be drilled from an ice-pad built in 4- 5ft of water depth approx. 1500' offshore in Mik. Bay. Nabors #18E will move from Prudhoe Bay Unit development drilling operations to the Badami #5 well-site as soon as the ice-road and pad have been completed and are capable of supporting the rig loads. Drilling Operations: The well cellar excavated before the rig arrives on location. So long as timing permits, the conductor hole will be pre-drilled and 30" conductor set and cemented before the rig's arrival. Move in, rig up. Accept rig for operations. Nipple up diverter and function test same. Directionally drill 16" hole to casing point. Full mudlogging facilities will be on location from spud to TD. Run logs. Run and cement 13-3/8", 68# casing to surface. Perform cement top-job if no cement seen at surface on primary cementation. A letter was submitted to the AOGCC dated 11/19/94 requesting a waiver from Reg. 20AAC25.030(b) for this well. A copy is enclosed with this permit application. Install blowout prevention equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and 5,000psi annular preventer. The initial BOPE test of 10M equipment will be conducted to 7,500psi; subsequent tests will be conducted to maximum surface pressure anticipated in the current hole section. A diagram of the 10,000psi BOP stack is enclosed. The diverter and mud system schematics will be consistant with those on file at the AOGCC for Nabors #18E. Maximum anticipated bottomhole pressure is 6500 psi (11.eppg EMW) at 10,600' TVDBRT. This information is based on offset well data and seismic-data interpretation. Maximum anticipated surface pressure is 5440 psi based on a gas column to surface from 10,600' TVDBRT. The transition from normal to abnormal pressure gradient is prognosed at approximately 9000'TVDBRT although there is some potential for it to occur as high as 8200'TVDBRT. Formation leak-off tests will be performed 10' below the 13-3/8" and 9-5/8" casing shoes. Directionally drill 12-1/4" hole to approx. 9700'MD (9:I00'TVD). Hole section TD will be based on geologic pick of the MBK90 marker formation. Run logs. Run 9- RECEIVED 5/8", 47#, casing string to within 10' of 12-1/4" TD and cement with Class G cement. The annulus will be used for injection of waste fluids and freeze protected. Drill and core 8-1/2" hole to TD. At core point the drilling mud will be changed out for a specialized coring fluid to aid core petrophysical analysis. Run logs. A decision to run 7" liner will be based on Icg information. If the liner is run it will be cemented using Class G to above the 9-5/8" shoe. Log and core data will be used to determine whether any drill stem tests are performed. DSTs will be conducted with the rig on location. Fluids produced from the well will be either re-injected back into the formation or the 9-5/8" x 13-3/8" annulus or transported to Endicott production facilities. Fluids and cuttings incidental to the drilling of the well will be transported for injection into the Prudhoe Bay Unit CC-2A disposal well or injected on-site down the 13-3/8" x 9-5/8" annulus once available. The well will be abandoned with the appropriate plugs and markers according to AOGCC regulations. The pad will be cleaned up of any surface debris. The nearest'°ffset well is over ~ mile away, hence no close approach data is included in this package. Offset well information indicates no H2S or CO2 gas will be present in Badami #5. The drilling fluid program and surface system will conform to the reguations set forth in 20AAC25.003. Drilling Hazards Shallow gas is not expected, however its possibility cannot be ruled out on any exploration well. Proper hole monitoring and hole fill techniques must be employed on every trip out of the hole. ,...__ ~The presence of overpressure is expected. Full gas measurement and pore pressure estimation mud-logging services will be used for the duration of the well. 9-5/8" casing will be set well before drilling into the Badami sand interval. Tight-hole has been encountered in the 3500'-5000'TVD section on offset wells. Hole conditions will be evaluated and appropriate remedial actions taken if neccessary prior to running logs and casing. REQUEST FOR EXEMPTION TO HYDROGEN SULFIDE REQUIREMENTS - 20AAC 25.065(C) BP Exploration (Alaska) Inc as operator of the Badami #5 well requests exemption to the hydrogen sulfide requirements of 20AAC 25.065 (c). Offset well information indicates that there is no hydrogen sulfide gas present in any of the formations that the well will be penetrating. Even though no formations which the Badami #5 well will penetrate are expected to contain hydrogen sulfide, the Nabors 18E rig being used is equiped with H2S monitors at the' shale shakers, bell nipple and rig floor. Audible and visual alarms from these monitors are in place. The rig is equiped with six Scott Airpacks in the rig-floor area as standard equipment. All personnel on location will be trained for emergency procedures in the presence of H2S as standard operating procedures. It is not deemed neccessary by BP Exploration to develop a further contingency plan. Memorandum To: Blair Wondzell, AOGCC 3001 Porcupine Drive, Anchorage, AK 99501 Date' 11/19/94 From- Adrian Clark Engineering Supervisor Tim Schofield Drilling Engineer Subject: PERMIT WAIVERS FOR BADAMI #4 AND #5. ,. This memo follows uP a telephone conversation between Mark Stanley and Blair Wondzell discussing the 1995 Badami drilling program. It is intended that two wells, Badami #4 and #5, will be drilled from ice pads constructed in shallow water about half a mile from the shore of Mikkelsen Bay. .CONDUCTOR CASING IN OFFSHORE WELLS State regulations 20 AAC 25.030 '(b) - (2) and (3) require that conductor casing be set between 300' and 1000' below the mud line and that a formation leak- off test be performed below the casing shoe. These regulations are intended to ensure that an influx from a formation above the surface casing point could be contained. It is requested that a waiver to these requirements is granted for the Badami #4 and #5 wells for the following reasons' a) Minimal Risk Of Influx Above The Intended Surface Casing Depth Of 4500' Neither interpretation of seismic surveys in Mikkelsen Bay or studies of open hole logs and mud/cuttinas oas Ioas from th~. R~ci~mi .~1 b) Lack Ot Competent Formations Above 1000'. The lithology above 1000' will consist of unconsolidated, coarse gravels, coarse sands and some soft mud. It is most unlikely that these formations could provide a strong enough shoe to enable an influx to be shut in with a BOP stack. The proposed well plan for Badami #4 and #5 will be for 30" structural casing to be set at least 100' below the mud line. A diverter will be installed and function tested on the structural casing. 16" sudace hole will then be drilled to the 13 3/8" casing setting point at approximately 4500'. No leak off test would be conducted below the 30" shoe. Please call Adriar~ Clark (564-4720) or Tim Schofield (564-5242) if you have any questions. Clark Engineering Supervisor BP Exploration Date Tim Schofield Date Drilling Engineer BP Exploration MUD PROGRAM: Badami #5 MUD SPECIFICATIONS- $1,JRFACE HOLF Sudace; Casing point; Mud Weight: ppg 8.5 - 9.8 9.5 - 9.8 Funnel Viscosity sec/qt ~300 < 150 YP Ibs/100ft2 50 - 70 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 60 - 80 20 - 30 'pH 9 - 10 9 - 10 APl Fluid loss mi/30 min 15-25 10-15 Solids % <8 MUD SPECIFICATIONS- INTERMEDIATE HOLF Sudace casing shoe to 9-5/8" casing point: LSND Gel/Polymer System Mud Weight ppg 9.0-10.5 Yield Point lbs/100ft2 5 - 15 Plastic Visc. 6 - 20 APl Fluid Loss mi/30 min 10 - 6 pH 9.5 Solids % <1 0 MUD SPECIFICATIONS-PRODUCTION INTERVAL' Regular Mud Coring Fluid Mud Weight ppg 12.0 - 13.5 12.0 - 13.5 Yield Point lbs/100ft2 10 - 20 25 - 35 Plastic Viscosity 15 - 25 45 - 55 APl Fluid loss mi/30 min 4- 8 4- 6 pH 9.5 - 10.5 7.5 Solids % 15 - 25 15-25 Pore pressure prediction techniques and observation of hole conditions will be used to increase mud weight in line with increases in bottom hole pore pressure. Keeping a safe overbalance of +/- 200psi is planned, this equates to a mud weight approximately 0.4 ppg over pore pressure EMW at 10,600'TVD 2OOO 4000 60O0 8000 10000 12O0O BADAMI #5 Anticipated Pore Pressure, Frac Gradient Plot ppg EMW 8 9 10 11 12 13 14 15 16 17 ........................... Pore Pressure I~,~. .......................... Mud Weight ,, , it --,---e -----Fracture Gradient \ -- \ \ _ \ · . .... --- ~:~ ~_.._, ...... 1i - DEC 1 4 199~ , ~ ~. )~ & (as Co, s. Co~]missi~}n _ ~ J/ A~chor~,, CASING SIZE: 13-3/8" 13-3/8" SURFACE CASING CEMENT PROGRAM CIRC. TEMP 70°F SPACER' 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE' Permafrost Type 'E' WEIGHT: 12.0 ppg APPROX #SACKS' 800 YIELD:2.15 ft3/sx THICKENING TIME: 5:30 hrs MIX WATER' 11.5 gps TAIL CEMENT TYPE: Premium Class 'G' with 2% CaCI ADDITIVES: As Required WEIGHT: 15.9 ppg , . APPROX #SACKS: 370 YIELD:1.15 ft3/sx THICKENING TIME: 4 hrs MIX WATER: 4.9 gps TOP JOB CEMENT TYPE: Permafrost Type 'C' ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD:0.95 ft'3/sx APPROX #SACKS: 250 MIX WATER: 3.68 gps CEMENT VOLUME: 1. Lead slurry to sudace 2. Tail slurry to 500' above shoe with 100% excess (based on theoretical gauge hole volume) 3. Top job volume 250 sx. RECEIVED DEC ~4 199~ Alaska 0il & Gas Cons. Commission Anchor~,. ,. 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM CIRC. TEMP: 160cF SPACER: 50 bbls Dual Spacer TAIL CEMENT TYPE: Class 'G' ADDITIVES: 0.2% CFR-3+ 0.2% Halad 344 +-0.2% HR-5 WEIGHT: 15.8ppg YIELD: 1.15ft3/sx APPROX #SACKS: 820 THICKENING TIME: 4.0 hrs MIX WATER: 5.0 gps CEMENT VOLUME: 1. Cement upto 2000' above shoe with 30% excess on intergrated Icg caliper volume (or 50% excess on theoretical hole volume if Icg not available) RECEIVED DEC 1 4 1994 OJJ & {}as Cons. Commissior~ Anchor~., .? ClRC, TEMP 180©F SPACER: 25 bbls Dual Spacer. 7" LINER CEMENT PROGRAM CEMENT TYPE: Class 'G' ADDITIVES: 0.25% CFR-3 + 0.35% Halad 344 + 0.2% HR-5 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 240 THICKENING TIME: 4 hrs total MIX WATER: 5.0 gps LINER o CEMENT VOLUME: Open hole integrated log caliper volume+ 20% excess. 7" x 9-5/8" annular volume (150' overlap) DEC 1 4 1994 ~taska 0il & Oas Cons. Commission I PRUDHOE' BAY DRI_LIN oUP · iiii i ! ii i i i i i , , , iii i i · · ii · _ i i i <KB> o 600- ..... ~i ~' ,, ; -secl UAUAMJ. ~D /HUd/ I i VERTICA. L SECTION VIEW I Lion at: I I : , !TVD Scale.: 1 inch = ~1200 feet ', , . Oep Scale.: 1 ihch 1200 feet I , i I ' I .... h ....... I ....... J. .. ' , ,, , ~ .. . ~nadrJ.]] Sch]umb~rger ; Marker IOent~ficat~.on MD BKB SE~TN ~NCLN .. ~ i A) KB : 0 0 0 0.00 B) KOP BUILD ~/~00 2t00 2100 0 C) END OF 2/100 BUILD 3078 ~05~ ~65 ~.57 .......... ~ ................. D} ~2-3/B' CA~NG ~OINT ~6~3 ~53~ GgO ~B.~7 El ~-5/B' CA~ING POINT ~525 913A 2325 F} TARGET ..... ~0029 9609 2494 ~.57 G) TD 111~7 10634 285B 19.57 [ . ................ i , ,, ... 'iraQI ~LI'Y' p ~N~: .... ...... ~ ...... NC~T A~PRr~O~ ~. :~ - I EXECU'FIOF4 ~ _, ...... ~ ~ ~ , ..,-- I '. i , , ~ .... ~ .. · i · ....... - 1 4 994 "i . .: . ~i~:k=n,~ m~ ~ ................................... ~ ~ ~nchor~"= uummisTT6~' ~2ooL ~8oo- 24001 3000- 3600 K 7800- 8400' 9000- . 9500 JO200 ..... 10800- .-1200 -600 0 600 1200 1800 2400 3000 3600 '~200 7~BO0 5,~00 6000 6600 . 7200 Section Departure ~',a~rill (cie3 ~!~2 ~.52 ~:oo P. l~ ...... S~BBNIgN~ O~a ~) ]]I~UNU WO~ EE:&I ~66I-9~-D~ PRUDHOE M~rZer Identification ~] KB B) KOP BUILD 2/100 C) END OF 2/JO0 BUILD D) ~3-3/8" CASING POINT E) g-5/8' CASING POINT F) ..... TARGET G) TD MD N/S 0 0 2100 0 3078 147 46,13 614 9525 207O 10029 222i BAY D'IRI E/W 1058 1300 T~ 'LING iiiii i _ __ BADAMI CLOSURE ' DECLINATION.' SCALE ' DRAWN ' ) GROUP _ #5 (P02) PLAN VIEW iii iiii i 2858 feet at Azimuth 27.06 30.2~7 E :l inch -' 600 feet 12/05/94 im i _ __ i mi mi m ANADRILL AKA-DPC' FEASIBILITY PLAN NOT APPROVED FOR EXECUTION .',PLAN TARGET 200 'T RADIUg : : I ,.. ' ........... "6EC ~"4]~s~ ' '-- ga 0il & 6as Cons 6ommis',[ion 300 0 300 600 900 1200 !500 1800 2100 2400 2700 3000 3300 3600 3900 ,~- WEST ' EAST -> iml _ i i m _ ilml i m III I -- RI~; NABORS 18E 13 5/8" BOP STACK 10,000PSI RKB I HYDRIL TYPE "GK" ANNULAR 5,000 PSI Kill line SCHAFFER PIPE RAM - 10,000PSI SCHAFFER BLIND RAM - 10,000PSI MUD CROSS I "lChoke line I SCHAFFER PIPE RAM - 10,000PSI '" I CASING SPOOL ~SG HEA~ 29" GROUND LEVEL RECEIVED DEC 1 4 1994 A!sska 0il & Gas Cons. Commission Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission ? (~ December 27, 1994 Staff ~~ Fml Subj: Variance Requests -- Badami/t4 & #5 BP Exploration has requested a variance from H2S contingency plan requirements (20 AAC 25.065 (c)) for each' well. Their intent is to provide H2S monitors at various sites on the rig and to provide Scott Airpack breathing apparatus as part of the standard rig floor equipment. A review of offset wells on the Badami prospect indicates H,_S was not encountered in the formations previously penetrated and tested by Badami #1 and #2. Badami #4 and #5 will encounter the same formations as penetrated by the earlier wells. BP is also requesting variance from conductor casing setting depth requirements of 20 AAC 25.030 Co) (2) and (3) for offshore wells. The variance request is predicated on lack of evidence of shallow gas in offsetting wells based on mud logs and interpretation of seismic surveys and presence of unconsolid, ated coarse sands, gravel and soft mud in the formations above 1¢100 feet. They feel the formations are not competent to contain shut in formation pressure should there be and influx. The staff have reviewed mud logs and drilling records and find that there are no indications of shallow gas hazards nor drilling problems above 4500 feet casing depth that BP has proposed as their second casing setting depth. Drilling mud weights ranged up to 9.5 ppg to 4500 feet depth in Badami #1 and #2 and appeared to increase in a normally as drilling progressed to those depths. Recommendation: The staff rccom~nends approval of the variances requested based on our review of available data indicating absence of shallow gas hazards, normal drilling conditions encountered and lack of H2S in offset wells in this prospect. BP EXPLORATION Memorandum To: Mark Stanley- Drilling Date: 5 Dec. 1994 cc: Well File- Badami #5 From: Walt Fulroth ~0/¢/~ Subj' Shallow Gas Survey for Badami #5 well site The Badami #5 well is currently planned to be directionally drilled from a surface location within the SW 1/4 of Sec 5, T9N, R20E (Attachment 1). Badami #5 drilling will start vertical and slowly build angle along an azimuth of about N27°E to an approximate depth of 4500' tvdss (approximately 990 ms seismic two-way recording time) where.13 3/8" casing will be set. In accordance with Alaska State permitting requirements, the potential for shallow (<4500') gas sources in the vicinity of the proposed well location has been reviewed. Analysis consisted of examination of 2-D/3-D seismic data near the well site (see Attachment 2) and looking for the following effects: · anomalous high or Iow amplitude seismic reflectors · velocity pull downs or time delays along individual seismic reflectors · phase changes along otherwise continuous reflectors Unfortunately, the sharp transition from a thick permafrost layer onshore to a very thin layer under Mikkelsen Bay creates severe ray path distortion immediately in the vicinity of the well path (Attachment 2). The non-permafrost layer is significantly lower velocity than its permafrost counterpart which is an identical situation to a shallow gas pocket. The data is also too shallow to use pre-stack seismic information to determine fluid content. Despite the data quality problem, the probability for shallow gas is'very Iow for the following reasons: 1) This same character occurs along the entire North Slope within 2000 feet of the coastline as it is here. 2) The amplitude character in the onshore data is very consistent and shows no sign of shallow gas. 3) No shallow gas has been encountered in nearby wells and no other data in the region show gas character. 4) In-situ gas formation is unlikely from these sediments and there is no shallow 4-way closure to trap gas beneath the permafrost. P~ E ~ E, IV ~ D DEC ] 4 1994 A~ska, Oil & Gas Cons. Commission Anchor; O Attachment O / o o o T9N-R2~E-S5. o .,~~ Target Location ~~-~ Badam~-05 ¢m'~/!/~l~~~ 'Juli "' / ~~ /arget Location Tolerance Window ,. .. ~ ...... . / O " u' / , .... ~ ................. '"- ....O / ~ · / ~ 5~.O-.~aclng exception on'% section / or,, // ~",,, "'....,, / / '.., / Potential Top.Hole Location ................0 ........ - ..... ." 0 0 ""'--"- RECEIVED ',..,. DEC 1 4 1994 ........ '-.. Anchorr ,. " ~ meier · NORTH .. - 1000 fe~"-:'.. " Badami-05 Location (Juliette) Date: S~:. 199~ t Attachmen: 2D ~Base Permafrost__: ......:: ..... =i.~_ ~Sag due to missing ........ . ........ ~. ...... . -..- ........ gh velocity ........... }ermafrost ............ ' ..................... '~' ...-.-'--'"'- ........ .... ;...,..-. ................ i'-,l.-i.- ~ "" ---::~ ..... '-'~ 2500 -. .. .: .:.-;; ..... ~ =.~.. ..... ~ BP EXPLORA3'ION Memorandum TO: Mark Stanley- Drilling FROM: Walt Fulroth- Exploration DATE: 2 December 1994 SUBJECT: Geophysical Analysis for Overpressure - Badami #5 The Badami #5 well is currently planned to be directionally drilled from a surface location within the SW 1/4, Sec 5, T9N, R20E to a target within the NW 1/4 of the same section at a depth-of about 11,000' tvdss (Attachment 1). Velocity analysis of 3-D, CDP seismic data in the vicinity of the Badami #5 well location were reviewed in an effort to determine a formation pressure profile in the vicinity of the operations site. This review was in accordance to State of Alaska permitting regulation 25.033, section El. Attachment 2 plots seismic RMS velocity vs. time in the vicinity of the Badami #5 well path. This plot suggests that the top of potential overpressure could fall between 8100' and 8700' tvdss. This is about 800' higher than surrounding wells would suggest. Although this value should not be disregarded, the velocity information could easily be in error due to its proximity to the permafrost/no permafrost transition zone and the pre-velocity static applied to the data to correct for this zone. A more reasonable trend can be seen on a similar plot from the Badami #1 (1.5 miles east)(Attachment 3) showing the top of overpressure between 9450' and 9950' tvdss. The mud-weight buildup chart from Badami #1 (Attachment 4) confirms the top overpressure within this range, Mapping this horizon to the west would give a tOp of overpressure at about 9000' tvdss. The predicted Pore PreSsure vs. Depth for Badami #5 from the seismic velocities is shown in Attachment 5. The likely case would be more in line with observations from other wells within the area. The casing design and mud program allow for expected formation pressures. cc: Well File - Badami #5 RECEIVED DEC 1 4 1994 Alaska Oil & Gas Cons. Commission Anchor[ ,~ O ,, { 0 0 0 Tqkl ~nn qn Target Location uaaami-05 ~~ (Juliette) 'Om 0 o ! · --.-..~.Z Potential Top..Hole Location O ...... - .......... "'O ............. 0 0 Target Location Tolerance Window / / ~E'¢EIVED DEC 1 4, 1994 A~aska Oil & ,Gas Cons. Commission AnChor~ :. O 0 0 0 .. NORTH ... .,. · ~ooo !~:.:-:,.: BP Exploration ......................... i Badami-05(Juliette)LOcation 1000 o o o o ~ o ~ 1200 m' 1400 BADAM! #5: RMS VELOCITY VS TIME - CDP 680424 Seismic Time (ms) 1600 1800 2000 2200 2400 I I I I ! I i. (TVDSS) I I 2600 28O0 0 BADAMI #1' RMS VELOCITY VS TIME - CDP 632400 1000 85.00 90.00 95.00 100.00 . Seismic Time (ms) 1200 1400 1600 1800 2000 2200 ' I t , i [ ~ , i i ~ i i i i i J i i i i j I J [...., I'"' ' I I I (TVDSS) 2400 2600 I I 28OO 3000 0 2000 4000 Badami I Mud Buildup I I I _ I I I 6000 8000 10000 Depth (tvdss) I 12000 I 14000 8000 7000 60O0 5OO0 4000 3000 2O0O 1000 - BADAMi #5-PRESSURE VS DEPTH 0 _1 I i I'VO~-,S *Mu¢~ We~gnl .Pore P~essure I 1000 9.0. 467 2000 9.0' 934 3000 9.0~ 1401 4000' 9 O: t868 ' __5000; 9.0~ 2335 6000' 9.0: 2e02 7000 g.l, 3306 __. 8000~ 9.2; 3819 8500 10.5: 4632 9000'. II.S' S37 t.~ g~00, 12.0: 591~ ~oooo: i~.o~ ~ ' ~o~o~' ~2.oI 11000: 12. I I 6907 11500 12.11 7221 '- I I ---_ ! 1000 2000 3000 4000 5000 6000 7000 8000 Depth (tvdss) 9000 10000 11000 12000 I nterOl'fice N lemo To: .[tla/.r Wondz. eg Fro,n: Robed P. (':randal~ Date: December~; ~ 99 ~ .. ...... , ..... , OW'l> 8, q-t{7 At your request I have reviewed the 0-5,000' measurcd depth interv:al of the [?s~dami i~? mmtl{m.,. Thc log shows tiffs well encounIered minor volumes of methane primarily associatecl with coal and lienite seams through tttis depth. At no time did this well encounter gas yolumes wttich may have ~'q~rcscnlcd a dr/tl.in.u hazard in this inlerval. Mud weights used Io drill this section ran in the 9.5 lb/gtd rmtge. This weig'hl un. id was lm~bably reqttired due to the presence of sticky shales and coal seams, no ehdence of overpressure is present in of this well, although ove~pressure is present below the H RZ in this area. I. would suggest any approval o fa program variance relal'ed lo potential dfil.hng hazards be contingent a re, view of data requi~'ed b.,,; .2'0 AAC 25.033 (e)(l). Memomndum To: Blair Wondzell, AOGCC Date: 11/19/94 3001 Porcupine Drive, Anchorage, AK 99501 From: Adrian Clark Tim Schofield Engineering Supervisor Drilling Engineer This memo follows up a telephone conversation between Mark Stanley and Blair Wondzell discussing the 1995 Badami drilling program. It is intended that two wells, Badami #4 and #5, will be drilled from ice pads constructed in shallow water about half a mile from the shore of Mikkelsen Bay. ,C,.ONDUCTOR CASING IN OFFSHORE WELLS State regulations 20 AAC 25.030 (b) - (2) and (3) require that conductor casing be set between 300' and 1000' below the mud line and that a formation leak- off test be performed below the casing shoe. These regulations are intended to ensure that an influx from a formation above the surface casing point could be contained. It is requested that a waiver to these requirements is granted for the Badami #4 and #5 wells for the following reasons: a) Minimal Risk Of Influx Above The Intended Surface Casing Depth Of 4500'. Neither interpretation of seismic surveys in Mikkelsen Bay or studies of open hole logs and mud/cuttings gas logs from the Badami #1 and #2 wells show any indications of shallow gas reservoirs. A Iow level of background gas in the earlier wells was due to the presence of some disseminated lignite and wood fragments and thin lignite beds. There is no evidence of abnormal pressures in this section in nearby wells and none are expected to be encountered. RECEIVED DEC - 2 1994 Oil & Gas Cons. Commission Anchorr. b) Lack Of Competent Formations Above 1000'. The lithology above 1000' will consist of unconsolidated, coarse gravels, coarse sands and some soft mud. It is most unlikely that these formations could provide a strong enough shoe to enable an influx to be shut in with a BOP stack. The proposed well plan for Badami #4 and #5 will be for 30" structural casing to be set at least 100' below the mud line. A diverter will be installed and function tested on the structural casing. 16" surface hole will then be drilled to the 13 3/8" casing setting point at approximately 4500'. No leak off test would be conducted below the 30" shoe. Please call Adrian Clark (564-4720) or Tim Schofield (564-5242) if you have any questions. Engineering Supervisor BP Exploration Date Tim Schofield Date Drilling Engineer BP Exploration DEC -' ~ 1994 oi,! & Gas Cons. Commission Anchor[-~: STATE PIPELINE COORDINATOR'S OFFICE ,~ Department of Environmental Conservation C Department of Natural Resources [] Department of Fish and Game November 9, 1994 Letter No.' 94-028 File No.' 0900.45.010. WALTER J. HICKEL, ~OVERNQ_R_..~._.~ c'OMM 411 WEST 4th AVENUE, ~~1 ANCHORAGE ALASKA 9~_~"~ PHONE: (~7)~78-8594 I SR ENG (~7) 278-8595 SR ENG FAX: (907) 272-~90 ENG ASST I 1 ENG ASST I SR GEOL~ GEOL A~ST~ .R~L ASSTI~ ~AT ~EC~ STAT TEC~ 'FILE ~.. Peter T. Hanley BP-Exploration (Alaska)!nc. P.O. Box 196612 Anchorage, Alaska 99519-6612 RE: Annular Injection Permit for Badami Appraisal Wells #4 and #5; Permit Authorization Number 9240-DB002-7BL On September 20, 1994, this office received your submittal of a request for a permit to inject drilling fluids down the annuli of the referenced wells under State General Permit 9240-DB002. Your September 20, 1994 submittal is an update to your earlier letter of July 14, 1994 regarding this project. The Department has completed review of your September 20, 1994 submittal and has the following comments: According to your submittal, Badami appraisal wells Number 4 and 5, are to be drilled from off-shore ice pads. The drilling of these two exploratory wells is planned during the winter of 1994-1995. As these are exploratory wells, the proposed receiving zone will need to be evaluated by the Department to determine if it is adequate to manage the injection fluids before injection can commence. As you have noted in your submittal, information regarding the top and bottom depth of the injection zone, the permeability, operating pressure, and average level of total dissolved solids of the ambient water within the injection zone will need to be provided to the Department for review. The exact bottom hole locations of the wells will also need to be provided. Subject to the above requirement, authorization is hereby granted to inject into the wells described below. This approval is also subject to the terms and conditions of General Permit Number 9240-DB002 and is valid for the time period specified below. ,RECEIVED NOV 15 1994' ,Alaska 0il & Gas Cons. Commission Anch0ra a Peter T. Hanley -2- Annular Injection Permit For Badami Appraisal Wells #4 and #5 November 9, 1994 Drill SiteWell Approximate Permit Number Disposal Period No. Volume (bbls) Badami 4 35,000 9240-DB002-7BL 1/1/95- 12/31/95 Badami 5 35,000 9240-DB002-7BL 1/1/95- 12/31/95 It is understood that this is a tentative schedule and is subject to change. It is also understood that the Department will be kept informed of the activities of the drilling program, the amounts and types of fluids being injected into each well, and the injection time frames by the submission of quarterly reports to this office. Radioactive isotopes permitted for injection must comply with 18 AAC 85, Radiation Protection. Please note that this authorization has been given a unique suffix designation to the general permit number (i.e. 9240-DB002-7BL). Please refer to this permit number and suffix for all correspondence and monitoring reports related to this authorization. A permit fee will be assessed for this authorization. If you have any questions, please do not hesitate to contact Mr. Ralph Kiehl of this office at 271-3649. Sincerely, ADEC Regional Administrator Pipeline Corridor Regional Office RK/mk (PCRO g:\cledcal\dec-clehralphk\94028.rk) cc: Tuckerman Babcock, AOGCC BP EXPLORATION September 20, 1994 Pamela Grefsrud Pipeline Corridor Regional Office Alaska Dept. of Environmental Conservation 411 W. 4th Avenue, Suite 2C Anchorage, AK 99501 900 East Benson Boulevard ..o. Box 19661 i. Anchorage. Alaska 99519-6612 [ (907) 561-5111 Badami Area Appraisal Wells Alaska Dept. of Environmental Conservation General Pe~,nit No. 9240-DB002-7H Notice of Disposal for Annular Pumping of Drilling Materials Dear Ms. Grefsrud: In 1993, BPExploration (Alaska) Inc. (BPXA) submitted a Plan of Operations and secured approval for the Badami #3 exploration well. Drilling of this well was subsequently deferred. On July 14, 1994, BPXA submitted a permit application package for the Badami Development Project. After submitting this package, BPXA redefined the proposed ~ppraisal well p, ogram (originally Phase 1 of the project) scheduled for the winter of 1994/1995, and gravel construction originally planned for early 1995 has now been deferred to the winter of 1995/1996. During winter 1994-1995, BPXA plans to drill two Badami appraisal wells from offshore ice pads. BPXA requests that the July 14, 1994 request to inject drilling fluids generated from drilling operations down the annulus of two Badami appraisal wells be amended with the new locations. The attached "Notice of Disposal", which contains the new locations, is submitted for your review and approval per the requirements of the above mentioned permit. Please call Karen Thomas at (907) 564-4305 if you have any questions concerning this request. Sincerely, Attachments cc: Tuckerman Babcock, Alaska Oil and Gas Conservation Cornmission ADEC'$ 1995 Appraisal Well Drilling ACtiv;ties Notice of DisPo~;al for Annular Pumping ~f Drilling Material~ under General Wastewater Disposal Permit (9240-DB002) 2) 3) 4)' Notification of Disposal Prudhoe Bay Drilling proposes to inject drilling fluids and associated wastewater down the annulus of two Badami appraisal wells. Information provided below describes the details of the proposed activities as required in Appendix A, Section I.B. of the General Wastewater Disposal Permit (9240-DB002) for Annular Pumping of Drilling Materials. Notification Information Well Designation and Location The bottomhole locations of the Badami appraisal wells are' Badami #4 T9N, R20E, S3 Badami #5 T9N, R20E, S5 Exact locations will be provided prior to ice pad construction. Materials to be Pumped The plan of operation calls for the pumping of excess drilling fluids that are developed solely from well operations. These fluids consist primari!y of excess mud products and fluids and rig wash water. Minor constituents include formation fluids, completion fluids, cement contaminated mud, and suspended drilling solids. Estimated Volumes The Pumped volumes per well are determined to be approximately one well's worth of materials incidental to drilling per annulus. This is determined not to exceed 35,000 barrels. Pumping Depth The' pump depth for the Badami wells will be below 4000 feet total vertical depth (TVD) based on the confining shales. The sudsce casing will be set at approximately 4000 feet TVD. RECEIVED SEP 2 2 1994 Ataska uli & Gas Cons. C0mrnission Anchorage 5) 6) 7) 8) 9/10) 11) Zone of Pumping The injection zone is within the Brookian Sequence. The depth of this zone is greater than 4000 feet TVD. Additional information regarding the top and bottom depth of the injection zone, the geological stratum of the injection zone, the permeability, operating pressure, and average level of total dissolved solids of the ambient water within the injection zone will be provided upon completion of the well. Before injection activities commence, the permeability of the injection zone will be verified and the Alaska Department of Environmental Conservation will be notified that the zone is suitable for injection activities. If annular injection is not an option, other alternatives for materials disposal shall be used. The Size and Porosity of the Injection Zone The statement that the receiving zone is adequately sized to accept the volume of fluids to be pumped will be provided upon completion of the well. Pumping Dates Pumping will take place after the intermediate casing string has been set. This date is estimated to be in mid February 1995. Well Schematic A schematic of the well and casing layout to the intermediate casing point is provided as Attachment I. Sealing of the Injection Zone The pumping annulus will be cemented upon well abandonment according to 20 AAC 25.105 Alaska Oil and Gas Conservation regulations. This information will be provided upon completion of the well. Drinking Water Aquifers Injection down this annulus will not cause a violation of State Water Quality Standards (18AAC 70) because the injection depth will exceed the 1,500-foot minimum as required by Appendix A of this permit. R. EC, EIVED SEP 2 2 ]994 Oil & Gas Cons. Commission Anchorage 20" Preset Conductor 80' BGL 13-3/8" ANNULUS CEMENTED TO SURFACE 13-3/8" casing ca. 4000' TVDBRT ZONE OF INJECTION 4000' TVD OR DEEPER TOP OF CEMENT AT APPROX. 9000'-6000' TVDBRT :: 9-5/8" casing ca. 9500' - 10,000' TVDBRT 8-1/2 hole to total depth RECEIVED SEP 2 2 1994 Alaska 0ii & Gas Cons. Commission Anchora~je BGL 'TVD BRT Below Ground Level Total Vertical Depth Below Rotary Table BP EXPLORATION (ALASKA) INC. BADAMI APPRAISAL WELLS ANNULAR INJECTION DIAGRAM DATE: SCALE: September 1994 NOT TO SCALE i i jl i ii FIGURE: 1 . . r MIT CHECKLIST ADMINISTRATION GEOLOGY 1. Permit fee attached .................. ~ ~ 2. Lease number appropriate ............... 3. Unique well name and number .............. ~ 4. Well located in a defined pool .............. Y 5. Well located proper distance from drlg unit boundary...~ N 6. Well located proper distance from other wells ...... ~ iN · 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. ~ 10. Operator has appropriate bond in force ......... Y~ N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval..~Y~N 13. Can permit be approved before 15-day wait ....... ~Y~ N PROGRAM: exp [] dev [] redrll [] aery [] GEOLOGY: 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or rese~e pit ............. 21. If a re-drill, has a 10-403 for abnd~t been approved~// 22. Adequate wellbore separation proposed .......... 23. If diverter required, is i= adequate .......... 24. Drilling fluid progr~ schematic & equip list adequate ~. ~o~ ~.~u~. ............ ~.~. ~ .. 26. ~oP~ ~r~s. ra~i~g a~ua=~; =a.= ~o ~/~-- ~ig.~ 28. Work will occur without opera=ion shutdown ....... 29. Is presence of H2S gas probable ............. 30. P.~i~ can be issued w/o hydrogen sulfide measures... . 33. Seabed condition su~ey (if off-shore) ......... , , ENGI~ERIN~: CO~ISSION: z "MS~cbeklist rev03/94 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. ~['.)ROUGN : Nt')RTH SLOPE 8T.ATE : AL,.ASKA AP1 NI..IMI.:::sER : 50-629-22533 RECEIVED APR 1 0 1995 Alaska Oil & 6a$ Cons. Commission Anchorage Ig Tame Peri. ti. cat!om T,j. stina ChlUn, berQer Alaska COmpUtiDO Center 2.-hPR-19q5 1.3:1! **** ','1' A P ~. NEAD~;;,~ **** SFRVTCF NA/~V : DiP DATE : q51(';4./ 2 ORIClN : Fb]C T~PW NA~K : 05090 P~'EV 101~,~ ',APE : ** SCHI,IIf~'IBERGER GEDOUEST ** C 0 ~,'~ P A N Y N A ~,.'! E: R P WFLI,: BA P ~'~'q I ~'5 F T g T., D: w I L 0 C A T SWATE: ~,b API N. U~.i B El,?: 50-6~9-225R3 L 0 C A T I 0 r,:~: 3334 ' S SECTION: 3 T~1w~,:~SII!P: qN RANGE: PFR~ANE~,,T D~T'I~M: ICE PAP E'bFiVAT!DN: 4' ].~ ~ ('; MEASURED ET..~::iVATION,5 K~: 3~.~' DF: 33' GL: 4,1' L m (; G I N G D l' S T ~ I C T: K ~ ~",l A .I b n (; (; I t"~ G E ~..~ G T N E g R: J, C R Y E R ************************************************************************ DATE [,,[.]GG r;~!;: 3-~AR-1905 TD DRTL~,ER: ~. :1.549~ T~ [.,OGGWR: ~., 1544' C~SING 3: q,625" * DRIL~,,ER. DEPT~,~ OF q57~' BIT SIZE R: ~',5" {9 1.1549" TY'PE VI.JUID l~:~ Hn PAGE: I$ Tat, e ver,i~Ic~tion l,i, stinq chlumberqer Alaska Comp,]tinq Center 2-APr,'-!995 1]:,1.1. P~: 7 P~,UT[) LOSS: q,6 M~[) FESISTiVITY: 0,7a3 ~ 66 DF:UP FTI~T~{AT~ PEGI, STT?] TY: 0.498 TKCI'~i'~TCI,~N/At,~ALYST: R. KRD':.:F:L,L 8 IGc:! PIC~,:T I,.)FII,~ DI:P.O(~I COi,:T~Ii':S ALI, ~IP TYPl~:S PICKED F'~I)M F~'II I~',IAGES 2,)~'II,ES DIP.C. 02 TH'P[~ l')!P.On~ CC,.~'~'PAI:~ EACH I~,~DI:VIDUAL DIP TYPE CO~PRISING BI° D~TA 15! FI!,Pj I)IP.O01 3.)BATA HAS BFFiN C[3PRF(jTEr~ FOP 30 L)EG~EE8 ;.,AGPETIC DECLINA'.I?IO~ *:*** FILF ~)A~;:~ : nip .OOl S~RVICE ~ Fi;TC VKRS ], C~ : o01C01 [:,~'.l:'r : ~51o4./ 2 N~X R~C 8TZF ~ !024 FII,,,F TYPE; ~ I.,['] LAST PAGE: BP EXPLORATION t!i a l,') ,/~ 1'41 # 5 API ~50-629-22533 W!L[)CAT I,.li.:.)l~'.~'F! SLOPE, AT,ASEA FI:LE PlP.()0~ 8A~iPLE RATE: VAPlAaLE DIP TYPES PICKED TABI,,.~ TYPE I CONS 'ru it,; I V A 1.,, U D E F ! N BP EXPI,,,OR. ATTCIN Company Name F ~ ~ '[ t,~ ~ C A 'i: F .i e i d N a'm e W~:~ E~,A[>At~.I ~5 Well Name Am:IN 50-629-22533 A, PI Serial Number FT.., 3334'8~'~JI.., & 4770'WEL, Field Location SECT 3 Section TOWN 9N TownshlD R~.NC 20E, Range I$ T,,,~¢e verifJcat!.on T,ist,!n~ C~lUt~berqer t~laSKa CamDe.lt,.nc Cent, er 2-A¢l'~-! 995 13:!I PAGE: ['1' ~/C3 F'U .T r,t A ICE 4, ~ n 34. 11549, 1~544. 11524, 36, COR~ 12,5 7. 76, (.~ 743 State or Province Witness 5!ame Service Order Number Permanent datum Elevation of Permanent Datum Lo~ ~easured From Above Permanent Dat[~m Elevatlon of Kelly Elevation o~ Derrick Floor Elevation of Ground Level Total. Depth - Driller Total Depth - Looger Bottom I,~o~ Interval ToD Leo ] .terval Drl. lltn~ Fluid TYpe Drilllno Fluld Density Drillin~ Fluld PB Drll!iD~ Fl. uld V~Scoslt¥ t)rlllIn~ FlUid Loss ~esi. stfVl, tV Of Nud Sample [.~ud Sam le Temperature ResistJ.~ ltv of Mud Filtrate ~ud Filtrate Sample Temperatu i.)EF'I D I;': p r) e~th DPT;; DiD ?rue DPA~ DiD ~zlmnth Tape ~erif~.cstion Listinr~ CblUmYerrjer Al~sKa Co.~ut~nq Center PAGE: I III~IIIIIIIIlli I I II 6 73 7 65 ~ 73 9 65 ~1. 66 65 16 66 0 66 ID D~pT VT D~T~ CEO DEG DDAZ CEO DEG ** DATA ** DEPT. 96()1..!~8 DEpw. 1~1700.176 DEPT. 10800.426 DEPT, lllO0.~6g DFPT. 11374,393 DPq'!{. GF(] 9.59,q,. DPAZ.GEO 30.592 DPTR,GEU 7.975 ,r.)pa z. GEO 86.039 DPTR.GEO 26.326 DPAZ,GEO 346,578 DP'YR. GEO 11.009 DP,AZ, GEO 1 ].,,4. J 74 DPT.R, GEO 9.645 DPAZ,GEO 42,549 **** FILE NA~E : DIP $ E R V .,[ C E : F L I' C V~S!O~t : ()0~C01 DATF ~aX RE'C SIZE : ~,Q24 F 7 b F T Y P LAST FI IS !fane Verificati. on L,.tstinc~ Chlumberqer ~].aska Cont~'.utin.~ (.'enter 2-APR-~gq5 1~:11 PAGE: **** F I l'..., ~' MEAl)ER S~RV!CE : ~[,IC D~TW : ~5/~a/ MAX RFC SIZE : ~ (~ FILF TYP[!; : I,C L~ST FII,E : Ir I L ~.] DIP.O02 ************* SAMD.[,~: PATE: VAPI~[.a. LE TYPE T U !',,! I V ~, L 0 D E F I C~t P.',P ~XPbO.RA'r~f~N Companv Name Field ~!a~e APlN SECT TOw~ C o U ~ STAT W!T~ EDD EKP, EDF T P L T L I DFT FT w I LDC ~ T 50-629-22533 3334'S~',~L & 4770'~i'Eb 3 20E ~,i OR T~,i 6LOPE USA 629136 ICE PAD ..... ! '! 54~, ~ 11524. CORE Well Name ,~P! Serial Number Field Location Section Township RaDge County State or Province Nation Witness Name Service Order Number ~ermanent datum Elevation of Permanent Datum bo~ Measured From Above Permanent Datt~m Elevation of Kell~ BUShing ~levat o~ o~ [)err ck Floor Elevat!oD of Ground Level Total Depth'- Driller Total DePth '- Logger Bottom bog Interval Top Log Interval Drilling Fluid Type ChlUmbero. er Alaska Cor~putir;~ Center 13:! ~ PAGE: 6 T II i,I T ctc3 V~I,U I)EFI ~mmmmmmmmmm~mmmm.,,~mme m mmmmmmmmmmMmmMmmmmmmmmmmmmmmmmmmmmmmmm m m 2,5 !)rllllng Fluid Density 7 Drlllinq Fluid Ph 7g, DrlllinO FluI~ Viscosity 4,b Orlllin~ F~uld Doss 0,743 Resist~. ~t. o~ ~ud Sample ~6, Mud Sample Temperature (~,49B Reststlg~tV o~ ~ud Filtrate S 55, Mud wiltra.e% Sample Temperatu 2,33 Resist.~.vity o~ Mud CaKe SamD1 ~4CST DECF 66. ~ud CaRe Sample Temperature B~T DEGF 15N, Bottom Hole Temperature mmmmmm~mmmmm~, m mmmm~mmmmm m m mm~m~m~mmmmmmmm~mmm~mm mm mm~ m ~mmmmmmmmmmmm~mmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmm 'I'~BI,E TYPP.'. : C{~PV ............................................' ' ' DPA~ Din Azimuth ** nATA 8 9 I l 13 14 15 16 7.3 ! 2 66 0 66 73 65 73 65 66 0 65 66 68 66 IS q'aDe verification I,ist.~na chlumberger Alaska Co.,¢,uti, no Center 2-t~P[{-1 995 PAGE: DFpm FT 629136 oO 000 O0 0 2 ! I. 4 6a 0000000000 D~T~ P. ED [)EG 690136 O0 000 00 0 ? 1 1 4 68 O000000000 DPA7 PE¢ DEG ~Zql'~ O0 009 OO 0 2 1 1 4 68 0000000000 I)EPT. q~nl.91.~ I)PTR.H~D 9.59g DPAZ.~E!) 30.592 DEPT. !.O7~o.17b DPTR.B~:D 7.975 DPAZ.BED 86.039 DFPT. 1~100.66~i r)P~R.BED ll.nO9 DP~Z.H~I) !,14.174 !)~PT. 11374.393 DPTR.BUb q.64~ DPAZ.BED 42.549 Clip **** FTLE TRA !', I,EIe **** FIL~ NAI'~i::,~ : DIP .0n2 S~RV!CE : FL'lC VERSION : 091C01 DaTF : g5/04/ 2 ~X REC S~ZBi : 1024 LAS~' FILE ~ **** FILE HEA Dl[~l< **** FIL~ ~',~A~E : !3211, P .003 VERSION : OG1CO1 DAT5~ : gstg4/ 2 ~4AX REC SIZE : 1024 F!L~' TYPE LAST PILE F'ILE D!P.O(:3 IS ~a~e 'Vert~.icati. on I,istino chlumberqer AlasKa Com~.}t~no Center 2-APR-!995 13:!1 PAGE: 8 DIPS ['~? ~M}<AK(.![!T PICKED FR~ ~'~I ]~IAGES TIBI,E TYI>~ : FN %'.~ l LOC,A'I API~ 50-62g-22533 F~, 3334'S~[, & 4770'wEb S~CT 3 TOW~.~ 9N R ~ NC 2 CO U~,' ~ORTH SLOPE STAT AI,ASKA NATI USA ~ IT},~ PUTNA~ SON 679!, 36 PDAT ICl~ PAD EPD FT APD FT 3~. E~ FT 38, EDF W"I' 33. E ~ L ~ T 4 1 T O D F'r 1 { 549 . TDb FT 1 l, 544. BLI FT T!,I PT 36, DWT COlt~ D~'V $ 76,, DFL F3 4 6 R~S ~lH~H O' 7~3 MST DEG~T 6~. " MFST ~" "' ~CST DEGF 66 ~ . BMT OEGF 15 8 Field Name Well Name API Serial Number Field l,ocation Section Township ~an~e County Sta~e or Province Nat on Witness Name Service Order Number Permanent datum Elevation o~ Permanent Dat~lm Lo~ Measured From ~sove Permanent Datum Elevation of KOllI Bu~hlng Elevation Of Derr cK leer Elevatlon of Ground Level Total DePth - Driller Total DePth - Logger Bottom bo Interval Top Loq I~terval Drilling Fluid Type Ortllln~ Fluid Density Drilling FlUid Ph Drill ~ Fl. tlld ViSCoSity Dr'il!,l~u .Fluid boss ReslstigttY of MUd Sample Ml~d Sample Temperature Resistl itY of'MUd Filtrate S gud Filtrate Sample Tempera'tu Resistivity of Mud CaKe Sampl. Mud Cake Sample Temperature Bottom Hole Temperates. re Tape verification [,ist.inQ chlumherger AlasKa CompL]t:ln~ Center 995 13: 1 I TABT~E; 'I'¥PW. : CU~¥ D~F~_ DPTP Dip Trtie DOA?, Dio ~Zimuth PAGE: DATA F'OIS~-~AT ,C,).i:;'ECTP'TCATTi.'~I',? PF;Ci)~i3 ** ** $E"1'' 'TYP.E - CNAI'g ** S E R V U W, p A P I ~ 'I I ~ E N U M ~,~ S I Z E ~ R P R 0 C E S !D ORD~:R ~ LOG TYPE CLASS MOD ~UMB S.A~P .ELEM CODF, CHEX) DFPT F'T 6291,36 00 000 00 0 3 I I 4 68 0000000000 DPTP BRK D~G 6291.36 00 000 O0 0 3 1 1 4 68 0000000000 DPA% B ~'. K .[)EG 629136 O0 O()O O0 0 3 1 1 4 6~ 0000000000 D ~ PT. q ~) 4 2,4 4 1 a, P T R. ~.~ R r',, 8 2. a 9 5 g P 1%, a R ii 3 0 2.1 0 3 D~]PT. 1 !, 343.0()0 ~)PTR. BRK 76. 770 PPlZ.,0~it 313.1,t0 I$ Tane Verif. icat.ion I, istiD.u CblUmberger Alaska. Comptlti. na Center ~-APR-1995 13:1 1 10 SFRVICE : FL, lC VFRSIOU : 0C~C01 F'TL~ TYPE LAST FILE FILF N A?~ E SERVICK : ~LIC VE~$IOW : O0~.CO1 !.)~TE ~AX REC SIZE FI LE TYPE L:~ST FILE : FILE DI: ,n. 004 SANPbE RATE: VA~IABbE TUN! VALU DEFI N ~P EXP:!~ORA,,rTON Cgmpan~ Name ~'~ ~'][LOCA Field ~ame W~ BADA. MI #:5 Well Name AP].~ 50-629-22533 API SerI, al Number FL 3334'8NL & 4770'i~E5 Field Location SECT 3 SectloD TOWN 9N TowDsbip RaNt 2 E ~ange COUP! NORTFi $[,,,~OP.E Cot]~t¥ IS 1'ar~e Yerif.icat.i¢')n [.istir, q chlumberg~r AlasKa Co~.'p~]t.inc~ Center PAGE: 11 Immmmmmmmmmm~mm~mmmmm~mmmm~m~mmmmmmmmmm m mm m SnN 629136 P~AT IC,~ APD FT 3~. EKH =T 3~. EnP rT 33. EGL ~T . l TDI.: FT 11544. BLI WT TI, I 121, 36, I)FD G/CB 12,5 DFpM 7 s v D~L F3 RmS OH~l.i O. 743 ~ST D6]GF 66, R~FS OH~M 0,49b MFST DEGF 55. ~CST DEGF 66, B'MT DEGF 15S, State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum bo~ Ueasured From ADove Permanent Datum Elevation of Kelly Bushing Elevation of berrlcK Floor Elevation of Ground Level Total Depth - Driller Total Depth - Looger Bottom Log Interval Top Loo Interval Drilling Fluid T~pe OrlllinO Fluid Density Drilling Fluid Ph Drilling Fluid Viscosity Orilling Fluid Loss Resistigit¥ of Mud Sample Mud. Sample TemPerat~re Resistt. gitY of Mud lltrate S ~ud Filtrate Sample Temperatu Reslstlvit¥ of Mud CaKe Sampl. ~.ld Cake Sample Temperature Bottom Hole Temperature T ~ B L 8'1T' , . ' %P~ : CUP, V IS Wane Ver..tf~.cat~o, [.,istir~q chlum~,erqer AlasKa Comi..),]tina Cente£ 2-AP~-1995 13:1 I PAGE: 1¸2 ** SET TYPV2 - C~A~,~ ** ID f'~RDF, R ~ L~G TYPb~ C[,.,ASS ~UD ~t.]t,~ SAMP ELEt4 CODE (HEX) DFPT FT 36 00 0 00 4 1 4 O 000000 0 0 D~TP ~Rf] DFG g2q136 O0 ()ilo O0 0 4 1 1 4 6~ 0000000000 DPA7, ~RO ~)FG 62Q !36, O0 000 OO 0 4 1 1 4 68 0000000000 **** FILM TRAII, ER **** FIb.F.~ ~I~,IE : t>I.!:' .004 SF, RVICE : FL!C VERSION : O01CO1 D,~TE : 95104/ 2 ~t~.X R~C SIZE : 1024 F 17 I.., F' "!7 Y P E; : LA.S~ FILE IS Tape Verification Llstino chlumberger Al.a$<a ComptltlDq Center FTLF NAi4~] : DIP .005 SFRVIC~, : Fb~C VERSIOn : c, 01C01 DaT~ ~ 95!0,~.t 2 r.!~X REC SIZE : ~024 FTL, F TY~ : L~3 LAST FILE : ~-APR-1995 13:11 PAGE: 13 FTLE ~IP,00K S A MP.LF, PATP]: F ~ ,i~PI~] FL SECm RANG C 0 U STAT NAT! P~AT L~F Ek'B EDF T P L BLI TLI DFT FT FT ~ILDC.~T 50'629-22533 3334'SN[,,, & 4770'~JE5 9 N 2 0 E; NORTH SbOPE ALASKA PUTNA~ 629136 ICE PAD 11544. 1152<~. 36. Well Name API Serl, al Number Field Location SeCtion Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From ,~bove ~ermanentDat~m Elevat on of Kelly Bushin. g levat on of Grot]nd Level Total DePth - Driller Total Depth - Logger Bottom Log Interval TOp LO0 Interval Orlll. iDg Fluid Type IS Tape Veri~ication l..,istin~ chlur~herg.~r Alaska Pom~.)~t.!nG Center 1.3:11 PAGE: 14 q? 11 ,. y V a L U [) F, F I mm~em~m~m~eemmm,~,m~m~m?~! me ! mm mmm~ bFl) dlC3 ,. Dr 1 ng Fl u.. .d tv Drilling Fluid Ph Drillln~ Fluid Viscosity Orll!ing Fluid Loss aesistivit¥ of Mud Sample ~ud Sample TemDerature Resistivity of Mud Filtrate gud Filtrate Sample Temperatu Resistivity of Mud Ca~e SamD1 gud Cake Sample Temperature Bottom Hole Temperature mmmmmm! mmmmmmem. ~ ~ ~ mmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmmm!, mm mmmmmmmmmmmmmmmmmmmmmmmmmmemmmmmmmmmmmmmmmmmmmm TA{~I,E TYPF : CURV [> ~ F 'r })EpT DePth DDTP DiD ?rue IDDAZ l)io ~zimuth ** DATA FORA~A'r SPEC.IFf ,tx is! ( .... TT.O ~-,',ECOP, D ** ** SET TYPE - 64, EB ** TYPE R~'~',PR CD[)E VhbllE 1 66 0 2 66 0 3 7:3 12 5 66 6 73 7 65 9 65 li 66 85 12 68 1 ~ 66 0 !4, F~5 VT 1.5 66 68 16 66 0 66 IS Tape Verification LiSt]hq cblumberqer Alaska Com,outinc~ Center 2-AF'R-1995 13:!1 PAGE: 15 ** S~;T TYPE - C~AN ** mmm mm mmmmm mm mmmmmmm mm mmmm ~m mmmmmmmm mm mmm mmmmmmmm mmmm DEPT FT 629136 00 000 00 0 5 1 1 4 68 0000000000 DDT~ FAil OEG 620136 O0 000 0(; o 5 1 1 4 68 0000000000 [)~A7 wAU D~G 629136 O0 000 00 0 5 1 1 4 68 0000000000 ** [)fi'fA ~* D~p'r. t0800.42~ r~P~'R. F'A U 26.326 Dt-'AZ. FAU 346.578 DEPT. 10800.426 !)PTR. FAI,.~ 26.326 DPAZ.FAU 346.578 **** FI[,,~. TRhI,'I, ER FILE ~",[~ME : OlP S~RVICE : ~bIC V ERS I r').N : O01CO1 DI]'~ : 05/04/ NIX REC SIZE ~ 1.0~4 FILF TYPE : I.~[,) * * * * F I L E F.I E .h [) [!.] iq *, *, FILI~ NA.~E'; : DIP .006 S~RV,,[CE ~ FLIC V~RSION : OOl CO1, DhT~ : 95/94/ 2 M,~X REC SIZE : 1024 FIL~: TYPE : LO bAST WILE ~ ,F I L E !') I P . () (,) 6 ,SAMPLE ~A, TE: VAPlAB E , C" ':. ' ' ;IS Tane Yer].iicatton hist. i. na chlu~herqer ~.l. asKa Co~.'[.;L]tlna Center PAGE: 3"A.b'f.E TYPW : ~* E 0~ ~ Com V Name ',,p , T.. N Dan F ~,' ~' I b D C A T ADI~ 50-62q-~2533 FL 3334'$~t, g 4770'~,~Eb SEC~ 3 Tn~<N 9N COUN NORTH SLOP~: STAT N.STT USA SmN ~29~36 PPAT ICE P.~D EPD ~T 4, L~F ~:7 A P D EKB PT 38, EDF TDD TDL BLI FT 1 1524, TLi wi 36. DFT CrlRF' ~L,JD DFD G/C3 12,5 DFP~ 7. DvV S 76. D F L R ~c S 0 H ~ ~,~ O, 743 ~ST DEGF 66 MFS ,T DEGF 5 5 R~CS n FI ~4't,~ c, 3 B~T OEGF' 158, Field Name Well Name lpI serial Number Field Location Section Township Ranqe Cou6ty State or Province Nation Witness Name Service Order Number Permanemt datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushinq Elevation o~ Derrick Floor Elevatlon of Ground Level Total. Depth - ~ril!er Total Depth - Logger Bottom Loq Interval 'Top Log Interval Drllli~,q Fluid Type Drllllng Fluid Density Dr 1,11n6 .Fluid Ph Drilling Fluid Viscosity Drilling. Fluid boss ReslstiPitY of MUd Sample ~ud Sample Temperature Resisti~itV of'M~ld Fi,ltrate $ ~ud Filtrate Sample TemPerat%~ Resistivity of MUd Ca~e Sampl ~ud Cake sample Temperature Bott6m Hole Temperature T~B! ~ TY,PF, Cb .V P~Pm De thp DPT~ Di.o Trt]e D~AZ Oir~ ~z,i. muth Tape Verification 10istinq chlumberqer A.las~a Computlno Center 2-APW-1995 1]:1i 17 2 66 3 ~3 12 · t 66 0 6 7 65 9 65 1~ 66 IP 13 66 0 14 65 15 66 6~ 16 66 1 ** SET N~MF S.RV D~pT FT DPTP FRC DEG Dmi~ FRC DE~G TYPE - CHAN ** S., P V' I: (:' F:A P T ,6 P P .I ~, E [l'~l N U ~4 B S Z R :F ~ R ~ ~ ORDE~ ~ LOG TYPE CLASS ~OD NUMB SiMP ELEM CODE (HEX) 6291 ]6 O0 000 O0 0 6 1 1 4 68 0000000000 629136 O0 000 DO 0 6 J. I 4 68 0000000000 629136 O0 000 O0 0 6 1 I 4 68 0000000000 ** DATA ** DEPT. 9647.260 DEPT. 11252.225 ** rND [)F' r)ATA DPTR.FRC 78.4i~6 DPA,Z. FRC ,9,15.349 P~. ~' R. ~"~C 80.999 oF,AZ. FRC 237.34~ IS Tape Verification Listino ChlU~,~erqer Alaska Comp,]ti. no Center SFPV!CE: : FLIC D~TF : g5/04/ 2 ~X ~EC STZW : 1024 F~L~ TYpE : [,[3 b.SST FiLE PAGE: 18 **** FILE FILP NA~E: : ~iP .007 S~RviCE : ~LIC VFKS!O% : O0~C:O1 DATE : qS/O4/ 2 ~hX ~EC SIZ~ : ~024 FIL~ TY¢Ei : bAST FI[.,E FILF,, DIP 007 ********l**** ,$l.,P BIDS'OF SL.~UI,~IPS PICKED FROM F[~,I INAGES T~BLF: TYPF : CONS TUN! VALU DEFI Chi BP ~X'P,bO~ ATION FN ~t,' I LDCA T APIN 50-629-2253] FI.: 3334'SN[.., & 4770'~E'b SECT 3 R ~ i,,JC 20E CObN' NORTH SLOPE STAT ALASKA N ~ T l U S g W I T ~ P U '1',' N A ¢~ SON 6~91,36 PDAT ICE PAD EDD FT 4. Com n~ Name Fie~a d Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order Number 'Permanent datum Elevat,iOD of Permanent Datu~ 1S Taoe Verl.£~.catJ. on l~.[stlna chlt]mberqer A].asKa Compt~tinq Center 2-APR-I..995 13:11 PAGE: . m mmm m mm mmmmmmm m m mmmmmmmmmmllm~mmlmm mmmmm m mmmmlm~m, mmmmlmmmmmmmmmmmmmmmmmmmmmm - Log Measured Fro~ APD WT 34, E~B PT 3~., E:C-L ~'T 4.1 T.~D %'T 11549. 'I'DL w! Il 544, Bt, l VT 11524. 'I'I, I PT 36, D?T CORE ~,OD DVD C/C3 DWP~ 7, DFV S 76, D~[, P'3 4. b R~S nH ~ t,.~ 0,743 ~gT DF]GF 66, ~FST DEaF 5~ R.CS O.H ~ ~',i 2 ~3 ~bove Permanent Datum Elevation of Kelly Bushina ~levat~on of Derrick Floor Elevation of Ground Level Total. Demth - Driller Total DeDtb - Lo~qer Bottom LOQ Interval 'tod Log Interval Orllllno Fluid Type Orillin~ Fluid Density Drillin FlUid Pb Drilling. Fluid Viscosity Drlllin6 Fluid Loss ~esistlo~ty of Mud Sample ~ud Sample ?em~erature ~eslstt ity of'~ud Filtrate S ~ud Filtrate Sample Temmeratu Resistivit~ o~ Mud Ca~e Sam~l ~ud Cake Sample Temperature Bottom Hole Temperature TYPE : CURv ** PA'FA FORPAT SPECTFTCAT.TON PECO~D ** 1 66 0 2 66 0 3 73 12 4 66 0 5 56 6 73 7 65 ~ 73 9 65 1! g6 85 1.2 68 I8 Wane vertf, icatfon I,,tstln~ chlumberqer AlasKa Comp:_~tino Center PAGE: 2O ** SET TYP~ - Ci,tAN ** .... 6291 000 0 7. t 1 4. 68 0000 DPT~ SLD DEG 620130 O0 000 O0 0 7 1 1 4 68 0000000000 DPAZ S[,P DEG 62°1~6 O0 PO0 O0 0 7 1 1 4 68 0000000000 $~ [lATh ** DEP'r . 0903.918 DPTR o S[,,P -999.250 DPaZ.St,P -999.250 DFPT. 11299.14..~ DPTR.SLP 18.01l D.PAZ.SLP 346,852 **** FILE TRAIL. ER **** FILF NA~qE : DIP .007 S~VICE : F,bIC VERSION : O0!C01 DaTE : ~5104/ 2 ~AX REC SFZE : 1.024 F.~L~ TYPE : LO L, ~ S q" F I [.,E : **** TaPE TRh ILgtl **** SERVIC~.'i }~ia,~,'lE : DIP D./%TF'. : 95/04/ 2 T~PF ~d~[:: ~ 05090 PREVIOUS TAPE : CO~'{~E~T : BP EXP!,,ORATIO5, ¢~![,,[)CAT, B~[)AMI ~5, 50-629-2253,3 I$ Ta.e Ver~,f~cat~on l, isti. D~. cblumberqer ,~lasKa Com~)utir~ Center 2.-APR-19~5 13:!1 PAGE: 1. * AbASKA COMPUTING CENTER ****************************** * ....... SCMLO~BERGER ....... ****************************** W~£Lb f',i'ANE : BADAM,I ~5 F,IMLD N A~,~,; : WIbDCAT MDROUGH : NORTH SLOPF, STATE : ALASKA API Nt.I!~ER : 50-629-225~3 REFERENCE NO : 95090 RECEIVED APR 1 0 Alaska Oil & Gas Cons. CommissiOn Anchorag.~ IS Tape veri'flcstion ~,.isti. nq chlumber!jer Alaska Compt]r. ina Centier 27-.~IAR,.1995 11:30 UJII~DCA?, BAD A,',I I ttS, 50-629-22533 **** TAPE HEAiJE $~RViCE r,IA~,F, : ~ DATP : o ORIGIN : F' 'I'AP~ NA~:E : q COS~I~,~UA'f~ON ~ : 1 PREVIOUS TAPE : DTf 5/03/27 LIC 5090 ** ** ** ******************** ******************** COMPAUY NAME: BP EX v~FTLL: BADAM P I E L, [): w .[ L D C BOROLJGH: NORTH $~'A ...... AbASK AD,I NI,.I~ER: 50'62 API NI,ID"~BO;R: LOCATION: 8ECTIO.N: SECTION: PERMANENT DATUA~ bOG ~4EASI..IRED FRO LOG MEASURED FRO ELEVATIONS ELEVATIONS KB bOGGInG D!oT bOGGING ENGINE<~ ~ITNESS: ***************** RUN ~LT~BER: 1 L)~,T~I LOGGED: 25 'lid DRILLER: 45 TD LOGGER: .44 BTT SIZE !: TYPE F[.,,UID IN HOb EXPLORA~IC)N, WILDCAT, bAOA?,,iI .~5, 50-6~9-22533 *************************************************************** ************************************************************** * * S C H !.~l..~lv! BEI~ G ~ R GEL~QUEST , *********************************************************** ********************************************************** ********************************************************** PI,,O~ ATION' SbOOE 9-22533 9-22533 334'SN~ & 4770'wEL TCIWNS'HIP: 9N RANG~: 20E TOWNSHIP: 9i< RANGE: 20~ ICE PAD ELEV'~TION: 4' ' . '~ '" N T KB 34 ABOVE [gRgANE 0ATUM KB 34' AgOV'g ,.~.,RgANENT DATUM 38' DF: 33' GL: 4,1' 38' DF: 33' GL: 4,1' KEN A I d, CRYgR ***************************************************** (~,~URFACE RUN) -,J AN- 1995 04' 99' " !a IDR,I[,,I..rER .r)EPTH 0~" 11..0' a 110' PAGE: IS Taoe Verification .[,ist].r~q 27-~AR-!995 11:30 ChlUmberger Alaska Com~:utinq Center D~NS!'I'Y: 9.4 VI[SCOSITY: 200 Pal a.4 Fb~iID LOSS: P~t: a.4 FhUID LOSS: 18.4 ~,~I,[) RESISTIVITY: 2,96 ~ 61 DEGF F'I~TglTE ~ESISTI~!'i'Yl 2.29 ~ ~1 :~Tli) C~K~ ~ES!S'flVITY: 2.6'2 ~a 52 ************************************************************************ i~TE L[]GGED: 9-~Eg-1995 'rD DRIbLEP: 957S' TD I,,DGGER: 9554' C~SI;q~ ~I 13.37b" ~ DRIoLER DEPTH OF 4495' BIT 3IZE 2: 12.25" ~a TYPE FL. UI~ IN ;tOI,~: LS~vO DEhISITY: 10.1 '~IlSC(']$IT~: 53 P~!: lo.2 Fbi.III) L,L~S5I 4.6 PM; I0.~ FDI..IID L. OS~: 4.~ t'~l;D RRSISTIVlTY: 1.95 ~ 74 D~,~[' FILTRATE RESiSTIvITY: 1,62 ~ 60 :'a~P CaKE RESISTIVITY: 1.iq ~ 60 DEGF ~vlXIMIIM TEt4. P RECURi)ED: 132 DEGF *********************************************************************** RIIM NUMBER: 4 (Ti) RI. lq) [')ATE LOGGED: 3-~,~aa- 1995 '.!.' t~ DR'Ib[.,E~: 1154g' ~,~ ,,GER 11544' C~SIN~ 3: 9.625" ~ DRiI.,L~R DEPTH OF 957~' BIT SlZ~i 3: a,5" ia 11549' TYPE FbUID IN }IDLE: COR'({ ~UD DE',~,~SI'I'Y: 12.5 V:iSCOS!TY: 76 P~t: 7 FLUID LOSS: P~t; 7 FL~ID LOSS: 4.6 ~!,~D RESISTIVITY: 0,743 (a 66 DEGF FILTRATE ~ES.ISTIVITY: 0.498 ~ 59 DEGF ;'ql~D C.~KE RESiSTIVIYY: 2.3B ~a 66 DEGF M.~,X:If'~UM 'rEMP ~ECORi)ED: 15S I)EGF ************************************************************************* ************************************************************************ SCFfLUMBERGER GEO()UE;ST JOB REFERENCE NO: 95090 TECHi'.~ICIAN/ANAbYST: R, TFCHNIC.IAM/AN.~LYS"P: R, KRUWELL 8IGNIFICA. NT REMARKS: . ~'" . , '' ~ '~ T 0~, HiD T. . ~'1' . 1 )FILES D!T 001 EDIt..,.)02. EDI .... .0 I 004, ED ..... r oo5 CO[:iTAIN CU'RVES ~},.A HAVE BEE.i ( D~PDED SO'ITHAT O~',}'LY VAI, ID D~TA IS PRE'SE DATA CHANNELS };'R.O~ COHO!ON TOOLS HAVE 6EP2N MERGED AND ALD DATA CHaNNEl,, SUFFtX'S REFLCCT THE TYPE OF T~O'b THEY WERC ~COUIRED I3Y. P '~ . ,. ~..tF CH~NME[,S GR 'MER, ~SP.'MCR, AMD CAbI.MER ARE C[]~PO,~I',TED Ci..'tANi~EI.S GIVE AS Cfl'N'~'IM[iOUS AS POSSIBLE gANl~.'~a RaY (GR,NE~), SPONTANEOUS P (') T E r,!".l ...... I Al., (8 p . r~ E R ), a i'll t) r' A t i P E R ( C i.L, I M ~; R ): T " " ~ "' ~'~ il,,$~4 TO 9577' (THE ,D RUN) 2.]OATA CHANNEDo (')VE:'.R ~.f,,IE:; ].,,I',~ERVAI,, FRO , 'HAVE BEEN DEPTt~ Ct'.)~REC'rED TO THE FO~<~A'r.,[ON MICRO I,'4AG.ER TOOL, (F;'qI). THE GA~'IA RAY FRO¢4 .'.PI:.IE; F'fqI ,(GR,FM]',:) IS iNCLUDED I~'~ FIDE EDIT.O01 FOR COHPA. RISOrq l~(] DEPTH CLiRF, LCTI NS WERE APPLIEI)':to THE SURFACE !NT'EPMEDI ATE 3, ) F :L I,,, E'S E 01 T ¢, ~ ,~;, T .Of) 6 THRI! MI) IT 016 ~.u~, ~b, IN [4E t tNEDIT~',D RAW FIEDD UAT , ~' ,, PAGE: IS TaPe Vertficat~,on ],istfncJ chlumberger Alaska Computinn Cer~ter 27-~AR-1995 l J, :30 SFRVICI.] : Fb~C ~ERSIO,I : 001, C0 !. D h T F : 9 5 / 0 MAX t.~(.: SIZE : 10'24 FILF TYPE : LAST FiLE : FIIJ~ EDIT 001. *********;*** S~PLE PATE: , D 7.,' ['] PMA~5[]R I N DUCT I0. ?.,! ,bSJ LONG SPACED SUNIC (REPROCESSED DT COMPRESSIONAB PUE TO CYCLE SKIPPII'~G) .DSI DIPOLE SO~!C I~AGEP TOOL ,CN',,? C0~,~'PENSATEI) NE[I'fR(,]~'~ TO(II,, .NGo NATURAL G.Ai"4~'iA RAY ,~"r,,- Tnt',, ,~qER ~ANMA R.A.Y~ SP[INTAIN~][)[iS P[)TEMT%A[~ AND CAI~ICER.. CO",~,POSIrEL" ~'3 T~] MAKE gA C ~'t C H A h.l ~x~ E L, A S C 0 ~:~ T I ~.i 0 ~.~ S h $ P 08 S I B ~,, g CO~aPARISON ThBt, E TYPE : C0~15 TU i'~l T V ALU' DEF I CN BPONExP.~'~[IRATi Company Name Field Name Well Name APl Seria~ N'umber Field hoc tlon Section Township Range County Stage or Province ~ation ~itness Name Servlce Order Number PermaneDt datum Elevation of PermaDent Datum I8 'rat, e verificat, fon r,/stinq chl. ur~'~ber(ler A]asKa Co:nputing Center 27-NgR-~905 1~: ~0 PA6E~ 4 T~I~4 i V hl.,IJ DEF! ...............................................................................................' ' ~ I Meas d F b Jo~. ute ro~ ~T FT FT ~T G/C3 $ F3 DEGF DEGF 4o 38, 33. 4.1 l!549, 1;544. 11524. 36. CORE 12.5 7 4.6 O. 3 66~4 55, 2.33 ~bove Permanent Datum Elevation of Kelly Bushing Elevation o~ Oerrlc~ Floor Elevation of Ground bevel Total Depth - Driller Total Dept~ - Logger Bottom boq Interval ToD [.~oG Interval Drilling Fluid Type Orillinq Fluid Density Drillin~ Fluid Ph Drilling Flui~ Viscosity Drillin~ Fl~]id boss ResistlvitY of Mud Sample ~ud Sample Temperature Resistivity of Mud F~ltrate S ~ud Filtrate ~ample Temperatu Resistivity of ~ud CaKe Sampl 66, ~'ud Cake Sample Temperature ~HT DEC. F 158. ~.Ot. to~,, ~lole T.e~perature T~B!,,E TYPF~ : CURV DEFI DePth SFLU I D p C I D r' CI~P OTCO. DT4P DPH I P~F C~,I TC CFTC HSG~ SFL Resistivi. ty Unaveroc~ed Ii',~DUCTION I)EEP PH.~SOP RESIST!VITY 1 I'~ [) ~..1 C T I O ~ i.",) k; E P P H A S O R C C,~ ~ L) Lt C T I V .[ T Y I N D U C T ! O ~ }~ a D ! U t%,~ P N A $ O I { C (3 N' D J C T I v I T Y DELT.~-T COt'4P~ESf~IONAL DEL'rA-T CO~'4PRESS IClb,IAL DELTA-T SH. EAt~ UPPER DiDOthE blOOE COMPENSATED Poisson's Ra, t ~o gtl,1 k Densi't~ Densit Pot Delta P~otoElectric Factor ~eutron Porosity Thermal Neutron ~at. io Calibrate~ Corrected Near Thermal Counts Corrected Far Thermal Counts ,.~o ~t. aBdard dam~tla Pay t.4NG~ Corr~Du. ted Gamma Rely H~GS Thorium Concentration HNGS uranium Concentration gt~G5 Formation Potassi~.lm Concent. ration HNGS Borenole Pot. ass.iu,', Concentratlon Gamma Ray IS Tape Yeriiicati. on Listinq ChlLlmbercler AlasKa Computinq Ce;~ter 995 i 1.: 30 PAGE: T Spontaneous Potent Caliper Gam~'~a Pay Temperature Res ist.~ vi tV ** r~ATA FORMAT SPEC[FTCATI[]N RECO~D ** ** SET TYP~: - 64E~ ** 1 66 2 66 0 3 73 J20 4 66 l 5 6 73 7 65 8 68 0.5 9 65 ~T 1i 66 12 68 13 6~ !4 65 15 66 6~ 16 66 O 66 0 ** SET TX'P}!;- CH,AN ** r,~Ai,4F SERV Lt~,~iT SF, PViCE APl API AP1 API FILE NL.iMt~ N{j~'B SiZM3 RMPR PROCESS ID O~I)ER ~ I, OG TYPE CLA~,S MUD NUMB SAMP F, LE~ CODE (HEX) DEPT FT 629!. i)6 00 000 ()0 0 1, 1 1 4 68 SVLI~ DTE OHMM 62'9i36 O0 000 O0 0 1 1 ,1, 4 68 IDP~.~ DTE ()}4M~ 629136 00 000 00 0 1 1, J 4 68 CTDP DYE M~4HO 629136 O0 000 O0 0 I I. ]. 4 68 I. F~ P ~"' P T E L) H.~'~ M 629 ~ 36 00 n 00 00 0 1 ]. 1 4 68 CIMP DTF M~O 629136 O0 000 O0 0 i ], ]. 4 68 DTCO LSS US/F 629136 O0 ()00 O0 0 1 I 1 4 68 DT4D DSI US/F 629136 O0 000 O0 0 1 1. 1 4 68 DT2 DSI I~S/F 6~ 136 O0 000 O0 0 1. 1 i 4 68 P P D S ~ 6291 36 00 000 00 0 1 I 1 4. 68 R. MOD LDT G/C3 629136 O0 000 O0 0 1 1 1 4 68 DPH~' LDT PU 629~36 ()0 OOO Off 0 1 I ~ 4 68 D~RD LDT G/C3 629136 O0 ()0(:) 0~ O i 1 J, 4 68 PEF LDT 6~91 ~6 O0 000 O0 0 1 1 1. 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tave Verification l, istin~ CblUmt, erger AlasKa Computinn Center 27-,~A~,-19q5 1.1:30 PAGE: TD ORDER t, hOG TYPF CLASS :~[ID ,qUME SA.qP F. bEM CODE (HEX) q'[; kh C ~',1T 629i36 C~'~.'C CNT CPS 6301'~6 CFTC CMT CP~ 629136 HSGP NGS GAPI 62~36 bCG~ ~GS GAPI 629136 HTHD NGS PP~ 62913e t~l'R A NGS PPM 62q13~ HFK NGS PU 629136 HFHK N(;S PU 629136 G~ ~'ER GAP/ 6201, ~6 SP ~EP r~V 62~i .~ C~ I.,I r~ER IN 62~I3o G¢ F,',~I G~PI 6291 ~6 ~'EP AMS DEGF 62Q136 ~PEg A~4S OHM~ 62~1]6 . mi ~ ~ ~ m m m mm mm mm m mm.mmmllmmmm mm.mm m .iim~! im! ImmlmM! .m . mmmmmmmm#mmm m m m m PU 6201 O0 (). . 1.} 0 1 1 58 0000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 o 1 1 { 4 68 0000000000 O0 oon O0 0 1 1 I 4 68 0000000000 O0 000 O0 0 i I ! 4 68 0000000000 O0 OOO O0 0 1 1 1 4 68 OOO0000000 O0 000 o0 0 1 1 1 4 6~ 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 O0 ()00 oo ~ 1 I 1 4 68 00o0000000 (,)0 o00 O0 0 1 1 1 4 68 0000000000 O0 000 Om o 1 I '1 4 68 0000000000 On 000 O0 0 1 ~ 1 4 68 0000000000 O0 000 OO 0 1 I. 1 4 68 O00OO00000 O0 000 O0 0 1 i I 4 68 0000000000 O0 000 On 0 1 1, 1 4 68 0000000000 O0 000 O0 0 1 1 I 4 68 000()000000 mm m mm...m! mm.mmmmm..mm~mmmmm~mmmmm m~! mm. [}EFT. 11524. OhO I M P[-~. DTR -999. 250 DT 2, D 5'.1' -999. 250 I.)RHO. LDT -999. 250 CNTC.Ct,tT -999. 250 [,{T.[tO~. NGS -999.25O GR.'MCR -999. 250 MTE~,~. A~qS 154. 774 D E P T t 14. 0 (). 0 00 I ~P~: DT[,?, -999.25(',, DT~'D8!' 143.346 DRHO.LDT -999.250 CNTC. C/4T -999. 250 HTHP. NGS -999. 250 GR. ~gR 79. 356 ~TE~. ~4S !56.2!8 I)EPT. 112(10.000 !~PH.DTE -999. 250 DT2. DST :140.3(}8 D~tiO. bDT -999,250 CNTC.CNT -999. 250 HTFIO. NGS 3. 567 GP.N~ER, ~9,498 ~TE~ . ~)',,i $ 154,775 $ ~'!.,, U. b',r }~; -999.250 !DPH.DTE -999.250 C!DP.DTE CiMP.DTE -999'250 DTCO.I~SS -999.250 DT,4P.DSI PR.DSI -999.250 P}tOB.LDT -999.,.9,50 DPHI.LDT PEF.LDT -999.250 NPHI.CNT -999.250 TNRA.CNT [~'TC.CNT -999.250 HSGR i~G8 999 250 }tCGR.NG8 ~!]~,A.~,~L.$ 999 250 HFN.i4GS 999 0 ,HB~K NGS .... ,,-', - . ' ' : ' , . SP. ~'~ER .14.688 CALI.MER -999.250 GR.F~I ,RES. AYeS O. 384 SF'LO DTP2 -999.250 IDP!',I.DTE -999.250 CIDP DTE . ,. . r~ "' " ' *~ p CIMP:DTE 999 250 DICL).bS$ -999 250 ,0174. :DSI PR.DS% 0.293 RHOB.I'.,~DT -999,250 DPHI..I, DT PEF.LDT '999.250 ~lP~i.CNT -999.250 CFTC.CNT -999.250 HSGR.NGS -999.250 HCGR.NGS HURA.NG8 -999.2.50 HFK.aGS -999.250 HBMK.NGS . ,LR 7 81.3 C~Li gER 8.309 GR.FMI ~RES, AMS O. 384 SFl,iJ . [)T~ -099.250 'It)PH. DT,~ -999 250 CI[)P. DTE C I M P . D T E - O 9 g . 250 D T C 0 . ]b ,$ 8 -999: ,9,. 50 O T 4 P . D 5 I PR.D$I 0.224 RHOS.bl)T -999.250 DPHI.LDT PEF. I,,DT -999.250 NPHI..CNT -999.250 TMRA.CNT NOS 33 359 HCGR.NGS CF~'C.CNT -999.250 HSGR. . HI,IRA.)4GS 1,.2~3 HFK ~IC, S 0.775 HBBK NGS SP.NLR -5~ 43a CA!.~I. ,ER 7.651 GR.FaI !4RES. AMS 0.39 1 -999.250 -999 250 -999:250 -999.250 999.250 99,250 ~99.250 -999.~50 77. 07 -999.250 -999.250 -999.250 -999.250 -999.250 '999..250 87.290 -999.,250 -999.250 25.295 0.183 29.49B IS Tape Yerif.~.cation ,'_,ist. i. nq chlUmberoer AlasKa Computi. no Center ] O00.000 SFI,!J.DTE 144.8 ]5 P~. -999. 250 PFF. bDT i9Q9.25(,,~ CFTC. C~,~T 8.825 Hi]RA.NGS 1,47.188 51~ES. A~S D~,pw. i0800.000 SFbi.~. O'rE DT~. PSI 1 ]6.336 PR. DSI DPHO. LDT -9~9. 250 PEF. LOT C~TC.C:qT -9~9.250 CFTC.C~T ~ T [.', ~.~. ,~S 145.6 80 u RES. A~'~S DF~Pqr. I0600.000 SFLU.i)TE ImPH.DTF] -999.250 CI~P.DTE DT2.DSI 138. 828 PR.DSI DPHO. LOT -999. 250 PKF. LDT CNTC.C~T -999.250 CFTC.CNT ~,{TH~. NGS 10.781 NLI[~A. NG8 GP. ~[fR 69. 704 SP. ~ER DBi:PT. 10400.000 SFLU.DTE I~PH.DTE -999.250 CI~P.DTE DT2. DS! 138. 288 PR.DSI D~HO. LDT -999. 250 PEF.bDT CNTC,CNT -999.250 CFTC.CNT HT;{O. NGS 13.360 HL;RA.~qG6 GP. ~EP 69. 798 SP. ~ ER ~,~TE;~4 A,~S 141.80I ~RE;& A~4S DFiPT. 10200.000 SFLU.DTE ! ~ P;'~ . DTE -999.250 C!~P.DTE DT~.DSI -999. 250 PR. DSI DPklO. 1,DT -999. 250 PEF. bDT CNTC.CNT -999.250 CFTC.CNT HTHO. ~,,~S 10.330 HLIRA. ~,~GS GP. ~ER 79. 000 SP. ~TE~'~. A ~S -999.250 DF, PT. I0000.000 SFLU,DTE I ~,'~PH. DTE -999.25O CII~P. DTE DT2. D$I -999. 250 PR. D8I I.)R,HO. LOT -999. 250 PE'.F. LDT Ch~TC.CNT -999.250 CFTC.CNT HTaO'NGS 10.232 F!U~A. NGS GR, ~ER 72. 851 SP.,~ER -,,~ vL.,,-,~, A~S -999,250, 27-!4.!~-1.995 11:30 -999.250 .! DPH.I)TE -999.250 DTCO.LSS 0.208 Ri~OS.LDT -999.12.50 l,iPH i. C,NT -999. 250 H~qGR. NGS 2.489 HFK.NGS -53.6~1 0.~1~ -999. 250 IDPH. DTk: -q99,250 OTCO.LS$ 0.236 RHOa.bo'r -999.250 ~.iPHI.CNT -999.250 2.692 hFK.,>~GS -54.1 ~8 CAI, I. 0.413 -999.250 !DPH.DT5 -999.250 DTCO.bSS 0.254 RHOS.LDT -999.250 MPHI.CNT -999.250 HSGR.NGS 2.452 HFK.NGS -66.92] CALI.MER 0.417 -999.250 !DPH,.DTE -999.250 DTCO.bSS 0.~37 ~HOS.LDT -999 250 NBHI.CNT -999:250 HSGR.NGS 2.687 HFK.NG8 -64.820 CALI,t~R 0.431 -999.250 IDPH.DTE -999.250 DTCO.bS$ =999.250 RHOB.LDT -999.250 NFHI.CMT -999.250 5.587 -999.250 CALI.NER -999.250 999:250 D '999.250 ~HOS,bo'r -099 250 NPHI.C~T 3.35~ HFK.NG$ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 76.485 1.785 7.576 -999.250 -999.250 -999.250 -999.250 70.102 1.452 9.125 -999.250 -999.250 -999.250 -999.250 81.984 1.806 9.418 -999.250 -999.250 -999.250 -999.250 100.947 2.348 11.~88 -999,250 -999.250 -999.250 -999,250 1.08.199 2.1,27 -999,,250 -999 250 -999i250 -999 250 -999.250 88.086 1.840 -999,250 CIDP.DTE DT4P.DSI DPHI.I, DT T~RA.CNT HCGR.~GS HBHK.NGS GR.FMI CIDP.DTE DT4P.D$I DPHI.I, DT TNRA.CNT HCGR.NGS HBHK.NGS GR.FMI CIDP.D%E DT4P.DSI OPHI.LDT TN~A.CST HCGR.NGS HB~K.NGS GR.FMI CIDP.DTE DT4P.DSI DPHI.LDT TMRA.CNT HCGR.NGS HBHKoMGS GR.FMI CIDP.DTE DT4P.D$I DPNI.LDT T~!RA.CNT HCGR.MGS GR.FMI CIDP.DTE DT4P.D$I [)PMI.LDT TNR~.C~T HCGR.NGS HBHK.NGS GR,F~,I, PAGE: -999.250 81.596 -999.250 -999,250 60.148 0.289 63.139 -999.250 80.125 -999.250 -999.250 51.496 0.287 6[.220 -999.250 79.686 -999.250 =999.250 66.648 0.339 69.704 -999.250 81.181 -999.250 -999.250 84.533 0.443 69.798 -999.250 -999.250 -999.2:50 -999.250 7t.065 0.491 79.000 ~999.250 999.250 -999.250 -999,250 65,539 0.971 72,851 IS ?a~e ver~fication [,istt, nn chlumberger AlasKa Com{)ut.inq Center DEPT. 9800.000 SFLU, i)'l'E ].~"P~. ?)TE -999,250 CIMP.DTL DT~. DSI -999. 250 PR. [)S I D~M~. LDT -999. 250 PFF. [,,DT CNTC.CNT -999,250 CFTC.CNT HTMO. NGS 10.439 Ut~.A. NG~ GP,~ER 72.463 SP.MER ~TE~'~ . A ~,IS -999. 250 ~'~ R~S. A~S DFPT. q600.O00 ].%~PH. r)TF -999.250 CI~P.DTE UT?. DST -999. 250 PR. DSI DRH~, LDT -999,250 PEF, bDT C~TC,CNT -999.250 CFTC.CMT }tTHO.NGS 11,234 GP. ~ER 73.69~ SP.MER ~TE~'~. A,~S -999.250 ~RES.AHS DF, pT. 9400.000 SFLU.DTE IuP+~.DTE 7.280 CIN!P.DTE DT~. DSI 1 d, 8.945 PR. DSt DRHO. LDT O. 0 J. 0 PEF. bDT CNTC,CNT 2467.731 CFTC,CNT HTNO,NGS -999,250 HURA.NGS GP. ~ER 76. 567 SP. ]~'~ER MTE~!.A~S 131.529 ~'RES. A"Y,S DEPT. 9200.000 SFL[i. Dq.'g l'~P[~. DTE 5.048 CI~iP.DTE DT?.DSI 164. 695 PR.DSI DRHO. [...D'~ O. 029 PEF, bDT CNTC.C~T 2398.775 CFTC.CNT [,tTNO. NGS -999.250 ~{URA.NG$ GP. ~ER 86.830 SP. P~E.R gTE~.A~S 130.500 ~,~RES. A~iS Ill) E P T. 9000 000 S F L U. D'.T g iI~p~.~. D'I'F 6;304 DTP, PS! 152.1 ~4 PR.DSI DRHO.LOT 0.01.3 PEF. N CNTC.CNT ~595,759 CFTC,C., HTHO.NGS -999,250 HURA,NGS GP, ~ER 80,236 SP, DEPT. 8800.000 l~pu.o'.rE 7.125 CI,~P.DTE D~.'~,DSI 154,1,21 PR,DSI. DI~ H O. bDT 0.02 o PEF. CNTC.CNT 2493,358 CFTC.CNT ~THO, MGS -999,250 FIUR A. ~GS G ~. S,E R 77. I ~ I S P. ~ E'R t~T E~..A ~ S 128.098 ~RES. AMS 27-~AR-1905 11:30 -999.250 IDPH.DT~] -999.250 DTCO.I.SS -999.250 RHOB.I. DT -999.250 N, PHI.CNT -999.250 I.~,S GR. N G,5 2. 959 }tFK. NG$ -999.250 CALI.MER -999.250 -999.250 IDPH.DTE -999.250 nTCO.LS$ -099.250 R~Ob. LDT -~99.250 NPHI..CNT -999.250 }tSGR,NG$ 3.026 }tFK.NGS -999.250 CALi,MER -999.250 6.544 IDP~t. DTE 137.370 DTCO.L$S 0.292 RBOB,bDT 3.2b$ NP}tI,CNT 883.008 HSGR,NGS -999,250 HF~.,NGS -0,875 CALI,MER 1.33! 4.910 T. DPH.DTE 198.116 DTCO.bSS 0,312 RHOB.1;;DT 3,314 NPHI, CNT 810,993 .HSGR.NGS -999.250 Fi'FK. ~GS -5.750 CALI.M'ER 1.357 6,343 IDPh,DTE .140,358 DTCO,i, SS 0 o 282 R H 0 E%, L D'T 3,363 NPEI,CNT R53.572 HSGR.NGS -999.250 }.{FK, NGS - 22.938 C A L I. ~'~ g R -999.~50 -999,250 -999.250 -999,250 94,227 2,291 -999,250 -999.250 -999.250 -990.~50 -999.250 93,554 2,113 -999,250 7.244! -999.250 2,528 27,486 -999.250 -999,250 13,585 4 972 '999i250 2 564 3O 574 999,250 1999,250 13.741 6,226 -999,250 2 566 30~469 -999 250 14 5 ,, 7.052 -999,250 2,4.90 29,666 -999,250 -999,250 13,045 CIDP.DTE DT4P.DSI DPHI.I, DT TMRA.CNT HCGR.MGS HBH~.NGS GR.FMI CIDP.DTE DT4P.D$I DPHI.LDT I'NRA.CNT HCGR,NG$ GP.F~I CIDP.DTE OT4P.D$I DPHI.LDT TgRA,CNT HCGR.NGS MBH~.NGS GR.FMI CIDP.DTE DT4P. DPHI ,LDT .I RA CNT HCGR:NGS' H B H K . N G S GR.F~I CIDP,DTE OT4P, DS I DPH I, I,,DT TNRA,CNT HCGR,NGS ,HBHK. NG$ GR .FMI "I E ( DP .DT DT4P:D$I DPHI.LDT TNRA.CNT HCGR,NG$ MBHK.NG$ GR.FMI PAGE: -999,250 -999,250 -999.250 -999,250 74,410 0,466 72,463 -999.25O -999,250 -999,250 -999,250 73,621 0,955 73,696 138.052 80,785 7,409 2,792 -999 2.50 -999:250 -999,250 201,144 86,023 5 04 -999,250 -999,250 -999,250 160,609 84,327 5'070 2,991 -999,250 -999 250 -999~250 141,797 84,960 -999,250 -999,250 :-999.250 .lis ?ave verJficatJ.,on [.,lst. ina chlumberger AlasKa Computinq Center D F p 'l. ~ 600.00 (? S ~' I., b. D T E IB'PP. OI'~ 5.205 CI[~P.DTF; r~T?. OS Y 165. 297 PR. DRHO, LDT O. 005 PFF. LDT CNTC.CNT 3058.173 CFTC.CMT H~H~.NGS -999.25(; Hg~A.NG8 G~. ~ER 37. Sql h~TE~. RES 1~7.509 NRFS.A~'~S DEPT. _~ 4C,(~. 000 SFLb. DTE I ~, PH. D'r ~? ~.461 CI~P.DTE DT?. DSI 154. 262 PR. DSI DP)~O. LDT O. 000 PEF. bDT CNIC.CNT 2900,051 CFTC.CNT HTHO.NGS -999.250 H~JRA.NGS GP. ~ER 55. 660 SF~. MgR DEPT. 8200.000 SFLU.DTE I~P.~.DTE 5.177 DT2. DS.I 1~-2.233 PR. OSI DRttO. I,,DT O. 0 ~ 5 PEF. LDT CNTC.CNT 2740.229 CFTC.CNT HTHO.NG8 -999 250 HU'RA. NG8 GR. MER 79 ~ 747 SP. MER P,iTEg.AMS 125.241 DEPT. 80()0.000 SFI, O.DTE I~Pg.DTE 6.196 CI~P. DTE', DT~.DSI 170.~50 PR.DSI DI~&O. LDT 0. 077 PEF. LDT CNTC.CNT 2148.061 CFTC.CNT HTfl~.NGS -999.250 HJRA.NGS G~ ~ER 73.906 SP. ~ER MTE~:A~S 1~4.04,4 ~RES.A~S DF, PT. 7800.000 SFLO.DTE IgPP, DTE 4.662 Ci~P. ~TE D'""'~DSI,, ,~, z 166.24.2 PR. DSI DRHO I,,,DT 0.0,16 PgF. cN'rC:CNT 24,62.03I. CF'rC.CN HTHO.NGS -999'250 BURA.NG$ GR. i~,~ g R' 65.8 B 0 SP. ~IER ,~4T'E;~. A 74 S 122.850 D~P,T'. 7600.000 SFLU 1.3 Tig 1'.~ pH. h" . [.I,E 6, 437 CI~P: I)TE~ PT2. DSI 163. 909 PR. DSI DRHO. LDT 0. 045 PEF. DDT C~iTC.CNT 2633.157 CFTC.tNT HTH~.NGS -999.250 HURA.NGS G~. ~ER 74. 387 BP. ~ER 995 11.: 30 5.922 TpPH. [.:TE !92.140 t)TCO.LSS 0.315 PHOB.LDT 2.4. !$ ~;pHI.CNT 1069.750 HSGR.~GS -999. 250 HFK. MGS I .364 5.$73 1DPH.DTE ~b4.7B1 DTCO.LSS 0.2~5 RHO6.LDT 2.524 ~PHI.C~T 1133.006 HSGR.NG$ -999.250 HFK.~GS -36.563 CALl.hER 1.3~2 4.426 IDPH.DTE 193.180 DTCO.LS$ 0.338 RHOB.L, DT 2.708 ~PHI.CNT 922.814 HSGR.NG8 -999.250 HFK.NGS -36.500 CALI.~ER 1.420 5.721 IDPH.DTE 1.~1.396 DTCO.LSS 0.311 RHOfi. LDT 3.~71 NPBI.CNT 652.11~ HSGR.~GS -999.250 }.{F'K.NGS -55.500 CALI.~ER 1.41`1 4.054 IDPH.DTE 214.5I)7 DTCO.LSS 0.293 RHOB,bDT 2.$72 NPHIoCNT 837.589 HSGR.NG$ -999.250 HFK.NGS -71.,188 CALi.~ER 1.432 5.537 -99~ 250 ,, . 2.253 28.061 -999.250 -999.250 12,393 6.039 -999.250 2.361. 24.607 -999.250 -999.250 12.979 5.064 -999.25O 2.344 29.321, =999.250 -999.250 13,1.16 5.962 -999.250 2.453 36.771. -999 250 12.495 4 871 -999: 5o 2 422 29i685 -999 250 -999.250 12.874 5.51,(i) IDPH.[,rE 6 661 ,1,55. ~48 DTCO. [.~SS -999i250 0,297 RHOB.LDT 2 506 3,342 NPHi.CNT 30. 011 , . - - 90~ 260 HSGR.NGS 999 25{ -999,250 HFK,.NGS -999, 250 1.458 CI'DP.DTE DT4P.DSI DPHI.I, DT TN~{A. CNT ttCG~. NGS H~h~. ~GS GR.FMI CT DP. DT4P.DSI DPHI. LDT 'rNRA, CNT HCGR. NGS ~BHK GR. F~', I CTDP.DTE DT4, P.D5I DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR.FMI ClDP.DTE DT4P.DSI DPHI I, DT TNRA.:CNT HCGR.NGS HBHK.NG$ G~.F~I CIDP.DTE DT4P.D$I DPH!.I,,DT TNR,A.CNT HCGR.NGS MBHK.NGS GR.F'SI DPbI'.LDT T~RA.CNT ,HCGR.NGS HBHK.NG$ GR.F~I PAGE: 180.588 85.852 24.044 2.831 =999.250 -999.250 -999.250 165.5B9 84.539 17.544 2.600 1 .25o 999.250 -999.250 197.467 90.072 18.560 2.915 -999.250 99.250 167 739 89:434 11,946 3.369 -999.250 -999.~50 -999.~50 205.290 89.989 13.829 2.939 -999.250 -999.250 -999.250 150,137 88.091 8.742 2.961 -999.250 :999.250 999.~50 IS Tame Verificatl. on f istino chlumterqer ~].aska Co~r[~t.itin.d Center DEPT. 7400.000 SFLU.DT{~ I~"PHoPTF 3.6~9 Ci~IP.DTE PT2.D$I 158.9~ 7 PR,DSI DPHO, LDT 0.013 PEF. C~TC.CNT 2702.196 CFTC.CNT HTHO.MGS -999.256 HUPA.NGS GP. ~.~ER 53,152 SP. DFPT, 7200.000 Sf'LU.DTE ]. ~ PW. D'.rF; 2.352 CIMP.DTE DT~. DS; 187. 465 PR. DS1 DPhO, LOT 0,005 PEF, bDT CNTC.CNT 2443.265 CFTC.CNT MTMO.NGS -999.259 g~}RA.NGS G~. ~Eg 57. 626 SP. ~qER ~TMU, A :~iS 119,230 MR~S,A~8 DFpT. 7000.000 Si:vLU. f;,TE 1,~P~;.DTE 5.145 CI~P.DTE D']'2. DS! 182.25't PR, DSI DRIED. L, OT. 0.037 PEF. LDT CN[['C. C~qT 227'70563 CFTC,C~T HTH~,NGS -999.25(; HURA.NGS GR, MER 69.818 SP, MER .NTEM. A~gS 11~7.743 MRE,S.A~S D ~ P T 6800.000 $ F [., U, D T g I~,P~: DTE 4.208 CIMP,OTE D'T'2. DSI 206,736 PR, DSI DRHO, LDT 0,0~5 PEF, bDT C~TC.CNT 2220,265 CFTC,CNT HTHO.NGS -999,250 NURA,NGS GR, MER 88. 352 MTE;~. A~S 116.3~7 MRES.AMS DEPT. 6600.()00 SF[,U.DTE .[ ~ p H. D T 'M 6.797 C I M p. 0 T ,< DTP. DS! 196.446 PR. DSI DRHO. [,DT O.O1C, PEF LDT CNTC . C ~ T 2 3 1. 3 . 3 6 4 CFTC ~ C ~ ? HTHO. ~G8 -999.250 HURA,NGS G~. ~ER 82, .4. 4 ~ 8P, ~R NTEM. A,~$ 1!,4.823 ~RFS,.AMS DEPT. 6400.000 IMpM.. ,,[).l. Ig 6,662, CI.MP,DTg DT2, DSI' 179. 229 PR. DS DPHO LOT 0 0]3 PEF' bDT CN~ C' ' .~ .... .CNT 2'493. 740 CFTC.CNT HTHO.NGS -999.250 HURA,,A~G5 NTE~{. A~S 1~3.~30 ~RFS.A~S 27-~AP-1995 11:30 5. 844 TDPH. DTE ~75.547 DTCU.LSS 0.271 Rk~Db. LDT 2.844 NPMI,CMT 95~.~06 HSGR.NGS -999.250 HFK.NG$ -91.0~3 CAI, i.~ER ~.458 3.024 IDPH.DTE 425.110 DTCO.LSS 0.330 RHOS.LDT 2.4:70 ~PHI.CMT 727.257 MSGR.~GS -999.250 HFK.NGS -111.750 CALI.MER 1.479 4.914 II)PE,DTE 194.363 DTCO.bSS 0.321 RHOB.bDT 3.014 NPHI,CNT 718.690 HSGR,NG$ -999.250 -76,750 CALI.~ER 1.495 4.551, IDPH,.DTg 237.665 DTCO.bSS 0.357 RHOB.bDT 3.464 MPMI.CNT 670,610 MSGR,NG$ '999,250 HFK,NGS -73,500 CALI,~ER 1.526 5.791 IDPH.DTE ~47.122 DTCO.bSS 0.346 RHOB.LDT 3 260 NPHI.CNT 737~59! NSGR.NGS '999.250 ~FK,NG8 -80,625 CALI.~ER ~.546 7.001 IDP[~. DTE 150. 113 DTCO. bSS 0,302 R~OB.L, DT 3.1~5 NPBI.CNT ~15,622 ~SGR.NGS -999.250 hFK,NG$ -]06,063 CALI,MER ~.552 3.626 -999.250 2.344 26.211 -999.250 -999.~50 13.01l 2.113 -999,250 2.251 35.998 -999.250 -g99.250 12.~82 5.1.24 -999.250 2.445 32.075 -999.250 -999.250 12.809 3 945 -999:250 ~ 456 999 250 :9992250 15.487 7 O20 -999i250 2 409 34, 225 -999 ] 250 -999 250 14~995 6.618 -999.250 2.358 32 13 ClDP. DTE DT4P.DS] DP?ti. [,DT TNRA.C~gT }iCGR. NGS HBHK.NGS GR. F~ I CIDP.DTE DT4P.DSI DPMI.I, DT TNRA.CNT HCGR.NGS HB~K.MG$ GR.FM! CIDP,DTE OT4P,DSI DPHI..LDT TNR~,CNT HCGR,MGS ~BHK.NGS GR,,F~I CIDP.DTE DT4P.DSI DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR.F~] CIDP.DTE DT4P.DSI DPMI.LDT TNRA.CNT HCGR.NGS HBHK.MGS GR.FM! CIDP.DTE DT4P.D~I DPMI.LDT TNRA.CNT HCGR.NGS MBRK.NGS GR.FMI PAGE: 275.784 89.040 18.533 2.707 -999.250 -999.250 -999.250 473.335 94.340 24.187 3.327 -999.250 -999.250 -999.250 195.151 93.604 12.449 3.098 '999.250 -999.250 -999.250 253i 11,728 3.236 -99~.250 -99 .250 "999.250 142.446 95.274 1.4.592 '3.230 -999.250 -999,250 -999.250 151.100 95.464 1'7,673 3.120 '999.250 '999.250 -999.250 10 iS Tane 'Verification Listlno chlumberger Alaska Computing Center DF. pT, 6200.000 IuPH,OTE 6.099 DT2,DSI 216.316 PR,DSI D~HO. LDT 0. 037 PFF, bDT CNTC.CNT 2029.022 CFTC.CNT HTHO.NGS -999.250 HUR~.NGS GP.~ER ~5,021 DFPT, 6000.000 SFI, U,DTE IMPu.DTE 4,532 C1NP.DTE DT~ ..,DSI 194.162 PR, DSi DPHP.. LDT 0.025 PEF.LDT CMTC.CNT 2103.708 CFTC.CNT HTHO.NGS -999.250 HL)RA.NGS GP, ME~ 74.251 SP, MTE~,A;~S 110.790 ~RES,A~S DFpT. 5800.000 SFLU.DTE I~p~.p'r~ 6.568 CI~P,DTE DT~.DSI 193.618 PR.DSI D~HO,LDT 0.011 PEF.LDT C~TC.C~T ~091.$39 CFTC.CNT ~THO,MGS -999,250 MURA,NG$ GP,~ER 72,435 SP,MER MTE~.AMS I09,6~1 ~RES.A~S DEPT 5600,000 SFLU DTE IgP}~!D"I~E 6,252 CI~P~DTE DT2 D$I 162.808 PR.DSI D~HO, LDT O, 039 PEF. LDT CNTC,CNT ~913'770 CFTC,CNT HTHO,NGS -999,250 HURA,NGS GP,MER 68.118 SP.MER ~TE~,A.i~I$ 1.08,895 ~RE$.AMS OFPT, 5400.000 SFLU.DTE I~P¢.DTE ~.168 CIMP.DT~ OT~.~Sl 257,630 PR.DSI DRHO.LDT -0,006 PEF.LDT CMTC.CNT ~772'778 CFTC.CNT HTHO,NGS -999,250 MURA,NG8 G~.~£R 76,426 SP,SER MTCD~.A~$ 107,68~ MRES.A~$ D~'PT. 5200,000 SFbU,DTE , D ~ ~ ' I~;P~~, ,. I'E 2.854 CI!~.P.DTE DT2. D8I 244. 593 PR, [)~HO. LDT O, 00~ PEF,LDT CNTC.CNT 1720.552 CFTC.CNT HTHO.NGS -999,250 HIJ~A,NGS G ~, ~ ~7 R 63,785 8 MTE~. Aqg 10:6.098 MRF.$,AMS 27-~,AR-1995 !1 :30 5,469 IDPh,DTE 1,~3,953 PTCO.LSS 0,3{)3 RHO~,bDr 3.442 NP~I.CNT 593.27~ ~SGR,NC~ -999,250 BF~.NG$ -90,06] CALI,.~4ER 1.579 5,822 TDPH.DTE "20,. .661 DTCO.LS$ 0.324 RHO6.bDT 3,238 biP~I.CNT 648.226 HSGR.NGS -999.250 HFK,NGS -95.125 CALI.MER 1.589 6,3~4 IDPH,DTE 1,52.247 DTCO.bS$ 0,329 RHOB.LDT 3,027 NPMI,CNT 665,778 ~SGR.NGS -~99'250 HFK,NG$ -113,063 CALi.MER 1.600 6.568 IDPM,DTE 1.59,948 DTCO,LSS 0,233 RHOB,LDT 2.981 MP~I.CNT 584,851 HSGR,NGS -999.250 HFK,,NG$ -105,688 CALI,~ER 1,617 3,599 IDP,H,DTE 315,6~8 DTCO.bSS 2,685 NPHI,CNT 521,756 MSGR,NG8 -999 250 HFK.'NGS -103:8'75 CALI.MER 1.621 3,834 IDPH,DTE 350.359 DTCO.LSS 0,390 RHOB,bDT 2.~03 NP~II,CNT 473 871 HSGR.NG$ -999~250 HFK,NGS -119,063 CALI.~ER 1.6~4 6.70~ -999.250 2.420 42,030 -99g,250 -999,250 14.221 5.501 -999.250 2.389 33.502 -999.250 -999.250 14.608 6,462 -99g.250 2.405 33.687 -99g.250 -999.250 13,826 6 431 -9991250 2,409 37.755 99 250 15 987 3,170 -999 250 2129S 34 687 -999~250 -999,250 13,906 2 852 -99912S0 2 314 40]997 -999,250 12,954 CIDP,DTE DT4P.DSI DPHI.LDT TNRA.CNT HCGR.MGS HBHK.NGS GR.F~I CIDP.DTE DT4P.D$I OPMI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR.FMI CIDP.DIE DT4P,D$I DPHI.LDT TNRA,CNT HCGR.NG$ BBf~K,NG$ GR,FMI CiDP DTE DT4PiD$I DPHI.LDT TNRA.CNT HCG~.NG$ HBHK.NGS GR,FNI ClDP.DTE DT4P,DSI DPHI,LDT TNR. A,CNT HCGR,NG$ HBH~:.NG8 GR.FMI ClDP.DTE DT4P.D$I DPHI.LDT TNRA.CNT HCGR.NGS ~BHK,NGS GR,F~I PAGE: 149.078 100.414 13.921 3.656 -999,250 -999.250 -999.250 181.795 99,017 15.822 3.194 -999,250 -999,250 -999,250 154,747 97,847 14,874 3.200 -999,250 -999,250 -999,250 155 491 962',106 589 -999,250 315 499 109 984 21 533 3:255 -999 250 -999 250 -999,250 350 638 20,350 3,600 -999.250 -999'250 '999,250 i$ Tar. e ver..~flcation Li. stJn~ cblun~ber,':}er .41asKa Computi. rho Center DEP?, 5000.000 SFLtI.D?E i~P~, h'rF 1.225 CI~P. DTE DT?. DSI 2 ]8. 975 PR. D~{~. T,DT -0. (, 1 I PEF. LDT CNTC. C)~T ] 880,2?9 CFTC.CMT HT~;n. NGS -999.250 HiJR A. NGS GP. ~ER ] 1. 564 MTE~. A?IS 102.490 DFPT. 4800.0D() SFLU.DTE I~PN. DTE 2.515 CI)~P.DTE DTP. DSI 2 ~ 5. 495 PW. DSI DR~tO. LDT O, 007 P~F, LDT CNTC,Cc.~T 1830,5~ CFTC,CMT HTHO.NGS -999.250 HUP~.NG~ GP. ~ER 69, I 19 SP, MER HTE~~. A:~S 102.2 ~0 uRFS. A~$ DFOT. 4600.000 SFI,U.DTE i~P~.DTK 1.166 CI~!P.DTE DT?. D,SI 2o7. 366 PR. DSI DR~O. I,,DT -0. 005 PMF. bDT CNTC.CNT ~990.322 CFTC.CNT MTHO.NGS -999.250 HORA.~GS G~.~ER 45.474 SP.~ER MTEP~, A>.~S 100.612 ~.~RES, AMS DEPT. 4400.000 SF i)~P.U. UTE 1.656 CIMP:'~'T D'I'~, D51 -999,250 PR, DSI DRHO, bDT -999,250 PEF, LOT CNTC,CNT -999.250 CFTC, CN ..,. MTHO, N~S -999,250 GR, PER 20,906 SP,MER MTE~, A~qS 76,9!6 DF-P~:''. 4200.000 SF[,U.DTE INP;~.DTE 2.061, CIMP.DTE PT2, DSI -999,250 'PR, DRHO. LDT -999. 250 PEF. bDT CNTC.CNT -999.250 CFTC. C~T HTHO.NGS -999.250 HURA.NGS G~. ~ER 4~. 469 SP. ~:TE~ , A)qS 7 ~. 831 SRES.. A ~'.~ S D F P T. 4000.000 $ F [, U, P T g .INP~. D,YE 2.941 CI DT2, DSI -999. 250 PR DRHO.LI)T -999 250 PEF, C't~'I"C, C N T -999,250 CFTC, (.N.[ ~THO, NGS -999,250 GP. ~F:;R 56.03 ], SP. MTE'M .,A~.~S 76.94~ 27-~,A~-1995 11:30 I .795 IDPH.DT~: 816.147 OTCO.L$S 0.351 RHOB.LOT 2.697 NPHI.CNT 478.894 HSGR,NGS -999.250 HFK.NGS -lb5.438 CALI. ~,ER 1.705 2.938 IDPH.DTE 397.588 DTCO.LS$ 0.338 RROB.GDT 2.944 NPHI.CN'r 517.384 HSGR.NGS -999.250 FiFK. NGS -]23.688 CA[.,I.~ER ! .69~ 1 955 IDPH.DTE 357.'434 DTCO.LS$ 0.253 RHOB.LDT 2.624 NPHI.CNT -999.250 -1.61.063 CALI, MER 1.723 3.000 IDPH.DTE 602.500 DTCO.b$$ 'q99.250 RHOB.LOT '999.250 NPMI.CNT '999.250 HSGR.NGS -~99.250 }'tF.~. NGS 59.1,88 CALI.~ER ~.949 2.926 IDPH*DTE 484.750 DTCO-bSS -999.250 RHOB.GDT -999.250 NPHI.CNT -999.250 HSGR.NGS -999.~50 HFK.NG6 -31.031 CALI,MER 2.881 2.973 IDPH.DTE 339.750 DTCO.LSS -999.250 RHOS.LDT -999.250 NPHI..CNT -999.250 HSGR,NGS -999.250 HFK,NGS -35.656 CALI.~ER 2.~$1. 1.147 -999.250 2.069 47.290 -999.250 -999.250 12.29t 2.596 -999.250 2.333 42.440 -999.250 -999.250 12.680 1.074 -999.250 2.!97 37.612 -999.250 -999 250 1, 440 o2:gta -999.250 -999.250 -999.250 1999 250 9 :2so ! 114~.349 -999.250 -999.250 -999 250 999i250 2.906 118,057 99.250 -999.250 999.250 CIDP.DTE DT4P.D$I DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR,F~I CIDP.DTE DT4P.DS! DPHI.LDT TNRA.CNT HCGP.NGS HBflK.NGS GR.FMI CIDP,DTE DT4P,DSI DPHI,LDT TNRA,CMT HCGR,NGS HB,HK NGS CIDP DTE DT4P:DSI DPHI,LDT TNRA,CNT HCGR,NGS ~{BHK.NGS GR.FMI CIDP DTE DT4P:DSI DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR.F~I C!DP.DTE DT4P.DSI DPHI..LDT TNRA.CNT HCGR.NGS BBHK.NGS GR.FMI PAGE: 12 872.168 114.5t4 35.227 3.943 -999.250 -999.250 -999.250 385.147 106.610 19.185 3.679 -999.250 -999.250 -999.250 930.929 11,9 300 27:433 3.415 -999.250 -999.250 -999.250 693 500 -999:250 -999,250 '999,250 '999,250 29992,50 999:250 530.500 -999 250 -999~250 -999.250 -999.250 -999"250 -999,250 344.000 -999.250 50 '999.~50 -999. !999.2~50 999 50 999~ 50 IS Tape Verification !,isti. ng c'blumher~ler AlasKa Comp~.ltJ..nn Center I)Fpw. 3800.0{)¢ SF[,U. DTE I ~ P}~. D'.,:~, 2.109 DT72. DSI -9~9,250 PR. DSi DPH~. L~)T -999.25¢ PFF. CNTC. CN T -999. 250 CFTC. CNT HT~If'~. NGS -999. 250 FU[{A. ~GS GP. ~ER 6~. ~75 MTE~'~. A~qS 75.2o0 DF, P~. 3600.00~,~ SFLU.DTE I"P?.DTF, 1.170 C I~". P. OTE DT?. DSI -999. 250 PR. DSf D~HO. LDT -999. 250 PEF. bDT C~,'TC.CNT -999,250 CFTC.CNT HTHO.NGS -999.250 HiJRA.NGS g~. MCR 35.313 gP. ~ER ]'~TE~. ABS 73.2~S ~RES.At~S DFPT, 3400.000 SFLU.DT~; I~P}:.DTE 2.260 CI~P. DTw, D'.r?, DSI -999. 250 PR. DSI DPHO. LI)T -909. 250 PEF. bDT CNTC.CNT -999.250 CFwC.CNT HTHD.NGS -999.250 HURA.N(;$ GP. ME~ 50. 750 SP. ~ER ,~TE~. ~hS 72.78 ] ~4RES. D~PT. 3200.000 SFLU.DTE I }~ P }-!. D T E 1.137 C I 1~ p. D T E DTP, Df.ii -999. 250 PR, [)SI I)~Ha, I, DT -999. 250 PEF, LDT CNTC.CNT -999.250 CFTC.CNT HTHO.NGS -999.250 HJ~A.NGS GP. ~ER ~8,51. 6 SP.~qER ~ TE}~r. A ~';IS 73.513 '~RES. A~!S DEPT, 3000.000 SFLiI,DTE II~P~. DTF, I .455 CI~4P. DTE D'r~. DS! -999. 250 PR. DRHO, LDT -999. 250 PEF. blOT CMTC,CNT -999.250 CFTC.CNT }fTBO,NGS -999.250 MURA,NG5 G ~. ~,1E ~ 33.313 $ P. a E R ~TE~. A~,,I $ 72.106 DEP?. 2800.o0() SFLU.DTE Ii~P}~. DTE 1.177 CI{~P.DTE DT~. DSI -999. 250 PR. DSI DPH~. I,DT -999.25(3 PF.F, LOT CNTC. C~:'JT -999.250 CFTC.CNT HT}.t~. ~,~GS -999.250 GP. M.E~ 33.3 :t 3 SP. ~a~,1. las 70.531 27-~!AR-19.~5 1~.:30 1.931 IDP~t. [)TE 473.750 DTCO.LSS -090.2.~0 RHO~. LOT -999.250 N.PHI.CNT -Q~9.~50 ~SGR..NG5 -999.250 HFK.NG5 -42.003 CALI.,'qER 2.945 2.695 !DP~,DTE 854.000 DTCU,b$$ -999.250 RH.~b,LDT -999.290 NPMI,C?4T -999.2~ HSGR. -~99.250 HFK.NGS -65.8 3.03] 2. 590 IDPH. DTE 442.250 DTCO.L$S -999.250 RHOB.LDT -999.250 N PH,I. C,"'~T -999.250 ~SGR.~GS -999.250 HFK,NGS -29.797 CALI.~ER 3. 008 2.2'75 112.305 -999.250 -999.250 -999.250 -999.250 -999.~50 1.061 127.917 -999.250 -999.250 -990.250 -999.250 -999.250 2.010 113,531 99,250 -999.250 -999 250 -999:250 2.928 !DPH.DTE 1.118 879.500 DTCO,[,SS 126,533 '999.250 RHOB.LDT -999.250 '999.250 NPHI.CNT -999.250 '999.250 HSGR.NGS -999.250 '999.2~0 HFK,NGS -999.250 -68.375 CALI.~ER -999.250 3.002 3.871 IDPH,DTE 686.500 DTCO.bS$ -999.250 ~HOS,hOT -999 250 NPHI.CNT -999~50 HSGR.NG8 -999.250 HFK.,NGS -62.031 CALI.MER 3.059 2.352 IDPH.OTE 849,000 DTCO,bSS -999.250 RHOB,BDT -999.250 NPHI.CNT -999.~50 HSGR.NGS -999. 50 HFK.NG$ -74.250 CALI.~!ER 3.162 1.313 1.37 859 -9992 o 999 250 39992250 -999 250 -9991250 1,065 1.39,~94 -999.~50 -999~50 -9991 50 -999.:~50 -999.~50 CIDP.DTE DT4P.DSI OPHI.t,OT 'rNRA.CNT HCG~.NGS HRHK.NGS GR.F~;I CIDP.D'rE OT4P.D$I DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GRoF~I ClDP.DTE DT4P.DSI DPHI.LOT I:'NRA.CNT HCGR.NGS HBHK.NGS GR.F~I CIOP.DTE DT4P,DSI DPHI,LDT T'NRA,CNT HCGR,NGS HBHK,NGS GR.FMI CIDP,DTE DT4P,DSI DPHI,LDT TNRA.CNT HCGR,NGS HBHK.NGS GR.FMI DT4 DSI OPHI,LDT TNRA,CNT HCGR,NGS HBHK,NGS GR.FMI PAGE: 13 439.250 -999.250 '999.250 -999.250 -999.250 -999.250 -999.250 942.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 497.000 -999250 '9992250 -999,250 -999,250 -999,250 -999,250 -99 500 -99 1250 -99 250 ~999 250 999~250 761 000 -9991250 -999,250 1999.250 999.250 938 O0 '999,250 '999,250 -999.250 -999,250 -999.250 18 lade Verif.icat]on !,!.st. inn chlumberqer Alaska Comput.inq Center DFpT. 200C,. 00£, SFLLt.DmE I~PI~. DI'E 1.O37 CIt,~P. DTE DPHO. LET -999.25 U PEP. LD~ CN:TC. C~T -9q9.250 CFTC.CNT HT~O. NGS -9g9. 250 g~l~ ~. fIGS G~. ~4E[.R 42. 469 SP, ?JER ~TE~'~. g t-IS 68,360 t~t R ES. A~S DEPT. 2400.00tI SFLU.D'rE I ~,PH. D°.CE 1.084 CIP,;P. DTE D_T?. ESI -999. 250 PR, DS I [)~HO. LDT -999. 250 PEF. LET CF~TC.Cr~T -999.250 CFTC.CMT HTHO.MGS -999.250 qiIRA.NGS GP. ~E~ 27.3,44 SP. t~TE~. A~qS 67,24 ] DEPT. 2209.000 SFI, U.DTE IN~PH.DTE 1.713 CIMP.DTE DT~, DSI -909. 250 PR, D.$I D~t~, LDT -999. 250 .PEF, LET CNTC,CNT -999,250 CFTC.C~T HTHO,NGS -999,250 HJRA.J'iGS G~. ~E~ 30.719 SP, MTEM..~MS 66.0[~h MRES.AMS DEPT. 2000. 000 SFLU. DT IgP~t. DTE 4.7~7 CI~P.DTE DT2, DSI -999. 250 PR. DRHO, LET -999. 250 PEF, L[)T CN'I'C,CNT -999,250 CFTC.CNT H TI'-~O. ,NGS -999.250 ~"~ U R A NGS 6~. ~'E~ 3 5.6~5 SP ~ :NEe t4TE*', At4$ 63,500 DEPt, 1800.o00 SFLU,DTE I'MP~', DTE 33,563 CII~P,DTE ET2, ESI -999,250 PR. D~HO..LDT '999. 250 PEF, LDT CNTC. CNT '999. 250 CFTC. CNT H~HO. NGS -999. 250 Ht,tRA. GR. NER 24. ! ~ 8 SP. t'IER NTE~;. A~4S 64. 400 MRE',$,. A~S D E P ~ 1 6 0 0. !~ o (,t S F I., U. D T E I M p ~'I: D T El 3 9.&~ 5 0 C [ :~ P · D T E VT2. DS ~ -999,250 PR, DS ! DPHO. I,,,,DT -999,250 PEF. LDT C~vTC,CNT -999.250 CFTC.CNT MTHO.NGS -999,250 HURA,NG8 G~, ~.{ER 33,969 SP, b~IER M TE ~,'~. ,A ~,'~ S 66, [;59 MR ~iS, 995 1 ]: 30 2.953 !DPH.i)'tE 610.5o0 DTCO. bSS -990.250 RHOB.hDT -999.250 -999.250 HSG~.NGS -q99.250 HFK,NGS -b3,906 CALI.MER 3.~42 2.5'14 IDPH.DTE q21.500 DTCO.L$S -999.250 RilflB. BDT -999.250 NPiII,CNT -999. 250 N,SGR . NGS -999.250 HFK.NG$ -b6.500 CALI.i~ER 3.2~8 3.336 IDPH,DTE 583,500 DTCO,LS$ -999.250 RHOB,LDT -999.250 NPHI.CMT -999,250 HSGR,NG8 -999.250 -47.813 C~LI.~ER 3.4i2 5. 520 IDPH, DTE 211.3'15 DTCO, LSS -999,250 RHOB.GDT -999.250 NPHI.CNT -999,250 HSGR,MGS -999,250 HFK NGS -48.563 CAI,,.,I~MER 3,545 702,500 !DPH,DTE 29,781 DTCO,LSS -999.250 RHOB,LDT -999.250 NPHI,CNT -999.250 HSGR,NGS -999.250 },tFK,.NGS -66.375 CAI,.,I,MER 3,396 227.375 IDPH.DTE 25,453 DTCO,bS$ -999,250 R}~O~,LOT -999,250 MPH!,CNT -999.250 HSGR.NGS -999.250 HF~.N'G$ -b3,344 CAI,,I.~ER 3.2~0 1..433 138.138 -999.250 -999.250 -999.250 -999.250 -999.250 1.051 150.219 -999.250 999.250 Z999.25o -999.250 -999.250 1.564 15o.117 -999.25o -999,250 -999.25o -999.25o -999.250 4.047 146.834 -999 250 -999i25o -999 250 -999,250 -999,250 381.000 77 303 '9991250 -999 250 -999 250 -999 250 -999,250 1.68.000 93.386 -99 250 -999.250 -999.250 -999.250 CIDP.DTE DT4P.DS! DPHI.LDT 'rNRA.CNT HCGR.NGS HBHK,MG$ GR.FMI CIDP.DTE DT4P.DSI DPMI.LDT TNRA.CNT HCGR.MGS HBHK.NGS GR.F~I CIDP.DTE DT4P.DSI DPHI,I, DT TNRA,CNT HCGR,NGS HBBK.NGS GR,FMI CIDP,DTE DT4P.DSI DPHI,LDT TNRA,.CNT }4CGR,NGS MBHK,NGS GR.FM! CIDP,DTE DT4P,DSI DPH:I,LDT '],'NRA,CNT HCGR,NGS HBHK,NG$ GR,F~I CID. D'IE OT4P:DSI DPHI.LDT TMRA.CNT HCGR.NGS HBHK,NGS G F~! PAGE: 697.500 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 951,000 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 638,500 -999,250 -999,250 -999.250 -999,250 -999,250 -999,2~0 246.875 -999,250 -999.250 -999.250 -999 2.150 -99 :zso -999.250 2,623 -999,250 -999,250 -999.250 -999,250 ~999,.250 -999,250 5 949 -9992250 -999,250 -999,250 -999,250 -999,250 -999,250 1.4 I$ ~"a~e verification ~.stina CblUmberqer Alaska Computir',q center D'r2. DS~ -999,2~0 PR. DSI -999 DRF~m, LI)T -999.25(~ PEF. bDT -~99 C~TC.CNT -999.25~ CFTC.CNT -(}99 HT}{O.NGS 9~9 250 ~.~UPA.NGS -~99 GP.~.~ER 21.67~ SP...?,',ER. -68 ~TE~'. ~,iS 6b.959 ~RMS. A~5 3 DFP"~ 12n0 000 SFLU D't'F · , · · · .... I ~" P v;. p T fi: 5.41. 4 C I ~ P, D T E P'l'~. PSI -999. 250 PR. DSI DP}~O. LDT -999. 250 PEF. LDT CNTC.CNT -999.250 CFTC.CNT HTHf~. ~GS 9°9 250 G~. ~E~ 23. 047 t~TE~, At4S 65.469 DFPT. 1000.000 SFLU.DTM IMPJJ.DTE 7.711 CIMP,DTE DT2, D$I -999. 250 PR, DSI DP~O. bDT -999. 250 PEF. LDT CNTC.CNT -999.250 CFTC.CNT HTHO.NGS -999.~50 GP,~E~ 23,813 SP. ~4ER I)EP?, 800,0()0 SFLU.DTE I'MPH.DTE 1950.000 CIMP.DTE D'.I'P, DSI -999. 250 PR.DSI DP t..{ O, I.,DT -999,250 PEP". LDT CNTC.CNT -999.250 CFTC.CNT HTHO.NGS -9~9,250 H[IRA.NGS GP MEP 32 969 S.P.~ER M~'E~~A~.IS 64'091, MKEo. A~ c t~$ I)MPT', 600.000 SFLU,DTE 2[~P}4 D.,,.E ~8 l~ft CIi~P D~E t · ~ ~ ~ '~' I2, DS! -999. 250 PR. DSI DP.HO. bDT -999,250 PEF, bDT CNTC.CNT -999,250 CFTC.CNT HTHO,.NGS -999.250 GP. M [~.', R 28,250 S P, MER: ~.TE~. AHS 67,072 DEPT. 400.000 SFbU.DTE I ~PI;'!. DTE 14.02.~ CIMP.[)TE DT~,DS! -999. 250 PR.PSI b ~ t.t 0. ~.~ D T -999.25 (> P F: F. I., D T C.MTC.CNT -999.250 CFTC.CNT ~tT[iO. NGS -999,250 HORA.NGS (;~. ~ER 21. 297 SP. ~IER .~tT E~. A~4S 65. '159 ~R ElS. A~$ 27-~'.AR-1995 1.1:30 37. 000 !84.625 -999.250 -q99.250 -99q.250 -q99.250 -29.922 3.303 9696. 129. -999. -999. -999. -999. -40. 3. 95. -999, -999 -999~ -999. -33. 3. 19, 54. -999. -999. -999. -999. -~5o 3. 22. 71. -...99. -990, -999. -999. -51. 3. 000 625 250 25O 250 250 844 44,9 250 813 25O 250 25O 25O 1,56 36!. 391 969 250 250 25O 250 375 242 938 25O 250 25O 25O 250 531 3,38 i DPH. DTE n?CO.bSS P. H 0 ~. ,[, D'r PtPHi. CNT HSGR. NGS HFK.NGS CALI.~IER IDPH.DTE DTCO,bSS RHOB. bDT NPNI.CNT HSGR.NG$ HFK,NGS CALI. MER IDPH. DTE DTCO - bSS R H 0 B. b .f) T NPH I · CNT NSGR,NGS h FK, NGS CALl, aER !DPH,DTE DTCO, bSS RHOB, bDT NPHI. CNT HSGR, NGS HFK. NGS CALX, MER IDPH,DTE DICO.bS$ NPHI,CNT HSGR-NGS HFK,NGS CAbI.~ER 27.3'75 94.782 -999.250 -999.250 -999.250 -999,250 -999.250 5,844 61,000 -999,250 -99q.250 -999,250 -999,250 -999,250 7.707 77.675 -999,250 -999.250 -999,250 -999.250 -999,250 77,188 95 526 -9991250 -999 250 -999:250 -999.2~0 -999,250 22.344 ,106.392 999.250 -999,250 -999.250 -999.250 -999.250 23 484 -999.250 -999,250 -999,250 -999,250 -999,250 CIDP.DrE DT4P.D$I DPNI.LDT TNRA.CNT HCGR.NGS MBHK.NGS GR.F~! C!DP.DTE DT4P.DSI DPHI.LDT TNRA.CNT HCGR.NGS HBHK.NGS GR.FM! CIDP.DTE DT4P,D$I DPHI.LDT TNRA.CNT HCGR,NGS HB~K.NGS GR.FMI CIDP.DTE DT4P.DSI DPHI'.bDT TNRA.CNT: HCGR..NGS ~iBHK.NGS GR.FMI CIDP.DTE DT4P,DSI DPf{I.LDT TMRA,CNT HCGR.NGS HBHK,NGS GR,FMI CIDP.DTE DT4P.DSI DPHI.LDT TMRA'CNT HCGR,NGS HBHK.NGS GR.F~I PAGE: 36,500 -999,250 -999,250 -999,250 -999.250 -999 250 -999:250 171.000 -999,250 -999.250 -999.250 -999,250 -999.250 -999,250 129,625 -999,250 -999,250 -999.250 -999~250 -999,250 -999,250 12.945 999~250 -999,250 2999,250 999.250 -999.250 44,719 -999 250 -999:250 -999, 0 -999,250 -999,250 42,563 -999,250 -999:'250 -999,250 -999'250 -999,250 -999"250 1.5 IS 'rape Vert~tcatl. on U_i. stinq chlumberqer AlasKa Computinq Cent:er 27-Y,,~R- J. 995 PAGE: 16 D E P q'. 2 o 0.0 (; {.~ S I,U P;q. DT~: 1.370 CIb~P. !.)TE DT.7. DSI -999. 250 DRHO. LDT -999,250 PEF. CNT'C. C~[4T -909.250 CFTC.CNT ~TIqO. PIGS -999. 250 HUP A. NG8 GR. ~ER 38.9~ 6 DFPT. 36.000 SFI, O.DTE IWPH.DTE -999.250 CIMP.DTE DT?, DST -999. 250 PR. DSI DRHO. LDT -999. 250 PEF. LDT CNTC.CNT -999.25(} CFTC.Cr4T HTHO. N(.;S -999.250 GD, ~ER -999.25g ~.TE~, A~4S -999.250 2.627 IDPH.DTE 729.5(30 D'ICO. LSS -999. 250 RHO~. bDT -g99.250 NPHI.CNT -999. 250 HSGR. f~GS -999.~.~0 HFK.NGS -30.8~4 CALi.~ER 3.33~. 165.317 -999.250 -999.250 -999.250 -999.250 -99g.250 -999.250 !DPM,DTE -999,950 -999.250 DTCO,LSS 167.077 -999.250 RHOD,LDT -999.250 -g99.250 NPHI,CNT -999o~50 -g99.250 HSGR.NGS -999.250 -999.250 MFK.NG5 -999.250 -999.250 CALI.~ER -999.250 -Qgg,2bO ClDP.DTE DT4P.DSI DPHI.LDT TNRA.CNT tICG~.NGS DBHK.NGS GR.F~I CIDP.DTE DT4P,DSI DPHI,LDT TMRA.CNT MCGR.NGS HBHK.NGS GR,F~I 766,000 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 **** FILE FILE ~,~A,ME : EDIT .001 SERVICE : FLIC VEtS,ION : o01C01 DATE: : 95/03/27 NAX RF, C SIZE : FIb~: TYPE : baS~ FILE **** FIbE }!EADER FI'I,~: NA~E : EDIT ,002 SERVICE : FLIC VERS,ION : OOICO1 DATE : g5/03/~7 ~AX REC SIZE : ]024 FILF TYPE : LO LAST FILE : FILE EDIT 002 IS Tare VerJ..f~catlon T,lst~.na cb].umberqer Alaska Co,~put.in~ Center 27-~AR-~gg5 !1:30 PAGE: 17 ,ATT ARPA¥ C¢);'~TAI~-iFD I~] ~HI& F'II, g ,AR~ "rH~ AIT 1' VERTICAL PESO[,UTION RES~STIV!TIES LI~ICORPECTFD F~)g [.)~P A~;D CORRECTED ~[~R DIP, TU.~iI VALU DEFI ....................................... ..... ............................... . ............ . ...... *'I£,OC~'t rleid ~f. a~e FT FT FT F~ FT FT FT FT G/C3 S DEGF DEGF DEGF FN A P I Fb SFC~' TO~N ,r, ST ~ T ~ IT~ PDAT EPD ADD EK B EDF Bb I TI, I D~ DFL; D~PH DFi¢ DFL ~IST R~FS ~FST R~CS ~CST B H T ,~ADA6~ I #5 50-629-~2533 3334'Si~L & 4770'~EL 3 9N 20g NORTH SLOPE AI,,ASKA USA P U T N A ~ ICE, PAD 11 ~2,5 0 498 158, ~ell Name API SeriaI Number Field Location Section Townsb~,p Range County State or Province Nation ~itness Name Service Order Number Permanent datum Elevatlon of Permanent Datum Loq Measured From ADore Permanent Datum Elevation of Kelly 8ushin~ Elevation of Derric~ Floor Elevation o~ Ground Level Total DePth - Driller Total Depth - Lo~ger Bottom, bo~ Interval P Lo~ I~terval T°111~ngDr Fluid Type gr!ll.~ng Fluid Density Dr.il!ln~ Fluid Ph Orill~n~ Fluta 'Viscosity Drilli~,~ Fl,~li.d boss Resi, stlgity Of Mud SamPle Mud Sample Temperature ResistiVity of ~Ud Filtrate S Mud,Filtrate Sample Temperatu Resistivity of aUd CaKe Sampl ~ud Cake Sample Temperature Bottom Hole Temperature IS fade Ver.i.ficat.ton [..,ist].nO chlumberger Alaska Computl. no Center 27-~AR-1.995 11 :3(') DEFT DFPT Depth AOIO AO2n A030 Ag60 A09C, i)C20 DC3n DCS~. DC9¢, ~!T ~' VERTICAL PESPO~$E, 20 RADIAL ~IDPOINT RESISTIVITY DIP CORRECTED !IT 1' VERTiCA!~ RESPO:'~$E, 30 RAOlAL ~IDPOINT RESISTIVITY DIP CORRECTED AlT l' VERTICAL RESPOl~,S£, 60 RAOIAL ~IDPOINT RESISTIVITY DIP CORRECTED AlT 1.' VERTICAL ~ESPONSE, 90 RADIAL ~IDPOINT kESISTIVITY DIP CORRECTED PAGE: 18 ** F'ATA FOR.~AT SPECIFICATIOn; RECOI~D :*:* 2 66 0 3 73 40 5 66 6 73 7 65 8 68 0,25 9 65 FT 11 66 25 12 68 13 66 0 14 65 15 66 6~ 16 66 0 66 ** SgT TYPE - CHAN ** ']]~;''~ ..... UNiT '''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''SPRY! APl I AP1 Fill,: ' S PROCESS !D ORDE;P # LOG TYPE CLASS ~OD NUMB SA~P EbEM CODE (HEX) FT 629:136 00 000 00 0 2 ! J, 4 68 0000000000 AO10 AlIT OHag 6291.36 00 000 00 0 2 1 1 4 68 0000000000 A020 giT O~MM 629136 00 000 OD o 2 1 1 4 68 0000000000 AO3a lit [.I!~MM 629136 00 000 O0 0 2 1 1 4 68 0000000000 ADS0 lit ONa~ 6291.36 00 000 00 0 2 1 1 4 68 0000000000 A090 AlT O~a~ 629136 00 000 00 0 2 1 I 4 68 0000000000 DC20 AlT (3~ 629136 00 000 00 0 2 1 1, 4 68 0000000000 IS wal:,e Verif.ication Listin,~ 27-~A~-lgg5 1.1:30 ChlUmberger Al. asks Comput. ino Cemter PAGE: 19 ID ~2~DER # LOG 7¥P~ CLASS ~OD NU~',B S~l? ESE~', CODE (HKX) DC3f~ AIT (]~M~ 62~136 O0 000 O0 0 2 J. I 4 6~ (,)(~00000000 DC60 AlT OF;l~ 629136 O0 6~0 O0 0 2 1 1 4 68 0000000000 Dcgo AlT OH~ 629136 O0 600 O0 0 2 1 i 4 68 0000000000 DFPT. 11524.000 AOIO.2IT 5.992 AO20.AIT 5.636 AO30.AIT AO60.A,I.T 5.423 Aogo. AIT 5.507 DC20.AIT -999.250 DC30.AIT DC60.A1T -999.~50 DC90.AIT -999.250 DFPT. 11400.000 AI~IO.A!T I0.215 Ag20.AIT 7.(!02 AO30.AiT AD60.AIT 6.81,4 .AOOO.AIT 6.785 DC20.AIT 7.152 DC30.AIT DC60.AIT 6.g80 DC~O.IlT 6.795 DEPT. 11200,000 AUIO,AIT 1950,000 A020, $.:IT 31 93~ AO30,AIT AO60.~IT 579.000 Aogo. AIT 37~.500 DC20.AIT 32:~28 DC30.AIT DC60.AIT 9~6.(,300 Dcgo. AIT 674...000 DEPT. 11000.00~ AOI. O.AIT 19.605 AO2(,.AIT 9 547 AO30.AIT AO60.AIT 7..426 AOgO.AIT 7.184 DC20. ~,IT 11~391 DC30.AiT I)C60.. A'IT 12,313 Dcgo,~IT 11.941 D~PT 10800.000 I~IO-AIT 43.875 .AO20.AIT 1~3.211 A030 AO60:AIT 20,523 AO90,AIT 2(,;.1(;9 DC20,AiT lz.891 .DC30~AIT DC60.AIT J. 9.266 DC90.AIT 18.672 DEPT. 10600 000 lOJO.AIT 23.934 AO20.:AIT 9 063 AO30.AIT AD6(;' AI.T 101672 ~[.190. ~IT 10,847 DC20,AIT 8:951 DC30.AIT DC60,~IT 10,956 DC90,,AIT 11.160 DKPT 10400'000 ~OiO.IlT 34.415 AO20.AIT 9 048 AO30.AIT AO6(~: i ]..T 11,163 ~O90.AIT 1.0,7t~5 DC20.~.IT 8:000 DC30,AIT I)C60,AIT S,399 Dcgo. AIT 8,233 DK. PT, 10296.00(t AOIO.AIT 19.154 AO20.AIT 7 51,4 A030 AlT AO60.,~,IT 7.571 AO9().AIT 7.4:15 DC20.~IT -99g,~250 DC30~,IT DC60,A'IT -999,250 .... DC~O AIT -999,'" ' 5.587 -999.250 6.929 6.908 48 719 47~680 8 980 ll:4oo 14,555 1. 4,05g 9,360 9.401 992 7.411 -999.250 ],$ ?a~e Yeriflcati. on cblumberoer AlasKa Computinc O'.enter 27-~AR-1995 1~:30 PAGE: 2O **** F I ][... F TRAI I,E.P F!L,F NA~E : RL';IT SFRV1CE : FL.~C D A'I'F : 95103127 k~X REC SIZ~ : 1024 FJL, V TYPE: : LO L~S· FILE : **** FILE HEADER **** V![,K NAME : FJDIT .003 SFRV ICE', : VLIC VFRE ItqN : 001C01 D~ IF'. : 05103127 ~X RKC 5TZ~ : 1024 FTI.,F TYPE : [.,0 l..,~ S ~' VIt, E : 6P EXPLOF:ATI£!~ AP1 ~50'629'22533 h' I LDCAT NORTH SL,[]PK, ALASKt~ FILK ED!T.O03 ************* $~MPLE RAT.E: 0,0~33 FT, ,L, DS ~I .~ESOI,,I, tI'ION LITHO DENSITY TDOL (IPLT TOOL STRING) T~BI,E TYPE : CONS TUNI VAL, U DEFI F~" ~ I I:.,,DC~ T Fie WI~,:< ~A[)A~I ~'5 Well Na~e A. PIf,: 50-629-22533 API Serial, Number FI, 3334'SNb g 4770'~EL Field I.,,ocation SFCT 3 Section TO~,? 9N Township RANG 20E Range COUN NORTt'i $ [.,[.)PE County S~AT ALASKA State or Province NATI' LiSA Nation W ! T~,:: PUTMAM Witness Name SO~'~i 629136 Servlce Order Number PDAT ICE P~D Permanent datum Tare verification Listina .CblU.mberger A],asl(a Compu~tin~ Center 27-~AR-1905 :][1 PAGE: 21 T U ~,~ T V A [: U D E F T E].evat on of .Permanent DatUm L F', Y k B A~D FT 34. EKS PT 38. EDP PT 33, ECL FT 4.1 TDD PT 11549, TD[, DT 115~4, BLI FT 11524, TLI PT 36. DFI.) ~/C3 12,5 DFPM 7, DFV S 76, DFL P'3 RWS UH~4~ 0,743 NCST DEGF ~6. BHT ~EGF 1, 58, Log Neasured From Above Permanent Datum Elevation o~ ~ell¥ 8ushiBg Elevation oi Derrick Floor ElevatioD off Ground Level Total Depth - Driller Total Depth - Logger Bottom Lo~ Interval TOD Log ! terval Drillim~ Fluid Type Drillin~ Fluid Density Drillin~ Fluid Pn Drillin~ Flui~ Viscosity DrillinQ Fl. uia Loss ResistiVity of ~ud Sample ~ud Sample TemPerature' Resistlvit~ of Mud Filtrate ~ud Filtra e SamPle Te peratu Resistivity of ~ud CaKe Sampl ~ud Cake Sample Temperature Bottom Hole Temperafu.~e Thi~l,:~] TYPE : CURV [.)FP .... De~th DPO MDp~I D~ H PFF!,, PHOTOELECT'~IC FACTOR FRON THE FAR DETECTDR LCA~, D~$ caliDer for I,~DS, same as CALI for LOT ** ~,ATA FOR~4AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** REPR CO VAL !, 66 0 2 66 0 3 73 32 4 66 IS ?ape Verification bisttno chlumberger AlasKa Computing Center 27-MA~-~995 I1:30 PAGE: 22 6 73 7 65 9 65 l] 66 1~ 68 13 66 14 65 15 66 16 66 0 66 C 0 P ~; ¥ U k 0.0~3 FI 32 0 6~ ! 1 mmmmmmmmmmmmmmmmmm.mmmmmmmmmmm ** SET TYPE - CHAM N~,'~,,~E SF. V SERV C APl ~ I I[' ORDER ~ LOG TYPP CLASS DEPT FT 6291.36 O0 000 O0 RN[)~ bD$ G/C3 629136 O0 000 O0 'NRH'~ LDS G/C3 6291,36 00 000 O0 [')PO LOS P.U 62913b 00 000 O0 NDpM LOS PU 6291.36 00 000 O0 DRH LDS G/C3 629136 O0 000 O0 PEFI, LDS 6291 i)6 00 000 O0 LCAI, I.,D$ lin 6291,36 0O 000 O0 AP1 F1 I.~U~B NU IZE REP PROCESS MUD NUMB SAMP E:bE~~, CODE (HEX) 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 O0000000OO 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 ! I 4 68 0000000000 0 3 1 1 4 68 0000000000 mmmmm#mm#mmmmmmmmmmmmmmmmmmmm#mmmmmmmmmm#mmmm 11, 348.9.41., R a 0 ~. L O S 10.40 (,I D ~ H. L D $ 1 1200.025 PHO~4.L,D 2 1 .,430 :DRM, LD$ 11000.025 6 , 885 025 R a 0 lv~ · b 0 $ 230 D~H.I3D$ 10600.025 9 , 0 ...q. ,2 10400,0'25 RHO~.bUS 7,55o DRH,bOS 2.478 0.027 2 -0 .306 .010 2.495 0.003 2,464 0'054 2.4~7 -0.009 2.517 0.016 NRMB.LDS 2,507 DPO.bDS PEFL, LD$ 9,130 LC,AL,LDS NRHB,LDS 2,300 DPO,bDS P E F I,,. b D S 3.301 h C A, L. L D $ NRMB,bDS 2.512 DPO.LDS PE:Fb,LDS 6,086 bC.AI,,. I~OS NRHB,LD8 2,475 DPO,LDS PEFL,LDS 5,857 bCAL,LDS NaH~,bDS 2 ,479 DPO.SDS PE'FL,LDS 5~906 LcAL,LDS ~RH8, bDS 2 539 DPO.LDS PEFL,bDS 5~818 bCAL,LDS 10.400 7,438 ~0,874 8,600 9 366 11.230 9,067 1,.~,078 .711 8',032 12.633 IS Tape Verification bitstino cbll.]~;ber.~er A]asKa Co~putinc~ Center DFpT. 10200.0'25 DEPT. 10900.025 P~O?i.LDS l,iPpg. LDS 13. 293 DFpT. qB00.0~5 ~H£~?t. LOS NDPH. LDS 10.571 DRH. LOS DFP?. ~600.025 RHOq. LOS 05, D H. NDp~. I~i),,q. 8. ' "' R LDS DFPT. 9577.025 NDP[{. I.,DS 10.11.0 DRH.LD$ ** END OF DA'fA ** 995 1.1.:~0 2.50~ 0.007 PEFL.LDS 2.44! 0.005 PEFL,. LBS 2.476 0.011 PEFb. LD$ 2.511 ~IRHB.LDS -0.001 PEFL.LDS ?.483 NRHB.LDS 0.0'77 PEFb.bD8 2.512 7.113 2.457 6.434 2.472 4.779 2.518 5.492 2.474 5.561 DPO.LDS LCAL.LDS DPO.LDS bCAL.LDS DPO.LDS LCAI,.LDS DPO.LDS LCAL.I, DS DPO.LDS bCA[,.LDS PAGE: 8.588 12,194 12.095 12.125 10.571 12.190 8.398 12.045 10.110 9.966 **** F~LE TRAII..~gP **** FILF NA~E : EDIT ,003 SERVICE : FL[C VERSIO~ : O01C01 DAT~ : ~5/03/27 '~ . FILF T~PE : LO LAST FI[,E : **** FILE FILE ~,~A~E : EO[T ,004 SERVICE : FLIC VER,~ I 0~ : 00lC01 DATE : 95103/27 NAX ,~{E,Z SIZE : ,1024 F!L[~ TYPE : LO LAS~ FI[,E BP' EXPLORATIOI'I BADAhfI APl ~50-629-22533 W I [,., D C A T NORTFi SLOPE, SAii,~PLF R.ATE: c1,,.1667 FT. .APS }~I RES(3LI,.tTI(]i~ EPITHEP, M~L NEUTROi~i ,i,iLT ~:!CROLOG 'TOOL (I PLT TOOL STRING) I$ Tape Yerificat].on l,isti, nq CblUm. herqer Alaska Co~putir~q Center 995 11: 30 PAGE: 24 TAtq. I,F, T'YP~. : C0~.'$ ',17, IJ ~ I VALU DEFI C T~ F~ iILDCAI Field Name w~ aAl)A~I ~5 ~ell ~;ame APT~T 50-629-22533 APT Serial Number Fl, 3334'S,i'~b & 4770'~EL Field Location SEC~ 3 Section TOwN 9N Township RANC 20~i: Range COU~{ NORTh SLOPE County STAT ALASKA State or Province NATI LISA Nation WlT~~ PIJTNAa witness Name S(]r~ 6~9136 Service Order Number PDAT ICi PAO Permanent datum EPD FT 4. Elevation of Permanent Datum L~F K~ Log ~easured From APl) FT 34, Above Permanent Datum EKB FT 3~. Elevation of Kelly Bus~inQ EDF FT 33. Elevation of Derrick Floor EGI, FT 4.1 Elevation of Grou[~d Level TDD FT 11549. Total DePth - Driller TDL FT 11544. Total Depth - Logger b[.,l FT 11524, Bottom Log Interval TLI. FT 36. Top LOg Interval DFT CORE MUD Orl!!inq Fluid Type ~[[,~ ~/C3 12.5 Orililn~ FlUid Density pH 7 Orill ng FluidPh DFV S 7~, Drilling Fluid Viscosity nfl.. F3 4.,6 Orl. ll inql Fluid boss ~MS n~i,~ 0!743 ~esistl[itY of ~ud Sample ST DEGF 6 MUd Sam le TemPerature R~FS OH)~ 0 ~98 a~slstl, i. tY of Milo Filtrate S ~FST DEAF' 55. .Mlud Filtrafe SamPle Temperatu R~C~ ,..:, OHMii4 2 33 Resistivity Of Mud CaKe Sampl ~C,.>~ DEGF ~6 ~ud Ca~e Sample Tom el'at[Ire BHT DEGF 15~. Oottom HoleTempera ute TAB!~E TYPE : CURV IS Tare Verlf,!.cation l,.i.$tinq Chll.lmberqer Alaska Computino Center 27-~AP-19q5 1l:30 PAGE: 25 DE?'I ......... ;': ;; ' '; .... MNOR :~icro-~orma 1 Resistivity ** DATA FOR.AT SPECIFICATION RECORD ** SET TYPE - 64EB ** T Y P.F., EPR CODE 1 66 0 2 66 0 3 73 40 4 66 .1. 5 66 6 73 7 65 8 68 O..!.. 66 9 65 ~'" 11. 66 25 12 13 66 0 14 65 FT 15 66 16 66 .!. 0 66 sg~v~ AP~ ~pI z API F :E ~L~B ~U~ SIZE R P P..,OCESS ORDER ~ LOG TYPE CLASS ~[;D NUIqB SA~P E'bE~ CODE (HEX) DEPT FT fi29136 00 000 00 0 4 I 1 4 68 APSC APS PU 629!36 00 000 00 0 4 1 1 4 68 FPSC .APS 629136 O0 000 O0 0 4 1 1 4 6~ ENPY AP,S PU 629136 O0 000 O0 0 4 1 1 4 68 A~JEC APS CPS 629136 O0 000 00 0 4 1 1 4 68 AFEC APS CPS 6291,]6 O0 000 O0 0 4 1 I 4 68 E~IF~ APS 629136 O0 000 O0 0 4 I i 4 68 ENA!;' APS 629136 O0 000 O0 0 4 1 1 4 68 NINV ~LT 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 * * D A T A * * IS Tape Verif..ication chlumher<;er Alaska C. ot. putinq Center DEP?. ! 14:4-7.9~;7 APSC. AD6 ANEC. APS -909.25~, AFEC. APS b; T ~ V. ~,~ i, 'r 3.744 ~".~ ;'..i F1 ~4. ~,,i L']' DF'PT. 11399. ANEC. bPS -909.2.K (} ~FEC. AP.. S DEPT. 11109.9(%7 aPSC.AP5 ANEC. Ap$ 3420.000 AFEC. ADS ~,l. NV. ~LT 5.4 ~ MNOR. P, LT 999.9~7 APSC. APS 33~4.500 AFEC.AP$ 2.64 O ~I ~ 0 R. ~ L T DFP'P. 107c~9.967 APSC.APS A~,~EC. APS 3339.!P5 AFEC.APS ;~iI Nv. MbT 3.4A9 MNOR. MbT DF, PT. 10399.967 ~,PSC. APS ANEC.APS 3256 250 A~ CAPS i~ I N V. M b T 0.96 * ~ N 0 R. ~'l L T DF:PT. 101,99.967 A:PSC. APS A. NEC. APS 3391.250 AFEC. APS M.I'. N .v, ~ilaT -999. 250 NNOR. ~LT DF, PT. 9999.967 APSC.APS · , ~ r~ . · A~EC APS 3339.000 ~EC APS ~';' I i'; v. ~ L T - 999.250 ~ N 0 R, a L T DFPT. 9799.967 APSC.APS A~EC. APS 3292.563 AF:EC. APS N T N V. ~ b T - 999.250 M :a 0 R. M L r DFPT. 9399.967 A,P$C. AP5 ANFC APS 999 250 F,.,C APS 27-~'1a~-1995 1t, :3(:) -<~99.250 FPSC.APS -990.25(.) E.qFR. AP$ 5. 706 -q99.250 FPSC.ADS -999.2b¢) ENFR.AP$ 5. O20 25.690 FPSC. ADS 920.5;)0 ENFR.APS 6. 906 20.636 FPSC.APS n~9. OUO ENFR. APS 3. 551 20.214 FPSC.APS R99.750 ENFR.APS 4.723 22.052 F P S C 963. 250 ENFR. APS 4.531 21.524 FPSC.APS 953.000 ENF~.APS 1.940 21.198 FPSC. APS 958.531 E'NFR. APS -999. 250 20.853 FPSC'APS 881.250 ~NFR,APS -999.250 22.976 FPSC,APS 868,125 ENFR.APS -999,250 22.1~1 FPSC.AP$ 881.3 5 ENFR.APS -999.250 -999.250 -999.250 -999.250 -999.250 0.261 4.188 0.239 4.048 0.257 4.338 0.245 4.058 0.245 4.078 0.256 4.200 0.269 4.347 0 284 4:589 0.262 4.3~9 -999. 250 FPS(.*. APS 999 250 -999.250 ENFR.APS :999:250 ,3.6 04 '999.250 FP$C.A~S ' 250 ENFR APS q99.. ,, . 2.763 999 25(') :999: ~S(,) ENPI.APS ENAR.AP$ ENPI.APS ENAR.APS ENPI.APS E~AR.APS ENPI.APS ENAR.APS ENPI.APS ENAR.APS ENPI.APS ENAR.APS ENPI.APS ENAR.APS ENPI.AP8 ENAR.APS ENPI. APS E N A R . A P $ ENPI.APS ENAR,APS ENPI.APS ENAR.,APS ENPI.APS ENAR.APS i;NPI.APS ENA. R.APS PAGE: 26 -999.~50 -999.250 -909.250 -999.250 22.107 0.731 16.597 0.686 16.109 0.698 18.085 0.695 17.532 0.691 17.254 0.687 18.378 0,.701 18 579 o:7 s 1,7.200 0.713 -999.250 -999.250 999 250 18 Tat, e veri.ticat~ion ~,istin~ chlumber!ter Alaska CoraputJng Center DFPT. ~ 909.90'? ~ PSC, A ~8 ANEC.APS -~99,250 AF'RC, ~mS MINV ..MLT 2. 250 rqi,~OR o H~ST DF'PT. R599. 967 APSC. APb ANE, C.APS -999.250 AFE'C.AP$ ;d I i',lV. MJ~T ~t. 0 2 4 M NflR. MLT DEp'r. 8399.967 APSC.ADS A~:,EC. APS -999. 250 AFEC. AmS MTNv. MLT 2,976 MNOR.'¢~'l,uT DEPW. 8199,967 APSC.Am$ A~'EC, APg -999.250 AFEC.APS MT_NV.MLT 2. ()'.~ ! M N OR. ,~,iL i~ DEPT. 7999.967 APSC.APS A~EC.APS -999,250 AFEC.APS MI~V.MLT 3.350 MNOR.~tLT DIe, pT . 7799.967 APSC.APS ANEC.APS -999.25('~ AFEC.APS 'MT. NIt, MbT 4. 445 ~q NOR. DEPT. 7599.967 APSC.APS ANEC. APS -999. 250 AFEC. APS M T t':~ V. N L, T 3.96 i, ~ N 0 R. ~ L, T DEPT. 6909.967 APSC.APS ANE(" ....... ,APS -999.25('I AFEC. APS DEPT. 6599.9,57 APSC.APS A,~,'!EC. h ~ .... -999,. 2r- ~ . , Jt AFF. CAPS I~l T NV, M I., T 2,9 76 ~ N 0 R. M L T 27-~AR-19Q5 -q99.250 WPSC.AP8 -999.250 ENFR.AP8 2.4~2 -999.250 FP$C.qPS -999.25~ ENFR.APS 4.246 -999.250 FPSC.A~S -999.250 ENF~.APS 4.827 -999.250 FPSC.APS -999.250 E.NFR,APS 3.22~ -999.250 FPSC.AOS -999,250 ENFR.APS 2.618 -999.250 FPSC.APS -~99.250 ENFR.APS 4.292 -999 250 F.PSC.APS -999:250 ENFR.AP$ 6.104 -999.250 FPSC.APS -999.250 ENFR.APS 4.017 -999.250 FPSC.AP$ -999.250 ENFR,APS 5.569 -999.250 FPSC.APS -999.250 ENFR.APS 5.164 :999.250 FPSC..AP$ .999.250 E~FR.APS 4.5'15 -999.250 FPSC.AP8 -999.250 ENFR,A~$ 2.!90 -999.250 FPSC.,AP8 -999,250 EbtFR.APS 3.1,99 -999.250 -999.250 -999.25O -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 999.25O :999.250 -999.250 -999.250 :999.250 999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 999 25 0 2999: 250 ENFI. APS ENAR.APS ENP!. APS ENAR.APS ENPI.APS ENAR.APS ENPI.APS ENAR.APS ENPI.APS E~:~'AR.APS ENPI.APS ENAR.APS ENPI,APS ENAR,APS ENPI.APS ENAR.APS ENPI APS ENAR:APS E N P '!. A P S ENAR.APS ENPI APS ENPI,.APS EN.AR.AP$ E~.PI,A $ ENAR,A:PS PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 99.250 -999250 =999:250 -~99..250 ,- 99.250 -~99 250 -999.250 -999.250 -999 250 :999.250 999.250 999.250 27 IS ~sve Yeti. float.ion L~.stint~ Chlumberqer A].asKa Comb, ut,(nn Center I'3~P~'. 6309. 967 AP,q.C. AoS A~EC. lPS -999.250 AFEC.A,~S k I ~i V. M I~ T 4.255 ?~} .q O a. M L 'I' DF:PT. 6109. 967 AOSC. A'm8 ANEC. APS -9Q9.2%1.1) AFF]C. A PS ~l N~,; . MbT 3. 345 ~4NGR. ~',LT DEPT. 5999. 967 APSC. AmS AMEC. APS -999. 259 AFEC. A.o,5 i'4 I. i',~ v ~,i !5 T 3 5 q 3l ,~ fq C R ~ b 'r . m · DF, PT. 5599.967 APSC.APS AMEC.APS -999.250 AFEC.APS }viI~3z. , .ul..,T 3.961. ~i',IOR.BLT. DF, PT. 5309.967 APSC.APS A~}EC. APS --999.250 AFEC.APS D~lPT. 51,,99.967 APSC.APS ANEC..APS -999.25{) AFEC. AP`5 ~TNV.MLT 4.03~ MiqOR. ~LT DEF'T 4,999 967 .RPSC ADS .., . . . . A. NEC. bPS -999.250 AFEC.AP~ M ? N v. ~ b T 4,..4 q 1. ~'1N O. M h T DEPT. 4709.967 APSC.ADS ANEC.APS -999 250 A[ EC.APS M 1 N v. ~,~ t5 T 4.0 l 3 ~ ~'!'O R. M ',L T DEPq~. 4,599. 967 z~PSC. Ar~S AMEC.APS -999 250 A~,~ APS ~INV.MbT 5.402 DEPT. 4490.134 APSC. ANEC. t~DS -999.250 AFKC.APS 'iq l,' N v. ~,~ Z, T .%. 552 ~ ~,{ O R. M t,, T 27-~,~A~-1995 11:3(1 999.250 FP~.C.AP$ -999.250 Er-~FR. APS 5.4t9 -~99.250 FPSC.APS -999.250 ENFR,AP$ 3.039 -999.250 FPSC.AP8 -999.250 ENFR.APS 4.201 -999.250 FPSC.AP$ -999.250 ENFR.APS 5. 409 -g99.250 FPSC.APS -999.250 ENFR.APS 4.805 -999.250 FPSC.APS -999.250 ENFR.APS 3.436 -999.250 FPSC.AP8 -999.250 ENFR.APS 4.461. -999.250 FPSC.APS -999.250 ENFR.APS :999 250 PPSC.APS 999~250 ENFR.AP8 4.079 -999.250 FPSC.APS -999.250 EMFR.AP$ 4.919 -q99.250 FPSC.AP$ -999.250 ENFR.AP$ 3.811 -999.250 -999.250 -999.250 -g99.250 -999.250 -999.250 -999.250 -999.250 2999.250 999.250 2~99.250 99.250 999 250 2999.'250 999 250 -.999 250 -999.250 -999. 250 -999.250 -999.250 Eb~PI.APS ENAR.APS ENPI.APS ENAR.APS ENPI.APS ENA~.APS E~PI.AP$ ENAR.APS ENPI.APS ENAR.APS ESFPI.APS ENAR.APS ENPI.APS ENPI.APS ENAR.APS ENPI,.AP$ ENPI.APS ENAR.APS ENPI.APS ENAR.APS PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999:250 '999.250 '999.250 -999.250 -999.250 '999. 250 -999.250 28 IS Tar~e Verifi. cation '[,istinq cblu~berqer AlasKa Co:~put. inq Center S~RV~CF~ : FbICi VERSIO:'~ : 00!C01 DaTF : ~aX REC SIZE L~Sq' WlBE 27-~Ag-~9Q5 11:3(i) PAGE: 29 FILF ~E : EDIT .005 SERVICE : ~LIC VERSIO:~ : o0tC01 DAT~ : 95103/27 M~X REC S~ZE : FI!.,F TYPE : LaSw FILE : BP EXPLORATIOM AP1 ~50-02g-22533 WILDCAT NORTH SI~OPE, ALASKA FILE SAr~DGE RATE: 0.'34!,67 FT, ,EDT HI RESOLUTION EbECTROI~AGNETIC PROPOGATIC)N TOOL (IPLT TOOL STRING) T~BLE TYP'E : CD! BP EXPLORATION Company Name FN WILDCAT Field Name WN BADA~I ~5 Well Name AD'I~) 50-629-2253,] ~PI Serial. NUmber FL 3334'SNb & 4770'~Eh Field Location 6EC? 3 Section TOW~,~ 9~ Township RAi'~(~~ 20E Range COUN NORTH SLOPE County STAT ALASKA State or Province N~T! liSA Nation WIT~) PUTNA~ Witness Name SON 629136 Service Order Number PDAT IC5 PAD Permanent datum IS Ta~e ~'erificat.lon Listinc~ CblUmber-qer AlasKa Comput~oo Center 27-NAR-1995 11 :30 PAGE: 30 EPD FT ~. Elevatlo ADb ~T 34. EDF FT 33 TDD F~ 1~549. T~I., FT 1~544. BLI FT 1~524. T[.,I FT 36. DFT CORE DEl.) G/C3 DFV S · DFL F3 4.6 ~S OH~ 0.743 ~ST DEG,' MFS~ DEGF 5~, R~C~,., OH~ 2 33 MCST DEGF 66, ~T DEGf' 158. Log ~easured From Above Permanent Datum Elevation of Kelly Bushing Elevation of ~errtc~ Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval TOp [,o~ Interval Drilling F']u~d TFpe ~rilling Fluid Density Drilling Fl.u~d Ph Drilling Fluid 'Viscosity Drilling Fluid Loss esistl~it¥ oi Muo Sample ud Sam~].e Temperature Resistivitv of Mud Filtrate S ~lud F1].trate SamPle Temperatu Resistlv{t¥ of ~ud CaAe Sampl ~ud Cake Sample Temperature Bottom Mole Temperature DEFI DEP? OePth E:PR EPT Resistlvitv EPH].' EPT Porosity E~TT EPT ,Attenuation TPL Time of Propagation in Lo[sy Formation ** PATA F ORr~A~ SPECIF:!CATI[}N RE:CORD ** l, 66 0 2 66 ,0 3 73 20 4 66 ]. 5 66 6 73 7 65 8 68 0,04J. Tape Verif,~catlo~ [istln~ chlumberqer AlasKa Com~utin~ Center 27-MAR-1995 11.:3(.) PAGE: 31 m~mmmmmm m mmmmmmmmmmm mmmmmmmmmmmmmm m mmmm 9 85 12 68 13 6o 0 14 65 15 6~ 68 1.6 66 0 66 mmmmmmmmmmmmmmm~mmmmmmmmmmmmmm ** SET '~-~F' S~':''~R ....... iT SE~V:~F AP1 A;~''X;''';~'~;~[I ........ NUM~ ~';~''~[[''~[[''';~;[[;;'''0 _ ID ORDER ~ LOG TYPF CLASS MOD NLI~B SAMP ELKM CODE (HEX) i)Kp~ FT 629136 O0 000 O0 0 5 1 1 4 68 O00OO00000 EPR EPT Og)~U 629136 O0 000 O0 0 5 1 1 4 68 O000000OO0 EPHI EPT PU 629136 O0 000 O0 0 5 1 1 4 68 0000000000 Eg'I'Y E, PT DB/~ 629136 O0 000 O0 0 5 1 1 4 68 0000000000 TPL EPT NS/~ 629136 O0 000 O0 0 5 ]. i 4 68 0000000000 * * D A T ~ * * D~PT, 1~377.975 EPR. E'.PT ~,875 EPHI., E:PT 13,446 EATT,EPT DFPT, 11200,018 f:PR,EPT 10,063 EPHI,EPT 2,051 EATT,F. PT TP[..,,EPT 9.289 DEPT 11000 018 EPR., EPT 3,6B8 EPHI,EPT 1,563 E~TT,~PT DEPT, !0800,0~.8 EPR.EPT 2.013 EPHI,EPT 13,853 EATT,EPT TpL,EPT ) 1,961 DTpL,EpEPT. T 1061.1. ~59<~00 O1~ EPR,EPT 2.557 KP~'I,EPT 12,988 EATT,EPT D~P'r, 10400,0iS ~:V~,~:PT 1.51! ~:P~I,EPT 26,0~3 ~i; ATT, ~¢PT *PL.EPT 14,180 DEPT 10200 0~8 EPR.EPT 2.400 EPHI ~., I~ 13.754 EATT F. PT DEPT 10000,018 EPR,EPT 2.734 E.P}.{ l., EPT 7,422 EATT,EPT TPI~:EPT 10.695 ' 4~0.042 23'1,000 345,500 362,000 431,219 369.719 366,000 ,IS 7'ape verification Llstino ,cblumberger ^las~a Comput, l.n~ Center TPL.5~PT 14.383 DE'PT. 9600.01,~ EP~.~:Pl TPI.EPT 13.9S~ DEPT. 9574.018 EPR.EPT TpI.FPT ~8.000 END L,F BATA $~ 27-~AR-1995 11:30 1.525 ~:P~I.EPT 1.7~4 EPFtI.EPT 0.961 EPHI. E.~T 27.124 EATT.EPT 25.574 EATT.EPT 45.313 EATT.EPT PAGE: 425.750 395.375 508.000 32 **** F T L,F.. TRAIbER F'TLF- NA~E : EDIT .005 SFRVICE : FL, IC VFR$IO~ : O01C01 [3 ~ 51'K : g5/03/~7 ~lX REC SIZe7 : 10~4 F 1' I.,F TYPE : '[, 5 ST FILE : Flb~: NA~E : EDIT .006 8FRV ICE;, : FLIC ~ERSION : O01COI D~TF : 9510~/27 ~X R~C SIZE : 1024 FILE', TYPE : LO l,~ ST FILE: : BP EXPbORATION AP1 ~50-629-22533 ~ I [.,[)CAT ~O~TH SLOPE, ALASKA FI'bE EDIT.O06 ************* a~,,,~ F'IE[,D aAI:N LOG FILE 0~' RUN ~1 (SURFAC~ RUN) ,DTE] PNASOR INDbCTIOM TOOL ,LGG1 LONG SPACED ~ONIC (REPROCESSED DT CONPRESSIONAL DUE TO CYCI,,E SglPPING) I$ Tar~e Verif~.cation Listina chlumberger AlasKa Computino Center 995 1 1: 30 PAGE: 33 TYPE : CONS TUI,i I VAI, U OEFI ..........................................C~' ~,P [~[,;~AT.I.O~.) ..................................................... Compa~v ~.~ame Field Name FT FT ~T FT ~/C3 $ DEGF DEGF API~ S~CT TO~ C 0 U ~ STAT NATT PDAT EPD L~F A EDF T D D TDL BL I TL I D ~ T D'P b i~tST R ~ CS BADaMI ~5 50-629-22533 3334'S~[, & ~770'~EL 3 9~ 20E NORTH SLOPE A.bASKA USA PUINA~ 629~36 iCE PAD 4. 34, 38. 33 11544, CORE 12.5 7 0 ~ 7 43 6 0 !98 ~ell ~ame API Serial Number Field Location Section Township Range County State or Province Nation witness Name Service Order NumDer Permanent datum Elevation of Permanent Datum Lo~ W, easured From Above Permanent Datum Elevatl. on of Kelly Bushing Elevation of Derric~ Floor Elevation of Ground Level Total DePt~ - Driller Total. Depth - Logger Bottom Log Interval Top [.,og Interval Drill,.no Fluid Type Orill ng Fluid Density OrlllI~ Fluid Ph Drill .... Flula Viscosity Drilling F,lu~d boss Resistiglty of Mud SamPle ~u'd Sample Temperature, Resl~t.i lty of Mud Filtrate ~ud ~ltrate Sample Temperatu 2,33 Resistivl. ty of Mud CaKe Sampl TA6I.,E TYPE : CU~V DEFI DEPT Dent CIDP INDUCTION' DEEP Pt, IASOR CONDUCTIVITY IDP~ '.INDUCTIO~\~ ~EEP pt,{ASOre RESISTIV:ITY CIMD !NDUCTIO'N ~EDILI~ PHASOR CONDUCTIVITY IgPH INDUCTION ~EDIU~ PHASOR RESISTIVITY C!bD COnductivity IL Deep Standard processed ILD Deep IDduct.lon Standard Processed Resistivity CI!,~ Conductivity IL Medium Standard Processed IS lane Verification bj. stinq cblumberoer A].aska ComputinO Center 27-~AR-1.995 .!..~ :30 PAGE: 34 DEFT m mm mmmm mmmmm mm~mmmmm~mmm m~mmmmmmmmmmmmmmmmmmm mmmmm m mmmmmmm I[,M ~edium l~d~ction Sta~ar~ Processed Resistivity IFRF InduCtiOn Calinrated Frequency IDQF Induction Dee~ Qual. it~ Factor l~OF Tnduct~,on ~ed ~]m Oual t¥ Factor ITRD Deep Inductio[] Real Intermediate CoDductivit¥ IIXD I')ee~ Inductioh (~uad Intermedlate ConductlvitT [IR~,~ ~4ed um Induction Real. IntermeO~ate Conductiv t¥ IIXS~ ~edi~]m ~nduction Ouad Intermediate Conductivity SFLU SFL Resistivity Unavera~ed SP Spontaneous Potential G~ Gamma Rav T~S Tension ~Tf]~ ~d Temperature ~R~iS ~[JD Resistivity HTE~ ~!ead Tension i)TCn DELTA-T CO~PRESSIONA[~ DATA FORgAT SP~CIFICA, TIUN RE£ORD ** ** SET TYPE - 64EB ** TYPE REPR CUDE 'VALUE 1 66 0 2 66 0 3 73 96 4 66 5 66 6 73 7 65 8 68 0,5 9 65 1.1 66 10 12 68 13 66 0 1~ 65 FI: 15 66 68 16 6(!5 1 0 66 ** SET TYP~] - CNAN ** !D ORDER ~ LOG TYPE CL,ASS MOD NUMB SA~P EhEM CODE (HEX) '~[¢~ ......... ~,,' ~2";i~;'"oo ......... oo~ '"'""ooo ............. ~ ~.'i' ..... ~'"",,'"'"'"',"'"' oooooo C10P DTE1 iqg},iO 6201.36 O0 000 O0 0 6 1 1 4 68 0000000000 IDPF~ [)TEl {]N.M~'~ 62g!36 O0 000 O0 0 6 i 1 4 68 0000000000 I$ Tane Ver.~ fi cation l~istino chlumberqer AlasKa Computino Center 27-~.,%~-.1995 1! :.3o PA(;~: 35 .... ...... ........ ; ..... ;'"r ....... i ; I~F'~ D"YE1 [.)H~ 629136 O0 000 O0 o 6 1 1 4 68 0000000000 CI. LD DTE1 :q~HO 629136 00 00() 00 0 6 1 I 4 bg 0000000000 ILD DTE1 OHN~ 62q136 O0 000 00 0 6 1 1 4 68 0000000000 CID~ DTE1 ~,i[{0 629136 ()0 000 O0 O 6 1 1 4 bS O00000OO00 I[:~ [)TEl [}n t~; ~ 62qi36 O0 000 O0 0 6 1 1 4 68 0000000000 IF~F [)TEl HZ 629136 0(.) 000 O0 0 6 1 1 4 68 0000000000 IDOl' DT[~I 62q136 OO 00(~ O0 0 6 1 1 4 68 0000000000 I ~ ~',~~ DTE1 &2gl3b 00 000 00 0 6 1 1 4 68 0000000000 IIRl" DTE1 M~,f~O 629136 O0 000 O0 0 6 1 1 4 b8 0000000000 IlXP, D'YE1 ~,i),!d~ 629136 00 000 00 0 6 1 1 4 68 0000000000 II~', D'.fEI. M~hO 629.136 0() 000 O0 0 6 1 I 4 68 0000000000 IIX['~ DTEI ~qY, dO 6291.~6 O0 00() O0 0 6 1 1 4 68 0000000000 SFLU DTM1 (O~,~ a2OI3h 00 ()00 O0 0 6 1 I 4 68 0000000000 SP DTE1 M~ 629i 36 00 000 00 0 6 1 1 4 6g 0000000000 GR 9TEl GAPI 620136 O0 000 00 0 6 1 1 4 6~ 0000000000 1'~ ~>~ S DTE1 bB. 620136 O0 000 O0 0 6 I 1 4 68 0000000000 NTE}~ DT~I DEGF 62913b O0 000 O0 0 6 1 I 4 68 0000000000 NRES DT~I O~!a~{ 629136 O0 000 O0 0 6 i 1 4 6a O000OO0000 HTE~: DTE1 hB 629136 O0 OOO O0 0 6 1 1 4 68 0000000000 * * I) A T ~ * * DEPT. 4551 501) CIDP [,'re;1 486 000 IDPH D!I'.E~. 2 057 CII~tP.DTEI I~PH. DTF, 1 2.1,25 C I I~L). D'.'rE 1 490~000 ILD,DTE1 2~039 CIL~.DTE1 .IL,~. DTE1 2.125 IFRE.DTE1 20.000 IDQF.DTE1 3.000 IMQF.DTE! ...... · ~ ') a '. · ,, IIRD.DTEi 393 50{) IIXD Lq. E1, 74 438 IIRM.DTEI 434 250 III~.DTE1 S F I, T,.'~, D T E 1 2.80 ~, S P. D T E 1. - 21 ~ 875 G R, .. D T E 1 35.875 T E N $. D T E ! N~E',~. D'l'~ 1 76.887 ~qRES. [)TEl 2.984 HTEN.DTE1 -1,85.000 DTCO.LSSI DEP,.~' ,440o.000 CIDP.[)TE1. 693 500 !DPH,[)TE1 1.440 CI,~!P.[)TE1 I~F' .DTEI 1.658 CII..,D. I)TE 1 738~000 I[,D. DT,E1 1.354 CIL~. DTE1 Ib~. D':rEi 1, b35 IFRE' DTE! 20. OOO IDOF't) TE1 O. 000 I~OF. DTEI IIRD.DTE1 553.500 IiXD,DTE1 97.875 IIRg. DTE1 559.500 II,X~.DTE1 SFLU.DT~I 3.000 SP.DTE1 -59.188 GR.DTE1 20.906 TENS.DTE1 MTE'~,"~. DTE 1 7b.91b ~4RES.DTEI ~.949 HTE~',,!, DTE 1 945.500 DTCO.LSS1 DFPT. 4,200.000 CIDP.DTE1 530.500 IDPH.DTE1 1.8"84 CIMP.DTE! I~P~'.DTE1 2.061, CI i,D. D'.,~E 1 540.500 ILD.DTEi 1.849 CILM.DTEI IL~.DTE1 2.012 I FRE. [,)'~E 1 20.000 IDQF.DTE1 0.000 I~OF.DTE1 .,,,,.t 1 42b 5O0 IIXD [)TE~ 83.125 IIRMoD'.PE1, 458 000 IIXM DTE1 SFI.,I.~. D'~'F 1, , 2.926 SP . [)TEl - 31.031 (,R. DT~,I" ' 44: 4~9 TE,~S. DTE 1' v ~iTE~. DT[< ! 76.831 ~qRES.DTE1 2.881 HTEN.DTE1 969.500 DTCO,.LSS1 DEPT. 4000.000 CIDP.DTE1 344.000 !DPit~. DTE1 2.906 I ~ P ~'i. D T E 1 2.9 ,~, 1 C I L [). D T E !. 347.000 I [, ['). D T E 1, 2,881 I'. I.,, u. [,.> ,,.f,~., 1 2 .9 ! 2 I F ~ E.. D T E ! 20.000 I b 0 ~. 0 T ~ 1 0 .000 I I R D. D T E 1 289.000 I l X ,0. D T E 1 4,4.7,19 ~ I E g. D T ~'~ l ] 19.750 470,000 470.000 2'000 ~6!344 1590 000 -999 250 602.500 611.500 0.000 35,625 31,40.000 102.913 484.750 496.500 0.000 38.406 3030.000 11.4.349 339,750 343250 OiO00 28 21,9 IS Tar~e verification Listinq Cbl.m, beruer Alaska Computinn Center ~,TE~ . LT.'E I 76.944 k~R FS. i)T6 ~ DFPT. 3600.000 CIDP.DTE! IWP}!. D,TEI 1.i70 ILF.. DT.F 1 1.1 $~5 IFRE. I)TE IIPD. DTEi 704. 500 I IXD. I-)TEl SF[.,I~. DYE i 2. 605 SP. MTE~.~. DTE1 73.2~8 DFPT. 3400. Oreo CIDP. DTE1, I~PH.DTE1 2.260 CILD.DTEJ l I.., ~. D'.i"~ :t 2.229 iFPE.DTE1 Il ~g. r~S"~ i 403.000 IIXO.DTE1 SFLU. DTE1 2. 590 SP. DTE1 MTE~.DTEI 72.7~1 DFPT. 3200.000 CIDP.DTEI, I ~ P I-{. D T E 1 I. 137 C I L D. D T E !. IL~i. D'fEI 1.1.56 IFRE.DTE1 I!RD.DTE1 6a6.500 I [XD.DTEI I~F'I,U, DTE..~ 2,92~ SP. DTE1 MTE.~I, DTE 1 73,513 ~R ES., DTE I. Ii) FPT. 3000. 000 CIDP. DTEI I~PH.DTE! 1.45,5 CILO.DTE1 I[,U.D'rE1 1.445 IFRE.DTE1 II~D,DTE1 584~00(; IIXD,DTE1 SFb!~. DTEI 3.871, SP. DTE 1 ~!TE~. DTE 1 72.106 MRES,DTE1 DEPT. 2800.000 CIDP.DTEI IMP~. DTEI 1. 177 CiLD, DTE1 T L~'~, DT~I 1,195 IFRE.DTE1 IIRD.I)TE1 701.500 IIXO' [)TEl. S F b U. r) T E 1 2.352 S P, D T E 1 gTE~:'. DT'E 1 70.531 [Ia~S,OTE1 DEPT. 2600,000 CIDP.DTEI, IMP~'. DY[.11 1.637 CILD.DTE1 1I,,~,. DTEI 1.650 IFRE.DTE1 I 1 ~. D [> T E t 538,500 t I X [:>. [>T E 1. SF~I.,I~[I. TE.I.3 " 2,953 SP.,[)TE1 ~fTE~. DTE 1. 68,36b aRES, DTE1 27-MAR-1995 11:~0 -35. 656 GR. [)TEl 2. t~61l MT~N.DTE1 439.250 !DPH.DTE1 448.5'30 ILD.[)TE1 26.000 IDOF.DTE1 55.719 II~M.DTE1 -42.Oo3 GR.DTE1 9.. 945 HTEa. DTE 1 9~,~2.5,~0 IDPrt. D'I'E1 ~85.500 ILD.DTE1 20.000 IDOF.DTE1 175.8'15 IIRi~.OTE1 -o5.813 GR.DTE1 3.033 HTEN,DTE1 497.000 IDP~.DTE1 497.750 ILD.OTEI 20.000 IDQF.DTE! 85 5,~3 l IRM. [)TE.1. -291797 GR , DT~I 3,f)O8 HTEN.OTE1 893.500 IDPH.DTE1 982.500 ILD.DTE1 20.000 IDQF.DTE1 136.875 IIRM.OT£1 -68,375 GR o DTEI 3 . 002 HTEN . 761.000 IDPH.OTE1 782,500 20.000 IDOF,DTE1 138.625 I, I R ,'~. O'.'[' E .1 -~2.031. (;R,DTE1 3.059 HTEN,DTE1 56,031 978.500 2.275 2.229 0.000 453.250 68.875 987.500 1.061 1.014 0.000 760.000 35.313 987.500 2.010 2.008 0.000 414.750 50.750 9~5.50o 1 lt8 1:018 0.000 778.500 28.516 965.000 1.313 ~.~77 0000 630~000 33.313 991,.090 938.000 IDPH.DTEI ![.065 969.500 II, D.DT£1 1.03~0 20 . 000 I D Q F , t~ .1' E 1 0.000 185. 750 I IR'M. DTEI 754. 500 -T?4:. 250 GR, DTE.1 33.313 3,162 NTEN,DTE1 i024,000 697.500 IDPH.DTE1 687.000 ILD,DTE1 20.000 IDQF.DTE1 1.38.125 'ilR~..DTE1 -63.906 GR,DTEI 3.242 HTEN.DTE1 1.433 1.454 0.000 554.500 42.469 1043.000 TE~S.DTE1 DTCO.LSSI CIMP.DTEI CIL~.DTE1 IMQF.DTE1 IIX~.DTE1 TE~iS.DTE1 DTCO.L$SI CI~P.D'IE1 CILM.DTE1 IgQF.DTE1 IIXM.DTE1 TENS.DTE1 DTCO.LSS1 CIhP.DTE1 CILM.DTE1 !MQF.DTE1 IIXg.DTE1 TENS.DTE1 DTCO.L$S~ CIMP.D1E1 CILM.DTE1 I~OF.DTE1 IIX~.DTE1 TENS.DTEI DTCO.LSS1 CIMP.DTE1 CIL~.DTE1 IgQF.DTE1 IIXM DTE1 TENS~DTE1 DTCO,L~S1. CIMP.DTE1 CILg.DTE1 I~GF.DTE1 IIXg.DTE1 TENS.DTE1 DTCO.L8$1 ClMP,DTEI CILM.DTE1 IMQF.DTEI IIXg.DTEI TENS.DTE1 DTCO.LSS1 PAGE: 36 30].5.000 118.057 473,750 491.500 0,000 77.000 3010.000 112.305 854.000 842.500 0.000 84.375 2920.000 127.917 442.250 448,250 0.000 58.438 11 531 879,500 864.000 0.000 75 625 2s9o2ooo 126,533 686.500 691..500 0,000 71.563 2495.000 137.859 849 .000 0.000 91.563 2440.000 139.2:94 610.500 605.500 0.000 63.313 2345,000 138,138 IS 'rape Verification l. istlncl ChlUmberoer .~.].asKa Colnotltinq Center DEFY. 240f). 0DO CiDP. i~PP.DTE1 1,094 CILL). IL~~ . D'.ITE i 1. Oq6 IFRE. I 1 ~[',. DTE l 711. 000 I IXD. SFL~. D'YE 1 2.574 SP. ~TE~. DTE l &7.241 ~RES. OEP?. 2200.00{} C I. Pp. IUPl'!. DTF, 1 !.713 CII,D. TL~,~. r;:r~ t i .681 IFRE. ITRD. DTE l 501. 500 IiXD. SWi, l~.r)T1;',l 3.33o SP. NTE[;. DTF [ £.6. O~H DEPT. 2000.000 CLOP. I l~Pl~"!. DTE i 4.727 C.[LD. IL~,DTEI 4,453 IFRE. IIRn. DTEi 21 O, 000 11XD. SFL!!. DTF, .1 5.52{) SP MTE~~, . DTEI 63. 500 DEFT, 1800.000 CIDP. I~PH. DTF.[ 33.563 CIt.,Do ILY', DTE1 31,406 IFRE, I!NP.,DTE! 5,002 I[XD, SFLU. r.) T E71 702. 500 SP. D~YPT. 1600.000 CIDP. I g P U. D T E 1 39.250 C I I,., D. IL~,.DTEI 37.531 IFRE. IIRD.DTEI 1.1.742 IIXD. SFLI~. DTEI 227. 375 SP. NTE~.DTMI 66.059 Y~:RES. D~PT. 1200.000 CIDP. INP~,'~. [:,TEI 5.41.4 CILD, I L ~.~. D T E i 5.7 ~. 9 I F ~ E. IIRD,DTE1 .141.250 IiXO. 5FLU, I)TFi 37 · 000 SP. MTE~?, I)T F.: 1 65,469 ~q:aES. DEPT. lO00.OOO CLOP. I ~ P H, D T E ! 7. '7 !, 1 C i L [',. l L ~'. D 5717711 6.8 a 0 I F R E. ITRD.DTE1 108.500 IIXD. SF'LI~. DTEI 9696.000 SP. NTEP:. DTEi 63. 584 ~4RES, 27-~,AR- 1. 995 1. 1.: 30 9bl .1300 !DPH.DTE1 990. 500 ILO. [)TEl 20.000 IOOF. D'I'E! 177,500 I IRt"',. OTE 1 'b6.500 GR.OTE1 3.248 }tTE~, DTEI 638.5~0 IDPH.DTEI 65~.500 IBD.DTE1 20.000 IDOF.DT~I 105.438 IIR,~.DTE1 -47.813 GR.DTE1 3.4i2 HTEN.DTE1 246. 875 !OPM. 248.375 II,O.DTEI 20.000 IDOF.DTE~ 29. 156 IIRrq.DTE1 -48. 563 GR. OTE1 3.545 HTEa. DTE1 2.623 !DP~i. D'FE1 5.g~5 ILD.DTE1 20.000 II)OF.DTE1 -0.354 IIRa. OTE1 -66. 375 GR. [)'FEI 3.396 HTEN.DTE1 5.949 IDPH.DTE1 9.0~6 ILl). DTE1 20.000 IDOF'.DTE1 -0.203 ! IR~,I. DTE1 -63. 344 GR. DTE1 3.240 HTEN,DTE1 36 500 IDPH. DTEI 35~281 ILD,DTE1 2().000 IDOF, DTE1 -0,112 !IRM.DTE1 -e~.5oo G~.DTEI 3.264 HTEN.DTE1 171 0 0 0 ~ D P.S. ~ T ~ ~ l. '7 4: o o o I L r:,,. DT¢ 1 2().000 I.DQF. DTE1 6.859 !IRM.DTE1 -29.922 GR.DTEI 3. 303 HTEN, DTE1 129.625 IDPi,t'. DTE 1 125.750 I I., D. L)'FE1 20. 000 !DOF, OTE1 ~. 258 i I R iq. D T E 1 '40. 844 GR,DTEI 3.449 HTEN.DTE1 1,051 1.009 O.OOO 819,000 27.3t4 1093.000 1.564 1.531 0.000 544.50O 30.719 1040.000 4 047 41o23 0.000 210.625 35,625 981,000 81. 000 0,000 30 281 1021.000 ~0 168.0u 1,10.000 0.000 25.344 33.9~9 956.500 27.375 28,328 0.000 97 063 914.500 5 84,4 5~7,42 0.000 164.625 23,.047 933,500 7.~707 7,949 0.000 !37.875 23.813 963,500 CINP.DTE1 CILM.DTEI I~OF.DTE1 IIX~.DTE1 TENS.DTE1 DTCO.[,SS1 CIMP.DTE1 CIL~.DTE1 IMQF.D'~E1 TENS.DTE1 DTCO.LSS1 CIMP.DTE1 CIbM.DTE1 IMGF.DTE1 IIX~.DTE1 TENS.DTEI DTCO.L$S1 CI~P.DTE1 ClLM.DTE1 I~GF.DTE1 IIXM.DTE1 TENS.DTE1 DTCO.LSS1 CIMP.DTE1 CIbM.DTEI IMGF DTE1 IIXM:DTE1 TENS.DTE! DTCO.LSSI ClMP DIE1 I~OF.DTE1 IIXM.DTEI TENS.DTEt DTCO.LSS1 CIMP DTE1 CIL~:DTE! iMQF.DTE1 IIXM.DTE1 TENS.DTE1 DTCO,LSS1 ClMP.DTE1 CIL~.DTE1 IMQF'DTE1 IIXM.DTE1 TENS.DTEI DTCO.I,,,8SI PAGE: 921.500 912.000 0.000 91.000 2200.000 150.219 583.500 594.500 0.000 50.531 2050.000 150.117 211,375 224,375 0.000 13,344 1915,000 146.834 29.781 31,828 0.000 0.184 1860,~00 25453 0.oo0 2.824 1625.000 93,386 10 , 0 0,000 1 86 94.782 18~.625 17 .750 0,000 1.35~':430000 6~o000 129.625 1,46.125 0,000 7.176 125~.000 7'~675 37 Tape Ver].ficetJon List:inc~ chlumberqer Alaska Cor~putino Center DFp~'. 36.000 CiDP.OTEI I~P~!. DTE1 -999.250 CII,,£). DTE I IL~,~.DTE1 -999.250 IIRP.DTE1 -9q9.250 IIXD.DTE1 SFBI>.DTE1 -999.250 SP,DTE1 ** END [)F DATA ** FIL1U ~iA~E : EDTT .006 S E H. V 1 C E : F,!,, ! C · v'~TRs I o~ : oo~,COi [) ~'J'~E : Of/t)3/27 ggX ~EC S'[Z~ : 1024 F ]..LE TYPE LAST FILE : 995 11: 30 12.945 ! DPH. OTk;1. 9.7:58 II, D.DTE1 20.OO0 !DQF.OT6I .!.092 IIRi~.DTE1 -33. I 56 C~. DTE1 3.361 HTEN.DTE1 44.719 IDPH.DTE1 ~5.438 IbO.DTE1 20.000 IDQF.DTE1 0.391 IIR~4,DTE1 -~5. 375 G~. OTEI 3.242 NTEN.DTE1 a2.563 IDPH. OT6~1 51.156 I!.,D.DTE1 20.000 lPQF.DTE1 11.172 IIRM.OTE1 -51.531 GR.DTE1 3.3'38 NTEN.OTE1 7~6.000 IDPH,DTE1 ~26.500 ILD.DTE1 20.000 IDQF.DTE1 86.313 !IRM,DTE1 -30.844 GR. DTE; 1 31. 332 H T E ~"~. DTE1 -999. 250 II[)PH. DTE1 -999.250 ILD.DTE1 -999,250 '.T DOF, OTE 1 '999.250 IIRa,DTE1 -999. 250 GR. DTE~ -999.250 },;TEt~. DTE1 77.188 102.438 0.OO0 16.094 32.969 961.500 22.344 22.000 0.000 53.500 28.25O 953.000 23..484 1.9.547 0.000 76.500 2J.297 939.500 1.305 1.209 0 000 6541500 38.906 909.OOO -999 25O -999.250 -999.250 -999.250 -999.250 -999.250 ClMP.DTE1 CILU.DTE1 IMOF.DTE1 IIXM.DTE1 TENS.DTE1 DTC~.LSSl CIMP.DTE1 CIbM.DTE1 IMQF.DTE1 IIX~.DTE1 TENS.DTE1 DTCO.bSS1 ClgP.DIE1 CILM.DTE1 IgOF.DTE1 IIXM.DTE1 TENS.DTEI DTCO.LSS1 ClMP.DTE1 CILM.DTE1 IMQF.DTEI. IIXM.DTE1 TENS.DTE1 DTCO.L$S1 CIMP,DTE1 CILM.DTE1 IMQF.DTE1 IIXM.DTE1 TENS.DTE1 DTCO.L$SI PAGE: 38 -7.813 16.906 0,000 7.273 1190.000 95.526 54,969 56,344 0.000 1.I63 1085.000 106,392 71.250 80.688 0.000 6.949 940.000 85.210 729.500 720.000 0,000 52.750 755.000 165'317 '999 50 '999 250 '999,250 '999.250 167,077 IS l"at>e Ver.i~i.ication ChlUn:berrler Alaska Computtho Center FTbF NAt4E : Ei..,TT .007 SFR~!CE : Fb!C I.) h T F. : 05/03/27 ~:aX kEC STZ~ : ~024 FILK ~YPg : I,g LaS? FIU~ : 2'/-5'i'AR-1905 11: PAGE: 39 BP EXPLORATIDN ~PI #50-629-22533 W I I.,DC A? t, iOR?M SLOPE, At, ASKA FII,E EDIT.O(>7 ShSPI~,,~ RATE: 0.5 FT. RA~' FIEhD ~*'~,IN !.,[]G {)F RUN ~3 (INT~R~EDIA',fE RUN) .DSi3 DIPDLS: S[jbJlC IMAGER TOt']b .LDT] LITf~O DENSITY TOOL ,CNT3 COMPENSATEI., NEUTRON TOO[., .M!,¥3 ~,~ICR[~bOG CA[,IPER (RI!N t~It}4 .DTE] AND .OSI3 TOUb STRING) TAB!,E ?YPE : COM$ '1' U N !7 V ~'~ I,,, U O E F I ..... .... . .............. ... ........ ..--~.-~;~---., ~ ,, .... ,,----- .... .............. .... ..................... C~,: P C .,t. aAII[)~ Cgm?an~ Name FN WILD AT Fleld Name FT BAD,ANI ,~5 50-629'22533 13334,'SN5 & 4,770 3 20E t,i(}RTH SI,,(,lPg USA P l.J T N A M 629136 I Ct::' PAP 4, 34, Nell Name API Serial Number Field bocatton Section Township Range County State or Province Nation Witness Name Service Order NumDer 'Peri, anent datum Elevation of Permanent Datum Log Measured ~'rom AOove Permanent Datum Elevation o~ Kelly Bushing Elevation o~ [)err~cK Floor Elevation of Ground Level IS TaPe V~ri~!¢at~on ~,j. st.lnq Chlornhero. er AlasKa Co~puting Center 27-HAR-] 995 II: BO PAGE: 40 TDD 1_~544. Total Depth - Logger TDL FT B[,i FT 11524. T[,I WT 36. DWI' COkE DFD G/C3 12.5 DFP+~ 7. DFV $ 76. DFL F3 R~S OH~ 0,743 ~ST DEGF" 66 ~FS'r DECF 55. R~CS OH¢~ 2.33 ~iCS~' DEGF 66~ bHT DEGF 15~. Bottom bo~ Interval Top Lo, I terval Drilllng f'luid Type Drilling Fluid Density Drilling Fluid Ph Orillin~ Fluid ¥iscosit¥ Drilling Fluid boss Resistfgit¥ of Mud Sample '~lud Sample Temperature Resistivity of Mud Filtrate S ~ud Filtrate Sample Temperatu Resistivity of Mud CaKe Sampl ~ud Cake Sample Temperature Bottom Hole Temperature DEFT DE CIDP IDPSq CI~P ! SFL!J SP G~ ,~'tR ES HTE~ D P H l DRHO PE'F TENS MRES N P it I C ~ T C CFTC D T 4 ~ bT2 PP C~ L ~ DePth .[NDUCTIO~ nEEP PHA$OR CO~gDUCTIVITY I~OUCTIO~ DEEP PHASOR RESISTIVITY INDUCTION ~EDit,.I~ PHASOR CONDUCTIVITY INDUCTION ~EDI(Jr~ PHASOR RESISTIVITY SF[ Resistivity Unaveraged SpoDtaneous Potential Gamma Ray Tension ~ud Temperature ~UD Resistivity Head Tension Density Porosity Bul~ Density ~elta RHO PhotoE;lectFlc Factor Caliper Gamma Ray Tension ~t].d Temperer, ute ~UD Resistivity Head Tension Net]tron Porosity Thermal Net]tron Ratio Calibrated Corrected ~,tear Thermal Counts Corrected Far Thermal Counts DELT.~-T CO~PRESSIONAI..~ HF ~ONOPOLE COMPENSATED (P&S) DELTA-T SHEAR UPPER DIPO[,E MODE COMPENSATED Poisson'S ~atio Caliper Tape Verification bistinq chlLlmberger Alaska Computing Center 995 11: 30 PAGE: 41 emmmmmmmeemmmmmmmemmmmemmmmmemmmmmmmmmmm~mmmemmmmmmmmmmmmee ** DATA FOR.~AT SPECIFICATION RECORD ** SET TYPE - 649~ ** TYPE ~ ALUE 2 66 0 3 73 120 5 66 7 65 8 68 0.5 9 65 FT 1] ~6 8 12 68 1) 66 0 14 65 FT 15 66 68 16 66 ] 0 66 1 DEPT FT 6291 )6 O0 000 O0 0 7 1 1 4 68 C,T, DP DT~3 ~!Nl~{O 629136 O0 000 O0 0 7 1 1 4 68 IOP~ 'o'rF3 OH.M~ 629136 00 000 00 0 7 1 1 4 68 CIMP D]I;E3 MMHO 629136 O0 000 00 0 7 I I 4 68 IM.PH' DTE3 {:)Ha~ 6291 '36 00 000 O0 0 7 1, I 4 68 SFL[~ DTE3 OHM~ 629136 O0 000 O0 0 7 1 1 4 68 SP DT~3 MY 629136 00 000 00 0 7 1 1 4 68 G~ DTE3 GAPI 629136 00 000 00 0 7 i I 4 68 TENS DTE3 L[~ 629136 O0 GO0 00 0 7 1 1 4 68 MTEu DTE3 DEGF 629136 O0 000 O0 0 7 1 1 4 68 ~RES DTE3 OHMM 629~36 O0 000 O0 0 7 i 1 4 68 [{TEN DTF3 bM 629136 00 000 O0 0 7 1 1 4 68 DPHI LDT3 PU 629136 O0 000 O0 O 7 1 1 4 68 RN(,)9 bDT3 G/C3 629~6 O0 000 00 0 7 1 I 4 68 DRH. O LDT3 G/C3 629136 O0 000 O0 0 7 1 I 4 68 pEP LOT3 629136 O0 000 O0 0 7 1 1 4 68 CILI LDT3 IN 629136 O0 00() O0 0 7 1 I 4 68 (;R bDT3 G~PI 629136 O0 000 OO 0 7 1, I 4 68 T~NS [~ i~i) T 3 [d[~, 629136 00 000 00 0 7 ], i 4 68 NTE~', LDT3 DEGP 629136 O0 000 O0 0 7 1 I 4 68 aRES LOT3 OHMa 629136 O0 000 O0 0 7 1, 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TaDe Verification [,istina chlumberger AlasKa Computing Center 27-~A~-1995 11:30 PAGE: 42 APl A TYPK CbA$S MTT'.~ LDT3 LB 629136 O0 OOO NPHT CNT3 PU 629136 O0 000 O0 'INR~ CNT3 629136 O0 000 O0 cN~rc CNT3 CPS 629136 CFTC CNT3 CPS &291~6 00 000 00 0 DT4P D$I3 U$/F 62~136 00 600 O0 0 DT2 DSI3 US/F 629136 O0 000 Oo 0 PP D$I3 629136 00 000 00 0 C~.LI FLT3 IN 62~36 00 000 00 0 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 7 1 I 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 I 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 mmmmmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmm ** DAI'A ** DFPT. 9579.000 CIDP.DTE3 lb2.225 I~PH.OTF3 6.8.12 SFLU.DTE3 6.430 TFN$.DTF3 4445.000 ~TE~.DTE3 131.143 DPHT,LDT3 4,7.086 ~HOB.LDT3 1.873 CALI.LDT3 8.895 GR.LDT3 ~ 19.952 M~ES.LDT3 1.156 HTE~q.LDT3 263.519 CN''~IC'. CNT3. 274,8.1~4 CFTC. CNT3 81~.326 P~.D$i3 0.323 CA[,I.~[,,~3 12.608 I)EPT. 9400.000 CIDP.DTE3 138.052 I ~,~ P ~, D T E 3 7.280 S F I,., O. D T E 3 6 544 TENS ~ DTE3 6165, 000 ~TEM, DTE3 1.31~ 5~9"~' D~H~.LDT3 7.409 RHO~'bDT3 2.528 CALI. LDT3 I 3. 585 GR. LD'T3 ~9. 958 ~ES.LDT3 ~.1,79 HTEN.LDT3 563 069 CNTC.CNT3 2467.731 CFTC.CNT3 883~008 PP.D613 0.292 CALI.MLT3 13 W,, ' c)200.000 C'IDP DTE3 20,,'1.144 D..,,,, P7. . , I ~ P ~, D T E 3 5,04. 8 $ F L U. D T E 3 4,910 T~NS.DTE3 6385.00g, MTEM.DTE3 ~30.500 O P H I, t,, D T 3 5.204 ~ H O B. L D 'I' 3 2.5 ~ 4 CAL, I. LDT3 13.74,1 OR LDT3 92.356 MRES.LDT3 1.215 FJTEN: [.,DT3 606.849 CNTC.CNT3 2398.775 CFTC CNT3 810.993 PP.DSI3 0.312 CALI[ ~I.,T3 13,592 DEPT. 9000.000 CIDP.DTE3 160.609 I~PV~.DTE3 6.304 SFI, U.DTE3 6.047 TFN$.DTE3 63~5.000 ~TEtA. DTE3 129.:245 D P H I' . [,,,, D T 3 5 . 070 ~ H O ~ . 1,, P T 3 2 . 566 CALI ,LDT3 14,523 GR,LDT3 .89,205 MRES,LDT3 !.237 ~TEN.LDT3 559.569 C~;TC.CNT3 2595.759 CFTC.CNT3 923.031 PP.DSI3 0.27t] CAI, I.,MLT3 14.511 !DPH.DTE3 6.569 ClMP.DTE3 SP.DTE3 0.000 G~.DTE3 HRES.DTE3 1.336 HTEN.DTE3 DRMO.bDT3 -0.034 PEF.LDT3 TEN$.LDT3 4780.000 ~TEM.LDT3 NPHI.CNT3 37.696 TNRA.CNT3 DT4P.DSI3 81.640 DT2.D$I3 IDPfi. DTf;3 7.:244 CIMP.DTE3 SP.DTE3 -0.875 GR.DIE3 ~RE$.DTE3 !.331 HTEN DTE3 DR, HO.LDT3 0 010 PEF:LDT3 TENS.LDT3 54601000 MTE~.LDT3 NPNI.CNT3 27 486 TNRA.CNT3 DT4P.DSI3 80 785 DT~.DSI3 . . IDPH DTE3 4.972 SP.DTE3 -5 750 GR.DTE3 MRES.DTE3 ].~337 tiTEN.DTE3 DREO.LDT3 0.029 PEF.LDT3 TENS.LDT3 5390.000 STEM.bDT3 NPHI.CN'T3 30.574 TNRA,.CN. T3 DT4P.DSI3 86.023 DT~.D613 IDPH, DTE3 6 ,2~6 CIMP.DTE3 $~:i,.DTE3 -.13:]~5 GR.DTE3 ~ R E $. D T ~ 3 ,1.' 3 3 9 H T ~; N D T E 3 DRH0 .SD 3 0.013 PEF,LDT3 TENS.bDT3 5405.000 MTEM.LDT3 NPHI.CNT3 30.469 TNR.A:. CaT3 DT4P.DSI3 84.327 DT2.DSI3 146.800 106.841 -128.092 3.159 139.756 3.619 1.59.584 137.370 76.567 1,093.328 3.268 2 92 1~8, 45 198.116 86.830 1141.501 3'314 136 765 2:998 164.695 · 36 1..21.0.588 3.578 133'.973 2o991 152.184 IS Tame Verl. ficatlon LJstino ChlU~T~beroer Al. asks Comg>utin9 Center DFpT. $800.00(, CIDP.DT~]3 I~PH. DTE3 7. ! 25 SFI.U. DTE3 TFi~S.DT~3 6080.2,06 ~.~TEa. OTE~ DPHT.LDT.~ 9.692 ~HOb. LDT3 C~LI .LDT3 13.045 GR. bDT3 ~,~RES. LDT3 1.253 ~TEN.LDT3 C~'TC.CNT3 2493.358 CFTC.CNT3 PP.DSI3 0.282 CALl. MI,TI DFPT. .~600.000 CIDP.DTE3 IMPN.DTE3 5.205 SFLU.DTE3 TFNS. D'I'F3 5890.000 ~TE~.DTE3 D P }-i ~' .LDT3 ~4.044 RHDS.LDT] CaLl. LDT3 12. 393 GR. LDT3 MRES.LDT3 1.27,i HTE,q. LDT3 C~TC.CNT3 3058. 173 CFTC.CNT3 PP.DSI3 0.3~5 CALI.MLT3 DF, pT, 8400.000 C1DP.DTE3 I~P~.D'IE3 6.461 SFLb. DTE3 TENS. D',rE3 5735.000 ~,TE~.DTE3 DPHT.LDT3 17.544 ~flO8. LD'I-3 CaLl. L[)T3 2. 569 GR. LDT3 MRES.LOT3 1.29~ ~'fEi~. LDT3 CNTC.CNT3 2990.051 CFTC.CNT3 P~,DSI3 0.285 CA[.,I. ~LT3 D~:PT. 8200.000 CIDP.DTE3 I~PN.DTF, 3 5.177 SFLU.DTE3 TEN$.DT~3 5535.000 .~TF,..iq. DTE 3 DPHI..LDT3 18.560 Rt'iOB. LDT3 CALl. bDT3 2. 569 GR. LDT3 },~RES.LDT3 1.38,4 HTEN.LDT3 C~',t'C . C a T 3 ~740.229 CFTC.CMT3 PR.DS!3 0.338 CAI, I. ~LT3 DgP, 8000 00O CiDP.DTE3 I~pFI.' DTE3 6,196 SFi, U. DTE3 TF, NS.DTE3 5435.000 ~TEM.DT~3 DP~il. LDT3 11. 946 RHOB. LDT3 C~,LI. LDT3 2. 569 GR. LDT3 MRES.LOT3 1.377 C~TC.CNT3 21.48.061 CFTC.CNT3 P~.DSI3 0.3~ 1 CALI.MLT3 DFJPT. 7800.00C, CIDP.DT5]3 I ,~ P~i ' D'I~I~,.', 3 4.662 SFLU.DTE3 TENS.DTE3 54~5.0,00 DPHT.LDT3 13.8~9 CALl. LDT3 2. 569 GR, bDT3 6~ES.LDT3 1.397 ~TEN. I,,DT3 CNTC.CaT3 246.2.031 CFTC.CNT3 PR'DSI3 0.293 CALI. ~ILT3 27-~AR-1995 11:30 '41 797 IDPH.DTE3 7.052 6.343 SP.DT~3 -22.938 128.098 ~R~S,DT£3 1.363 ~.490 DRHO.LDT3 0.020 86.188 TENS.bDT3 5360.000 5~1 792 NPMI.CNT3 29.666 853~572 DT4P.DSI3 84.960 13.390 180.568 !DPH.DTE3 5.537 5.922 SP.OTE3 -50.188 ~27.509 ~ES.DTE3 1.364 2.253 DRHO.LDT3 0.005 4~.567 TEN$.LDT3 5040.000 561.758 NPHI.CNT3 28.061 1009.750 DT4P.DSI3 85.85~ 12.874 105.5~9 !DPH.DTE3 6.039 5.873 SP.DTE3 -36.563 126,006 ~RES.DTE3 1,.382 2.36~ DRFIO.bDT3 0.000 ~0.9~7 TENS.LDT3 51,40.000 675.474 NPHI,CNT3 24.607 IJ33 006 DT4P,DSI3 84.539 197 4~7 IDPH.DTE] 5 064 4~426 SP.DTE3 -36:500 125. 41 1 420 2'344 DRHOoLDT3 01015 72.386 TENS.SDT3 4855.000 519.901 NPHI.CNT3 29.321 922.81,4 DT4PoDSI3 90.072 13.1,16 t67.739 IDPH.DTE3 5.962 5.72 ! SP. DTE3 -58. 500 124.044 ~.,~R,E8. DTE3 1.,411 2.453 DRHO,LDT3 0.077 84.206 TENS.LDT3 4695.000 534.641 ~PHI.CNT3 36.771 652,111 DT4P, DSI3 89,434 12.4.95 205.290 I DP},,i. £, ..FE3 4 871 4.054 SP.OTE3 -71:188 122.850 ~RES.DTE3 l, 432 2,4.22 DRHO., , Lit3)' 0~016 74.070 TENS'bDT3 4735.000~ 544.199 NPHI'CHT3 29.685 837'589 DT4P.DSI3 89.989 12.874 CIMP.DTE3 GR.DTE3 HTEN.DTE3 Pf, F.LDT3 ~TE~.I, DT3 TNRA.CNT3 DT2,D$I3 CIMP.DTE3 G~.DTE3 HTEN,DTE3 PEF.LDT3 MTEM.LDT3 T~RA.CNT3 DT2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 MTE~.LDT3 TNRA,CNT3 DT2.DSI3 CIMP DTE3 GR:DTE3 HTEN.DTE3 PEF.LDT3 NTE~.[.DT3 TNRA.CNT3 DT2.D$I3 CI~P.DTE3 GR DTE3 PEF.LDT3 MTE~.,LDT3 TMRA.CNT3 DT2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 MTEM,LDT3 TMRA.CNT3 DT~.D$I3 PAGE: 43 140.358 77,141 1091.560 3,363 ~32,168 2.938 154.121 192.140 37.591 1168.897 2.418 130.526 2.831 165.297 154.781 55.660 1148.516 2 524 1.28:454 2.600 I54.262 193.180 79.747 1127.934 2.708 1~..027 .91.5 182.233 161.396 73.906 1090.471 ,1 71 12 ,575 17~ '369 ,$50 214.507 65.880 1111..580 2.872 12~.172 .939 166.242 IS Tare verlitcation Listlna chlumberqer A].ssKa Ccmputtnq Center DFP'I'~. 7600.~00 C!OP.DTE3 I~'~P~.8'.[73 5.437 SFI,U.DTE3 TFN~.DiE3 53~5.000 DPHT.[,DT3 8.742 Cn LI. LDT3 2. 569 GR. bDT3 ~RES.LDT3 1.434 ~7'5~N. LDT3 CNIC.C,'4T3 2633. 157 CFTC.C~T3 P~'.DSI3 0.297 CAI,I. r{'LT3 DEPT. 7400.000 CIDP.D~E3 IuP~.DTF3 3.629 SFt, U.DTE3 TENS.DIE3 5215.00o DPHI.LDTB ~8.533 ~HOS.LD'I3 C~LT .LOT3 2. 569 GR.LDT3 M~ES.t, OT3 1.437 NTEN.L, DT3 C~TC.CNT3 ~702.1.96 CFTC.CNT3 DFPT. 7200.000 CIDP.DTE3 I"P~.DTE3 2.352 SFbU.DTE3 TFNS.DTE3 4965.000 ~TEi~i. 0TE3 DPHI.LDT3 24.107 CALl . LDT3 2. 569 GR. bDT3 ~PES.LDT3 1.466 C~:TC'.. C~T3 ~443.265 CFTC.CNT3 P~.DSt3 0.3BO CAI.,I. ~LT 3 DEPT. 7000.000 CIDP.DTE3 IMP~; DTE',3 5.1,45 SFLU DTE3 'F'. D' . ~ .... NS,~,~F3 4885 000 ~'4TEF{~DTE3 [,)PH ~. [,DT3 12.449 RHOB,LDT3 C~.LI. bDT3 2. 569 GR. LDT3 I,t ~ E S. [,, D T 3 1.479 ~ T E'N. b O T 3 C ~"t ~ c. C ~ T 3 2 2 7 7.5 6 3 C F T C, C ~ T 3 ~.0813 o.32!, CALI. aI,,,T3 D E P T. 6800.000 C I D P, D'I' g 3 I~PH.DTE3 ,4.208 SFLU.DTE3 TENS.DTE3 4695.000 DPHI.L[)T3 11.726 RHOB.LDT3 C~Lt. LDT3 2. 569 CR. bDT 3 ~,l~ ES I,,,OT 3 1.5~1 HTEI'4. LOT3 CNTCiC~T3 ~220.265 CFTC.CaT3 DEPT. 6600.000 CIDP.DTE3 I}~PN'DTE3 6.797 SFLU.DTE3 '~N E . ~ rea. 1r~ $.o'r 3 451.0 00{'.~ ~ ' ...... DTE3 Drill. t,~T3 14.592 ~iOb.LOT3 ClL!.I,.,DT3 2.569 GR.LDT3 a ~ E S ,[., D T 3 I. 533 ~ T E N. I,., O T 3 CNTC~C~T3 ~3~ 3.36.~ CFTC CNT3 P9~'D,LI3 0.346 CALI~MI,,T3 2'?-t~;AR-~995 11:30 150. 137 !DPH. DT£3 6.661 5.510 SF'.DTE3 -62.625 !21.610 ERF. S. DTE3 1 .458 2.506 DRFIO.LDT3 0.045 70.665 TE~S.LDT3 4765.000 638.128 t,~PH I. CNT3 30.011 968.260 DT4P.DSI3 88.091 14.253 275.784 IDPH.DTE3 3.626 5.844 SP.DTE3 -91 .063 120.419 ~RES.DT£3 1.458 2.344: DRHO.LDT3 0.013 60.865 TENS.EDT3 4355.000 540.425 NPIqI.CNT3 26.211, 958.1U6 DT4P.DSI3 89.040 13.011 473.335 IDPH.DTE3 3.024 SP.DTE3 119.230 MRE$.DTE3 2.251 DRHO.LDT3 56.808 TENS.L, DT3 543.855 NPHI.CNT3 727,257 DT4P,D$I] t95.151 IDPH.DTE3 4.914 SP.DT£3 11.7.743 ~RES.DTE3 2.445 DREO.bDT3 75.421 TENS.LDT3 575.306 NPHI.CNT3 718.690 DT4P.DSI3 12.80g -111~750 1.479 0 OO5 gs:ooo 35.998 94.340 5.124 -76.750 i 495 0:037 41.85.000 32.075 93.604 253.472 IDPH,DTE3 3 945 4'581 '$P.DT£3 -73~500 116.387 ,,RE$.DTE3 1.526 2.456 DRMO.LDT3 0 025 92 ~0 TENS.SDT3 3975:000 533]~=7 ~,tPHI.CNT3 34 335 670 610 D't4P.DSI3 971605 15~487 142.446 IDPH.DTE3 7.020 5.791 SP,D~E3 -80.625 114.023 ~RES.D E3 1.546 2.409 DRHO,hDT3 0.010 85.531 TENS.LDT3 3855.000 545.453 NP~i.CNT3 34.225 737.591 DT4P.DSI3 95.274 14.995 CI~P.DTE3 GR.DTE3 HTEN.DTE3 PEF.t, DT3 b%TE~.LDT3 TNRA.CNT3 DT2.DSI3 CT~P.DTE3 GR.D?E3 HTEN.DTE3 PEF.LDT3 MTE~.LDT3 TNRA.CNT3 DT2.D$I3 CI~P.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 ~iTE~.I.,DT3 TNRA.CNT3 DT2.D$13 CI~P.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 MTEM.!,DT3 TNRA.CNT3 DT2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 ~TE~.LDT3 TNRA.CNT3 DT2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.I,,DT3 MTE~.LDT3 TNRA.CNT3 DT2.DSI3 PAGE: 44 155.348 74.387 1184.121 3.342 122.166 2.961 163.909 275.547 53.152 1137.550 2.844 120.755 2.707 158.917 425.110 5'7.626 1147.612 2.470 118.714 3.327 187.465 194 363 69!81,8 1,133 696 3.014 117.318 3.098 182.257 .237.665 88.352 i087.139 3.464 1'16.007 3.,236 206.736 147.122 82.444 1.030.175 3.260 113.936 3.230 196.446 I$ Ta~e Verification I, lstino chlU~berger AlasKs C. omPutin~ Center DFPT. 64~00.000 CIDP.DTE3 i~P".DTF. 3 6.962 SFI, U.DTE] TENS. DTE3 4.500,0aW ~Tgtq. DTE3 DPH]. LDT3 17.673 RHOB. LOT3 CAL!. LOT3 2. 569 GR. LDT 3 b~ES,!~OT3 1,553 HTEN,LDT3 CMTC.C~qT3 2493.740 C~TC. C~'oT 3 P~.DS!3 0.302 ChLI.MLT3 DFPT. 6200.000 CiDP.i)TE3 IgP~4.DTE3 6.099 SFLU.DTE3 T~NS.DT~.3 ~375.000 DP.~ l'. LO'r3 13.9~1 C~ b~. Lb'r3 2. 569 GR. LDT3 ~,'i¢ES.LDT3 I .5~3 HTE~.LDT3 C~'TC. C;~T3 2029.022 CFTC.CNT3 PP.DSI3 0.36i CALI.IqLT3 DF. pT. 6000.000 CIDP.DTE3 I~P~,.DTE3 4.532 SFLd.DTE3 F'N S. DTF,.,3 4395.000 M T F,).~ DTE3 IT.) P H 1. I, ,DT3 15.822 RHO8* . b f) 'it' 3 C,AI,,I. LOT3 2,569 GR.LOT3 MRE~.LDT3 1.59t1 MT ,F.,N. [~DT 3 CN'i'C. CNT3 2103.708 CFTC.CNT3 PP,, D,,LI 3 0.324 C~bl.aLT3 DEPT. 5800.000 CIDP.DTE3 l~P[~. DTF, 3 6.568 SF[,U. I)T[~3 "' . 3 4245 DPBI~I,9 3,,, 14.874 R~iO6.I,,D.,3 CALl. LOT3 2. 569 GR. BDT3 M ~ E S. L O T 3 I 61, 5 ~ T E ~'~. b O T 3 CM~'C, CNT3 P091~8.]8 CFTC,CNT3 P~,DSI3 0,329 CALI,~LT3 DEPT, 5600.000 CIDP,DTE3 IM.P;,!. DTE3 6.252 SF[.,U. DTE3 T F, ~ $. D '.r E 3 4 ,f~ ~ 5.000 ~ T E a. D'r E 3 DPHI. LDT3 1,i. 589 RHOB. bDT3 C~LI. LgT3 2. 569 GR. LOT'3 I.~RES. I, DT3 t ,6'~9 MTEN.bOT3 CNTC.CNT3 19~3.770 CFTC.C~T3 PP.DSI3 0.233 CAI,,,I, ~4bT 3 D F ? T 54 o 0.000 C i D P. D,:F E 3 I ~P~'!i: DTE3 ,3. 168 SFI,,U. DTE3 TENS.DTE] 3920.0,:)0 D P H l. I, ~) T 3 ~ 1.5 't 3 R ,H 0 B. L 0 T 3 CALl'. LDT3 2. 569 (;R. LOT3 MRES,LDT3 !,650 CNTC. C~'~T3 1772.778 CFTC,CNT3 P ~'., D $13 0.3 ~,~ 9 C ,A L I. ~4 L T 3 27-~AR-1995 11:30 151.100 IDPH.DTE3 6.618 7.001 SP.DTE3 -106.063 113.430 MRFS.DTE] 1.552 2.358 DRBt).LDT~ 0.033 ~3.1.39 TENS.LDT3 3720.000 487.~7 NPHI.C~T3 32.401 ~15.622 DT4P.DSI3 95.464 13.221 169.078 !DPH.OTE3 6.70B 5.409 SP.DTEB -90.063 112.210 ~'IRES.DTE3 1.579 2.420 DRHO.LDT3 0.037 85.217 TENS.LDT3 3700.000 487.436 NPHI.CNT3 q~.030 593.273 DT4P.DSI~ 100.414 14.22~ 181.795 IDPH.DTE3 5.501 5.822 SP.DTE3 -95 125 110 780 MRES.DTE3 1~589 2~389 DR~O.bDT3 0.025 78.276 TENS.bDT3 3670.000 55~.49~ NPkI,CNT3 33 562 648.226 DT4P.OSI3 99~01,7 14.608 154.'747 IDPt'I. DTE3 6.g~] 6.384 SP.DTE3 -113. 109.611 ~!RES,DTE3 1 600 2,4(15 DRHO,:bDT3 0:011 77.770 TENS.bDT3 3630.000 5q5.229 NPHI.CNT3 33.687 665.778 [],4P.D.$I3)' 97.847 13.826 155.491 IDPH,DTE3 6,431 6.568 SP,DTE3 -105.688 1,08.895 MRES,DTE3 !,61.7 9*409 DR}"{O'LDT3 0.039 75,2.40 TENS.hOT3 3400.000 550.701 [,IPMI.CNT3 37 755 5B4,851 DT4P.DSI3 96~106 15,.987 315,499 IDPtt. DTE3 3,599 ~P,DTE3 :1,07,6~4 2,~95 DRHO,BOT3 78,019 ~"' , .... ENS bDT3 5~3,6i4 NPBI,CMT3 521,756 DT4P,DSI3 13.906 3 1.621 '0.006 3300.000 34.687 109.984 CIMP.DTE3 GR.DTE3 BTEN.DTE3 PEF.LDT3 ~TE~.LDT3 TMR~.CNT3 DI2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF,LDT3 gTEg.LD]'3 TNR,A.CNT3 DT2.DSI3 ClMP.DTE3 GR.DTE3 HT£M.DTE3 PEF.LOT3 MTEg.I, DT3 TNRA.CNT3 DT2.DSI3 CIMP.DTE3 G~,DTE3 HTEN.DTE3 PEF,bDT3 ~TEg.LDT3 TNRA.CNT3 C!MP.DTE3 GR.,DTE3 MTEN.DTE3 PEF*LDT3 MTE~.LDT3 TNRA.C~T3 DT2.D$I3 CI~P I)TE3 HTEN.DTE3 PEF.bDT3 aTE~..'bDT3 T~RA,CNT3 DT2,D$I3 PAGE: 150.113 58.481 1061.070 3.185 111.957 3.120 179,229 163.953 '85.021 1081.533 3.442 110.407 3.656 216.316 220.661 74'251 1103.469 3.238 108.895 3.194 194.162 152.247 72.435 1133,740 3.027 107.481, 3.200 193.618 159,'948 68.138 1130.052 2,981 105,483 3,423 162,808 317~'688 ,426 1t40..135 5 051 255 257.630 45 IS Tar, e 'Verif. i. cation 'rr'isting ChlUmb. erqer ,~,l, aska ¢omput. inq Center 27-MAR-1995 111]0 DFPT. 5200.00() CIDP.[)TE3 350.638 !DPH.DI"E3 ?,.,, 852 !~'PF'. DTE3 2.854 SFLi. I. O'rE 3 3.834 SP.DTE3 -119.063 TFNS.DT~i3 3735.090 ~TE~,]. DTE3 !06.098 MRES.I)TE3 1.644 [)Phi ~,D'F 3 20.350 R t!O~%. I,D'['3 2.314 DRH(]. LD~r3 0.006 CANT :I,~)T~ 2.5A9 GR.LDY] 72.6~0 TENS.j~DT3 3080.000 ?,~ES. LDT3 1.697 NTEN.LgT] 522.858 NPHI.CNT3 40.997 C~TTC. C~iT 3 1720.552 CFTC.CNT3 473.871 DT4P.DSI3 10].984 PR.DST3 O. 3'~0 C.AI.,I. M5%] 12.954 D~p'~. 5000.OOu ClI'}P. D'~E] 872.108 IDPH.DTE] l,~.47 I~P~!.DT~] 1.225 SFL,J. DTE3 1.795 SP. D'~E3 -165.438 TENS.gTE3 3570.000 MTE}q.DTE] 102.490 MRES.D~E3 1..705 DPHT.I,DT3 35.227 RH~B.L;)T3 2.0°9 DRHO.LDT3 -0.011 CALl .bDT3 ~.569 GR.LOT] 33.691 TENS.LDT3 2985.000 ~ES. LDT3 1.7~7 MTE$~. L;)T] 525.428 NPHI.CNT3 47.290 C~TC.CNT3 1880.2T~ CFTC.C,~T] 478.894 DT4P.DSI3 114.514 PD.D~{T3 0.3'{i CALI.MLT] 12.29] DP:PT. 4800.0.')0 CIDP DTE] 385.147 TDPH.DTE3 2.596 I~pH ,PT~3 2 515 SFgU~"'r" . - . . . . D.E3 2 938 SP DTE3 -123 688 T~NS DTR3 3~00. OOt,) MTE~t. DTE3 !02.2~0 MRES.DTE] 1.692 DPH !: [,.,{)T3 19.11~5 RHO~. I,O'r3 2.333 DRHO.LDT3 0.007 CALl. Li)T3 2.5~9 GR.LOT] 74.208 TENS.LOT3 2930.000 ~RES. [,DT3 1.748 HTEN. I~OT3 559.074 NPHI.CNT3 42.440 CNTC.CNT3 ~830.586 CFTC.CNT] 517.3~4 DT'4P. DSI3 ~06.610 PP,DSI3 0.3)8 CALI.M'GY3 12,6~0 DFpT, 4600.(}00 CIDP.DTE3 q30.929 II')PM. DTE3 1.074 I~'~,PN. [)TE3 1. 166 SFLU.DTE3 1.965 SP. DTE3 -161..063 TENS.DTE3 3460,000 ~T~] ~.1, [>'CE 3 !00.612 },~RES, DTE3 1.723 DPH". Li)T3 2"7.433 RHO~.LDT3 2,197 DRHO..hDT3 -0,005 CALI.LDT3 2.569 GR.I, Li3 47.964 ENS.L, DT,3 810 000 N R g $. L i~ T 3 I · 7 ~ ~i C~iTC.CNT3 1990.32X CFTC,CNT3 604.012 DT4P,OSI3 119' 300 PR.9aI3 0.253 CAI, I,,M, LT3 DEPT. 4400. 000 CIDP.DTE3 -! 77. 104 IDPid.DTE3 I ~ P H. {')T ~.', 3 22.540 S F' b U. D T g 3 3.242 S P ,. D T g 3 T,...~NS. ....E3 3405 0~'~0 a',CS, i. DTE3 99 270 MRES.DTE3 DPFtI. LI>T3 55.328 ~HiDB.LDT3 1.737 DRHO,LOT3 CALT,LDT3 2.569 GR,LDT3 41.854 TENS.LOT3 M~ES. I,,DT3 I,'7~]2 HT~N,LOT3 579.3b~ NPHI.C;~IT] CNT~,CNT3 1289,0'{.3 CFTC. CNT,~I 304.4~4 DT4P,DSI3 P~.D~I3 0.460 CAI,,~I. ~,Ii~T ] 13.108 1950 000 1.749 -0 998 ~760 000 51 1, 33 54,.799 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 MTEM.LDT3 TNRA.CNT3 D]'~.DSI3 CINP.DTE3 GR.DTE3 HTEN.D%E3 PEF.LDT3 MTE~.LDT3 TNRA.CNT3 DT2.D$I3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF.LDT3 ~TE~.LDT3 TNRA.C~T3 DT~.DSI3 CIMP.DTE3 GR.DTE3 HTEN.DTE3 PEF,LDT3 MTEM.LDT3 TNRA.CNT3 DT2.DSI3 CIMP,DT£3 GR. DTE 3 HTEN, DTE3 PEF. LDT3 ~ITEM,LDT3 TN'RA. CNT3 P'r~, ,,: : DS] 3 DEP? 436m.500 CIDP.DTE3 177.104 TDPH DTE3 1950 000 C'IMP.DTE3 : .......... 22 540 SFL'U. DTE3 3,256 , - , .,,F' DTE3 ~,60. 125 GR.DTE3 TENS,D.E3 3355 000 MTgM L'I,C,] 99.~36 ~RES.DTE3 1.749 HTEN.DTE3 D P {~i 1'. 1, D T 3 55.328 R H O ~.:.~. 1,., ,') 13 I 737 D R H 0. L D T 3 - 0 998 P g F. b D T 3 CALT,L[.)T3 2.569 aR.bDT:] 41,854 ~.'ENS L'OT3 2760:000 ~TE~,LDT3 NRES. LDT3 1.7a2 HTEN. I,,DT3 579. 362 NPHI.CNT3 51' 133 TNRA.CNT3 C~,~TC C,'~'r., 1289 013 CFTC,CNT3 3o4.4t, 4 DT4P.DSI3 54 577 DT2.DSI'3 PP.DSI3 0.47~ CaLI.NLT3 13.132 P A G E: 46 350.359 63.785 1149.663 2.803 102.490 3.600 244.593 816.147 31.564 1.129.633 2.697 98.905 3.943 2]8.975 397.588 69.119 1139.501 2 944 971941 57 434 11,41. 68 96.411 44.365 22.693 1157.333 20'40~ 95.566 4.153 215.766 44.365 ~6.537 1151,431 '20.401 95'566 4.153 265,874 iS Tar, e Yeri~i. cati. on L, istlnq chlumherger Alaska Computinq Center PAGE: 47 **** FI i.,E HF.: al)ER SERVICE : VErSIOn1 : ~O~CO1 DATE : ~5/t)~127 FILF TYP~3 L~ST FILE : ~%P EXPLORATION AP:[ #50-629-22513 WILDCAT t'~tORTH SI.,i.)[~E, ALASKA FILE EDIT.O08 SAI4PLF, [{gTE; 0.1667 FT. RAW FIELD ,MAIN LOG OF RU,a ~3 (INTERMEDIATE RUN) . ~'iLT 3 i~I '.r.. C R O I., O C, TA[½[,.,i~',,: 9?YP.F., : CQNS C N b P EX P.[~ 0 R A T I ' ;'] . t..). ,, Com:pany Name ,IF'N ~ ILDCA',I~ Field Name ~,~ B,ADAMI ~5 ~e,ll Name AP:,[N 50-629-22533 AP1 Serial Number FI,., 3334'SNL & 4770'~4EL Field Location S~:(]~ 3 Section TOwN 9N Township RANC 20E Range I$ Ta~e Yerj, flcat].on ),ist;ino chlumherqer Alaska Co[,~putinq Center 27-~{AR-1995 11:30 PAG£: 48 T T., ~.; ! V A L b D g F I mmmmm*mmmm ~ mm mmmMm.,mmm mm mmmmmmmmmmmm m m~ m mmlmmmmmmm~mmmmlmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmlmmm COi. t~ r~IIRT. SLOPE STAT ALASNA NAT? USA ~II~V PUTNA~ SON 629136 PPA? iCL PAD EPh FT [,,MF KB APb FT 34. EKB ~T 38. EDF FT 33. E~L FT 4 1 TDD FT 1{549. TDL FT 11544. BLI PT TLI FT 36. DFT (]ORE ~LiD DWD G/C3 12.5 DFPH 7. DwV S 76. DFL F3 4o~ R~,tS ~H~M 0.743 ~tST DEGF 66. aFST D~;GF R~C8 OH~i~ 2 ~3 ~CS,r DEGF County State or Province Nation ~itness Na~e · Service Order NUmber Permanent datum Elevation oi Permanent Datum Log Measured From ADove Permanent Datum Elevation of Kelly Bushing Elevation of Derric~ Floor Elevation of Ground Level Total Depth - Driller Total DePth - Logger ~ottom bo~ Interval TOD Log I terval Drilling Fluid Type Drilling Fluid Density Drillin~ FlUid Ph Drlllin~ Fluid Viscosity rillln~ FlU. Id Loss esist~,Vit¥ of Mud Sample ~ud Sample Temperature Resistivity of ~ud Filtrate S ~iud Filtrate Sample Temperatu Resistivity of Mud CaKe sampl , ~6. ~ud, Ca~e SamPle Temperature ~ DEC, F 58. 8otto., Hole Tempe, re ute TABLE TYPE : CL)RV DEFI DFPT Depth MINV MiCro-Inverse Res~.stlv!t¥ M~!OR ~lcro-Norn~al Resistivity ** DATA FOR~,,IAT $[>ECI[~?'IiC,ATIOI'J R ** SET TYPE - 64gB ** TYPE REPR CODE YALUE 2 66 0 3 73 ~2 4 66 IS q~aDe Verification Listln~ ChlUmherqer ~],aSKO ComDutinq Center ;27-t~.~AR-19q5 11,:~0 PAGE: 49 ** S DEPT FT MINV MLT3 OH .. 7 65 @ 68 9 65 1~ 66 12 6~ 1~ 66 14 65 15 6~ 16 66 0 66 0.166 85 0 I Ew TYPE - CNAN ** ~RD~R # LOG TYPE CLASS MOD MUNB SAMP EbEM COD~ (HEX) 629136 00 000 00 0 8 1 1 4 68 0000000000 N~ 62~136 00 000 00 0 8 ! 1 4 68 0000000000 MN 629136 00 000 00 0 8 1 I 4 68 0000000000 ** DEPT, [)~PT. DEPT, DMPT, DEPT. DEPT., DEPT. DEPT. DEPT. DEPT, DEPT, q579.334 ~,~IiN V. Mt,'r 3 -999,250 MNOR. MI:.,T3 -999.250 9400 000 MI.NV.,,.LZ3 3 160 MMOR ,~[,,,r3 3.841 9200.000 ~,~IN V. MI,~T3 2.728 MNOR. MI.,T] 2.725 9000.000 MINV.MLT3 2.359 gN[)R. MI,,,T3 2.649 8800.000 ~ I NV. i'~I..T3 2.676 ~NOR. M[.,T3 2.947 6600.000 ~INV.MLT3 3.961 MNOR.~bT3 5.018 8400.000 MINV.MhT3 3.546 MNOR.aLT3 4.560 8200.000 ~ZNV. ~.~LT] 2.428 MNOR.a[,T3 ~000.000 ~INV. ML, T3 3.708 ~INOR. aLT3 4.223 7800.000 8INV.NLT3 3.373 ~:NOR, MLT3 3.520 7600.000 ~.[N v. l~it,:r 3 3.356 ~NOR. ~b'r3 3.742 I$ Tame Verification Llstin¢.] chlumberc!er Alaska Computin~. Cemter [>EpT. 7.400. 000 ~I DFPT. 7200.00U ~IS!V. bL'I'3 DF. Pm. 7000.00O DEPT. 6800. GO0 ~iNV. DEPT. 6600.00O ~INV. ?4LT3 DEPT. 6,400. 000 DEPT. 6200. 000 ~4INV. ~,l, T3 DFPT. 6000.000 MIMV.~iLT3 DFPT. 5800.000 ~INV.MLT] DFP~. 5000.000 D~P~~. 5400.00O DFpT. 5200.000 ~IN'V. MLT3 D~]PT. 5000.000 ~I~V.MLT3 DEPT. 4800.000 MINV.~LT~ DEP?. 4600.000 MINV.~LTB DEPT, 4400.000 ~.INV.MLT) D~PT. 4362.500 ~INV.MLT3 END OF DATA ** 27-~AR-I995 1~:30 4.174 MNO~.~L'!'3 3.892 ~OR.,~f..,T3 4.359 MNOR.KL?I 2.342 ~NOR.~I, T3 2.676 HNOR.MI, T3 4.295 ~NOR.~LT3 3.178 3.673 MNOR.MLT3 4.036 4.025 ~OR,ML'r3 3.207 ~NOR.MLT3 4.077 HNO~.aLT3 4.319 MNOR.MLT3 4.347 MNOR.MLT3 3.990 ~qNOR.MLT3 0.003 -999.250 NNOR.MLT3 5.133 4.774 4.376 2.358 3.077 5.454 3.008 4.323 5.302 4.927 3.436 4.552 4.270 4.300 3.773 -0.0,42 -999.250 PAGE~ 5O Tape Ver,!.f.lcation Listing chl. umherger AlasKa Co~putinq Center F!bF~ NAUE ~r~t/ICg : F.~IC DATF F~AX REC SIZ~ : 1024 FILF TYPE : LAST FILE : 27-MAR-J. gq5 11:30 PAGE: 51 BP EXPLORATION BA[)AIqI ~5 AP1 ~50-629-22533 :~ILDCAT NDRTN SI,OP~, ALASKA FI[LB F, DIT 009 S.~PI..,E RATE: 0,5 RA~ FIELD MAIN LOG DATA OF RUN #4 (TO RUN) ,AIT4 ,A~RA¥ INDUCTION TOOL ,DSI4 DIPOLE SONIC .T..MAGER TOOL, ,~.~NG4 ~'*iATURAL GA~A RAY &PECTROSCOPY TOOL (IPLT TOO[, STRING) ,~4LT4 FiICROLOG TOOL (CALIPER) TABLE TYPE : CONS CN BP EXPLDRAT![IN FN v~ I LDCA 'it ~! 6ADA~II #5 AP I~ 50-629-~2533 FL, 3334'SNL & 4770'~E5 8~CT 3 TO~ ~,~ 9~ C O I.] ~: ~ORTH SLOPE S~AT A[,ASKA Na.'.rl 6SA W ITN PIITNA~ SON 629~, 36 Pr)AT ICE FAD gPl) FI 4. APD FT 34, EKB WT 3~, EOF ET 3 3 Company Name Field Ma~e Well Name API Serial Number Field Location Section Township Range County State or Province Nation ~itness Name Service Order NumDer Permanen~ datum Elevatiom of Permanent Datum I, og Measured From ADore Permanent Datum EleVation of Kelly BushinQ Elevation of DerricK.Floor Elevation of Ground Level Total,, Depth -Drtller IS ~'ar~e Verl. fication l,istiD~ chlumberger Alaska Computing Center 27-MAR-1995 1.1:30 PAGE: 52 T U ~'~: ! V A I., U D E F ~ ....................................... ~.;~;: ............................. 1 D th''''''''' ........ ' ..... '''' 1. ~ DI~ Fl' Tot a. e~ - Lo~g_ e r Bottom beg Interval. Top t, og Interval Drilling FlUld Type Drillin~ Fluid Density Drlllin Fluid Ph Drilling Fluid Viscosity Drilling Fluid boss ResistiVitY of Mud Sample ~ud Sample Temcerature Reslstt ity of ~ud Filtrate S ~ud Filtrate SamPle Temperatu Resistivity of Mud CaKe Sampl Mud Cake Sample Temperature Bottom Hole Temperature TABLE TYPE :CUP, V DEFI DFPT Depth SP S~ont. a~eous Potential G~ G mma ~ay TE~$ Temslon ~tTE~ ~ud Temper~t, ure M~ES ~UD ReslstiVJty HTE~ ~ead Tension DT4P DELTA-T CO~PRESSI[)NAL MF MONOPOLE CONPEMSATED PT2 DELTA-T $~EAR UPPER DIPOLE MODE CONPENSATED P~ Polsson'$ Ratio C~LI Caliper HSGP HNGS Standard Gamma Ray HCG~ ~NG$ Commuted Gamma Ray HTHO HNG8 Thorium Concentration ~,{~}R~ HNG$ Uranium Concentration ~F~ HNG6 Formation Potassium Concentration ~BH~ ~GS 6orehole Potassium Concentration TENS Tension ** DATA F'O~AT 8PECIFICATI{.]~~ RECORD ** SET TYPE - 64:EB ** TYPE REPR CODE VAbUE 1 66 0 2 66 0 I$ Ta~e Ver.lflcatlon T,lstJ. nq chlumkerqer h!asKa Computinq Center 27-~A,R-1995 11:30 PAGE: 53 D S G 7' D D P C H .H T I~,I,~,~IIl~II~IIIi,m-im..iii~slm.iI~mIm~,Iim, 3 73 72 4 66 5 66 6 73 7 65 ~ 68 0.5 9 65 11 66 14 12 68 13 66 0 1.4 65 F'~I' 15 66 6B 16 66 1 0 66 1 ** SET TYPE - CHAN ** SF', SER ia APl AP1 FII,E UMB NU B SIZE REPR . OCESS ID ORDER ~ I.,OG ~,"YPE Ci,~SS ~OD NUMB SAMP gLEa CODE (HBX) mmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmm-mm~mmmmmmmmm#mmmmmmmmmmmmm-mmmmmmmmmmm-~m~mmmmmmm KPT FT 6291136 00 000 O0 O 9 1 1 4 68 0000000000 P hIT4 ~V 629136 O0 000 O0 0 9 1 1 4 68 0000000000 R lIT4 (;APl 629136 O0 00() O0 0 9 1 I 4 68 OOO0000000 F:NS gIT4 LB 62~136 O0 000 O0 0 9 ] I 4 68 O00OO00000 TE~ AIT4 DEGF 629136 O0 000 O0 0 9 1 1 4 65 0000000000 RE~ AIT4 OHMM 629136 O0 000 O0 O 9 i 1 4 68 0000000000 Wg~ AIT4 LB 629136 O0 000 O0 0 9 1 I 4 68 0000000000 T4P DSI4 US/F 629136 O0 O00 O0 0 9 1 1 4 68 0000000000 T2 D$I4 bStF 629136 O0 000 0¢) 0 9 1 I 4 68 0000000000 R DSI4 629136 O0 000 O0 0 9 I 1 4 68 0000000000 fib] MLT,4 IN 629136 00 000 OD 0 9 1 1 4 68 O0000000OO SGP NAG4: GAPI 629136 O0 000 O0 0 9 1 1 4 68 0000000000 CG~ HNG4 GAPI 629136 O0 000 O0 0 9 I 1 4 68 0000000000 TNO HNG4 PP~ 629136 O0 000 O0 0 9 I 1 4 68 0000000000 UR~ HNG4 PP~ 629136 O0 OOO O0 0 9 1 1 4 68 0000000000 F~ ~'NG4 PU 629136 O0 O00 O0 0 9 1 1 4 68 0000000000 BHK HNG4 PU 629136 O0 000 O0 0 9 1 1 4 68 0000000000 ~NS HNG4 LB 6291,36 O0 000 O0 0 9 1 1 4 68 0000000000 DATA DEPT 11524.000 SP.AIT4 -14.688 GR.AIT4 84 265 ~T,E~, ~ A IT4 154.774 ~RES.. Ail"4 0.364 HTEN.AIT4 1326~306 [',T2. DSI4. 1, 56. 256 T PR' DSI4 O. 306 CALI. ~,LI 4 8,426 H. CGP, HNG4 -999,250 ~{ .. He!, }~NG4 -999.250 HUR A ,.i.tNG4 -999.250 HBHK, HNG4 -999. 250 TENS. kiNG4 -999. 250 TENS.AIT4 DT4P.DSI4 BSGR.HNG~. HFK.HNG4 ~025,000 82.668 999.250 '999.250 IS .TaDe Verlf, lcat$o~, ChlUmberger AlasKa Ccn, putinc] Center DEPT. I 1. 40('~, (>OO 8~. A~'.I'4 MTE~':. AIT4 156,21~i ~kF~8. AIT4 PT?. PSI 4 141. ~09 PR. [,814 HCG~.HN(;4 -999.250 M'rt~(]. [~NC;4 ~P.H~, HNG4 -999.250 TENS;. ~<hg4 DFFT. 1 1000. 000 8P. AIT4 F,T ~;k'./~ I T4 147.308 ~,~RFS. AIT4 D'P2.DSI4 144. 390 PR. DSI4 HCG~'.~NG4 60.215 HTF~U. ~G4 DF'PT. 1080(,;. (300 SP. A I~"4 ~T[;;~]./% I T4 145.501 It~RF.S. AIT4 DT?. DSI 4 138,536 P~. DSI4 HCGR }lNG4 60.967 HTIIO. 6NG4 H~H~HNG4 0.2~7 TENS.HNG4 DFp,T. 10600.00(! ,S'P. AIT4 I~TE~,~ . A IT4 14,4.723 MRES.AIT4 DT?.DSI4 139.47C, PR.DS,I4 [tBHg ,HNG4 0.339 TENS.HNG4 DFPT. !o400. 000 ,.qP. AIT4 MTE,~ AIT4 141.827 DT~ :D8~4 133. 206 PR.[)SI4 HCG~t.HNG4 78.670 H~H~':, HNG4 0.443 TE~:~5. HNG4 27-~.A~-I, 9Q5 11 :30 -37.813 (;R.AIT4 79.356 0.384 }!TE~.AIT4 1223.856 0.287 CALI.~4I,T4 ~.309 -999.2b0 HIIRA,HNG4 -999.250 -54.625 g~.AIT4 30.~73 0.390 HTEH.ATT4 1037.852 0.~27 CgLi.~iLT4 7.643 3.651 MURA.mNG4 1.294 1450.000 -52.625 GR.AIT4 58.480 0.410 H~'EN.AIT4 1114.018 0.2~ CALI.MbT4 7.568 9.1~5 HURA.HNG4 3.048 2275.000 -53.938 GR.AIT4 65.632 0.414 ~TEN.AIT4 1021.548 0.245 CALi. IqLT4 9.326 9.~,20 HURA,HNG4 3.286 2455.000 -~7.063 GR.AIT4 68.031 0.417 HTEN.AIT4 3884.079 0.245 CALI.NLT4 9.510 10.632 ~I]RA,fiNG4 2,330 2235.000 938 GR.AIT4 67 688 't*~'430 HTEN AIT4 1169:014 0.219 CALI.tqLT4 I1 ~76 112.025 ,~tUR, A.HNG4 2S748 2045.000 -999.250 GR,A!T4 -999.250 HTEN.AIT4 -999.250 CAI,,i.MLT4 9.585 HURA.HNG4 1135.000 D ~: P ~' 10000.000 $ P. A I T ~, -999.250 (.; R. A I 'ir 4 ~*~T~':F,'AIT4 -999 25(,! ~!R~$.AI',['4 -999 250 }tTEN AIT4 DT?,.DSI'4 -999.250 PR.DSI4 -999.2fi0 CALi,~tbT4 HCG~.HNG4 68.352 ~'{Tt)O. HNG4 10.308 [,,IURA. HNG4 k~Bit~ . H~'~G,4 1.013 TENS.HNG4 1295.000 -999.25() -999.250 -999.250 3.711 -999 250 -999:25(,1 -999,250 3.588 TENS.AIT4 DT4P.DSI4 [~8GR.HNG4 HFK.HNG4 TENS.AIT4 DT4P.DSI4 HSGR.HNG4 HFK.[ING4 TE~S.AIT4 DT4P.DSI4 HSGR.HNG4 ~FK.H~tG4 TENS.AlT4 DT4P.D$I4 HSGR.HNG4 HFK.HNG4 TENS.AiT4 DT4P.DSI4 HSGR.HNG4 HFK.HNG4 TENS.AIT4 DT4P.D$14 HSGR.HNG4 HFK.HNG4 TENS.AIT4 DT4P.DSi4 HSGR.NNG4 !tFK.HNG4 TENS.AIT4 DT4P.DSI4 HSGR.HNG4 HFK.HNG4 DEP .'!" 98 O0. (.~0(,) 8P. AI,T,~, -999.250 GR,/;IT4 -999.25(I TENS.,AIT4 ' ' - . ,,, ' , N /ti,I, 4 -999.250 DT4P,D814 ~,TF,~./tI'I,,4 999 250 ~RFiS..A',I't"~ -999 250 H,.~E..., [ p{,~ ~'% . .....,,. '~ . . ... ,,, ~:. DSi4 90~.25t .... PRol)814 -999 250 CAL!.MLT4 -999.250 HSGR..HNG4 HCG~.~. HN G,4 78.92O HT}.,{O. BD(~4 12.386 ,~!URA. HNG4 2.44,!, HFK.HNG4 HBHF,.HNG4 0,466 T~N8. },tNG4 865.000 PAGE: 54 6810.000 77.593 -999,250 -999.250 6500,000 85.806 33.598 0.768 05.000 6579.698 81.445 1.727 64~0.~00 9. 52 83.445 1.780 9745.000 81.042 79,306 1.698 6840.000 79.881 9~.600 2.255 -999.2,50 -999.250 92,317 t.954 25O 91.432 1.982 .-999,250 -999.250 94.765 2,206 IS Tame Verificat!on Listir~q Chl~l~,~beroer AlasKa ComputinO Center 27-,~AR-1995 1.1:~0 PAGE: 55 DEPT. 9600. 000 SP. A.!T4 MTE~'~. AlT4 -999.250 ~',~RK5. A IT4 [~'1'2 D514. -999 250 PR DSI4 · . . HCGP. ~NG4 73. t~ J. I HTN[]. ~{NG4 HBBK.HNG4 0.955 Tt<,NS. ~NG4 DF, PT 0552 50(; SP AII4 MT E~.: .AIT4 -999.25(; ~RFS. AIT4 D..T?.DSI4 -9q9.250 PR.DSI4 HCG[~.HNG4 -909.2~0 HT}~L]. i{~lG4 Fi gHl~:. H'NG4 -999.250 TENS.HNGa DATA -999.250 GR. AI}i4 -999.250 -~99.25,) NTE,q. AI 4 -999.250 -999.2..50 CALI.MLT4 -999.250 10.691 HURA.MNG4 4. ~74 2320. 000 -999.250 -999.250 -990.250 -990.250 -999.250 }.{TEN.AIT4 CAI, I.MLT4 -999.250 -999.250 -999.250 -999.250 TENS.AlT4 i)T4P.DSI4 HSGR.HNG4 HFK.HNG4 TEN$.AIT4 DT4P.DSI4 BSGR.HNG4 HFK.HNG4 -999.250 -999.250 102.234 2.172 -999.250 -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAUE : EDIT ,009 SERVICE : FLIC YERSION : O01CO1 DAT~~ : 9510]/27 NAX REC SIZE : ].024 FIL~ TYPE : LO L~ST FILE **** FILE WE~[)ER **** FILE ~A~E : EDIT ,010 SERVICE : FLIC VERSION : O01CO1 DAT~ : 95103/27 ~× REC SIZE : FILE TYPE: : LO L~ST FILE : AP1 NORTH "~ ') T FILW, EI..I 010 ******~**~**~ SAMPLE RATE: 0,~5 F'T, R~W FIELD i~AIN bOG DATA ,A!T4 ,A'~RAY CONTAINED EXPLORATION ~50-629-22533 WILDCAT SbOPE, ALASKA OF RiJN ~4 (Tm NDUCTION T t",'~ [') I'. ~ THIS F'I[,E ARE THE hit 1' V E R T I C h I.., P E $ 0 [.., U T i 0 N RESISTIVITIES IS t'a~e 'Verification I, istir)n chlU~.beroer AlasKa Comput.i, nq Center 27-~AR-1995 11:30 i}NC~Rr~ECI'ED FP,.F,' [)TP Al',tl,) CO}~RKC]:F'b ~'~ PTP. PAGE: 56 APIN 50-629-22533 FI. 3334'S~L & 4770'~EL SEC~' 3 T 0 ~ Y 9 N COtj ~ l:,i fir T H SLOPE STAT aLASKA NATI USA WITN SON 629136 pDAT iCE PAD EPD FT 4, L~" APl.) FT 34. E~B FT 38, EDF ~T 33, E~L PT 4 1 ~D[., FT I~549. TDL FT 11544° B[,I FT 11524, TLI FT 36. DFT CORE MUD DF[) G/C3 1,2,5 DFPH 7 Dry s 7g. OFL F3 4 6 R~$ OH~'~i"~ 0i743 ~4FS? DEGF Well Name ~PI Serial Number Field Location Section Township Range County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum bog Measured From Above Permanent Datum ElevatioD of ~elly Bushing Elevation of Derrick Floor Elevation of Ground Level Total DePth - Driller Total DePth - Logger Bottom Log Interval TOD Lo~I6t:erval Drilling FlUid Type Dri. l~lnq Flul, d Density Dril ~ng FI, ui~ Ph Drilling Fluid Viscosity Dri. lli~g.f'luld boss Resistlvl'ty of Mud Sample Mud Sam le Temperature aesisti~i.'t~ o~tUd Filtrates ~ud flitra"e SamPle Temperatu Resistivity of ~ud CaKe Sampl DEGF 66. ~ud Cake SamPle Temperature ~'t DE(;F 158. Bottom .HOl:e Tempera ute · TYPE : CUPV DEF I DEPT AD1 e Afl 20 A03O IS q'aDe Ver.ificatlon ~,ist. in~ ChlU~berqer h].asKa Co~p,..~tlnq Center 27-.~AR-~gQ5 11 :BO PAGE: 57 ** r~ATA FDRUAT SPECIFICATIO~~ ~EC(J~D ** TYPE REPP YAbUE 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0,25 g 65 F T 1~ 66 ~3 12 68 13 66 0 1.4 65 FT 15 6~ 68 16 66 0 66 ** eET T o yDH - CHAN ** NA,~iE SER NiT SERVI AP1 ,,~P ~% 1 aPI FIE NUmB B SIZE RE PROCESS" ,S ID O~DER # bOG TYPE Ct, ASS MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 629136 O0 000 O0 0 10 I 1 4 68 AOIO ,~IT,4 (]H~ 6129136 O0 000 O0 0 lO I 1 4 68 A020 AlT4 OHM~ 629136 O0 000 O0 0 10 1 1 4 68 A 030 ,a ~t T 4 0 ~,,t: ~ ~ 62 q 136 00 000 00 0 10 1 I 4 68 A060 A.IT4 OHM~a 62'~13~ O0 000 09 0 10 1 1 4 68 A090 AIT4 OH~b~ 629136 O0 000 O0 0 10 1 1 4 68 Al'Bt) a ',t T4 62q136 O0 000 O0 0 10 1 1 4 68 DC20 .a~:T4 OH~aM 629136 O0 000 O0 0 10 1 1 4 68 DC30 giT4 (.)Ha~ 620136 O0 000 O0 0 10 1 I 4 68 DC60 liT4 OHa~ 6~9136 O0 000 O0 0 !0 1 i 4 68 DC9e~ A,[T4 014~4~ 629136 O0 000 O0 0 10 I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS ~'ape 'Ver.i.~icat].on Listino chlumherger AlasKa Computinc Center 27-MAR-1995 11:30 PAGE: 58 mm ~ mmm mmmmm .i mmmmmmmmmmmmmm.mmmm.mmmmmmmmmm m .mmm~mmmmmmmmmmm~mmmm mm mmm m I mmm mmmmmm.mmm~ m DEPT. 1!524.0n0 ~OIO.AIT4 6.~7 ~02O.AIT4 5,717 AO30.AIT4 AOAO.AIT4 5.541 ,%O90.AIT4 5.621 AI~I).AIT4 8.426 DC20.AIT4 DC3~.AiT4 -999.25~; 17CGO.AIT4 -099.250 DC90.AIT4 -999.250 [)~Pw. 11400.000 AOIO.AIT4 8.907 AO20.AIT4 6,375 AO30.AIT4 AOG~.~IT4 6.902 A(ogO.AIT4 6.857 AIBD.AIT4 8.309 DC20.A1T4 DC30.A~T4 6.437 OCGO.AIT~ 6.677 DCg;).AIT4 6.638 DFPT. 11200.000 ,~Ltl O. AIT4 lqSO.OOO AO20.AIT4 27,819 AO30.AIT4 AOBO.AIT4 692.66! AitqO. ALIT4 455.~91 AIBO.AtT4 7,643 DC20.AIT4 DCJO.AIT4 48,604 DCGO,~IT4 1079.801 Dcgo,AIT4 80~.263 DEPT. 1] 000.00() aqlO.AIT4 37.098 AO20,AIT4 16.521 AO30.AIT4 A06O AIT4 10.019 AogO.AIT4 9.526 AIBD.AIT4 7,568 DC~O.~I~4 Dc3n~AIT4 ,12.610 DC60,AIT4 1~ .302 DCqO.AIT4 10.829 DEPT. lOB00.000 AOlt).AIT4 38.402 AO20. AIT4 12 858 AO30.AIT4 A06~ AIT4 19.860 AOgO.AIT4 19.503 AIBO.AIY4 9:326 DC20.~IT4 DC30~AIT4 1.3.7~3 DcGO.AIT4 1~.816 DC90..&!T4 18' 312 DEPT. 10600.000 AO!O,AIT4 23.117 AO20.AIT4 9.054 AO30.AIT4 . . '"4 11 9~6 AIBD AIT4 9,510 DC20,AIT4 AB60 AiT4 ~,I 736 AOOO,,AI~ .... DC30.AIT4 9.469 DC60.AI~4 :1,1.34,1. DC90.AIT4 11.484 D.EPT 10400,000 AO!O,AIT4 50.612 AO20,AIT4 9,482 AO30.AiT4 A06~ ~ A',[T4 ~0,475 AogO,A!T4 10.122 AI, BD.AIT4 11.876 DC20.A, IT4 C30 AT'P~ 8,88b DC60 Ali q 154 DCOO,AIT4 8,759 OEPT, I028~,000 AO,IO.AiT4 -999.25() AO20,AIT4 -999.250 AO30.AIT,4 A060 AI 4 999,250 ~090 A r4 -999,250 AIBD,AIT4 999 250 DC20.AIT4 : : - . , 1'- T DC30,A!T4 999 250 DCGO A 4 -999.250 DC,gO,AIT4 999 250 ** }:'.,.ND OF' DA.A ** 5.724 -999.250 6.301 6.483 45.424 32.585 11.931 17.097 14,286 12.516 9 5O7 8~906 305 1,97 -999,250 -999,250 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : gblC VER$It]N : OOICO1 DATE : 95103127 ~,%.AX RE(] S~ZE : 1024 F!LF, TYPE : L~$? FiLE lS TaDe veri.~ication f,istinq chlun:berqer AlasKa ¢'or:~puti. nq Center 27-r4AR-19¢45 1,1 :30 PAGE: 59 bP E×PGORATICN BADAMI #5 APl ~50-629-22533 WILDCAT NORTH SbOP~, ALASKA MDIT.011 RATE: 0.O~33 FT. FIELD aAIN LOG DATA OF RL}~~ #4 (TD RUN) ,£,DS4 }ti PESO!.,t.,tTIO!,i LITHO DENSITY TOOL (,[PbT TOOl, STRING) TYPE : CONS T U r~ ! ¥ A I, U D E F I CN BP EX'Pl~ORATI[)N W ~:~ ~.A D A a I # 5 API ~!' 50-629-22,533 FI, 3334'8NL & 4770 S~C'r 3 T O ~ 'f,l 9 N RING 20E COLIN NORTH STAT ALASKA W:!TN 50N 629136 PDAT ICE PAD ~PD FT 'i, L~F APD FT 3~, EK.~ FT 38, 'E P F F T 33 TDD F~ 1{549. TDL FT 11544, ELI FT 11524, Compan Name Field'~ame Well Name AP1 Serial Nu~,ber Field Location Section Township Range ~ountYtate or .Province Nation ~ttness Name Service Order Number Permanent datum Elevation o~ Permanent Datum Log ~easured From ADore Permanent Datum Elevation of Eell¥ Bushing Elevation of Derrick FlOor ElevatiOn of' Ground bevel Total Depth - Driller Total Depth~- Logger ~ottom Log interval Tape Veri~.!.catJ. on I.,ist.inq chlumberqer AlasKa Computinq Cento. r 27-N,,{R-1995 I !: ]0 PAGE: 60 TI, I VT 36. OFT CORE MOD DFD G/C3 12.5 DFP~ 7. DF'V S 76. DFL F3 MST DEaF 66, i~FST DEGF 5 R~CS OH~4 2.33 MCST DEGF TOp Log Interval Drilling Fluid Type Drilling Fluid Density Drilling Fluid Pb Drilling Fluid Viscosity DrillinQ Fluid boss Resist].~ity of Mud Sample ~ud Sample TemPerature Resistivity of Mu~ Filtrate S Mud Filtrate SamPle Temperatu Resistivity of Mud Cake Sampl Mud Cake Sample Temperature B~T OEG.F 158. Rottom Hole Temperature TABI,E TYPE : CORV DF.,F I DEPY t)e~th ACTS gU' RS PRS~ ACT[. OVRt, NRHB N D P ~ RHS3 RH~4,. DRH DPU PEFL PHOTOEI~ECTRIC FACTOR FROI~ T~E FAR DETECTOR hCA[, ORS caliper for LOS, same as CAbI for LDT ** DATA FORI,,~AT SPFCIFICATIO~,~ RECORD ** ** SET TYPE - 64EB ** 1 66 0 2 66 0 3 73 64 4 66 5 66 6 73 IS Tare veri.~icatJon l.istino chlumberq, er Alaska Compute. nO Center 27-,~AR-1995 11:30 PAGE: 61 T E REP~ CO 9 65 11 66 1. b 12 68 14 65 FI 15 66 0 66 AN ,, .AP.i API I [, B NiJg. IZE REPR LOG TYDE CLASS ~OD iqU.~B SA~P EBEig CODE DEPT FT 620136 00 ACTS '[.,DS4 $ 629136 00 DVRS I, O84 CPS 6201,]6 00 pRS.q. LDS4 629136 O0 ACTL LDS4 S 620.136 O0 OVRI', LOS4 CPS 620136 O0 NRHB 1,584 G/C3 629136 00 N DP['~ LDS4 PU 629].36 O0 RHS~ LDS4 G/C3 629136 00 RH,.%.,"4 LDS4 G/C3 629136 00 RNL LDS4 G/C3 629136 00 RHO~ LOS4 G/C3 6291:36 O0 DP~ [., ~.') S 4 G/C3 629136 O0 DPO l., L)$ 4 PU 6291, 36 00 PKFL LDS4 6291. 36 O0 LCAI,, [.,DS4 IN 629136 O0 000 O0 0 11 I I 4 68 000 OOO O0 0 11 1 1, 4 68 000 000 00 0 11 1 1 4 68 000 000 O0 0 11 1 1 4 68 000 000 O0 0 11 1 1 4 68 000 000 O0 0 11 I 1 4 68 000 000 O0 0 11 1 1 4 68 000 000 O0 0 1.1, 1 1 4 68 000 000 O0 0 11 1 I 4 68 000 000 O0 0 11 1 1 4 68 000 000 O0 0 11 1 1 4 68 000 000 O0 0 11 1 i 4 68 000 000 O0 0 11 I I 4 68 000 000 O0 0 J 1 1 1 4 68 000 000 O0 0 11 1 I 4 68 000 000 O0 0 11 1 1 4 68 000 * * D g T A * * DEPT. 11.200. 000 ACt['L. LOS.4 0. 250 R ~ S :3. L I3 $ 4 2.331. DR~.LDS4 -0.0l 3 TS. bUS 4 R h. L D $ 4 84 .LDS4 P[), LDS4 ACTS. LDS4 0 V P i.,. L l.) S 4, RH$4 LBS4 I.)Po ~ LD,$4 ~CTS. LD$4 0 V r:, L. L P S 4 R}tS4. LDS4 D P 0. LDS 4 -999.250 OVRS.LDS4 -999.250 PRSS. -999.250 NRHS.LDS4 -999.250 NDPH. -999.250 R'HL,LDS4 -999.250 RHOM. -999.250 PE]FL.LDS4 -999.250 LCAL, 0.~50 (3V.RS. [~DS4 64.000 PRSS. 20. 000 NR. HB. LDS4 2..311 NDPH, 2.370 RNL. i,,DS4 2,318 R~O~. 20,849 PEFL,LDS4 3.354 hCAL, 0.250 OVRS. L, D84 64 000 PRSS. 36.000 NRFtB.,LDS4 2~511 NDPH. 2.377 RHL. LDS4 2i 466 RHO~. 9. 175 DEFL. LDS4 4. 832 LCIL. R ESS (HEX) 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 O0O0OOO 0000000 0000000 0000000 0000000 0000000 LDS4 L D $ 4 LDS4 LDS4 LD$4 LDS.4 LD84 LDS4 I,,DS4 LDS4 LDS4 LDS4 '999,]50 '999, 50 "999.250 '999.250 724 000 ~.306 8.597 596,000 9.17~ 2.49 9.648 IS Tame verl. ficati,.on [,istim.q chlumber,',.].er Alask'a Computlr)q Cen~teI- DFpT. 10600.000 ACTS.LDS4 ACTL.LDS4 0.250 FIYRL~. LDS4 RHS3.I,DS4 2.463 RHS4.LDS4 O~. !_,DS4 0. O05 t]P[3. LDS ~ DEPT. 10400.000 ACT$.LDS4 ACTI,.LDS4 0.500 OVRb. LD$4 HHS3.LDS4 2.532 R~{S4.I, DS4 DRH.LDS4 0.002 DPOoLDS4 DEPT iO200,OOU ACTS.LDS4 .ACTI,~ LD$4 0.250 OVRb. I~D$4 RHS3.LDS4 2.465 RH$4 L, DS4 DRN.LDS4 0.019 DPO~LDS4 DFPT 10000.000 ACTS.LDS4 ACTI,~rnS4.~,.,~,. 0. 500 F~VPb. LDS4 R~S3.LOS4 2.409 R!iS4.LDS4 DRH. [,DS4 0. O~9 OPO. LDS4 DEPT. 9800.000 ,~CTS.. LDS4 ACTL.LDS4 0.250 OVRL.LDS4 RHS3 I.,,OS 4 2.452 ~HS4.LDS4 DRI~: [,,DS4 O. 0~0 DPO. LD54 D~.:PT. 9600.000 ACTS.LBS4 AC.T !.,. I.,, DS4 0.500 OV R [.~ LD54 R~S3.LDS4 2.492 R,}i84: LDS4 ~ R ~. [, 0 $ 4 - 0.004 b P 0. L D $ 4, DEPT. 9552.500 l C',!'* $.. I,,,D 54 ACTL'LD$4 -999'250 OV~L.LDS4 RDS3.LOS4 -999,250 RHS4.LDS4 DR~.LDS4 -999.250 DP(3. LDS4 **** FILE TRAILER 8FRVICE : FLI, 'VF~RS ION : 001. C01 DATE : 95/03/~7 NiX REC SIZE : ~.024 FILF TYPE Ln, ST FILE : 27-~AR-1995 11:30 0.250 OVP$.[,DS4 4.000 2.500 RHL.~DS4 10.173 PEFL.LDS4 0.250 OVRS.LD$4 20.000 NRHB.LD&4. 2.440 RHL.LD$4 10.921 PEFL.LDS4 0.500 OVR$.LDS4 44.000 NRHB.LDS4 2.522 kHL.LDS4 6.~16 PEFL.LDS4 0.250 OVRS.LDS4 48.000 NRHb. LDS4 2.436 RHb. DDS4 7.455 PEFL.LDS4 0.500 OVPS,LDS4 42.000 NRHb. LDS4 2.344 R~b,LDS4 11.386 PEFL,LDS4 0.250 OVRS.LDS4 24.000 NRHD.LDS4 2.400 RHL,LDS4 9.441 PEFL~.LDS4 0.500 OVRS.LD$4 36.000 NRHB.LD&4 2.510 RHb. LDS4 9,596 PEFL,LDS4 'g99,250 OV~$,LDS4 '999.250 NRHB,LDS4 '999.250 RHL.LDS4 '999,250 PEFL.LDS4 48.000 2.486 2.485 4.523 52.000 2.500 2.463 4.349 36.000 2,521 2.533 5.150 44.000 2.523 2.505 6.390 64.000 2.473 2.430 7.126 48.000 ~.499 2.471 4.134 34.000 2.496 2.,494 4.312 -999 250 -9991'250 -999250 -9991250 PRSS.LDS4 NDPH.LDS4 RHO~.LDS4 LCAL.LDS4 PR$S.LDS4 NDPH.I, DS4 RHOM.LDS4 LCAL.LDS4 PR$S.LDS4 NDPH.LDS4 RHO~.LDS4 LCAL.LD$4 PRSS.LD$4 NDPH.LDS4 RHO~.LDS4 I, CAL.LDS4 PRSS.LDS4 NDPH.LDS4 RHO~.LDS4 LCAL,LDS4 PRSS.LDS4 ~DPH.LDS4 RHO~.LDS4 LCAL.LD$4 PRSS LDS4 NDPH:LDS4 RHO~'LDS4 LCAL.LDS4 PRSS.LDS4 NDPH,LD$4 RHO~,LDS4 LCAL.LDS4 PAGE: 62 624,000 11,721 2,482 10,272 5BO.O00 10.428 2.470 9.518 526.000 7.923 2.538 12.009 684.000 7.455 2.~27 11. 42 752000 11~386 2.462 10.725 660.000 9.441 2.494 12.509 580'.000 9,315 2,492 12.423 -999 250 999 250 -999.250 IS 1'a..ne VerlficatJ. on [.,lstlno cblumber(~er AlasK:a Co~.~.~utJ. nq Center 27-~AR-~.995 11 ;30 PAGE: 5P EXPLORATION APl #50-629-22533 WILDCAT NORT}~ SLOP~, ALASKA FIL~ EDIT,O]2 SA~PL~ ~AYE: 0,~667 RA~ FIELD OAT~ OF gAl~ !,Og PUN #4 (IPLLI.' TOOL STRING) ,APS4 MI RESOLtlTIOt.,i EPI'IT:i'tER~AL NEUTRON TOOL (IP[,T TOOL STRING) ,MLT4 ~,~ICRObOG TOOl., TYPE ~ CO~]S T tl ~'~ I V A b U O E F I C~ ~pEXPLORATION Compan~ Name .F~ WILDCAt' Field Name WN APl t~ FI,, SECT TOW~ COUM STAT WITN PDAT EPD .A P D E~B EDF TDL FT FT FT FT FT BADA~I #5 50-629-22533 3334'SNL & 4770'WEL 9N ~IORTH SLOPE ALASKA USA PUTNAM 6291.36 ICE 34. 1.1.54,4, Well Name AP1 Serial Number Field. Location Section Township Range County State or Province Nation Witness Name SerVice Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevatio~ of Kelly Bu~hi~g Elevation of Derrick floor Elevat~om o~f Ground Level Total DePth - Driller Total DePth- Logger IS Tar, e Yerificst~.on !.~i. st.in~ chlumheruer A]asKa Computlna Center 27-~AR-~.995 11:30 PAGE: 64 TI,.t~,I VALIJ DEFT Bbl ~T 11524' ~ottom bog Interval TI,! FT 36. Top Log Interval DFT CORE MUD Drilling Fluid Type DFD G/C3 17.5 ~rllling Fluid Density DFPN 7. Drilling Fluid Ph DFV $ 76. DrilliDO FlUid ViScosity DF[, W3 ~.b Orlllln~ Fluid boss R~S OH~N 0o7~,3 ~esist~gltF o~ Mud Sample ~$T D~GF' 66. ~ud Sample Temperature R~FS O~l~ 0.49~ Resistivity of ~,ud Filtrate S SFST DEGF 55 ~ud Filtrate SamPle Temperatu R~CS []HMM ~"~3 Resistiv~.ty of Mud CaKe Sampl ~CSI' DEGF 66. ~ud Cake SampLe Temperature BNT DEGF 15B. Bottom Hole Temperature TYPE ; CURV D~FT I)F,.PT Depth ~INV ~icro-Inverse ~esist~,v~,tV ~NOP ~,~icro-Nor~al ReSlstivit[ F'PSC APS NEAR/FAR CORRECTKD ANDSTO~'~ F'OROSITY AF~,:C A1EP A2EP ATN~ AT~'T ENF'P AP[,C APSC ENP~ APDC STGF STANO OFF DISTA;(~Cg, COMPUTED APS NEAR/ARRAY CORRE;CTgD L'I~ES.7'O~,!~' POROSITY EXCEPT FOR FSAb ** PATA FORgAT SPECIFICATIOn:' R~;CORD ** ** SET TYPE - 64EB ** T PE R P CODE LUg 2 66 3 73 68 ,4 66 IS Ta~e Verif.ication [~lstinq chltl~berger AlasKa Co;r. pkltlr~o Center 27-MAP-1995 !!:30 PAGE: 65 mmm#mmmm,mmmm.mmmmmm,mmmm.m~mmm.mmm 5 ~6 6 73 7 65 8 68 0,166 9 65 FI 11 66 3 66 0 4 65 F~~ 5 66 68 6 66 66 ** SET I D DEpT FT MINV MLT4 OHM~ MN[)~ ~LT4 FPSC ~PS4 ANE. C APS4 CPS AF'gC ~PS4 CPS A1EP APS4 CPS g2MP APS4 C~S ATNT ~PS4 S ATFT APS4 EMF~ APS4 E~AP APS4 APLC APS4 PU APSC APS4 PU EMPI APS4 APDC APS,4 PU STOV APS4 IN 62 TYPE - CHAN ORDE~ # LO.G TYPE CLASS 629136 O0 000 O0 0 629136 O0 000 O0 0 629136 O0 000 O0 0 629136 O0 000 O0 0 6291. 36 O0 000 O0 0 6291 ~ 6 00 000 (,) (> 0 6291,36 O0 000 O0 0 6291 36 O0 000 O0 0 6291,36 O0 000 O0 0 629136 O0 000 O0 0 629136 O0 ()00 O0 () 629136 O0 000 O0 0 6291 ?]6 O0 000 O0 0 629136 O0 000 O0 0 629136 O0 000 O0 0 629136 O0 000 O0 0 9136 O0 000 O0 0 0 h N U .~4 $ S A .~. P E [, E M C [. D E ( H E X ) 12 1 i 4 68 0000000000 12 1, i 4 68 0000000000 12 1 I 4 68 0000000000 12 1 1 4 68 0000000000 12 1 1 4 68 0000000000 12 1 1 4 68 0000000000 12 1 1 4 68 0000000000 12 1 1 4 68 0000000000 1,2 I I 4 68 0000000000 1.2 1 1 4 68 0000000000 12 1 1 4 68 0000000000 12 1. 1 4 68 0000000000 1,2 I 1 4 68 0000000000 12 I I 4 68 0000000000 12 1 1 4 68 0000000000 12 I 1 4 68 '0000000000 12 1, 1 4 68 0000000000 * * D A !!,' 11 * * DEPT. 11524 A,.,LC.APS4 -999 ATNT.APS4 -999 AP!.,,C.AP$4 -999 STOF,APS4 -999 DFPT. 11400 ANEC.APS4 -999 ATNT.AP$4 -999 API,,C.AP$4 -999 STOF,APS4 -999 000 M.INV ~LT4 3 588 MN[)R {.tb'.14 5 972 FPSC APS4 ,250 AFEC.APS4 -999,250 A1. EP,APS4 -999:250 A2EP,AP$4 ,250 ~'TF'IT,APS4 -999,250 ENFR,APS4 -999i250 ENAR,APS4 ,250 aPSC,APS4 -999.~50 ENP.I,AP$4 -999 250 APDC,APS4 ,250 000 MINV ~,bI4, 3 57.1 :~NOR MLT4 6 1.09 FPSC:,APS4 .250 AFEC, APS4 -999,250 A1EP.APS4 -999 250 A2EP.APS4 .250 ATFT.APS4 -999,250 ENFR,AP54 -999~250 EN'AR'APS4 ,25(') A~SC.APS4 -999,250 ENPI,~PS4 -999; 250 APDC,APS4 ,25O -999 250 999.250 -999,250 -999,250 -999,250 -999'250 IS Tar, e Verif, icatJ, on LiStJ. nq chlumberger AlaSKa Cornputli%Q Center DEPT. 11200.000 ANEC.APS4 3345.333 AFEC.APS4 AT?~T.AP$4 0.75U A~FT.APS4 APLC.APS4 !9.17~ APSC.APS4 $ff'OF.APS4 0.113 DEP?. I1000.OOt) ~I~V.MLT4 ANh, C,APS4 3209.333 AFFC.aPS4 AT~T.APS4 0.750 ATF'T.AP$4 APLC.APS4 17.746 aPSC.APS4 STGV.APS4 0.415 DEPT. 10800.000 ~INV.k~[,T4 ANEC.APS4 3164.000 AFEC.APS4 ATNT.AP$4 0.750 A'~FT.AP54 APLC.IPS4 13.530 APSC.AP$4, Sq'OF.APS4 0.926 DEPT. 10600.000 ANEC.APS4 332,2.667 ATNT.APS4 0.750 ATFI'. APS4 APLC.APS4 16.043 APSC.ADS4 STOW.APS4 0.4!7 D E P T. l. 0400.000 ,41 N V. 14 ,[,,'I 4 ANEC. APS4 3234.0o0 AFEC.AP64 ATNT.~PS4 0.500 ATFT.APS4 APl~C. APS4 18.257 APSC.APS4 STOW..APS4 O. 256 27-~A~-1.995 1.1:30 5.330 ~Nf')R.~4BT4 6.995 1004.000 AIEF'.AOS4 2272.000 1.000 ENFR.AP54 3.899 27.932 ENP!.APS4 19.171 ~.372 ~qNOk. GILT4 3.628 932.000 A1EP.APS4 2317.333 0.750 E[,iFR.APS4 4 235 21.846 ENPI.APS4 17:746 4.015 ~NOR.HLT4 906.000 A1EP.AP$4 3.000 ENFR.AP$4 17.508 ENPI.APS4 5.537 231,3.333 4.175 13.530 3.496 ~NOR,MLI4 4.682 i001.333 A1EP.AP$4 2508.000 0.750 ENFR.APS4 4.085 20.075 ENPI.AP$4 16.043 1.023 NNOR.~T4 1.963 902.000 A1EP.APS4 2430.000 0.500 ENFR.APS4 4.264 22.~31 ENPi. AP$4 18.257 FP$C.AP$4 A2EP.AP$4 ENAR.APS4 APDC.APS4 FP$C.APS4 A2EP.APS4 ENAR.APS4 ~PDC.APS4 FPSC.APS4 A2EP.APS4 ENAR.APS4 APDC.APS4 FPSC.APS4 A2EP.APS4 ENAR.AP$4 APDC,APS4 FPSC.APS4 A2EP.AP$4 ENAR.APS4 APDC.AP$4 DF. PT 10200 000 Mi:NV P.L]4 999 250 ~tN'OR,MLT4 999 ~50 FPSC,.APS4 ANEC.APS4 3362.667 AFEC.APS4 9381667 A1EP,APS4 249~%000 A2EP.APS4 ATNT.APS4 0.750 ATP.T'APS4 0.750 EhFR,APS4 4,044 ENAR..APS4 A. PLC. APS4 16.014 APSC, APS4 20,025 ENPI,APS4 16,372 APDC.APS4 s~'o~'. ~PS4 o. 3~9 DEPT 1.0000.0()0 MIN'V.~I,I, 4 -99~ 250 MNOR a.,~t,4 999 250 FPSC A,P,S4 ANEC:~PS4 341,4.667 ~,F~,C,AP$4 ~12.000 A1EP.A~S.4 ~2421667 A2EP APS4 ,AT'~,*T APSa 0 750 AT,, ~ APS4 0.750 ENFR.AP$4 4 633 ENA, R~APS4 . · ~, ' · ' . ,, ~,, APLC.APS4 1.7.9~3 A.PSC.AP$4 22 11,0 E, Si[,.,[.AP$4 19~053 APDC.APS4 STOF.APS& 0.622 D E P T. 9800.000 ,~ I ~,~ V. ~'i L T 4 - 999.250 ~q N 0 .R. a 5 T 4 - 999 · 250 NEC APS4 349,!.667 A, F"' ' ' ' ' A T : F ~ C. A P,, 8,,~ .4 1001 .333 A 1 E P . A P S 4 2349.333 ANT APS4 0.750 ,~,[,'I.' A~o4 0 750 ENFR.APS4 4.187 API,,C. APS4 18.9R~ APSC.AP&4 22.795 ENPI.APS4 17.955 STOF. APS4 0. 139 FPSC A:PS4 A2gP '. AP$4 E N A'R, A P S 4 APDC.APS4 DEPm. 9600.000 MiNV.MLT4 -999.250 ~4NOR,HLT4 -999.250 FPSC.APS4 ANEC.AP$4 3352'000 AFEC.APS4 919.200 A,I, EP.AP84 22BI.3,33 A2E,P.APS4 ATNT ,APSE 0,750 A',FFT,A.P$4 1.250 E~NFR..APS4 4.239 EN,AR.AP84 ADI,,,~C~APS4 19.712 APSC,AP$4 23.607 E'NPI.APS4 ~B.437 APDC.APS4 STOF.APS4 0.185 PAGE: 66 0.235 2414.667 0.699 19.163 0.255 2305.333 0.703 18.875 0.226 2248.000 0.696 1.5.938 0.241 2430.667 0,682 17.011 0.263 2344.000 0.697 ~.8'799 0 38 0.679 0.283 2213.333 0.724 19.913 0.259 2468.000 0.699 19.086 0.263 710 20.031 IS Tat~e verffication l,.,lstlnq chlumberger AlasKa ComP~]tJnq Center 27-.~.~AR-1995 11:30 PAGEs 7 DE':PT. 9552.665 ~4 II,iV. lq LT4 -(.~99. 250 ~NOR.MLT4 ANF:C. APg4 -999.250 AFKC.APS4 -99q.250 A1E:P. ~PS4 ATNT.APS4 -9~9.250 ATF'T. bPS4 -999.250 ENFR.APS4 APLC.APS4 -9q9.250 APSC.AP84 -999.250 Ef~PI.APS4 S~'C~. APS4 -999.250 -999.250 FPSC.APS4 -999.~50 A2EP.APS4 -999.250 ENAR.APS4 44.084 APDC.APS4 -999.250 -999.250 -999.250 -999.250 **** FTLE FTLF I~!A~E] : EDIT .012 SERVICE : FbIC V~'[~SION : ~O1CO1 DAT~ : 95tU~t27 FILF TYPE LAST F I I.,E **** FILE HEADER **** FILr< NAME : F, DI'Y .013 SERVICE : FLIC VERSION : O0.~COi [) A'r ~: : 95103/27 ivtlxX I~;C S!Z[': FTLF TYPE : LAST FILE : }?ILM ED!T.OI3 ************* SAb~:PLE RAT.I:.;: 0,(')4167 F~,.". RA¢~ F',IE!,D DATA O}:' }vtAIa I~{)r; kUN *~4: (TD },tUN) .EPT4 HI RESOI..~UTION ELECTPO~.~!'AGNETIC PROPOGATIOPo TOOt, (IPI,,T TOOL ,STRING) IS Ta~e Ve..rifJ. catiom l,istinq chll~mberc.$er Alaska Com[:,ut. ino Center 27-~/,R-1995 PAGE: 68 TItF 1 VALti DEFI CN bP 0 m any Name F'N ¢, I LDCA'.r W~" bADAHI ~5 APIN 50-629-22533 FI, 3334'SI.~L g ~770'WEb SECT 3 RaNG 20E COU ~.~ STAT NAI'~ L~Sh wlT~,: PITT NA PDAT iCE PAD APD F'.r 34, ~g FT 38, EDF F~ 3 TUb FT 1 ~ 549, BLI FT 1. J, 524. TI.,I FY 36, DFT (:ORE MUD DFD ~/C3 12.5 DFPI4 DFV S DFI,, F3 4 R'"l ~ 0 H',','I 0~7.43 Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Servlce Order Number Permanent datum Elevation of Permanent Datum Log ~easured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation o~ Ground Level Total.. Depth- Driller Total Depth - Logger Bott~.m Log Interval Top [o~ I~terval Drilling Fluid Type Drtllin~ Fluid Density Drilling Fluid Pb Drillin~ Fluid Viscosity Drill. inq Fluid Loss ResistigltY of ~Ud Sample Mud Sample Temperature Resistivity of Mud Filtrate S ~ud Filtrate SamPle TemPeratu Resistivity of MUd CaKe Samp! Mud CaKe Sample Temperature Bottom Hole Temperature IABI...E TYPE : CUPV D F,, P T t) e D t h EATT EPT httent]ation EPR EPT ~esi. stlvity EPHI EPT Porosity TPb Time of Propagation in I,.,OSSy [;"ormatior~ IS Ta[~e Yer~fJcat,ion Listino chlumberoer AlasKa ComputJ. nq Center 27-~;AR-,1.995 ll :30 PAGE: 69 ** t"ATA ** SET -; SPECIk'IC/~,.q.'IuI',~ RECORD ** TYPE- t~4EF ** E R [: P . !¢ E E 66 0 66 73 66 66 73 68 o.041 65 FT J,~ 6b 51 12 3 66 0 14 65 15 66 68 16 66 66 ** SET TYP N~M~': SMRV UN,IT SER ID ORD DEPT 62. EbTT EPT4 D8/M 629 EPR EPT4 OHM~ 629 EPH~~ EPT4 PU 629 TPb EPT4 ~S/~ 629 E- CHAN ** VICE APl F : APl. APl Fl'. E NUMB NUMB SIZE ER # LOG TYPE CLAMS ]~OD NUmB SA~P ELEM CODE {HEX) O0 OhO 0 3 1, 1 4 68 0000000 136 O0 000 O0 0 13 ~ 1 4 68 0000000000 136 O0 000 O0 0 ].3 1 1 ~ 68 0000000000 136 O0 000 O0 ¢) ]3 I 1 4 68 0000000000 136 O0 00© O0 0 1,3 1 1 4 68 0000000000 ** DATA DEPT. TPL. F, PT4 DEPT. TPL. F, PT4 DEPT. TPL, EPT4 DEPT. TPL, 5~PT4 11377.95 '999.25 t1200.00 9.23 11000.00 ~2.6S 10800.00 ~0.74, 9 EATT.EPT4 -999.250 EPR.EPT4 -999.250 EPHI.EPT4 0 0 B.r, ATT EPT4 ~41,50~ EPR.E;Pr. 9, .......... ~ 4 308 EPHI,EPT4 7 0 F;ATT.EPT4 356.954 EPR. E;PT4 2.390 ~:PHI. EBT4 (,) BqtATT. EP'I?4 330.753 EPR.EPT4 3.310 EPHI.EPT4 -999.250 .1,696 19. 389 8.725 IS Tape Vertfl. catio. [.ist.~nq chl. Umberoer AlasKa Co~putinq Center DEPT. ! 0000. t~O () EATT. RPT4 TpI.,. FPT4 ! 2.2~3 DYP~. 10~,~0o.000 FATT.EPT4 TPI,.EPT4 1 DF. pT. 102OO. 00o F, ATT. kPT'4 TP[,.EPT4 13.264 DFPT, ] 0000.o00 TP~,.EPT4 ~0.927 DEPT. 9600.000 EATT. E;PT4. TPI,,. FPT4 13. DF]PT. o~o00.000 EATT.EPT4 TPL. EPT4 15.536 DEPT. 9552.500 KATT.EPTa. TpI,.EPT4 -999.250 ** gND OF DATA ** 27-!~AR-t9~5 1.'!1 -~eg. 123 EPR.EPT4 5o7.519 EPR. EPT4 409.805 EPR.EPT4 3~1.280 EPR.EPT4 358.960 EPR.EPT4 427.096 EPR.EPT4 2.312 1..363 1.765 2.446 2.246 1.401 -099.250 EPR.EPT4 -999.250 EPHI.EPT4 EPH!.EPT4 EPHI.EPT4 EPHI.EPT4 EP}~I.EPT4 EPPI.EPT4 EPM!.EPT4 PAGE: 70 16.676 10.515 21.203 8.330 22.802 33.723 -999.250 **** FILE TRAILER **** FILE MA~E : EDIT .013 SERVICE : FLIC ¥'ERSION : 001, C01 DATE7 : 95/03/~7 gAX REC SIZE I 1024 FILE TYPE : !.,0 L~ST FILE : **** FII,.,E HEADER **** FILM ~,IA~E : EDIT .014 SERVICE : VERSION : 00lC01 I)ATF : 95/03/27 MAX. REC $IZ~ : !,024 FILE TYPE LAST FILE FILE AP1 #50-629-22533 WILDCAT N{,'i!RTF~ SbO[,;E, IS ~'ape verification bist.inq chlU~?,erger l\].asks Computj. nq Center 27-~.AR-1995 11 :710 SA~,~PLE FAME: 0.5 FT. RAw F;E!,D RFP~AT FIfE [}F PUk; ~I (Si,RI'ACE RUN) ,[)TK1. FIqASO~ INDiJCT!t3N TOOL, .~,SR1 I.,~ t'~ G SPACFD [)AGE: TYPE : CG~:S TU~,iT VALU DEFI .......................................[~P FXRLORATID[4'''''''''''''' ................. ~ ............ ' ......... ' ....... CU ompanY Name FN V,' T L, DCA 'i API~,~ 50-629-22533 SFCT 3 TO ~ ~..' R~N~ 20E CO[,J N NORTH SLOPE STAT ALASKA N ~ T T l~ S A SON 6291. 36 PDAT I. CE PAD EDP FT q ~ h M F ~, B APD FT 34, EKB FT 3 g, EDF FT 33, EGL FT ~ ~ TOD FT J. { 5a9. TDL FT 11544, BI,,, I FT 1.1524, T ~.: I F T 36, OFT CORE ~UD DFD G/C3 12,5 D~' P U 7 DrY S 7 &, I) F L F 3 4 6 MFST D:EGF 5 5 RMCS OH~ 2, :~3 MCST DEGF 66 . BNT DEGF' 158, Field Name Well Name AP1 Serial Number Field bocation Section Township Range County State or Province Nation witness Name Service Order NumDer Permanent datum Elevation o~ Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation oi Derrick Floor Elevation o~ Ground Level Total Depth -Driller Total Depth - Logger Bottom Log Interval Top Log I~terval Drilling f'.luiQ Type Drll~Inq Fluid Density Dril. ng Fluia P~ Dr.il.l..inc FlUid Viscosity Drillin~.Flul. a boss ResistiVity o~ Mud Sample ~ud Sample TemPerature Resistivity Of Mud Filtrate Mud Filtrate SamPleTemPeratU Resistivity Of ~ud Ca~e Sampl ~ud Cake Sample Temperature Bottom Mole Temperature I$ Tane ver,~.i.~cat,,ion chlumberger Alaska Coral;utC, nc3 Center 27-~'~AR-1995 1] :30 DFPT Depth CIDP INDUCTION DE[:P P}IAS[]P COr'~DUCTIVITY IUP[~ I~]DbCTION DE[:P [.,HASO~ ~ESIST!VITY ClMP INDUCTI()N ,~EDJ. UP P~ASO¢ CONL, UCTIV1TY l~P}! INDbCTION gEDIUI-": PH&SOR PESISTIVITY ClLD Conductivity ti., Deep Standard Processed I[,D Deed InOuction [taDoard Processed Resistivity CIL[~ CO~d,.~ctivity i[, ~edium StaBd~rd Processed ILM ~edium Imduction StaBdard Processed ~esistivitv I.F~'~i Induction Calibrated FreoueBcy IDOF !ndt~ctJ. om Deep i~uality Factor IuOF InOuctlo¢ ~edium Oual. lty Factor iI~[., Deep IBductIon }~eal Intermeal. at.e Cor~ductIvity IIXD Deed Imduction Ouad Inter~ediate Conductivity II~;~ ~edlum I~ductioD Resl IBtermedIate Conductivity IIX~ ~edium l'.nductjon (4t!ad Intermediate Conductivity SFLI; SFL Resistl. vltv Uhaveraqed SP Spontameous Po~entl al. GP Gamma Ray TENS Tension ~ T 5,;~~ ~ud Temperature NRKS ~OD ~esist:ivity ~TE~,~ [~ead TeDS DT DE[,TA-T DTL DEI.,T A-T LONG DTLN DELTA-T LONG SPACING DTL[' DELTA-T DONG SPACIkG FAR TT1 TRANSIT TIgE 1 TT2 TRA.~,~SIT TI~E 2 TT3 TRA'NSIT TIgE 3 TT4 TRANSIT TI~E 4 bTT1 LONG SPACING TRANSIT I.,TT2 LDNG SPACING TRANSIT T~F,', NODE 2 LTT3 LONG SPACING TRAr.:!SIT TIME 'NODE 3 LTT4 LONG SPACING TRANSIT TI~,~F ~ODE 4 PAGE: 72 ** DATA FORe, AT SPECIFICATION ¢ECOR[) ** ** SET TYPE - 64EB ** T~PE REPR COPE VAbt~; 1 66 0 2 66 0 3 73 ~ 66 5 66 IS Ta~,e V'erification Listlt~q ChlU.,,berger i\].aska Corr~put. inc Cer~ter 27-~,~AR-] 995 1.1:30 73 ~.; C DE VALU 6 73 7 65 ~ 6~ 0,5 9 65 FT 1~ 66 7 1~ 6~ 13 66 0 14 65 FT 15 66 68 16 66 ~ TYPE ** SET ID ORDE;P, ~. i~OG TYPE CLASS .............DFFT [~'''~29136 ~;''';';. 0 ........ 00 CIPP DTR1 ~.~HO 6291~6 O0 000 00 iDP~ TDPH ;.)TR] 620136 O0 000 O0 CTMP DTR1 M~HC 629136 00 000 00 I~P~ BTR1 OH~tjM 629136 O0 000 O0 CIb[, DTRI M~HO 629136 O0 000 O0 I[.,D DTRI (]HN~ 629136 O0 00() O0 CIL~ DTRI M~HO 629136 O0 OOu O0 Ib]~ DTRI [)HMM 62Q136 O0 000 O0 IFRF, IF'PE [)TR1 629136 O0 000 O0 IOOF DTR1 6291.36 O0 000 O0 IMOF' DTR1 629136 ()0 000 O0 IIRD OTR1. MMHO ~29136 00 000 00 I'R~', D,I,.~I ~,4MHO 629136 00 000 00 IIX~:. DTPl g[~HO 629136 00 000 00 ~;FLU p'r¢l OHaM 620136 O0 000 00 SP DTRI gV 629136 00 000 00 G~ DTR1 GAPI 629136 00 000 00 T~ b,l S DTR1 [,B 629136 00 000 00 MTE~ DTRI DEGF 629136 0O 000 O0 M~ES r3TPl f)HMbl 629136 OO 000 OO HTEN DTR1 LB 629136 00 (.)00 O0 DT LSR1 US/P' 629136 O0 000 00 DTL LSRI i,}$/P 629136 00 000 00 DTL~,~ I..,SRI 0$/F 629136 00 000 00 DTLF LSRI US/F 629136 O0 000 T T 1 68 R 1. tis 629136 00 000 00 TT2 LSRi US 6291 36 0o 000 O0 T T 3 L S R i. i,J S 629136 00 00 () 0 O ~'T4 LSR 1 US 629136 O0 OOO O0 L T'J: ~. LSRI US 629136 O0 000 O0 LTT? LSRi US 629136 O0 000 O0 LTT3 I,,,S~ 1 US 629136 O0 OOO O0 ;'";; ......... i'" ........ ; ............. ';" 1 4 8 0000o0000 0 14 1 I 4 68 0000000000 0 1.4 1 I 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 I 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1, i 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 1 4 68 0000000000 0 1,4 1. 1 4 68 0000000000 0 14 I 1 4 68 0000000000 0 14 1. I 4 68 0000000000 0 1,4 1 1 4 68 0000000000 0 1~ 1 I 4 68 0000000000 0 14 I I 4 68 0000000000 0 1.4 1 I 4 68 0000000000 0 14 1 1 4 68 0000000000 0 1,,4 1 1, 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 I 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 1 1 4 68 0000000000 0 1.4 1 1 4 68 0000000000 0 !4 1 1 4 68 0000000000 0 14 1 1, 4 68 0000000000 0 1,4 1, I 4 68 0000000000 0 14 1, I 4 68 0000000000 0 1,4 1 1 4 68 0000000000 0 14 1 I 4 68 0000000000 0 14 1 1 4 68 0000000000 0 14 I I 4 68 0000000000 0 1.4 I 1 4 68 0000000000 IS Tar, e YerifIcati. on I,lst, i. nq ChlUmt, ercler AlasKa Comp,itir'~c] Center 27-a,AP-1995 11:30 PAGE: 74 * * ;'.) A T A * * DFPT. 4551.50(:, CIDP. I)TR.~ 48~1..250 IDPH. IDPH ~.076 CI~P. DTR1 I~p~i. DTR 1 2.0~.o CIL[.~. DTR 1 ~4.7~0 I[,~). DT~I 2.061 CIbM.DTR1 IL~Z.DTRI 2.09U IFRE..IFRE 20.000 IDOF.OTR1 3.000 IM~F.DTR1 I!RD.DTR1 389.750 Ii~D.[)TR1 7).875 IIR~.DTR1 44~ .500 IIXM.DTR1 SFLI.~. DTRI 2.859 SP.DTR1 -22.203 GR.DTR~ 51.656 TENS.DTR% ~4mE~, DTR 1 76.~31 ~R~]'S. DTR ~ 2.8~7 HTEN.DTR~ -~93.125 DT.I,SRi DTI,.LSR1 116.100 D'fI.N. I,SR 1 li4.7U0 DTLF.bSR1 114.300 TTI.[,SRi TT~.LSRi 530.000 TT3.bSRI 996.400 TT4.bSR1 764.400 LTT1.LSR1 I~TT~. LSR I ~. 126.40(3 bTT3.bSR1 1564.400 LTT4.LSR1 1359.600 DF. pT. 4~00.Oo, 0 C[DP.OTR1 687.500 lbPH.IDBN ~.45] CIMP.DTRI I~PN. D'['Ri 1.6q6 CiLL). DTR 1. 726.000 ILD.DTR1 1.377 CILM.DTR1 IL~.D'P~i 1.684 IFRE.IFRE 20.000 IDGF.[)TR1 0.000 IMOF.DTR1 IIRD.~ .~1 546.000 IiXD.DTR] 100.375 IIR.g. DTR1 544 000 IIXM DTR1 SFb..~ DTR1 3 197 SP.DTR'I ';1,938 GR.DTR1 22:250 TENS.DTR~ NTE~.DTR1 76.859 ~'~RES. DTR 1 2.7~5 HTEN.DTR1 939.500 DT.LSR~ DT~ Lo 1 i03.70() DTI~N.bSR!, 106 100 DTLF b,,,R1 I00.700 TT2.[,,,~R1 o0~ 4,00 TT3.LSRt, 1006 400 TT4 LSR1 791 200 LTT~ LSR1 1118 t)00 bTT3 LSR1, 1509 600 [,,TT4 LSR1. 1312'000 DEPT 4335.500 CIDP.ii)?R1 gb! 500 IDPH.IDPH 1.0}9 CI~P.DTR1 ' ,, D.~I 1024:000 ILD, DTR1 0, g76 CIb~,~T~I I ~ P ~. D T R 1 1.092 C .I [., 0. "' Tb~ DTR1 1. 12'"' ]FRg I.. ~E 20 000 IDOF,DTR1 0 000 IMOF DTR1 II~.D.DTR1 724.500 [ I X.l.',,~. L~T R 1 1"'15: 500 I IRJ'q. OTR1 80], :000 IIXM.,DTR1 SF/,U DT,RI 2 836 SP LI.~I 68.688 GH [)TR1 31.188 TENS.DTR1 , . . ,'~ t g N. MT'E:~ DTRI 70 578 MRES DTR1 2.848 }" [)TR1 057.000 DT.LSRI. ¢ T [, ~ L e ........ b S R 1 125 000 T'I" 1. L S R 1 o R 1 126.800 ~) ~'' ' "'". ~, ,. ~,,..~r,~ LSR1, 125.200 DTLP. . TT?.LSRi 51S.400 TT3.LSR1 1110.600 TT4,LSR1 886.800 LTT1.LSR1 T'~ . TT . . 'T L ~ LS~I 1247.60C, L , 3 bS'Rl 1734 800 [,,~.,4 bSR1 1497.200 ** END UF DATA ** 478.250 478.250 2.000 35.938 1640,000 117.100 764.000 1352.000 589,000 593.500 0,000 37,906 3140.000 109,2.00 794.400 1310.800 915.000 890.500 0,000 ~7.813 3160.000 177 100 881 200 1501, 600 **** F 1' L,F: TN A I[,,ER FTLE ~:~A~E : EOIT .0 SEiRV.ICE : FblC VERS I0~t : 00!C01 DATE : 95/0]/27 ~AX REC 8'iZF; : ~02,4 FILF TYPE : bo bAST FILE : Fane verification [,isti, n~ ChlUmberger AlasKa Computinq Center 27-MA~-1995 11:]0 PAGE: 75 [%P EZ PL, r)R ATICIN [5A DA IV T. ~5 APl ~50-b29-22533 t,~ l 1., 0 C. A ************* 86MPI,,E RATE: 0.5 FT, ' 1E~,IEI.)IATE RI.,Ii,t) ,.~.A~ FIEI,D REPMAT PILE OF' '~,LIN ~.B (Ii''~'' ~'" ,DTR] PHASOR Ip, iDtJCTION TOOL ,!,)SR3 DIPOLE ,..qONIC I~AGF, R ,LDR~ LITHO DENe ,CNR~ CO~IPENSATED .r4LR3 i',"~ICROI,.,f'IG CAI..,]iPE~ rRLIN WITH .PTR] A~,IP .[')SR3 TOOL STRING) TYPE : CONS '1' U ,,'] ! v A !,, O D E F I C[,! ~<~P EXPt~,ORA,,~ION Company Name. F~i WIbDCAT Field N'ame API,~~, C 0 U ~; STAT N A T 1: $ 0 N P~AT E P [) LMF A P D EKB EOb FT ~T FT MT bADAM! #5 50-629-22533 3334'SNL g 4770'~EL 9~ NORTH ALASKA USA PUTNAM 629136 I C E P A Well Name API Serial Number Field bocation Section Township Range Coufity State or'Province ~atlon ~itness Name Servlce Order Number Permanent datum Elevation of Permanent Datum hog Neasured From Above Permanent Datum Eileva:tion of Kell~ ~u~hing Elevation of Oerr c loot Elevation oZ Ground Level IS Ta~e Yerification ].iistinO CblUnberqer .~%.lasKa Computinq Center 27-..'4AR-.I. gQ5 11:30 PAGE: 76 ThD VT l lb otal DePth - Dr 1 er TDI, Fq 11544, bLl F'I TI,I ?T 36, DFT COkE DF[> G/~3 1~.5 [)F P ~', 7, DFV S 76. DFL ~3 ~ST DEGF 06. ~MF,q 0~ 0,498 ~ FST DEGF 55, RuC.5 fl?{~.; 2.33 ~,~CST [)EGF 66. BaT DEGF 158. Total Depth - Logger Bottom Log Interval P Log Interval T°illing Fluid TY e Dr ~ Drilling Fluid De sity Drill~n~ Fluid Ph Drilling Fluid Viscosity Oril].img Fluid Loss ~esistlg~,tV of Mud Sample Mud Sample Temperature Resist! l~y of ~ud Filtrate S ~ud Filtrate Sample Temperatu Resistlvft¥ of Mud CaKe Sampl ~ud Cake Sample Temperature Bottom Hole Temperature mm#mm~mm~mmmmmmmmmm#m mm mm m m mmmmm~#mm~mmmmm~##mmmmmmmm~mmmmmmmmm~mmmmmmmmmmmmmmmm~mmmmmmmmmmmm~msm~! TIBI,E TYPF ,', CURV D.FPT D e p t h CTD.P TNDUCTI',ON D[f,E.P PHASUR '..(,)~[)UCTIVITY ,IDP~ INDUCTION DEEP PHASt)R RESISTIVITY CIt~)P IND~C'.I'ION MEDii. I'M PHAS~ COND[.ICTIVITY I~PH :INDUCi ..... ON' ~EDiU.~; PgaS(:)~ RESIS,I~.IVITY 8FhU SFI, Reslstivit, y Unavera~ed 8P $~ontaneous Potential GP Gam ~a Ray T E ~ S T e n s t o n MTE'" ~(]d Temperature M~E$ M,U~ Peststivtty H~,~ Head 'I'ens lor~ DPHI Denslty Porosity DBHO !)e 1 t.a PEF PhotoElectric Factor CII.,1 Cal. iDer GR Gamma Ray Tf:NS Tens NTE~ ~Ud Temperature ~ES ~dD Reslstiv!tv HTE~:, Head Tens ion N P}"J. ] N'eut. ro~ Porosit:yR '..I"NR~ Thermal ~,:e,~tron ,atio Calibrated CNfC Corrected Near Thermal CollDtS CFTC Corrected Far Thermal. Counts C ~. I.., I C a 1 i D e r DT2 DELTA-T SHEA[? UPPER I'.'~IPOI,E MODE CG ~Pi.,.,NSATED PP Polsson's Ratio IS q'a~e verif~cat, iom T, istin,~ Chlt.]mherqer /,lasKa Comput.imq Center PAGE: 77 ** DATA FORb~AT SPECTE'ICATI!Jb .~EC(JR[;' ** 1 66 0 2 66 3 73 1i6 4 66 1. 5 66 6 73 7 6b 8 68 0.5 9 65 FT I ~ 66 19. 1~ 66 14 65 FT 15 66 68 16 66 1. 0 66 ** SET TYPE- CHA · [: SERV u . SERVICE ID ORDER ~ i3 D F P T FT 629136 00 Cf. DP DTR3 ~tNHO 629136 00 IDPb DTR3 OH~b! 629136 00 CI~P DTR3 MSHO 6291~6 O0 I~P¢ DTR3 OHMN 629136 O0 SFL!~ DTR3 O~N~ 629136 O0 SD DTR3 MV 629136 0() G¢ DT~3 GAP1620136 O0 TENS DT~3 I,.,B 629136 00 NTEP DTP3 DEGV 62ql. 36 O0 ;'4DES DT~3 C}~ 629136 O0 BT E~; DT~3 LB 6291,~6 O0 DP},tT LDO.3 .PU 629136 O0 P .1. A P ':I OG TYPE CLASS 000 00 000 O0 000 O0 000 (.) 0 000 00 000 00 000 O0 000 O0 0 00 0 0 00 0 0 0 000 O0 (') 0 0 0 0 000 0 (,) 0 0 0 0 () 000 00 00 0 0 0 ~:} 00 00 0 00 0 0 0 00 0 0 000 O0 000 O0 (.) 00 00 O(,)u O0 000 0 0 DPHP LDR3 G/C3 629136 O0 PEF U!)R3 629:l. 36 O0 CAL.T LDR3 1N 629136 O0 GR LDR3 GAPI 629136 TFNS LDR3 LB 629136 O0 NTE~ LE'.,R3 DEGF 629136 00 N~EF, L[)a3 CiHa'~'~ 629136 O0 klg"Ek I,I)R3 LB 6291,36 O0 NP~II' CaR3 PU 629136 0 TNRg CaR3 629136 O0 CMTC CNR3 CPS 629136 O0 oC s ~ P I F i !', E ~,~ ~,~ t::~ N ti . I Z E R E P R P R S !q[)[) N:UNB SAMP EhEM CODE (HEX) . .. .... ..... ...... ...... .................. o 1.5 1 I 4600008 000000 0 15 I 1 4 68 0000000000 0 15 1. 1 4 68 0000000000 0 15 1 1 4 68 0000000000 0 1,5 1, I 4 68 0000000000 0 15 1 1 4 68 0000000000 0 15 1 I 4 68 0000000000 0 15 1. 1 4 68 0000000000 0 15 i 1 4 68 0000000000 0 15 I 1 4 68 0000000000 0 15 1, 1 4 68 0000000000 0 15 ! 1 4 68 0000000000 0 15 1 1 4 68 0000000000 0 15 1 1 4 68 0000000000 0 !,5 ! 1 4 68 0000000000 0 !5 1. 1 4 68 0000000000 0 15 1 1. 4 68 0000000000 0 1,,5 ! 1 4 68 0000000000 0 15 1 1 4 68 0000000000 0 15 1, 1 4 68 0000000000 O 15 1. 1. 4 68 0000000000 0 15 1 1 4 68 0000000000 0 !5 I. I 4 68 0000000000 0 1.5 1 I 4 68 0000000000 IS ~'aD~.? Yeri. ilcation [,ist,inq ch3..l~mber~!er ~\.lasKa Com[-~t]tinq Cer~ter PAGE: 78 ...... ............. ........................ --- r.~ 3 (:P~ o 6 o0 0 00 1 I 4 6 00000000 C~L,l ~ba3 I~ 629136 0o 000 O0 0 15 1 1 4 ~8 0000000000 DT4~~ I)S~3 I}$/F 62~1~6 O0 000 00 0 15 1 1 4 68 0000000000 9?2 DSR3 US/F 629136 O0 O00 00 0 15 1. 1 4 68 0000000000 P;* DSP3 620136 O0 000 mo 0 15 1 1 4 68 0000000000 DFPT. 9567.500 C]iDP.DTt{~ 151.5°3 IDPtt. DTR3 6.59R CI51P.DTR3 I~P~.DTR3 6,455 S?[..U. DTR 3 6.417 SP.DTR3 0.000 GR.DTR3 TFi~S.DTR3 4,i85.000 ~ITE~',i. DTR 3 130.834 ~RES. DTR3 1.330 HTEN.DTR3 DPhI.L[)~3 -999.25o ORHO.LDR3 -999.250 PEF.GOR3 -999.250 CALI.LDR3 GD I.DR3 99q.250 E~IS. L,)R3 -999.~50 ~,ITE~4 . LI)R 3 999.250 ~'4RES. LDR3 HTB;N. I,DR3 -999.250 r,~P H I .CNR3 -999.250 TNRA.CNR3 ~999.250 CNTC.CNR3 CFTC.C~P3 -999.25o CALI. ~,~!.JR ~ 8.929 I'.)T4P. DSR3 82.352 DT2.DSR3 PR. DSR3 0.31. ]. DEP'r. 0400.000 CIDP. I,)TR3 157.344. IDPH.DTR3 6.355 CIgP.DTR3 I~4P~.DTR3 6.373 SFI,U.DT~3 6.629 SP.DTR3 1.063 GR.DTR3 TF~$.DTR3 61,15,00(,} ~iTEa. t)TR3 130.~20 ~RES, })TR 3 !.3~7 HTEN.DTR3 DPHI .LDR3 6.385 DR[,10, LDR, 3 0.0i4 PEF.LDR3 3.135 CALI. I..,DR3 G~.LDR3 BB.Tz?7 T[i;NS. LDR3 5945.000 ;,,~TB~i~4. LDR 3 138 ~12 ~tRES. [,,,DR 3 HTL~:. I(,~DR 3 635.839 ~:l:PH i. C~i~3 30.283 TNRA'CNR3 3~011. CNTC.CNR3 CFTC. ~'~m3 858.S01 CAt, I.~LR3 13.!24 DT4P,DSR3 80 535 DT2.DSR3 PI~',D5~3 0.2~5 DEPT. 9387 000 CiDP t)TR3 -999.250 IDPH LIR3 -999.250 CI~P.DTR3 ""' I',>T R 3 -999.250 S,P, DTR3 -999.250 GR DTR3 i ~t[,"H. DTR 3 -999.25{) ,,,>~ LU, , . TENS.DTR3 -999.250 ~iTE~i. DTR3 -999.250 ~RF, S..0TR3 -999 ~50 HTEN.DTR3 D P H 1. L [> ~i .3 3.754: D ~:';~ H O. b D R 3 0.046 P E F. 1., O R 3 3 ~~ 09 C h b I. L D R 3 GP.LI) R3 92 126 ]E~S, 5DR3 5785.0V0 ~,l'Eh.bOR3 138 0(,)1 aRES LDR3 BTE~., LDR3 51.4 5~ ~:~ P H I , C ~,,~ R 3, 29 ,459 'r. hRA' , CNR3 2 ,957, CNTC . CNR3 CFTC~CNR3 859~479 CALi. ~I,~a3 -999.250 OT4P.DSR3 -999.250 DT2.OSR3 PP.~SR3 -999,250 154.91.4 77.429 -90.345 -999.250 -999.250 -999.250 157.317 156.918 788 072 108:236 13.482 1..200 ~527.455 148.713 -999.250 -999,250 -999,250 ~3.502. ~,.195 2491..159 '999.250 **** FILE T~{~ I LEP, SB:RV IC:~ : Pl.,lC VERSiO~ : 00!.C01 DAT~7 : 95103127 ~,'tlX REC SIZE : 1,024 IS Tape Verf..~!cation I, ist.tnq chlun, berqer Almsk'a Com~,ut.ino Center FTLF N A ,~ E V~?~S IOa : nO1CO1 DATF : MA~ REC STZE : ~0'24 FI [.,F TYPE LIST FI[,E : 27-~-~hR-],gq5 1, I130 PAGE: 79 EDIToOI6 RATE: 0.1.667 F'T. R~' FIEI,D REPEA? FILE OF !4[JN #3 (INTERi'~Ei)IATE RUN) , b~I.,a 3 ~ T C~OL[-J¢; TUOI~ T~BI,E TYPE : CONS TIlN I VAt,,U DEFI CN BP EXPLORATION Company Name FN WN APl N SECT STAT $0 N PDAT EPD APl) E~ B EDF E ~ L T D TDL TI,,, I FT ~T ~T FT FT '~;I bPCh T bADA~4I ~5 50':629'22533 3334'SNL, & 4770'WE6 20E NORTii SLOPE AI..,ASKA bSA PUTNAM t:~291, 36 iCE PAD 34, 3S. 33, 1'{ 549, 36, Field Name ~ell Name AP1 Serial Number Field t, ocatlon Section. Township Range County Stal~ or Prov~nce Nat n Wltnes~ Name Service Order Number Permar~ent datum Elevation of Permanent Datum bog Measured From Amore Permanent Datum Elevation of Kelly Bushin~ Elevation of Derrick Floor Elevation of Ground Level Total Depth- Driller Total Depthi bogg~r BOt.'tom .i..~Oq I terv~l TOp IS ~are Ver~f.i. cetior, l_,istlnq ChllU~berg!er h].ssk'o Co~put. i. nq Center 27-~',AP-19q5 i 1:30 PAGE: 80 DFD G/C3 12.5 DFPU 7. DVV S 76. MST DE',GF 66. R~FS (1HM ~,, 0,496 N,F'ST DEGF 55. R~C5 OHMH MCST DEGF 66, BWT DEaF 158, Oril].inq Fluio Density Drilling Fluid Ph Ori, llln~ FlulO Viscosity Prillin~ Fluid boss ~esisttgtty ot Mud Sample ~ud Sample Temperature ResistiVitY of Mud Filtrate s ~ud Filtrate Sample Temperatu Resistivity o~ Mud CaKe Sampl Mud Cake Sample Temperature Bottom Hole Temperature TABI,L ']i'YPFi : C'URV 2 66 0 3 73 12 4 66 5 66 6 73 7 65 8 68 O, 166 1,1 66 85 13 66 0 1.4 65 1,5 66 66 16 66 I 0 66 ,l IS Tape ~erif.lcatton. !,ist~n~ ch].t~nberqer [~lasKa Comk, utlno' Center 27-MAR-1995 11:30 PAGE: DEPT FT 62~13e 00 000 00 0 16 1 1 4 68 0000000000 ~,!I~V ~'L~3 ON~,'~ 62913e, O0 000 O0 0 16 1 1 4 68 0000000000 ~J(3K' ~L~3 OH~,I~,~ &2~136 O0 O0o O0 0 16 1 1 4 68 0000000000 81 DFpT. q567.83z.~ ~,INV. ,~[,R 3 -99q.250 MNOR.MLR3 -99q.250 D~PT. 9400.00(: t~ i t,;V. a[,~ 3 4.917 gNO~, ~'~LR3 4.361 DFPT. 0398.500 ~iNV, MI,.,R 3 -~99.250 MNOR.MLR3 -999.250 END [lw DATA **** FILE TRA I I~,ER 8EPV.ICE : FLIC V~RSlON : oo~col DAT~7 : 95/03/~7 t4,aX RFC SIZE : 1074 FILF TYPE : LO L~ST FILE : **** TAPE DAT[; : 95/03/~7 OP',I ~ 1N : FL!C T/P~ NA~4E : 95090 PREVIOUS TAPE : COM~IEh/T : BP E'XPI.,ORATiON, WILDCn. T, t:'~lDa,~..!l ~5, 50-629-22533 **** REE!, TRAILEP. *.*** SERVICE NI~.~E : EDIT [)ATF : .95/03/~7 OPI~IN : FLIC REEl, NA~E : r~5090 CONTI, NUATI[3~ ~ : PREVIOUS REEL : RECEIVED .APR 1 0 1995 CUMPANY I',~A~E .,' BP E:XPI,t','i.~RATION WELL ~.,!~N[': : BADA~I #5 BOROUGH : NORTH ELOPE STATE : AL~SK, A: ApI NU~E~ : 50-629-22533 REFERE~CE NO ~ 95090 IS ~,'a~e Yeriflcotion l,istJn~ ChlU,mberger AlasKa Co~,putinO Center 26-5;AR-1995 i6:0] PAGE: **** F!L~ }..lEADER F~bF NA~E : EDI:I ,00] $~RVlCE : FbTC VERSiO~ : O01A10 [).~ TE : 95/03/26 MAX R~C SIZE : F I ],.~F TYPE : LaS~ ~ILE ** ** SCHLI.INBEPGER GEOOUEST ** ** bOCAT!ON: 3334:'8Nb & 4770'WE, RANGE: 2.0E PERP~.ANENT t)ATI~,~: ICE PA[) E!.,.FVATIOb': LOG MEASURED [,"ROF~ I~,~ 34' IS Zar, e YerI£icati. on T,ist, ir~o chlUm~:erq~r Alaska ComDutJnc~ Cent. er 16:01 E~,EVATI .~NS KD: 38' DF: 33' GL: 4.1' LO, GG I ~aG DISTRICT: I,,.r.~GG I ~'G E~JGI NEMP,: J. W1TN~SS: T. PUTNA~ ************************************************************************ D~TE LG~G~D: ~-~,~AR- 1995 TD DPI[,LER: 1154o' T~ [.,(.)~GER: 11544' C~,SING ]: 0.625" ~ [)RI[:LEO, [)~PT[! OE 9578' mIT SIZE ~: ~,5" (~ TYPE FbUiD IN M~OLE': CORE DENSITY: 12,5 PH: 7 FI.,UItD LOSS: 4.6 SCBI,,U~BERCER GEDQUEST dO£~ REFFREkCE r,',O: 95090 TFCHI',~TCTAN/ANALYST: }~, KRUwEL!, STGNIF!C,ANT REf<~A P, KS: 1,)ALL DATA HAS BEEN SPEED Cf?.PRECTED 2.)..P,,I~ECTTONAL DATA }lAS EtF'EM COPRECTE~D FOR 30 DEGRE';E& MhGN~TIC DECLINATION 3,)DIP CHANNELS OUAF SSi.), DPAZ.~SD, A~D DPIR L~SD AF~E OUTPUT CHANNELS FR[:3t~ T[~E t~t~h~,t S{][.]~g DIP PPOc~}SsI~G ~,ETpi06 USING h 4' WINDOW wITH A 2' SLIDING STEm ~ND 35 [')EG~EES ~ SEARCU ANGLE, PAGE: 2 TABLE TYPE : CONS TUNI VAbU DEFI CN BPEXATi~'pDOr. ~ Compan~ Name Field Name FN W IbDC AT WN BAD,bI1. ~5 APi~.I 50'629'22533 F'I, 3334'S.N1., & 477(.,'~E[., T ~ W M 9 N COliN ~:ORTH ~LOPE STAT ALASKA ~ T l U S A SON 6291 36 [:, [~ a T I C E:; P A b EPD F'T 4. APD ~T 3~. E~B VT 38. EDF FT 3,3. Well Name API Serial Number Field Location Sectlom Township Range County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum boq ~easur'ed From Above Permanent Datum Elevation of K.,ll¥ Bushin~ Elevatiom of Derrick Floor IS Tape YeriiIcation Listtnq ChlUmher0er AlasKa Core,ut. thO Center 26-~,~' AP- 19. 95 16:01 TDD FT 11549. TDL FT t1544. B[,I FT 1~378. TLI FT 9588. DFT CORF DFD n/C3 DF'PH 7, DVV $ 76. DFL F3 4.0 MST DEGF 66. R~FS OH~ (3.498 ~FST DEGF 55. R~CS OH~ 2.33 ~CST DEGF 66. BHT DE(;F 158, Total Depth - Driller Total Depth - Loqger Bottom Loq Interval ~o~ t, oa Interva~ 1. r llnq Fl. ui~ Type Drilling Fluid Den$it~ Drlllinq Fluid Ph Drlllinb Flui~ ViSCOSity Drlllin6 FlUid Loss Reslstl~ity oi !~ud Sample ud Sa~:ple TemDerature .esistlvttv oi ~ud Filtrate S ~ud Filtrate 8ample Temperatu Resistivity of Mud CaKe Sampl ~ud Cake Sammle Temperature Bottom Hole Temperature T~BI.,E TYPE : CURV DEF I D~PT Depth DDTD DiD True DDA~ DiD ~zlmuth OUAF ~ualit¥ ~actor (SHDT) C~ Caliper ~. - 3 C~ Caliper 2 - 4 DEV! Hole Deviation H~ZI Hole Azimuth P~AZ Pad 1 aztmut~ . ~ ' AT ** D^'PA FORMAT SP,,,,CIFIC ION Riif~COPD ** ** SET TYPE - 64EB ** T:YD~; R~PR COD~] VAbUE ], 66 2 66 3 73 4 6 6 5 66 6 73 7 65 8 73 9 65 0 36 IS ~'ape Verification List,.tnq chlumherqer ~lask, a Compt]tlnc] Center 26-~AR-1995 16:O1. PAGE: T Y P b; _ E m 11 66 ,. 1~ 68 13 66 0 14 65 ~'% 15 66 6~ 16 ~6 1 () 66 0 ** SET TYPE N~H ~V Uh~IT -E . nRDE D~P? ~'~ 62c~. DPT~ MSD LEG 6291 DPA7 ~$n LEG 6291 OUAF ~$h 62Ol C1 Fi~I IN 6291, C2 Fi,il' IN 6291 D~VT F~I LEG 6201 H~ZT FMI LEG 6291 B~&.~ - CNAN ** ......... ' R ¢ LO(; TYPE CLASS NOD Nti~B SA~P EbE~ CODE [HEX) 00 00 0 0 1 1. ,, 68 0000 36 O0 000 O0 0 I 1 1 4 68 0000000000 36 0(} 000 O0 0 i 1 1 4 68 0000000000 36 O0 000 O0 O I ! ! 4 68 0000000000 36 O0 000 O0 0 1 1 1 4 68 0000000000 36 00 000 00 0 1 1 1 4 68 0000000000 36 O0 O00 O0 0 1 ~, ! ~¢ 68 0000000000 30 O0 000 O0 0 1 1 I 4 68 0000000000 0 1 I 1, 4 68 0000000000 ** DATA ** DEPT. 11378.00(} DPTR.MSL) C!.FM! 8.128 C2.F*~I PI, AZ.FMI 27~.3f)5 -999. 250 £PAZ') ' . MSD -999 . 250 OUAF . MSD 9.069 f}EVI"' " .'FMI 36.041 HAZI.FMI 8.509 DJ, A~.MSD 112 314 Ol,,l A F 8 994, r')EVI ,Fn! ,'16162 · .... "~ ~, · ~ .t~ 14.396 8.711 DPAZ 4SD 59 32(i OUA. F.MSD DEVZoF'MI 37~067 HAZI.FSI 8,129 DPAZ,~4SD 1.12 938 OltAF.MSD 9.900 DEVI.FMI 37~481 :HAZ!.FMI 6.868 9.06I DPAZ. ~!SD :1,49 256 QUAF,MSD -999,250 26,673 2 000 2sis44 000 20,000 25.29'7 20.000 24,965 15.000 25,841 IS ?a~,.e Yet~~fi. cation ;0Jstln~ cblt.lmber,.]er Al. asKa Con, p~atipa Center DFipT. 10800. Pl AT,. F~,~ I 305. D F P T. I 0 '700.0 o 0 D P w R. ~ S D DEPT. 10600.0o0 DPTR. C!. F'~iI 9.037 C2. F;.!I P~ ~,. W.~ ! 302.505 DFPT. 10500.00o C.i. FNI 8. 862 C2. P! A%.FF~.I 305.7?8 DFPT. 10400.000 DPTR.NSD C~ .WN! 9.247 P 1 AZ. F;,'i ! '30 ~. 72~, DFpT. 10300. O 9 () D P"I'R. CI. F!q .T.' 9.24,2 pl AZ.FreT 305.545 DEPT. 10200.000 DPTR.HSD ¢1 .lrNI 9.369 C 2. Fl~,"l I P !/~. 7,,. F'~I! ,$10. 625 DFPT. 10100.000 DPTW. A'~SD CJ .W~! 9.2~4: C2. F'NI P.1 ~%. WRY!! 312.428 p 1/1%. FYtI 307.46(, DEPT. 9900.000 DPTR. ?~,SD CJ. FN '.15 9,597 P~,AZ. F!gl 31,9. 560 DFPT, 9800.000 DPTR. N SD C1. Fi41 9.2}~2 f-'2. F~I P! AT.F'i'47 305,811 DEPT, 9700.000 b ~>TR , t,'tSD C~..wtqI 9. 259 C2, F'b~I pl ~.Z, . F'?, ! 3!., 1. 171. DE'~ PT. 9600.0{.)G r)p T (-.~. ?lSD }:'1 ./~?. Fi'.'; T 295.4'.~5 16:01, 5.058 DPAZ.~,tSD ~.923 DP~Z.~SD 10.392 DFt¥I.~'Mi 0.944 DPAZ.{qSD 21.6~7 DPAZ.!4SD 12,035 DEVI.~'gI 14.080 DPAZ.NSD 1~.417 BEVI.F~I 9.313 DPAZ.MSD 1.2.178 OEV!.FNI 17.757 DFAZ.NSD 12.282 DEVI.F}II 5.~25 DPAZ.MSD 11,.867 DEVI.F~:II 6.ii3a DPAZ.aSD 11.997 DEVI.?'MI 19.1i6 DPAZ.MSD 12.453 DEVI.FgI 14.477 DPAZ.fqSD 12.]~2 DEVI.F~I 6.825 DPAZ,[48D 11.996 DEVI.FaI 13,:.832 DPgZ.iqSD 12.31~, DEVI,FMI 14.147 39.655 49.673 39.919 3.63.277 39.990 154.130 40.507 207.61] 39.541 75.9]3 38.520 84.284 37'715 222 817 75.880 35.40~ 72 881 ~,, 05:207 a 19vs 56.004 3~,.372 OUAF.~$D OUAF.MSD }tAZT.FMI OUAF.M$D OUAF.USD OUAF. ~SD OI. IAF.MSD HAZI.FMI OlJAF.~SD B.~ZI.FMI Qt]A.F'.NSD HAZI.FMI OUAF.MSD HAZI.FMt Ot,IAF.MSD BAZ!.F~q,I QUAF.~$D QI,,iAF.~SD OI. Jhlr . PAGE: 20.000 26,046 19,000 26.044 20.000 27.328 2.000 27.482 2.000 27.882 14.000 28.149 15,000 28.420 15,.000 28.8,30 1,2.000 29,284 14,000 29.478 1,2,.000 29.802 19.000 30.551 8,000 29,206 IS Tar>e Verification Listing. chlumberoer AlasKa Con:put~n~ Center 26-~&~-1995 16:01 PAGE: DE:PT. qS.RS. 500 r~.PTR. P! AT,. FM! -999.25a UUAF.MSD 30.463 HAZt.F,~I -999.250 ~6.763 ~ EN~) OF DATA ** SFRVICE ~ VERSiO;q : O0!nlO [)~,TF : ~l~X RRC STZR : !024 LnST Ft[,E [)ATE : 95/{i3/26 OPlC[N : FL~[C REEL ~A~IE : 05090 C~NTINU~TI[]N ~ : .... ' ~ ~' BADA~',~I ~5,50-62~-22533 LIS VERIFICATION LISTING FOR: BP EXPLORATION BADAMI #5 BADAMI WILDCAT BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR BP EXPLORATION BADAMI #5 BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS Note: Bulk Density Compensated [RWD] Bulk Density Time Since Drilled [RWD] Bulk Density Data Density Integrated [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Density Long Space Apparent [RWD] Photoelectric Cross Section [RWD] Density Porosity (LS) [RWD] Density Porosity (SS) [RWD] Delta RHO - Density [RWD] Gamma Ray Memory (APl) [RWD] Neutron Far Base [Base] Neutron Near Base [Base] Neutron Porosity Time Since Drilled [RWD] Neutron Porosity Data Density Integrated [RWD] Neutron Porosity (LS) Borehole Corr [RWD] Neutron Porosity (SS) Borehole Corr [RWD] Neutron Porosity Ratio Borehole Corr. [RWD] Phase Difference Base [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] Subsea True Vertical Depth CDS Temperature [RWD] Surface Weight On Bit AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling g/cc mins pts mmholm mmholm g/cc Ble p.u. p.u. g/cc MWD-API cps cps mins. pts p.u. p.u. p.u. deg deg mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m ff deg F klbs Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 30 MAR 95 7:33a ~== ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = I , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = l , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: O--depth units l=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX -- 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRiTETAP = I , ! Write Tape-Image File: 0=NO, I=YES 12 SPLITLIS = I , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES =/0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END ~== USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = I , LISTMETHOD = 0 , LISTFREQ = 50, LISTMAX = 0 , STATS = 0 , FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES =/0/, INTERPOLATE='YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ~ !-- CONSTANT PARAMETERS ........................................... AUTOCURV= 0.000000E+00 AUTOFILE= 0.000000E+00 COMMENTS= 1.00000 FORCETYP= 0.000000E+00 INFORECS= 1.00000 LISTFREQ= 50.0000 LISTMAX = 0.000000E+00 LISTMETH= 0.000000E+00 SELFTEST= 0.000000E+00 SPLITLIS= i.00000 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 WRITETAP= 1.00000 dpcoef = !.00000 dpcte = 1.00000 drlength= 0.000000E+00 listwave= 0.000000E+00 maxrecln= 0.000000E+00 minrecln= 0.000000E+00 nsamples= 0.000000E+00 numcurvs= 0.000000E+00 numdatar= 0.000000E+00 numrecfl= 0.000000E+00 tfendep = 0.000000E+00 tflevsp = 0.000000E+00 tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 wcrlevsp= 0.000000E+00 wcrtop = 0.000000E+00 !-- ARRAY PARAMETERS .............................................. SUBFILES(1) = SUBFILES( 3) = SUBFILES( 5) =-9999.00 SUBFILES( 7) =-9999.00 SUBFILES( 9) =-9999.00 SUBFILES(11) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES( 21) = -9999.00 SUBFILES(23) =-9999.00 SUBFILES(25) =-9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES( 31) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES( 41) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(47) =-9999.00 SUBFILES(49) =-9999.00 SUBFILES( 51) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(57) = -9999.00 , SUBFILES(59) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(65) = -9999.00 0.000000E+00 SUBFILES(2) =-9999.00 -9999.00 SUBFILES( 4)=-9999.00 SUBFILES( 6)=-9999.00 SUBFILES(8) = -9999.00 SUBFILES(10) = -9999.00 SUBFILES(12) =-9999.00 SUBFILES(14) =-9999.00 SUBFILES(16) =-9999.00 SUBFILES(18) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) =-9999.00 SUBFILES(30) =-9999.00 SUBFILES(32) =-9999.00 SUBFILES(34) =-9999.00 SUBFILES(36) =-9999.00 SUBFILES(38) =-9999.00 SUBFILES(40) =-9999.00 SUBFILES(42) =-9999.00 SUBFILES(44) =-9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) =-9999.00 SUBFILES(58) =-9999.00 SUBFILES(60) =-9999.00 SUBFILES(62) =-9999.00 SUBFILES(64) =-9999.00 SUBFILES(66) =-9999.00 SUBFILES(67); -9999.00 SUBFILES(68): -9999.00 SUBFILES(69) ---9999.00 SUBFILES(70) ---9999.00 SUBFILES( 71) -- -9999.00 SUBFILES(72) -- -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) -- -9999.00 SUBFILES(75) =-9999.00 SUBFILES(76) = -9999.00 SUBFILES(77) -- -9999.00 SUBFILES(78)-- -9999.00 SUBFILES(79) -- -9999.00 SUBFILES(80) -- -9999.00 SUBFILES( 81) = -9999.00 SUBFILES(82) -- -9999.00 SUBFILES(83) -- -9999.00 SUBFILES(84) -- -9999.00 SUBFILES(85) -- -9999.00 SUBFILES(86) -- -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) ---9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) -- -9999.00 SUBFILES( 91) -- -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) -- -9999.00 SUBFILES(94) = -9999.00 SUBFILES(95) -- -9999.00 SUBFILES(96) = -9999.00 SUBFILES(97) -- -9999.00 SUBFILES(98) -- -9999.00 SUBFILES(99) = -9999.00 SUBFILES(100) -- -9999.00 SUBFILES(101) = -9999.00 SUBFILES(102) -- -9999.00 SUBFILES(103) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(106) -- -9999.00 SUBFILES(107) = -9999.00 SUBFILES(108) -- -9999.00 SUBFILES(109) -- -9999.00 SUBFILES(110) = -9999.00 SUBFILES(111) ~ -9999.00 SUBFILES(112) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(115) -- -9999.00 SUBFILES(116) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(118) -- -9999.00 SUBFILES(119) ~ -9999.00 SUBFILES(120) -- -9999.00 SUBFILES(121) -- -9999.00 SUBFILES(122) -- -9999.00 SUBFILES(123) -- -9999.00 SUBFILES(124) -- -9999.00 SUBFILES(125) = -9999.00 SUBFILES(126) -- -9999.00 SUBFILES(127) = -9999.00 SUBFILES(128) -- -9999.00 ~-- STRING PARAMETERS ............................................. INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: C:\DATA\I415\1415.TAP (Output Tape-Image file will be created) Listing Method CLISTMETH") = 0, Depth Unit oriented listing. Listing Frequency CLISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS=I to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=ri" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= I to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC=I) Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS # WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 6 JOB NUMBER: 1415 LOGGING ENGINEER: OPERATOR WITNESS: Badami #5 50-629-22533 BP Exploration (Alaska) Inc. BAKER HUGHES INTEQ MWD RUN 7 MWD RUN 8 1415 1415 J. BURTON K. GILBERT J. BURTON M. WHITELY M. WHITELY M. WHITELY MWDRUN 9 MWDRUNI0 MWDRUNll JOB NUMBER: 1415 1415 1415 LOGGING ENGINEER: T. BROCKWAY J. BURTON T. BROCKWAY OPERATOR WITNESS: N. SCALES N. SCALES N. SCALES MWD RUN 12 MWD RUN 13 MWD RUN 14 JOB NUMBER: 1415 1415 1415 LOGGING ENGINEER: J. BURTON T. BROCKWAY J. BURTON OPERATOR WITNESS: N. SCALES M. WHITELY M. WHITELY SURFACE LOCATION SECTION: TOWNSHIP: 9N RANGE: 20E FNL: FSL: 1936 FEL: 4878 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 35.65 DERRICK FLOOR: 34.65 GROUND LEVEL: 4.25 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) IST STRING 16.000 13.375 4495.0 2ND STRING 12.250 9.625 9578.0 3RD STRING 8.500 PRODUCTION STRING # REMARKS: NO DEPTH SHIFTING PERFORMED ON FILE. Tape Subtile I is type: LIS **** REEL HEADER **** MWD 95/3/30 01 **** TAPE HEADER **** MWD 95/3/30 1415 01 Tape Subtile: 1 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ALL DENSITY DATA ACQUIRED WHILE ROTATING. **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 6168.0 11549.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 6168.0 7768.0 MWD 4 7768.0 9142.0 MWD 5 9142.0 9528.0 MWD 6 9578.0 9578.0 MWD 7 9578.0 10368.0 MWD 7 10368.0 10520.0 MWD 7 10520.0 10974.0 MWD 11 10974.0 11105.0 MWD 12 11105.0 11549.0 $ # REMARKS: CN : BP Exploration (Alaska) WN : Badami/t5 FN : Wildcat / Delineatio COLIN :North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 12 13 14 15 16 000 1 0000000 I 000 I Rep Code Count Bytes 68 12 48 Sum: 12 48 48 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: APl API APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 RHOBMWD 68 IG/C3 4 4 98 660 71 6 PEF MWD 68 I BN/E 4 4 98 660 71 6 DRHOMWD 68 IG/C3 4 4 98 660 71 6 GR MWD 68 I GAPI 4 4 98 660 71 6 FCNTMWD 68 I CPS 4 4 98 660 71 6 NCNTMWD 68 1 CPS 4 4 98 660 71 6 NPHIMWD 68 I PU-S 4 4 98 660 71 6 RA MWD 68 I OHMM 4 4 98 660 71 6 ROP MWD 68 I FPHR 4 4 98 660 71 6 RP MWD 68 I OHMM 4 4 98 660 71 6 TEMPMWD 68 I DEGF 4 4 98 660 71 6 WBCSMWD 68 I LB 4 4 98 660 71 6 48 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 19 FRAMES * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 567 Tape File Start Depth = 6168.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18804 datums Tape Subtile: 2 659 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is ty. pe: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 6168.0 7768.0 $ LOG HEADER DATA DATE LOGGED: 4 FEB 95 SOFTWARE SURFACE SOFTWARE VERSION: 2.13 RO DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 6168.0 BOTTOM LOG INTERVAL (FT): 7768.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 32.5 MAXIMUM ANGLE: 36.1 # , TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ 2.13 RO MEMORY STOP DEPTH BOREHOLE CONDITIONS MUD TYPE: LSND BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): .0 TOOL NUMBER 1738-90 MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COUN : North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 3. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(I) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213 1415 16 000 1 0000000 I 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F .~.~ Curves: Name Tool Code Samples I BDCM MWD 68 2 BDEM MWD 68 3 BDIMMWD 68 4 CADEMWD 68 5 CPDEMWD 68 6 DCCM MWD 68 7 DLAM MWD 68 8 DPEM MWD 68 9 DPLM MWD 68 I0 DPSMMWD 68 11 DRHMMWD 68 12 DSAMMWD 68 13 GRAMMWD 68 14 NFBMMWD 68 15 NNBMMWD 68 16 NPEMMWD 68 17 NPIMMWD 68 18 NPLM MWD 68 19 NPSM MWD 68 20 NRCMMWD 68 21 PDBM MWD 68 22 PDCM MWD 68 23 PDEM MWD 68 24 PDIM MWD 68 25 RACMMWD 68 26 RADEMWD 68 27 ROPA MWD 68 28 ROPSMWD 68 29 RPCMMWD 68 30 RPDEMWD 68 31 STVDMWD 68 32 TCDMMWD 68 33 WBCSMWD 68 APl APl APl APl Log Crv Crv Units Size Length Typ Typ Cls Mod I G/CC 4 4 98 660 71 6 I MINS 4 4 98 660 71 6 I PTS 4 4 98 660 71 6 1 MMHO 4 4 98 660 71 6 1 MMHO 4 4 98 660 71 6 I 4 4 98 660 71 6 I G/CC 4 4 98 660 71 6 I B/E 4 4 98 660 71 6 1 PU 4 4 98 660 71 6 ! [U 4 4 98 660 71 6 I G/CC 4 4 98 660 71 6 I G/CC 4 4 98 660 71 6 I GAPI 4 4 98 660 7l 6 I CPS 4 4 98 660 71 6 I CPS 4 4 98 660 7l 6 1 MINS 4 4 98 660 71 6 I PTS 4 4 98 660 71 6 I PU 4 4 98 660 71 6 1 PU 4 4 98 660 71 6 I RATI 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 I MINS 4 4 98 660 71 6 I PTS 4 4 98 660 71 6 I OHMM 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I FPHR 4 4 98 660 71 6 I FPHR 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I OHMM 4 4 98 660 71 6 I FT 4 4 98 660 71 6 I DEGF 4 4 98 660 71 6 1 LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 915 Tape File Start Depth = 6168.000000 Tape File End Depth = 7768.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 37554 datums Tape Subtile: 3 980 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 7768.0 9142.0 $ LOG HEADER DATA DATE LOGGED: 7 FEB 95 SOFTWARE SURFACE SOFTWARE VERSION: 2.13 RO DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 2.13 RO MEMORY TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 7768.0 BOTTOM LOG INTERVAL (FT): 9142.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 30.7 MAXIMUM ANGLE: 35.4 STOP DEPTH BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND 12.250 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1738-90 MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 950 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COUN : North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 4. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(I) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 12 13 14 15 16 000 I 0000000 1 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F Curves: Name Tool Code APl APl APl APl Log Crv Crv Samples Units Size Length Typ Typ Cls Mod 1 BDCMMWD 68 I G/CC 4 4 98 660 71 6 2 BDEMMWD 68 1 MINS 4 4 98 660 71 6 3 BDIMMWD 68 1 PTS 4 4 98 660 71 6 4 CADEMWD 68 I MMHO 4 4 98 660 71 6 5 CPDEMWD 68 I MMHO 4 4 98 660 71 6 6 DCCMMWD 68 I 4 4 98 660 71 6 7 DLAMMWD 68 I G/CC 4 4 98 660 71 6 8 DPEMMWD 68 I B/E 4 4 98 660 71 6 9 DPLMMWD 68 I PU 4 4 98 660 71 6 10 DPSMMWD 68 I [U 4 4 98 660 71 6 1l DRHMMWD 68 I G/CC 4 4 98 660 71 6 12 DSAMMWD 68 1 G/CC 4 4 98 660 71 6 13 GRAMMWD 68 I GAPI 4 4 98 660 71 6 14 NFBMMWD 68 I CPS 4 4 98 660 71 6 15 NNBMMWD 68 1 CPS 4 4 98 660 71 6 16 NPEMMWD 68 I MINS 4 4 98 660 71 6 17 NPIMMWD 68 1 PTS 4 4 98 660 71 6 18 NPLMMWD 68 I PU 4 4 98 660 71 6 19 NPSMMWD 68 1 PU 4 4 98 660 71 6 20 NRCMMWD 68 I RATI 4 4 98 660 71 6 21 PDBMMWD 68 I DEG 4 4 98 660 71 6 22 PDCMMWD 68 I DEG 4 4 98 660 71 6 23 PDEMMWD 68 I MINS 4 4 98 660 71 6 24 PDIMMWD 68 1 PTS 4 4 98 660 71 6 25 RACMMWD 68 1 OHMM 4 4 98 660 71 6 26 RADEMWD 68 1 OHMM 4 4 98 660 71 6 27 ROPAMWD 68 I FPHR 4 4 98 660 71 6 28 ROPSMWD 68 I FPHR 4 4 98 660 71 6 29 RPCMMWD 68 I OHMM 4 4 98 660 71 6 30 RPDEMWD 68 1 ©HMM 4 4 98 660 71 6 31 STVDMWD 68 1 FT 4 4 98 660 71 6 32 TCDMMWD 68 1 DEGF 4 4 98 660 71 6 33 WBCSMWD 68 I LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE// 0) 958 BYTES * Total Data Records: 786 Tape File Start Depth = 7768.000000 Tape File End Depth = 9142.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51065 datums Tape Subtile: 4 851 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 5 is type: LIS **** FILE HEADER **** MWD .004 1024 LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9142.0 9528.0 $ LOG HEADER DATA DATE LOGGED: 8 FEB 95 SOFTWARE SURFACE SOFTWARE VERSION: 2.13 RO DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 2.13 RO MEMORY TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 9142.0 BOTTOM LOG INTERVAL (FT): 9528.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 30.8 MAXIMUM ANGLE: 31.2 STOP DEPTH BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 BOREHOLE CONDITIONS MUD TYPE: LSND TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1738-90 MUD DENSITY (LB/G): I0. I0 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TEMPERATURE: .000 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 .0 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: INTERVAL FROM 5927 TO 5978 FT MD (8884 TO 8927 FT SSTVD WAS NOT LOGGED DUE TO TOOL OFFSET AT CASING POINT. $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COLIN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(I) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213 141516 000 1 0000000 I 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 3 ONE DEPTH PER FRAME Tape depth ID: F 33 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 BDCMMWD 68 I G/CC 4 4 98 660 71 6 2 BDEM MWD 68 1 MINS 4 4 98660 71 6 3 BDIMMWD 68 I PTS 4 4 98 660 71 6 4 CADEMWD 68 I MMHO 4 4 98 660 71 6 5 CPDEMWD 68 I MMHO 4 4 98 660 71 6 6 DCCMMWD 68 I 4 4 98 660 71 6 7 DLAMMWD 68 ! G/CC 4 4 98 660 71 6 8 DPEMMWD 68 I B/E 4 4 98 660 71 6 9 DPLMMWD 68 I PU 4 4 98 660 71 6 I0 DPSMMWD 68 I [U 4 4 98 660 71 6 11 DRHMMWD 68 I G/CC 4 4 98 660 71 6 12 DSAM MWD 68 I G/CC 4 4 98660 71 6 13 GRAMMWD 68 I GAPI 4 4 98 660 71 6 14 NFBMMWD 68 I CPS 4 4 98 660 71 6 15 NNBMMWD 68 I CPS 4 4 98 660 71 6 16 NPEMMWD 68 I MINS 4 4 98 660 71 6 17 NPIMMWD 68 I PTS 4 4 98 660 71 6 18 NPLMMWD 68 I PU 4 4 98 660 71 6 19 NPSMMWD 68 I PU 4 4 98 660 71 6 20 NRCMMWD 68 I RATI 4 4 98 660 71 6 21 PDBMMWD 68 ! DEG 4 4 98 660 71 6 22 PDCMMWD 68 I DEG 4 4 98 660 71 6 23 PDEMMWD 68 i MINS 4 4 98 660 71 6 24 PDIMMWD 68 I PTS 4 4 98 660 71 6 25 RACMMWD 68 1 OHMM 4 4 98 660 71 6 26 RADEMWD 68 1 OHMM 4 4 98 660 71 6 27 ROPAMWD 68 1 FPHR 4 4 98 660 71 6 28 ROPSMWD 68 I FPHR 4 4 98 660 71 6 29 RPCMMWD 68 I OHMM 4 4 98 660 71 6 30 RPDEMWD 68 i OHMM 4 4 98 660 71 6 31 STVDMWD 68 I FT 4 4 98 660 71 6 32 TCDMMWD 68 I DEGF 4 4 98 660 71 6 33 WBCSMWD 68 I LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 221 Tape File Start Depth = 9142.000000 Tape File End Depth = 9528.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 46690 datums Tape Subtile: 5 287 records... Minimum record length: 62 bytes Maximum record length: 958 bytes 32 Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9578.0 9578.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): STOP DEPTH 2.13 RO 2.13 RO TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 9578.0 BOTTOM LOG INTERVAL (FT): 9578.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 31.2 MAXIMUM ANGLE: 31.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S): 60.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 750 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 .000 .000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: INTERVAL FROM 9566 TO 9580 FT MD (8917 TO 8928 FT SSTVD WAS DRILLED WITH A 8 1/2 INCH BIT AND LOGGED AFTER SETTING 9 5/8 INCH CASING. INTERVAL FROM 9622 TO 9650 FT MD (8965 TO 8990 FT SSTVD WAS NOT LOGGED DUE TO A DOWNHOLE FAILURE OF THE RESISTIVITY/GAMMA SUB. $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COLIN :North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 6. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(I) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 I 0000000 1 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FI:LAME Tape depth ID: F oo Curves: Name Tool Code Samples I BDCM MWD 68 2 BDEM MWD 68 3 BDIMMWD 68 4 CADEMWD 68 5 CPDEMWD 68 6 DCCMMWD 68 7 DLAM MWD 68 8 DPEM MWD 68 9 DPLM MWD 68 I0 DPSM MWD 68 11 DRHM MWD 68 12 DSAM MWD 68 13 GRAM MWD 68 14 NFBM MWD 68 15 NNBM MWD 68 16 NPEM MWD 68 17 NPIMMWD 68 18 NPLM MWD 68 19 NPSMMWD 68 20 NRCMMWD 68 21 PDBM MWD 68 22 PDCM MWD 68 23 PDEM MWD 68 24 PDIMMWD 68 25 RACMMWD 68 26 RADEMWD 68 27 ROPAMWD 68 28 ROPS MWD 68 29 RPCMMWD 68 30 RPDEMWD 68 31 STVDMWD 68 32 TCDMMWD 68 33 WBCSMWD 68 APl APl APl APl Log Crv Crv Units Size Length Typ Typ Cls Mod I G/CC 4 4 98 660 71 6 1 MINS 4 4 98 660 71 6 1 PTS 4 4 98 660 71 6 I MMHO 4 4 98 660 71 6 I MMHO 4 4 98 660 71 6 I 4 4 98 660 71 6 I G/CC 4 4 98 660 71 6 I B/E 4 4 98 660 71 6 I PU 4 4 98 660 71 6 I [U 4 4 98 660 71 6 1 G/CC 4 4 98 660 71 6 I G/CC 4 4 98 660 71 6 I GAPI 4 4 98 660 71 6 I CPS 4 4 98 660 71 6 1 CPS 4 4 98 660 71 6 I MINS 4 4 98 660 71 6 I PTS 4 4 98 660 71 6 I PU 4 4 98 660 71 6 I PU 4 4 98 660 71 6 I RATI 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 1 MINS 4 4 98 660 71 6 I PTS 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I OHMM 4 4 98 660 71 6 1 FPHR 4 4 98 660 71 6 I FPHR 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I OHMM 4 4 98660 71 6 1 FT 4 4 98 660 71 6 1 DEGF 4 4 98 660 71 6 1 LB 4 4 98 660 71 6 132 * DATA RECORD (TYPE# 0) Total Data Records: I 142 BYTES * Tape File Start Depth = 9578.000000 Tape File End Depth = 9578.000000 Tape File Level Spacing = 0.000000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51100 datums Tape Subtile: 6 72 records... Minimum record length: 62 bytes Maximum record length: 824 bytes Tape Subtile 7 is type: LIS **** FILE HEADER **** MWD .006 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9578.0 10368.0 $ LOG HEADER DATA DATE LOGGED: 16 FEB 95 SOFTWARE SURFACE SOFTWARE VERSION: 2.13 RO DOWNHOLE SOFTWARE VERSION: 2.13 RO DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 9578.0 BOTTOM LOG INTERVAL (FT): 10368.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 30.8 MAXIMUM ANGLE: 38.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COLIN : North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 910111213141516 000 I 0000000 1 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 33 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 BDCM MWD 68 I G/CC 4 4 98 660 71 6 2 BDEM MWD 68 I MINS 4 4 98 660 71 6 3 BDIMMWD 68 I PTS 4 4 98 660 71 6 4 CADEMWD 68 I MMHO 4 4 98 660 71 6 5 CPDEMWD 68 1 MMHO 4 4 98 660 71 6 6 DCCMMWD 68 I 4 4 98 660 71 6 7 DLAMMWD 68 1 G/CC 4 4 98 660 71 6 8 DPEMMWD 68 1 B/E 4 4 98 660 71 6 9 DPLMMWD 68 1 PU 4 4 98 660 71 6 10 DPSMMWD 68 1 [U 4 4 98 660 71 6 11 DRHMMWD 68 1 G/CC 4 4 98 660 71 6 12 DSAMMWD 68 I G/CC 4 4 98 660 71 6 13 GRAMMWD 68 1 GAPI 4 4 98 660 71 6 14 NFBMMWD 68 I CPS 4 4 98 660 71 6 15 NNBMMWD 68 I CPS 4 4 98 660 71 6 16 NPEMMWD 68 I MINS 4 4 98 660 71 6 17 NPIMMWD 68 I PTS 4 4 98 660 71 6 18 NPLMMWD 68 1 PU 4 4 98 660 71 6 19 NPSMMWD 68 I PU 4 4 98 660 71 6 20 NRCMMWD 68 I RATI 4 4 98 660 71 6 21 PDBMMWD 68 I DEG 4 4 98 660 71 6 22 PDCMMWD 68 I DEG 4 4 98 660 71 6 23 PDEMMWD 68 I MINS 4 4 98 660 71 6 24 PDIMMWD 68 I PTS 4 4 98 660 71 6 25 RACMMWD 68 1 OHMM 4 4 98 660 71 6 26 RADEMWD 68 I OHMM 4 4 98 660 71 6 27 ROPAMWD 68 I FPHR 4 4 98 660 71 6 28 ROPSMWD 68 I FPHR 4 4 98 660 71 6 29 RPCMMWD 68 1 OHMM 4 4 98 660 71 6 30 RPDEMWD 68 I OHMM 4 4 98 660 71 6 31 STVDMWD 68 I FT 4 4 98 660 71 6 32 TCDMMWD 68 I DEGF 4 4 98 660 71 6 33 WBCSMWD 68 I LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES* Total Data Records: 452 Tape File Start Depth = 9578.000000 Tape File End Depth = 10368.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 65296 datums Tape Subtile: 7 517 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 8 is type: LIS **** FILE HEADER **** MWD .007 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10368.0 10520.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): STOP DEPTH 2.13 RO 2.13 RO MEMORY 20 FEB 95 TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 10368.0 BOTTOM LOG INTERVAL (FT): 10520.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 38.1 MAXIMUM ANGLE: 39.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: BLAND CORE MUD DENSITY (LB/G): 12.20 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 .000 .000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: INTERVAL FROM 10368 TO 10520 FT MD (9582 TO 9675 FT SSTVD) WAS LOGGED WHILE REAMING 80 HOURS AFTER BEING DRILLED DUE TO A FAILURE OF THE DOWNHOLE LOGGI'NG SUITE AND SUBSEQUENT CHANGE OVER TO CORING FLUID. $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7RR. * FORMAT REcoRD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 12 13 14 15 16 000 1 0000000 I 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 3 ONE DEPTH PER FRAME Tape depth ID: F 33 Curves: Name Tool Code Samples 1 BDCM MWD 68 2 BDEM MWD 68 3 BDIM MWD 68 4 CADEMWD 68 5 CPDE MWD 68 6 DCCM MWD 68 7 DLAM MWD 68 8 DPEM MWD 68 9 DPLM MWD 68 10 DPSM MWD 68 11 DKHM MWD 68 12 DSAM MWD 68 13 GRAM MWD 68 14 NFBM MWD 68 15 NNBM MWD 68 16 NPEM MWD 68 17 NPIMMWD 68 18 NPLM MWD 68 19 NPSM MWD 68 20 NRCMMWD 68 21 PDBM MWD 68 22 PDCM MWD 68 23 PDEM MWD 68 24 PDIM MWD 68 25 RACM MWD 68 26 RADEMWD 68 27 ROPA MWD 68 28 ROPSMWD 68 29 RPCM MWD 68 30 RPDEMWD 68 31 STVD MWD 68 32 TCDMMWD 68 33 WBCS MWD 68 APl AP! API APl Log Crv Crv Units Size Length Typ Typ Cls Mod G/CC 4 4 98 660 71 6 MINS 4 4 98 660 71 6 PTS 4 4 98 660 71 6 MMHO 4 4 98 660 71 6 MMHO 4 4 98 660 71 6 4 4 98 660 71 6 G/CC 4 4 98 660 71 6 B/E 4 4 98 660 71 6 PU 4 4 98 660 71 6 [U 4 4 98 660 71 6 G/CC 4 4 98 660 71 6 G/CC 4 4 98 660 71 6 GAPI 4 4 98 660 71 6 CPS 4' 4 98 660 71 6 CPS 4 4 98 660 71 6 MINS 4 4 98 660 71 6 PTS 4 4 98 660 71 6 PU 4 4 98 660 71 6 PU 4 4 98 660 71 6 RATI 4 4 98 660 71 6 DEG 4 4 98 660 71 6 DEG 4 4 98 660 71 6 MINS 4 4 98 660 71 6 PTS 4 4 98 660 71 6 OHMM 4 4 98 660 71 6 OHMM 4 4 98 660 71 6 FPHR 4 4 98 660 71 6 FPHR 4 4 98 660 71 6 OHMM 4 4 98 660 71 6 ©HMM 4 4 98 660 71 6 FT 4 4 98 660 71 6 DEGF 4 4 98 660 71 6 LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 87 Tape File Start Depth = 10368.000000 Tape File End Depth = 10520.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54713 datums Tape Subtile: 8 155 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 9 is type: LIS **** FILE HEADER **** MWD .008 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD I0520.0 I0974.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 23 FEB 95 STOP DEPTH 2.13 RO 2.13 RO MEMORY TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 10520.0 BOTTOM LOG INTERVAL (FT): 10974.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 38.8 MAXIMUM ANGLE: 39.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: BLAND CORE MUD DENSITY (LB/G): 12.40 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 4100 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COUN : North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7RR. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(I) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 12 13 14 15 16 000 1 0000000 1 000 I Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 33 Curves: Name Tool Code Samples API API API API Log Crv Crv Units Size Length Typ Typ Cls Mod I BDCMMWD 68 I G/CC 4 4 98 660 71 6 2 BDEMMWD 68 I MINS 4 4 98 660 71 6 3 BDIMMWD 68 l PTS 4 4 98 660 71 6 4 CADEMWD 68 I MMHO 4 4 98 660 71 6 5 CPDEMWD 68 I MMHO 4 4 98 660 71 6 6 DCCMMWD 68 I 4 4 98 660 71 6 7 DLAMMWD 68 I G/CC 4 4 98 660 71 6 8 DPEMMWD 68 I B/E 4 4 98 660 71 6 9 DPLMMWD 68 1 PU 4 4 98 660 71 6 I0 DPSMMWD 68 I [U 4 4 98 660 71 6 I1 DRHMMWD 68 I G/CC 4 4 98 660 71 6 12 DSAMMWD 68 I G/CC 4 4 98 660 71 6 13 GRAMMWD 68 1 GAPI 4 4 98 660 71 6 14 NFBMMWD 68 I CPS 4 4 98 660 71 6 15 NNBMMWD 68 I CPS 4 4 98 660 71 6 16 NPEMMWD 68 I MINS 4 4 98 660 71 6 17 NPIMMWD 68 1 PTS 4 4 98 660 71 6 18 NPLMMWD 68 I PU 4 4 98 660 71 6 19 NPSMMWD 68 I PU 4 4 98 660 71 6 20 NRCMMWD 68 I RATI 4 4 98 660 71 6 21 PDBMMWD 68 I DEG 4 4 98 660 71 6 22 PDCMMWD 68 ! DEG 4 4 98 660 71 6 23 PDEMMWD 68 I MINS 4 4 98 660 71 6 24 PDIMMWD 68 I PTS 4 4 98 660 71 6 25 RACMMWD 68 I OHMM 4 4 98 660 71 6 26 RADEMWD 68 I OHMM 4 4 98 660 71 6 27 ROPAMWD 68 I FPHR 4 4 98 660 71 6 28 ROPSMWD 68 I FPHR 4 4 98 660 71 6 29 RPCMMWD 68 I OHMM 4 4 98 660 71 6 30 RPDEMWD 68 I OHMM 4 4 98 660 71 6 31 STVDMWD 68 I FT 4 4 98 660 71 6 32 TCDMMWD 68 1 DEGF 4 4 98 660 71 6 33 WBCSMWD 68 I LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES* Total Data Records: 260 Tape File Start Depth = 10520.000000 Tape File End Depth = 10974.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 76024 datums Tape Subtile: 9 325 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile I0 is type: LIS **** FILE HEADER **** MWD .009 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10974.0 11105.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): STOP DEPTH 2.13 RO 2.13 RO MEMORY 25 FEB 95 TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 10974.0 BOTTOM LOG INTERVAL (FT): 11105.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 38.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: BLAND CORE MUD DENSITY (LB/G): 12.40 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COUN :North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 1 I. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(l) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 123 45678910111213141516 000 1000000010001 Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F "nm -~.~ Curves: Name Tool Code Samples API API APl APl Log Crv Crv Units Size Length Typ Typ Cls Mod 1 BDCMMWD 68 I G/CC 4 4 98 660 71 6 2 BDEMMWD 68 I MINS 4 4 98 660 71 6 3 BDIMMWD 68 I PTS 4 4 98 660 71 6 4 CADE MWD 68 1 MMHO 4 4 98 660 71 6 5 CPDEMWD 68 1 MMHO 4 4 98 660 71 6 6 DCCM MWD 68 I 4 498 660 71 6 7 DLAMMWD 68 I G/CC 4 4 98 660 71 6 8 DPEMMWD 68 I B/E 4 4 98 660 71 6 9 DPLM MWD 68 I PU 4 4 98 660 71 6 10 DPSMMWD 68 1 [U 4 4 98 660 71 6 I1 DRHMMWD 68 I G/CC 4 4 98 660 71 6 12 DSAMMWD 68 I G/CC 4 4 98 660 71 6 13 GRAMMWD 68 I GAPI 4 4 98 660 71 6 14 NFBMMWD 68 I CPS 4 4 98 660 71 6 15 NNBMMWD 68 I CPS 4 4 98 660 71 6 16 NPEMMWD 68 I MINS 4 4 98 660 71 6 17 NPIMMWD 68 I PTS 4 4 98 660 71 6 18 NPLMMWD 68 I PU 4 4 98 660 71 6 19 NPSMMWD 68 I PU 4 4 98 660 71 6 20 NRCMMWD 68 I RATI 4 4 98 660 71 6 21 PDBMMWD 68 I DEG 4 4 98 660 71 6 22 PDCMMWD 68 I DEG 4 4 98 660 71 6 23 PDEMMWD 68 I MINS 4 4 98 660 71 6 24 PDIMMWD 68 I PTS 4 4 98 660 71 6 25 RACMMWD 68 I OHMM 4 4 98 660 71 6 26 RADEMWD 68 I OHMM 4 4 98 660 71 6 27 ROPAMWD 68 I FPHR 4 4 98 660 71 6 28 ROPSMWD 68 I FPHR 4 4 98 660 71 6 29 RPCMMWD 68 I OHMM 4 4 98 660 71 6 30 RPDEMWD 68 I OHMM 4 4 98 660 71 6 31 STVDMWD 68 I FT 4 4 98 660 71 6 32 TCDMMWD 68 I DEGF 4 4 98 660 71 6 33 WBCSMWD 68 1 LB 4 4 98 660 71 6 132 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 75 Tape File Start Depth -- 10974.000000 Tape File End Depth = 11105.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57846 datums Tape Subtile: 10 140 records... Minimum record length: 62 bytes Maximum record length: 958 bytes 32 Tape Subfile I1 is type: LIS **** FILE HEADER **** MWD .010 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11105.0 11549.0 $ LOG HEADER DATA DATE LOGGED: 02 MAR 95 SOFTWARE SURFACE SOFTWARE VERSION: 2.13 RO DOWNHOLE SOFTWARE VERSION: 2.13 RO DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): .0 TOP LOG INTERVAL (FT): 11105.0 BOTTOM LOG INTERVAL (FT): 11540.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 33.7 MAXIMUM ANGLE: 36.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 6188-02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: BLAND CORE MUD DENSITY (LB/G): 12.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: $ CN : BP Exploration (Alaska) WN : Badami #5 FN : Wildcat / Delineatio COLIN : North Slope STAT :Alaska .000 .0 .000 .0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 12. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(I) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 000 I 0000000 I 000 1 Rep Code Count Bytes 68 33 132 Sum: 33 132 132 fndun a [F ] 1.00000000 ONE DEPTH PER FRAlVlE Tape depth ID: F 33 Curves: Name Tool Code Samples APl APl APl APl Log Crv Crv Units Size Length Typ Typ Cls Mod 1 BDCM MWD 68 1 G/CC 2 BDEM MWD 68 I MINS 3 BDIM MWD 68 I PTS 4 4 CADEMWD 68 I MMH© 5 CPDE MWD 68 I MMHO 6 DCCM MWD 68 I 4 7 DLAM MWD 68 I G/CC 8 DPEM MWD 68 ! B/E 4 9 DPLMMWD 68 I PU 4 I0 DPSM MWD 68 I [U 11 DRHMMWD 68 I G/CC 12 DSAM MWD 68 I G/CC 13 GRAM MWD 68 I GAPI 14 NFBM MWD 68 I CPS 15 NNBMMWD 68 I CPS 16 NPEMMWD 68 I MINS 17 NPIM MWD 68 I PTS 18 NPLMMWD 68 I PU 19 NPSMMWD 68 I PU 20 NRCM MWD 68 I RATI 21 PDBM MWD 68 I DEG 22 PDCM MWD 68 ! DEG 23 PDEM MWD 68 I MINS 24 PDIM MWD 68 I PTS 25 RACM MWD 68 1 ©HMM 26 RADEMWD 68 I OHMM 27 ROPA MWD 68 I FPHR 28 ROPS MWD 68 I FPHR 29 RPCM MWD 68 I OHMM 30 RPDE MWD 68 I OHMM 31 STVD MWD 68 I FT 4 32 TCDM MWD 68 I DEGF 33 WBCS MWD 68 I LB 4 132 4 4 98 660 71 6 4 4 98 66O 71 6 4 98 660 71 6 4 4 98 660 71 6 4 4 98 66O 71 6 4 98 660 71 6 4 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 7l 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 254 Tape File Start Depth = 11105.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86481 datums Tape Subtile: 11 319 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 12 is type: LIS **** TAPE TRAILER **** MWD 95/3/30 1415 Ol **** REEL TRAILER **** MWD 95/3/30 01 Tape Subtile: 12 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 30 MAR 95 7:37a Elapsed execution time = 3 minutes, 26.6 seconds. SYSTEM RETURN CODE = 0 Tape Subtile I is type: LIS Tape Subtile 2 is type: LIS DEPTH RHOB PEF FCNT NCNT NPHI RP TEMP WBCS DR_HO RA GR ROP 6168.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6168.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.0040 -999.2500 6200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.1325 -999.2500 -999.2500 -999.2500 7.4813 115.7426 -999.2500 6250.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.4530 84.3125 38.2855 -999.2500 6.0829 109.9361 52.0947 6300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.9465 88.6438 25.7249 -999.2500 4.6789 128.4326 41.6758 6350.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.4727 92.1875 25.9988 -999.2500 6.3151 68.4424 196.8023 6400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.9304 93.0875 23.9342 -999.25OO 6.4432 78.4442 122.0222 6450.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.6780 94.5500 29.4800 -999.2500 7.7644 86.3139 I00.7547 6500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.8545 96.8000 23.7927 -999.25O0 6.8273 94.3029 59.0407 6550.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.0018 98.7688 22.3635 -999.2500 7.2417 I04.9344 45.4344 6600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.2203 99.8375 21.7042 -999.2500 7.4633 104.1650 39.3635 6650.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.7227 98.7125 25.4580 -999.2500 6.8708 109.8466 32.0020 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 6700.0000 -999.2500 4.4191 -999.2500 -999.2500 104.0000 -999.2500 -999.2500 42.5999 -999.2500 5.0386 122.1765 30.9864 6750.0000 -999.2500 3.9565 -999.2500 -999.2500 105.5750 -999.2500 -999.2500 35.5034 -999.2500 3.6461 126.4658 41.2730 6800.0000 -999.2500 2.0070 -999.2500 -999.2500 106.8125 -999.2500 -999.2500 37.7290 -999.2500 2.0329 122.2431 48.5069 6850.0000 -999.2500 4.4451 -999.2500 -999.2500 107.9375 -999.2500 -999.2500 36.5636 -999.2500 5.1010 114.0591 49.6472 6900.0000 -999.2500 4.5567 -999.2500 -999.2500 106.5875 -999.2500 -999.2500 8.9477 -999.2500 5.4370 100.1479 43.7717 6950.0000 -999.2500 4.9805 -999.2500 -999.2500 108.4625 -999.2500 -999.2500 32.7849 -999.2500 5.6790 99.5373 71.7495 7000.0000 -999.2500 4.4196 -999.2500 -999.2500 110.8625 -999.2500 -999.2500 12.2808 -999.2500 5.1964 98.9472 77.8559 7050.0000 -999.2500 3.4256 -999.2500 -999.2500 110.6375 -999.2500 -999.2500 28.0601 -999.2500 3.6224 70.0802 192.7426 7100.0000 -999.2500 4.5743 -999.2500 -999.2500 111.6500 -999.2500 -999.2500 34.2046 -999.2500 5.3287 115.8024 27.3728 7150.0000 -999.2500 2.2693 -999.2500 -999.2500 111.8187 -999.2500 -999.2500 33.2942 -999.2500 2.4876 58.9476 51.0856 7200.0000 -999.2500 2.1098 -999.2500 -999.2500 112.6625 -999.2500 -999.2500 28.0765 -999.25oo 2.0575 58.8376 322.1713 7250.0000 -999.2500 1.7123 -999.2500 -999.2500 107.0375 -999.2500 -999.2500 23.4104 -999.2500 1.7943 53.4905 98.9759 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DPd-tO GR RA ROP 7300.0000 -999.2500 -999.2500 -999.2500 61.8253 -999.2500 -999.2500 -999.2500 1.8392 269.8180 1.8814 107.9375 28.4541 -999.2500 -999.2500 107.8250 -999.2500 -999.2500 26.0478 7350.0000 -999.2500 3.7663 -999.2500 -999.2500 110.0750 -999.2500 -999.2500 24.0739 7400.0000 -999.2500 3.3635 -999.2500 -999.2500 111.4250 -999.2500 -999.2500 21.7372 7450.0000 -999.2500 4.2597 -999.2500 95.5397 3.6627 31.5989 -999.2500 88.8151 3.4107 60.9871 -999.2500 103.7310 4.8649 44.2945 7500.0000 -999.2500 -999.2500 -999.2500 86.4315 -999.2500 -999.2500 -999.2500 4.2015 84.3095 3.7117 112.8875 31.3732 -999.2500 -999.2500 109.8500 -999.2500 -999.2500 32.0134 7550.0000 -999.2500 4.8175 -999.2500 -999.2500 114.8562 -999.2500 -999.2500 38.6618 7600.0000 -999.2500 5.7707 -999.2500 101.1796 5.5032 22.1345 -999.2500 96.4366 6.7896 50.5932 7650.0000 -999.2500 -999.2500 -999.2500 78.5460 -999.2500 -999.2500 -999.2500 4.2056 150.3378 3.8113 116.6000 38.0582 7700.0000 -999.2500 4.1800 -999.2500 -999.2500 114.6500 -999.2500 -999.2500 35.5697 7750.0000 -999.2500 5.2783 -999.2500 -999.2500 118.4000 -999.2500 -999.2500 20.0731 7800.0000 -999.2500 5.3135 -999.2500 -999.2500 117.9500 -999.2500 -999.2500 35.4594 7850.0000 -999.2500 6.7862 -999.2500 -999.2500 103.7375 -999.2500 -999.2500 7.0636 -999.2500 94.4760 4.7768 74.1242 -999.2500 86.9881 5.5781 20.6576 -999.2500 96.1923 5.6261 62.0696 -999.2500 116.8584 7.7410 100.7546 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 7900.000O -999.2500 5.2223 -999.2500 -999.2500 104.7875 -999.2500 -999.2500 2.3718 -999.2500 5.8723 71.8009 122.2029 7950.0000 -999.2500 6.3964 -999.2500 -999.2500 106.8125 -999.2500 -999.2500 9.1553 -999.2500 7.5246 136.6451 56.2958 8000.0000 -999.2500 5.2190 -999.2500 -999.2500 108.0500 -999.2500 -999.2500 2.6874 -999.2500 5.8703 98.0867 86.1169 8050.0000 -999.2500 5.1015 -999.2500 -999.2500 109.2125 -999.2500 -999.2500 1.9209 -999.2500 5.7621 106.6477 73.1845 8100.0000 -999.2500 5.2188 -999.2500 -999.2500 109.8500 -999.2500 -999.2500 7.7037 -999.25OO 6.0208 121.1016 50.3773 8150.0000 -999.2500 4.7717 -999.2500 -999.2500 114.1250 -999.2500 -999.2500 1.1342 -999.2500 5.5520 112.3383 111.4973 8200.0000 -999.2500 5.0902 -999.2500 -999.2500 114.0125 -999.2500 -999.2500 0.3223 -999.2500 6.2416 100.2669 149.9446 8250.0000 -999.2500 4.1076 -999.2500 -999.2500 116.6000 -999.2500 -999.2500 0.6635 -999.2500 4.6831 122.0105 59.0647 8300.0OOO -999.2500 2.8195 -999.2500 -999.2500 115.3344 -999.2500 -999.2500 1.6105 -999.2500 3.1041 93.6842 18.3190 8350.0000 -999.2500 3.6743 -999.2500 -999.2500 113.6750 -999.2500 -999.2500 6.7892 -999.2500 4.1542 114.3511 21.1683 8400.0000 -999.2500 5.5770 -999.2500 -999.2500 113.3375 -999.2500 -999.2500 9.0161 -999.2500 6.4570 97.8529 35.1849 '8450.0000 -999.2500 4.5503 -999.2500 -999.2500 117.2750 -999.2500 -999.2500 4.5000 -999.2500 4.9741 61.0017 107.7091 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 8500.0000 -999.2500 4.6176 -999.2500 -999.2500 116.9375 -999.2500 -999.2500 1.7412 -999.2500 5.4101 106.2610 75.4018 8550.0000 -999.2500 4.8488 -999.2500 -999.2500 116.8250 -999.2500 -999.2500 4.0417 -999.2500 5.5433 110.2986 114.2258 8600.0000 -999.2500 5.4512 -999.2500 -999.2500 117.7250 -999.2500 -999.2500 3.2491 -999.2500 5.7606 105.8240 79.6665 8650.00O0 -999.2500 4.5884 -999.2500 -999.2500 121.6625 -999.2500 -999.2500 1.5856 -999.2500 5.6501 93.6267 78.7530 8700.0000 -999.2500 5.0914 -999.2500 -999.2500 123.0125 -999.2500 -999.2500 2.6467 -999.2500 6.1154 100.4932 118.1355 8750.0000 -999.2500 12.4308 -999.2500 -999.2500 121.7750 -999.2500 -999.2500 9.3136 -999.2500 12.2820 70.5759 28.8355 8800.0000 '-999.2500 5.6543 -999.2500 -999.2500 123.3500 -999.2500 -999.2500 0.0751 -999.2500 6.0818 100.6056 22.3299 8850.0000 -999.2500 5.7313 -999.2500 -999.2500 124.5875 -999.2500 -999.2500 3.0272 -999.2500 6.5998 99.2095 38.1063 8900.0000 -999.2500 4.9190 -999.2500 -999.2500 125.6000 -999.2500 -999.2500 -999.2500 -999.2500 5.7024 119.9496 48.6500 8950.000O -999.2500 4.6955 -999.2500 -999.2500 124.4750 -999.2500 -999.2500 20.0451 -999.2500 5.3572 115.4623 44.8593 9000.0000 -999.2500 5.2173 -999.2500 -999.2500 125.8250 -999.2500 -999.2500 20.8281 -999.2500 5.9823 104.0881 46.3558 9050.0000 -999.2500 5.9959 -999.2500 -999.2500 126.2750 -999.2500 -999.2500 23.4752 -999.2500 6.6123 110.6806 43.1829 DEPTH FCNT RP RI-lOB NCNT TEMP PEF NPHI WBCS DRHO RA GR ROP 9100.0000 -999.2500 5.4861 -999.2500 -999.2500 126.8376 -999.2500 -999.2500 16.5887 -999.2500 6.5501 114.9602 39.8055 9150.0000 -999.2500 6.2064 -999.2500 -999.2500 119.4125 -999.2500 -999.2500 32.9864 -999.2500 7.4210 109.6017 19.2453 9200.0000 -999.2500 6.1340 -999.2500 -999.2500 108.5844 -999.2500 -999.2500 29.9879 -999.2500 7.1751 104.5651 31.3618 9250.0000 -999.2500 5.5878 -999.2500 -999.2500 113.3375 -999.2500 -999.2500 29.9879 -999.2500 6.3833 113.0794 23.6252 9300.0000 -999.2500 5.6926 -999.2500 -999.2500 114.5750 -999.2500 -999.2500 46.2878 -999.2500 6.5343 112.9524 25.6803 9350.0000 -999.2500 5.7512 -999.2500 -999.2500 113.2625 -999.2500 -999.2500 57.3177 -999.2500 6.6856 106.6025 13.5367 9400.0000 -999.250O 5.8415 -999.2500 -999.2500 119.6375 -999.2500 -999.2500 25.1371 -999.2500 6.7003 109.5029 25.3135 9450.0000 -999.2500 4.9279 -999.2500 -999.2500 122.0000 -999.2500 -999.2500 33.8410 -999.2500 6.0464 113.7537 25.0829 9500.0000 -999.2500 5.6327 -999.2500 -999.2500 122.9000 -999.2500 -999.25O0 36.8794 -999.2500 6.4885 112.7482 27.3728 9550.0000 -999.2500 -999.2500 -999.2500 -999.2500 124.5875 -999.2500 -999.2500 43.6077 -999.2500 -999.2500 -999.2500 54.5213 9600.0000 32.8750 5.6672 2.5123 6972.0000 134.1500 7.8457 31.8918 -999.2500 0.0408 8.2159 109.9202 5.3399 9650.0000 37.8125 -999.2500 2.5566 7056.0000 114.8000 5.5552 27.2958 5.2972 0.0307 -999.2500 107.9257 35.2126 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 9700.0000 36.5937 5.8054 2.5730 7154.0000 119.9750 5.4976 28.8755 1.1043 0.0297 8.2890 108.5456 38.1390 9750.0000 40.2396 6.9443 2.6023 7015.1670 123.1250 5.8977 25.6264 1.7284 0.0667 9.4690 106.2277 24.7824 9800.0O00 35.7500 5.9711 2.5535 7088.0000 127.9625 5.7493 29.3655 0.1705 0.0222 8.3145 110.8097 31.4281 9850.0000 38.7500 6.4156 2.5698 7126.0000 129.5375 5.6335 26.8644 0.0210 0.0102 8.9475 110.1987 24.4141 9900.000O 37.9375 6.1607 2.5608 7093.0000 130.5500 5.7241 27.3589 0.4120 0.0268 8.9942 121.1237 24.9569 9950.00O0 38.1875 5.7924 2.5911 6941.0000 131.7875 6.0528 26.4515 1.8651 0.0444 7.9474 106.8206 27.1267 !0000.0000 36.6339 6.9943 2.5353 6998.0000 131.7875 6.2877 28.1217 0.9244 0.0506 10.3556 108.3300 52.7024 0050.0000 33.8125 6.9857 2.5272 7020.0000 124.5125 5.9644 31.1296 16.1682 0.0363 9.8300 108.0066 17.7158 I0100.0000 36.3125 6.5618 2.5475 7077.0000 127.9625 6.0363 28.7610 21.3581 0.0345 9.7252 106.8206 15.7200 10150.0000 38.7500 6.1410 2.5419 7009.0000 130.3250 5.7335 26.2984 24.4612 0.0064 8.9486 106.1198 38.9438 10200.0000 38.1875 5.9077 2.5776 6959.0000 132.6875 6.4483 26.5398 10.9774 0.0387 8.3631 109.4081 18.1738 10250.0000 39.9375 5.6745 2.5799 6926.0000 134.4875 5.3526 25.0174 23.6673 0.0303 8.4665 117.6738 81.2959 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 10300.0000 35.6875 6.0825 2.5721 7082.0000 135.4297 5.8134 29.3977 17.2410 0.0576 8.7115 107.6831 35.9483 10350.0000 -999.2500 6.6803 2.5737 -999.2500 136.2875 5.6098 -999.2500 23.4100 0.0248 9.3973 108.5995 35.9504 10400.0000 -999.2500 7.5802 -999.2500 -999.2500 136.9625 -999.2500 -999.2500 19.0131 -999.2500 11.6028 109.4335 32.1238 10450.0000 -999.2500 10.7503 -999.2500 -999.2500 137.7500 -999.2500 -999.2500 5.1283 -999.2500 26.6124 100.0760 43.2181 10500.0000 -999.2500 5.7157 -999.2500 -999.2500 115.3625 -999.2500 -999.2500 8.0587 -999.2500 9.6508 116.3901 14.7338 10550.0000 -999.2500 8.0780 -999.2500 -999.2500 116.0000 -999.2500 -999.2500 13.7663 -999.2500 14.5410 I19.6323 62.0208 10600.0000 -999.2500 9.5181 -999.2500 -999.2500 113.8437 -999.2500 -999.2500 9.9999 -999.2500 20.6474 108.9410 48.2487 10650.0000 -999.2500 9.5230 -999.2500 -999.2500 113.0562 -999.2500 -999.2500 9.6681 -999.2500 22.4330 108.8179 54.6583 10700.0000 -999.2500 9.1328 -999.2500 -999.2500 116.6000 -999.2500 -999.2500 10.7975 -999.2500 22.3721 111.1983 58.1287 10750.0000 -999.2500 13.8993 -999.2500 -999.2500 118.2875 -999.2500 -999.2500 8.5864 -999.2500 44.9512 104.9189 59.0677 1O80O.O00O -999.2500 25.6630 -999.2500 -999.2500 119.7125 -999.2500 -999.2500 9.6870 -999.2500 453.9620 58.2751 62.0696 10850.0000 -999.2500 9.1112 -999.2500 -999.2500 121.6625 -999.2500 -999.2500 9.5894 -999.2500 20.9332 96.8748 46.3558 DEPTH FCNT RP RHOB NCNT TEMP PEF NPHI WBCS DRHO GR ROP 10900.0000 -999.2500 10.0564 -999.2500 -999.2500 122.4500 -999.2500 -909.2500 9.3355 -999.2500 23.3307 98.5574 58.1287 10950.0000 -999.2500 8.4572 -999.2500 -999.2500 126.0500 -999.2500 -999.2500 9.17i3 -999.2500 19.6004 114.9389 47.2133 11000.0000 -999.2500 10.6266 -999.250O -999.2500 127.0625 -999.2500 -999.2500 9.9781 -999.250O 21.1010 114.2354 57.1129 11050.0000 -999.2500 6.7961 -999.2500 -999.2500 126.8750 -999.2500 -999.2500 29.5183 -999.2500 12.0658 121.9769 10.2346 11100.0000 -999.2500 9.6093 -999.2500 -999.2500 132.8000 -999.2500 -999.250O 29.5259 -999.2500 24.2503 103.1541 12.3303 11150.0000 -999.2500 15.1037 -999.250O -999.2500 127.0625 -999.2500 -999.2500 -999.2500 -999.2500 68.1715 85.8551 2.5755 11200.0000 -999.2500 62.8950 -999.2500 -999.2500 124.4750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 45.2854 7.1020 11250.0000~ -999.2500 8.2931 -999.2500 -999.2500 122.9000 -999.2500 -999.2500 -999.2500 -999.2500 26.5621 105.1241 2.0761 11300.0000 -999.2500 4.5123 -999.2500 -999.2500 126.7250 -999.2500 -999.2500 -999.2500 -999.2500 7.1614 142.5541 38.5205 11350.0000 -999.2500 5.3257 -999.2500 -999.2500 129.5375 -999.2500 -999.2500 -999.2500 -999.2500 8.4690 123.5929 45.0365 11400.0000 -999.2500 5.2581 -999.2500 -999.2500 130.9438 -999.2500 -999.2500 -999.2500 -999.2500 8.8106 129.5337 60.0053 11450.0000 -999.2500 4.9507 -999.2500 -999.2500 133.8125 -999.2500 -999.2500 -999.2500 -999.2500 8.4025 150.1468 51.7459 DEPTH RHOB PEF FCNT NCNT NPHI RP TEMP WBCS DRI-IO GR ROP 11500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13.0540 135.1625 -999.2500 -999.2500 15.5306 65.2932 60.0169 11549.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 31.2900 Tape File Start Depth = 6168.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPlM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 6168.0000 -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 6168.2500 -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 6200.0000 -999.2500 -999.2500 156.0337 93.6818 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.4961 8.9156 7.4813 6.7090 -999.2500 6.4089 -999.2500 -999.2500 -999.2500 149.0545 -999.2500 -999.2500 115.7426 -999.2500 -999.2500 -999.2500 36.5000 186.5000 -999.2500 6.1325 -999.2500 6250.0000 -999.2500 -999.2500 -999.2500 179.9695 175.7647 98.9461 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.9361 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.1562 9.6303 79.5000 544.5000 6.0829 5.5565 50.1655 52.0947 5.4530 5.6894 -999.2500 84.3125 38.2855 6300.0000 -999.2500 -999.2500 193.8776 103.5588 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.7344 10.2540 4.6789 4.3607 38.5927 5.1579 -999.2500 88.6438 -999.2500 229.3215 -999.2500 -999.2500 128.4326 -999.2500 -999.2500 -999.2500 91.0000 909.0000, 41.6758 4.9465 25.7249 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 6350.0000 -999.2500 -999.2500 -999.2500 174.0320 175.0814 98.7805 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 68.4424 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.0781 9.6078 36.0000 1161.0000 6.3151 5.7461 161.9294 196.8023 5.4727 5.7116 -999.2500 92.1875 25.9988 6400.0000 -999.2500 -999.2500 -999.2500 170.3816 161.4209 95.1525 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 78.4442 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.5625 9.1149 43.5000 1462.5000 6.4432 5.8692 120.5599 122.0222 5.9304 6.1950 099.2500 93.0875 23.9342 6450.0000 -999.2500 -999.2500 -999.2500 143.6835 143.0763 90.0510 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 86.3139 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13.8516 8.4245 52.0000 1796.5000 7.7644 6.9597 94.6135 100.7547 6.6780 6.9893 -999.2500 94.5500 29.4800 6500.0000 163.5717 -999.2500 -999.2500 -999.2500 6.8273 6.1135 -999.2500 -999.2500 -999.2500 161.8969 95.7248 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.3029 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6172 9.1933 63.0000 2139.5000 6.1768 67.5253 59.0407 5.8545 -999.2500 96.8000 23.7927 6550.0000 159.4394 -999.2500 -999.2500 -999.2500 7.2417 6.2720 -999.2500 -999.2500 -999.2500 153.5166 94.6246 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.9344 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.4531 9.0434 90.5000 2502.5000 6.5140 49.5157 45.4344 6.0018 -999.2500 98.7688 22.3635 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 6600.0000 153.7979 -999.2500 -999.2500 -999.2500 7.4633 6.5020 -999.2500 -999.2500 -999.2500 149.2620 93.0652 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.1650 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.2396 8.8320 87.5000 2884.5000 6.6996 40.0795 39.3635 6.2203 -999.2500 99.8375 21.7042 6700.0000 -999.2500 -999.2500 -999.2500 215.0936 217.4889 109.1805 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 122.1765 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.3594 11.0271 95.5000 3623.5000 5.0386 4.6491 29.7220 30.9864 4.4191 4.5979 -999.2500 104.0000 42.5999 6750.0000 -999.2500 -999.2500 -999.2500 290.8626 243.3113 115.0125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 126.4658 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.1354 11.8259 83.0000 3985.0000 3.6461 3.4380 41.3889 41.2730 3.9565 4.1100 -999.2500 105.5750 35.5034 6800.0000 -999.2500 -999.2500 -999.2500 513.0182 391.2020 158.8322 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 122.2431 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.0937 15.7938 78.,0000 4342.5000 2.0329 1.9492 45.7058 48.5069 2.0070 2.5562 -999.2500 106.8125 37.7290 6650.0000 -999.2500 -999.2500 -999.2500 161.1066 167.3241 96.7447 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.8466 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6875 9.3311 113.0000 3250.5000 6.8708 6.2071 35.2164 32.0020 5.7227 5.9764 -999.2500 98.7125 25.4580 DEPTH CPDE DPSM NNBM NRCM RACM RPDE BDCM DCCM DRHM NPEM PDBM RADE STVD BDEM DLAM DSAM NPIM PDCM ROPA TCDM BDIM DPEM GRAM NPLM PDEM ROPS WBCS CADE DPLM NFBM NPSM PDIM RPCM 6850.0000 214.2213 -999.2500 -999.2500 -999.2500 5.1010 4.6681 -999.2500 108.8805 -999.2500 -999.2500 16.2375 4.7024 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.9230 51.0990 107.9375 -999.2500 -999.2500 114.0591 -999.2500 84.5000 49.6472 36.5636 212.6561 -999.2500 -999.2500 -999.2500 4707.5000 4.4451 6900.0000 210.7994 -999.2500 -999.2500 -999.2500 5.4370 4.7438 -999.2500 107.6200 -999.2500 -999.2500 16.1250 4.9869 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.8137 40.0133 106.5875 -999.2500 -999.2500 100.1479 -999.2500 84.5000 43.7717 8.9477 200.5269 -999.2500 -999.2500 -999.2500 4996.5OO0 4.5567 6950.0000 192.6800 -999.2500 -999.2500 -999.2500 5.6790 5.1900 -999.2500 103.2266 -999.2500 -999.2500 15.4844 5.2042 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.2135 70.9014 108.4625 -999.2500 -999.2500 99.5373 -999.2500 48.5000 71.7495 32.7849 192.1514 -999.2500 -999.2500 -999.2500 5326.5000 4.9805 7000.0000 217.4671 -999.2500 -999.2500 -999.2500 5.1964 4.5984 -999.2500 109.1756 -999.2500 -999.2500 16.3125 4.7813 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11.0265 77.5503 110.8625 -999.2500 -999.2500 98.9472 -999.2500 40.0000 77.8559 12.2808 209.1468 -999.2500 -999.2500 -999.2500 5559.0000 4.4196 7050.0000 281.5550 -999.2500 -999.2500 -999.2500 3.6224 3.5517 -999.2500 123.1127 -999.2500 -999.2500 18.1979 3.4038 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12.9372 200.7530 110.6375 -999.2500 -999.2500 70.0802 -999.2500 70.0000 192.7426 28.0601 293.7901 -999.2500 -999.2500 -999.25O0 5866.5000 3.4256 DEPTH CPDE DPSM NNBM NRCM RACM RPDE 7100.0000 209.9940 -999.2500 -999.2500 -999.2500 5.3287 4.7620 7150.0000 427.1877 ~999.2500 -999.2500 -999.2500 2.4876 2.3409 7200.0000 459.8019 -999.2500 -999.2500 -999.2500 2.0575 2.1748 7250.0000 567.8206 -999.2500 -999.2500 -999.2500 1.7943 1.7611 7300.0000 520.4491 -999.2500 -999.2500 -999.2500 1.8392 1.9214 7350.0000 255.7660 -999.2500 -999.2500 -999.2500 3.6627 BDCM DCCM DRHM NPEM PDBM RADE STVD -999.2500 107.4253 -999.25O0 -999.2500 16.0417 4.8975 -999.2500 -999.2500 149.7585 -999.2500 -999.2500 21.8437 2.3674 -999.2500 -999.2500 155.0756 -999.2500 -999.2500 22.6406 1.9736 -999.2500 -999.2500 171.4161 -999.2500 -999.2500 24.8750 1.7249 -999.2500 -999.2500 163.8324 -999.2500 -999.2500 23.9000 1.7692 -999.2500 -999.2500 117.7161 -999.2500 -999.25OO 17.5000 3.4481 BDEM DLAM DSAM NPIM PDCM ROPA TCDM -999.2500 -999.2500 -999.2500 -999.2500 10.7871 27.4679 111.6500 -999.2500 -999.2500 -999.2500 -999.2500 16.5991 49.7705 111.8187 -999.2500 -999.2500 -999.2500 -999.2500 17.3296 293.0385 112.6625 -999.2500 -999.2500 -999.2500 -999.2500 19.5719 104.7295 107.0375 -999.2500 -999.2500 -999.2500 -999.2500 5.5537 260.3949 107.9375 -999.2500 -999.2500 -999.2500 -999.2500 12.1966 40.3743 BDIM DPEM GRAM NPLM PDEM ROPS WBCS -999.2500 -999.2500 115.8024 -999.2500 69.0000 27.3728 34.2046 -999.2500 -999.2500 58.9476 -999.2500 45.0000 51.0856 33.2942 -999.2500 -999.2500 58.8376 -999.2500 125.0000 322.1713 28.0765 -999.2500 -999.2500 53.4905 -999.2500 46.0000 98.9759 23.4104 -999.2500 -999.2500 61.8253 -999.2500 130.0000 269.8180 28.4541 -999.2500 -999.2500 95.5397 -999.2500 36.0000 31.5989 CADE DPLM NFBM NPSM PDIM RPCM 204.1845 -999.2500 -999.2500 -999.2500 6202.5000 4.5743 422.4016 -999.2500 -999.2500 -999.2500 6450.0O00 2.2693 506.6777 -999.2500 -999.2500 -999.2500 6741.5000 2.1098 579.7540 -999.2500 -999.2500 -999.2500 7019.0000 1.7123 565.2379 -999.2500 -999.2500 -999.2500 7300.0000 1.8814 290.0179 -999.2500 -999.2500 -999.2500 7471.0000 3.7663 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 7400.0000 -999.2500 099.2500 -999.2500 310.9205 286.7850 124.1838 -999.2500 099.2500 -999.2500 -999.2500 -999.2500 -999.2500 88.8151 099.2500 -999.2500 -999.2500 099.2500 -999.2500 -999.2500 -999.2500 18.3750 13.0843 70.5000 7805.5000 3.4107 3.2163 79.6468 60.9871 3.3635 3.4869 -999.2500 110.0750 24.0739 7450.0000 -999.2500 -999.2500 -999.2500 222.3568 225.7695 111.0828 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.7310 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.5625 11.2875 53.5000 8138.5000 4.8649 4.4973 43.1371 44.2945 4.2597 4.4293 -999.2500 111.4250 21.7372 7500.0000 -999.2500 -999.2500 -999.2500 255.4943 259.4998 118.5305 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 86.4315 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.6161 12.3083 131.5000 8489.5000 4.2015 3.9140 86.1883 84.3095 3.7117 3.8536 -999.2500 I12.8875 31.3732 7550.0000 -999.2500 -999.2500 -999.2500 197.9306 199.2903 104.8478 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 101.1796 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.7187 10.4348 100.5000 8826.5000 5.5032 5.0523 21.7846 22.1345 4.8175 5.0178 -999.2500 109.8500 32.0134 7600.0000 165.9488 -999.2500 -999.2500 -999.2500 6.7896 6.0260 -999.2500 -999.2500 -999.2500 162.8035 96.3692 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 96.4366 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.5312 9.2801 77.0000 9169.0000 6.1424 56.2511 50.5932 5.7707 -999.2500 114.8562 38.6618 3.9098 -999.2500 107.8250 26.0478 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM N'NBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 7650.0000 -999.2500 -999.2500 -999.2500 255.0433 252.6525 117.0582 -999.2500 -999.2500 -999.2500 -999.2500 099.2500 -999.2500 78.5460 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.3750 12.1063 92.0000 9525.5000 4.2056 3.9209 128.2934 150.3378 3.8113 3.9580 -999.2500 116.6000 38.0582 7700.0000 -999.2500 -999.2500 -999.2500 226.2518 230.0858 112.0742 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.4760 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.6508 11.4233 53.0000 9842.0000 4.7768 4.4199 74.5160 74.1242 4.1800 4.3462 -999.2500 114.6500 35.5697 7750.0000 -999.2500 -999.2500 181.6647 100.4620 -999.2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.0781 9.8367 5.5781 5.1317 42.4433 5.5046 -999.2500 118.4000 -999.2500 194.8662 -999.2500 -999.2500 86.9881 -999.2500 -999.2500 -999.2500 56.0000 10097.0000 20.6576 5.2783 20.0731 7768.0000 -999.2500 -999.2500 -999.2500 252.9043 245.0848 115.4017 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 72.2439 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.1172 11.8792 50.0000 10198.0000 4.2399 3.9541 174.0632 88.5891 3.9282 4.0802 -999.2500 117.7250 26.9624 Tape File Start Depth = 6168.000000 Tape File End Depth = 7768.000000 Tape File Level Spacing = 0.250000 .Tape File Depth Units = Feet Tape Subtile 4 is ~pe: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 7768.0000 -999.2500 -999.2500 245.0848 115.4017 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.1172 11.8792 4.2399 3.9541 174.0632 4.0802 -999.2500 I17.7250 -999.2500 252.9043 -999.2500 -999.2500 72.2439 -999.2500 -999.2500 -999.2500 50.0000 10198.0000 88.5891 3.9282 26.9624 7768.2500 -999.2500 -999.2500 -999.2500 249.8401 242.7495 114.8888 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 74.6672 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.0469 11.8089 50.0000 10199.5000 4.2951 4.0026 174.0632 145.5718 3.9655 4.1195 -999.2500 117.7250 26.0082 7800.0000 -999.2500 -999.2500 180.4102 100.1509 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.2109 9.7943 5.6261 5.1482 56.3911 5.5429 -999.2500 117.9500 -999.2500 194.2436 -999.2500 -999.2500 96.1923 -999.2500 -999.2500 -999.2500 833.0000 I0426.0000 62.0696 5.3135 35.4594 7850.0000 -999.2500 -999.2500 140.8523 89.3832 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13.7500 8.3344 7.7410 6.9439 105.8870 7.0996 -999.2500 103.7375 -999.2500 144.0105 -999.2500 -999.2500 116.8584 -999.2500 -999.2500 -999.2500 46.0000 10728.0000 100.7546 6.7862 7.0636 7900.0000 -999.2500 -999.2500 183.6454 100.9638 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.2891 9.9050 5.8723 5.3709 132.1255 5.4453 -999.2500 104.7875 -999.2500 186.1869 -999.2500 -999.2500 71.8009 -999.2500 -999.2500 -999.2500 37.5000 11024.5000 122.2029 5.2223 2.3718 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 7950.0000 149.5208 -999.2500 -999.2500 -999.2500 7.5246 6.6880 -999.2500 -999.2500 -999.2500 148.0553 91.8675 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 136.6451 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.0469 8.6699 42.0000 11349.5000 6.7542 69.2607 56.2958 6.3964 -999.2500 106.8125 9.1553 8000.0000 -999.2500 -999.2500 -999.2500 186.2455 183.7616 100.9937 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 98.0867 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.2656 9.9091 163.0000 11708.0000 5.8703 5.3693 70.1717 86.1169 5.2190 5.4418 -999.2500 108.0500 2.6874 8050.0000 -999.2500 -999.2500 -999.2500 189.5471 188.0492 102.0742 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.6477 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.4219 10.0563 106.0000 12073.0000 5.7621 5.2757 82.6558 73.1845 5.1015 5.3178 -999.2500 109.2125 1.9209 8100.0000 183.7701 -999.2500 -999.2500 -999.2500 6.0208 5.4416 -999.2500 -999.2500 -999.2500 182.0370 100.9957 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 121.1016 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.2266 9.9094 53.0000 12371.5000 5.4934 47.2708 50.3773 5.2188 -999.2500 109.8500 7.7037 8150.0000 201.2336 -999.2500 -999.2500 -999.2500 5.5520 4.9693 -999.2500 -999.2500 -999.2500 196.5160 105.3177 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 112.3383 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.8125 10.4990 65.5000 12680.5000 5.0886 98.8554 111.4973 4.7717 -999.2500 114.1250 1.1342 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRA1M NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM ?DEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 8200.0000 -999.2500 -999.2500 -999.2500 176.4478 188.4825 102.1804 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100.2669 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.3646 10.0708 53.0000 13007.5000 6.2416 5.6674 139.4918 149.9446 5.0902 5.3055 -999.2500 114.0125 0.3223 8250.0000 -999.2500 -999.2500 -999.2500 230.5866 234.3074 112.9990 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 122.0105 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.9023 11.5500 78.0000 13309.5000 4.6831 4.3368 58.6966 59.0647 4.1076 4.2679 -999.2500 116.6000 0.6635 8300.0000 -999.2500 -999.2500 -999.2500 341.2228 342.9020 135.0283 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 93.6842 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 19.9062 14.5748 172.0000 13728.5000 3.1041 2.9306 16.1749 18.3190 2.8195 2.9163 -999.2500 115.3344 1.6105 8350.0000 -999.2500 -999.2500 -999.2500 258.3374 262.3018 119.0986 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 114.3511 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.7656 12.3862 175.0000 14081.5000 4.1542 3.8709 20.5725 21.1683 3.6743 3.8124 -999.2500 113.6750 6.7892 8400.0000 171.8176 -999.2500 -999.2500 -999.2500 6.4570 5.8201 -999.2500 -999.2500 -999.2500 170.5482 97.9141 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 97.8529 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.8203 9.4900 94.0000 14434.0000 5.8634 36.4462 35.1849 5.5770 -999.2500 113.3375 9.0161 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 8450.0000 -999.2500 -999.2500 -999.2500 217.4830 211.1537 107.6909 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 61.0017 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.1562 10.8234 138.0000 14793.5000 4.9741 4.5981 120.4764 107.7091 4.5503 4.7359 -999.2500 117.2750 4.5000 8500.0000 -999.2500 -999.2500 -999.2500 201.4086 208.0819 106.9516 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.2610 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.0625 10.7223 107.5000 15126.5000 5.4101 4.9650 76.6585 75.4018 4.6176 4.8058 -999.2500 116.9375 1.7412 8550.0000 -999.2500 -999.2500 -999.2500 196.6710 197.8405 104.5304 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.2986 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.6927 10.3860 131.0000 15480.5000 5.5433 5.0846 117.2172 114.2258 4.8488 5.0546 -999.2500 116.8250 4.0417 8600.0000 175.8838 -999.2500 -999.2500 -999.2500 5.7606 5.6856 -999.2500 -999.2500 -999.2500 189.0968 98.9618 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 105.8240 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.9062 9.6325 74.0000 15822.0000 5.2883 73.0876 79.6665 5.4512 -999.2500 117.7250 3.2491 8650.0000 -999.2500 -999.2500 -999.2500 193.7165 209.2787 107.2704 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 93.6267 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.0208 10.7614 57.5000 16157.5000 5.6501 5.1622 77.2249 78.7530 4.5884 4.7783 -999.2500 121.6625 1.5856 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM KADE ROPA ROPS KPCM RPDE STVD TCDM WBCS 8700.0000 -999.2500 -999.2500 -999.2500 179.6966 188.4364 102.1689 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100.4932 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.3437 10.0693 252.5000 16438.5000 6.1154 5.5649 I04.8586 118.1355 5.0914 5.3068 -999.2500 123.0125 2.6467 8750.0000 -999.2500 -999.2500 -999.2500 93.8981 76.2085 67.7895 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 70.5759 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.7406 5.4732 98.0000 16796.5000 12.2820 10.6498 30.4423 28.8355 12.4308 13.1219 -999.2500 121.7750 9.3136 8800.0000 169.4819 -999.2500 -999.2500 -999.2500 6.0818 5.9003 8850.0000 167.1331 -999.2500 -999.2500 -999.2500 6.5998 5.9833 -999.2500 -999.2500 -999.2500 179.7946 97.2881 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100.6056 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6484 9.4049 87.5000 17175.5000 5.5619 26.6026 22.3299 5.6543 -999.2500 123.3500 0.0751 -999.2500 -999.2500 -999.2500 167.0573 96.6772 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 99.2095 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.5508 9.3219 81.5000 17480.5000 5.9860 41.9911 38.1063 5.7313 -999.2500 124.5875 3.0272 8900.0000 -999.2500 2999.2500 -999.2500 191.5969 195.3977 103.8291 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 119.9496 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.5469 10.3027 98.5000 17857.5000 5.7024 5.2193 49.6062 48.6500 4.9190 5.1178 -999.2500 125.6000 -999.2500 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 8950.0000 -999.2500 -999.2500 -999.2500 203.0689 204.5833 106.1159 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 115.4623 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.8359 10.6074 I00.0000 18238.5000 5.3572 4.9244 41.3700 44.8593 4.6955 4.8880 -999.2500 124.4750 20.0451 9000.0000 -999.2500 -999.2500 183.8215 101.0089 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.1380 9.9112 5.9823 5.4617 44.2353 5.4401 -999.2500 125.8250 9050.0000 -999.2500 -999.2500 159.5930 94.6681 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6339 9.0470 6.6123 -999.2500 42.5676 6.2659 -999.2500 126.2750 -999.2500 183.0940 -999.2500 -999.2500 104.0881 -999.2500 -999.2500 -999.2500 99.5000 18616.5000 46.3558 5.2173 20.8281 -999.2500 -999.2500 -999.2500 -999.2500 110.6806 -999.2500 -999.2500 -999.2500 52.5714 -999.2500 43.1829 5.9959 23.4752 9100.0000 -999.2500 -999.2500 -999.2500 168.5035 174.7137 98.6672 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 114.9602 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.9049 9.5924 312.5000 19043.5000 6.5501 5.9346 42.3647 39.8055 5.4861 5.7236 -999.2500 126.8376 16.5887 9142.0000 -999.2500 -999.2500 149.2357 91.7745 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.1094 8.6574 7.3613 6.6269 5.3109 6.7008 -999.2500 121.3925 -999.2500 150.9011 -999.2500 -999.2500 109.8341 -999.2500 -999.2500 -999.2500 1503.5000 19355.5000 4.3600 6.4104 21.9913 Tape File Start Depth = 7768.000000 Tape File End Depth = 9142.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 5 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9142.0000 -999.2500 149.2357 91.7745 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.1094 7.3613 6.6269 6.7008 -999.2500 -999.2500 -999.2500 150.9011 -999.2500 -999.2500 -999.2500 -999.2500 109.8341 -999.2500 -999.2500 -999.2500 -999.2500 8.6574 1503.5000 19355.5000 5.3109 4.3600 6.4104 121.3925 21.9913 9142.2500 -999.2500 149.2357 91.7745 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.1094 7.3715 6.6344 6.7008 -999.2500 -999.2500 -999.2500 150.7285 -999.2500 -999.2500 -999.2500 -999.2500 i12.4803 -999.2500 -999.2500 -999.2500 -999.2500 8.6574 1500.0000 19357.5000 5.3109 4.9939 6.4104 121.1900 19.9921 9150.0000 -999.2500 -999.2500 154.2068 93.1623 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.2847 8.8452 7.4210 6.6641 19.5452 6.4848 -999.2500 119.4125 -999.2500 150.0569 -999.2500 -999.2500 109.6017 -999.2500 -999.2500 -999.2500 1489.5000 19418.5000 19.2453 6.2064 32.9864 9200.0000 -999.2500 -999.2500 156.0550 93.6714 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.3097 8.9142 7.1751 6.4649 27.6320 6.4080 -999.2500 108.5844 -999.2500 154.6807 -999.2500 -999.2500 104.5651 -999.2500 -999.2500 -999.2500 170.5000 19820.5000 31.3618 6.1340 29.9879 9250.0000 -999.2500 -999.2500 171.4747 97.8259 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.8646 9.4780 6.3833 5.8052 24.3025 5.8318 -999.2500 113.3375 -999.2500 172.2599 -999.2500 -999.2500 113.0794 -999.2500 -999.2500 -999.2500 152.0000 20217.5000 23.6252 5.5878 29.9879 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9300.0000 168.5981 -999.2500 -999.2500 -999.2500 6.5343 5.9313 -999.2500 -999.2500 -999.2500 168.6088 96.9830 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 112.9524 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.7656 9.3730 186.0000 20586.0000 5.9309 25.7213 25.6803 5.6926 -999.2500 114.5750 46.2878 9350.0000 -999.2500 -999.2500 -999.2500 165.1189 166.5617 96.5213 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.6025 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6068 9.3007 138.0000 20986.5000 6.6856 6.0562 13.8979 13.5367 5.7512 6.0038 -999.2500 113.2625 57.3177 9400.0000 163.9310 -999.2500 -999.2500 -999.2500 6.7003 6.1001 -999.2500 -999.2500 -999.2500 164.6961 95.8240 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.5029 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.4844 9.2061 122.5000 21389.5000 6.0718 26.8959 25.3135 5.8415 -999.2500 119.6375 25.1371 9450.0000 -999.2500 -999.2500 -999.2500 181.7303 194.8272 103.7408 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 113.7537 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.5508 10.2837 129.0000 21795.5000 6.0464 5.5027 27.7582 25.0829 4.9279 5.1328 -999.2500 122.0000 33.8410 9500.0000 -999.2500 -999.2500 -999.2500 169.7399 170.1452 97.4621 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 112.7482 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6875 9.4286 117.0000 22194.5000 6.4885 5.8914 26.5538 27.3728 5.6327 5.8773 -999.2500 122.9000 36.8794 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM Iq.ACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9528.0000 -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 34.4938 38.9586 -999.2500 -999.2500 124.1375 42.3076 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9142.000000 Tape File End Depth = 9528.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 6 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9578.0000 1.8030 1444.2498 172.9344 98.2324 2.7455 51.3359 -999.2500 3.6864 6043.0000 1458.0000 43.0000 261.4588 19.8281 9.5171 0.0874 -999.2500 28.2365 5.7825 -999.2500 125.9375 -999.2500 -999.2500 66.9300 37.2328 -999.2500 29.1616 45.0789 -999.2500 53.0434 23.3437 41.1888 -999.2500 5.5383 Tape File Start Depth = 9578.000000 Tape File End Depth = 9578.000000 Tape File Level Spacing = 0.000000 Tape File Depth Units = Feet Tape Subtile 7 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPlM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9578.0000 1.8030 1444.2498 172.9344 98.2324 2.7455 51.3359 -999.2500 3.6864 6043.0000 1458.0000 43.0000 261.4588 19.8281 9.5171 0.0874 -999.2500 28.2365 5.7825 -999.2500 125.9375 9578.2500 1.8047 1444.4998 97.8485 79.2268 2.7462 51.2327 -999.2500 3.6868 6015.0000 1458.0000 44.0000 246.3939 16.8281 6.5187 0.0875 -999.2500 28.2365 10.2199 -999.2500 125.9375 9600.0000 2.5123 921.0000 168.2641 97.1853 2.4715 8.3458 0.0408 2.4443 6972.0000 935.0000 144.0000 214.1968 19.6016 9.3498 8.2159 7.2538 5.8336 5.9430 -999.2500 134.1500 -999.2500 -999.2500 66.9300 37.2328 -999.2500 29.1616 45.0789 -999.2500 -999.2500 69.5175 34.1581 -999.2500 28.0492 45.3454 117.0000 7.8457 109.9202 28.0767 877.5000 5.3399 -999.2500 -999.2500 53.0434 23.3437 41.1888 -999.250O 5.5383 -999.2500 52.9438 24.6562 38.0876 -999.2500 8.8189 137.8587 11.5618 32.8750 31.8918 22519.0000 5.6672 9650.0000 2.5566 131.0000 352.0000 -999.2500 -999.2500 -999.2500 2.5251 5.5552 8.9692 5.6590 0.0307 2.5184 107.9257 37.8125 7056.0000 142.0000 377.0000 23.6167 27.2958 188.4710 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 32.7253 35.2126 -999.2500 -999.2500 -999.2500 114.8000 5.2972 527.000O 5.4976 108.5456 25.1450 48.0000 38.1390 1.1043 9700.0000 2.5730 82.0000 164.8060 96.1005 2.5433 4.6647 0.0297 2.5235 7154.0000 99.0000 -999.2500 197.4832 19.4844 9.2256 8.2890 7.3118 40.7869 6.0677 -999.2500 119.9750 136.7654 8.0098 36.5937 28.8755 23035.5000 5.8054 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 9750.0000 2.6023 285.0000 758.0000 120.8910 137.4175 88.4365 2.5357 5.8977 6.2961 2.8887 0.0667 2.4913 106.2277 40.2396 7015.1670 305.0000 789.0000 22.0193 25.6264 178.3369 18.4492 8.1890 76.0000 23379.5000 9.4690 8.2719 28.9128 24.7824 6.9443 7.2771 -999.2500 123.1250 1.7284 9800.0000 2.5535 99.0000 972.0000 136.2010 160.1577 94.8505 2.5313 5.7493 9.1507 5.8471 0.0222 2.5166 110.8097 35.7500 7088.0000 114.0000 1006.0000 25.6199 29.3655 200.2484 19.3437 9.0564 59.0000 23740.5000 8.3145 7.3421 33.0664 31.4281 5.9711 6.2438 -999.2500 127.9625 0.1705 9850.0000 2.5698 112.0000 !179.0000 127.4111 148.9485 91.7398 2.5596 5.6335 8.1959 4.8576 0.0102 2.5528 110.1987 38.7500 7126.0000 129.5000 1217.5000 23.2014 26.8644 185.9368 18.9250 8.6351 64.6667 24062.5000 8.9475 7.8486 27.2646 24.4141 6.4156 6.7137 -999.2500 129.5375 0.0210 9900.0000 2.5608 91.0000 1388.0000 127.1324 155.1964 93.4821 2.5435 5.7241 8.7241 5.4050 0.0268 2.5135 121.1237 37.9375 7093.0000 105.0000 1424.0000 23.6777 27.3589 188.8351 19.1667 8.8707 55.0000 24396.0000 8.9942 7.8658 26.8512 24.9569 6.1607 6.4434 -999.2500 130.5500 0.4120 9950.0000 165.1958 3.5705 6941.0000 183.5786 7.9474 6.0534 2.5911 141.0000 1622.0000 141.8305 96.2007 2.5466 6.0528 6.9540 0.0444 2.5170 106.8206 38.1875 154.0000 1650.0000 22.8021 26.4515 19.5417 9.2396 79.0000 24754.5000 7.0507 27.9284 27.1267 5.7924 -999.2500 131.7875 1.8651 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10000.0000 136.4456 6.9541 6998.0000 193.1653 I0.3556 7.3289 2.5353 426.5000 -999.2500 112.1038 88.1435 2.4846 6.2877 10.2189 0.0506 2.4509 108.3300 36.6339 456.1429 -999.2500 24.4162 28.1217 18.4375 8.1496 404.0000 25070.5000 8.9203 49.6865 52.7024 6.9943 -999.2500 131.7875 0.9244 10050.0000 2.5272 168.5000 1977.5000 117.1037 136.5727 88.1935 2.4909 5.9644 10.6907 7.4431 0.0363 2.4667 108.0066 33.8125 7020.0000 195.0000 2012.5000 27.3358 31.1296 209.9741 18.4297 8.1563 99.0000 25382.5000 9.8300 8.5394 22.3088 17.7158 6.9857 7.3221 -999.2500 124.5125 16.1682 I0100.0000 2.5475 121.0000 2177.0000 118.6025 145.5472 90.7861 2.5129 6.0363 9.5050 6.2143 0.0345 2.4899 106.8206 36.3125 7077.0000 132.0000 2201.0000 25.0339 28.7610 196.8405 18.7969 8.5061 92.0000 25718.5000 9.7252 8.4315 14.1358 15.7200 6.5618 6.8706 -999.2500 127.9625 21.3581 10150.0000 2.5419 105.5000 2375.5000 127.7085 155.7066 93.6212 2.5355 5.7335 9.8320 6.5531 0.0064 2.5313 106.1198 38.7500 7009.0000 131.0000 2415.0000 22.6545 26.2984 182.6862 19.1875 8.8897 48.0000 26036.5000 8.9486 7.8303 43.8038 38.9438 6.1410 6.4223 -999.2500 130.3250 24.4612 10200.00O0 161.9471 4.3889 6959.00O0 184.0836 8.3631 6.1749 2.5776 200.0000 -999.2500 135.5990 95.3229 2.5323 6.4483 7.7436 0.0387 2.5066 109.4081 38.1875 209.0000 -999.2500 22.8874 26.5398 19.4375 9.1205 161.0000 26401.5000 7.3747 16.8917 18.1738 5.9077 -999.2500 132.6875 10.9774 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DPd-IM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10250.0000 2.5799 69.0000 -999.2500 134.4681 168.7089 97.1268 2.5388 5.3526 7.6088 4.2492 0.0303 2.5229 I17.6738 39.9375 6926.0000 80.0000 2765.0000 21.4216 25.0174 175.1552 19.6875 9.3655 41.5000 26727.0000 8.4665 7.4367 68.5271 81.2959 5.6745 5.9274 -999.2500 134.4875 23.6673 10300.0000 2.5721 75.0000 2904.0000 131.2259 156.6551 94.0387 2.5145 5.8134 8.0668 4.7238 0.0576 2.4761 107.6831 35.6875 7082.0000 98.0000 2924.0000 25.6511 29.3977 200.4293 19.2500 6.2749 41.0000 27041.0000 8.7115 7.6204 50.6315 35.9483 6.0825 6.3834 -999.2500 135.4297 17.2410 10350.0000 2.5737 71.0000 3064.0000 121.9412 142.9562 90.0365 2.5425 5.6098 7.9679 4.6213 0.0248 2.5252 108.5995 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.7344 5.8832 46.5000 27365.0000 9.3973 8.2007 36.1696 35.9504 6.6803 6.9952 -999.2500 136.2875 23.4100 10368.0000 -999.2500 -999.2500 -999.2500 127.6936 146.5207 91.0546 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 108.3254 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.8750 6.0639 36.0000 27481.5000 8.9151 7.8312 34.6495 29.5083 6.5202 6.8250 -999.2500 136.6250 17.8039 Tape File Start Depth = 9578.000000 Tape File End Depth = 10368.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 8 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10368.0000 -999.2500 -999.2500 -999.2500 127.6936 146.5207 91.0546 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 108.3254 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.8750 6.0639 36.0000 27481.5000 8.9151 7.8312 34.6495 29.5083 6.5202 6.8250 -999.2500 136.6250 .17.8039 10368.2500 -999.2500 -999,2500 -999.2500 127.6929 150.5975 92.2100 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 113.6198 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 19.0312 6.1107 36.0000 27483.0000 8.9307 7.8313 34.6495 32.9358 6.3453 6.6402 -999.2500 136.6250 18.1359 10400.0000 -999.2500 -999.2500 -999.2500 115.4179 125.4568 84.9309 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.4335 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.7187 7.6981 4772.0000 25157.0000 II.6028 8.6642 26.3758 32.1238 7.5802 7.9709 -999.2500 136.9625 19.0131 10450.0000 -999.2500 -999.2500 -999.2500 53.5953 87.9193 72.3892 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100.0760 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.1406 6.0340 4695.5000 25483.5000 26.6124 18.6584 42.7963 43.2181 10.7503 11.3741 -999.2500 137.7500 5.1283 10500.0000 -999.2500 -999.2500 -999.2500 142.4974 167.1611 96.8003 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 116.3901 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 20.6562 9.3020 68.5000 25814.5000 9.6508 7.0177 15.3328 14.7338 5.7157 5.9823 -999.2500 115.3625 8.0587 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10520.0000 -999.2500 -999.2500 106.4374 78.8504 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.0937 6.8861 16.5046 11.6683 47.8171 9.3952 -999.2500 117.9500 -999.2500 85.7020 -999.2500 -999.2500 113.1888 -999.2500 -999.2500 -999.2500 3715.5000 25948.0000 51.5384 8.9112 15.1926 Tape File Start Depth = 10368.000000 Tape File End Depth = 10520.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 9 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10520.0000 -999.2500 -999.2500 106.4374 78.8504 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.0937 6.8861 16.5046 11.6683 47.8171 9.3952 -999.2500 117.9500 10520.2500 -999.2500 -999.2500 103.7614 77.9520 ~999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.9687 6.7670 16.1691 11.4933 47.8171 9.637'5 -999.2500 117.9500 10550.0000 -999.2500 -999.2500 117.6196 82.4809 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.4583 7.3699 14.5410 10.3552 54.6056 8.5020 -999.2500 116.0000 10600.0000 -999.2500 -999.2500 99.5127 76.5117 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.7604 6.5763 20.6474 14.0966 49.2139 10.0490 -999.2500 113.8437 10650.0000 -999.2500 -999.2500 99.4593 76.4937 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.8047 6.5739 22.4330 15.0178 51.6335 10.0544 -999.2500 113.0562 -999.2500 85.7020 -999.2500 -999.2500 113.1888 -999.2500 -999.2500 -999.2500 3715.5000 25948.0000 51.5384 8.9112 15.1926 -999.2500 87.0072 -999.2500 -999.2500 103.9544 -999.2500 -999.2500 -999.2500 3715.0000 25949.5000 49.0575 9.1372 15.2207 -999.2500 96.5701 -999.2500 -999.2500 119.6323 -999.2500 -999.2500 -999.2500 2991.5000 26157.0000 62.0208 8.0780 13.7663 -999.2500 70.9392 -999.2500 -999.2500 108.9410 -999.2500 -999.2500 -999.2500 53.5000 26507.0000 48.2487 9.5181 9.9999 -999.2500 66.5875 -999.2500 -999.2500 108.8179 -999.2500 -999.2500 -999.2500 56.5000 26843.0000 54.6583 9.5230 9.6681 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10700.0000 -999.2500 -999.2500 -999.2500 67.0715 103.8089 77.9694 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 111.1983 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.0625 6.7691 64.5000 27187.0000 22.3721 14.9095 55.0329 58.1287 9.1328 9.6331 -999.2500 116.6000 10.7975 10750.0000 -999.2500 -999.2500 -999.2500 40.3788 67.6797 64.4748 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.9189 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.3750 5.0099 103.0000 27517.5000 44.9512 24.7655 52.9616 59.0677 13.8993 14.7755 -999.2500 118.2875 8.5864 10800.0000 -999.2500 -999.2500 -999.2500 20.1646 36.1986 49.2502 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 58.2751 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.6042 3.1389 75.0000 27874.5000 453.9620 49.5918 59.2223 62.0696 25.6630 27.6254 -999.2500 119.7125 9.6870 10850.0000 -999.2500 -999.2500 -999.2500 70.5560 104.0498 78.0539 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 96.8748 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.3646 6.7814 53.5000 28220.0000 20.9332 14.1731 47.6901 46.3558 9.1112 9.6108 -999.2500 121.6625 9.5894 10900.0000 -999.2500 -999.2500 -999.2500 64.2473 94.1330 74.6176 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 98.5574 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.9792 6.3274 155.0000 28500.5000 23.3307 15.5649 60.0618 58.1287 10.0564 10.6233 -999.2500 122.4500 9.3355 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10950.0000 -999.2500 -999.2500 112.2704 80.7622 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.8437 7.1415 19.6004 13.3514 46.4625 8.9071 -999.2500 126.0500 10974.0000 -999.2500 -999.2500 98.1357 75.9149 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.2031 6.5122 24.3489 15.9553 43.0525 10.1900 -999.2500 126.8375 -999.2500 74.8983 -999.2500 -999.2500 114.9389 -999.2500 -999.2500 -999.2500 59.0000 28866.5000 47.2133 8.4572 9.1713 -999.2500 62.6750 -999.2500 -999.2500 111.4035 -999.2500 -999.2500 -999.2500 135.0000 29021.5000 44.4891 9.6829 9.5261 Tape File Start Depth = 10520.000000 Tape File End Depth = 10974.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 10 is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 10974.0000 -999.2500 -999.2500 -999.2500 62.6750 98.1357 75.9149 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 111.4035 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.2031 6.5122 135.0000 29021.5000 24.3489 15.9553 43.0525 44.4891 9.6829 lO.1900 -999.2500 126.8375 9.5261 10974.2500 -999.2500 -999.2500 -999.2500 70.1845 101.6653 77.2258 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.8494 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.2500 6.6716 2037.0000 29023.0000 21.0021 14.2481 43.0525 43.5313 9.3264 9.8362 -999.2500 126.8375 9.3418 11000.0000 -999.2500 -999.2500 -999.2500 68.8867 89.0277 72.7705 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 114.2354 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.6250 6.0849 2015.5000 29177.0000 21.1010 14.5166 59.2756 57.1129 10.6266 11.2325 -999.2500 127.0625 9.9781 11050.0000 -999.2500 -999.2500 -999.2500 116.3237 140.2641 89.3233 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 121.9769 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 20.0740 8.2899 43.5000 29565.0000 12.0658 8.5967 10.2760 10.2346 6.7961 7.1294 -999.2500 126.8750 29.5183 11100.0000 -999.2500 -999.2500 -999.2500 62.8146 98.5485 76.1798 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.1541 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.4659 6.5299 37.3333 29986.5000 24.2503 15.9199 13.1530 12.3303 9.6093 10.1473 -999.2500 132.8000 29.5259 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS R~CM RPDE STVD TCDM WBCS 11105.0000 -999.2500 -999.2500 86.9127 72.0282 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.0729 5.9846 31.2324 20.7316 12.7056 11.5058 -999.2500 133.7000 -999.2500 48.2356 -999.2500 -999.2500 111.4035 -999.2500 -999.2500 -999.2500 7466.5000 30027.0000 13.0290 10.8695 29.0782 Tape File Start Depth = 10974.000000 Tape File End Depth = I I105.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile II is type: LIS DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 11105.0000 -999.2500 -999.2500 -999.2500 48.2356 86.9127 72.0282 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 111.4035 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.0729 5.9846 7466.5000 30027.0000 31.2324 20.7316 12.7056 13.0290 10.8695 11.5058 -999.2500 133.7000 29.0782 11105.2500 -999.2500 -999.2500 -999.2500 55.7425 95.5351 75.3160 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.4335 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.4722 6.3925 7469.0000 30028.5000 25.2268 17.9396 12.7056 12.8134 9.8527 10.4674 -999.2500 133.7750 29.1630 11150.0000 -999.2500 -999.2500 -999.2500 31.3057 62.1935 62.1259 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 85.8551 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 16.4062 4.7111 4891.0000 -999.2500 68.1715 31.9431 2.5754 2.5755 15.1037 16.0789 -999.2500 127.0625 -999.2500 11200.0000 -999.2500 -999.2500 -999.2500 -999.2500 14.3906 33.9964 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 45.2854 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13.0625 1.4888 4122.0000 30475.5000 -999.2500 -999.2500 6.6974 7.1020 62.8950 69.4898 -999.2500 124.4750 -999.2500 11250.0000 -999.2500 -999.2500 -999.2500 52.1021 114.4816 81.4915 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 105.1241 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 18.7812 7.2363 2239.0000 30740.5000 26.5621 19.1931 1.9594 2.0761 8.2931 8.7350 -999.2500 122.9000 -999.2500 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM WBCS 11300.0000 -999.2500 -999.2500 -999.2500 157.0978 '212.5263 108.1155 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 142.5541 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 22.5562 10.8442 14.0000 31100.0000 7.1614 6.3655 39.1742 38.5205 4.5123 4.7053 -999.2500 126.7250 -999.2500 11350.0000 -999.2500 -999.2500 -999.2500 134.8078 179.6094 100.0433 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 123.5929 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.5521 9.7417 8.5000 31480~0000 8.4690 7.4180 45.3140 45.0365 5.3257 5.5676 -999.2500 129.5375 -999.2500 11400.0000 -999.2500 -999.2500 -999.2500 130.4603 181.9448 100.6421 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 129.5337 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.6875 9.8234 9.6667 31827.5000 8.8106 7.6652 54.8631 60.0053 5.2581 5.4962 -999.2500 130.9438 -999.2500 11450.0000 -999.2500 -999.2500 -999.2500 136.2789 193.4368 103.5171 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 150.1468 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 22.1458 10.2157 15.0000 32202.0000 8.4025 7.3379 46.4579 51.7459 4.9507 5.1696 -999.2500 133.8125 -999.2500 11500.0000 -999.2500 -999.2500 -999.2500 77.2130 72.1221 66.3143 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 65.2932 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 17.2135 5.2441 9.3333 32550.5000 15.5306 12.9512 71.8429 60.0169 13.0540 13.8654 -999.2500 135.1625 -999.2500 DEPTH BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDBM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE STVD TCDM W'BCS 11549.0000 -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 31.2900 31.2900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 11105.000000 Tape File End Depth --- 11549.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 12 is t-ype: LIS
